CA2524689A1 - Thermal processes for subsurface formations - Google Patents
Thermal processes for subsurface formations Download PDFInfo
- Publication number
- CA2524689A1 CA2524689A1 CA002524689A CA2524689A CA2524689A1 CA 2524689 A1 CA2524689 A1 CA 2524689A1 CA 002524689 A CA002524689 A CA 002524689A CA 2524689 A CA2524689 A CA 2524689A CA 2524689 A1 CA2524689 A1 CA 2524689A1
- Authority
- CA
- Canada
- Prior art keywords
- formation
- electrically resistive
- heater
- ferromagnetic material
- temperature
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Granted
Links
- 230000015572 biosynthetic process Effects 0.000 title claims abstract 1167
- 238000000034 method Methods 0.000 title claims abstract 1086
- 230000008569 process Effects 0.000 title claims abstract 4
- 238000005755 formation reaction Methods 0.000 title claims 1159
- 229930195733 hydrocarbon Natural products 0.000 claims abstract 366
- 150000002430 hydrocarbons Chemical class 0.000 claims abstract 366
- 239000004215 Carbon black (E152) Substances 0.000 claims abstract 178
- 238000012546 transfer Methods 0.000 claims abstract 110
- 239000004020 conductor Substances 0.000 claims 778
- 239000003302 ferromagnetic material Substances 0.000 claims 557
- 239000012530 fluid Substances 0.000 claims 232
- 230000002829 reductive effect Effects 0.000 claims 226
- 238000010438 heat treatment Methods 0.000 claims 204
- 239000000203 mixture Substances 0.000 claims 141
- 230000007423 decrease Effects 0.000 claims 81
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 claims 80
- XEEYBQQBJWHFJM-UHFFFAOYSA-N Iron Chemical compound [Fe] XEEYBQQBJWHFJM-UHFFFAOYSA-N 0.000 claims 74
- 238000004519 manufacturing process Methods 0.000 claims 68
- 239000000463 material Substances 0.000 claims 65
- 230000004888 barrier function Effects 0.000 claims 62
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 claims 54
- 239000002689 soil Substances 0.000 claims 51
- PXHVJJICTQNCMI-UHFFFAOYSA-N Nickel Chemical compound [Ni] PXHVJJICTQNCMI-UHFFFAOYSA-N 0.000 claims 50
- 230000003247 decreasing effect Effects 0.000 claims 50
- 230000005294 ferromagnetic effect Effects 0.000 claims 46
- 239000007789 gas Substances 0.000 claims 45
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims 44
- 239000001257 hydrogen Substances 0.000 claims 41
- 229910052739 hydrogen Inorganic materials 0.000 claims 41
- UFHFLCQGNIYNRP-UHFFFAOYSA-N Hydrogen Chemical compound [H][H] UFHFLCQGNIYNRP-UHFFFAOYSA-N 0.000 claims 39
- 229910052742 iron Inorganic materials 0.000 claims 37
- 238000000197 pyrolysis Methods 0.000 claims 36
- 239000008186 active pharmaceutical agent Substances 0.000 claims 34
- 239000000446 fuel Substances 0.000 claims 34
- 230000005484 gravity Effects 0.000 claims 34
- 239000000615 nonconductor Substances 0.000 claims 30
- 239000001569 carbon dioxide Substances 0.000 claims 27
- 229910002092 carbon dioxide Inorganic materials 0.000 claims 27
- 230000001590 oxidative effect Effects 0.000 claims 27
- 229910052759 nickel Inorganic materials 0.000 claims 25
- VYZAMTAEIAYCRO-UHFFFAOYSA-N Chromium Chemical compound [Cr] VYZAMTAEIAYCRO-UHFFFAOYSA-N 0.000 claims 22
- 239000011651 chromium Substances 0.000 claims 22
- 229910052804 chromium Inorganic materials 0.000 claims 22
- 238000002156 mixing Methods 0.000 claims 22
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 claims 21
- 229910045601 alloy Inorganic materials 0.000 claims 21
- 239000000956 alloy Substances 0.000 claims 21
- 229910052799 carbon Inorganic materials 0.000 claims 21
- 230000036961 partial effect Effects 0.000 claims 21
- 239000003507 refrigerant Substances 0.000 claims 21
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 claims 20
- 239000007800 oxidant agent Substances 0.000 claims 20
- RYGMFSIKBFXOCR-UHFFFAOYSA-N Copper Chemical compound [Cu] RYGMFSIKBFXOCR-UHFFFAOYSA-N 0.000 claims 19
- 239000010941 cobalt Substances 0.000 claims 19
- 229910017052 cobalt Inorganic materials 0.000 claims 19
- GUTLYIVDDKVIGB-UHFFFAOYSA-N cobalt atom Chemical compound [Co] GUTLYIVDDKVIGB-UHFFFAOYSA-N 0.000 claims 19
- 229910052802 copper Inorganic materials 0.000 claims 19
- 239000010949 copper Substances 0.000 claims 19
- 238000011065 in-situ storage Methods 0.000 claims 18
- WFKWXMTUELFFGS-UHFFFAOYSA-N tungsten Chemical compound [W] WFKWXMTUELFFGS-UHFFFAOYSA-N 0.000 claims 17
- 239000010937 tungsten Substances 0.000 claims 17
- 229910052721 tungsten Inorganic materials 0.000 claims 17
- 239000012777 electrically insulating material Substances 0.000 claims 15
- 150000002989 phenols Chemical class 0.000 claims 15
- 239000004568 cement Substances 0.000 claims 14
- 239000001307 helium Substances 0.000 claims 14
- 229910052734 helium Inorganic materials 0.000 claims 14
- SWQJXJOGLNCZEY-UHFFFAOYSA-N helium atom Chemical compound [He] SWQJXJOGLNCZEY-UHFFFAOYSA-N 0.000 claims 14
- 239000012071 phase Substances 0.000 claims 13
- 238000005553 drilling Methods 0.000 claims 12
- 238000007254 oxidation reaction Methods 0.000 claims 12
- 230000035699 permeability Effects 0.000 claims 12
- 238000002485 combustion reaction Methods 0.000 claims 11
- 238000012544 monitoring process Methods 0.000 claims 11
- 230000003287 optical effect Effects 0.000 claims 11
- 230000000712 assembly Effects 0.000 claims 10
- 238000000429 assembly Methods 0.000 claims 10
- 230000000694 effects Effects 0.000 claims 10
- 238000004880 explosion Methods 0.000 claims 10
- 230000005291 magnetic effect Effects 0.000 claims 10
- 229910052757 nitrogen Inorganic materials 0.000 claims 10
- 230000003647 oxidation Effects 0.000 claims 10
- 238000005086 pumping Methods 0.000 claims 10
- QGZKDVFQNNGYKY-UHFFFAOYSA-N Ammonia Chemical compound N QGZKDVFQNNGYKY-UHFFFAOYSA-N 0.000 claims 8
- 238000009835 boiling Methods 0.000 claims 8
- 239000004927 clay Substances 0.000 claims 8
- 238000007710 freezing Methods 0.000 claims 8
- 230000008014 freezing Effects 0.000 claims 8
- QVGXLLKOCUKJST-UHFFFAOYSA-N atomic oxygen Chemical compound [O] QVGXLLKOCUKJST-UHFFFAOYSA-N 0.000 claims 7
- 239000003990 capacitor Substances 0.000 claims 7
- 150000004767 nitrides Chemical class 0.000 claims 7
- 239000001301 oxygen Substances 0.000 claims 7
- 229910052760 oxygen Inorganic materials 0.000 claims 7
- 230000010363 phase shift Effects 0.000 claims 7
- 230000001902 propagating effect Effects 0.000 claims 7
- 229910052581 Si3N4 Inorganic materials 0.000 claims 6
- 229910000831 Steel Inorganic materials 0.000 claims 6
- 239000003245 coal Substances 0.000 claims 6
- 239000002131 composite material Substances 0.000 claims 6
- 230000002401 inhibitory effect Effects 0.000 claims 6
- HQVNEWCFYHHQES-UHFFFAOYSA-N silicon nitride Chemical compound N12[Si]34N5[Si]62N3[Si]51N64 HQVNEWCFYHHQES-UHFFFAOYSA-N 0.000 claims 6
- 239000010959 steel Substances 0.000 claims 6
- 230000003197 catalytic effect Effects 0.000 claims 5
- 238000005260 corrosion Methods 0.000 claims 5
- 230000007797 corrosion Effects 0.000 claims 5
- 239000002360 explosive Substances 0.000 claims 5
- 239000012528 membrane Substances 0.000 claims 5
- 238000013508 migration Methods 0.000 claims 5
- 230000005012 migration Effects 0.000 claims 5
- 239000004058 oil shale Substances 0.000 claims 5
- 238000004088 simulation Methods 0.000 claims 5
- 229910052582 BN Inorganic materials 0.000 claims 4
- PZNSFCLAULLKQX-UHFFFAOYSA-N Boron nitride Chemical compound N#B PZNSFCLAULLKQX-UHFFFAOYSA-N 0.000 claims 4
- 229910021529 ammonia Inorganic materials 0.000 claims 4
- 238000004939 coking Methods 0.000 claims 4
- 238000004891 communication Methods 0.000 claims 4
- 239000011810 insulating material Substances 0.000 claims 4
- 230000001681 protective effect Effects 0.000 claims 4
- 238000000926 separation method Methods 0.000 claims 4
- 229910052782 aluminium Inorganic materials 0.000 claims 3
- XAGFODPZIPBFFR-UHFFFAOYSA-N aluminium Chemical compound [Al] XAGFODPZIPBFFR-UHFFFAOYSA-N 0.000 claims 3
- 239000003795 chemical substances by application Substances 0.000 claims 3
- 230000008878 coupling Effects 0.000 claims 3
- 238000010168 coupling process Methods 0.000 claims 3
- 238000005859 coupling reaction Methods 0.000 claims 3
- 239000000835 fiber Substances 0.000 claims 3
- 239000013529 heat transfer fluid Substances 0.000 claims 3
- 230000000670 limiting effect Effects 0.000 claims 3
- 239000002245 particle Substances 0.000 claims 3
- 230000000644 propagated effect Effects 0.000 claims 3
- 230000009919 sequestration Effects 0.000 claims 3
- 238000007493 shaping process Methods 0.000 claims 3
- 238000004513 sizing Methods 0.000 claims 3
- 229910021647 smectite Inorganic materials 0.000 claims 3
- 238000003786 synthesis reaction Methods 0.000 claims 3
- 229910000975 Carbon steel Inorganic materials 0.000 claims 2
- 229910000570 Cupronickel Inorganic materials 0.000 claims 2
- 238000001069 Raman spectroscopy Methods 0.000 claims 2
- 238000013459 approach Methods 0.000 claims 2
- 238000003556 assay Methods 0.000 claims 2
- 239000010962 carbon steel Substances 0.000 claims 2
- 239000000919 ceramic Substances 0.000 claims 2
- 150000001875 compounds Chemical class 0.000 claims 2
- YOCUPQPZWBBYIX-UHFFFAOYSA-N copper nickel Chemical compound [Ni].[Cu] YOCUPQPZWBBYIX-UHFFFAOYSA-N 0.000 claims 2
- 150000002431 hydrogen Chemical class 0.000 claims 2
- 238000009413 insulation Methods 0.000 claims 2
- 239000000395 magnesium oxide Substances 0.000 claims 2
- CPLXHLVBOLITMK-UHFFFAOYSA-N magnesium oxide Inorganic materials [Mg]=O CPLXHLVBOLITMK-UHFFFAOYSA-N 0.000 claims 2
- AXZKOIWUVFPNLO-UHFFFAOYSA-N magnesium;oxygen(2-) Chemical compound [O-2].[Mg+2] AXZKOIWUVFPNLO-UHFFFAOYSA-N 0.000 claims 2
- WPBNNNQJVZRUHP-UHFFFAOYSA-L manganese(2+);methyl n-[[2-(methoxycarbonylcarbamothioylamino)phenyl]carbamothioyl]carbamate;n-[2-(sulfidocarbothioylamino)ethyl]carbamodithioate Chemical compound [Mn+2].[S-]C(=S)NCCNC([S-])=S.COC(=O)NC(=S)NC1=CC=CC=C1NC(=S)NC(=O)OC WPBNNNQJVZRUHP-UHFFFAOYSA-L 0.000 claims 2
- 229910052751 metal Inorganic materials 0.000 claims 2
- 239000002184 metal Substances 0.000 claims 2
- 230000005404 monopole Effects 0.000 claims 2
- 238000013021 overheating Methods 0.000 claims 2
- 239000008188 pellet Substances 0.000 claims 2
- 238000010992 reflux Methods 0.000 claims 2
- 230000003252 repetitive effect Effects 0.000 claims 2
- 238000007789 sealing Methods 0.000 claims 2
- 239000010935 stainless steel Substances 0.000 claims 2
- 229910001220 stainless steel Inorganic materials 0.000 claims 2
- 239000003476 subbituminous coal Substances 0.000 claims 2
- 229910052715 tantalum Inorganic materials 0.000 claims 2
- GUVRBAGPIYLISA-UHFFFAOYSA-N tantalum atom Chemical compound [Ta] GUVRBAGPIYLISA-UHFFFAOYSA-N 0.000 claims 2
- 238000003466 welding Methods 0.000 claims 2
- 150000005207 1,3-dihydroxybenzenes Chemical class 0.000 claims 1
- PETRWTHZSKVLRE-UHFFFAOYSA-N 2-Methoxy-4-methylphenol Chemical class COC1=CC(C)=CC=C1O PETRWTHZSKVLRE-UHFFFAOYSA-N 0.000 claims 1
- OTMSDBZUPAUEDD-UHFFFAOYSA-N Ethane Chemical compound CC OTMSDBZUPAUEDD-UHFFFAOYSA-N 0.000 claims 1
- VGGSQFUCUMXWEO-UHFFFAOYSA-N Ethene Chemical compound C=C VGGSQFUCUMXWEO-UHFFFAOYSA-N 0.000 claims 1
- ISWSIDIOOBJBQZ-UHFFFAOYSA-N Phenol Chemical compound OC1=CC=CC=C1 ISWSIDIOOBJBQZ-UHFFFAOYSA-N 0.000 claims 1
- 235000017899 Spathodea campanulata Nutrition 0.000 claims 1
- NINIDFKCEFEMDL-UHFFFAOYSA-N Sulfur Chemical compound [S] NINIDFKCEFEMDL-UHFFFAOYSA-N 0.000 claims 1
- 150000001336 alkenes Chemical class 0.000 claims 1
- 238000004458 analytical method Methods 0.000 claims 1
- 150000001491 aromatic compounds Chemical class 0.000 claims 1
- 230000015556 catabolic process Effects 0.000 claims 1
- 230000008859 change Effects 0.000 claims 1
- 238000009833 condensation Methods 0.000 claims 1
- 230000005494 condensation Effects 0.000 claims 1
- 150000001924 cycloalkanes Chemical class 0.000 claims 1
- 238000006731 degradation reaction Methods 0.000 claims 1
- 238000004821 distillation Methods 0.000 claims 1
- 230000005611 electricity Effects 0.000 claims 1
- 239000003337 fertilizer Substances 0.000 claims 1
- PCHJSUWPFVWCPO-UHFFFAOYSA-N gold Chemical compound [Au] PCHJSUWPFVWCPO-UHFFFAOYSA-N 0.000 claims 1
- 229910052737 gold Inorganic materials 0.000 claims 1
- 239000010931 gold Substances 0.000 claims 1
- 238000005984 hydrogenation reaction Methods 0.000 claims 1
- 230000000977 initiatory effect Effects 0.000 claims 1
- 229910052500 inorganic mineral Inorganic materials 0.000 claims 1
- 230000001788 irregular Effects 0.000 claims 1
- 239000007788 liquid Substances 0.000 claims 1
- 239000000696 magnetic material Substances 0.000 claims 1
- 239000010445 mica Substances 0.000 claims 1
- 229910052618 mica group Inorganic materials 0.000 claims 1
- 239000011707 mineral Substances 0.000 claims 1
- 239000013307 optical fiber Substances 0.000 claims 1
- 229920001296 polysiloxane Polymers 0.000 claims 1
- 239000000843 powder Substances 0.000 claims 1
- 239000012779 reinforcing material Substances 0.000 claims 1
- 230000000630 rising effect Effects 0.000 claims 1
- 150000003839 salts Chemical class 0.000 claims 1
- 239000003381 stabilizer Substances 0.000 claims 1
- 230000003068 static effect Effects 0.000 claims 1
- 239000004575 stone Substances 0.000 claims 1
- 239000000126 substance Substances 0.000 claims 1
- 229910052717 sulfur Inorganic materials 0.000 claims 1
- 239000011593 sulfur Substances 0.000 claims 1
- 239000012808 vapor phase Substances 0.000 claims 1
- 239000004079 vitrinite Substances 0.000 claims 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
- E21B43/243—Combustion in situ
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B36/00—Heating, cooling, insulating arrangements for boreholes or wells, e.g. for use in permafrost zones
- E21B36/02—Heating, cooling, insulating arrangements for boreholes or wells, e.g. for use in permafrost zones using burners
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B36/00—Heating, cooling, insulating arrangements for boreholes or wells, e.g. for use in permafrost zones
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B36/00—Heating, cooling, insulating arrangements for boreholes or wells, e.g. for use in permafrost zones
- E21B36/001—Cooling arrangements
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B36/00—Heating, cooling, insulating arrangements for boreholes or wells, e.g. for use in permafrost zones
- E21B36/04—Heating, cooling, insulating arrangements for boreholes or wells, e.g. for use in permafrost zones using electrical heaters
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/006—Production of coal-bed methane
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
- E21B43/2401—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection by means of electricity
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/06—Measuring temperature or pressure
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/06—Measuring temperature or pressure
- E21B47/07—Temperature
Abstract
A process may include providing heat from one or more heaters to at least a portion of a subsurface formation. Heat may transfer from one or more heater s to a part of a formation. In some embodiments, heat from the one or more hea t sources may pyrolyze at least some hydrocarbons in a part of a subsurface formation. Hydrocarbons and/or other products may be produced from a subsurface formation. Certain embodiments describe apparatus, methods, and/or processes used in treating a subsurface or hydrocarbon containing formation.
Claims (25)
1. A method for forming at least one opening in a geological formation, comprising:
forming a portion of an opening in the formation;
providing an acoustic wave to at least a portion of the formation, wherein the acoustic wave is configured to propagate between at least one geological discontinuity of the formation and at least a portion of the opening;
sensing at least one reflection of the acoustic wave in at least a portion of the opening;
using the sensed reflection to assess an approximate location of at least a portion of the opening in the formation; and forming an additional portion of the opening based on, at least in part, the assessed approximate location of at least a portion of the opening.
forming a portion of an opening in the formation;
providing an acoustic wave to at least a portion of the formation, wherein the acoustic wave is configured to propagate between at least one geological discontinuity of the formation and at least a portion of the opening;
sensing at least one reflection of the acoustic wave in at least a portion of the opening;
using the sensed reflection to assess an approximate location of at least a portion of the opening in the formation; and forming an additional portion of the opening based on, at least in part, the assessed approximate location of at least a portion of the opening.
2. The method of claim 1, further comprising using the sensed reflection to maintain an approximate desired location of the opening between an overburden of the formation and an underburden of the formation.
3. The method of claim 1, wherein at least one geological discontinuity comprises a boundary of the formation.
4. The method of claim 1, further comprising using the sensed reflection to maintain the location of the opening at approximately midway between an overburden of the formation and an underburden of the formation.
5. The method of claim 1, further comprising producing the acoustic wave using a monopole source or a dipole source.
6. The method of claim 1, further comprising sensing the reflection of the acoustic wave using one or more sensors in at least a portion of the opening.
7. The method of claim 1, further comprising producing the acoustic wave using a source for producing the acoustic wave in at least a portion of the opening.
8. The method of claim 1, further comprising producing the acoustic wave using a source for producing the acoustic wave in at least a portion of the opening, and sensing the acoustic wave using one or more sensors in at least a portion of the opening.
9. The method of claim 1, further comprising sensing the reflection of the acoustic wave during formation of at least a portion of the opening in the formation.
10. The method of claim 1, further comprising using a calculated or assessed acoustic velocity in the formation when using the sensed reflection to assess the location of the opening in the formation.
11. The method of claim 1, further comprising propagating an acoustic wave between an overburden of the formation and the opening.
12. The method of claim 1, further comprising propagating an acoustic wave between an underburden of the formation and the opening.
13. The method of claim 1, further comprising propagating an acoustic wave between an overburden of the formation and the opening, and an underburden of the formation and the opening.
14. The method of claim 1, further comprising using information from the sensed acoustic wave to, at least in part, guide a drilling system in forming the opening.
15. The method of claim 1, further comprising substantially simultaneously providing acoustic waves, sensing reflected acoustic waves, and using information from the sensed acoustic waves to, at least in part, guide a drilling system in forming the opening.
16. The method of claim 1, further comprising using information from the sensed acoustic wave to, at least in part, substantially simultaneously guide a drilling system in forming the opening.
17. The method of claim 1, further comprising using information from the sensed acoustic wave to assess a location of at least a part of the opening, and then using such assessed location to, at least in part, guide a drilling system in forming the opening.
18. The method of claim 1, further comprising using information from the sensed acoustic waves to assess locations of parts of the opening, and then using such assessed locations to, at least in part, guide a drilling system in forming the opening.
19. The method of claim 1, wherein a first opening is formed using the sensed acoustic wave, and further comprising forming one or more additional openings by using magnetic tracking to form at least one of the additional openings at a selected approximate distance from the first opening.
20. The method of claim 1, further comprising assessing an approximate orientation of the opening with an inclinometer.
21. The method of claim 1, further comprising assessing an approximate location of the opening relative to a second opening in the formation by detecting one or more magnetic fields produced from the second opening.
22. The method of claim 1, further comprising assessing an approximate location of the opening relative to a second opening in the formation by detecting one or more magnetic fields produced from the second opening with a magnetometer.
23. The method of claim 1, further comprising assessing an approximate location of the opening relative to a second opening in the formation by detecting one or more magnetic fields produced from the second opening so that the opening is formed at an approximate desired distance from the second opening.
24. The method of claim 1, wherein at least a portion of the formation comprises hydrocarbons, the method further comprising heating at least a portion of the formation and pyrolyzing at least some hydrocarbons in the formation.
2S. The method of claim 1, further comprising heating at least a portion of the formation, and controlling a pressure and a temperature in at least a part of the formation, wherein the pressure is controlled as a function of temperature, and/or the temperature is controlled as a function of pressure.
26. The method of claim 1, further comprising heating at least a portion of the formation, and producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API
gravity of at least about 25°.
27. The method of claim 1, further comprising heating at least a portion of the formation, controlling a pressure in at least a part of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.
28. The method of claim 1, further comprising heating at least a portion of the formation, and controlling formation conditions such that a mixture produced from the formation comprises a partial pressure of H2 in the mixture greater than about 0.5 bars.
29. The method of claim 1, further comprising heating at least a portion of the formation, and altering a pressure in the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
30. The method of claim 1, further comprising heating at least a portion of the formation to a minimum pyrolysis temperature of about 270 °C.
31. A method for heating a hydrocarbon containing formation, comprising:
providing heat to the formation from one or more heaters in one or more openings in the formation, wherein at least one of the openings has been formed by:
forming a portion of an opening in the formation;
providing an acoustic wave to at least a portion of the formation, wherein the acoustic wave is configured to propagate between at least one geological discontinuity of the formation and at least a portion of the opening;
sensing at least one reflection of the acoustic wave in at least a portion of the opening; and using the sensed reflection to assess an approximate location of at least a portion of the opening in the formation.
32. The method of claim 31, wherein at least one portion of an opening has been formed based on, at least in part, the assessed approximate location of at least a portion of the opening.
33. The method of claim 31, wherein at least one portion of an opening has been formed using the sensed reflection to maintain an approximate desired location of the opening between an overburden of the formation and an underburden of the formation.
34. The method of claim 31, wherein at least one geological discontinuity comprises a boundary of the formation.
35. The method of claim 31, wherein at least one portion of an opening has been formed based on, at least in part, using the sensed reflection to maintain the location of the opening at approximately midway between an overburden of the formation and an underburden of the formation.
36. The method of claim 31, wherein at least one portion of an opening has been formed based on, at least in part, producing the acoustic wave using a monopole source or a dipole source.
37. The method of claim 31, wherein at least one portion of an opening has been formed based on, at least in part, sensing the reflection of the acoustic wave using one or more sensors in at least a portion of the opening.
38. The method of claim 31, wherein at least one portion of an opening has been formed based on, at least in part, producing the acoustic wave using a source for producing the acoustic wave in at least a portion of the opening.
39. The method of claim 31, wherein at least one portion of an opening has been formed based on, at least in part, producing the acoustic wave using a source for producing the acoustic wave in at least a portion of the opening, and sensing the acoustic wave using one or more sensors in at least a portion of the opening.
40. The method of claim 31, wherein at least one portion of an opening has been formed based on, at least in part, sensing the reflection of the acoustic wave during formation of at least a portion of the opening in the formation.
41. The method of claim 31, wherein at least one portion of an opening has been formed based on, at least in part, using a calculated or assessed velocity in the formation when using the sensed reflection to assess the location of the opening in the formation.
42. The method of claim 31, wherein at least one portion of an opening has been formed based on, at least in part, propagating an acoustic wave between an overburden of the formation and the opening.
43. The method of claim 31, wherein at least one portion of an opening has been formed based on, at least in part, propagating an acoustic wave between an underburden of the formation and the opening.
44. The method of claim 31, wherein at least one portion of an opening has been formed based on, at least in part, propagating an acoustic wave between an overburden of the formation and the opening and an underburden of the formation and the opening.
45. The method of claim 31, wherein at least one portion of an opening has been formed based on, at least in part, using information from the sensed acoustic wave to, at least in part, guide a drilling system in forming the opening.
46. The method of claim 31, wherein at least one portion of an opening has been formed based on, at least in part, substantially simultaneously providing acoustic waves, sensing reflected acoustic waves, and using information from the sensed acoustic waves to, at least in part, guide a drilling system in forming the opening.
47. The method of claim 31, wherein at least one portion of an opening has been formed based on, at least in part, using information from the sensed acoustic wave to, at least in part, substantially simultaneously guide a drilling system in forming the opening.
48. The method of claim 31, wherein at least one portion of an opening has been formed based on, at least in part, using information from the sensed acoustic wave to assess a location of at least a part of the opening, and then using such assessed location to, at least in part, guide a drilling system in forming the opening.
49. The method of claim 31, wherein at least one portion of an opening has been formed based on, at least in part, using information from the sensed acoustic waves to assess locations of parts of the opening, and then using such assessed locations to, at least in part, guide a drilling system in forming the opening.
50. The method of claim 31, wherein at least one portion of an opening has been formed based on, at least in part, using the sensed acoustic wave, and further comprising forming one or more additional openings by using magnetic tracking to form one or more additional openings at a selected approximate distance from the first opening.
51. The method of claim 31, further comprising assessing an approximate orientation of the opening with an inclinometer.
$2. The method of claim 31, further comprising assessing an approximate location of the opening relative to a second opening in the formation by detecting one or more magnetic fields produced from the second opening.
53. The method of claim 31, further comprising assessing an approximate location of the opening relative to a second opening in the formation by detecting one or more magnetic fields produced from the second opening with a magnetometer.
54. The method of claim 31, further comprising assessing an approximate location of the opening relative to a second opening in the formation by detecting one or more magnetic fields produced from the second opening so that the opening is formed at an approximate desired distance from the second opening.
55. The method of claim 31, further comprising pyrolyzing at least some hydrocarbons in the formation.
56. The method of claim 31, further comprising controlling a pressure and a temperature in at least a part of the formation, wherein the pressure is controlled as a function of temperature, and/or the temperature is controlled as a function of pressure.
57. The method of claim 31, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
58. The method of claim 31, further comprising controlling a pressure in at least a part of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.
59. The method of claim 31, further comprising controlling formation conditions such that a produced mixture comprises a partial pressure of H2 in the mixture greater than about 0.5 bars.
60. The method of claim 31, further comprising altering a pressure in the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
61. The method of claim 31, further comprising heating at least a portion of the formation to a minimum pyrolysis temperature of about 270 °C.
62. A method of producing phenolic compounds from a hydrocarbon containing formation, comprising:
providing heat from one or more heaters to at least a portion of the formation;
allowing the heat to transfer from one or more of the heaters to a section of the formation;
producing formation fluids from the formation; and controlling at least one condition in at least a portion of the formation to selectively produce phenolic compounds in the formation fluid, wherein controlling at least one condition comprises controlling production of hydrogen from the formation.
63. The method of claim 62, wherein controlling at least one condition comprises forming a perimeter barrier around a part of the section of the formation to define a treatment area before providing heat.
64. The method of claim 62, wherein controlling at least one condition comprises heating the section to a temperature greater than 260 °C.
65. The method of claim 62, further comprising separating the phenolic compounds from the produced formation fluids.
66. The method of claim 62, further comprising separating the phenolic compounds from the produced formation fluids, wherein the phenolic compounds comprise creosol compounds.
67. The method of claim 62, further comprising separating the phenolic compounds from the produced formation fluids, wherein the phenolic compounds comprise resorcinol compounds.
68. The method of claim 62, further comprising separating the phenolic compounds from the produced formation fluids, wherein the phenolic compounds comprise phenol.
69. The method of claim 62, wherein the mixture is produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars.
70. The method of claim 62, further comprising controlling the heating of the portion of the formation such that a temperature of a majority of the portion is less than about 375 °C.
71. The method of claim 62, wherein the formation fluids produced further comprise hydrocarbons having an average API gravity greater than about 25°.
72. A method of treating a hydrocarbon containing formation in situ, comprising:
providing heat from one or more heaters to at least a portion of the formation;
allowing the heat to transfer from one or more of the heaters to a section of the formation;
providing hydrogen to the section, wherein a flow rate of hydrogen is controlled as a function of an amount of hydrogen in a mixture produced from the formation; and producing the mixture from the formation.
73. The method of claim 72, further comprising reducing an amount of the mixture produced from one or more production wells in the formation based on the amount of hydrogen produced from one or more of the production wells in the formation.
74. The method of claim 72, wherein the amount of hydrogen in the mixture produced from the formation is assessed by determining a partial pressure of the hydrogen in gases produced from one or more production wells.
75. The method of claim 74, wherein the partial pressure of the hydrogen in gases produced from one or more production wells is at least about 0.5 bars.
76. The method of claim 72, wherein the amount of hydrogen in the mixture produced from the formation is assessed by determining an initial pressure in the formation before providing hydrogen to the section, and wherein producing a mixture from the formation comprises producing the mixture when a pressure in the formation after hydrogen has been provided to the section decreases to approximately the initial pressure in the formation.
77. The method of claim 72, wherein the amount of hydrogen in the mixture produced from the formation is assessed by determining an increase in production of condensable hydrocarbons produced from the formation.
78. The method of claim 72, wherein producing a mixture from the formation comprises pumping the mixture with a submersible pump.
79. The method of claim 72, wherein the produced mixture comprises substantially condensable hydrocarbons.
80. The method of claim 72, wherein the produced mixture comprises phenols.
81. The method of claim 72, further comprising controlling heating of the portion of the formation such that a temperature of a majority of the portion is less than about 375 °C.
82. The method of claim 72, wherein the produced mixture comprises hydrocarbons having an average API
gravity greater than about 25°.
83. A method of treating a hydrocarbon containing formation in situ, comprising:
providing heat from one or more heaters to at least a portion of the formation;
allowing the heat to transfer from one or more of the heaters to a section of the formation;
providing hydrogen to the section of the formation; and controlling production of hydrogen from a plurality of production wells in the formation; wherein the production of hydrogen produced from one or more production wells is controlled by selectively and preferentially producing the mixture as a liquid from the formation.
84. The method of claim 83, wherein controlling hydrogen production from the formation comprises inhibiting production of gas from the formation.
85. The method of claim 83, wherein controlling hydrogen production from the formation comprises increasing production of condensable hydrocarbons from the formation.
86. The method of claim 83, wherein the mixture comprises condensable hydrocarbons, and wherein producing the mixture comprises pumping the mixture with a submersible pump.
87. The method of claim 83, further comprising controlling the heat provided to the formation such that a temperature of a majority of the section is less than about 375 °C.
88. The method of claim 83, wherein the produced mixture comprises hydrocarbons having an average API
gravity greater than about 25°.
89. The method of claim 83, wherein the mixture is produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars.
90. The method of claim 83, wherein the produced mixture comprises phenols.
91. A method of treating a hydrocarbon containing formation in situ, comprising:
providing heat from one or more heaters to at least a portion of the formation;
allowing the heat to transfer from one or more of the heaters to a section of the formation;
providing a mixture of hydrogen and a carrier fluid to the section;
controlling production of hydrogen from the formation; and producing formation fluid from the formation.
92. The method of claim 91, wherein the carrier fluid is nitrogen.
93. The method of claim 91, wherein the carrier fluid is methane.
94. The method of claim 91, wherein the carrier fluid is carbon dioxide.
95. The method of claim 91, wherein an amount of hydrogen in the mixture ranges from about 1 wt% to about 80 wt%.
96. The method of claim 91, wherein controlling hydrogen production from the formation comprises inhibiting production of gas from the formation.
97. The method of claim 91, wherein controlling hydrogen production from the formation comprises increasing production of condensable hydrocarbons from the formation.
98. The method of claim 91, wherein the produced formation fluid comprises condensable hydrocarbons and wherein producing the formation fluid comprises pumping the mixture with a submersible pump.
99. The method of claim 91, wherein the produced formation fluid comprises phenols.
100. The method of claim 91, wherein the mixture is produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars.
101. The method of claim 91, further comprising controlling the heating of the portion of the formation such that a temperature of a majority of the portion is less than about 375 °C.
102. The method of claim 91, wherein the formation fluid produced further comprises hydrocarbons having an average API gravity greater than about 25°.
103. A method of treating a hydrocarbon containing formation in situ, comprising;
forming a barrier around a treatment area of the formation to inhibit migration of fluids from the treatment area of the formation;
providing hydrogen to the treatment area;
providing heat from one or more heaters to the treatment area;
allowing the heat to transfer from one or more of the heaters to a section of the formation;
controlling production of hydrogen from the formation; and producing a mixture from the formation.
104. The method of claim 103, wherein controlling the production of hydrogen from the formation comprises inhibiting gas production from the formation.
105. The method of claim 103, wherein controlling the production of hydrogen from the formation comprises increasing condensable hydrocarbons production from the formation.
106. The method of claim 103, wherein controlling the production of hydrogen from the formation comprises increasing condensable hydrocarbons production, and wherein producing the mixture comprises pumping the condensable hydrocarbons with a submersible pump.
107. The method of claim 103, wherein the produced mixture comprises condensable hydrocarbons.
108. The method of claim 103, wherein the produced mixture comprises phenols.
109. The method of claim 103, wherein the mixture is produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars.
110. The method of claim 103, further comprising controlling the heating of the portion of the formation such that a temperature of a majority of the portion is less than about 375 °C.
111. The method of claim 103, wherein the formation fluid produced further comprises hydrocarbons having an average API gravity greater than about 25°.
112. A method of treating a hydrocarbon containing formation in situ, comprising;
providing a refrigerant to a plurality of barrier wells surrounding a treatment area of the formation;
establishing a frozen barrier zone to inhibit migration of fluids from the treatment area of the formation;
providing hydrogen to the treatment area;
providing heat from one or more heaters to the treatment area;
allowing the heat to transfer from one or more of the heaters to a section of the formation;
controlling production of hydrogen from the section; and producing a mixture from the formation.
113. The method of claim 112, wherein controlling hydrogen production from the formation comprises inhibiting gas production from the formation.
114. The method of claim 112, wherein controlling hydrogen production from the formation comprises increasing production of condensable hydrocarbons from the formation.
115. The method of claim 112, wherein controlling hydrogen production from the formation comprises increasing production of condensable hydrocarbons, and wherein producing the mixture comprises pumping the condensable hydrocarbons with a submersible pump.
116. The method of claim 112, wherein the produced mixture comprises substantially condensable hydrocarbons.
117. The method of claim 112, wherein the produced mixture comprises phenols.
118. The method of claim 112, wherein the mixture is produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars.
119. The method of claim 112, further comprising controlling the heating of the portion of the formation such that a temperature of a majority of the portion is less than about 375 °C.
120. The method of claim 112, wherein the formation fluid produced further comprises hydrocarbons having an average API gravity greater than about 25°.
121. A method for treating a hydrocarbon containing formation, comprising:
providing heat from one or more heaters to at least a portion of the formation, wherein at least one of the heaters is in at least one wellbore in the formation, and wherein at least one of the wellbores has been sized, at least in part, based on a determination of expansion of the formation caused by heating of the formation such that expansion of the formation caused by heating of the formation is not sufficient to cause substantial deformation of one or more heaters in such sized wellbores, and wherein a ratio of an outside diameter of the heater to an inside diameter of the wellbore is less than about 0.75;
allowing the heat to transfer from the one or more heaters to a part of the formation; and producing a mixture from the formation.
122. The method of claim 121, wherein at least one of the wellbores comprises an open wellbore.
123. The method of claim 121, wherein the ratio of the outside diameter of the heater to the inside diameter of the wellbore is less than about 0.5.
124. The method of claim 121, wherein the ratio of the outside diameter of the heater to the inside diameter of the wellbore is less than about 0.3.
125. The method of claim 121, further comprising controlling the heating to maintain a minimum space between at least one of the heaters and the formation in at least one of the wellbores.
126. The method of claim 121, further comprising controlling the heating using a temperature limited heater.
127. The method of claim 121, further comprising controlling the heating to maintain a minimum space of at least about 0.25 cm between at least one of the heaters and the formation in at least one wellbore.
128. The method of claim 121, wherein a diameter of one or more of the sized wellbores is greater than or equal to about 30 cm.
129. The method of claim 121, wherein one or more of the wellbores have an expanded diameter proximate to relatively rich zones in the formation.
130. The method of claim 129, wherein one or more of the expanded diameters is greater than or equal to about 30 cm.
131. The method of claim 129, wherein the relatively rich zones comprise a richness greater than about 0.15 L/kg.
132. The method of claim 129, wherein the relatively rich zones comprise a richness greater than about 0.17 L/kg.
133. The method of claim 121, further comprising adjusting a heat output of at least one of the heaters such that the heat output provided to relatively rich zones of the formation is less than the heat output provided to other zones of the formation.
134. The method of claim 133, wherein the relatively rich zones comprise a richness greater than about 0.15 L/kg.
135. The method of claim 121, further comprising adjusting a heat output of at least one of the heaters such that the heat output provided to relatively rich zones of the formation is less than about 1/2 the heat output provided to other zones of the formation.
136. The method of claim 121, further comprising reaming at least one of the wellbores after at least some heating of the formation from such wellbores.
137. The method of claim 121, further comprising reaming at least one of the wellbores after at least some heating of the formation from such wellbores, and wherein the reaming is conducted to remove at least some hydrocarbon material that has expanded in such wellbores.
138. The method of claim 121, further comprising removing at least one of the heaters from at least one of the wellbores, and then reaming at least one such wellbore.
139. The method of claim 121, further comprising perforating one or more relatively rich zones in at least part of the formation to allow for expansion of at least one or more of the relatively rich zones during heating of the formation.
140. The method of claim 121, further comprising placing a liner in at least one of the wellbores, between at least a part of one of the heaters and the formation, wherein the liner inhibits heater deformation caused by thermal expansion of the formation during heating.
141. The method of claim 140, wherein the liner comprises a mechanical strength sufficient to inhibit collapsing of the liner proximate relatively rich zones of the formation.
142. The method of claim 140, wherein the liner comprises one or more openings to allow fluids to flow through the wellbore in which the liner is placed.
143. The method of claim 140, wherein a ratio of an outside diameter of the liner to the inside diameter of the wellbore in which the liner is placed is less than about 0.75.
144. The method of claim 140, wherein a ratio of an outside diameter of the liner to the inside diameter of the wellbore in which the liner is placed is less than about 0.5.
145. The method of claim 140, wherein a ratio of an outside diameter of the liner to the inside diameter of the wellbore in which the liner is placed is less than about 0.3.
146. The method of claim 121, further comprising maintaining a temperature in at least a portion of the formation in a pyrolysis temperature range, with a lower pyrolysis temperature of about 250 °C and an upper pyrolysis temperature of about 400 °C.
147. The method of claim 121, further comprising heating at least a part of the formation to substantially pyrolyze at least some hydrocarbons in the formation.
148. The method of claim 121, further comprising controlling a pressure and a temperature in at least a part of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.
149. The method of claim 121, wherein allowing the heat to transfer from the one or more heaters to the part of the formation comprises transferring heat substantially by conduction.
150. The method of claim 121, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
151. The method of claim 121, further comprising controlling a pressure in at least a majority of a part of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.
152. The method of claim 121, further comprising controlling formation conditions such that the produced mixture comprises a partial pressure of H2 in the mixture greater than about 0.5 bars.
153. The method of claim 121, wherein the formation comprises an oil shale formation.
154. The method of claim 121, wherein the formation comprises a coal formation.
155. A method for treating a hydrocarbon containing formation, comprising:
providing heat from one or more heaters to at least a portion of the formation, wherein at least one of the heaters is in at least one of one or more wellbores in the formation, and wherein heating from one or more of the heaters is controlled to inhibit substantial deformation of one or more of the heaters caused by thermal expansion of the formation against such one or more heaters;
allowing the heat to transfer from the one or more heaters to a part of the formation; and producing a mixture from the formation.
156. The method of claim 155, wherein at least one of the wellbores comprises an uncased wellbore.
157. The method of claim 155, further comprising controlling the heating to maintain a minimum space between at least one of the heaters and the formation in at least one of the wellbores.
158. The method of claim 155, further comprising controlling the heating using a temperature limited heater.
159. The method of claim 155, further comprising controlling the heating to maintain a minimum space of at least about 0.25 cm between at least one of the heaters and the formation in at least one of the wellbores.
160. The method of claim 155, wherein at least one of the heaters is in at least one of the wellbores having a diameter sufficient to inhibit the formation from expanding against such heater during heating of the formation.
161. The method of claim 160, wherein the diameter of at least one of the wellbores having a diameter sufficient to inhibit the formation from expanding against such heater during the heating of the formation is greater than or equal to about 30 cm.
162. The method of claim 155, wherein one or more of the wellbores have an expanded diameter proximate to relatively rich zones in the formation.
163. The method of claim 162, wherein the expanded diameter is greater than or equal to about 30 cm.
164. The method of claim 162, wherein the relatively rich zones comprise a richness greater than about 0.15 L/kg.
165. The method of claim 162, wherein the relatively rich zones comprise a richness greater than about 0.17 L/kg.
166. The method of claim 155, wherein controlling the heating comprises adjusting a heat output of at least one of the heaters such that the heat output provided to relatively rich zones of the formation is less than the heat output provided to other zones of the formation.
167. The method of claim 155, wherein controlling the heating comprises adjusting a heat output of at least one of the heaters such that about the heat output provided to relatively rich zones of the formation is less than about 1/2 the heat output provided to other zones of the formation.
168. The method of claim 167, wherein the relatively rich zones comprise a richness greater than about 0.15 L/kg.
169. The method of claim 155, further comprising reaming at least one of the wellbores after at least some heating of the formation from such wellbores.
170. The method of claim 155, further comprising reaming at least one of the wellbores after at least some heating of the formation from such wellbores, and wherein the reaming is conducted to remove at least some hydrocarbon material that has expanded in such wellbores.
171. The method of claim 155, further comprising removing at least one of the heaters from at least one of the wellbores, and then reaming at least one such wellbore.
172,. The method of claim 155, further comprising perforating one or more relatively rich zones in at least part of the formation to allow for expansion of at least one or more of the relatively rich zones during heating of the formation.
173. The method of claim 155, further comprising placing a liner in at least one of the wellbores and between at least a part of one of the heaters and the formation, wherein the liner inhibits heater deformation caused by thermal expansion of the formation during heating.
174. The method of claim 173, wherein the liner comprises a mechanical strength sufficient to inhibit collapsing of the liner proximate relatively rich zones of the formation.
175. The method of claim 173, wherein the liner comprises one or more openings to allow fluids to flow through the wellbore in which the liner is placed.
176. The method of claim 173, wherein a ratio of an outside diameter of the liner to the inside diameter of the wellbore in which the liner is placed is less than 0.75.
177. The method of claim 173, wherein a ratio of an outside diameter of the liner to the inside diameter of the wellbore in which the liner is placed is less than 0.5.
178. The method of claim 173, wherein a ratio of an outside diameter of the liner to the inside diameter of the wellbore in which the liner is placed is less than 0.3.
179. The method of claim 155, further comprising maintaining a temperature in at least a portion of the formation in a pyrolysis temperature range with a lower pyrolysis temperature of about 250 °C and an upper pyrolysis temperature of about 400 °C.
180. The method of claim 155, further comprising heating at least a part of the formation to substantially pyrolyze at least some hydrocarbons in the formation.
181. The method of claim 155, further comprising controlling a pressure and a temperature in at least a part of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.
182. The method of claim 155, wherein allowing the heat to transfer from the one or more heaters to the part of the formation comprises transferring heat substantially by conduction.
183. The method of claim 155, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
184. The method of claim 155, further comprising controlling a pressure in at least a majority of a part of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.
185. The method of claim 155, further comprising controlling formation conditions such that the produced mixture comprises a partial pressure of H2 in the mixture greater than about 0.5 bars.
186. The method of claim 155, wherein the formation comprises an oil shale formation.
187. The method of claim 155, wherein the formation comprises a coal formation.
188. A system configured to heat at least a part of a hydrocarbon containing formation, comprising:
an elongated heater located in an opening in the formation, wherein at least a portion of the formation has a richness of at least about 30 gallons of hydrocarbons per ton of formation, as measured by Fischer Assay, and wherein the heater is configured to provide heat to at least a part of the formation during use such that at least a part of the formation is heated to at least about 250 °C; and wherein an initial diameter of the opening is at least 1.5 times the largest transverse cross-sectional dimension of the heater in the opening and proximate the part of the formation being heated such that it inhibits the formation from deforming the heater due to expansion of the formation caused by heating of the formation.
189. The system of claim 188, wherein the initial diameter of the opening is at least about 2 times the largest transverse cross-sectional dimension of the heater in the opening.
190. The system of claim 188, wherein the initial diameter of the opening is sufficiently large enough to inhibit the formation from deforming the heater during heating of the formation.
191. The system of claim 188, wherein the initial diameter of the opening is sufficiently large enough to inhibit the formation from seizing the heater during heating of the formation.
192. The system of claim 188, wherein the initial diameter of the opening is sufficiently large enough to inhibit the formation from damaging the heater during heating of the formation.
193. The system of claim 188, wherein the initial diameter of the opening is sufficiently large enough to inhibit the formation from compressing the heater during heating of the formation.
194. The system of claim 188, wherein the initial diameter of the opening is at least 3 times the largest transverse cross-sectional dimension of the heater in the opening.
195. The system of claim 188, wherein the initial diameter of the opening is at least 4 times the largest transverse cross-sectional dimension of the heater in the opening.
196. The system of claim 188, wherein the system is configured to pyrolyze at least some hydrocarbons in the formation during use.
197. The system of claim 188, wherein the initial diameter of the opening is approximately a size of a drillbit used to form the opening.
198. The system of claim 188, wherein the heater comprises a ferromagnetic material.
199. The system of claim 188, wherein the heater comprises a temperature limited heater.
200. The system of claim 188, wherein the opening comprises an uncased wellbore.
201. The system of claim 188, wherein the heater is located in at least a portion of a deformation resistant container.
202. The system of claim 201, wherein the initial diameter of the opening is sufficiently large enough to inhibit the formation from deforming the deformation resistant container during heating of the formation.
203. The system of claim 188, wherein the initial diameter of the opening is at least 2 times the largest transverse cross-sectional dimension of the heater in the opening and proximate a part of the formation that comprises a richness of at least about 0.12 L/kg.
204. The system of claim 188, wherein the formation comprises an oil shale formation.
205. The system of claim 188, wherein the formation comprises a coal formation.
206. A method for treating a hydrocarbon containing formation, comprising:
heating a first volume of the formation using a first set of heaters; and heating a second volume of the formation using a second set of heaters, wherein the first volume is spaced apart from the second volume by a third volume of the formation, and wherein the first volume, the second volume, and the third volume are sized, shaped, and/or located to inhibit deformation of subsurface equipment caused by geomechanical motion of the formation during heating.
207. The method of claim 206, further comprising allowing the heat to transfer from the first volume and the second volume of the formation to at least a part of the formation.
208. The method of claim 206, wherein a footprint of the first volume, the second volume, or the third volume is sized, shaped, or located to inhibit deformation of subsurface equipment caused by geomechanical motion of the formation during heating.
209. The method of claim 206, further comprising sizing, shaping, or locating the first volume, second volume, or third volume to inhibit deformation of subsurface equipment caused by geomechanical motion of the formation during heating.
210. The method of claim 206, further comprising calculating geomechanical motion in a footprint of the first volume or the second volume, and using the calculated geomechanical motion to size, shape, or locate the first volume, the second volume, or the third volume.
211. The method of claim 206, further comprising allowing the heat to transfer from the first volume and the second volume of the formation to at least a part of the formation, and producing a mixture from the formation.
212. The method of claim 206, wherein the third volume substantially surrounds the first volume, and the second volume substantially surrounds the first volume.
213. The method of claim 206, wherein the third volume substantially surrounds all or a portion of the first volume, and the second volume substantially surrounds all or a portion of the third volume.
214. The method of claim 206, wherein the third volume has a footprint that is a linear, curved, or irregular shaped strip.
215. The method of claim 206, wherein the first volume and the second volume comprise rectangular footprints.
216. The method of claim 206, wherein the first volume and the second volume comprise square footprints.
217. The method of claim 206, wherein the first volume and the second volume comprise circular footprints.
218. The method of claim 206, wherein the first volume and the second volume comprise footprints in a concentric ring pattern.
219. The method of claim 206, wherein the first volume, the second volume, and the third volume comprise rectangular footprints.
220. The method of claim 206, wherein the first volume, the second volume, and the third volume comprise square footprints.
221. The method of claim 206, wherein the first volume, the second volume, and the third volume comprise circular footprints.
222. The method of claim 206, wherein the first volume, the second volume, and the third volume comprise footprints in a concentric ring pattern.
223. The method of claim 206, wherein the first volume, the second volume, or the third volume are sized, shaped, or located based on, at least in part, a calculated geomechanical motion of at least a portion of the formation.
224. The method of claim 206, further comprising sizing, shaping, or locating the first volume, the second volume, or the third volume based on, at least in part, a calculated geomechanical motion of at least a portion of the formation.
225. The method of claim 206, wherein the first volume, the second volume, or the third volume are sized, shaped, or located, at least in part, to inhibit deformation, caused by geomechanical motion of one or more selected wellbores in the formation.
226. The method of claim 206, wherein the first volume, the second volume, or the third volume are at least in part sized, shaped, or located based on a calculated geomechanical motion of at least a portion of the formation, and wherein the first volume, the second volume, or the third volume are sized, shaped, or located, at least in part, to inhibit deformation, caused by geomechanical motion, of one or more selected wellbores in the formation.
227. The method of claim 206, wherein the first volume, the second volume, or the third volume of the formation have been sized, shaped, or located, at least in part, based on a simulation.
228. The method of claim 206, wherein the first volume, the second volume, and the third volume of the formation have been sized, shaped, or located, at least in part, based on a simulation.
229. The method of claim 206, wherein a footprint area of the first volume, the second volume, or the third volume is less than about 400 square meters.
230. The method of claim 206, further comprising heating with a third set of heaters after a selected amount of geomechanical motion in the first volume or the second volume.
231. The method of claim 206, further comprising heating with a third set of heaters to maintain or enhance a production rate of a mixture from the formation.
232. The method of claim 206, further comprising maintaining a temperature in at least a portion of the formation in a pyrolysis temperature range with a lower pyrolysis temperature of about 250 °C and an upper pyrolysis temperature of about 400 °C.
233. The method of claim 206, further comprising pyrolyzing at least some hydrocarbons in the formation.
234. The method of claim 206, further comprising controlling a pressure and a temperature in at least a part of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.
235. The method of claim 206, further comprising producing a mixture from the formation.
236. The method of claim 235, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
237. The method of claim 235, further comprising controlling formation conditions such that the produced mixture comprises a partial pressure of H2 in the mixture greater than about 0.5 bars.
238. The method of claim 206, further comprising controlling a pressure in at least a part of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.
239. The method of claim 206, wherein the formation comprises an oil shale formation.
240. The method of claim 206, wherein the formation comprises a coal formation.
241. A method for treating a hydrocarbon containing formation, comprising:
heating a first volume of the formation using a first set of heaters;
heating a second volume of the formation using a second set of heaters, wherein the first volume is spaced apart from the second volume by a third volume of the formation;
heating the third volume using a third set of heaters, wherein the third set of heaters begins heating at a selected time after the first set of heaters and the second set of heaters;
allowing the heat to transfer from the first volume, the second volume, and the third volume of the formation to at least a part of the formation; and producing a mixture from the formation.
242. The method of claim 241, wherein the first volume, the second volume, or the third volume are sized, shaped, or located based on, at least in part, a calculated geomechanical motion of at least a portion of the formation.
243. The method of claim 241, further comprising sizing, shaping, or locating the first volume, the second volume, or the third volume based on, at least in part, a calculated geomechanical motion of at least a portion of the formation.
244. The method of claim 241, wherein the first volume, the second volume, or the third volume are sized, shaped, or located, at least in part, to inhibit deformation, caused by geomechanical motion, of one or more selected wellbores in the formation.
245. The method of claim 241, wherein the first volume, the second volume, or the third volume are at least in part sized, shaped, or located based on a calculated geomechanical motion of at least a portion of the formation, and wherein the first volume, the second volume, or the third volume are sized, shaped, or located, at least in part, to inhibit deformation caused by geomechanical motion of one or more selected wellbores in the formation.
246. The method of claim 241, wherein the first volume, the second volume, or the third volume of the formation has been sized, shaped, or located, at least in part, based on a simulation.
247. The method of claim 241, wherein the first volume, the second volume, and the third volume of the formation have been sized, shaped, or located, at leapt in part, based on a simulation.
248. The method of claim 241, wherein a footprint area of the first volume, the second volume, or the third volume is less than about 400 square meters.
249. The method of claim 241, wherein the third set of heaters begins heating after a selected amount of geomechanical motion in the first volume or the second volume.
250. The method of claim 241, wherein the third set of heaters begins heating to maintain or enhance a production rate of the mixture from the formation.
251. The method of claim 241, wherein the selected time has been at least in part determined using a simulation.
252. The method of claim 241, wherein the first volume and the second volume comprise rectangular footprints.
253. The method of claim 241, wherein the first volume and the second volume comprise square footprints.
254. The method of claim 241, wherein the first volume and the second volume comprise circular footprints.
255. The method of claim 241, wherein the first volume, the second volume, and the third volume comprise rectangular footprints.
256. The method of claim 241, wherein the first volume, the second volume, and the third volume comprise square footprints.
257. The method of claim 241, wherein the first volume, the second volume, and the third volume comprise circular footprints.
258. The method of claim 241, wherein the first volume, the second volume, and the third volume comprise footprints in a concentric ring pattern.
259. The method of claim 241, further comprising maintaining a temperature in at least a portion of the formation in a pyrolysis temperature range with a lower pyrolysis temperature of about 250 °C and an upper pyrolysis temperature of about 400 °C.
260. The method of claim 241, further comprising pyrolyzing at least some of the hydrocarbons in the formation.
261. The method of claim 241, further comprising controlling a pressure and a temperature in at least a majority of the part of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.
262. The method of claim 241, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
263. The method of claim 241, further comprising controlling a pressure in at least a majority of a part of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.
264. The method of claim 241, further comprising controlling formation conditions such that the produced mixture comprises a partial pressure of H2 in the mixture greater than about 0.5 bars.
265. The method of claim 241, wherein the third set of heaters begins heating about 6 months after the first set of heaters or the second set of heaters begins heating.
266. The method of claim 241, wherein the formation comprises an oil shale formation.
267. The method of claim 241, wherein the formation comprises a coal formation.
268. A system configured to heat at least a part of a subsurface formation, comprising:
an AC power supply;
one or more electrical conductors configured to be electrically coupled to the AC power supply and placed in an opening in the formation, wherein at least one of the electrical conductors comprises a heater section, the heater section comprising an electrically resistive ferromagnetic material configured to provide an electrically resistive heat output when AC is applied to the ferromagnetic material, and wherein the heater section is configured to provide a reduced amount of heat near or above a selected temperature during use due to the decreasing AC
resistance of the heater section when the temperature of the ferromagnetic material is near or above the selected temperature; and wherein the system is configured to allow heat to transfer from the heater section to a part of the formation.
269. The system of claim 268, wherein the heater section automatically provides a reduced amount of heat above or near the selected temperature.
270. The system of claim 268, wherein at least a portion of the heater section is positionable adjacent to an overburden of the formation to heat at least a part of the overburden to inhibit condensation of vapors in a wellbore passing through the overburden.
271. The system of claim 268, wherein at least a portion of the heater section is positionable adjacent to hydrocarbon material in the formation to raise a temperature of at least some of the hydrocarbon material to or above a pyrolysis temperature.
272. The system of claim 268, wherein the subsurface formation comprises a hydrocarbon containing formation, and wherein the system is configured to pyrolyze at least some hydrocarbons in the formation.
273. The system of claim 268, wherein the subsurface formation comprises contaminated soil, and wherein the system is configured to decontaminate at least a portion of the contaminated soil.
274. The system of claim 268, wherein the system comprises three or more electrical conductors, and wherein at least three of the electrical conductors are configured to be electrically connected in a three-phase configuration.
275. The system of claim 268, wherein the heater section is configured to provide the reduced amount of heat without controlled adjustment of the AC.
276. The system of claim 268, wherein the heater section is configured to exhibit an increase in operating temperature of less than about 1.5 °C above or near a selected operating temperature when a thermal load proximate the heater section decreases by about 1 watt per meter.
277. The system of claim 268, further comprising an oxidation heater placed in the opening in the formation.
278. The system of claim 277, wherein the oxidation heater comprises a natural distributed combustor.
279. The system of claim 277, wherein the oxidation heater comprises a flameless distributed combustor.
280. The system of claim 277, wherein at least one of the electrical conductors is configured to provide heat to initiate an oxidation reaction in the oxidation heater during use.
281. The system of claim 277, wherein the selected temperature is above an initiation temperature for an oxidation reaction to commence in the oxidation heater, and wherein the selected temperature is below an operating temperature of the oxidation heater during use.
282. The system of claim 268, further comprising a highly electrically conductive material coupled to at least a portion of the ferromagnetic material of an electrical conductor, wherein AC
applied to the electrical conductor substantially flows through the ferromagnetic conductor when a temperature of the ferromagnetic conductor is below the selected temperature, and wherein the AC applied to the conductor is configured to flow through the highly electrically conductive material when the temperature of the ferromagnetic conductor is near or above the selected temperature.
283. The system of claim 268, wherein the ferromagnetic material comprises an elongated material, wherein the system further comprises an elongated highly electrically conductive material, and wherein at least about 50% of the elongated material is electrically coupled to the elongated highly electrically conductive material.
284. The system of claim 268, wherein at least one of the electrical conductors is configured to provide a reduced amount of heat above or near the selected temperature that is about 20% or less of the heat output at about 50 °C below the selected temperature.
285. The system of claim 268, wherein the heater section is configured such that the decreased AC resistance through the heater section above or near the selected temperature is about 20%
or less than the AC resistance at about 50 °C below the selected temperature.
286. The system of claim 268, wherein the AC resistance of the heater section above or near the selected temperature is about 80% or less of the AC resistance at about 50 °C
below the selected temperature.
287. The system of claim 268, wherein the AC resistance of the heater section decreases above the selected temperature to provide the reduced amount of heat.
288. The system of claim 268, wherein the heater section is configured to automatically exhibit the decreased AC resistance above or near a selected temperature.
289. The system of claim 268, further comprising a non-ferromagnetic material coupled to the ferromagnetic material, wherein the non-ferromagnetic material has a higher electrical conductivity than the ferromagnetic material.
290. The system of claim 268, further comprising a second ferromagnetic material coupled to the ferromagnetic material.
291. The system of claim 268, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
292. The system of claim 268, wherein at least one of the electrical conductors is electrically coupled to the earth, and wherein electrical current is propagated from the electrical conductor to the earth.
293. The system of claim 268, wherein the heater section is elongated, and wherein the reduced amount of heat is less than about 400 watts per meter of length of the heater section.
294. The system of claim 268, wherein the heater section is elongated, and wherein the heat output from the ferromagnetic material is greater than about 400 watts per meter of length of the heater section when the temperature of the ferromagnetic material is below the selected temperature during use.
295. The system of claim 268, wherein the ferromagnetic material has a turndown ratio of at least about 2 to 1.
296. The system of claim 268, further comprising a deformation resistant container configured.to contain at least one electrical conductor, and wherein the selected temperature is chosen such that the deformation resistant container has a creep-rupture strength of at least about 3000 psi at 100,000 hours at the selected temperature.
297. The system of claim 268, wherein one or more electrical conductors comprise two or more electrical conductors and an electrically insulating material placed between at least two of the electrical conductors.
298. The system of claim 268, wherein the ferromagnetic material comprises iron, nickel, chromium, cobalt, tungsten, or a mixture thereof.
299. The system of claim 268, wherein the ferromagnetic material comprises a mixture of iron and nickel.
300. The system of claim 268, wherein the ferromagnetic material comprises a mixture of iron and cobalt.
301. The system of claim 268, wherein the system is configured such that the ferromagnetic material has a thickness of at least about 3/4 of a skin depth of the AC at the Curie temperature of the ferromagnetic material.
302. The system of claim 268, wherein the system is configured such that the ferromagnetic material has a thickness of at least about 3/4 of a skin depth of the AC at the Curie temperature of the ferromagnetic material, and wherein the ferromagnetic material is coupled to a material that is more conductive that the ferromagnetic material such that the coupled materials exhibit a greater conductivity at the Curie temperature of the ferromagnetic material than the ferromagnetic material with the same thickness as the coupled materials.
303. The system of claim 268, wherein the system is configured such that the ferromagnetic material has a thickness of at least about a skin depth of the AC at the Curie temperature of the ferromagnetic material.
304. The system of claim 268, wherein the ferromagnetic material comprises two or more ferromagnetic materials with different Curie temperatures.
305. The system of claim 268, wherein at least one of the electrical conductors comprises ferromagnetic material and non-ferromagnetic electrically conductive material.
306. The system of claim 268, wherein the subsurface formation comprises a hydrocarbon containing formation, and wherein at least a portion of the electrically resistive ferromagnetic material is located proximate a relatively rich zone of the formation.
307. The system of claim 268, wherein the ferromagnetic material is coupled to a corrosion resistant material.
308. The system of claim 268, wherein at least one of the electrical conductors is part of an insulated conductor heater.
309. The system of claim 268, wherein at least one of the electrical conductors is part of a conductor-in-conduit heater.
310. The system of claim 268, wherein the ferromagnetic material is coupled to a material that is more conductive than the ferromagnetic material, and wherein thicknesses of both materials and skin depth characteristics of the ferromagnetic material are configured to provide a selected resistance profile as a function of temperature.
311. The system of claim 268, wherein at least a portion of at least one of the electrical conductors comprises a relatively flat AC resistance profile in a temperature range between about 100 °C and 750 °C.
312. The system of claim 268, wherein at least a portion of at least one of the electrical conductors comprises a relatively flat AC resistance profile in a temperature range between about 100 °C and 700 °C and a relatively sharp resistance profile at a temperature above about 700 °C and less than about 850 °C.
313. The system of claim 268, wherein at least a portion of at least one of the electrical conductors comprises a relatively flat AC resistance profile in a temperature range between about 300 °C and 600 °C.
314. The system of claim 268, wherein at least a portion of at least one electrically resistive ferromagnetic material is longer than about 10 m.
315. The system of claim 268, wherein the system is configured to sharply reduce the heat output at or near the selected temperature.
316. The system of claim 268, wherein at least one of the electrical conductors comprises an electrically resistive ferromagnetic material drawn together with or against a material with a higher conductivity than the ferromagnetic material.
317. The system of claim 268, wherein at least one of the electrical conductors comprises an elongated conduit comprising a center portion and an outer portion, and wherein the center portion comprises iron and has a diameter of at least about 0.5 cm.
318. The system of claim 268, wherein at least one of the electrical conductors comprises a composite material, wherein the composite material comprises a first material with a resistance that decreases when the first material is heated to the selected temperature, wherein the composite material comprises a second material that is more electrically conductive than the first material, and wherein the first material is coupled to the second material.
319. The system of claim 268, wherein the reduced amount of heat comprises a heating rate lower than the rate at which the formation will absorb or transfer heat, thereby inhibiting overheating of the formation.
320. The system of claim 268, wherein at least one of the electrical conductors is elongated and configured such that only electrically resistive sections at or near the selected temperature will automatically reduce the heat output.
321. The system of claim 268, wherein the system is configured such that an AC
resistance of at least one of the electrical conductors increases with an increase in temperature up to the selected temperature.
322. The system of claim 268, wherein the system is configured such that an AC
resistance of at least one of the electrical conductors decreases with an increase in temperature above the selected temperature.
323. The system of claim 268, wherein the system is configured to apply AC of at least about 70 amps to at least one of the electrical conductors.
324. The system of claim 268, wherein the system is configured to apply AC at about 180 Hz.
325. The system of claim 268, wherein the system is configured to apply AC at about 60 Hz.
326. The system of claim 268, wherein the ferromagnetic material is positioned in an opening in the formation, and wherein at least a portion of the opening in the formation adjacent to the ferromagnetic material comprises an uncased wellbore.
327. The system of claim 268, wherein the ferromagnetic material is configured to radiatively heat the formation.
328. The system of claim 268, wherein at least one of the electrical conductors is located in an overburden of the formation.
329. The system of claim 268, wherein at least one of the electrical conductors is coupled to a cable, and wherein the cable comprises a plurality of copper wires coated with an oxidation resistant alloy.
330. A method for heating a subsurface formation, comprising:
applying AC to one or more electrical conductors located in the subsurface formation to provide an electrically resistive heat output, wherein at least one of the electrical conductors comprises an electrically resistive ferromagnetic material that provides heat when AC flows through the electrically resistive ferromagnetic material, and wherein such electrical conductor comprising electrically resistive ferromagnetic material provides a reduced amount of heat above or near a selected temperature; and allowing the heat to transfer from the electrically resistive ferromagnetic material to a part of the subsurface formation.
331. The method of claim 330, wherein the electrically resistive ferromagnetic material automatically provides a selected reduced amount of heat above or near a selected temperature.
332. The method of claim 330, further comprising placing one or more of the electrical conductors in a wellbore in the formation.
333. The method of claim 330, wherein an AC resistance of the ferromagnetic material decreases above the selected temperature to provide the reduced amount of heat.
334. The method of claim 330, wherein a thickness of the ferromagnetic material is greater than about 3/4 of a skin depth of the AC at the Curie temperature of the ferromagnetic material.
335. The method of claim 330, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
336. The method of claim 330, wherein the selected temperature is within about 50 °C of the Curie temperature of the ferromagnetic material.
337. The method of claim 330, wherein the subsurface formation comprises a hydrocarbon containing formation.
338. The method of claim 330, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising heating at least some hydrocarbons in the formation such that at least some of the hydrocarbons are pyrolyzed.
339. The method of claim 330, wherein one or more of the electrical conductors are located in a wellbore, and further comprising providing a reduced amount of heat of less than about 400 watts per meter of length of the wellbore while one or more of the electrical conductors are above or near the selected temperature.
340. The method of claim 330, wherein one or more of the electrical conductors are located in a wellbore, and further comprising providing a heat output of greater than about 400 watts per meter of length of the wellbore while one or more of the electrical conductors are below the selected temperature.
341. The method of claim 330, further comprising controlling the amount of current applied to one or more of the electrical conductors to control the amount of heat provided by the ferromagnetic material.
342. The method of claim 330, further comprising applying an AC of at least about 70 amps to the electrical conductors.
343. The method of claim 330, further comprising applying an AC of at least about 100 amps to the electrical conductors.
344. The method of claim 330, further comprising applying the AC at a frequency of about 180 Hz.
345. The method of claim 330, wherein the heat transfers radiatively from at least one of the electrical conductors to at least the part of the formation.
346. The method of claim 330, further comprising providing a relatively constant heat output when an electrical conductor is in a temperature range between about 300 °C and 600 °C.
347. The method of claim 330, further comprising providing a relatively constant heat output when an electrical conductor is in a temperature range between about 100 °C and 750 °C.
348. The method of claim 330, further comprising providing a heat output from at least one of the electrical conductors, wherein an AC resistance of one or more of such electrical conductors above or near the selected temperature is about 80% or less of the AC resistance of such one or more electrical conductors at about 50 °C
below the selected temperature.
349. The method of claim 330, further comprising providing an initial electrically resistive heat output when the electrical conductor providing the heat output is at least about 50 °C
below the selected temperature, and automatically providing the reduced amount of heat above or near the selected temperature.
350. The method of claim 330, wherein the subsurface formation comprises contaminated soil, and further comprising using the provided heat to decontaminate the soil.
351. The method of claim 330, wherein at least one of the electrical conductors is electrically coupled to the earth, and further comprising propagating electrical current from at least one of the electrical conductors to the earth.
352. The method of claim 330, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about
2S. The method of claim 1, further comprising heating at least a portion of the formation, and controlling a pressure and a temperature in at least a part of the formation, wherein the pressure is controlled as a function of temperature, and/or the temperature is controlled as a function of pressure.
26. The method of claim 1, further comprising heating at least a portion of the formation, and producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API
gravity of at least about 25°.
27. The method of claim 1, further comprising heating at least a portion of the formation, controlling a pressure in at least a part of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.
28. The method of claim 1, further comprising heating at least a portion of the formation, and controlling formation conditions such that a mixture produced from the formation comprises a partial pressure of H2 in the mixture greater than about 0.5 bars.
29. The method of claim 1, further comprising heating at least a portion of the formation, and altering a pressure in the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
30. The method of claim 1, further comprising heating at least a portion of the formation to a minimum pyrolysis temperature of about 270 °C.
31. A method for heating a hydrocarbon containing formation, comprising:
providing heat to the formation from one or more heaters in one or more openings in the formation, wherein at least one of the openings has been formed by:
forming a portion of an opening in the formation;
providing an acoustic wave to at least a portion of the formation, wherein the acoustic wave is configured to propagate between at least one geological discontinuity of the formation and at least a portion of the opening;
sensing at least one reflection of the acoustic wave in at least a portion of the opening; and using the sensed reflection to assess an approximate location of at least a portion of the opening in the formation.
32. The method of claim 31, wherein at least one portion of an opening has been formed based on, at least in part, the assessed approximate location of at least a portion of the opening.
33. The method of claim 31, wherein at least one portion of an opening has been formed using the sensed reflection to maintain an approximate desired location of the opening between an overburden of the formation and an underburden of the formation.
34. The method of claim 31, wherein at least one geological discontinuity comprises a boundary of the formation.
35. The method of claim 31, wherein at least one portion of an opening has been formed based on, at least in part, using the sensed reflection to maintain the location of the opening at approximately midway between an overburden of the formation and an underburden of the formation.
36. The method of claim 31, wherein at least one portion of an opening has been formed based on, at least in part, producing the acoustic wave using a monopole source or a dipole source.
37. The method of claim 31, wherein at least one portion of an opening has been formed based on, at least in part, sensing the reflection of the acoustic wave using one or more sensors in at least a portion of the opening.
38. The method of claim 31, wherein at least one portion of an opening has been formed based on, at least in part, producing the acoustic wave using a source for producing the acoustic wave in at least a portion of the opening.
39. The method of claim 31, wherein at least one portion of an opening has been formed based on, at least in part, producing the acoustic wave using a source for producing the acoustic wave in at least a portion of the opening, and sensing the acoustic wave using one or more sensors in at least a portion of the opening.
40. The method of claim 31, wherein at least one portion of an opening has been formed based on, at least in part, sensing the reflection of the acoustic wave during formation of at least a portion of the opening in the formation.
41. The method of claim 31, wherein at least one portion of an opening has been formed based on, at least in part, using a calculated or assessed velocity in the formation when using the sensed reflection to assess the location of the opening in the formation.
42. The method of claim 31, wherein at least one portion of an opening has been formed based on, at least in part, propagating an acoustic wave between an overburden of the formation and the opening.
43. The method of claim 31, wherein at least one portion of an opening has been formed based on, at least in part, propagating an acoustic wave between an underburden of the formation and the opening.
44. The method of claim 31, wherein at least one portion of an opening has been formed based on, at least in part, propagating an acoustic wave between an overburden of the formation and the opening and an underburden of the formation and the opening.
45. The method of claim 31, wherein at least one portion of an opening has been formed based on, at least in part, using information from the sensed acoustic wave to, at least in part, guide a drilling system in forming the opening.
46. The method of claim 31, wherein at least one portion of an opening has been formed based on, at least in part, substantially simultaneously providing acoustic waves, sensing reflected acoustic waves, and using information from the sensed acoustic waves to, at least in part, guide a drilling system in forming the opening.
47. The method of claim 31, wherein at least one portion of an opening has been formed based on, at least in part, using information from the sensed acoustic wave to, at least in part, substantially simultaneously guide a drilling system in forming the opening.
48. The method of claim 31, wherein at least one portion of an opening has been formed based on, at least in part, using information from the sensed acoustic wave to assess a location of at least a part of the opening, and then using such assessed location to, at least in part, guide a drilling system in forming the opening.
49. The method of claim 31, wherein at least one portion of an opening has been formed based on, at least in part, using information from the sensed acoustic waves to assess locations of parts of the opening, and then using such assessed locations to, at least in part, guide a drilling system in forming the opening.
50. The method of claim 31, wherein at least one portion of an opening has been formed based on, at least in part, using the sensed acoustic wave, and further comprising forming one or more additional openings by using magnetic tracking to form one or more additional openings at a selected approximate distance from the first opening.
51. The method of claim 31, further comprising assessing an approximate orientation of the opening with an inclinometer.
$2. The method of claim 31, further comprising assessing an approximate location of the opening relative to a second opening in the formation by detecting one or more magnetic fields produced from the second opening.
53. The method of claim 31, further comprising assessing an approximate location of the opening relative to a second opening in the formation by detecting one or more magnetic fields produced from the second opening with a magnetometer.
54. The method of claim 31, further comprising assessing an approximate location of the opening relative to a second opening in the formation by detecting one or more magnetic fields produced from the second opening so that the opening is formed at an approximate desired distance from the second opening.
55. The method of claim 31, further comprising pyrolyzing at least some hydrocarbons in the formation.
56. The method of claim 31, further comprising controlling a pressure and a temperature in at least a part of the formation, wherein the pressure is controlled as a function of temperature, and/or the temperature is controlled as a function of pressure.
57. The method of claim 31, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
58. The method of claim 31, further comprising controlling a pressure in at least a part of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.
59. The method of claim 31, further comprising controlling formation conditions such that a produced mixture comprises a partial pressure of H2 in the mixture greater than about 0.5 bars.
60. The method of claim 31, further comprising altering a pressure in the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
61. The method of claim 31, further comprising heating at least a portion of the formation to a minimum pyrolysis temperature of about 270 °C.
62. A method of producing phenolic compounds from a hydrocarbon containing formation, comprising:
providing heat from one or more heaters to at least a portion of the formation;
allowing the heat to transfer from one or more of the heaters to a section of the formation;
producing formation fluids from the formation; and controlling at least one condition in at least a portion of the formation to selectively produce phenolic compounds in the formation fluid, wherein controlling at least one condition comprises controlling production of hydrogen from the formation.
63. The method of claim 62, wherein controlling at least one condition comprises forming a perimeter barrier around a part of the section of the formation to define a treatment area before providing heat.
64. The method of claim 62, wherein controlling at least one condition comprises heating the section to a temperature greater than 260 °C.
65. The method of claim 62, further comprising separating the phenolic compounds from the produced formation fluids.
66. The method of claim 62, further comprising separating the phenolic compounds from the produced formation fluids, wherein the phenolic compounds comprise creosol compounds.
67. The method of claim 62, further comprising separating the phenolic compounds from the produced formation fluids, wherein the phenolic compounds comprise resorcinol compounds.
68. The method of claim 62, further comprising separating the phenolic compounds from the produced formation fluids, wherein the phenolic compounds comprise phenol.
69. The method of claim 62, wherein the mixture is produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars.
70. The method of claim 62, further comprising controlling the heating of the portion of the formation such that a temperature of a majority of the portion is less than about 375 °C.
71. The method of claim 62, wherein the formation fluids produced further comprise hydrocarbons having an average API gravity greater than about 25°.
72. A method of treating a hydrocarbon containing formation in situ, comprising:
providing heat from one or more heaters to at least a portion of the formation;
allowing the heat to transfer from one or more of the heaters to a section of the formation;
providing hydrogen to the section, wherein a flow rate of hydrogen is controlled as a function of an amount of hydrogen in a mixture produced from the formation; and producing the mixture from the formation.
73. The method of claim 72, further comprising reducing an amount of the mixture produced from one or more production wells in the formation based on the amount of hydrogen produced from one or more of the production wells in the formation.
74. The method of claim 72, wherein the amount of hydrogen in the mixture produced from the formation is assessed by determining a partial pressure of the hydrogen in gases produced from one or more production wells.
75. The method of claim 74, wherein the partial pressure of the hydrogen in gases produced from one or more production wells is at least about 0.5 bars.
76. The method of claim 72, wherein the amount of hydrogen in the mixture produced from the formation is assessed by determining an initial pressure in the formation before providing hydrogen to the section, and wherein producing a mixture from the formation comprises producing the mixture when a pressure in the formation after hydrogen has been provided to the section decreases to approximately the initial pressure in the formation.
77. The method of claim 72, wherein the amount of hydrogen in the mixture produced from the formation is assessed by determining an increase in production of condensable hydrocarbons produced from the formation.
78. The method of claim 72, wherein producing a mixture from the formation comprises pumping the mixture with a submersible pump.
79. The method of claim 72, wherein the produced mixture comprises substantially condensable hydrocarbons.
80. The method of claim 72, wherein the produced mixture comprises phenols.
81. The method of claim 72, further comprising controlling heating of the portion of the formation such that a temperature of a majority of the portion is less than about 375 °C.
82. The method of claim 72, wherein the produced mixture comprises hydrocarbons having an average API
gravity greater than about 25°.
83. A method of treating a hydrocarbon containing formation in situ, comprising:
providing heat from one or more heaters to at least a portion of the formation;
allowing the heat to transfer from one or more of the heaters to a section of the formation;
providing hydrogen to the section of the formation; and controlling production of hydrogen from a plurality of production wells in the formation; wherein the production of hydrogen produced from one or more production wells is controlled by selectively and preferentially producing the mixture as a liquid from the formation.
84. The method of claim 83, wherein controlling hydrogen production from the formation comprises inhibiting production of gas from the formation.
85. The method of claim 83, wherein controlling hydrogen production from the formation comprises increasing production of condensable hydrocarbons from the formation.
86. The method of claim 83, wherein the mixture comprises condensable hydrocarbons, and wherein producing the mixture comprises pumping the mixture with a submersible pump.
87. The method of claim 83, further comprising controlling the heat provided to the formation such that a temperature of a majority of the section is less than about 375 °C.
88. The method of claim 83, wherein the produced mixture comprises hydrocarbons having an average API
gravity greater than about 25°.
89. The method of claim 83, wherein the mixture is produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars.
90. The method of claim 83, wherein the produced mixture comprises phenols.
91. A method of treating a hydrocarbon containing formation in situ, comprising:
providing heat from one or more heaters to at least a portion of the formation;
allowing the heat to transfer from one or more of the heaters to a section of the formation;
providing a mixture of hydrogen and a carrier fluid to the section;
controlling production of hydrogen from the formation; and producing formation fluid from the formation.
92. The method of claim 91, wherein the carrier fluid is nitrogen.
93. The method of claim 91, wherein the carrier fluid is methane.
94. The method of claim 91, wherein the carrier fluid is carbon dioxide.
95. The method of claim 91, wherein an amount of hydrogen in the mixture ranges from about 1 wt% to about 80 wt%.
96. The method of claim 91, wherein controlling hydrogen production from the formation comprises inhibiting production of gas from the formation.
97. The method of claim 91, wherein controlling hydrogen production from the formation comprises increasing production of condensable hydrocarbons from the formation.
98. The method of claim 91, wherein the produced formation fluid comprises condensable hydrocarbons and wherein producing the formation fluid comprises pumping the mixture with a submersible pump.
99. The method of claim 91, wherein the produced formation fluid comprises phenols.
100. The method of claim 91, wherein the mixture is produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars.
101. The method of claim 91, further comprising controlling the heating of the portion of the formation such that a temperature of a majority of the portion is less than about 375 °C.
102. The method of claim 91, wherein the formation fluid produced further comprises hydrocarbons having an average API gravity greater than about 25°.
103. A method of treating a hydrocarbon containing formation in situ, comprising;
forming a barrier around a treatment area of the formation to inhibit migration of fluids from the treatment area of the formation;
providing hydrogen to the treatment area;
providing heat from one or more heaters to the treatment area;
allowing the heat to transfer from one or more of the heaters to a section of the formation;
controlling production of hydrogen from the formation; and producing a mixture from the formation.
104. The method of claim 103, wherein controlling the production of hydrogen from the formation comprises inhibiting gas production from the formation.
105. The method of claim 103, wherein controlling the production of hydrogen from the formation comprises increasing condensable hydrocarbons production from the formation.
106. The method of claim 103, wherein controlling the production of hydrogen from the formation comprises increasing condensable hydrocarbons production, and wherein producing the mixture comprises pumping the condensable hydrocarbons with a submersible pump.
107. The method of claim 103, wherein the produced mixture comprises condensable hydrocarbons.
108. The method of claim 103, wherein the produced mixture comprises phenols.
109. The method of claim 103, wherein the mixture is produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars.
110. The method of claim 103, further comprising controlling the heating of the portion of the formation such that a temperature of a majority of the portion is less than about 375 °C.
111. The method of claim 103, wherein the formation fluid produced further comprises hydrocarbons having an average API gravity greater than about 25°.
112. A method of treating a hydrocarbon containing formation in situ, comprising;
providing a refrigerant to a plurality of barrier wells surrounding a treatment area of the formation;
establishing a frozen barrier zone to inhibit migration of fluids from the treatment area of the formation;
providing hydrogen to the treatment area;
providing heat from one or more heaters to the treatment area;
allowing the heat to transfer from one or more of the heaters to a section of the formation;
controlling production of hydrogen from the section; and producing a mixture from the formation.
113. The method of claim 112, wherein controlling hydrogen production from the formation comprises inhibiting gas production from the formation.
114. The method of claim 112, wherein controlling hydrogen production from the formation comprises increasing production of condensable hydrocarbons from the formation.
115. The method of claim 112, wherein controlling hydrogen production from the formation comprises increasing production of condensable hydrocarbons, and wherein producing the mixture comprises pumping the condensable hydrocarbons with a submersible pump.
116. The method of claim 112, wherein the produced mixture comprises substantially condensable hydrocarbons.
117. The method of claim 112, wherein the produced mixture comprises phenols.
118. The method of claim 112, wherein the mixture is produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars.
119. The method of claim 112, further comprising controlling the heating of the portion of the formation such that a temperature of a majority of the portion is less than about 375 °C.
120. The method of claim 112, wherein the formation fluid produced further comprises hydrocarbons having an average API gravity greater than about 25°.
121. A method for treating a hydrocarbon containing formation, comprising:
providing heat from one or more heaters to at least a portion of the formation, wherein at least one of the heaters is in at least one wellbore in the formation, and wherein at least one of the wellbores has been sized, at least in part, based on a determination of expansion of the formation caused by heating of the formation such that expansion of the formation caused by heating of the formation is not sufficient to cause substantial deformation of one or more heaters in such sized wellbores, and wherein a ratio of an outside diameter of the heater to an inside diameter of the wellbore is less than about 0.75;
allowing the heat to transfer from the one or more heaters to a part of the formation; and producing a mixture from the formation.
122. The method of claim 121, wherein at least one of the wellbores comprises an open wellbore.
123. The method of claim 121, wherein the ratio of the outside diameter of the heater to the inside diameter of the wellbore is less than about 0.5.
124. The method of claim 121, wherein the ratio of the outside diameter of the heater to the inside diameter of the wellbore is less than about 0.3.
125. The method of claim 121, further comprising controlling the heating to maintain a minimum space between at least one of the heaters and the formation in at least one of the wellbores.
126. The method of claim 121, further comprising controlling the heating using a temperature limited heater.
127. The method of claim 121, further comprising controlling the heating to maintain a minimum space of at least about 0.25 cm between at least one of the heaters and the formation in at least one wellbore.
128. The method of claim 121, wherein a diameter of one or more of the sized wellbores is greater than or equal to about 30 cm.
129. The method of claim 121, wherein one or more of the wellbores have an expanded diameter proximate to relatively rich zones in the formation.
130. The method of claim 129, wherein one or more of the expanded diameters is greater than or equal to about 30 cm.
131. The method of claim 129, wherein the relatively rich zones comprise a richness greater than about 0.15 L/kg.
132. The method of claim 129, wherein the relatively rich zones comprise a richness greater than about 0.17 L/kg.
133. The method of claim 121, further comprising adjusting a heat output of at least one of the heaters such that the heat output provided to relatively rich zones of the formation is less than the heat output provided to other zones of the formation.
134. The method of claim 133, wherein the relatively rich zones comprise a richness greater than about 0.15 L/kg.
135. The method of claim 121, further comprising adjusting a heat output of at least one of the heaters such that the heat output provided to relatively rich zones of the formation is less than about 1/2 the heat output provided to other zones of the formation.
136. The method of claim 121, further comprising reaming at least one of the wellbores after at least some heating of the formation from such wellbores.
137. The method of claim 121, further comprising reaming at least one of the wellbores after at least some heating of the formation from such wellbores, and wherein the reaming is conducted to remove at least some hydrocarbon material that has expanded in such wellbores.
138. The method of claim 121, further comprising removing at least one of the heaters from at least one of the wellbores, and then reaming at least one such wellbore.
139. The method of claim 121, further comprising perforating one or more relatively rich zones in at least part of the formation to allow for expansion of at least one or more of the relatively rich zones during heating of the formation.
140. The method of claim 121, further comprising placing a liner in at least one of the wellbores, between at least a part of one of the heaters and the formation, wherein the liner inhibits heater deformation caused by thermal expansion of the formation during heating.
141. The method of claim 140, wherein the liner comprises a mechanical strength sufficient to inhibit collapsing of the liner proximate relatively rich zones of the formation.
142. The method of claim 140, wherein the liner comprises one or more openings to allow fluids to flow through the wellbore in which the liner is placed.
143. The method of claim 140, wherein a ratio of an outside diameter of the liner to the inside diameter of the wellbore in which the liner is placed is less than about 0.75.
144. The method of claim 140, wherein a ratio of an outside diameter of the liner to the inside diameter of the wellbore in which the liner is placed is less than about 0.5.
145. The method of claim 140, wherein a ratio of an outside diameter of the liner to the inside diameter of the wellbore in which the liner is placed is less than about 0.3.
146. The method of claim 121, further comprising maintaining a temperature in at least a portion of the formation in a pyrolysis temperature range, with a lower pyrolysis temperature of about 250 °C and an upper pyrolysis temperature of about 400 °C.
147. The method of claim 121, further comprising heating at least a part of the formation to substantially pyrolyze at least some hydrocarbons in the formation.
148. The method of claim 121, further comprising controlling a pressure and a temperature in at least a part of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.
149. The method of claim 121, wherein allowing the heat to transfer from the one or more heaters to the part of the formation comprises transferring heat substantially by conduction.
150. The method of claim 121, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
151. The method of claim 121, further comprising controlling a pressure in at least a majority of a part of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.
152. The method of claim 121, further comprising controlling formation conditions such that the produced mixture comprises a partial pressure of H2 in the mixture greater than about 0.5 bars.
153. The method of claim 121, wherein the formation comprises an oil shale formation.
154. The method of claim 121, wherein the formation comprises a coal formation.
155. A method for treating a hydrocarbon containing formation, comprising:
providing heat from one or more heaters to at least a portion of the formation, wherein at least one of the heaters is in at least one of one or more wellbores in the formation, and wherein heating from one or more of the heaters is controlled to inhibit substantial deformation of one or more of the heaters caused by thermal expansion of the formation against such one or more heaters;
allowing the heat to transfer from the one or more heaters to a part of the formation; and producing a mixture from the formation.
156. The method of claim 155, wherein at least one of the wellbores comprises an uncased wellbore.
157. The method of claim 155, further comprising controlling the heating to maintain a minimum space between at least one of the heaters and the formation in at least one of the wellbores.
158. The method of claim 155, further comprising controlling the heating using a temperature limited heater.
159. The method of claim 155, further comprising controlling the heating to maintain a minimum space of at least about 0.25 cm between at least one of the heaters and the formation in at least one of the wellbores.
160. The method of claim 155, wherein at least one of the heaters is in at least one of the wellbores having a diameter sufficient to inhibit the formation from expanding against such heater during heating of the formation.
161. The method of claim 160, wherein the diameter of at least one of the wellbores having a diameter sufficient to inhibit the formation from expanding against such heater during the heating of the formation is greater than or equal to about 30 cm.
162. The method of claim 155, wherein one or more of the wellbores have an expanded diameter proximate to relatively rich zones in the formation.
163. The method of claim 162, wherein the expanded diameter is greater than or equal to about 30 cm.
164. The method of claim 162, wherein the relatively rich zones comprise a richness greater than about 0.15 L/kg.
165. The method of claim 162, wherein the relatively rich zones comprise a richness greater than about 0.17 L/kg.
166. The method of claim 155, wherein controlling the heating comprises adjusting a heat output of at least one of the heaters such that the heat output provided to relatively rich zones of the formation is less than the heat output provided to other zones of the formation.
167. The method of claim 155, wherein controlling the heating comprises adjusting a heat output of at least one of the heaters such that about the heat output provided to relatively rich zones of the formation is less than about 1/2 the heat output provided to other zones of the formation.
168. The method of claim 167, wherein the relatively rich zones comprise a richness greater than about 0.15 L/kg.
169. The method of claim 155, further comprising reaming at least one of the wellbores after at least some heating of the formation from such wellbores.
170. The method of claim 155, further comprising reaming at least one of the wellbores after at least some heating of the formation from such wellbores, and wherein the reaming is conducted to remove at least some hydrocarbon material that has expanded in such wellbores.
171. The method of claim 155, further comprising removing at least one of the heaters from at least one of the wellbores, and then reaming at least one such wellbore.
172,. The method of claim 155, further comprising perforating one or more relatively rich zones in at least part of the formation to allow for expansion of at least one or more of the relatively rich zones during heating of the formation.
173. The method of claim 155, further comprising placing a liner in at least one of the wellbores and between at least a part of one of the heaters and the formation, wherein the liner inhibits heater deformation caused by thermal expansion of the formation during heating.
174. The method of claim 173, wherein the liner comprises a mechanical strength sufficient to inhibit collapsing of the liner proximate relatively rich zones of the formation.
175. The method of claim 173, wherein the liner comprises one or more openings to allow fluids to flow through the wellbore in which the liner is placed.
176. The method of claim 173, wherein a ratio of an outside diameter of the liner to the inside diameter of the wellbore in which the liner is placed is less than 0.75.
177. The method of claim 173, wherein a ratio of an outside diameter of the liner to the inside diameter of the wellbore in which the liner is placed is less than 0.5.
178. The method of claim 173, wherein a ratio of an outside diameter of the liner to the inside diameter of the wellbore in which the liner is placed is less than 0.3.
179. The method of claim 155, further comprising maintaining a temperature in at least a portion of the formation in a pyrolysis temperature range with a lower pyrolysis temperature of about 250 °C and an upper pyrolysis temperature of about 400 °C.
180. The method of claim 155, further comprising heating at least a part of the formation to substantially pyrolyze at least some hydrocarbons in the formation.
181. The method of claim 155, further comprising controlling a pressure and a temperature in at least a part of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.
182. The method of claim 155, wherein allowing the heat to transfer from the one or more heaters to the part of the formation comprises transferring heat substantially by conduction.
183. The method of claim 155, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
184. The method of claim 155, further comprising controlling a pressure in at least a majority of a part of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.
185. The method of claim 155, further comprising controlling formation conditions such that the produced mixture comprises a partial pressure of H2 in the mixture greater than about 0.5 bars.
186. The method of claim 155, wherein the formation comprises an oil shale formation.
187. The method of claim 155, wherein the formation comprises a coal formation.
188. A system configured to heat at least a part of a hydrocarbon containing formation, comprising:
an elongated heater located in an opening in the formation, wherein at least a portion of the formation has a richness of at least about 30 gallons of hydrocarbons per ton of formation, as measured by Fischer Assay, and wherein the heater is configured to provide heat to at least a part of the formation during use such that at least a part of the formation is heated to at least about 250 °C; and wherein an initial diameter of the opening is at least 1.5 times the largest transverse cross-sectional dimension of the heater in the opening and proximate the part of the formation being heated such that it inhibits the formation from deforming the heater due to expansion of the formation caused by heating of the formation.
189. The system of claim 188, wherein the initial diameter of the opening is at least about 2 times the largest transverse cross-sectional dimension of the heater in the opening.
190. The system of claim 188, wherein the initial diameter of the opening is sufficiently large enough to inhibit the formation from deforming the heater during heating of the formation.
191. The system of claim 188, wherein the initial diameter of the opening is sufficiently large enough to inhibit the formation from seizing the heater during heating of the formation.
192. The system of claim 188, wherein the initial diameter of the opening is sufficiently large enough to inhibit the formation from damaging the heater during heating of the formation.
193. The system of claim 188, wherein the initial diameter of the opening is sufficiently large enough to inhibit the formation from compressing the heater during heating of the formation.
194. The system of claim 188, wherein the initial diameter of the opening is at least 3 times the largest transverse cross-sectional dimension of the heater in the opening.
195. The system of claim 188, wherein the initial diameter of the opening is at least 4 times the largest transverse cross-sectional dimension of the heater in the opening.
196. The system of claim 188, wherein the system is configured to pyrolyze at least some hydrocarbons in the formation during use.
197. The system of claim 188, wherein the initial diameter of the opening is approximately a size of a drillbit used to form the opening.
198. The system of claim 188, wherein the heater comprises a ferromagnetic material.
199. The system of claim 188, wherein the heater comprises a temperature limited heater.
200. The system of claim 188, wherein the opening comprises an uncased wellbore.
201. The system of claim 188, wherein the heater is located in at least a portion of a deformation resistant container.
202. The system of claim 201, wherein the initial diameter of the opening is sufficiently large enough to inhibit the formation from deforming the deformation resistant container during heating of the formation.
203. The system of claim 188, wherein the initial diameter of the opening is at least 2 times the largest transverse cross-sectional dimension of the heater in the opening and proximate a part of the formation that comprises a richness of at least about 0.12 L/kg.
204. The system of claim 188, wherein the formation comprises an oil shale formation.
205. The system of claim 188, wherein the formation comprises a coal formation.
206. A method for treating a hydrocarbon containing formation, comprising:
heating a first volume of the formation using a first set of heaters; and heating a second volume of the formation using a second set of heaters, wherein the first volume is spaced apart from the second volume by a third volume of the formation, and wherein the first volume, the second volume, and the third volume are sized, shaped, and/or located to inhibit deformation of subsurface equipment caused by geomechanical motion of the formation during heating.
207. The method of claim 206, further comprising allowing the heat to transfer from the first volume and the second volume of the formation to at least a part of the formation.
208. The method of claim 206, wherein a footprint of the first volume, the second volume, or the third volume is sized, shaped, or located to inhibit deformation of subsurface equipment caused by geomechanical motion of the formation during heating.
209. The method of claim 206, further comprising sizing, shaping, or locating the first volume, second volume, or third volume to inhibit deformation of subsurface equipment caused by geomechanical motion of the formation during heating.
210. The method of claim 206, further comprising calculating geomechanical motion in a footprint of the first volume or the second volume, and using the calculated geomechanical motion to size, shape, or locate the first volume, the second volume, or the third volume.
211. The method of claim 206, further comprising allowing the heat to transfer from the first volume and the second volume of the formation to at least a part of the formation, and producing a mixture from the formation.
212. The method of claim 206, wherein the third volume substantially surrounds the first volume, and the second volume substantially surrounds the first volume.
213. The method of claim 206, wherein the third volume substantially surrounds all or a portion of the first volume, and the second volume substantially surrounds all or a portion of the third volume.
214. The method of claim 206, wherein the third volume has a footprint that is a linear, curved, or irregular shaped strip.
215. The method of claim 206, wherein the first volume and the second volume comprise rectangular footprints.
216. The method of claim 206, wherein the first volume and the second volume comprise square footprints.
217. The method of claim 206, wherein the first volume and the second volume comprise circular footprints.
218. The method of claim 206, wherein the first volume and the second volume comprise footprints in a concentric ring pattern.
219. The method of claim 206, wherein the first volume, the second volume, and the third volume comprise rectangular footprints.
220. The method of claim 206, wherein the first volume, the second volume, and the third volume comprise square footprints.
221. The method of claim 206, wherein the first volume, the second volume, and the third volume comprise circular footprints.
222. The method of claim 206, wherein the first volume, the second volume, and the third volume comprise footprints in a concentric ring pattern.
223. The method of claim 206, wherein the first volume, the second volume, or the third volume are sized, shaped, or located based on, at least in part, a calculated geomechanical motion of at least a portion of the formation.
224. The method of claim 206, further comprising sizing, shaping, or locating the first volume, the second volume, or the third volume based on, at least in part, a calculated geomechanical motion of at least a portion of the formation.
225. The method of claim 206, wherein the first volume, the second volume, or the third volume are sized, shaped, or located, at least in part, to inhibit deformation, caused by geomechanical motion of one or more selected wellbores in the formation.
226. The method of claim 206, wherein the first volume, the second volume, or the third volume are at least in part sized, shaped, or located based on a calculated geomechanical motion of at least a portion of the formation, and wherein the first volume, the second volume, or the third volume are sized, shaped, or located, at least in part, to inhibit deformation, caused by geomechanical motion, of one or more selected wellbores in the formation.
227. The method of claim 206, wherein the first volume, the second volume, or the third volume of the formation have been sized, shaped, or located, at least in part, based on a simulation.
228. The method of claim 206, wherein the first volume, the second volume, and the third volume of the formation have been sized, shaped, or located, at least in part, based on a simulation.
229. The method of claim 206, wherein a footprint area of the first volume, the second volume, or the third volume is less than about 400 square meters.
230. The method of claim 206, further comprising heating with a third set of heaters after a selected amount of geomechanical motion in the first volume or the second volume.
231. The method of claim 206, further comprising heating with a third set of heaters to maintain or enhance a production rate of a mixture from the formation.
232. The method of claim 206, further comprising maintaining a temperature in at least a portion of the formation in a pyrolysis temperature range with a lower pyrolysis temperature of about 250 °C and an upper pyrolysis temperature of about 400 °C.
233. The method of claim 206, further comprising pyrolyzing at least some hydrocarbons in the formation.
234. The method of claim 206, further comprising controlling a pressure and a temperature in at least a part of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.
235. The method of claim 206, further comprising producing a mixture from the formation.
236. The method of claim 235, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
237. The method of claim 235, further comprising controlling formation conditions such that the produced mixture comprises a partial pressure of H2 in the mixture greater than about 0.5 bars.
238. The method of claim 206, further comprising controlling a pressure in at least a part of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.
239. The method of claim 206, wherein the formation comprises an oil shale formation.
240. The method of claim 206, wherein the formation comprises a coal formation.
241. A method for treating a hydrocarbon containing formation, comprising:
heating a first volume of the formation using a first set of heaters;
heating a second volume of the formation using a second set of heaters, wherein the first volume is spaced apart from the second volume by a third volume of the formation;
heating the third volume using a third set of heaters, wherein the third set of heaters begins heating at a selected time after the first set of heaters and the second set of heaters;
allowing the heat to transfer from the first volume, the second volume, and the third volume of the formation to at least a part of the formation; and producing a mixture from the formation.
242. The method of claim 241, wherein the first volume, the second volume, or the third volume are sized, shaped, or located based on, at least in part, a calculated geomechanical motion of at least a portion of the formation.
243. The method of claim 241, further comprising sizing, shaping, or locating the first volume, the second volume, or the third volume based on, at least in part, a calculated geomechanical motion of at least a portion of the formation.
244. The method of claim 241, wherein the first volume, the second volume, or the third volume are sized, shaped, or located, at least in part, to inhibit deformation, caused by geomechanical motion, of one or more selected wellbores in the formation.
245. The method of claim 241, wherein the first volume, the second volume, or the third volume are at least in part sized, shaped, or located based on a calculated geomechanical motion of at least a portion of the formation, and wherein the first volume, the second volume, or the third volume are sized, shaped, or located, at least in part, to inhibit deformation caused by geomechanical motion of one or more selected wellbores in the formation.
246. The method of claim 241, wherein the first volume, the second volume, or the third volume of the formation has been sized, shaped, or located, at least in part, based on a simulation.
247. The method of claim 241, wherein the first volume, the second volume, and the third volume of the formation have been sized, shaped, or located, at leapt in part, based on a simulation.
248. The method of claim 241, wherein a footprint area of the first volume, the second volume, or the third volume is less than about 400 square meters.
249. The method of claim 241, wherein the third set of heaters begins heating after a selected amount of geomechanical motion in the first volume or the second volume.
250. The method of claim 241, wherein the third set of heaters begins heating to maintain or enhance a production rate of the mixture from the formation.
251. The method of claim 241, wherein the selected time has been at least in part determined using a simulation.
252. The method of claim 241, wherein the first volume and the second volume comprise rectangular footprints.
253. The method of claim 241, wherein the first volume and the second volume comprise square footprints.
254. The method of claim 241, wherein the first volume and the second volume comprise circular footprints.
255. The method of claim 241, wherein the first volume, the second volume, and the third volume comprise rectangular footprints.
256. The method of claim 241, wherein the first volume, the second volume, and the third volume comprise square footprints.
257. The method of claim 241, wherein the first volume, the second volume, and the third volume comprise circular footprints.
258. The method of claim 241, wherein the first volume, the second volume, and the third volume comprise footprints in a concentric ring pattern.
259. The method of claim 241, further comprising maintaining a temperature in at least a portion of the formation in a pyrolysis temperature range with a lower pyrolysis temperature of about 250 °C and an upper pyrolysis temperature of about 400 °C.
260. The method of claim 241, further comprising pyrolyzing at least some of the hydrocarbons in the formation.
261. The method of claim 241, further comprising controlling a pressure and a temperature in at least a majority of the part of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.
262. The method of claim 241, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
263. The method of claim 241, further comprising controlling a pressure in at least a majority of a part of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.
264. The method of claim 241, further comprising controlling formation conditions such that the produced mixture comprises a partial pressure of H2 in the mixture greater than about 0.5 bars.
265. The method of claim 241, wherein the third set of heaters begins heating about 6 months after the first set of heaters or the second set of heaters begins heating.
266. The method of claim 241, wherein the formation comprises an oil shale formation.
267. The method of claim 241, wherein the formation comprises a coal formation.
268. A system configured to heat at least a part of a subsurface formation, comprising:
an AC power supply;
one or more electrical conductors configured to be electrically coupled to the AC power supply and placed in an opening in the formation, wherein at least one of the electrical conductors comprises a heater section, the heater section comprising an electrically resistive ferromagnetic material configured to provide an electrically resistive heat output when AC is applied to the ferromagnetic material, and wherein the heater section is configured to provide a reduced amount of heat near or above a selected temperature during use due to the decreasing AC
resistance of the heater section when the temperature of the ferromagnetic material is near or above the selected temperature; and wherein the system is configured to allow heat to transfer from the heater section to a part of the formation.
269. The system of claim 268, wherein the heater section automatically provides a reduced amount of heat above or near the selected temperature.
270. The system of claim 268, wherein at least a portion of the heater section is positionable adjacent to an overburden of the formation to heat at least a part of the overburden to inhibit condensation of vapors in a wellbore passing through the overburden.
271. The system of claim 268, wherein at least a portion of the heater section is positionable adjacent to hydrocarbon material in the formation to raise a temperature of at least some of the hydrocarbon material to or above a pyrolysis temperature.
272. The system of claim 268, wherein the subsurface formation comprises a hydrocarbon containing formation, and wherein the system is configured to pyrolyze at least some hydrocarbons in the formation.
273. The system of claim 268, wherein the subsurface formation comprises contaminated soil, and wherein the system is configured to decontaminate at least a portion of the contaminated soil.
274. The system of claim 268, wherein the system comprises three or more electrical conductors, and wherein at least three of the electrical conductors are configured to be electrically connected in a three-phase configuration.
275. The system of claim 268, wherein the heater section is configured to provide the reduced amount of heat without controlled adjustment of the AC.
276. The system of claim 268, wherein the heater section is configured to exhibit an increase in operating temperature of less than about 1.5 °C above or near a selected operating temperature when a thermal load proximate the heater section decreases by about 1 watt per meter.
277. The system of claim 268, further comprising an oxidation heater placed in the opening in the formation.
278. The system of claim 277, wherein the oxidation heater comprises a natural distributed combustor.
279. The system of claim 277, wherein the oxidation heater comprises a flameless distributed combustor.
280. The system of claim 277, wherein at least one of the electrical conductors is configured to provide heat to initiate an oxidation reaction in the oxidation heater during use.
281. The system of claim 277, wherein the selected temperature is above an initiation temperature for an oxidation reaction to commence in the oxidation heater, and wherein the selected temperature is below an operating temperature of the oxidation heater during use.
282. The system of claim 268, further comprising a highly electrically conductive material coupled to at least a portion of the ferromagnetic material of an electrical conductor, wherein AC
applied to the electrical conductor substantially flows through the ferromagnetic conductor when a temperature of the ferromagnetic conductor is below the selected temperature, and wherein the AC applied to the conductor is configured to flow through the highly electrically conductive material when the temperature of the ferromagnetic conductor is near or above the selected temperature.
283. The system of claim 268, wherein the ferromagnetic material comprises an elongated material, wherein the system further comprises an elongated highly electrically conductive material, and wherein at least about 50% of the elongated material is electrically coupled to the elongated highly electrically conductive material.
284. The system of claim 268, wherein at least one of the electrical conductors is configured to provide a reduced amount of heat above or near the selected temperature that is about 20% or less of the heat output at about 50 °C below the selected temperature.
285. The system of claim 268, wherein the heater section is configured such that the decreased AC resistance through the heater section above or near the selected temperature is about 20%
or less than the AC resistance at about 50 °C below the selected temperature.
286. The system of claim 268, wherein the AC resistance of the heater section above or near the selected temperature is about 80% or less of the AC resistance at about 50 °C
below the selected temperature.
287. The system of claim 268, wherein the AC resistance of the heater section decreases above the selected temperature to provide the reduced amount of heat.
288. The system of claim 268, wherein the heater section is configured to automatically exhibit the decreased AC resistance above or near a selected temperature.
289. The system of claim 268, further comprising a non-ferromagnetic material coupled to the ferromagnetic material, wherein the non-ferromagnetic material has a higher electrical conductivity than the ferromagnetic material.
290. The system of claim 268, further comprising a second ferromagnetic material coupled to the ferromagnetic material.
291. The system of claim 268, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
292. The system of claim 268, wherein at least one of the electrical conductors is electrically coupled to the earth, and wherein electrical current is propagated from the electrical conductor to the earth.
293. The system of claim 268, wherein the heater section is elongated, and wherein the reduced amount of heat is less than about 400 watts per meter of length of the heater section.
294. The system of claim 268, wherein the heater section is elongated, and wherein the heat output from the ferromagnetic material is greater than about 400 watts per meter of length of the heater section when the temperature of the ferromagnetic material is below the selected temperature during use.
295. The system of claim 268, wherein the ferromagnetic material has a turndown ratio of at least about 2 to 1.
296. The system of claim 268, further comprising a deformation resistant container configured.to contain at least one electrical conductor, and wherein the selected temperature is chosen such that the deformation resistant container has a creep-rupture strength of at least about 3000 psi at 100,000 hours at the selected temperature.
297. The system of claim 268, wherein one or more electrical conductors comprise two or more electrical conductors and an electrically insulating material placed between at least two of the electrical conductors.
298. The system of claim 268, wherein the ferromagnetic material comprises iron, nickel, chromium, cobalt, tungsten, or a mixture thereof.
299. The system of claim 268, wherein the ferromagnetic material comprises a mixture of iron and nickel.
300. The system of claim 268, wherein the ferromagnetic material comprises a mixture of iron and cobalt.
301. The system of claim 268, wherein the system is configured such that the ferromagnetic material has a thickness of at least about 3/4 of a skin depth of the AC at the Curie temperature of the ferromagnetic material.
302. The system of claim 268, wherein the system is configured such that the ferromagnetic material has a thickness of at least about 3/4 of a skin depth of the AC at the Curie temperature of the ferromagnetic material, and wherein the ferromagnetic material is coupled to a material that is more conductive that the ferromagnetic material such that the coupled materials exhibit a greater conductivity at the Curie temperature of the ferromagnetic material than the ferromagnetic material with the same thickness as the coupled materials.
303. The system of claim 268, wherein the system is configured such that the ferromagnetic material has a thickness of at least about a skin depth of the AC at the Curie temperature of the ferromagnetic material.
304. The system of claim 268, wherein the ferromagnetic material comprises two or more ferromagnetic materials with different Curie temperatures.
305. The system of claim 268, wherein at least one of the electrical conductors comprises ferromagnetic material and non-ferromagnetic electrically conductive material.
306. The system of claim 268, wherein the subsurface formation comprises a hydrocarbon containing formation, and wherein at least a portion of the electrically resistive ferromagnetic material is located proximate a relatively rich zone of the formation.
307. The system of claim 268, wherein the ferromagnetic material is coupled to a corrosion resistant material.
308. The system of claim 268, wherein at least one of the electrical conductors is part of an insulated conductor heater.
309. The system of claim 268, wherein at least one of the electrical conductors is part of a conductor-in-conduit heater.
310. The system of claim 268, wherein the ferromagnetic material is coupled to a material that is more conductive than the ferromagnetic material, and wherein thicknesses of both materials and skin depth characteristics of the ferromagnetic material are configured to provide a selected resistance profile as a function of temperature.
311. The system of claim 268, wherein at least a portion of at least one of the electrical conductors comprises a relatively flat AC resistance profile in a temperature range between about 100 °C and 750 °C.
312. The system of claim 268, wherein at least a portion of at least one of the electrical conductors comprises a relatively flat AC resistance profile in a temperature range between about 100 °C and 700 °C and a relatively sharp resistance profile at a temperature above about 700 °C and less than about 850 °C.
313. The system of claim 268, wherein at least a portion of at least one of the electrical conductors comprises a relatively flat AC resistance profile in a temperature range between about 300 °C and 600 °C.
314. The system of claim 268, wherein at least a portion of at least one electrically resistive ferromagnetic material is longer than about 10 m.
315. The system of claim 268, wherein the system is configured to sharply reduce the heat output at or near the selected temperature.
316. The system of claim 268, wherein at least one of the electrical conductors comprises an electrically resistive ferromagnetic material drawn together with or against a material with a higher conductivity than the ferromagnetic material.
317. The system of claim 268, wherein at least one of the electrical conductors comprises an elongated conduit comprising a center portion and an outer portion, and wherein the center portion comprises iron and has a diameter of at least about 0.5 cm.
318. The system of claim 268, wherein at least one of the electrical conductors comprises a composite material, wherein the composite material comprises a first material with a resistance that decreases when the first material is heated to the selected temperature, wherein the composite material comprises a second material that is more electrically conductive than the first material, and wherein the first material is coupled to the second material.
319. The system of claim 268, wherein the reduced amount of heat comprises a heating rate lower than the rate at which the formation will absorb or transfer heat, thereby inhibiting overheating of the formation.
320. The system of claim 268, wherein at least one of the electrical conductors is elongated and configured such that only electrically resistive sections at or near the selected temperature will automatically reduce the heat output.
321. The system of claim 268, wherein the system is configured such that an AC
resistance of at least one of the electrical conductors increases with an increase in temperature up to the selected temperature.
322. The system of claim 268, wherein the system is configured such that an AC
resistance of at least one of the electrical conductors decreases with an increase in temperature above the selected temperature.
323. The system of claim 268, wherein the system is configured to apply AC of at least about 70 amps to at least one of the electrical conductors.
324. The system of claim 268, wherein the system is configured to apply AC at about 180 Hz.
325. The system of claim 268, wherein the system is configured to apply AC at about 60 Hz.
326. The system of claim 268, wherein the ferromagnetic material is positioned in an opening in the formation, and wherein at least a portion of the opening in the formation adjacent to the ferromagnetic material comprises an uncased wellbore.
327. The system of claim 268, wherein the ferromagnetic material is configured to radiatively heat the formation.
328. The system of claim 268, wherein at least one of the electrical conductors is located in an overburden of the formation.
329. The system of claim 268, wherein at least one of the electrical conductors is coupled to a cable, and wherein the cable comprises a plurality of copper wires coated with an oxidation resistant alloy.
330. A method for heating a subsurface formation, comprising:
applying AC to one or more electrical conductors located in the subsurface formation to provide an electrically resistive heat output, wherein at least one of the electrical conductors comprises an electrically resistive ferromagnetic material that provides heat when AC flows through the electrically resistive ferromagnetic material, and wherein such electrical conductor comprising electrically resistive ferromagnetic material provides a reduced amount of heat above or near a selected temperature; and allowing the heat to transfer from the electrically resistive ferromagnetic material to a part of the subsurface formation.
331. The method of claim 330, wherein the electrically resistive ferromagnetic material automatically provides a selected reduced amount of heat above or near a selected temperature.
332. The method of claim 330, further comprising placing one or more of the electrical conductors in a wellbore in the formation.
333. The method of claim 330, wherein an AC resistance of the ferromagnetic material decreases above the selected temperature to provide the reduced amount of heat.
334. The method of claim 330, wherein a thickness of the ferromagnetic material is greater than about 3/4 of a skin depth of the AC at the Curie temperature of the ferromagnetic material.
335. The method of claim 330, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
336. The method of claim 330, wherein the selected temperature is within about 50 °C of the Curie temperature of the ferromagnetic material.
337. The method of claim 330, wherein the subsurface formation comprises a hydrocarbon containing formation.
338. The method of claim 330, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising heating at least some hydrocarbons in the formation such that at least some of the hydrocarbons are pyrolyzed.
339. The method of claim 330, wherein one or more of the electrical conductors are located in a wellbore, and further comprising providing a reduced amount of heat of less than about 400 watts per meter of length of the wellbore while one or more of the electrical conductors are above or near the selected temperature.
340. The method of claim 330, wherein one or more of the electrical conductors are located in a wellbore, and further comprising providing a heat output of greater than about 400 watts per meter of length of the wellbore while one or more of the electrical conductors are below the selected temperature.
341. The method of claim 330, further comprising controlling the amount of current applied to one or more of the electrical conductors to control the amount of heat provided by the ferromagnetic material.
342. The method of claim 330, further comprising applying an AC of at least about 70 amps to the electrical conductors.
343. The method of claim 330, further comprising applying an AC of at least about 100 amps to the electrical conductors.
344. The method of claim 330, further comprising applying the AC at a frequency of about 180 Hz.
345. The method of claim 330, wherein the heat transfers radiatively from at least one of the electrical conductors to at least the part of the formation.
346. The method of claim 330, further comprising providing a relatively constant heat output when an electrical conductor is in a temperature range between about 300 °C and 600 °C.
347. The method of claim 330, further comprising providing a relatively constant heat output when an electrical conductor is in a temperature range between about 100 °C and 750 °C.
348. The method of claim 330, further comprising providing a heat output from at least one of the electrical conductors, wherein an AC resistance of one or more of such electrical conductors above or near the selected temperature is about 80% or less of the AC resistance of such one or more electrical conductors at about 50 °C
below the selected temperature.
349. The method of claim 330, further comprising providing an initial electrically resistive heat output when the electrical conductor providing the heat output is at least about 50 °C
below the selected temperature, and automatically providing the reduced amount of heat above or near the selected temperature.
350. The method of claim 330, wherein the subsurface formation comprises contaminated soil, and further comprising using the provided heat to decontaminate the soil.
351. The method of claim 330, wherein at least one of the electrical conductors is electrically coupled to the earth, and further comprising propagating electrical current from at least one of the electrical conductors to the earth.
352. The method of claim 330, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about
25°.
353. The method of claim 330, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising controlling a pressure in at least a part of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.
354. The method of claim 330, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising controlling formation conditions such that a produced mixture comprises a partial pressure of H2 greater than about 0.5 bars.
355. The method of claim 330, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising altering a pressure in the formation to inhibit production of hydrocarbons having carbon numbers greater than about 25.
356. The method of claim 330, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising controlling the provided heat to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
357. The method of claim 330, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising heating at least a portion of the part of the formation to a minimum pyrolysis temperature of about 270 °C.
358. The method of claim 330, further comprising controlling a skin depth in the ferromagnetic material by controlling a frequency of the applied AC.
359. The method of claim 330, further comprising increasing the AC applied to at least one of the electrical conductors as the temperature of such electrical conductors increases, and continuing to do so until the temperature is at or near the selected temperature.
360. The method of claim 330, further comprising controlling an amount of current applied to at least one of the electrical conductors to control an amount of heat output from such electrical conductors.
361. The method of claim 330, further comprising increasing an amount of current applied to at least one of the electrical conductors to decrease an amount of heat output from such electrical conductors.
362. The method of claim 330, further comprising decreasing an amount of current applied to at least one of the electrical conductors to increase an amount of heat output from such electrical conductors.
363. The method of claim 330, further comprising producing fluids from the formation, and producing refined products from the produced fluids.
364. The method of claim 330, further comprising producing fluids from the formation, and producing a blending agent from the produced fluids.
365. The method of claim 330, further comprising providing heat from at least one of the electrical conductors to fluids in a wellbore in the formation.
366. The method of claim 330, further comprising producing fluids from the formation, and blending the produced fluids with hydrocarbons having an API gravity below about 15°.
367. A method for heating a subsurface formation, comprising:
applying AC to one or more electrical conductors placed in an opening in the formation, wherein at least one of the electrical conductors comprises one or more electrically resistive sections;
providing an electrically resistive heat output from at least one of the electrically resistive sections, wherein such electrically resistive sections provide a reduced amount of heat above or near a selected temperature that is about 20% or less of the heat output at about 50 °C below the selected temperature; and allowing the heat to transfer from at least one of the electrically resistive sections to at least a part of the formation.
368. The method of claim 367, further comprising applying the AC at a frequency of about 180 Hz.
369. The method of claim 367, further comprising placing one or more of the electrical conductors in the opening.
370. The method of claim 367, further comprising providing an initial electrically resistive heat output when the electrically resistive section providing the heat output is at least about 50 °C below the selected temperature, and automatically providing the reduced amount of heat above or near the selected temperature.
371. The method of claim 367, further comprising providing a reduced amount of heat above or near the selected temperature that is less than about 20% of the heat output at about 40 °C below the selected temperature.
372. The method of claim 367, further comprising providing a reduced amount of heat above or near the selected temperature that is less than about 20% of the heat output at about 30 °C below the selected temperature.
373. The method of claim 367, further comprising providing a reduced amount of heat above or near the selected temperature that is less than about 15% of the heat output at about 50 °C below the selected temperature.
374. The method of claim 367, further comprising providing a reduced amount of heat above or near the selected temperature that is less than about 10% of the heat output at about 50 °C below the selected temperature.
375. The method of claim 367, further comprising allowing the heat to transfer radiatively from at least one of the electrically resistive sections to at least a part of the formation.
376. The method of claim 367, wherein at least one of the electrically resistive sections comprises ferromagnetic material, and wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
377. The method of claim 367, wherein at least one of the electrically resistive sections comprises ferromagnetic material, and wherein the selected temperature is within about 50 °C of the Curie temperature of the ferromagnetic material.
378. The method of claim 367, further comprising providing a relatively constant heat output from one or more of the electrically resistive sections when such electrically resistive sections are in a temperature range between about 100 °C and about 750 °C.
379. The method of claim 367, further comprising automatically decreasing an AC resistance of at least one of the electrically resistive sections when such an electrically resistive section is above the selected temperature to provide the reduced amount of heat above the selected temperature.
380. The method of claim 367, wherein the subsurface formation comprises a hydrocarbon containing formation.
381. The method of claim 367, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising heating at least some hydrocarbons in the formation to pyrolyze at some of the hydrocarbons in the formation.
382. The method of claim 367, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising positioning at least one of the electrically resistive sections proximate a relatively rich zone of the formation.
383. The method of claim 367, further comprising providing a reduced amount of heat of less than about 400 watts per meter of length of the opening above or near the selected temperature.
384. The method of claim 367, further comprising applying AC of at least about 70 amps to at least one of the electrical conductors.
385. A method for heating a subsurface formation, comprising:
applying a current to one or more electrical conductors placed in an opening in the formation, wherein at least one of the electrical conductors comprises one or more electrically resistive sections;
providing an electrically resistive heat output from at least one of the electrically resistive sections, wherein such electrically resistive sections provide a reduced amount of heat above or near a selected temperature that is about 20% or less of the heat output at about 50 °C below the selected temperature; and allowing the heat to transfer from at least one of the electrically resistive sections to at least a part of the formation.
386. The method of claim 385, further comprising applying alternating current to the one or more electrical conductors.
387. The method of claim 385, further comprising applying direct current to the one or more electrical conductors.
388. The method of claim 385, further comprising placing one or more of the electrical conductors in the opening.
389. The method of claim 385, further comprising providing an initial electrically resistive heat output when the electrically resistive section providing the heat output is at least about 50 °C below the selected temperature, and automatically providing the reduced amount of heat above or near the selected temperature.
390. The method of claim 385, further comprising providing a reduced amount of heat above or near the selected temperature that is less than about 20% of the heat output at about 40 °C below the selected temperature.
391. The method of claim 385, further comprising providing a reduced amount of heat above or near the selected temperature that is less than about 20% of the heat output at about 30 °C below the selected temperature.
392. The method of claim 385, further comprising allowing the heat to transfer radiatively from at least one of the electrically resistive sections to at least a part of the formation.
393. The method of claim 385, further comprising automatically decreasing an AC resistance of at least one of the electrically resistive sections when such an electrically resistive section is above the selected temperature to provide the reduced amount of heat above the selected temperature.
394. The method of claim 385, further comprising automatically increasing a resistance of at least one of the electrically resistive sections when such an electrically resistive section is above the selected temperature to provide the reduced amount of heat above the selected temperature.
395. The method of claim 385, further comprising automatically increasing a resistance of at least one of the electrically resistive sections by a factor of at least about 4 when such an electrically resistive section is above the selected temperature to provide the reduced amount of heat above the selected temperature.
396. The method of claim 385, further comprising automatically increasing a resistance of at least one of the electrically resistive sections when such an electrically resistive section is above the selected temperature to provide the reduced amount of heat above the selected temperature such that electrical current propagates through at least one other electrically resistive section.
397. The method of claim 385, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising heating at least some hydrocarbons in the formation to pyrolyze at some of the hydrocarbons in the formation.
398. A method for heating a subsurface formation, comprising:
applying AC to one or more electrical conductors placed in an opening in the formation, wherein at least one of the electrical conductors comprises an electrically resistive ferromagnetic material that provides an electrically resistive heat output when AC is applied to the ferromagnetic material, and wherein AC is applied when the ferromagnetic material is about 50 °C below a Curie temperature of the ferromagnetic material to provide an initial electrically resistive heat output;
allowing the temperature of the ferromagnetic material to approach or rise above the Curie temperature of the ferromagnetic material; and allowing the heat output from at least one of the electrical conductors to decrease below the initial electrically resistive heat output as a result of a change in AC resistance of such electrical conductor caused by the temperature of the ferromagnetic material approaching or rising above the Curie temperature of the ferromagnetic material.
399. The method of claim 398, further comprising applying AC at a frequency of about 180 Hz.
400. The method of claim 398, further comprising placing one or more of the electrical conductors in the opening.
401. The method of claim 398, wherein the decreased heat output is less than about 50% of the initial heat output.
402. The method of claim 398, wherein the decreased heat output is less than about 20% of the initial heat output.
403. The method of claim 398, further comprising allowing the heat to transfer radiatively from at least one of the electrical conductors to at least a part of the formation.
404. The method of claim 398, wherein the subsurface formation comprises a hydrocarbon containing formation.
405. The method of claim 398, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising heating at least some hydrocarbons in the formation to pyrolyze at some of the hydrocarbons in the formation.
406. The method of claim 398, further comprising producing at least some fluids from the formation.
407. The method of claim 398, wherein the declined heat output is less than about 400 watts per meter of length of the opening.
408. The method of claim 398, further comprising applying AC of at least about 70 amps to at least one of the electrical conductors.
409. A heater system, comprising:
an AC supply configured to provide AC at a voltage above about 200 volts;
an electrical conductor comprising one or more ferromagnetic sections, wherein the electrical conductor is electrically coupled to the AC supply, wherein at least one of the ferromagnetic sections is configured to provide an electrically resistive heat output during application of AC to the electrical conductor such that heat can transfer to material adjacent to such ferromagnetic section, and wherein such ferromagnetic section is configured to provide a reduced amount of heat above or near a selected temperature during use; and wherein the selected temperature is at or about the Curie temperature of the ferromagnetic section.
410. The heater system of claim 409, wherein the AC supply is configured to provide the AC at a voltage above about 650 volts.
411. The heater system of claim 409, wherein the AC supply is configured to provide the AC at a voltage above about 1000 volts.
412. The heater system of claim 409, wherein the heater system is configured to provide heat to a subsurface formation.
413. The heater system of claim 409, wherein the heater system is configured to provide heat to a hydrocarbon containing formation.
414. The heater system of claim 409, wherein the heater system is configured to provide heat to a hydrocarbon containing formation, and wherein the heater system is configured to pyrolyze at least some hydrocarbons in the formation.
415. The heater system of claim 409, wherein the heater system is configured to provide heat to contaminated soil, and wherein the heater system is configured to decontaminate at least a portion of the contaminated soil.
416. The heater system of claim 409, wherein the heater system is configured to provide heat to at least a portion of an opening in a subsurface formation.
417. The heater system of claim 409, wherein the heater system comprises three or more electrical conductors, and wherein at least three of the electrical conductors are configured to be coupled in a three-phase electrical configuration.
418. The heater system of claim 409, wherein at least one of the ferromagnetic sections comprises iron, nickel, chromium, cobalt, tungsten, or a mixture thereof.
419. The heater system of claim 409, wherein at least one of the ferromagnetic sections has a thickness of at least about 3/4 of a skin depth of the AC at the Curie temperature of such ferromagnetic sections.
420. The heater system of claim 409, wherein the heat output below the selected temperature is greater than about 400 watts per meter of the electrical conductor.
421. The heater system of claim 409, wherein at least one portion of the electrical conductor is configured to comprise a relatively flat AC resistance profile in a temperature range between about 100 °C and 750 °C.
422. The heater system of claim 409, wherein at least a portion of the electrical conductor is longer than about m.
423. The heater system of claim 409, wherein the heater system is configured to sharply reduce the heat output at or near the selected temperature.
424. The heater system of claim 409, wherein the heater system is configured such that the heat output from at least a portion of the system decreases at or near the selected temperature due to the Curie effect.
425. The heater system of claim 409, wherein the heater system is configured such that an AC resistance of the electrical conductor increases with an increase in temperature up to the selected temperature, and wherein the system is configured such that an AC resistance of the electrical conductor decreases with an increase in temperature from above the selected temperature.
426. The heater system of claim 409, wherein the system is configured to apply AC of at least about 70 amps to the electrical conductor.
427. The heater system of claim 409, wherein at least one of the electrical conductors comprises a turndown ratio of at least about 2 to 1.
428. The heater system of claim 409, wherein the system is configured to apply AC at about 180 Hz.
429. The heater system of claim 409, wherein the heater system is configured to withstand operating temperatures of about 250 °C or above.
430. The heater system of claim 409, wherein the heater system withstands operating temperatures of about 250 °C or above.
431. The heater system of claim 409, wherein the electrical conductor is configured to automatically provide the reduced amount of heat above or near the selected temperature.
432. A method of heating, comprising:
providing an AC at a voltage above about 200 volts to one or more electrical conductors to provide an electrically resistive heat output, wherein at least one of the electrical conductors comprises one or more electrically resistive sections; and wherein at least one of the electrically resistive sections comprises an electrically resistive ferromagnetic material and provides a reduced amount of heat above or near a selected temperature, and wherein the selected temperature is within about 50 °C of the Curie temperature of the ferromagnetic material.
433. The method of claim 432, further comprising providing the AC at a voltage above about 650 volts.
434. The method of claim 432, further comprising providing the AC to at least one of the electrical conductors at or above the selected temperature.
435. The method of claim 432, further comprising providing the AC at a frequency of about 180 Hz.
436. The method of claim 432, further comprising placing one or more of the electrical conductors in a wellbore in a subsurface formation.
437. The method of claim 432, further comprising providing an initial electrically resistive heat output when the electrical conductor providing the heat output is at least about 50 °C
below the selected temperature, and automatically providing the reduced amount of heat above or near the selected temperature.
438. The method of claim 432, further comprising allowing heat to transfer from at least one of the electrically resistive sections to at least a part of a subsurface formation.
439. The method of claim 432, further comprising providing a relatively constant heat output when the ferromagnetic material is in a temperature range between about 300 °C
and about 600 °C.
440. The method of claim 432, further comprising providing a relatively constant heat output when the ferromagnetic material is in a temperature range between about 100 °C
and about 750 °C.
441. The method of claim 432, wherein an AC resistance of at least one of the electrically resistive sections decreases above the selected temperature to provide the reduced amount of heat.
442. The method of claim 432, wherein the electrically resistive ferromagnetic material has a thickness of at least about 3/4 of a skin depth of AC at the Curie temperature of the ferromagnetic material.
443. The method of claim 432, further comprising allowing heat to transfer from at least one of the electrically resistive sections to at least a part of a subsurface formation, wherein the subsurface formation comprises a hydrocarbon containing formation.
444. The method of claim 432, further comprising allowing heat to transfer from at least one of the electrically resistive sections to at least a part of a hydrocarbon containing formation, and further comprising at least some hydrocarbons in the formation.
445. The method of claim 432, wherein the reduced amount of heat is less than about 400 watts per meter of length of an electrical conductor.
446. The method of claim 432, further comprising controlling a skin depth in at least one of the electrically resistive sections by controlling a frequency of the applied AC.
447. The method of claim 432, further comprising applying additional current to at least one of the electrically resistive sections as the temperature of such electrically resistive sections increases until the temperature is at or near the selected temperature.
448. The method of claim 432, wherein an amount of heat output provided from at least one of the electrically resistive sections is determined by an amount of current applied to at least one of the electrical conductors.
449. The method of claim 432, further comprising controlling an amount of heat provided by at least one of the electrically resistive sections by controlling an amount of current applied to at least one of the electrical conductors.
450. The method of claim 432, further comprising applying current of at least about 70 amps to at least one of the electrical conductors.
451. The method of claim 432, further comprising applying current of at least about 100 amps to at least one of the electrical conductors.
452. A heater system, comprising:
an AC supply configured to provide AC at a voltage above about 200 volts;
an electrical conductor coupled to the AC supply, and wherein the electrical conductor comprises one or more electrically resistive sections, wherein at least one of the electrically resistive sections comprises an electrically resistive ferromagnetic material, wherein the electrical conductor is configured to provide an electrically resistive heat output during application of the AC to the electrical conductor, and wherein the electrical conductor is configured to provide a reduced amount of heat above or near a selected temperature that is about 20% or less of the heat output at about 50°C below the selected temperature during use;
and wherein the selected temperature is at or about the Curie temperature of the ferromagnetic material.
453. The heater system of claim 452, wherein the AC supply is configured to provide AC at a voltage above about 650 volts.
454. The heater system of claim 452, wherein the AC supply is configured to provide AC at a voltage above about 1000 volts.
455. The heater system of claim 452, wherein the heater system is configured to provide heat to a subsurface formation.
456. The heater system of claim 452, wherein the heater system is configured to provide heat to a hydrocarbon containing formation.
457. The heater system of claim 452, wherein the heater system is configured to provide heat to a hydrocarbon containing formation, and wherein the system is configured to pyrolyze at least some hydrocarbons in the formation.
458. The heater system of claim 452, wherein the ferromagnetic material comprises iron, nickel, chromium, cobalt, tungsten, or a mixture thereof.
459. The heater system of claim 452, wherein the heat output below the selected temperature is greater than about 400 watts per meter of length of the electrical conductor.
460. The heater system of claim 452, wherein at least one portion of the electrical conductor is configured to comprise a relatively flat AC resistance profile in a temperature range between about 100°C and 750°C.
461. The heater system of claim 452, wherein the heater system is configured to sharply reduce the heat output at or near the selected temperature.
462. The heater system of claim 452, wherein the system is configured to apply AC of at least about 70 amps to the electrical conductor.
463. The heater system of claim 452, wherein at least one of the electrical conductors comprises a turndown ratio of at least about 2 to 1.
464. The heater system of claim 452, wherein the system is configured to apply AC at about 180 Hz.
465. The heater system of claim 452, wherein the electrical conductor is configured to automatically provide the reduced amount of heat above or near the selected temperature.
466. A heater system, comprising:
an AC supply configured to provide AC at a frequency between about 100 Hz and about 1000 Hz;
an electrical conductor electrically coupled to the AC supply, wherein the electrical conductor comprises at least one electrically resistive section configured to provide an electrically resistive heat output during application of the AC to the electrically resistive section during use; and wherein the electrical conductor comprises an electrically resistive ferromagnetic material and is configured to provide a reduced amount of heat above or near a selected temperature, and wherein the selected temperature is within about 50°C of the Curie temperature of the ferromagnetic material.
467. The heater system of claim 466, wherein the AC supply is coupled to a supply of line current, and wherein the AC supply is configured to provide AC at about three times the frequency of the line current.
468. The heater system of claim 466, wherein the AC supply is configured to provide AC with a frequency between about 140 Hz and about 200 Hz.
469. The heater system of claim 466, wherein AC supply is configured to provide AC with a frequency between about 400 Hz and about 550 Hz.
470. The heater system of claim 466, wherein the heater system is configured to provide heat to a subsurface formation.
471. The heater system of claim 466, wherein the heater system is configured to provide heat to a hydrocarbon containing formation, and wherein the heater system is configured to pyrolyze at least some hydrocarbons in the formation.
472. The heater system of claim 466, wherein the heater system is configured to provide heat to contaminated soil, and wherein the heater system is configured to decontaminate at least a portion of the contaminated soil.
473. The heater system of claim 466, wherein the heater system is configured to provide heat to at least a portion of an opening in a subsurface formation.
474. The heater system of claim 466, wherein the ferromagnetic material comprises iron, nickel, chromium, cobalt, tungsten, or a mixture thereof.
475. The heater system of claim 466, wherein a thickness of the ferromagnetic material is at least about 3/4 of a skin depth of the AC at the Curie temperature of the ferromagnetic material.
476. The heater system of claim 466, wherein the heat output below the selected temperature is greater than about 400 watts per meter of the electrical conductor.
477. The heater system of claim 466, wherein at least a portion of at least one of the electrical conductors is configured to comprise a relatively flat AC resistance profile in a temperature range between about 100°C and 750 °C.
478. The heater system of claim 466, wherein at least a portion of at least one of the electrical conductors is longer than about 10 m.
479. The heater system of claim 466, wherein the heater system is configured to sharply reduce the heat output at or near the selected temperature.
480. The heater system of claim 466, wherein the heater system is configured such that the heat output of at least a portion of the system decreases at or near the selected temperature due to the Curie effect.
481. The heater system of claim 466, wherein the system is configured to apply AC of at least about 70 amps to at least one of the electrically resistive sections.
482. The heater system of claim 466, wherein at least one of the electrically resistive sections comprises a turndown ratio of at least about 2 to 1.
483. The heater system of claim 466, wherein the heater system is configured to withstand operating temperatures of about 250°C or above.
484. The heater system of claim 466, wherein the electrical conductor is configured to automatically provide the reduced amount of heat above or near the selected temperature.
485. A method of heating, comprising:
providing AC at a frequency between about 100 Hz and about 1000 Hz to an electrical conductor to provide an electrically resistive heat output, wherein the electrical conductor comprises at least one electrically resistive section; and wherein at least one of the electrically resistive sections comprises an electrically resistive ferromagnetic material and provides a reduced amount of heat above or near a selected temperature, and wherein the selected temperature is within about 50°C of the Curie temperature of the ferromagnetic material.
486. The method of claim 485, further comprising providing the AC to the electrical conductor when the electrical conductor is at or above the selected temperature.
487. The method of claim 485, further comprising placing the electrical conductor in a wellbore in a subsurface formation.
488. The method of claim 485, further comprising providing an initial electrically resistive heat output when the electrical conductor providing the heat output is at least about 50°C
below the selected temperature, and automatically providing the reduced amount of heat above or near the selected temperature.
489. The method of claim 485, further comprising providing the AC at about three times the frequency of line current from an AC supply.
490. The method of claim 485, further comprising providing the AC at a frequency between about 140 Hz and about 200 Hz.
491. The method of claim 485, further comprising providing the AC at a frequency between about 400 Hz and about 550 Hz.
492. The method of claim 485, further comprising providing the AC to the electrical conductor when the electrical conductor is at or above the selected temperature.
493. The method of claim 485, further comprising allowing heat to transfer from at least one of the electrically resistive sections to at least a part of a subsurface formation.
494. The method of claim 485, further comprising providing a relatively constant heat output when the ferromagnetic material is in a temperature range between about 100°C
and 750°C.
495. The method of claim 485, wherein an AC resistance of the electrical conductor decreases above the selected temperature to provide the reduced amount of heat.
496. The method of claim 485, wherein a thickness of the ferromagnetic material is at least about 3/4 of a skin depth of the AC at the Curie temperature of the ferromagnetic material.
497. The method of claim 485, further comprising allowing heat to transfer from the electrical conductor to at least a part of a subsurface formation, wherein the subsurface formation comprises a hydrocarbon containing formation.
498. The method of claim 485, further comprising allowing heat to transfer from the electrical conductor to at least a part of a hydrocarbon containing formation, and pyrolyzing at least some hydrocarbons in the formation.
499. The method of claim 485, further comprising providing a reduced amount of heat above or near the selected temperature of less than about 400 watts per meter of length of the electrical conductor.
500. The method of claim 485, further comprising controlling a skin depth in the electrical conductor by controlling a frequency of the AC applied to the electrical conductor.
501. The method of claim 485, further comprising controlling the heat applied from the electrical conductor by allowing less heat to be applied from any part of the electrical conductor that is at or near the selected temperature.
502. The method of claim 485, further comprising controlling the amount of current applied to the electrical conductor to control an amount of heat provided by at least one of the electrically resistive sections.
503. The method of claim 485, further comprising applying current of at least about 70 amps to the electrical conductor.
504. A heater system, comprising:
an AC supply configured to provide AC at a frequency between about 100 Hz and about 1000 Hz;
an electrical conductor electrically coupled to the AC supply, wherein the electrical conductor comprises at least one electrically resistive section configured to provide an electrically resistive heat output during application of the AC from the AC supply to the electrically resistive section during use;
and wherein the electrical conductor comprises an electrically resistive ferromagnetic material and is configured to provide a reduced amount of heat above or near a selected temperature that is about 20% or less of the heat output at about 50°C below the selected temperature, and wherein the selected temperature is at or about the Curie temperature of the ferromagnetic material.
505. The heater system of claim 504, wherein the AC supply is coupled to a supply of line current, and wherein the AC supply is configured to provide AC at about three times the frequency of the line current.
506. The heater system of claim 504, wherein the frequency is between about 140 Hz and about 200 Hz.
507. The heater system of claim 504, wherein the frequency is between about 400 Hz and about 550 Hz.
508. The heater system of claim 504, wherein the heater system is configured to provide heat to a subsurface formation.
509. The heater system of claim 504, wherein the heater system is configured to provide heat to a hydrocarbon containing formation, and wherein the heater system is configured to pyrolyze at least some hydrocarbons in the formation.
510. The heater system of claim 504, wherein the heater system is configured to provide heat to at least a portion of an opening in a subsurface formation.
511. The heater system of claim 504, wherein the ferromagnetic material comprises iron, nickel, chromium, cobalt, tungsten, or a mixture thereof.
512. The heater system of claim 504, wherein a thickness of the ferromagnetic material is at least about 3/4 of a skin depth of the AC at the Curie temperature of the ferromagnetic material.
513. The heater system of claim 504, wherein the heat output below the selected temperature is greater than about 400 watts per meter of length of the electrical conductor.
514. The heater system of claim 504, wherein at least a portion of at least one of the electrical conductors is configured to comprise a relatively flat AC resistance profile in a temperature range between about 100°C and 750 °C.
515. The heater system of claim 504, wherein the heater system is configured to sharply reduce the heat output at or near the selected temperature.
516. The heater system of claim 504, wherein the system is configured to apply AC of at least about 70 amps to at least one of the electrically resistive sections.
517. The heater system of claim 504, wherein at least one of the electrically resistive sections comprises a turndown ratio of at least about 2 to 1.
518. The heater system of claim 504, wherein the electrical conductor is configured to automatically provide the reduced amount of heat above or near the selected temperature.
519. A heater, comprising:
an electrical conductor configured to generate an electrically resistive heat output during application of AC
to the electrical conductor, wherein the electrical conductor comprises an electrically resistive ferromagnetic material at least partially surrounding a non-ferromagnetic material such that the heater provides a reduced amount of heat above or near a selected temperature;
an electrical insulator at least partially surrounding the electrical conductor; and a sheath at least partially surrounding the electrical insulator.
520. The heater of claim 519, wherein the electrical conductor comprises coextruded ferromagnetic material and non-ferromagnetic material.
521. The heater of claim 519, wherein the electrical insulator comprises a pre-formed electrical insulator.
522. The heater of claim 519, wherein the sheath comprises electrically conductive material.
523. The heater of claim 519, wherein the sheath comprises two or more electrically conductive strips that are longitudinally welded together.
524. The heater of claim 519, wherein the heater comprises one or more portions coupled together, wherein each portion comprises at least a section of the electrical conductor.
525. The heater of claim 519, wherein the heater comprises one or more portions coupled together, wherein each portion comprises at least one section of the electrical conductor, and wherein at least one section of the electrical conductor has been coupled to at least another section of the electrical conductor using a weld.
526. The heater of claim 525, wherein the weld comprises non-ferromagnetic welding material.
527. The heater of claim 519, wherein the heater is configured to allow heat to transfer from the heater to a part of a subsurface formation to pyrolyze at least some hydrocarbons in the subsurface formation.
528. The heater of claim 519, wherein the heater is configured to be placed in an opening in a subsurface formation.
529. The heater of claim 519, wherein heater is configured such that a resistance of the ferromagnetic material decreases above the selected temperature such that the heater provides the reduced amount of heat above the selected temperature.
530. The heater of claim 519, further comprising a second ferromagnetic material coupled to the ferromagnetic material.
531. The heater of claim 519, wherein the heater is configured such that the selected temperature is approximately the Curie temperature of the ferromagnetic material.
532. The heater of claim 519, wherein the ferromagnetic material comprises iron.
533. The heater of claim 519, wherein the reduced amount of heat is less than about 400 watts per meter of length of the heater.
534. The heater of claim 519, wherein the heat output is greater than about 400 watts per meter of length of the heater at about 50 °C below the selected temperature.
535. The heater of claim 519, wherein the heater comprises a relatively flat AC resistance profile in a temperature range between about 100 °C and 750 °C.
536. The heater of claim 519, wherein the heater is an elongated rod, and wherein at least a portion of the elongated rod is longer than about 10 m.
537. The heater of claim 519, wherein the ferromagnetic material comprises a turndown ratio of at least about 2 to 1.
538. The heater of claim 519, wherein the non-ferromagnetic material comprises copper.
539. The heater of claim 519, wherein the electrical conductor, the electrical insulator, and the sheath are portions of an insulated conductor heater.
540. The heater of claim 519, wherein the electrical insulator comprises magnesium oxide.
541. The heater of claim 519, wherein the sheath comprises steel.
542. The heater of claim 519, wherein the sheath comprises copper and steel.
543. The heater of claim 519, wherein the ferromagnetic material is configured to automatically provide the reduced amount of heat above or near the selected temperature that is about 20% or less of the heat output at about 50 °C below the selected temperature.
544. A method of heating a subsurface formation, comprising:
providing AC to an electrical conductor to provide an electrically resistive heat output, wherein the electrical conductor comprises an electrically resistive ferromagnetic material at least partially surrounding a non-ferromagnetic material such that the electrical conductor provides a reduced amount of heat above or near a selected temperature, wherein an electrical insulator at least partially surrounds the electrical conductor, and wherein a sheath at least partially surrounds the electrical insulator; and allowing heat to transfer from the electrical conductor to at least part of the subsurface formation.
545. The method of claim 544, further comprising providing the AC to the electrical conductor when the electrical conductor is at or above the selected temperature.
546. The method of claim 544, further comprising placing the electrical conductor in a wellbore in the subsurface formation.
547. The method of claim 544, further comprising providing an initial electrically resistive heat output when the electrical conductor providing the heat output is at least about 50 °C
below the selected temperature, and automatically providing the reduced amount of heat above or near the selected temperature.
548. The method of claim 544, further comprising providing the AC at a frequency between about 100 Hz and about 1000 Hz.
549. The method of claim 544, further comprising providing a relatively constant heat output when the ferromagnetic material is in a temperature range between about 100 °C
and 750 °C.
550. The method of claim 544, wherein an AC resistance of the electrical conductor decreases above the selected temperature to provide the reduced amount of heat.
551. The method of claim 544, wherein a thickness of the ferromagnetic material is at least about 3/4 of a skin depth of the AC at the Curie temperature of the ferromagnetic material.
552. The method of claim 544, wherein the subsurface formation comprises a hydrocarbon containing formation.
553. The method of claim 544, further comprising allowing heat to transfer from the electrical conductor to at least a part of a hydrocarbon containing formation, and pyrolyzing at least some hydrocarbons in the formation.
554. The method of claim 544, further comprising providing a reduced amount of heat above or near the selected temperature of less than about 400 watts per meter of length of the electrical conductor.
555. The method of claim 544, further comprising controlling a skin depth in the electrical conductor by controlling a frequency of the AC applied to the electrical conductor.
556. The method of claim 544, further comprising controlling the heat applied from the electrical conductor by allowing less heat to be applied from any part of the electrical conductor that is at or near the selected temperature.
557. The method of claim 544, further comprising controlling the amount of current applied to the electrical conductor to control an amount of heat provided by at least one of the electrically resistive sections.
558. The method of claim 544, further comprising applying current of at least about 70 amps to the electrical conductor.
559. A heater, comprising:
an electrical conductor configured to generate an electrically resistive heat output during application of AC
to the electrical conductor, wherein the electrical conductor comprises an electrically resistive ferromagnetic alloy at least partially surrounding a non-ferromagnetic material such that the heater provides a reduced amount of heat above or near a selected temperature, and wherein the ferromagnetic alloy comprises nickel;
an electrical insulator at least partially surrounding the electrical conductor; and a sheath at least partially surrounding the electrical insulator.
560. The heater of claim 559, wherein the electrical insulator comprises a pre-formed electrical insulator.
561. The heater of claim 559, wherein the sheath comprises electrically conductive material.
562. The heater of claim 559, wherein the sheath is formed of electrically conductive strips that are longitudinally welded together.
563. The heater of claim 559, wherein the heater comprises one or more portions coupled together, wherein each portion comprises at least a section of the electrical conductor.
564. The heater of claim 559, wherein the heater comprises one or more portions coupled together, wherein each portion comprises at least one section of the electrical conductor, and wherein at least one section of the electrical conductor has been coupled to at least another section of the electrical conductor using a weld.
565. The heater of claim 564, wherein the weld comprises non-ferromagnetic welding material.
566. The heater of claim 559, wherein the ferromagnetic alloy comprises at least about 25 % by weight nickel.
567. The heater of claim 559, wherein the ferromagnetic alloy comprises less than about 45 % by weight nickel.
568. The heater of claim 559, wherein the ferromagnetic alloy comprises iron.
569. The heater of claim 559, wherein the ferromagnetic alloy comprises chromium.
570. The heater of claim 559, wherein the electrical insulator comprises silicone.
571. The heater of claim 559, wherein the heater is configured to allow heat to transfer from the heater to a part of a subsurface formation to mobilize at least some hydrocarbons in the subsurface formation.
572. The heater of claim 559, wherein the heater is configured to be placed in an opening in a subsurface formation.
573. The heater of claim 559, wherein a resistance of the ferromagnetic alloy decreases above the selected temperature such that the heater provides the reduced amount of heat above the selected temperature.
574. The heater of claim 559, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic alloy.
575. The heater of claim 559, wherein the reduced amount of heat is less than about 200 watts per meter of length of the heater.
576. The heater of claim 559, wherein the heat output is greater than about 300 watts per meter of length of the heater below the selected temperature.
577. The heater of claim 559, wherein the ferromagnetic alloy comprises a turndown ratio of at least about 2 to 1.
578. The heater of claim 559, wherein the non-ferromagnetic material comprises copper.
579. The heater of claim 559, wherein the electrical conductor, the electrical insulator, and the sheath are portions of an insulated conductor heater.
580. The heater of claim 559, wherein a thickness of the ferromagnetic alloy is at least about 3/4 of a skin depth of the AC at the Curie temperature of the ferromagnetic alloy.
581. The heater of claim 559, wherein the sheath comprises steel.
582. The heater of claim 559, wherein the sheath comprises copper and steel.
583. A heater, comprising:
an electrical conductor configured to generate an electrically resistive heat output during application of AC
to the electrical conductor, wherein the electrical conductor comprises an electrically resistive ferromagnetic material at least partially surrounding a non-ferromagnetic material such that the heater provides a reduced amount of heat above or near a selected temperature;
a conduit at least partially surrounding the electrical conductor; and a centralizer configured to maintain a separation distance between the electrical conductor and the conduit.
584. The heater of claim 583, wherein the electrical conductor is formed by a coextrusion process that combines the ferromagnetic material and the non-ferromagnetic material.
585. The heater of claim 583, wherein the centralizer comprises silicon nitride.
586. The heater of claim 583, wherein the conduit comprises electrically conductive material.
587. The neater of claim 583, wherein the heater comprises one or more portions coupled together, wherein each portion comprises at least one section of the electrical conductor, and wherein at least one section of the electrical conductor has been coupled to at least another section of the electrical conductor using a weld.
588. The heater of claim 583, wherein the heater is configured to allow heat to transfer from the heater to a part of a subsurface formation to pyrolyze at least some hydrocarbons in the subsurface formation.
589. The heater of claim 583, wherein the heater is configured to be placed in an opening in a subsurface formation.
590. The heater of claim 583, wherein a resistance of the ferromagnetic material decreases above the selected temperature such that the heater provides the reduced amount of heat above the selected temperature.
591. The heater of claim 583, further comprising a second ferromagnetic material coupled to the ferromagnetic material.
592. The heater of claim 583, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
593. The heater of claim 583, wherein the ferromagnetic material comprises iron.
594. The heater of claim 583, wherein the reduced amount of heat is less than about 400 watts per meter of length of the heater.
595. The heater of claim 583, wherein the heat output below the selected temperature is greater than about 400 watts per meter of length of the heater.
596. The heater of claim 583, wherein the heater comprises a relatively flat AC resistance profile in a temperature range between about 100 °C and 750 °C.
597. The heater of claim 583, wherein at least a portion of the heater is longer than about 10 m.
598. The heater of claim 583, wherein the ferromagnetic material comprises a turndown ratio of at least about 2 to 1.
599. The heater of claim 583, wherein the non-ferromagnetic material comprises copper.
600. A method of heating a subsurface formation, comprising:
providing AC to an electrical conductor to provide an electrically resistive heat output, wherein the electrical conductor comprises an electrically resistive ferromagnetic material at least partially surrounding a non-ferromagnetic material such that the electrical conductor provides a reduced amount of heat above or near a selected temperature, wherein a conduit at least partially surrounds the electrical conductor, and wherein a centralizes maintains a separation distance between the electrical conductor and the conduit; and allowing heat to transfer from the electrical conductor to at least part of the subsurface formation.
601. The method of claim 600, wherein the AC provided to the electrical conductor has a frequency between about 100 Hz and about 1000 Hz.
602. The method of claim 600, wherein the reduced amount of heat is provided without adjusting the amperage of the AC applied to the electrical conductor.
603. The method of claim 600, further comprising providing an initial electrically resistive heat output when the electrical conductor providing the heat output is at least about 50 °C
below the selected temperature, and automatically providing the reduced amount of heat above or near the selected temperature.
604. The method of claim 600, further comprising placing the electrical conductor in a wellbore in the subsurface formation.
605. The method of claim 600, wherein heat output from the electrical conductor is substantially constant when a temperature of the electrical conductor is between about 100 °C and 750 °C.
606. The method of claim 600, wherein an AC resistance of the electrical conductor decreases above the selected temperature to provide the reduced amount of heat.
607. The method of claim 600, wherein a thickness of the ferromagnetic material is at least about 3/4 of a skin depth of the AC at the Curie temperature of the ferromagnetic material.
608. The method of claim 600, further comprising providing a reduced amount of heat above or near the selected temperature of less than about 400 watts per meter of length of the electrical conductor.
609. The method of claim 600, further comprising controlling a skin depth in the electrical conductor by controlling a frequency of the AC applied to the electrical conductor.
610. The method of claim 600, further comprising controlling the heat applied from the electrical conductor by allowing less heat to be applied from any part of the electrical conductor that is at or near the selected temperature.
611. The method of claim 600, further comprising applying current of at least about 70 amps to the electrical conductor.
612. A heater, comprising:
an electrical conductor configured to generate an electrically resistive heat output when AC is applied to the electrical conductor, wherein the electrical conductor comprises an electrically resistive ferromagnetic material at least partially surrounding a non-ferromagnetic material, and wherein the ferromagnetic material is configured to provide a reduced amount of heat above or near a selected temperature that is about 20% or less of the heat output at about 50 °C below the selected temperature;
a conduit at least partially surrounding the electrical conductor; and a centralizer configured to maintain a separation distance between the electrical conductor and the conduit.
613. The heater of claim 612, wherein the centralizes comprises silicon nitride, 614. The heater of claim 612, wherein the heater comprises one or more portions coupled together, wherein each portion comprises at least one section of the electrical conductor, and wherein at least one section of the electrical conductor has been coupled to at least another section of the electrical conductor using a weld.
615. The heater of claim 612, wherein a resistance of the ferromagnetic material decreases above the selected temperature such that the heater provides the reduced amount of heat above the selected temperature.
616. The heater of claim 612, further comprising a second ferromagnetic material coupled to the ferromagnetic material.
617. The heater of claim 612, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
618. The heater of claim 612, wherein the ferromagnetic material comprises iron.
619. The heater of claim 612, wherein the reduced amount of heat is less than about 400 watts per meter of length of the heater.
620. The heater of claim 612, wherein the heat output below the selected temperature is greater than about 400 watts per meter of length of the heater.
621. The heater of claim 612, wherein the heater comprises a relatively flat AC resistance profile in a temperature range between about 100 °C and 750 °C.
622. The heater of claim 612, wherein at least a portion of the heater is longer than about 10 m.
623. The heater of claim 612, wherein the ferromagnetic material comprises a turndown ratio of at least about 2 to 1.
624. The heater of claim 612, wherein the non-ferromagnetic material comprises copper.
625. A system configured to heat a part of a hydrocarbon containing formation, comprising:
a conduit configured to be placed in an opening in the formation, wherein the conduit is configured to allow fluids to be produced from the formation;
one or more electrical conductors configured to be placed in the opening in the formation, wherein at least one of the electrical conductors comprises a heater section, the heater section comprising an electrically resistive ferromagnetic material configured to provide an electrically resistive heat output when AC is applied to the ferromagnetic material, wherein the ferromagnetic material provides a reduced amount of heat above or near a selected temperature during use, and wherein the reduced heat output inhibits a temperature rise of the ferromagnetic material above a temperature that causes undesired degradation of hydrocarbon material adjacent to the ferromagnetic material; and wherein the system is configured to allow heat to transfer from the heater section to a part of the formation such that the heat reduces the viscosity of fluids in the formation and/or fluids at, near, and/or in the opening.
626. The system of claim 625, wherein one or more of the electrical conductors are located inside the conduit.
627. The system of claim 625, wherein one or more of the electrical conductors are located inside the conduit, and wherein such electrical conductors comprise an inner conduit configured to allow fluids to propagate through the inner conduit.
628. The system of claim 625, wherein the system is configured to allow a gas to be provided to the opening, and wherein the gas is configured to reduce the density of fluids to facilitate production of the fluids from the formation.
629. The system of claim 625, further comprising a pump configured to produce fluids from the opening.
630. The system of claim 625, wherein the system is configured to reduce the viscosity of fluids in the formation to less than about 50 centipoise.
631. The system of claim 625, wherein the system is configured such that the ferromagnetic material automatically provides a selected reduced amount of heat above or near the selected temperature.
632. The system of claim 625, wherein the system is configured such that the AC resistance of the ferromagnetic material decreases when the temperature of ferromagnetic material is near or above the selected temperature.
633. The system of claim 625, wherein at least one of the electrical conductors is configured to exhibit an increase in operating temperature of less than about 1.5 °C above or near a selected operating temperature when a thermal load proximate such electrical conductor decreases by about 1 watt per meter of the electrical conductor.
634. The system of claim 625, further comprising a highly electrically conductive material coupled to at least a portion of the ferromagnetic material of an electrical conductor, wherein AC
applied to the electrical conductor substantially flows through the ferromagnetic conductor when a temperature of the ferromagnetic conductor is below the selected temperature, and wherein the AC applied to the conductor is configured to flow through the highly electrically conductive material when the temperature of the ferromagnetic conductor is near or above the selected temperature.
635. The system of claim 625, wherein at least one of the electrical conductors is configured to provide a reduced amount of heat above or near the selected temperature that is about 20% or less of the heat output at about 50 °C below the selected temperature.
636. The system of claim 625, wherein at least one of the electrical conductors is configured such that a decreased AC resistance through such electrical conductor above or near the selected temperature is about 20% or less than the electrical resistance at about 50 °C below the selected temperature.
637. The system of claim 625, wherein an AC resistance of at least one of the electrical conductors above or near the selected temperature is about 80% or less of an AC resistance at about 50 °C below the selected temperature.
638. The system of claim 625, wherein the system is configured such that an AC
resistance of the ferromagnetic material decreases above the selected temperature to provide the reduced amount of heat.
639. The system of claim 625, further comprising a non-ferromagnetic material coupled to the ferromagnetic material, wherein the non-ferromagnetic material has a higher electrical conductivity than the ferromagnetic material.
640. The system of claim 625, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
641. The system of claim 625, wherein the selected temperature is less than about 300 °C.
642. The system of claim 625, wherein the system is configured to limit a temperature in the formation at or near the wellbore to less than about 250 °C.
643. The system of claim 625, wherein the reduced amount of heat is less than about 200 watts per meter of length of the electrical conductor.
644. The system of claim 625, wherein heat output from the ferromagnetic material is greater than about 300 watts per meter of length of the electrical conductor when the temperature of the ferromagnetic material is below the selected temperature during use.
645. The system of claim 625, wherein the ferromagnetic material has a turndown ratio of at least about 2 to 1.
646. The system of claim 625, wherein the ferromagnetic material comprises iron, nickel, chromium, or a mixture thereof.
647. The system of claim 625, wherein the system is configured such that the ferromagnetic material has a thickness of at least about 3/4 of a skin depth of AC at the Curie temperature of the ferromagnetic material.
648. The system of claim 625, wherein at least one of the electrical conductors comprises ferromagnetic material and non-ferromagnetic electrically conductive material.
649. The system of claim 625, wherein the hydrocarbon containing formation comprises a relatively permeable formation containing heavy hydrocarbons.
650. The system of claim 625, wherein the electrically resistive ferromagnetic material is elongated and at least a portion of the ferromagnetic material is longer than about 10 m.
651. The system of claim 625, wherein the system is configured to sharply reduce the heat output at or near the selected temperature.
652. The system of claim 625, wherein at least one of the electrical conductors is elongated and configured such that only electrically resistive sections at or near the selected temperature will automatically reduce the heat output.
653. The system of claim 625, wherein the system is configured such that an AC
resistance of at least one of the electrical conductors increases with an increase in temperature up to the selected temperature.
654. The system of claim 625, wherein the system is configured such that an AC
resistance of at least one of the electrical conductors decreases with an increase in temperature above the selected temperature.
655. The system of claim 625, wherein the system is configured such that at least about 70 amps is applied to at least one of the electrical conductors.
656. The system of claim 625, wherein the system is configured such that a frequency of the AC is about 180 Hz.
657. The system of claim 625, wherein the system is configured such that a frequency of the AC is about 60 Hz.
658. The system of claim 625, wherein the ferromagnetic material is positioned in the opening in the formation, and wherein at least a portion of the opening in the formation adjacent to the ferromagnetic material comprises one or more openings for allowing fluids to enter the wellbore.
659. A method for treating a hydrocarbon containing formation, comprising:
applying AC to one or more electrical conductors located in an opening in the formation to provide an electrically resistive heat output, wherein at least one of the electrical conductors comprises an electrically resistive ferromagnetic material that provides heat when AC flows through the electrically resistive ferromagnetic material, and wherein the electrically resistive ferromagnetic material provides a reduced amount of heat above or near a selected temperature;
allowing the heat to transfer from the electrically resistive ferromagnetic material to a part of the formation so that a viscosity of fluids at or near the opening in the formation is reduced; and producing the fluids through the opening.
660. The method of claim 659, wherein the ferromagnetic material automatically provides the reduced amount of heat above or near the selected temperature.
661. The method of claim 659, further comprising placing the one or more electrical conductors in the opening.
662. The method of claim 659, further comprising providing an initial electrically resistive heat output when the electrical conductor providing the heat output is at least about 50 °C
below the selected temperature, and automatically providing the reduced amount of heat above or near the selected temperature.
663. The method of claim 659, wherein the viscosity of fluids at or near the opening is reduced to less than about 50 centipoise.
664. The method of claim 659, further comprising providing a gas to the opening that reduces the density of the fluids so that the fluids are pushed out of the opening to the surface of the formation by the formation pressure.
665. The method of claim 659, further comprising producing the fluids from the opening by pumping the fluids from the opening.
666. The method of claim 659, further comprising producing the fluids from the opening through the electrical conductors.
667. The method of claim 659, further comprising producing the fluids from the opening through a conduit located in the opening.
668. The method of claim 659, further comprising limiting a temperature in the formation at or near the opening to less than about 250 °C.
669. The method of claim 659, wherein the electrically resistive ferromagnetic material automatically provides a selected reduced amount of heat above or near a selected temperature.
670. The method of claim 659, wherein an AC resistance of the ferromagnetic material decreases above the selected temperature to provide the reduced amount of heat.
671. The method of claim 659, wherein a thickness of the ferromagnetic material is greater than about 3/4 of a skin depth of the AC at the Curie temperature of the ferromagnetic material.
672. The method of claim 659, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
673. The method of claim 659, wherein the selected temperature is less than about 300 °C.
674. The method of claim 659, further comprising providing a reduced amount of heat above or near the selected temperature of less than about 200 watts per meter of length of an electrical conductor.
675. The method of claim 659, further comprising providing a heat output below the selected temperature of greater than about 300 watts per meter of length of an electrical conductor.
676. The method of claim 659, further comprising controlling the amount of current applied to the electrical conductors to control the amount of heat provided by the ferromagnetic material.
677. The method of claim 659, further comprising applying an AC of at least about 70 amps to the electrical conductors.
678. The method of claim 659, further comprising providing a heat output from at least one of the electrical conductors, wherein an AC resistance of such electrical conductors above or near the selected temperature is about 80% or less of the AC resistance of such electrical conductors at about 50 °C below the selected temperature.
679. The method of claim 659, further comprising controlling a skin depth in the ferromagnetic material by controlling a frequency of the applied AC.
680. The method of claim 659, further comprising increasing the AC applied to at least one of the electrical conductors as the temperature of such electrical conductors increases, and continuing to do so until the temperature is at or near the selected temperature.
681. The method of claim 659, further comprising controlling an amount of current applied to at least one of the electrical conductors to control an amount of heat output from such electrical conductors.
682. The method of claim 659, further comprising increasing an amount of current applied to at least one of the electrical conductors to decrease an amount of heat output from such electrical conductors.
683. The method of claim 659, further comprising decreasing an amount of current applied to at least one of the electrical conductors to increase an amount of heat output from such electrical conductors.
684. The method of claim 659, wherein the hydrocarbon containing formation comprises a relatively permeable formation containing heavy hydrocarbons.
685. A method for treating a hydrocarbon containing formation, comprising:
applying AC to one or more electrical conductors located in an opening in the formation to provide an electrically resistive heat output, wherein at least one of the electrical conductors comprises an electrically resistive ferromagnetic material that provides heat when AC flows through the electrically resistive ferromagnetic material, and wherein the electrically resistive ferromagnetic material provides a reduced amount of heat above or near a selected temperature;
allowing the heat to transfer from the electrically resistive ferromagnetic material to a part of the formation to enhance radial flow of fluids from portions of the formation surrounding the opening to the opening; and producing the fluids through the opening.
686. The method of claim 685, wherein the ferromagnetic material automatically provides the reduced amount of heat above or near the selected temperature.
687. The method of claim 685, further comprising placing one or more of the electrical conductors in the opening.
688. The method of claim 685, further comprising providing an initial electrically resistive heat output when the electrical conductor providing the heat output is at least about 50°C
below the selected temperature, and automatically providing the reduced amount of heat above or near the selected temperature.
689. The method of claim 685, wherein the viscosity of fluids at or near the opening is reduced to less than about 50 centipoise.
690. The method of claim 685, further comprising producing the fluids from the opening by pumping the fluids from the opening.
691. The method of claim 685, further comprising producing the fluids from the opening through the electrical conductors.
692. The method of claim 685, further comprising producing the fluids from the opening through a conduit located in the opening.
693. The method of claim 685, further comprising limiting a temperature in the formation at or near the opening to less than about 250 °C.
694. The method of claim 685, wherein the electrically resistive ferromagnetic material automatically provides a selected reduced amount of heat above or near a selected temperature.
695. The method of claim 685, wherein an AC resistance of the ferromagnetic material decreases above the selected temperature to provide the reduced amount of heat.
696. The method of claim 685, wherein a thickness of the ferromagnetic material is greater than about 3/4 of a skin depth of AC at the Curie temperature of the ferromagnetic material.
697. The method of claim 685, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
698. The method of claim 685, wherein the selected temperature is less than about 300 °C.
699. The method of claim 685, further comprising providing a reduced amount of heat above or near the selected temperature of less than about 200 watts per meter of length of an electrical conductor.
700. The method of claim 685, further comprising providing a heat output below the selected temperature of greater than about 300 watts per meter of length of an electrical conductor.
701. The method of claim 685, further comprising controlling the amount of current applied to the electrical conductors to control the amount of heat provided by the ferromagnetic material.
702. The method of claim 685, further comprising applying an AC of at least about 70 amps to the electrical conductors.
703. The method of claim 685, further comprising providing a heat output from at least one of the electrical conductors, wherein an AC resistance of such electrical conductors above or near the selected temperature is about 80% or less of the AC resistance of such electrical conductors at about 50°C below the selected temperature.
704. The method of claim 685, further comprising controlling a skin depth in the ferromagnetic material by controlling a frequency of the applied AC.
705. The method of claim 685, further comprising increasing the amount of AC
applied to at least one of the electrical conductors as the temperature of such electrical conductors increases, and continuing to do so until the temperature is at or near the selected temperature.
706. The method of claim 685, further comprising controlling an amount of current applied to at least one of the electrical conductors to control an amount of heat output from such electrical conductors.
707. The method of claim 685, further comprising increasing an amount of current applied to at least one of the electrical conductors to decrease an amount of heat output from such electrical conductors.
708. The method of claim 685, further comprising decreasing an amount of current applied to at least one of the electrical conductors to increase an amount of heat output from such electrical conductors.
709. The method of claim 685, wherein the hydrocarbon containing formation comprises a relatively permeable formation containing heavy hydrocarbons.
710. A method for heating a hydrocarbon containing formation, comprising:
applying AC to one or more electrical conductors placed in an opening in the formation, wherein at least one of the electrical conductors comprises one or more electrically resistive sections;
providing a heat output from at least one of the electrically resistive sections, wherein such electrically resistive sections provide a reduced amount of heat above or near a selected temperature that is about 20% or less of the heat output at about 50 °C below the selected temperature;
allowing the heat to transfer from at least one of the electrically resistive sections to at least a part of the formation such that a temperature in the formation at or near the opening is maintained between about 150 °C and about 250 °C to reduce a viscosity of fluids at or near the opening in the formation; and producing the reduced viscosity fluids through the opening.
711. The method of claim 710, wherein the viscosity of fluids at or near the opening is reduced to less than about 50 centipoise.
712. The method of claim 710, further comprising placing one or more of the electrical conductors in the opening.
713. The method of claim 710, further comprising providing an initial electrically resistive heat output when the electrically resistive section providing the heat output is at least about 50 °C below the selected temperature, and automatically providing the reduced amount of heat above or near the selected temperature.
714. The method of claim 710, further comprising providing a gas to the opening that reduces the density of the reduced viscosity fluids so that the reduced viscosity fluids are pushed out of the opening to the surface of the formation by the formation pressure.
715. The method of claim 710, further comprising producing the reduced viscosity fluids from the opening by pumping the reduced viscosity fluids from the opening.
716. The method of claim 710, further comprising producing the reduced viscosity fluids from the opening through the electrical conductors.
717. The method of claim 710, further comprising producing the reduced viscosity fluids from the opening through a conduit located in the opening.
718. The method of claim 710, further comprising providing a reduced amount of heat above or near the selected temperature that is less than about 20% of the heat output at about 40 °C below the selected temperature.
719. The method of claim 710, further comprising providing a reduced amount of heat above or near the selected temperature that is less than about 20% of the heat output at about 30 °C below the selected temperature.
720. The method of claim 710, further comprising providing a reduced amount of heat above or near the selected temperature that is less than about 15% of the heat output at about 50°C below the selected temperature.
721. The method of claim 710, further comprising providing a reduced amount of heat above or near the selected temperature that is less than about 10% of the heat output at about 50°C below the selected temperature.
722. The method of claim 710, wherein at least one electrically resistive section comprises ferromagnetic material, and wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
723. The method of claim 710, wherein the selected temperature is less than about 300 °C.
724. The method of claim 710, further comprising automatically decreasing an AC resistance of at least one of the electrically resistive sections when such electrically resistive sections are above the selected temperature to provide the reduced amount of heat above the selected temperature.
725. The method of claim 710, further comprising providing a reduced amount of heat above or near the selected temperature of less than about 200 watts per meter of length of an electrical conductor.
726. The method of claim 710, further comprising applying AC of at least about 70 amps to at least one of the electrical conductors.
727. The method of claim 710, wherein the hydrocarbon containing formation comprises a relatively permeable formation containing heavy hydrocarbons.
728. The method of claim 710, wherein the electrically resistive sections are configured to automatically provide the reduced amount of heat above or near the selected temperature.
729. The method of claim 710, wherein the electrically resistive sections automatically provide a selected reduced amount of heat above or near a selected temperature.
730. A system for treating a formation in situ, comprising:
five or more oxidizers configured to be placed in an opening in the formation;
one or more conduits, wherein at least one of the conduits is configured to provide at least oxidizing fluid to the oxidizers, and wherein at least one of the conduits is configured to provide at least fuel to the oxidizers;
wherein the oxidizers are configured to allow combustion of a mixture of the fuel and the oxidizing fluid to produce heat and exhaust gas; and wherein the oxidizers and the conduit configured to provide at least the oxidizing fluid to the oxidizers are configured such that at least a portion of exhaust gas from at least one of the oxidizers is mixed with at least a portion of the oxidizing fluid provided to at least another one of the oxidizers.
731. The system of claim 730, wherein the system comprises ten or more oxidizers configured to be placed in the opening in the formation.
732. The system of claim 730, further comprising a flameless distributed combustors placed in the opening in the formation.
733. The system of claim 730, wherein at least one of the oxidizers comprises a mixing chamber, and wherein the mixing chamber comprises orifices.
734. The system of claim 730, wherein at least one of the oxidizers comprises a mixing chamber, and wherein the mixing chamber comprises at least one static mixer.
735. The system of claim 730, wherein at least one of the oxidizers comprises a constriction configured to increase a flow velocity of the mixture of the fuel and the oxidizing fluid.
736. The system of claim 730, wherein at least one of the oxidizers comprises a mixing chamber and a screen, and wherein the screen is configured such that a flow velocity of fluid through the mixing chamber exceeds a flow velocity of fluid through the screen.
737. The system of claim 730, wherein at least one of the oxidizers comprises a mixing chamber and a screen, and wherein an effective diameter of the screen exceeds an effective diameter of the mixing chamber.
738. The system of claim 730, wherein at least one of the oxidizers comprises a screen, and wherein the screen comprises openings.
739. The system of claim 730, wherein at least one of the oxidizers is positioned in the conduit configured to provide at least oxidizing fluid to the oxidizers.
740. The system of claim 730, wherein a spacing between a terminal oxidizer and the oxidizer adjacent to the terminal oxidizer exceeds a spacing between other pairs of adjacent oxidizers in the system.
741. The system of claim 730, wherein a terminal oxidizer is a catalytic oxidizer.
742. The system of claim 730, wherein a terminal oxidizer is configured to reach a higher peak temperature than the other oxidizers in the system.
743. The system of claim 730, wherein a terminal oxidizer is configured to consume more oxidizing fluid than each of the other oxidizers in the system.
744. The system of claim 730, wherein a terminal oxidizer is configured to oxidize more fuel than each of the other oxidizers in the system.
745. The system of claim 730, wherein the one or more conduits comprise a fuel conduit and an oxidizer conduit, and wherein the fuel conduit is positioned substantially concentrically in the oxidizer conduit.
746. The system of claim 730, wherein the one or more conduits comprise a fuel conduit and an oxidizer conduit, and wherein the fuel conduit and the oxidizers are positioned substantially concentrically in the oxidizer conduit.
747. The system of claim 730, wherein the one or more conduits comprise a fuel conduit and an oxidizer conduit, and wherein the fuel conduit is substantially parallel to the oxidizer conduit.
748. The system of claim 730, wherein the one or more conduits comprise a fuel conduit and an oxidizer conduit, wherein the fuel conduit is substantially parallel to the oxidizer conduit, and wherein the oxidizers are positioned between the fuel conduit and the oxidizer conduit.
749. The system of claim 730, wherein the conduit configured to provide at least the fuel to the oxidizers comprises a catalytic inner surface.
750. The system of claim 730, wherein the conduit configured to provide at least the fuel to the oxidizers is further configured such that at least a portion of exhaust gas from at least one of the oxidizers is mixed with at least a portion of the fuel provided to at least another one of the oxidizers.
751. The system of claim 730, wherein the conduit configured to provide at least the fuel to the oxidizers is further configured such that at least a portion of exhaust gas from at least one of the oxidizers is mixed with at least a portion of the fuel provided to at least another one of the oxidizers.
752. The system of claim 730, further comprising a venturi device coupled to the conduit configured to provide at least the fuel to the oxidizers, wherein the venturi device is configured to provide at least a portion of the exhaust gas from at least one of the oxidizers to the conduit configured to provide at least the fuel to the oxidizers, and wherein the venturi device is further configured to increase a velocity of the fuel flow.
753. The system of claim 730, further comprising a valve coupled to the conduit configured to provide at least the fuel to the oxidizers, wherein the valve is configured to control fuel flow to at least one of the oxidizers.
754. The system of claim 730, further comprising a valve coupled to the conduit configured to provide at least the fuel to the oxidizers, wherein the valve is configured to control fuel flow to at least one of the oxidizers, and wherein the valve is a self-regulating valve.
755. The system of claim 730, wherein one or more of the conduits are configured such that at least a portion of the exhaust gas heats at least a portion of the formation.
756. The system of claim 730, further comprising a membrane positioned in the conduit configured to provide at least oxidizing fluid to the oxidizers, wherein the membrane is configured to increase a concentration of oxygen in the oxidizing fluid.
757. The system of claim 730, further comprising a membrane positioned in the conduit configured to provide at least oxidizing fluid to the oxidizers, wherein the membrane is configured to increase a concentration of oxygen in the oxidizing fluid, and wherein the system is further configured to allow heat to transfer from the exhaust gas to the membrane to increase a concentration of oxygen in the oxidizing fluid.
758. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers.
759. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, and wherein at least one of the oxidizers comprises a catalytic surface proximate one of the ignition sources.
760. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least of the ignition sources comprises an electrical ignition source.
761. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a spark plug, and wherein a voltage of less than about 3000 V is provided to the spark plug.
762. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a spark plug, and wherein a voltage of less than about 1000 V is provided to the spark plug.
763. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a glow plug.
764. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a glow plug, and wherein a voltage of less than about 1000 V is provided to the glow plug.
765. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a glow plug, and wherein a voltage of less than about 630 V is provided to the glow plug.
766. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a glow plug, and wherein a voltage of less than about 120 V is provided to the glow plug.
767. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a glow plug, and wherein a voltage between about V and about 120 V is provided to the glow plug.
768. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a catalytic glow plug.
769. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a temperature limited heater.
770. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a cable with one or more igniter sections.
771. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a cable with one or more igniter sections, and wherein at least one of the igniter sections comprises a temperature limited heater.
772. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a ferromagnetic material.
773. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a mechanical ignition source.
774. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a mechanical ignition source, and wherein the mechanical ignition source is configured to be driven by a fluid.
775. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a mechanical ignition source, and wherein the mechanical ignition source includes a flint stone.
776. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises an electrical generator.
777. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises an electrical generator, and wherein the electrical generator is configured to be driven by a fluid.
778. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a pilot light.
779. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a fireball.
780. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a flame front.
781. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a fireflood.
782. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises catalytic material.
783. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a pyrophoric fluid provided proximate such oxidizers.
784. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a pellet launching system, one or more explosive pellets, and one or more points of ignition.
785. A method of treating a formation in situ, comprising:
providing fuel to a series of oxidizers positioned in an opening in the formation;
providing oxidizing fluid to the series of oxidizers positioned in the opening in the formation;
mixing at least a portion of the fuel with at least a portion of the oxidizing fluid to form a fuel/oxidizing fluid mixture;
igniting the fuel/oxidizing fluid mixture at or near the oxidizers;
allowing the fuel/oxidizing fluid mixture to react in the oxidizers to produce heat and exhaust gas;
mixing at least a portion of the exhaust gas from one or more of the oxidizers with the oxidizing fluid provided to another one or more of the oxidizers; and allowing heat to transfer from the exhaust gas to a portion of the formation.
786. The method of claim 785, further comprising establishing a pyrolysis zone in at least a portion of the formation.
787. The method of claim 785, further comprising mixing at least a portion of the exhaust gas with at least a portion of the fuel provided to at least one of the oxidizers.
788. The method of claim 785, further comprising introducing at least a portion of the exhaust gas into a flow of at least a portion of the oxidizing fluid to increase a flow velocity of the oxidizing fluid.
789. The method of claim 785, further comprising enriching the oxidizing fluid to increase an oxygen content of the oxidizing fluid.
790. The method of claim 785, further comprising controlling a flow rate of fuel to at least one of the oxidizers.
791. The method of claim 785, further comprising controlling a flow rate of oxidizing fluid to at least one of the oxidizers.
792. The method of claim 785, further comprising providing steam to the fuel to inhibit coking.
793. A system for treating a formation in situ, comprising:
one or more heater assemblies positionable in an opening in the formation, wherein each heater assembly comprises one or more heaters, and wherein the heaters are configured to transfer heat to the formation to establish a pyrolysis zone in the formation;
an optical sensor array positionable along a length of at least one of the heater assemblies, wherein the optical sensor array is configured to transmit one or more signals; and one or more instruments configured to receive at least one of the signals transmitted by the optical sensor array.
794. The system of claim 793, wherein the optical sensor array is configured to operate when a temperature in the opening is up to about 700°C.
795. The system of claim 793, wherein at least one heater assembly comprises an oxidizer positioned in the opening in the formation, and further comprising one or more ignition sources configured to ignite at least one of the oxidizers, and wherein at least one of the instruments is configured to monitor at least one of the oxidizers to determine if such oxidizers are ignited.
796. The system of claim 793, wherein the oxidizers are configured such that heat from at least one of the ignited oxidizers ignites at least one of the oxidizers that is not ignited.
797. The system of claim 793, further comprising a control system in communication with one of the instruments and at least one of the ignition sources, wherein the control system is configured to activate one of the ignition sources to ignite at least one of the oxidizers based on the communication from the instrument.
798. The system of claim 793, further comprising a sleeve positionable adjacent one of the heater assemblies, wherein the optical sensor array is at least partially positionable in the sleeve.
799. The system of claim 793, wherein the optical sensor array comprises a high temperature resistant material.
800. The system of claim 793, wherein the optical sensor array comprises gold.
801. The system of claim 793, wherein the optical sensor array is a high temperature rated optical fiber.
802. The system of claim 793, wherein the optical sensor array is a high temperature rated fiber optic cable.
803. The system of claim 793, wherein at least one of the instruments is configured to analyze a Raman backscattering component of at least one of the signals.
804. The system of claim 793, wherein at least one of the instruments is configured to analyze a Brillouin backscattering component of at least one of the signals.
805. The system of claim 793, wherein at least one of the instruments is configured to analyze a Brillouin backscattering component of at least one of the signals and a Raman backscattering component of at least one of the signals.
806. The system of claim 793, wherein at least one of the instruments is configured to analyze a Rayleigh component of at least one of the signals.
807. The system of claim 793, further comprising a laser configured such that output from the laser is transmitted through the optical sensor array to produce a signal.
808. The system of claim 793, wherein at least one of the instruments is configured to provide a profile of pressure adjacent to at least one of the heater assemblies.
809. The system of claim 793 wherein at least one of the instruments is configured to provide a profile of temperature adjacent to at least one of the heater assemblies.
810. The system of claim 793, wherein at least one of the signals from at least one of the units indicates a temperature and a position of at least one heater in at least one of the heater assemblies.
811. The system of claim 793, wherein at least one of the signals from at least one of the units indicates temperature and strain at one or more locations along at least one of the heater assemblies.
812. The system of claim 793, wherein at least one of the signals from at least one of the units indicates temperature and pressure at one or more locations along at least one of the heater assemblies.
813. The system of claim 793, wherein at least one of the signals from at least one of the units indicates a gas composition at one or more locations along at least one of the heater assemblies.
814. The system of claim 793, further comprising a control system in communication with one of the instruments, wherein the control system is configured to control one or more operating parameters of at least one of the heater assemblies based on communication from at least one of the instruments.
815. A method of monitoring an environment in an opening in a formation, comprising:
providing heat from a heater assembly in the opening of the formation;
repetitively monitoring one or more parameters at two or more locations along a length of the heater assembly with a sensor array;
analyzing at least one of the parameters to assess conditions in the opening of the formation; and using information from the analysis of at least one of the parameters to alter conditions in the opening of the formation, 816. The method of claim 815, wherein repetitively monitoring the one or more parameters comprises continuously monitoring the one or more parameters.
817. The method of claim 815, wherein the optical sensor array is used when a temperature in the opening is up to about 700 °C.
818. The method of claim 815, further comprising monitoring temperature.
819. The method of claim 815, further comprising monitoring pressure.
820. The method of claim 815, further comprising monitoring strain.
821. The method of claim 815, further comprising monitoring gas composition.
822. The method of claim 815, further comprising monitoring temperature and strain.
823. The method of claim 815, further comprising monitoring temperature and pressure.
824. A method for forming a wellbore in a hydrocarbon containing formation, comprising:
forming a first opening of the wellbore beginning at the earth's surface and ending underground;
forming a second opening of the wellbore beginning at the earth's surface and ending underground proximate the first opening; and coupling the openings underground using an expandable conduit.
825. The method of claim 824, further comprising aligning the first opening and the second opening underground using magnetic tracking of a magnet source in the first opening.
826. The method of claim 824, wherein at least a portion of the wellbore is formed substantially horizontally in a hydrocarbon layer of the formation.
827. The method of claim 824, wherein the openings begin substantially in an overburden of the formation.
828. The method of claim 824, wherein the openings begin substantially in an overburden of the formation, and placing reinforcing material in the overburden portions of the openings.
829. The method of claim 824, further comprising forming the first opening by drilling from the earth's surface with machinery located proximate the location of the first opening.
830. The method of claim 824, further comprising coupling the first and second openings by placing an expandable conduit partially in the first opening, partially in the second opening, and in a space between the first and second openings, and then expanding the expandable conduit.
831. The method of claim 824, further comprising forming the second opening by drilling from the earth's surface with machinery located proximate the location of the second opening.
832. The method of claim 824, further comprising placing a casing in the first opening.
833. The method of claim 824, further comprising sealing the expandable conduit to the first opening and the second opening.
834. The method of claim 824, further comprising placing one or more heaters in the wellbore or coupling one or more heaters to the wellbore, wherein at least one of the heaters is configured to provide or transfer heat to at least part of the formation to pyrolyze at least some hydrocarbons in the formation.
835. The method of claim 834, wherein at least one of the heaters comprises one or more oxidizers located in the wellbore.
836. The method of claim 834, wherein at least one of the heaters comprises one or more oxidizers located on the earth's surface, wherein at least one of the oxidizers is coupled to the wellbore.
837. The method of claim 824, further comprising forming a second wellbore in the formation using, at least in part, a magnetic field produced in the wellbore, wherein the second wellbore begins and ends at different locations on the earth's surface.
838. The method of claim 824, further comprising forming at least part of the first opening at an angle with respect to the earth's surface, wherein the angle is between about 25°
and about 90°.
839. The method of claim 824, further comprising forming at least part of the second opening at an angle with respect to the earth's surface, wherein the angle is between about 25°
and about 90°.
840. A system configured to heat at least a part of a subsurface formation, comprising:
one or more electrical conductors configured to be placed in an opening in the formation, wherein at least one electrical conductor comprises at least one electrically resistive portion configured to provide a heat output when alternating current is applied through such electrically resistive portion, and wherein at least one of such electrically resistive portions comprises one or more ferromagnetic materials, and is configured, when above or near a selected temperature and when alternating current is applied, to inherently provide a reduced heat output; and wherein the system is configured to allow heat to transfer from at least one of the electrically resistive portions to at least a part of the subsurface formation.
841. The system of claim 840, wherein at least one electrical conductor is configured to propagate electrical current out of the opening.
842. The system of claim 840, wherein at least one electrical conductor is configured to propagate electrical current into the opening.
843. The system of claim 840, wherein the subsurface formation comprises a hydrocarbon containing formation.
844. The system of claim 840, wherein the subsurface formation comprises a hydrocarbon containing formation, and wherein the system is configured to pyrolyze at least some hydrocarbons in the formation.
845. The system of claim 840, wherein the subsurface formation comprises contaminated soil.
846. The system of claim 840, wherein the subsurface formation comprises contaminated soil, and wherein the system is configured to remediate at least a portion of the contaminated soil.
847. The system of claim 840, wherein the system is configured to provide heat to at least a portion of the opening in the formation.
848. The system of claim 840, further comprising a deformation resistant container, wherein at least a portion of the system is located in the deformation resistant container, and wherein the selected temperature is selected such that the deformation resistant container has a creep-rupture strength of at least about 3000 psi at 100,000 hours at the selected temperature.
849. The system of claim 848, wherein the deformation resistant container comprises an alloy, and the alloy comprises iron, chromium, nickel, manganese, carbon, and tantalum.
850. The system of claim 840, wherein three or more electrical conductors are configured to be coupled in a three-phase electrical configuration.
851. The system of claim 840, wherein at least one electrical conductor comprises an inner conductor and at least one electrical conductor comprises an outer conductor.
852. The system of claim 840, further comprising an electrically insulating material placed between at least two electrical conductors.
853. The system of claim 852, wherein the electrically insulating material comprises ceramic.
854. The system of claim 840, further comprising an electrically insulating material, comprising a packed powder, placed between at least two electrical conductors.
855. The system of claim 840, further comprising a flexible electrically insulating material placed between at least two electrical conductors.
856. The system of claim 840, wherein at least one electrically resistive portion comprises an AC resistance that decreases at, near, or above the selected temperature such that the at least one electrically resistive portion provides the reduced heat output above the selected temperature.
857. The system of claim 840, wherein at least one ferromagnetic material comprises iron, nickel, chromium, cobalt, tungsten, or mixtures thereof.
858. The system of claim 840, wherein at least one ferromagnetic material has a thickness that is at least about 3/4 of a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
859. The system of claim 840, wherein at least one ferromagnetic material has a thickness that is at least about 3/4 of a skin depth of the alternating current at the Curie temperature of the ferromagnetic material, and wherein the ferromagnetic material is coupled to a more conductive material such that, at the Curie temperature of the ferromagnetic material, the electrically resistive portion has a higher conductivity than the electrically resistive portion would if the ferromagnetic material were used, in the same or greater thickness, without the more conductive material.
860. The system of claim 840, wherein at least one electrically resistive portion comprises a first ferromagnetic material with a first Curie temperature, and a second ferromagnetic material with a second Curie temperature.
861. The system of claim 840, wherein at least one ferromagnetic material has a thickness that is at least about a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
862. The system of claim 840, wherein at least one ferromagnetic material has a thickness at least about 1.5 times greater than a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
863. The system of claim 840, wherein at least one ferromagnetic material is coupled to a higher conductivity material.
864. The system of claim 840, wherein at least one ferromagnetic material is coupled to a higher conductivity non-ferromagnetic material.
865. The system of claim 840, wherein the selected temperature is approximately the Curie temperature of at least one ferromagnetic material.
866. The system of claim 840, wherein at least one electrically resistive portion comprises ferromagnetic material and non-ferromagnetic electrically conductive material.
867. The system of claim 840, wherein the subsurface formation comprises a hydrocarbon containing formation, and wherein at least one electrically resistive portion is located proximate a relatively rich zone of the formation.
868. The system of claim 840, wherein at least one electrically resistive portion is located proximate a hot spot of the formation.
869. The system of claim 840, wherein at least one electrically resistive portion comprises carbon steel.
870. The system of claim 840, wherein at least one electrically resistive portion comprises iron.
871. The system of claim 840, wherein at least one ferromagnetic material is coupled to a corrosion resistant material.
872. The system of claim 840, further comprising a corrosion resistant material coated on at least one ferromagnetic material.
873. The system of claim 840, wherein the electrically resistive portion comprises one or more bends.
874. The system of claim 840, wherein the electrically resistive portion comprises a helically shaped portion.
875. The system of claim 840, wherein the electrically resistive portion is part of an insulated conductor heater.
876. The system of claim 840, wherein the electrically resistive portion comprises a thickness of ferromagnetic material, and such ferromagnetic material is coupled to a thickness of a more conductive material, and wherein the thickness of the ferromagnetic material and the thickness of the more conductive material have been selected such that the electrically resistive portion provides a selected resistance profile as a function of temperature.
877. The system of claim 840, wherein the electrically resistive portion comprises a thickness of a ferromagnetic material, and such ferromagnetic material comprises iron, nickel, chromium, cobalt, or mixtures thereof, and such ferromagnetic material is coupled to a thickness of a more conductive material, and wherein the thickness of the ferromagnetic material and the thickness of the more conductive material have been selected such that the electrically resistive portion provides a selected resistance profile as a function of temperature.
878. The system of claim 840, wherein the electrically resistive portion comprises a thickness of a ferromagnetic material, and such ferromagnetic material comprises a first Curie temperature material and a second Curie temperature material, and such ferromagnetic material is coupled to a thickness of a more conductive material, and wherein the thickness of the ferromagnetic material and the thickness of the more conductive material have been selected such that the electrically resistive portion provides a selected resistance profile as a function of temperature.
879. The system of claim 840, wherein the electrically resistive portion comprises a thickness of a ferromagnetic material, and such ferromagnetic material is coupled to a thickness of a more conductive material, and wherein the thickness and skin depth characteristics of the ferromagnetic material, and the thickness of the more conductive material, have been selected such that the electrically resistive portion provides a selected resistance profile as a function of temperature.
880. The system of claim 840, wherein the electrically resistive portion is part of an insulated conductor heater, and the insulated conductor heater is frictionally secured against a cased or open wellbore.
881. The system of claim 840, wherein the electrically resistive portion is part of a conductor-in-conduit heater.
882. The system of claim 840, wherein at least one electrical conductor is electrically coupled to the earth, and wherein electrical current is propagated from the electrical conductor to the earth.
883. The system of claim 840, wherein the reduced heat output is less than about 400 watts per meter.
884. The system of claim 840, wherein at least one electrical conductor comprises at least one section configured to comprise a relatively flat AC resistance profile in a temperature range between about 100 °C and 750 °C.
885. The system of claim 840, wherein at least one electrical conductor comprises at least one section configured to comprise a relatively flat AC resistance profile in a temperature range between about 100 °C and 700 °C, and a relatively sharp resistance profile at a temperature above about 700 °C and less than about 850 °C.
886. The system of claim 840, wherein at least one electrical conductor comprises at least one section configured to comprise a relatively flat AC resistance profile in a temperature range between about 300 °C and 600 °C.
887. The system of claim 840, wherein at least one electrical conductor is greater than about 10 m in length.
888. The system of claim 840, wherein at least one electrical conductor is greater than about 50 m in length.
889. The system of claim 840, wherein at least one electrical conductor is greater than about 100 m in length.
890. The system of claim 840, wherein the system is configured to reduce the heat output such that the system does not overheat in the opening.
891. The system of claim 840, wherein the system is configured to sharply reduce the heat output at or near the selected temperature.
892. The system of claim 840, wherein at least one electrically resistive portion comprises drawn iron.
893. The system of claim 840, wherein at least one electrically resistive portion comprises a ferromagnetic material drawn together or against a more conductive material.
894. The system of claim 840, wherein at least one electrically resistive portion comprises an elongated conduit comprising iron, wherein a center of the conduit is lined or filled with a material comprising copper or aluminum.
895. The system of claim 840, wherein at least one electrically resistive portion comprises an elongated conduit comprising iron, wherein a center of the conduit is filled with a material comprising stranded copper.
896. The system of claim 840, wherein at least one electrically resistive portion comprises an elongated conduit comprising iron, wherein a center of the conduit is lined or filled with a material comprising copper or aluminum, and wherein the copper or aluminum was melted in a center of the conduit and allowed to harden.
897. The system of claim 840, wherein at least one electrically resistive portion comprises an elongated conduit comprising a center portion and an outer portion, and wherein the diameter of the center portion is at least about 0.5 cm and comprises iron.
898. The system of claim 840, wherein at least one electrically resistive portion comprises an elongated conduit comprising a center portion and an outer portion.
899. The system of claim 840, wherein at least one electrically resistive portion comprises an elongated conduit comprising a center portion and an outer portion, wherein the center portion comprises a ferromagnetic material, and wherein a diameter of the center portion is at least about 3/4 of a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
900. The system of claim 840, wherein at least one of the electrically resistive portions comprises a composite material, wherein the composite material comprises a first material that has a resistance that declines when heated to the selected temperature, and wherein the composite material includes a second material that is more electrically conductive than the first material, and wherein the first material is coupled to the second material.
901. The system of claim 840, wherein the system is configured such that, at or near the selected temperature, the heat output of at least a portion of the system declines due to the Curie effect of at least one ferromagnetic material.
902. The system of claim 840, wherein the heat output is reduced below the rate at which the formation will absorb or transfer heat, thereby inhibiting overheating of the formation.
903. The system of claim 840, wherein the electrically resistive portion comprises a magnetic material that, at or near the selected temperature, becomes substantially nonmagnetic.
904. The system of claim 840, wherein the electrically resistive portion is elongated, and configured such that only portions of the electrically resistive portion that are at or near the selected temperature will inherently reduce heat output.
905. The system of claim 840, wherein the system comprises a heater which in turn comprises one or more of the electrically resistive portions.
906. The system of claim 840, configured such that when a temperature of at least one electrically resistive portion is below the selected temperature, and such temperature increases, then an AC resistance of such electrically resistive portion increases.
907. The system of claim 840, configured such that when a temperature of at least one electrically resistive portion is above the selected temperature, and such temperature increases, then an AC resistance of such electrically resistive portion decreases.
908. The system of claim 840, configured that when a temperature of at least one electrically resistive portion is below the selected temperature, and such temperature increases, then an AC
resistance of such electrically resistive portion gradually decreases.
909. The system of claim 840, configured such that when a temperature of at least one electrically resistive portion is above the selected temperature, and such temperature increases, then an AC resistance of such electrically resistive portion sharply decreases.
910. The system of claim 840, configured such that when a temperature of at least one electrically resistive portion is below the selected temperature, and such temperature increases, then an AC resistance of such electrically resistive portion increases, and when a temperature of at least one electrically resistive portion is above the selected temperature, and such temperature increases, then an AC resistance of such electrically resistive portion decreases.
911. The system of claim 840, configured such that when a temperature of at least one electrically resistive portion is below the selected temperature, and such temperature increases, then an AC resistance of such electrically resistive portion increases, and when a temperature of at least one electrically resistive portion is above the selected temperature, and such temperature increases, then an AC resistance of such electrically resistive portion decreases, and wherein the selected temperature is a temperature above the boiling point of water but below a failure temperature of one or more system components.
912. The system of claim 840, configured such that when a temperature of at least one electrically resistive portion is above the selected temperature, and such temperature increases, then an AC resistance of such electrically resistive portion gradually decreases.
913. The system of claim 840, wherein the amount of heat output provided from at least one electrically resistive portion is configured to be determined by the amount of current applied to such electrically resistive portion below the selected temperature.
914. The system of claim 840, wherein the amount of current applied to at least one electrically resistive portion is configured to be increased to decrease the amount of heat output from such electrically resistive portion below the selected temperature.
915. The system of claim 840, wherein the amount of current applied to at least one electrically resistive portion is configured to be decreased to increase the amount of heat output from such electrically resistive portion below the selected temperature.
916. The system of claim 840, wherein the amount of current applied to at least one electrically resistive portion is at least about 70 amps.
917. The system of claim 840, wherein the amount of current applied to at least one electrically resistive portion is at least about 100 amps.
918. The system of claim 840, wherein at least one electrically resistive portion comprises a turndown ratio of at least about 2 to 1.
919. The system of claim 840, wherein the applied current comprises alternating current operating at about 180 Hz AC frequency.
920. The system of claim 840, wherein the applied current comprises alternating current operating at about 60 Hz AC frequency.
921. The system of claim 840, wherein the opening comprises an uncased wellbore.
922. The system of claim 840, wherein the system is configured to radiatively heat the formation in the opening.
923. The system of claim 840, further comprising a fluid placed in the opening, wherein the system is configured to heat the fluid such that the fluid inhibits the opening from collapsing the system.
924. The system of claim 923, wherein the fluid comprises salt.
925. The system of claim 840, wherein the system is configured to withstand operating temperatures of about 250 °C or above.
926. The system of claim 840, wherein the system withstands operating temperatures of about 250 °C or above.
927. The system of claim 840, wherein at least one electrically resistive portion is located in an overburden of the formation.
928. The system of claim 840, wherein at least one electrically resistive portion located in an overburden of the formation is configured to inhibit fluid reflux in the overburden during use.
929. The system of claim 840, wherein at least one electrically resistive portion is coupled to a cable, and wherein the cable comprises a plurality of copper wires coated with an oxidation resistant alloy.
930. The system of claim 929, wherein the oxidation resistant alloy comprises stainless steel.
931. The system of claim 929, wherein the cable is a furnace cable.
932. The system of claim 929, wherein at least a portion of the cable is located inside at least a portion of an electrically resistive portion.
933. The system of claim 929, wherein the cable is electrically insulated with a material comprising mica.
934. The system of claim 929, wherein the cable is electrically insulated with a fiber comprising ceramic and mineral.
935. A method for heating a subsurface formation, comprising:
applying an alternating electrical current to one or more electrical conductors placed in an opening in the formation;
providing a heat output from at least one electrical conductor, wherein at least one electrical conductor comprises one or more electrically resistive portions, wherein at least one electrically resistive portion comprises one or more ferromagnetic materials, and wherein at least one of such electrically resistive portions is configured, when above or near a selected temperature, to inherently provide a reduced heat output; and allowing the heat to transfer from one or more electrically resistive portions to at least a part of the formation.
936. The method of claim 935, further comprising applying the alternating electrical current to the one or more electrical conductors at about 180 Hz operating frequency.
937. The method of claim 935, wherein the heat is allowed to transfer radiatively from the one or more electrically resistive portions to at least a part of the formation.
938. The method of claim 935, wherein the selected temperature is approximately the Curie temperature of at least one ferromagnetic material.
939. The method of claim 935, further comprising providing a relatively constant heat output in a temperature range between about 300 °C and 600 °C.
940. The method of claim 935, further comprising providing a relatively constant heat output in a temperature range between about 100 °C and 750 °C.
941. The method of claim 935, wherein at least one electrically resistive portion comprises an AC resistance that decreases above the selected temperature such that the electrically resistive portion provides the reduced heat output above the selected temperature.
942. The method of claim 935, wherein at least one ferromagnetic material has a thickness of at least about 3/4 of a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
943. The method of claim 935, wherein the subsurface formation comprises a hydrocarbon containing formation.
944. The method of claim 935, wherein the subsurface formation comprises a hydrocarbon containing formation, the method further comprising pyrolyzing at least some hydrocarbons in the formation.
945. The method of claim 935, wherein the subsurface formation comprises contaminated soil.
946. The method of claim 935, wherein the subsurface formation comprises contaminated soil, the method further comprising remediating at least a portion of the contaminated soil.
947. The method of claim 935, wherein the subsurface formation comprises a hydrocarbon containing formation, the method further comprising locating at least one electrically resistive portion proximate a relatively rich zone of the formation.
948. The method of claim 935, further comprising locating at least one electrically resistive portion proximate a hot spot of the formation.
949. The method of claim 935, wherein the subsurface formation comprises a hydrocarbon containing formation, the method further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
950. The method of claim 935, wherein the subsurface formation comprises a hydrocarbon containing formation, the method further comprising controlling a pressure within at least a part of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.
951. The method of claim 935, wherein the subsurface formation comprises a hydrocarbon containing formation, the method further comprising controlling formation conditions such that a produced mixture comprises a partial pressure of HZ within the mixture greater than about 0.5 bars.
952. The method of claim 935, wherein the subsurface formation comprises a hydrocarbon containing formation, the method further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
953. The method of claim 935, wherein the subsurface formation comprises a hydrocarbon containing formation, the method wherein at least a portion of the part of the formation is heated to a minimum pyrolysis temperature of about 270 °C.
954. The method of claim 935, wherein the reduced heat output is less than about 400 watts per meter.
955. The method of claim 935, further comprising controlling a skin depth in at least one electrically resistive portion by controlling a frequency of alternating current applied to at least one electrically resistive portion.
956. The method of claim 935, further comprising applying additional power to at least one electrically resistive portion as the temperature of the electrically resistive portion increases, and continuing to do so until the temperature is at or near the selected temperature.
957. The method of claim 935, wherein the subsurface formation contains at least two portions with different thermal conductivities, and further comprising applying heat to such portions with an electrically resistive portion that is proximate to such portions, and further comprising inherently allowing less heat to be applied from a part of an electrically resistive portion that is proximate a portion of the formation with a lower thermal conductivity.
958. The method of claim 935, wherein the subsurface formation contains at least two portions with different thermal conductivities, and further comprising applying heat to such portions with an electrically resistive portion that is proximate to such portions, and further comprising inherently allowing less heat to be applied from a part of the electrically resistive portion that is proximate a portion of the formation with a lower thermal conductivity while also allowing more heat to be applied from a part of the electrically resistive portion that is proximate a portion of the formation with a higher thermal conductivity.
959. The method of claim 935, wherein the subsurface formation contains at least two layers with different thermal conductivities, and further comprising applying heat to such layers with an electrically resistive portion that is proximate to such layers, and further comprising inherently allowing less heat to be applied from a part of an electrically resistive portion that is proximate a layer of the formation with a lower thermal conductivity.
960. The method of claim 935, wherein the subsurface formation contains at least two layers with different thermal conductivities, and further comprising applying heat to such layers with an electrically resistive portion that is proximate to such layers, and further comprising inherently allowing less heat to be applied from a part of the electrically resistive portion that is proximate a layer of the formation with a lower thermal conductivity while also allowing more heat to be applied from a part of the electrically resistive portion that is proximate a layer of the formation with a higher thermal conductivity.
961. The method of claim 935, further comprising controlling the heat applied from an electrically resistive portion by allowing less heat to be applied from any part of the electrically resistive portion that is at or near the selected temperature.
962. The method of claim 935, wherein an amount of heat output provided from at least one electrically resistive portion is determined by the amount of current applied to the electrical conductors.
963. The method of claim 935, further comprising controlling the amount of current applied to the electrical conductors to control an amount of heat provided by at least one electrically resistive portion.
964. The method of claim 935, further comprising increasing the amount of current applied to the electrical conductors to decrease an amount of heat provided by at least one electrically resistive portion.
965. The method of claim 935, further comprising decreasing the amount of current applied to the electrical conductors to increase an amount of heat provided by at least one electrically resistive portion.
966. The method of claim 935, further comprising applying at least about 70 amps of current to electrical conductors.
967. The method of claim 935, further comprising applying at least about 100 amps of current to electrical conductors.
968. The method of claim 935, further comprising producing fluids from the formation, and producing refined products from the produced fluids.
969. The method of claim 935, further comprising producing fluids from the formation, and producing a blending agent from the produced fluids.
970. The method of claim 935, further comprising producing fluids from the formation, and blending the produced fluids with hydrocarbons having an API gravity below about 15°.
971. A system configured to heat at least a part of a subsurface formation, comprising:
one or more electrical conductors configured to be placed in an opening in the formation, wherein at least one electrical conductor comprises at least one electrically resistive portion configured to provide a heat output when an alternating current is applied through such electrically resistive portion, and wherein at least one of such electrically resistive portions is configured, when operating above or near a selected temperature and when alternating current is applied, to only increase in operating temperature by less than about 1.5 °C when the thermal load decreases by about 1 watt per meter proximate to the one or more electrically resistive portions; and wherein the system is configured to allow heat to transfer from at least one of the electrically resistive portions to at least a part of the formation.
972. The system of claim 971, wherein the subsurface formation comprises a hydrocarbon containing formation.
973. The system of claim 971, wherein the subsurface formation comprises a hydrocarbon containing formation, and wherein the system is configured to pyrolyze at least some hydrocarbons in the formation.
974. The system of claim 971, wherein the subsurface formation comprises contaminated soil.
975. The system of claim 971, wherein the subsurface formation comprises contaminated soil, and wherein the system is configured to remediate at least a portion of the contaminated soil.
976. The system of claim 971, wherein the system is configured to provide heat to at least a portion of the opening in the formation.
977. The system of claim 971, wherein three or more electrical conductors are configured to be coupled in a three-phase electrical configuration.
978. The system of claim 971, further comprising an electrically insulating material placed between at least two electrical conductors.
979. The system of claim 971, wherein at least one electrically resistive portion comprises a ferromagnetic material.
980. The system of claim 971, wherein at least one electrically resistive portion comprises a ferromagnetic material comprising iron, nickel, chromium, cobalt, tungsten, or mixtures thereof.
981. The system of claim 971, wherein at least one electrically resistive portion comprises a ferromagnetic material with a thickness that is at least about 3/4 of a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
982. The system of claim 971, wherein at least one electrically resistive portion comprises a first ferromagnetic material with a first Curie temperature, and a second ferromagnetic material with a second Curie temperature.
983. The system of claim 971, wherein at least one electrically resistive portion comprises ferromagnetic material coupled to a higher conductivity non-ferromagnetic material.
984. The system of claim 971, wherein at least one electrically resistive portion comprises ferromagnetic material, and wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
985. The system of claim 971, wherein the electrically resistive portion comprises a thickness of ferromagnetic material, and such ferromagnetic material is coupled to a thickness of a more conductive material, and wherein the thickness of the ferromagnetic material and the thickness of the more conductive material have been selected such that the electrically resistive portion provides a selected resistance profile as a function of temperature.
986. The system of claim 971, wherein the heat output is greater than about 400 watts per meter below the selected temperature.
987. The system of claim 971, wherein at least one electrical conductor comprises at least one section configured to comprise a relatively flat AC resistance profile in a temperature range between about 100 °C and 750 °C.
988. The system of claim 971, wherein at least one electrical conductor is greater than about 10 m in length.
989. The system of claim 971, wherein the system is configured to sharply reduce the heat output at or near the selected temperature.
990. The system of claim 971, wherein the system is configured such that, at or near the selected temperature, the heat output of at least a portion of the system declines due to the Curie effect.
991. The system of claim 971, wherein the system comprises a heater which in turn comprises one or more of the electrically resistive portions.
992. The system of claim 971, configured such that when a temperature of at least one electrically resistive portion is below the selected temperature, and such temperature increases, then an AC resistance of such electrically resistive portion increases, and when a temperature of at least one electrically resistive portion is above the selected temperature, and such temperature increases, then an AC resistance of such electrically resistive portion decreases.
993. The system of claim 971, wherein the amount of heat output provided from at least one electrically resistive portion is configured to be determined by the amount of current applied to such electrically resistive portion below the selected temperature.
994. The system of claim 971, wherein the amount of current applied to at least one electrically resistive portion is at least about 70 amps.
995. The system of claim 971, wherein at least one electrically resistive portion comprises a turndown ratio of at least about 2 to 1.
996. The system of claim 971, wherein the applied current comprises alternating current operating at about 180 Hz AC frequency.
997. The system of claim 971, wherein the opening comprises an uncased wellbore.
998. The system of claim 971, wherein the system is configured to radiatively heat the formation in the opening.
999. The system of claim 971, wherein the system is configured to withstand operating temperatures of about 250 °C or above.
1000. The system of claim 971, wherein the system withstands operating temperatures of about 250 °C or above.
1001. The system of claim 971, wherein at least one electrically resistive portion is configured to inherently provide a decreased heat output above or near the selected temperature.
1002. The system of claim 971, wherein at least one electrically resistive portion is configured to inherently provide a heat output above or near the selected temperature that is about 20%
or less of the heat output at about 50 °C below the selected temperature.
1003. A heater system, comprising:
an AC supply configured to provide alternating current at a voltage above about 650 volts;
an electrical conductor comprising at least one electrically resistive portion configured to provide a heat output during application of the alternating electrical current to the electrically resistive portion during use; and wherein the electrical conductor comprises a ferromagnetic material and is configured to provide a reduced heat output above or near a selected temperature, wherein the selected temperature is at or about the Curie temperature of the ferromagnetic material.
1004. The heater system of claim 1003, wherein the voltage is above about 1000 volts.
1005. The heater system of claim 1003, wherein the heater is configured to provide heat to a subsurface formation.
1006. The heater system of claim 1003, wherein the heater is configured to provide heat to a hydrocarbon containing formation.
1007. The heater system of claim 1003, wherein the heater is configured to provide heat to a hydrocarbon containing formation, and wherein the system is configured to pyrolyze at least some hydrocarbons in the formation.
1008. The heater system of claim 1003, wherein the heater is configured to provide heat to contaminated soil.
1009. The heater system of claim 1003, wherein the heater is configured to provide heat to contaminated soil, and wherein the system is configured to remediate at least a portion of the contaminated soil.
1010. The heater system of claim 1003, wherein the system is configured to provide heat to at least a portion of an opening in a subsurface formation.
1011. The heater system of claim 1003, wherein three or more electrical conductors are configured to be coupled in a three-phase electrical configuration.
1012. The heater system of claim 1003, wherein the ferromagnetic material comprises iron, nickel, chromium, cobalt, tungsten, or mixtures thereof.
1013. The heater system of claim 1003, wherein the ferromagnetic material has a thickness that is at least about 3/4 of a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
1014. The heater system of claim 1003, further comprising a higher conductivity non-ferromagnetic material coupled to the ferromagnetic material.
1015. The heater system of claim 1003, wherein the heat output is greater than about 400 watts per meter below the selected temperature.
1016. The heater system of claim 1003, wherein the electrical conductor comprises at least one section configured to comprise a relatively flat AC resistance profile in a temperature range between about 100 °C and 750 °C.
1017. The heater system of claim 1003, wherein the electrical conductor is greater than about 10 m in length.
1018. The heater system of claim 1003, wherein the system is configured to sharply reduce the heat output at or near the selected temperature.
1019. The heater system of claim 1003, wherein the system is configured such that, at or near the selected temperature, the heat output of at least a portion of the system declines due to the Curie effect.
1020. The heater system of claim 1003, configured such that when a temperature of the electrical conductor is below the selected temperature, and such temperature increases, then an AC
resistance of the electrical conductor increases, and when a temperature of the electrical conductor is above the selected temperature, and such temperature increases, then an AC resistance of the electrical conductor decreases.
1021. The heater system of claim 1003, wherein the amount of current applied to the electrical conductor is at least about 70 amps.
1022. The heater system of claim 1003, wherein the electrical conductor comprises a turndown ratio of at least about 2 to 1.
1023. The heater system of claim 1003, wherein the alternating current comprises alternating current operating at about 180 Hz AC frequency.
1024. The heater system of claim 1003, wherein the system is configured to withstand operating temperatures of about 250 °C or above.
1025. The heater system of claim 1003, wherein the system withstands operating temperatures of about 250 °C or above.
1026. The heater system of claim 1003, wherein the electrical conductor is configured to inherently provide a decreased heat output above or near the selected temperature.
1027. The heater system of claim 1003, wherein the electrical conductor is configured to inherently provide a heat output above or near the selected temperature that is about 20% or less of the heat output at about 50 °C below the selected temperature.
102. A method of heating, comprising:
providing an alternating current at a voltage above about 650 volts to an electrical conductor comprising at least one electrically resistive portion to provide a heat output; and wherein at least one electrically resistive portion comprises a ferromagnetic material and is configured to provide a reduced heat output above or near a selected temperature, and wherein the selected temperature is at or about the Curie temperature of the ferromagnetic material.
1029. The method of heating of claim 1028, further comprising providing the alternating current to the electrical conductor when the electrical conductor is at or above the selected temperature.
1030. The method of heating of claim 1028, further comprising applying the alternating electrical current to the one or more electrical conductors at about 180 Hz operating frequency.
1031. The method of heating of claim 1028, further comprising allowing heat to transfer from at least one electrically resistive portion to at least a part of a subsurface formation.
1032. The method of heating of claim 1028, further comprising providing a relatively constant heat output in a temperature range between about 300 °C and 600 °C.
1033. The method of heating of claim 1028, further comprising providing a relatively constant heat output in a temperature range between about 100 °C and 750 °C.
1034. The method of heating of claim 1028, wherein at least one electrically resistive portion comprises an AC
resistance that decreases above the selected temperature such that the electrically resistive portion provides the reduced heat output above the selected temperature.
1035. The method of heating of claim 1028, wherein at least one ferromagnetic material has a thickness of at least about 3/4 of a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
1036. The method of heating of claim 1028, further comprising allowing heat to transfer from at least one electrically resistive portion to at least a part of a subsurface formation, wherein the subsurface formation comprises a hydrocarbon containing formation.
1037. The method of heating of claim 1028, further comprising allowing heat to transfer from at least one electrically resistive portion to at least a part of a hydrocarbon containing formation, and pyrolyzing at least some hydrocarbons in the formation.
1038. The method of heating of claim 1028, wherein the reduced heat output is less than about 400 watts per meter.
1039. The method of heating of claim 1028, further comprising controlling a skin depth in at least one electrically resistive portion by controlling a frequency of alternating current applied to at least one electrically resistive portion.
1040. The method of heating of claim 1028, further comprising applying additional power to at least one electrically resistive portion as the temperature of the electrically resistive portion increases, and continuing to do so until the temperature is at or near the selected temperature.
1041. The method of heating of claim 1028, further comprising controlling the heat applied from an electrically resistive portion by allowing less heat to be applied from any part of the electrically resistive portion that is at or near the selected temperature.
1042. The method of heating of claim 1028, wherein an amount of heat output provided from at least one electrically resistive portion is determined by the amount of current applied to the electrical conductors.
1043. The method of heating of claim 1028, further comprising controlling the amount of current applied to the electrical conductors to control an amount of heat provided by at least one electrically resistive portion.
1044. The method of heating of claim 1028, further comprising applying at least about 70 amps of current to the electrical conductors.
1045. The method of heating of claim 1028, further comprising applying at least about 100 amps of current to the electrical conductors.
1046. A system configured to heat at least a part of a subsurface formation, comprising:
one or more electrical conductors configured to be placed in an opening in the formation, wherein at least one electrical conductor comprises at least one electrically resistive portion that comprises at least one ferromagnetic material, and is configured to provide a heat output when an alternating current is provided to such electrically resistive portion, and wherein at least one of such electrically resistive portions is configured, when above or near a selected temperature, to inherently exhibit a decreased AC
resistance; and wherein the system is configured to allow heat to transfer from at least one of the electrically resistive portions to at least a part of the formation.
1047. The system of claim 1046, wherein the subsurface formation comprises a hydrocarbon containing formation.
1048. The system of claim 1046, wherein the subsurface formation comprises a hydrocarbon containing formation, and wherein the system is configured to pyrolyze at least some hydrocarbons in the formation.
1049. The system of claim 1046, wherein the subsurface formation comprises contaminated soil.
1050. The system of claim 1046, wherein the subsurface formation comprises contaminated soil, and wherein the system is configured to remediate at least a portion of the contaminated soil.
1051. The system of claim 1046, wherein the system is configured to provide heat to at least a portion of the opening in the formation.
1052. The system of claim 1046, wherein the decreased AC resistance is less than about 80% of the AC
resistance at about 50 °C below the selected temperature.
1053. The system of claim 1046, wherein three or more electrical conductors are configured to be coupled in a three-phase electrical configuration.
1054. The system of claim 1046, further comprising an electrically insulating material placed between at least two electrical conductors.
1055. The system of claim 1046, wherein at least one ferromagnetic material comprises iron, nickel, chromium, cobalt, tungsten, or mixtures thereof.
1056. The system of claim 1046, wherein at least one ferromagnetic material has a thickness that is at least about 3/4 of a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
1057. The system of claim 1046, wherein at least one electrically resistive portion comprises ferromagnetic material coupled to a higher conductivity non-ferromagnetic material.
1058. The system of claim 1046, wherein the selected temperature is approximately the Curie temperature of at least one ferromagnetic material.
1059. The system of claim 1046, wherein the electrically resistive portion comprises a thickness of ferromagnetic material, and such ferromagnetic material is coupled to a thickness of a more conductive material, and wherein the thickness of the ferromagnetic material and the thickness of the more conductive material have been selected such that the electrically resistive portion provides a selected resistance profile as a function of temperature.
1060. The system of claim 1046, wherein the heat output is greater than about 400 watts per meter below the selected temperature.
1061. The system of claim 1046, wherein at least one electrical conductor comprises at least one section configured to comprise a relatively flat AC resistance profile in a temperature range between about 100 °C and 750 °C.
1062. The system of claim 1046, wherein at least one electrical conductor is greater than about 10 m in length.
1063. The system of claim 1046, wherein the system is configured to sharply reduce the heat output at or near the selected temperature.
1064. The system of claim 1046, wherein the system is configured such that, at or near the selected temperature, the heat output of at least a portion of the system declines due to the Curie effect.
1065. The system of claim 1046, wherein the amount of heat output provided from at least one electrically resistive portion is configured to be determined by the amount of current applied to such electrically resistive portion below the selected temperature.
1066. The system of claim 1046, wherein the amount of current applied to at least one electrically resistive portion is at least about 70 amps.
1067. The system of claim 1,046, wherein at least one electrically resistive portion comprises a turndown ratio of at least about 2 to 1.
1068. The system of claim 1046, wherein the applied current comprises alternating current operating at about 180 Hz AC frequency.
1069. The system of claim 1046, wherein the opening comprises an uncased wellbore.
1070. The system of claim 1046, wherein the system is configured to radiatively heat the formation in the opening.
1071. The system of claim 1046, wherein the system is configured to withstand operating temperatures of about 250 °C or above.
1072. The system of claim 1046, wherein at least one electrically resistive portion is configured to inherently provide a decreased heat output above or near the selected temperature.
1073. The system of claim 1046, wherein at least one electrically resistive portion is configured to inherently provide a heat output above or near the selected temperature that is about 20%
or less of the heat output at about 50 °C below the selected temperature.
1074. A subsurface heating system, comprising:
one or more electrical conductors configured to be placed in an opening in the subsurface, wherein at least one electrical conductor comprises at least one electrically resistive portion configured to provide a heat output when an alternating current is applied through such electrically resistive portion, and wherein at least one of such electrically resistive portions is configured, when above or near a selected temperature, to provide a reduced heat output that is about 20% or less of the heat output provided at about 50 °C below the selected temperature; and wherein the system is configured to allow heat to transfer from at least one of the electrically resistive portions to at least a part of the subsurface.
1075. The system of claim 1074, wherein the subsurface comprises a hydrocarbon containing formation.
1076. The system of claim 1074, wherein the subsurface comprises a hydrocarbon containing formation, and wherein the system is configured to pyrolyze at least some hydrocarbons in the formation.
1077. The system of claim 1074, wherein the subsurface comprises contaminated soil.
1078. The system of claim 1074, wherein the subsurface comprises contaminated soil, and wherein the system is configured to remediate at least a portion of the contaminated soil.
1079. The system of claim 1074, wherein the system is configured to provide heat to at least a portion of the opening in the subsurface.
1080. The system of claim 1074, wherein the reduced heat output is less than about 20% of the heat output at about 40 °C below the selected temperature.
1081. The system of claim 1074, wherein the reduced heat output is less than about 20% of the heat output at about 30 °C below the selected temperature.
1082. The system of claim 1074, wherein the reduced heat output is less than about 15% of the heat output at about 50 °C below the selected temperature.
1083. The system of claim 1074, wherein the reduced heat output is less than about 10% of the heat output at about 50 °C below the selected temperature.
1084. The system of claim 1074, wherein three or more electrical conductors are configured to be coupled in a three-phase electrical configuration.
1085. The system of claim 1074, wherein at least one electrically resistive portion has an AC resistance that decreases at, near, or above the selected temperature such that the heat output provided by at least one electrically resistive portion decreases above or near the selected temperature.
1086. The system of claim 1074, wherein at least one electrically resistive portion comprises a ferromagnetic material.
1087. The system of claim 1074, wherein at least one electrically resistive portion comprises a ferromagnetic material comprising iron, nickel, chromium, cobalt, tungsten, or mixtures thereof.
1088. The system of claim 1074, wherein at least one electrically resistive portion comprises a ferromagnetic material with a thickness that is at least about 3/4 of a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
1089. The system of claim 1074, wherein at least one electrically resistive portion comprises a first ferromagnetic material with a first Curie temperature, and a second ferromagnetic material with a second Curie temperature.
1090. The system of claim 1074, wherein at least one electrically resistive portion comprises ferromagnetic material coupled to a higher conductivity non-ferromagnetic material.
1091. The system of claim 1074, wherein at least one electrically resistive portion comprises ferromagnetic material, and wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1092. The system of claim 1074, wherein the electrically resistive portion comprises a thickness of ferromagnetic material, and such ferromagnetic material is coupled to a thickness of a more conductive material, and wherein the thickness of the ferromagnetic material and the thickness of the more conductive material have been selected such that the electrically resistive portion provides a selected resistance profile as a function of temperature.
1093. The system of claim 1074, wherein the heat output is greater than about 400 watts per meter below the selected temperature.
1094. The system of claim 1074, wherein at least one electrical conductor comprises at least one section configured to comprise a relatively flat AC resistance profile in a temperature range between about 100 °C and 750 °C.
1095. The system of claim 1074, wherein at Least one electrical conductor is greater than about 10 m in length.
1096. The system of claim 1074, wherein the system is configured to sharply reduce the heat output at or near the selected temperature.
1097. The system of claim 1074, wherein the system is configured such that, at or near the selected temperature, the heat output of at least a portion of the system declines due to the Curie effect.
1098. The system of claim 1074, configured such that when a temperature of at least one electrically resistive portion is below the selected temperature, and such temperature increases, then an AC resistance of such electrically resistive portion increases, and when a temperature of at least one electrically resistive portion is above the selected temperature, and such temperature increases, then an AC resistance of such electrically resistive portion decreases.
1099. The system of claim 1074, wherein the amount of heat output provided from at least one electrically resistive portion is configured to be determined by the amount of current applied to such electrically resistive portion below the selected temperature.
1100. The system of claim 1074, wherein the amount of current applied to at least one electrically resistive portion is at least about 70 amps.
1101. The system of claim 1074, wherein at least one electrically resistive portion comprises a turndown ratio of at least about 2 to 1.
1102. The system of claim 1074, wherein the applied current comprises alternating current operating at about 180 Hz AC frequency.
1103. The system of claim 1074, wherein the opening comprises an uncased wellbore.
1104. The system of claim 1074, wherein the system is configured to withstand operating temperatures of about 250 °C or above.
1105. The system of claim 1074, wherein at least one electrically resistive portion comprises a decreased AC
resistance above or near the selected temperature that is less than about 80%
of an AC resistance at about 50 °C
below the selected temperature.
1106. A wellbore heating system, comprising:
one or more electrical conductors configured to be placed in the wellbore in the formation, wherein at least one electrical conductor comprises at least one electrically resistive portion configured to provide a heat output when alternating current is applied through such electrically resistive portion, and wherein at least one of such electrically resistive portions is configured such that the electric resistance though the electrically resistive portion decreases by at least about 20% when above or near a selected temperature, as compared to the electrical resistance at about 50 °C below the selected temperature; and wherein the system is configured to allow heat to transfer from at least one of the electrically resistive portions to at least a part of the wellbore.
1107. The system of claim 1106, wherein the decreased electrical resistance provides a decreased heat output when above or near the selected temperature.
110. The system of claim 1106, wherein the electric resistance though the electrically resistive portion decreases by at least about 30% when above or near a selected temperature, as compared to the electrical resistance at about 50 °C below the selected temperature.
1109. The system of claim 1106, wherein the electric resistance though the electrically resistive portion decreases by at least about 40% when above or near a selected temperature, as compared to the electrical resistance at about 50 °C below the selected temperature.
1110. The system of claim 1106, wherein the electric resistance through the electrically resistive portion decreases by at least about 50% when above or near a selected temperature, as compared to the electrical resistance at about 50 °C below the selected temperature.
1111. The system of claim 1106, wherein the wellbore is located in a subsurface formation.
1112. The system of claim 1106, wherein the wellbore is located in a hydrocarbon containing formation, and wherein the system is configured to pyrolyze at least some hydrocarbons in the formation.
1113. The system of claim 1106, wherein the wellbore is located in contaminated soil.
1114. The system of claim 1106, wherein the wellbore is located in contaminated soil, and wherein the system is configured to remediate at least a portion of the contaminated soil.
1115. The system of claim 1106, wherein three or more electrical conductors are configured to be coupled in a three-phase electrical configuration.
1116. The system of claim 1106, further comprising an electrically insulating material placed between at least two electrical conductors.
1117. The system of claim 1106, wherein at least one electrically resistive portion comprises a ferromagnetic material.
111. The system of claim 1106, wherein at least one electrically resistive portion comprises a ferromagnetic material comprising iron, nickel, chromium, cobalt, tungsten, or mixtures thereof.
1119. The system of claim 1106, wherein at least one electrically resistive portion comprises a ferromagnetic material with a thickness that is at least about 3/4 of a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
1120. The system of claim 1206, wherein at least one electrically resistive portion comprises a first ferromagnetic material with a first Curie temperature, and a second ferromagnetic material with a second Curie temperature.
1121. The system of claim 1106, wherein at least one electrically resistive portion comprises ferromagnetic material coupled to a higher conductivity non-ferromagnetic material.
1122. The system of claim 1106, wherein at least one electrically resistive portion comprises ferromagnetic material, and wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1123. The system of claim 1106, wherein the electrically resistive portion comprises a thickness of ferromagnetic material, and such ferromagnetic material is coupled to a thickness of a more conductive material, and wherein the thickness of the ferromagnetic material and the thickness of the more conductive material have been selected such that the electrically resistive portion provides a selected resistance profile as a function of temperature.
1124. The system of claim 1106, wherein the heat output is greater than about 400 watts per meter below the selected temperature.
1125. The system of claim 1106, wherein at least one electrical conductor comprises at least one section configured to comprise a relatively flat AC resistance profile in a temperature range between about 100 °C and 750 °C.
1126. The system of claim 1106, wherein at least one electrical conductor is greater than about 10 m in length.
1127. The system of claim 1106, wherein the system is configured to sharply reduce the heat output at or near the selected temperature.
112. The system of claim 1106, wherein the system is configured such that, at or near the selected temperature, the heat output of at least a portion of the system declines due to the Curie effect.
1129. The system of claim 1106, wherein the amount of heat output provided from at least one electrically resistive portion is configured to be determined by the amount of current applied to such electrically resistive portion below the selected temperature.
1130. The system of claim 1106, wherein the amount of current applied to at least one electrically resistive portion is at least about 70 amps.
1131. The system of claim 1106, wherein at least one electrically resistive portion comprises a turndown ratio of at least about 2 to 1.
1132. The system of claim 1106, wherein the applied current comprises alternating current operating at about 180 Hz AC frequency.
1133. The system of claim 1106, wherein the wellbore comprises an uncased wellbore.
1134. The system of claim 1106, wherein the system is configured to withstand operating temperatures of about 250 °C or above.
1135. The system of claim 1106, wherein at least one electrically resistive portion is configured to provide a reduced heat output above or near the selected temperature that is less than about 20% of the heat output provided at about 50 °C below the selected temperature.
1136. A wellbore heating system, comprising:
one or more electrical conductors configured to be placed in the wellbore in the formation, wherein at least one electrical conductor comprises at least one electrically resistive portion configured to provide a heat output when alternating current is applied through such electrically resistive portion, and wherein at least one of such electrically resistive portions has, when above or near a selected temperature, a decreased AC resistance that is about 80% or less of an AC resistance at about 50 °C below the selected temperature; and wherein the system is configured to allow heat to transfer from at least one of the electrically resistive portions to at least a part of the wellbore.
1137. The system of claim 1136, wherein the wellbore is located in a subsurface formation.
1138. The system of claim 1136, wherein the wellbore is located in a hydrocarbon containing formation, and wherein the system is configured to pyrolyze at least some hydrocarbons in the formation.
1139. The system of claim 1136, wherein the wellbore is located in contaminated soil.
1140. The system of claim 1136, wherein the wellbore is located in contaminated soil, and wherein the system is configured to remediate at least a portion of the contaminated soil.
1141. The system of claim 1236, wherein the decreased AC resistance is about 70% or less of the AC resistance at about 50 °C below the selected temperature.
1142. The system of claim 1136, wherein the decreased AC resistance is about 60% or less of the AC resistance at about 50 °C below the selected temperature.
1143. The system of claim 1136, wherein the decreased AC resistance is about 50% or less of the AC resistance at about 50 °C below the selected temperature.
1144. The system of claim 1136, wherein the decreased AC resistance is about 80% or less of the AC resistance at about 40 °C below the selected temperature.
1145. The system of claim 1136, wherein the decreased AC resistance is about 80% or less of the AC resistance at about 30 °C below the selected temperature.
1146. The system of claim 1136, wherein three or more electrical conductors are configured to be coupled in a three-phase electrical configuration.
1147. The system of claim 1136, further comprising an electrically insulating material placed between at least two electrical conductors.
1148. The system of claim 1136, wherein at least one electrically resistive portion comprises a ferromagnetic material.
1149. The system of claim 1136, wherein at least one electrically resistive portion comprises a ferromagnetic material comprising iron, nickel, chromium, cobalt, tungsten, or mixtures thereof.
1150. The system of claim 1136, wherein at least one electrically resistive portion comprises a ferromagnetic material with a thickness that is at least about 3/4 of a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
1151. The system of claim 1136, wherein at least one electrically resistive portion comprises a first ferromagnetic material with a first Curie temperature, and a second ferromagnetic material with a second Curie temperature.
1152. The system of claim 1136, wherein at least one electrically resistive portion comprises ferromagnetic material coupled to a higher conductivity non-ferromagnetic material.
1153. The system of claim 1136, wherein at least one electrically resistive portion comprises ferromagnetic material, and wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1154. The system of claim 1136, wherein the electrically resistive portion comprises a thickness of ferromagnetic material, and such ferromagnetic material is coupled to a thickness of a more conductive material, and wherein the thickness of the ferromagnetic material and the thickness of the more conductive material have been selected such that the electrically resistive portion provides a selected resistance profile as a function of temperature.
1155. The system of claim 1136, wherein the heat output is greater than about 400 watts per meter below the selected temperature.
1156. The system of claim 1136, wherein at least one electrical conductor comprises at least one section configured to comprise a relatively flat AC resistance profile in a temperature range between about 100 °C and 750 °C.
1157. The system of claim 1136, wherein at least one electrical conductor is greater than about 10 m in length.
1158. The system of claim 1136, wherein the system is configured to sharply reduce the heat output at or near the selected temperature.
1159. The system of claim 1136, wherein the system is configured such that, at or near the selected temperature, the heat output of at least a portion of the system declines due to the Curie effect.
1160. The system of claim 1136, wherein the amount of heat output provided from at least one electrically resistive portion is configured to be determined by the amount of current applied to such electrically resistive portion below the selected temperature.
1161. The system of claim 1136, wherein the amount of current applied to at least one electrically resistive portion is at least about 70 amps.
1162. The system of claim 1136, wherein at least one electrically resistive portion comprises a turndown ratio of at least about 2 to 1.
1163. The system of claim 1136, wherein the applied current comprises alternating current operating at about 180 Hz AC frequency.
1164. The system of claim 1136, wherein the wellbore comprises an uncased wellbore.
1165. The system of claim 1136, wherein the system is configured to withstand operating temperatures of about 250 °C or above.
1166. The system of claim 1136, wherein at least one electrically resistive portion is configured to provide a reduced heat output above or near the selected temperature that is less than about 20% of the heat output provided at about 50 °C below the selected temperature.
1167. A method for heating a subsurface formation, comprising:
applying an alternating electrical current to one or more electrical conductors placed in an opening in the formation, wherein at least one electrical conductor comprises one or more electrically resistive portions, and wherein at least one electrically resistive portion comprises one or more ferromagnetic materials;
providing a heat output from at least one electrically resistive portion, wherein at least one of such electrically resistive portions is configured, when above or near a selected temperature, to inherently exhibit a decreased AC resistance; and allowing the heat to transfer from one or more electrically resistive portions to at least a part of the formation.
1168. The method of claim 1167, further comprising applying the alternating electrical current to the one or more electrical conductors at about 180 Hz operating frequency.
1169. The method of claim 1167, wherein the heat is allowed to transfer radiatively from the one or more electrically resistive portions to at least a part of the formation.
1170. The method of claim 1167, wherein the selected temperature is approximately the Curie temperature of at least one ferromagnetic material.
1171. The method of claim 1167, further comprising providing a relatively constant heat output in a temperature range between about 100 °C and 750 °C.
1172. The method of claim 1167, wherein at least one electrically resistive portion comprises an AC resistance that decreases above the selected temperature such that the electrically resistive portion provides the reduced heat output above the selected temperature.
1173. The method of claim 1167, wherein the subsurface formation comprises a hydrocarbon containing formation.
1174. The method of claim 1167, wherein the subsurface formation comprises a hydrocarbon containing formation, the method further comprising pyrolyzing at least some hydrocarbons in the formation.
1175. The method of claim 1167, wherein the subsurface formation comprises a hydrocarbon containing formation, the method further comprising locating at least one electrically resistive portion proximate a relatively rich zone of the formation.
1176. The method of claim 1167, wherein the reduced heat output is less than about 400 watts per meter.
1177. The method of claim 1167, further comprising applying at least about 70 amps of current to the electrical conductors.
1178. The method of claim 1167, further comprising producing fluids from the formation, and producing refined products from the produced fluids.
1179. The method of claim 1167, further comprising producing fluids from the formation, and producing a blending agent from the produced fluids.
1180. The method of claim 1167, further comprising producing fluids from the formation, and blending the produced fluids with hydrocarbons having an API gravity below about 15°.
1181. A method for heating a subsurface formation, comprising:
applying an alternating electrical current to one or more electrical conductors placed in an opening in the formation, wherein at least one electrical conductor comprises one or more electrically resistive portions;
providing a heat output from at least one electrically resistive portion, wherein at least one of such electrically resistive portions is configured, when above or near a selected temperature, to provide a heat output that is about 20% or less of the heat output at about 50 °C below the selected temperature; and allowing the heat to transfer from one or more electrically resistive portions to at least a part of the formation.
1182. The method of claim 118I, further comprising applying the alternating electrical current to the one or more electrical conductors at about 180 Hz operating frequency.
1183. The method of claim 1181, wherein the reduced heat output is less than about 20% of the heat output at about 40 °C below the selected temperature.
1184. The method of claim 1181, wherein the reduced heat output is less than about 20% of the heat output at about 30 °C below the selected temperature.
1185. The method of claim 1181, wherein the reduced heat output is less than about 15% of the heat output at about 50 °C below the selected temperature.
116. The method of claim 1281, wherein the reduced heat output is less than about 10% of the heat output at about 50 °C below the selected temperature.
1187. The method of claim 1181, wherein the heat is allowed to transfer radiatively from the one or more electrically resistive portions to at least a part of the formation.
118. The method of claim 1181, wherein the selected temperature is approximately the Curie temperature of at least one ferromagnetic material.
119. The method of claim 1181, further comprising providing a relatively constant heat output in a temperature range between about 100 °C and 750 °C.
1190. The method of claim 1181, wherein at least one electrically resistive portion comprises an AC resistance that decreases above the selected temperature such that the electrically resistive portion provides the reduced heat output above the selected temperature.
1191. The method of claim 1181, wherein the subsurface formation comprises a hydrocarbon containing formation.
1192. The method of claim 1181, wherein the subsurface formation comprises a hydrocarbon containing formation, the method further comprising pyrolyzing at least some hydrocarbons in the formation.
1193. The method of claim 1181, wherein the subsurface formation comprises a hydrocarbon containing formation, the method further comprising locating at least one electrically resistive portion proximate a relatively rich zone of the formation.
1194. The method of claim 1181, wherein the reduced heat output is less than about 400 watts per meter.
1195. The method of claim 1181, further comprising applying at least about 70 amps of current to the electrical conductors.
1196. A method for heating a subsurface formation, comprising:
applying an alternating electrical current to one or more electrical conductors placed in an opening in the formation, wherein at least one electrical conductor comprises one or more electrically resistive portions;
providing a heat output from at least one electrically resistive portion, wherein at least one of such electrically resistive portions, when above or near a selected temperature, has a decreased AC resistance that is about 80% or less of the AC resistance at about 50 °C below the selected temperature; and allowing the heat to transfer from one or more electrically resistive portions to at least a part of the formation.
1197. The method of claim 1196, further comprising applying the alternating electrical current to the one or more electrical conductors at about 180 Hz operating frequency.
1198. The method of claim 1296, wherein the decreased AC resistance is about 70% or less of the AC resistance at about 50 °C below the selected temperature.
1199. The method of claim 1196, wherein the decreased AC resistance is about 60% or less of the AC resistance at about 50 °C below the selected temperature.
1200. The method of claim 1196, wherein the decreased AC resistance is about 50% or less of the AC resistance at about 50 °C below the selected temperature.
1201. The method of claim 1196, wherein the decreased AC resistance is about 80% or less of the AC resistance at about 40 °C below the selected temperature.
1202. The method of claim 1196, wherein the decreased AC resistance is about 80% or less of the AC resistance at about 30 °C below the selected temperature.
1203. The method of claim 1196, wherein the heat is allowed to transfer radiatively from the one or more electrically resistive portions to at least a part of the formation.
1204. The method of claim 1196, wherein the selected temperature is approximately the Curia temperature of at least one ferromagnetic material.
1205. The method of claim 1196, further comprising providing a relatively constant heat output in a temperature range between about 100 °C and 750 °C.
1206. The method of claim 1196, wherein at least one electrically resistive portion comprises an AC resistance that decreases above the selected temperature such that the electrically resistive portion provides the reduced heat output above the selected temperature.
1207. The method of claim 1196, wherein the subsurface formation comprises a hydrocarbon containing formation.
1208. The method of claim 1196, wherein the subsurface formation comprises a hydrocarbon containing formation, the method further comprising pyrolyzing at least some hydrocarbons in the formation.
1209. The method of claim 1196, wherein the subsurface formation comprises a hydrocarbon containing formation, the method further comprising locating at least one electrically resistive portion proximate a relatively rich zone of the formation.
1210. The method of claim 1196, wherein the reduced heat output is less than about 400 watts per meter.
1211. The method of claim 1196, further comprising applying at least about 70 amps of current to electrical conductors.
1212. A system configured to heat at least a part of a subsurface formation, comprising:
one or more electrical conductors configured to be placed in an opening in the formation, wherein at least one electrical conductor comprises an electrically resistive ferromagnetic material configured to provide, when energized by an alternating current, a reduced heat output above or near a selected temperature; and wherein the system is configured to allow heat to transfer from the electrical conductors to a part of the formation.
1213. The system of claim 1212, wherein the subsurface formation comprises a hydrocarbon containing formation.
1214. The system of claim 1212, wherein the subsurface formation comprises a hydrocarbon containing formation, and wherein the system is configured to pyrolyze at least some hydrocarbons in the formation.
1215. The system of claim 1212, wherein the subsurface formation comprises contaminated soil.
1216. The system of claim 1212, wherein the subsurface formation comprises contaminated soil, and wherein the system is configured to remediate at least a portion of the contaminated soil.
1217. The system of claim 1212, wherein the system is configured to provide heat to at least a portion of the opening in the formation.
1218. The system of claim 1212, wherein three or more electrical conductors are configured to be coupled in a three-phase electrical configuration.
1219. The system of claim 1212, wherein at least one electrical conductor comprises an inner conductor and at least one electrical conductor comprises an outer conductor.
1220. The system of claim 1212, further comprising an electrically insulating material placed between at least two electrical conductors.
1221. The system of claim 1212, wherein the ferromagnetic material comprises an AC resistance that decreases above the selected temperature such that the system provides the reduced heat output above the selected temperature.
1222. The system of claim 1212, further comprising a higher conductivity non-ferromagnetic material coupled to the ferromagnetic material.
1223. The system of claim 1212, further comprising a second ferromagnetic material coupled to the ferromagnetic material.
1224. The system of claim 1212, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1225. The system of claim 1212, wherein at least one electrical conductor is electrically coupled to the earth, and wherein electrical current is propagated from the electrical conductor to the earth.
1226. The system of claim 1212, wherein the reduced heat output is less than about 400 watts per meter.
1227. The system of claim 1212, wherein the heat output is greater than about 400 watts per meter below the selected temperature.
1228. The system of claim 1212, wherein at least one electrical conductor comprises at least one section configured to comprise a relatively flat AC resistance profile in a temperature range between about 100 °C and 750 °C.
1229. The system of claim 1212, wherein at least one electrical conductor is greater than about 10 m in length.
1230. The system of claim 1212, wherein the amount of current applied to the ferromagnetic material is at least about 70 amps.
1231. The system of claim 1212, wherein the ferromagnetic material comprises a turndown ratio of at least about 2 to 1.
1232. A method for heating a subsurface formation, comprising:
applying an alternating electrical current to one or more electrical conductors placed in an opening in the formation, wherein at least one electrical conductor comprises a ferromagnetic material;
providing a heat output, wherein the ferromagnetic material is configured to provide a reduced heat output above or near a selected temperature; and allowing the heat to transfer from the one or more electrical conductors to a part of the formation.
1233. The method of claim 1232, further comprising providing a relatively constant heat output in a temperature range between about 100 °C and 750 °C.
1234. The method of claim 1232, wherein the ferromagnetic material comprises an AC resistance that decreases above the selected temperature such that the ferromagnetic material provides the reduced heat output above the selected temperature.
1235. The method of claim 1232, wherein the ferromagnetic material comprises a thickness greater than about 3/4 of a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
1236. The method of claim 1232, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1237. The method of claim 1232, wherein the subsurface formation comprises a hydrocarbon containing formation.
1238. The method of claim 1232, wherein the subsurface formation comprises a hydrocarbon containing formation, the method further comprising pyrolyzing at least some hydrocarbons in the formation.
1239. The method of claim 1232, wherein the reduced heat output is less than about 400 watts per meter.
1240. The method of claim 1232, wherein the heat output is greater than about 400 watts per meter below the selected temperature.
1241. The method of claim 1232, further comprising controlling the amount of current applied to the ferromagnetic material to control the amount of heat provided by the ferromagnetic material.
1242. The method of claim 1232, further comprising applying at least about 70 amps of current to the ferromagnetic material.
1243. A system configured to heat at least a part of a subsurface formation, comprising:
one or more electrical conductors configured to be placed in an opening in the formation, wherein at least one electrical conductor comprises a ferromagnetic material configured to provide a reduced heat output above or near a selected temperature, wherein at least one electrical conductor is electrically coupled to the earth, and wherein alternating electrical current propagates from the electrical conductor to the earth; and wherein the system is configured to allow heat to transfer from the electrical conductors to a part of the formation.
1244. The system of claim 1243, wherein at least one electrical conductor is electrically coupled to the earth through an electrical contacting section.
1245. The system of claim 1243, wherein the electrical contacting section comprises a second opening coupled to the opening.
1246. The system of claim 1243, wherein the electrical contacting section comprises a second opening coupled to the opening and having a larger diameter than the opening.
1247. The system of claim 1243, wherein the electrical contacting section comprises a second opening coupled to the opening, and wherein the second opening is filled with a material that enhances electrical contact between at least one electrical conductor and the earth.
1248. The system of claim 1243, wherein at least one electrical conductor is configured to propagate electrical current into the opening.
1249. The system of claim 1243, wherein at least one electrical conductor is configured to propagate electrical current out of the opening.
1250. The system of claim 1243, wherein three or more electrical conductors are configured to be coupled in a three-phase electrical configuration.
1251. The system of claim 1243, wherein at least one electrical conductor comprises an inner conductor and at least one electrical conductor comprises an outer conductor.
1252. The system of claim 1243, further comprising an electrically insulating material placed between at least two electrical conductors.
1253. The system of claim 1243, wherein the ferromagnetic material comprises a resistance that decreases above the selected temperature such that the system provides the reduced heat output above the selected temperature.
1254. The system of claim 1243, wherein the ferromagnetic material comprises a thickness greater than about 3/a of a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
1255. The system of claim 1243, further comprising a higher conductivity material coupled to the ferromagnetic material.
1256. The system of claim 1243, further comprising a higher conductivity non-ferromagnetic material coupled to the ferromagnetic material.
1257. The system of claim 1243, further comprising a second ferromagnetic material coupled to the ferromagnetic material.
1258. The system of claim 1243, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1259. The system of claim 1243, wherein the ferromagnetic material comprises iron.
1260. The system of claim 1243, wherein the reduced heat output is less than about 400 watts per meter.
1261. The system of claim 1243, wherein the heat output is greater than about 400 watts per meter below the selected temperature.
1262. The system of claim 1243, wherein at least one electrical conductor comprises at least one section configured to comprise a relatively flat AC resistance profile in a temperature range between about 100 °C and 750 °C.
1263. The system of claim 1243, wherein at least one electrical conductor is greater than about 10 m in length.
1264. The system of claim 1243, wherein the amount of current applied to the ferromagnetic material is at least about 70 amps.
1265. The system of claim 1243, wherein the ferromagnetic material comprises a turndown ratio of at least about 2 to 1.
1266. The system of claim 1243, wherein the subsurface formation comprises a hydrocarbon containing formation.
1267. The system of claim 1243, wherein the subsurface formation comprises a hydrocarbon containing formation, and wherein the system is configured to pyrolyze at least some hydrocarbons in the formation.
1268. The system of claim 1243, wherein the subsurface formation comprises contaminated soil.
1269. The system of claim 1243, wherein the subsurface formation comprises contaminated soil, and wherein the system is configured to remediate at least a portion of the contaminated soil.
1270. The system of claim 1243, wherein the system is configured to provide heat to at least a portion of the opening in the formation.
1271. A method for heating a subsurface formation, comprising:
applying an alternating electrical current to one or more electrical conductors placed in an opening in the formation, wherein at least one electrical conductor comprises a ferromagnetic material;
providing a heat output from the ferromagnetic material, wherein the ferromagnetic material is configured to provide a reduced heat output above or near a selected temperature, wherein at least one electrical conductor is electrically coupled to the earth, and wherein electrical current propagates from the electrical conductor to the earth;
and allowing the heat to transfer from the one or more electrical conductors to a part of the formation.
1272. The method of claim 1271, further comprising allowing the electrical current to propagate through at least one electrical conductor into the opening.
1273. The method of claim 1271, further comprising providing a relatively constant heat output in a temperature range between about 100 °C and 750 °C.
1274. The method of claim 1271, wherein the ferromagnetic material comprises a resistance that decreases above the selected temperature such that the ferromagnetic material provides the reduced heat output above the selected temperature.
1275. The method of claim 1271, wherein the ferromagnetic material comprises a thickness greater than about 3/4 of a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
1276. The method of claim 1271, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1277. The method of claim 1271, wherein the subsurface formation comprises a hydrocarbon containing formation.
1278. The method of claim 1271, wherein the subsurface formation comprises a hydrocarbon containing formation, the method further comprising pyrolyzing at least some hydrocarbons in the formation.
1279. The method of claim 1271, wherein the reduced heat output is less than about 400 watts per meter.
1280. The method of claim 1271, wherein the heat output is greater than about 400 watts per meter below the selected temperature.
1281. The method of claim 1271, wherein the amount of heat output provided from the ferromagnetic material is determined by the amount of current applied to the ferromagnetic material.
1282. The method of claim 1271, further comprising controlling the amount of current applied to the ferromagnetic material to control the amount of heat provided by the ferromagnetic material.
1283. The method of claim 1271, further comprising applying at least about 70 amps of current to the ferromagnetic material.
1284. A heater system, comprising:
an AC supply configured to provide alternating current at a frequency between about 100 Hz and about 600 Hz;
an electrical conductor comprising at least one electrically resistive portion configured to provide a heat output during application of the alternating electrical current to the electrically resistive portion during use; and wherein the electrical conductor comprises a ferromagnetic material and is configured to provide a reduced heat output above or near a selected temperature, and wherein the selected temperature is at or about the Curie temperature of the ferromagnetic material.
1285. The heater system of claim 1284, wherein the AC supply is coupled to a supply of line current, and wherein the AC supply is configured to provide alternating current at about three times the frequency of the line current.
1286. The heater system of claim 1284, wherein the frequency is between about 140 Hz and about 200 Hz.
1287. The heater system of claim 1284, wherein the frequency is between about 400 Hz and about 550 Hz.
1288. The heater system of claim 1284, wherein the heater is configured to provide heat to a subsurface formation.
1289. The heater system of claim 1284, wherein the heater is configured to provide heat to a hydrocarbon containing formation, and wherein the system is configured to pyrolyze at least some hydrocarbons in the formation.
1290. The heater system of claim 1284, wherein the heater is configured to provide heat to contaminated soil, and wherein the system is configured to remediate at least a portion of the contaminated soil.
1291. The heater system of claim 1284, wherein the system is configured to provide heat to at least a portion of an opening in a subsurface formation.
1292. The heater system of claim 1284, wherein the ferromagnetic material comprises iron, nickel, chromium, cobalt, tungsten, or mixtures thereof.
1293. The heater system of claim 1284, wherein the ferromagnetic material has a thickness that is at least about 3/4 of a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
1294. The heater system of claim 1284, wherein the ferromagnetic material is coupled to a higher conductivity non-ferromagnetic material.
1295. The heater system of claim 1284, wherein the heat output is greater than about 400 watts per meter below the selected temperature.
1296. The heater system of claim 1284, wherein at least one electrical conductor comprises at least one section configured to comprise a relatively flat AC resistance profile in a temperature range between about 100 °C and 750 °C.
1297. The heater system of claim 1284, wherein at least one electrical conductor is greater than about 10 m in length.
129. The heater system of claim 1284, wherein the system is configured to sharply reduce the heat output at or near the selected temperature.
1299. The heater system of claim 1284, wherein the system is configured such that, at or near the selected temperature, the heat output of at least a portion of the system declines due to the Curie effect.
1300. The heater system of claim 1284, wherein the amount of heat output provided from at least one electrically resistive portion is configured to be determined by the amount of current applied to such electrically resistive portion below the selected temperature.
1301. The heater system of claim 1284, wherein the amount of current applied to at least one electrically resistive portion is at least about 70 amps.
1302. The heater system of claim 1284, wherein at least one electrically resistive portion comprises a turndown ratio of at least about 2 to 1.
1303. The heater system of claim 1284, wherein the heater system is configured to withstand operating temperatures of about 250 °C or above.
1304. The heater system of claim 1284, wherein the electrical conductor is configured to inherently provide a decreased heat output above or near the selected temperature.
1305. The heater system of claim 1284, wherein the electrical conductor is configured to inherently provide a heat output above or near the selected temperature that is about 20% or less of the heat output at about 50 °C below the selected temperature.
1306. A method of heating, comprising:
providing an alternating current at a frequency between about 100 Hz and about 600 Hz to an electrical conductor comprising at least one electrically resistive portion to provide a heat output; and wherein the electrical conductor comprises a ferromagnetic material and is configured to provide a reduced heat output above or near a selected temperature, and wherein the selected temperature is at or about the Curie temperature of the ferromagnetic material.
1307. The method of heating of claim 1306, further comprising providing the alternating current to the electrical conductor when the electrical conductor is at or above the selected temperature.
1308. The method of heating of claim 1306, further comprising providing the alternating current at about three times the frequency of line current from an AC supply.
1309. The method of heating of claim 1306, wherein the frequency is between about 140 Hz and about 200 Hz.
1310. The method of heating of claim 1306, wherein the frequency is between about 400 Hz and about 550 Hz.
1311. The method of heating of claim 1306, further comprising providing the alternating current to the electrical conductor when the electrical conductor is at or above the selected temperature.
1312. The method of heating of claim 1306, further comprising allowing heat to transfer from at least one electrically resistive portion to at least a part of a subsurface formation.
1313. The method of heating of claim 1306, further comprising providing a relatively constant heat output in a temperature range between about 100 °C and 750 °C.
1314. The method of heating of claim 1306, wherein the electrical conductor comprises an AC resistance that decreases above the selected temperature such that the electrical conductor provides the reduced heat output above the selected temperature.
1315. The method of heating of claim 1306, wherein the ferromagnetic material has a thickness of at least about 3/4 of a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
1316. The method of heating of claim 1306, further comprising allowing heat to transfer from the electrical conductor to at least a part of a subsurface formation, wherein the subsurface formation comprises a hydrocarbon containing formation.
1317. The method of heating of claim 1306, further comprising allowing heat to transfer from the electrical conductor to at least a part of a hydrocarbon containing formation, and pyrolyzing at least some hydrocarbons in the formation.
1318. The method of heating of claim 1306, wherein the reduced heat output is less than about 400 watts per meter.
1319. The method of heating of claim 1306, further comprising controlling a skin depth in the electrical conductor by controlling a frequency of alternating current applied to the electrical conductor.
1320. The method of heating of claim 1306, further comprising controlling the heat applied from the electrical conductor by allowing less heat to be applied from any part of the electrical conductor that is at or near the selected temperature.
1321. The method of heating of claim 1306, further comprising controlling the amount of current applied to the electrical conductor to control an amount of heat provided by at least one electrically resistive portion.
1322. The method of heating of claim 1306, further comprising applying at least about 70 amps of current to the electrical conductor.
1323. A heater, comprising:
an electrical conductor configured to generate heat during application of electrical current to the electrical conductor, wherein the electrical conductor is configured to provide a heat output of at least about 400 watts per meter during use below a selected temperature; and wherein the electrical conductor comprises a ferromagnetic material that, when alternating current is applied to it, a skin depth of such alternating current is greater than about 3/4 of the skin depth of the alternating current at the Curie temperature of the ferromagnetic material, such that the heater provides a reduced heat output above or near the selected temperature.
1324. The heater of claim 1323, wherein the heater is configured to provide heat to a subsurface formation.
1325. The heater of claim 1323, wherein the heater is configured to provide heat to a hydrocarbon containing formation, and wherein the system is configured to pyrolyze at least some hydrocarbons in the formation.
1326. The heater of claim 1323, wherein the heater is configured to provide heat to contaminated soil, and wherein the system is configured to remediate at least a portion of the contaminated soil.
1327. The heater of claim 1323, wherein the heater is configured to provide heat to at least a portion of an opening in a subsurface formation.
1328. The heater of claim 1323, further comprising two additional electrical conductors configured to generate heat during application of electrical current to the two additional electrical conductors, wherein the electrical conductor and the two additional electrical conductors are configured to be coupled in a three-phase electrical configuration.
1329. The heater of claim 1323, further comprising at least one additional electrical conductor.
1330. The heater of claim 1323, further comprising at least one additional electrical conductor and an electrically insulating material placed between the electrical conductor and at least one additional electrical conductor.
1331. The heater of claim 1323, wherein a resistance of the ferromagnetic material decreases above the selected temperature such that the heater provides the reduced heat output above the selected temperature.
1332. The heater of claim 1323, further comprising a higher conductivity material coupled to the ferromagnetic material.
1333. The heater of claim 1323, further comprising a higher conductivity non-ferromagnetic material coupled to the ferromagnetic material.
1334. The heater of claim 1323, further comprising a second ferromagnetic material coupled to the ferromagnetic material.
1335. The heater of claim 1323, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1336. The heater of claim 1323, wherein the ferromagnetic material comprises iron.
1337. The heater of claim 1323, wherein the reduced heat output is less than about 400 watts per meter.
1338. The heater of claim 1323, wherein the heater comprises a relatively flat AC resistance profile in a temperature range between about 100 °C and 750 °C.
1339. The heater of claim 1323, wherein the heater is greater than about 10 m in length.
1340. The heater of claim 1323, wherein the amount of heat output provided from the ferromagnetic material is configured to be determined by an amount of current applied to the ferromagnetic material.
1341. The heater of claim 1323, wherein the amount of current applied to the ferromagnetic material is at least about 70 amps.
2342. The heater of claim 1323, wherein the ferromagnetic material comprises a turndown ratio of at least about 2 to 1.
1343. The heater of claim 1323, wherein the heater is configured to be used to provide heat in a chemical plant.
1344. The heater of claim 1323, wherein the heater is configured to be used to provide heat to a reactor tube.
1345. The heater of claim 1323, wherein the heater is configured to be used to provide heat to a distillation column.
1346. The heater of claim 1323, wherein the heater is configured to be used to provide heat to a coker.
1347. The heater of claim 1323, wherein the heater comprises a 100,000 hour creep strength of at least about 3,000 psi at 650 °C.
1348. The heater of claim 1323, wherein the heater comprises an outside diameter of less than about 5 cm.
1349. A method, comprising:
applying an alternating electrical current to one or more electrical conductors, wherein at least one electrical conductor comprises a ferromagnetic material; and providing a heat output from the ferromagnetic material, wherein the ferromagnetic material is configured to provide a reduced beat output above or near a selected temperature, wherein the heat output is at least about 400 watts per meter below the selected temperature.
1350. The method of claim 1349, further comprising providing the alternating current to the electrical conductor when the electrical conductor is at or above the selected temperature.
1351. The method of claim 1349, further comprising applying the alternating electrical current to the one or more electrical conductors at about 180 Hz operating frequency.
1352. The method of claim 1349, further comprising allowing heat to transfer from at least one electrical conductor to at least a part of a subsurface formation.
1353. The method of claim 1349, further comprising providing a relatively constant heat output in a temperature range between about 300 °C and 600 °C.
1354. The method of claim 1349, further comprising providing a relatively constant heat output in a temperature range between about 100 °C and 750 °C.
1355. The method of claim 1349, wherein at least one electrical conductor comprises an AC resistance that decreases above the selected temperature such that the electrical conductor provides the reduced heat output above the selected temperature.
1356. The method of claim 1349, wherein the ferromagnetic material has a thickness of at least about 3/4 of a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
1357. The method of claim 1349, further comprising allowing heat to transfer from at least one electrical conductor to at least a part of a subsurface formation, wherein the subsurface formation comprises a hydrocarbon containing formation.
135. The method of claim 1349, further comprising allowing heat to transfer from at least one electrical conductor to at least a part of a hydrocarbon containing formation, and pyrolyzing at least some hydrocarbons in the formation.
1359. The method of claim 1349, wherein the reduced heat output is less than about 400 watts per meter.
1360. The method of claim 1349, further comprising controlling a skin depth in at least one electrical conductor by controlling a frequency of alternating current applied to at least one electrical conductor.
1361. The method of claim 1349, further comprising applying additional power to at least one electrical conductor as the temperature of the electrical conductor increases, and continuing to do so until the temperature is at or near the selected temperature.
1362. The method of claim 1349, further comprising controlling the heat applied from an electrical conductor by allowing less heat to be applied from any part of the electrical conductor that is at or near the selected temperature.
1363. The method of claim 1349, further comprising controlling the amount of current applied to the electrical conductors to control an amount of heat provided by at least one electrically resistive portion.
1364. The method of claim 1349, further comprising applying at least about 70 amps of current to the electrical conductors.
1365. A heater, comprising:
an electrical conductor;
an electrical insulator at least partially surrounding the electrical conductor;
a sheath at least partially surrounding the electrical insulator;
a conduit configured to generate a heat output during application of alternating electrical current to the conduit, wherein the electrical conductor, the electrical insulator, and the sheath are at least partially located inside the conduit; and wherein the conduit comprises a ferromagnetic material such that the heater provides a reduced heat output above or near a selected temperature.
1366. The heater of claim 1365, wherein the amount of current applied to the conduit is at least about 70 amps.
1367. The heater of claim 1365, wherein the heat output below the selected temperature is configured to be increased by decreasing the amount of current applied to the conduit.
1368. The heater of claim 1365, wherein the heat output below the selected temperature is configured to be decreased by increasing the amount of current applied to the conduit.
1369. The heater of claim 1365, wherein the heater is configured to allow heat to transfer from the heater to a part of a subsurface formation to pyrolyze at least some hydrocarbons in the subsurface formation.
1370. The heater of claim 1365, wherein the heater is configured to be placed in an opening in a subsurface formation.
1371. The heater of claim 1365, wherein a resistance of the ferromagnetic material decreases above the selected temperature such that the heater provides the reduced heat output above the selected temperature.
1372. The heater of claim 1365, further comprising a second ferromagnetic material coupled to the ferromagnetic material.
1373. The heater of claim 1365, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1374. The heater of claim 1365, wherein the ferromagnetic material comprises iron.
1375. The heater of claim 1365, wherein the reduced heat output is less than about 400 watts per meter.
1376. The heater of claim 1365, wherein the heat output is greater than about 400 watts per meter below the selected temperature.
1377. The heater of claim 1365, wherein the heater comprises a relatively flat AC resistance profile in a temperature range between about 100 °C and 750 °C.
1378. The heater of claim 1365, wherein the heater is greater than about 10 m in length.
1379. The heater of claim 1365, wherein the ferromagnetic material comprises a turndown ratio of at least about 2 to 1.
1380. The heater of claim 1365, wherein the heater comprises an outside diameter of less than about 5 cm.
1381. The heater of claim 1365, wherein the electrical conductor comprises copper.
1382. The heater of claim 1365, wherein the electrical conductor comprises stranded copper.
1383. The heater of claim 1365, wherein the electrical conductor comprises stranded copper coated with steel.
1384. The heater of claim 1365, wherein the electrical conductor, the electrical insulator, and the sheath are portions of a furnace cable.
1385. The heater of claim 1365, wherein the electrical conductor, the electrical insulator, and the sheath are portions of an insulated conductor heater.
1386. The heater of claim 1365, wherein a thickness of the conduit is at least about 3/4 of a skin depth of alternating current at the Curie temperature of the ferromagnetic material.
1387. The heater of claim 1365, wherein the electrical insulator comprises magnesium oxide.
1388. The heater of claim 1365, wherein the sheath comprises steel.
1389. The heater of claim 1365, further comprising a low electrical resistance metal coupled to at least a portion of the outside of the ferromagnetic material.
1390. The heater of claim 1389, further comprising a protective sheath coupled to the outside of at least a portion of the low electrical resistance metal.
1391. The heater of claim 1390, wherein the protective sheath comprises a second ferromagnetic material.
1392. The heater of claim 1390, wherein the protective sheath comprises a second ferromagnetic material, and wherein the second ferromagnetic material has a Curie temperature above the selected temperature.
1393. The heater of claim 1365, further comprising an electrically conductive lining placed on the inside of a portion of the conduit in an overburden section of a subsurface formation.
1394. The heater of claim 1365, further comprising a copper lining placed on the inside of a portion of the conduit in an overburden section of a subsurface formation.
1395. The heater of claim 1365, wherein the ferromagnetic material is configured to inherently provide the reduced heat output above or near the selected temperature that is about 20%
or less of the heat output at about 50 °C below the selected temperature.
1396. The heater of claim 1365, further comprising a deformation resistant container, wherein at least a portion of the system is located in the deformation resistant container, and wherein the selected temperature is selected such that the deformation resistant container has a creep-rupture strength of at least about 3000 psi at 100,000 hours at the selected temperature.
1397. The heater of claim 1365, wherein the deformation resistant container comprises an alloy, and the alloy comprises iron, chromium, nickel, manganese, carbon, and tantalum.
1398. A system configured to heat at least a part of a subsurface formation, comprising:
one or more electrical conductors configured to be placed in an opening in the formation, wherein at least one electrical conductor comprises at least one electrically resistive portion configured to provide a heat output when alternating current is applied through such electrically resistive portion, and wherein at least one of such electrically resistive portions comprises one or more ferromagnetic materials, and is configured, when above or near a selected temperature and when alternating current is applied, to inherently provide a reduced heat output;
a combustion heater placed in the opening in the formation; and wherein the system is configured to allow heat to transfer from at least one of the electrically resistive portions to at least a part of the formation.
1399. The system of claim 1398, wherein the combustion heater comprises a natural distributed combustor.
1400. The system of claim 1398, wherein the combustion heater comprises a flameless distributed combustor.
1401. The system of claim 1398, wherein at least one electrical conductor is configured to provide heat to maintain combustion in the combustion heater during use.
1402. The system of claim 1398, wherein the subsurface formation comprises a hydrocarbon containing formation.
1403. The system of claim 1398, wherein the subsurface formation comprises a hydrocarbon containing formation, and wherein the system is configured to pyrolyze at least some hydrocarbons in the formation.
1404. The system of claim 1398, wherein the subsurface formation comprises contaminated soil.
1405. The system of claim 1398, wherein the subsurface formation comprises contaminated soil, and wherein the system is configured to remediate at least a portion of the contaminated soil.
1406. The system of claim 1398, wherein the system is configured to provide heat to at least a portion of the opening in the formation.
1407. The system of claim 1398, wherein at least one of the electrically resistive portions is configured to provide heat to ignite at least part of the combustion heater.
1408. The system of claim 1398, wherein at least one of the electrically resistive portions is configured to be an ignition source for at least part of the combustion heater.
1409. The system of claim 1398, wherein the system is configured such that at least one electrically resistive portion maintains a minimum temperature of the system above an auto-ignition temperature of a combustion mixture being provided to at least part of the combustion heater.
1410. A heater for a subsurface formation, comprising:
an electrical conductor configured to generate a heat output during application of alternating electrical current to the electrical conductor;
wherein the electrical conductor comprises a ferromagnetic material, wherein the ferromagnetic material provides, when alternating current is applied to it, a reduced heat output above or near a selected temperature, and wherein the ferromagnetic material comprises a turndown ratio of at least 2:1;
and wherein the heater is configured to heat at least a part of a subsurface formation.
1411. The heater of claim 1410, wherein the amount of current applied to the electrical conductor is at least about 70 amps.
1412. The heater of claim 1410, wherein the ferromagnetic material has a thickness greater than a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
1413. The heater of claim 1410, wherein the heat output below the selected temperature is configured to be increased by decreasing the amount of current applied to the electrical conductor.
1414. The heater of claim 1410, wherein the heat output below the selected temperature is configured to be decreased by increasing the amount of current applied to the electrical conductor.
1415. The heater of claim 1410, wherein the heater is configured to provide heat to a subsurface formation.
1416. The heater of claim 1410, wherein the heater is configured to provide heat to a hydrocarbon containing formation, and wherein the system is configured to pyrolyze at least some hydrocarbons in the formation.
1417. The heater of claim 1410, wherein the heater is configured to provide heat to contaminated soil, and wherein the system is configured to remediate at least a portion of the contaminated soil.
1418. The heater of claim 1410, wherein the heater is configured to provide heat to at least a portion of an opening in a subsurface formation.
1419. The heater of claim 1410, further comprising at least one additional electrical conductor.
1420. The heater of claim 1410, further comprising at least one additional electrical conductor and an electrically insulating material placed between the electrical conductor and at least one additional electrical conductor.
1421. The heater of claim 1410, wherein a resistance of the ferromagnetic material decreases above a selected temperature of the ferromagnetic material such that the heater provides the reduced heat output above the selected temperature.
1422. The heater of claim 1410, further comprising a higher conductivity non-ferromagnetic material coupled to the ferromagnetic material.
1423. The heater of claim 1410, further comprising a second ferromagnetic material coupled to the ferromagnetic material.
1424. The heater of claim 1410, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1425. The heater of claim 1410, wherein the reduced heat output is less than about 400 watts per meter.
1426. The heater of claim 1410, wherein the heat output is greater than about 400 watts per meter below the selected temperature.
1427. The heater of claim 1410, wherein the heater is greater than about 10 m in length.
1428. The heater of claim 1410, wherein the ferromagnetic material comprises a turndown ratio of at least about 3 to 1.
1429. The heater of claim 1410, wherein the ferromagnetic material comprises a turndown ratio of at least about to 1.
1430. The heater of claim 1410, wherein the heater comprises an outside diameter of less than about 5 cm.
1431. A heater for a subsurface formation, comprising:
at least one section comprising a first electrical conductor configured to generate a heat output during application of an alternating electrical current to the first electrical conductor;
wherein the first electrical conductor comprises a ferromagnetic material, and the heater provides, when an alternating current is applied to it, a reduced heat output above or near a selected temperature;
at least one section comprising a second electrical conductor, wherein the second electrical conductor comprises a highly electrically conductive material, wherein at least a portion of the first electrical conductor is electrically coupled to at least a portion of the second electrical conductor such that a majority of the electrical current does not flow through the second electrical conductor below the selected temperature, and such that, at the selected temperature, a majority of the electrical current flows through the second electrical conductor; and wherein the heater is configured to heat at least part of a subsurface formation.
1432. The heater of claim 1431, wherein at least one section comprising the first electrical conductor is electrically coupled to at least one section comprising the second electrical conductor.
1433. The heater of claim 1431, wherein at least one section comprising the first electrical conductor is coupled between at least two sections comprising the second electrical conductor.
1434. The heater of claim 1431, wherein at least one section comprising the second electrical conductor is coupled between at least two sections comprising the first electrical conductor.
1435. The heater of claim 1431, wherein at least one section comprising the first electrical conductor is located proximate a portion of a subsurface formation selected for heating.
1436. The heater of claim 1431, wherein at least one section comprising the second electrical conductor is located proximate a portion of a subsurface formation selected to not be heated.
1437. The heater of claim 1431, wherein the second electrical conductor comprises copper.
1438. The heater of claim 1431, wherein the amount of current applied to the first electrical conductor is at least about 70 amps.
1439. The heater of claim 1431, wherein the ferromagnetic material has a thickness greater than a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
1440. The heater of claim 1431, wherein the heat output below the selected temperature is configured to be increased by decreasing the amount of current applied to the first electrical conductor.
1441. The heater of claim 1431, wherein the heat output below the selected temperature is configured to be decreased by increasing the amount of current applied to the first electrical conductor.
1442. The heater of claim 1431, wherein the heater is configured to provide heat to a subsurface formation.
1443. The heater of claim 1431, wherein the heater is configured to provide heat to a hydrocarbon containing formation, and wherein the system is configured to pyrolyze at least some hydrocarbons in the formation.
1444. The heater of claim 1431, wherein the heater is configured to provide heat to contaminated soil, and wherein the system is configured to remediate at least a portion of the contaminated soil.
1445. The heater of claim 1431, wherein the heater is configured to provide heat to at least a portion of an opening in a subsurface formation.
1446. The heater of claim 1431, further comprising at least one additional electrical conductor coupled to the first electrical conductor.
1447. The heater of claim 1431, further comprising at least one additional electrical conductor coupled to the first electrical conductor and an electrically insulating material placed between the first electrical conductor and at least one additional electrical conductor.
1448. The heater of claim 1431, wherein a resistance of the ferromagnetic material decreases above a selected temperature of the ferromagnetic material such that the heater provides the reduced heat output above the selected temperature.
1449. The heater of claim 1431, further comprising a higher conductivity non-ferromagnetic material coupled to the ferromagnetic material.
1450. The heater of claim 1431, further comprising a second ferromagnetic material coupled to the ferromagnetic material.
1451. The heater of claim 1431, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1452. The heater of claim 1431, wherein the reduced heat output is less than about 400 watts per meter.
1453. The heater of claim 1431, wherein the heat output is greater than about 400 watts per meter below the selected temperature.
1454. The heater of claim 1431, wherein the heater is greater than about 10 m in length.
1455. The heater of claim 1431, wherein the ferromagnetic material comprises a turndown ratio of at least about 2 to 1.
1456. The heater of claim 1431, wherein the heater comprises an outside diameter of less than about 5 cm.
1457. A heater for a subsurface formation, comprising:
a first elongated electrical conductor configured to generate a heat output during application of an alternating electrical current to the first electrical conductor, wherein the first electrical conductor comprises a ferromagnetic material, and the first elongated electrical conductor provides, when an alternating current is applied to it, a reduced heat output above or near a selected temperature;
a second elongated electrical conductor comprising a highly electrically conductive material, wherein at least a significant length of the first electrical conductor is electrically coupled to the second electrical conductor;
and wherein the heater is configured to heat at least part of a subsurface formation.
1458. The heater of claim 1457, wherein the second elongated electrical conductor comprises copper.
1459. The heater of claim 1457, wherein the amount of current applied to the first elongated electrical conductor is at least about 70 amps.
1460. The heater of claim 1457, wherein the ferromagnetic material has a thickness greater than a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
1461. The heater of claim 1457, wherein the heat output below the selected-temperature is configured to be increased by decreasing the amount of current applied to the first elongated electrical conductor.
1462. The heater of claim 1457, wherein the heat output below the selected temperature is configured to be decreased by increasing the amount of current applied to the first elongated electrical conductor.
1463. The heater of claim 1457, wherein the heater is configured to provide heat to a subsurface formation.
1464. The heater of claim 1457, wherein the heater is configured to provide heat to a hydrocarbon containing formation, and wherein the system is configured to pyrolyze at least some hydrocarbons in the formation.
1465. The heater of claim 1457, wherein the heater is configured to provide heat to contaminated soil, and wherein the system is configured to remediate at least a portion of the contaminated soil.
1466. The heater of claim 1457, wherein the heater is configured to provide heat to at least a portion of an opening in a subsurface formation.
1467. The heater of claim 1457, further comprising at least one additional electrical conductor coupled to the first elongated electrical conductor.
1468. The heater of claim 1457, further comprising at least one additional electrical conductor coupled to the first elongated electrical conductor and an electrically insulating material placed between the first elongated electrical conductor and at least one additional electrical conductor.
1469. The heater of claim 1457, wherein a resistance of the ferromagnetic material decreases above a selected temperature of the ferromagnetic material such that the heater provides the reduced heat output above the selected temperature.
1470. The heater of claim 1457, further comprising a higher conductivity non-ferromagnetic material coupled to the ferromagnetic material.
1471. The heater of claim 1457, further comprising a second ferromagnetic material coupled to the ferromagnetic material.
1472. The heater of claim 1457, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1473. The heater of claim 1457, wherein the reduced heat output is less than about 400 watts per meter.
1474. The heater of claim 1457, wherein the heat output is greater than about 400 watts per meter below the selected temperature.
1475. The heater of claim 1457, wherein the heater is greater than about 10 m in length.
1476. The heater of claim 1457, wherein the ferromagnetic material comprises a turndown ratio of at least about 2 to 1.
1477. The heater of claim 1457, wherein the heater comprises an outside diameter of less than about 5 cm.
1478. The heater of claim 1457, wherein the first elongated electrical conductor and the second elongated electrical conductor are electrically coupled such that a majority of the electrical current does not flow through the second elongated electrical conductor below the selected temperature, and such that, near or above the selected temperature, a majority of the electrical current flows through the second elongated electrical conductor.
1479. A method for heating fluids in a wellbore, comprising:
applying alternating electrical current to one or more electrical conductors placed in a wellbore, wherein at least one electrical conductor comprises one or more electrically resistive portions; and providing heat from at least one electrically resistive portion to fluids in the wellbore, wherein at least one of such electrically resistive portions is configured, when above or near a selected temperature, to inherently provide a reduced heat output.
1480. The method of claim 1479, further comprising producing fluids through the opening in the formation.
1481. The method of claim 1480, wherein the produced fluids comprise at least some hydrocarbons from the formation.
1482. The method of claim 1480, wherein the produced fluids comprise at least some pyrolyzed hydrocarbons from the formation.
1483. The method of claim 1479, further comprising providing a relatively constant heat output in a temperature range between about 300 °C and 600 °C.
1484. The method of claim 1479, further comprising providing a relatively constant heat output in a temperature range between about 100 °C and 750 °C.
1485. The method of claim 1479, wherein at least one electrically conductive portion comprises a resistance that decreases above the selected temperature such that the electrically conductive portion provides the reduced heat output above the selected temperature.
1486. The method of claim 1479, wherein at least one electrically conductive portion comprises ferromagnetic material with a thickness greater than about 3/4 of a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
1487. The method of claim 1479, wherein at least one electrically conductive portion comprises ferromagnetic material.
1488. The method of claim 1479, further comprising allowing heat to transfer from the wellbore to at least a part of a hydrocarbon containing formation, and pyrolyzing at least some hydrocarbons in the hydrocarbon containing formation.
1489. The method of claim 1479, wherein the reduced heat output is less than about 400 watts per meter.
1490. The method of claim 1479, wherein the heat output is greater than about 400 watts per meter below the selected temperature.
1491. The method of claim 1479, further comprising controlling a skin depth in at least one electrically resistive portion by controlling a frequency of alternating current applied to at least one electrically resistive portion.
1492. The method of claim 1479, further comprising applying additional power to at least one electrically resistive portion as the temperature of the electrically resistive portion increases, and continuing to do so until the temperature is at or near the selected temperature.
1493. The method of claim 1479, wherein the amount of heat output provided from at least one electrically resistive portion is determined by the amount of current applied to such electrically resistive portion.
1494. The method of claim 1479, further comprising controlling the amount of current applied to at least one electrically resistive portion to control the amount of heat provided by such electrically resistive portion.
1495. The method of claim 1479, farther comprising increasing the amount of current applied to at least one electrically resistive portion to decrease the amount of heat provided by such electrically resistive portion.
1496. The method of claim 1479, further comprising decreasing the amount of current applied to at least one electrically resistive portion to increase the amount of heat provided by such electrically resistive portion.
1497. The method of claim 1479, further comprising applying at least about 70 amps of current to at least one electrically resistive portion.
1498. A system configured to insulate an overburden of at least a part of a hydrocarbon containing formation, comprising:
an opening in a part of the formation;
a first conduit located in the opening;
an insulating material located between the first conduit and the overburden;
a second conduit located inside the first conduit With an annular region between the first and second conduits; and at least one baffle in the annular region.
1499. The system of claim 1498, wherein the insulating material is cement.
1500. The system of claim 1498, wherein the insulting material is foamed cement.
1501. The system of claim 1500, wherein the cement is foamed with nitrogen.
1502. The system of claim 1498, wherein the first conduit extends through the overburden of the formation.
1503. The system of claim 1498, wherein at least one baffle is positioned at a bottom of the first conduit and seals the annular region.
1504. The system of claim 1498, wherein a pressure in the annular region is maintained below about 2 bar.
1505. The system of claim 1498, further comprising a gas placed in the annular region.
1506. The system of claim 1505, wherein the gas comprises air.
1507. The system of claim 1505, wherein the gas comprises nitrogen.
1508. A method whereby heat transfer between an overburden of at least a part of a hydrocarbon containing formation and a conduit positioned in an opening in a part of the formation is decreased, comprising:
locating an insulating material between a first conduit and the overburden;
locating a second conduit inside the first conduit and forming an annular region between the first and second conduits; and positioning at least one baffle in the annular region.
1509. The method of claim 1508, wherein the insulating material is cement.
1510. The method of claim 1508, wherein the insulting material is foamed cement.
1511. The method of claim 1510, wherein the foamed cement is foamed with nitrogen.
1512. The method of claim 1508, wherein the first conduit extends through the overburden.
1513. The method of claim 1508, further comprising sealing the annular region with at least one baffle positioned at a bottom of the first conduit.
1514. The method of claim 1508, further comprising maintaining a pressure in the annular region below about 1 bar.
1515. The method of claim 1508, further comprising providing a gas to the annular region.
1516. The method of claim 1515, wherein the gas comprises air.
1517. The method of claim 1515, wherein the gas comprises nitrogen.
1518. A system configured to reduce a temperature of at least a part of a hydrocarbon containing formation, comprising:
an opening in a part of the formation;
a first conduit located in the opening;
a second conduit located inside the first conduit with an annular region between the first and second conduits;
a third conduit located inside the second conduit;
at least one baffle located in the annular region; and at least one refrigerant configured to be provided through the second and third conduits.
1519. The system of claim 1518, wherein the first conduit extends through an overburden section.
1520. The system of claim 1518, wherein the baffle is positioned at a bottom of the first conduit and seals the annular region.
1521. The system of claim 1518, wherein the annular region contains a gas.
1522. The system of claim 1521, wherein the gas comprises air.
1523. The system of claim 1521, wherein the gas comprises nitrogen.
1524. The system of claim 1518, wherein a pressure in the annular region is maintained below 1 bar.
1525. The system of claim 1518, wherein the first conduit is fixed in place with cement.
1526. The system of claim 1518, wherein the first conduit is fixed in place with foamed cement.
1527. The system of claim 1526, wherein the foamed cement comprises cement foamed with nitrogen.
1528. A method configured to reduce the temperature of at least a part of a hydrocarbon containing formation, comprising:
locating a first conduit in an opening in a part of the formation;
positioning a second conduit inside the first conduit;
positioning a third conduit inside the second conduit;
providing an annular region between the first and second conduits;
positioning a baffle in the annular region; and providing refrigerant to the second conduit.
1529. The system of claim 1528, wherein the first conduit extends through an overburden section.
1530. The system of claim 1528, wherein the baffle is positioned at a bottom of the first conduit and seals the annular region.
1531. The system of claim 1528, wherein the annular region contains a gas.
1532. The system of claim 1531, wherein the gas comprises air.
1533. The system of claim 1531, wherein the gas comprises nitrogen.
1534. The system of claim 1528, wherein a pressure in the annular region is maintained below 1 bar.
1535. The system of claim 1528, wherein the first conduit is fixed in place with cement.
1536. The system of claim 1528, wherein the first conduit is fixed in place with foamed cement.
1537. The system of claim 1536, wherein the foamed cement comprises cement foamed with nitrogen.
1538. The system of claim 1528, wherein the refrigerant exits a bottom of the second conduit, enters a bottom of the third conduit, and exits a top of the third conduit.
1539. A method of treating a hydrocarbon containing formation, comprising:
providing a first barrier to a first portion of the formation, wherein the first portion comprises methane;
removing water from the first portion;
producing fluids from the first portion, wherein produced fluids from the first portion comprise methane;
providing a second barrier to a second portion of the formation, wherein the second portion comprises methane;
removing water from the second portion, and then transferring at least a portion of such water to the first portion; and producing fluids from the second portion, wherein produced fluids from the second portion comprise methane.
1540. A method of treating a hydrocarbon containing formation, comprising:
providing a first barrier to a first portion of the formation;
removing water from the first portion;
providing a second barrier to a second portion of the formation, wherein the second portion comprises methane;
removing water from the second portion, and then transferring at least a portion of such water to the first portion; and producing fluids from the second portion, wherein produced fluids comprise methane.
1541. The method of claim 1540, wherein the first and second portions are substantially adjacent each other.
1542. The method of claim 1540, wherein providing a first barrier comprises:
providing refrigerant to a plurality of freeze wells to form a low temperature zone around the first portion;
and lowering a temperature within the low temperature zone to a temperature less than about a freezing temperature of water.
1543. The method of claim 1540, wherein providing a second barrier comprises:
providing refrigerant to a plurality of freeze wells to form a low temperature zone around the second portion; and lowering a temperature within the low temperature zone to a temperature less than about a freezing temperature of water.
1544. The method of claim 1540, wherein providing a first barrier comprises providing refrigerant to a plurality of freeze wells to form a frozen barrier zone and wherein the frozen barrier zone at least partially inhibits fluids from flowing into or out of the portion.
1545. The method of claim 1540, wherein providing a second barrier comprises providing refrigerant to a plurality of freeze wells to form a frozen barrier zone and wherein the frozen barrier zone at least partially inhibits fluids from flowing into or out of the portion.
2546. The method of claim 1540, further comprising:
providing heat from one or more heaters to at least one portion of the formation; and allowing the heat to transfer from at least one of the heaters to a part of the formation.
1547. The method of claim 1540, wherein an average temperature of at least one portion of the formation is less than about a boiling point of water at formation conditions.
1548. The method of claim 1540, wherein an average temperature of at least one portion of the formation is less than about 100 °C.
1549. A method of recovering methane from a hydrocarbon containing formation, comprising:
providing a barrier to a first portion of the formation, wherein the first portion comprises methane;
removing water from the first portion and then transferring at least a portion of such water to a second portion of the formation; and producing fluids from the first portion, wherein the produced fluids comprise methane.
1550. The method of claim 1549, wherein providing a barrier comprises:
providing refrigerant to a plurality of freeze wells to form a low temperature zone around the portion; and lowering a temperature within the low temperature zone to a temperature less than about a freezing temperature of water.
1551. The method of claim 1549, wherein providing a barrier comprises providing refrigerant to a plurality of freeze wells to form a frozen barrier zone and wherein the frozen barrier zone at least partially inhibits fluids from flowing into or out of the portion.
1552. The method of claim 1549, further comprising:
providing heat from one or more heaters to at least one portion of the formation; and allowing the heat to transfer from at least one of the heaters to a part of the formation.
1553. The method of claim 1549, wherein an average temperature of at least one portion of the formation is less than about a boiling point of water at formation conditions.
1554. The method of claim 1549, wherein an average temperature of at least one portion of the formation is less than about 100 °C.
1555. A method of treating a hydrocarbon containing formation, comprising:
assessing a thickness of a portion of the formation to be treated, wherein such portion comprises methane;
using such thickness to determine a number of barrier wells to provide to the portion of the formation;
providing a plurality of barrier wells to the portion of the formation;
removing water from a portion of the formation; and producing fluids from a portion of the formation, wherein the produced fluids comprise methane.
1556. The method of claim 1555, wherein providing at least one barrier comprises:
providing refrigerant to a plurality of freeze wells to form a low temperature zone around the portion; and lowering a temperature within the low temperature zone to a temperature less than about a freezing temperature of water.
1557. The method of claim 1555, wherein providing at least one barrier comprises providing refrigerant to a plurality of freeze wells to form a frozen barrier zone and wherein the frozen barrier zone at least partially inhibits fluids from flowing into or out of the portion.
1558. The method of claim 1555, further comprising:
providing heat from one or more heaters to at least one portion of the formation; and allowing the heat to transfer from at least one of the heaters to a part of the formation.
1559. The method of claim 1555, wherein an average temperature of at least one portion of the formation is less than about a boiling point of water at formation conditions.
1560. The method of claim 1555, wherein an average temperature of at least one portion of the formation is less than about 100 °C.
1561. A method of treating a hydrocarbon containing formation, comprising:
providing a first barrier to a first portion of the formation, wherein the first portion comprises methane;
providing a second barrier to a second portion of the formation, wherein at least a part of the first portion is positioned substantially between the second portion and a surface of the formation;
removing water from the first portion;
producing fluids from the first portion, wherein produced fluids from the first portion comprise methane;
removing water from the second portion of the formation, and then transferring at least a portion of such water to the first portion of the formation; and producing fluids from the second portion, wherein produced fluids from the second portion comprise methane.
1562. The method of claim 1561, wherein providing the first barrier comprises providing refrigerant to a plurality of freeze wells to form a frozen barrier zone and wherein the frozen barrier zone at least partially inhibits fluids from flowing into or out of the portion.
1563. The method of claim 1561, further comprising:
providing heat from one or more heaters to at least one portion of the formation; and allowing the heat to transfer from at least one of the heaters to a part of the formation.
1564. The method of claim 1561, wherein an average temperature of at least one portion of the formation is less than about a boiling point of water at formation conditions.
1565. The method of claim 1561, wherein an average temperature of at least one portion of the formation is less than about 100 °C.
1566. A method of in situ sequestration of carbon dioxide within a hydrocarbon containing formation, comprising:
storing carbon dioxide within at least one portion of the formation, wherein at least some methane has been produced from the portion of the formation prior to storing the carbon dioxide within the portion of the formation, and wherein the portion of the formation has been at least partially isolated from other subsurface areas using a barrier wall.
1567. The method of claim 1566, wherein water has been removed from the portion of the formation after the barrier wall was in place.
1568. The method of claim 1566, wherein the carbon dioxide is stored within a spent portion of the formation.
1569. The method of claim 1568, wherein the spent portion of the formation comprises hydrocarbon containing material within a section of the formation that has been heated and from which condensable hydrocarbons have been produced, and wherein the spent portion of the formation is at a temperature at which carbon dioxide adsorbs onto the hydrocarbon containing material.
1570. The method of claim 1566, further comprising raising a water level within the portion to inhibit migration of the carbon dioxide from the portion.
1571. The method of claim 1566, further comprising using the carbon dioxide to displace methane.
1572. The method of claim 1566, wherein the portion of the formation is more than about 760 m below ground surface.
1573. The method of claim 1566, further comprising adsorbing a portion of the carbon dioxide within the portion.
1574. A method of in situ sequestration of carbon dioxide within a hydrocarbon containing formation, comprising:
producing fluids from at least a portion of the formation, wherein produced fluids comprise methane, and wherein the portion of the formation has been at least partially isolated from other subsurface areas using a barrier wall; and storing carbon dioxide within the portion.
1575. The method of claim 1574, wherein water has been removed from the portion of the formation after the barrier wall was in place.
1576. The method of claim 1574, wherein the carbon dioxide is stored within a spent portion of the formation.
1577. The method of claim 1576, wherein the spent portion of the formation comprises hydrocarbon containing material within a section of the formation that has been heated and from which condensable hydrocarbons have been produced, and wherein the spent portion of the formation is at a temperature at which carbon dioxide adsorbs onto the hydrocarbon containing material.
1578. The method of claim 1574, further comprising raising a water level within the portion to inhibit migration of the carbon dioxide from the portion.
1579. The method of claim 1574, further comprising using the carbon dioxide to displace methane.
1580. The method of claim 1574, wherein the portion of the formation is more than about 760 m below ground surface.
1581. The method of claim 1574, further comprising adsorbing a portion of the carbon dioxide within the portion.
1582. The method of claim 1574, wherein producing fluids from the formation comprises removing pyrolyzation products from the formation.
1583. The method of claim 1574, wherein producing fluids from the formation comprises heating a portion of the formation to a temperature sufficient to generate synthesis gas; introducing a synthesis gas generating fluid into the part of the formation; and removing synthesis gas from the formation.
1584. A method of in situ sequestration of carbon dioxide within a hydrocarbon containing formation, comprising:
providing heat from one or more heaters to at least one portion of the formation, wherein the portion comprises methane, and wherein the portion of the formation has been at least partially isolated from other subsurface areas using a barrier wall;
allowing the heat to transfer from the one or more heaters to a part of the formation;
producing fluids from the formation, wherein produced fluids comprise methane;
allowing the portion to cool; and storing carbon dioxide within the portion.
1585. The method of claim 1584, wherein water has been removed from the portion of the formation after the barrier wall was in place.
1586. The method of claim 1584, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the part of the formation.
1587. The method of claim 1584, wherein the carbon dioxide is stored within a spent portion of the formation.
1588. The method of claim 1587, wherein the spent portion of the formation comprises hydrocarbon containing material within a section of the formation that has been heated and from which condensable hydrocarbons have been produced, and wherein the spent portion of the formation is at a temperature at which carbon dioxide adsorbs onto the hydrocarbon containing material.
1589. The method of claim 1587, wherein the spent portion of the formation comprises a substantially uniform permeability created by heating the spent formation and removing fluid during formation of the spent portion.
1590. The method of claim 1584, further comprising raising a water level within the portion to inhibit migration of the carbon dioxide from the portion.
1591. The method of claim 1584, further comprising using the carbon dioxide to displace methane.
1592. The method of claim 1584, wherein the portion of the formation is more than about 750 m below ground surface.
1593. The method of claim 1584, further comprising adsorbing a portion of the carbon dioxide within the portion.
1594. The method of claim 1584, wherein producing fluids from the formation comprises removing pyrolyzation products from the formation.
1595. The method of claim 1584, wherein heating the part of the formation comprises introducing an oxidizing fluid into the part of the formation, reacting the oxidizing fluid within the part of the formation to heat the part of the formation.
1596. The method of claim 1584, wherein heating the part of the formation comprises:
heating hydrocarbon containing material adjacent to one or more wellbores to a temperature sufficient to support oxidation of the hydrocarbon containing material with an oxidant;
introducing the oxidant to hydrocarbon containing material adjacent to one or more wellbores to oxidize hydrocarbons and produce heat; and conveying produced heat to the portion.
1597. The method of claim 1584, wherein at least one of the heaters comprises an electrical heater.
1598. The method of claim 1584, wherein at least one of the heaters comprises a flameless distributed combustor.
1599. The method of claim 1598, wherein a portion of fuel for one or more flameless distributed combustors is obtained from the formation.
1600. The method of claim 1584, wherein at least one of the heaters comprises a heater well in the formation through which heat transfer fluid is circulated.
1601. The method of claim 1600, wherein the heat transfer fluid comprises combustion products.
1602. The method of claim 1600, wherein the heat transfer fluid comprises steam.
1603. The method of claim 1584, further comprising:
producing condensable hydrocarbons under pressure; and generating electricity by passing a portion of the produced fluids through a turbine.
1604. The method of claim 1584, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.
1605. The method of claim 1584, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units of heaters are repeated over an area of the formation to form a repetitive pattern of units.
1606. A method of treating a hydrocarbon containing formation in situ, comprising:
providing heat from one or more heaters to at least one portion of the formation, wherein the formation comprises sub-bituminous coal;
allowing the heat to transfer from the one or more heaters to a part of the formation;
providing H2 to the part of the formation; and producing fluids from the formation.
1607. The method of claim 1606, wherein a portion of the formation comprises methane.
1608. The method of claim 1606, wherein the sub-bituminous coal has a vitrinite reflectance of less than about 0.5%.
1609. The method of claim 1606, wherein produced fluids comprise methane.
1610. The method of claim 1606, wherein one or more heaters comprise at least two heaters, and wherein superposition of heat from at least two heaters pyrolyzes at least some hydrocarbons within the part of the formation.
1611. The method of claim 1606, further comprising maintaining a temperature within the part of the formation within a pyrolysis temperature range.
1612. The method of claim 1606, wherein at least one of the heaters comprises an electrical heater.
1613. The method of claim 1606, wherein at least one of the heaters comprises a surface burner.
1614. The method of claim 1606, wherein at least one of the heaters comprises a flameless distributed combustor.
1615. The method of claim 1606, wherein at least one of the heaters comprises a natural distributed combustor.
1616. The method of claim 1606, further comprising controlling a pressure and a temperature within at least a majority of the part of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.
1617. The method of claim 1606, further comprising controlling the heat such that an average heating rate of the part of the formation is less than about 1 °C per day during pyrolysis.
1618. The method of claim 1606, wherein providing heat from the one or more heaters to at least a portion of formation comprises:
heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C v.rho.B, wherein .rho.B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10 °C/day.
1619. The method of claim 1606, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.
1620. The method of claim 1606, wherein providing heat from the one or more heaters comprises heating the part of the formation such that a thermal conductivity of at least a portion of the part of the formation is greater than about 0.5 W/(m °C).
1621. The method of claim 1606, further comprising producing a mixture comprising condensable hydrocarbons having an API gravity of at least about 25°.
1622. The method of claim 1606, further comprising producing a mixture comprising condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.
1623. The method of claim 1606, further comprising producing a mixture comprising non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
1624. The method of claim 1606, further comprising producing a mixture comprising condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.
1625. The method of claim 1606, further comprising producing a mixture comprising condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
1626. The method of claim 1606, further comprising producing a mixture comprising condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
1627. The method of claim 1606, further comprising producing a mixture comprising condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.
1628. The method of claim 1606, further comprising producing a mixture comprising condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.
1629. The method of claim 1606, further comprising producing a mixture comprising condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
1630. The method of claim 1606, further comprising producing a mixture comprising condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.
1631. The method of claim 1606, further comprising producing a mixture comprising condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.
1632. The method of claim 1606, further comprising producing a mixture comprising a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.
1633. The method of claim 1606, further comprising producing a mixture comprising ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.
1634. The method of claim 1606, further comprising producing a mixture comprising ammonia, and wherein the ammonia is used to produce fertilizer.
1635. The method of claim 1606, further comprising controlling a pressure within at least a majority of the part of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.
1636. The method of claim 1606, further comprising controlling formation conditions to produce a mixture, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
1637. The method of claim 1606, wherein a partial pressure of H2 within a produced fluid is measured when the produced fluid is at a production well.
1638. The method of claim 1606, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1639. The method of claim 1606, further comprising:
providing hydrogen (H2) to a heated section to hydrogenate hydrocarbons within the heated section; and heating a portion of the section with heat from hydrogenation.
1640. The method of claim 1606, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the part of the formation to greater than about 100 millidarcy.
1641. The method of claim 1606, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the part of the formation.
1642. The method of claim 1606, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.
1643. The method of claim 1606, further comprising producing a mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.
1644. The method of claim 1606, wherein at least about 20 heaters are disposed in the formation for each production well.
1645. The method of claim 1606, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.
1646. The method of claim 1606, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
1647. The method of claim 1606, further comprising providing at least one barrier wall to inhibit fluids flowing into or out of the portion.
1648. A method of treating a hydrocarbon containing formation in situ, comprising:
producing fluids from the formation, wherein the produced fluids comprise methane;
separating H2 from the produced fluids or converting at least some of the produced fluids to H2; and providing at least some of the separated or converted H2 to the portion of the formation.
1649. The method of claim 1648, further comprising controlling a pressure and a temperature within at least a majority of a part of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.
1650. The method of claim 1648, further comprising controlling formation conditions to produce the fluids, wherein a partial pressure of H2 within the fluids is greater than about 0.5 bars.
1651. The method of claim 1648, wherein a partial pressure of H2 within the fluids is measured when the fluids are at a production well.
1652. The method of claim 1648, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1653. A method of treating a hydrocarbon containing formation in situ, comprising:
producing fluids from the formation, wherein the produced fluids comprise methane;
separating H2 from the produced fluids or converting at least some of the produced fluids to H2;
providing heat from one or more heaters to at least one portion of the formation, wherein the portion comprises methane;
allowing the heat to transfer from the one or more heaters to a part of the formation; and providing at least some of the separated or converted H2 to the portion of the formation.
1654. The method of claim 1653, further comprising controlling a pressure and a temperature within at least a majority of a part of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.
1655. The method of claim 1653, further comprising controlling formation conditions to produce the fluids, wherein a partial pressure of H2 within the fluids is greater than about 0.5 bars.
1656. The method of claim 1653, wherein a partial pressure of H2 within the fluids is measured when the fluids are at a production well.
1657. The method of claim 1653, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1658. A method of treating a hydrocarbon containing formation in situ, comprising:
providing at least one barrier wall to at least a portion of the formation;
reducing a pressure in the portion of the formation in a controlled manner, wherein the portion of the formation comprises methane; and producing fluids from the formation, wherein the produced fluids comprise methane.
1659. The method of claim 1658, further comprising:
providing heat from one or more heaters to at least a portion of the formation; and allowing the heat to transfer from the one or more heaters to a part of the formation.
1660. The method of claim 1658, further comprising reducing the pressure below atmospheric pressure.
1661. The method of claim 1658, wherein reducing the pressure comprises removing water from the portion of the formation.
1662. The method of claim 1661, wherein removing water from the portion of the formation comprises using one or more dewatering wells.
1663. The method of claim 1658, wherein reducing the pressure comprises drawing up to a vacuum.
1664. The method of claim 1658, wherein reducing the pressure comprises drawing a vacuum.
1665. The method of claim 1658, further comprising providing a barrier to a portion of the formation.
1666. The method of claim 1665, wherein providing a barrier comprises:
providing refrigerant to a plurality of freeze wells to form a low temperature zone around the portion; and lowering a temperature within the low temperature zone to a temperature less than about a freezing temperature of water.
1667. The method of claim 1665, wherein providing a barrier comprises providing refrigerant to a plurality of freeze wells to form a frozen barrier zone and wherein the frozen barrier zone at least partially inhibits fluids from flowing into or out of the portion.
1668. The method of claim 1658, wherein an average temperature of at least one portion of the formation is less than about a boiling point of water at formation conditions.
1669. The method of claim 1658, wherein an average temperature of at least one portion of the formation is less than about 100°C.
1670. The method of claim 1658, further comprising:
providing a barrier to a portion of the formation; and removing water from the portion.
1671. A method of treating a hydrocarbon containing formation in situ, comprising:
providing a barrier to at least a portion of the formation, wherein the barrier inhibits fluids from flowing into or out of the portion;
removing at least some water from the portion;
reducing a pressure in the portion of the formation, wherein the portion of the formation comprises methane; and producing fluids from the formation, wherein the produced fluids comprise methane.
1672. The method of claim 1671, further comprising:
providing heat from one or more heaters to at least a portion of the formation; and allowing the heat to transfer from the one or more heaters to a part of the formation.
1673. The method of claim 1671, further comprising reducing the pressure below atmospheric pressure.
1674. The method of claim 1671, wherein the methane produced is coal bed methane.
1675. The method of claim 1671, wherein removing the water comprises pumping water from the portion of the formation.
1676. The method of claim 1675, wherein removing water from the portion of the formation comprises using one or more dewatering wells.
1677. The method of claim 1671, wherein reducing the pressure comprises drawing a vacuum.
1678. The method of claim 1671, wherein providing a barrier comprises:
providing refrigerant to a plurality of freeze wells to form a low temperature zone around at least a portion of the portion; and lowering a temperature within the low temperature zone to a temperature less than about a freezing temperature of water.
1679. The method of claim 1671, wherein providing a barrier comprises providing refrigerant to a plurality of freeze wells to form a frozen barrier zone and wherein the frozen barrier zone at least partially inhibits fluids from flowing into or out of the portion.
1680. The method of claim 1671, wherein an average temperature of at least one portion of the formation is less than about a boiling point of water at formation conditions.
1681. The method of claim 1671, wherein an average temperature of at least one portion of the formation is less than about 100 °C.
1682. A method of treating a hydrocarbon containing formation in situ, comprising:
providing a first barrier to a first portion of the formation, wherein the first portion comprises methane;
removing water from the first portion;
producing fluids from the first portion, wherein produced fluids from the first portion comprise methane;
providing a second barrier to a second portion of the formation, wherein the second portion comprises methane;
removing water from the second portion, and then transferring at least a portion of such water to the first portion;
providing carbon dioxide to the second portion of the formation; and producing fluids from the second portion, wherein produced fluids from the second portion comprise methane.
1683. The method of claim 1682, further comprising providing carbon dioxide to the first portion of the formation.
1684. The method of claim 1683, wherein at least some of the carbon dioxide provided to the first portion displaces methane.
1685. The method of claim 1682, wherein at least some of the carbon dioxide displaces methane.
1686. The method of claim 1682, wherein providing a first barrier comprises:
providing refrigerant to a plurality of freeze wells to form a low temperature zone around the first portion;
and lowering a temperature within the low temperature zone to a temperature less than about a freezing temperature of water.
1687. The method of claim 1682, wherein providing a second barrier comprises:
providing refrigerant to a plurality of freeze wells to form a low temperature zone around the second portion; and lowering a temperature within the low temperature zone to a temperature less than about a freezing temperature of water.
1688. The method of claim 1682, wherein providing a first barrier comprises providing refrigerant to a plurality of freeze wells to form a frozen barrier zone and wherein the frozen barrier zone at least partially inhibits fluids from flowing into or out of the portion.
1689. The method of claim 1682, wherein providing a second barrier comprises providing refrigerant to a plurality of freeze wells to form a frozen barrier zone and wherein the frozen barrier zone at least partially inhibits fluids from flowing into or out of the portion.
1690. The method of claim 1682, further comprising:
providing heat from one or more heaters to at least one portion of the formation; and allowing the heat to transfer from at least one of the heaters to a part of the formation.
1691. A heating system, comprising:
an electrical conductor configured to generate an electrically resistive heat output during application of electrical current to the electrical conductor, wherein the electrical conductor comprises an electrically resistive ferromagnetic material;
a conduit at least partially surrounding the electrical conductor;
a fluid located in a space between the electrical conductor and the conduit, wherein the fluid has a higher thermal conductivity than air at 1 atm and a temperature in the space; and wherein the heating system is configured to provide a reduced amount of heat above or near a selected temperature.
1692. The heating system of claim 1691, wherein the electrical conductor at least partially surrounds a non-ferromagnetic material.
1693. The heating system of claim 1691, wherein the fluid comprises an electrically insulating fluid.
1694. The heating system of claim 1691, wherein the fluid comprises helium.
1695. The heating system of claim 1691, wherein the fluid comprises helium, and wherein the space between the electrical conductor and the conduit comprises at least about 50% by volume helium.
1696. The heating system of claim 1691, wherein the fluid comprises helium, and wherein the space between the electrical conductor and the conduit comprises at least about 75% by volume helium.
1697. The heating system of claim 1691, wherein the fluid comprises helium, and wherein the space between the electrical conductor and the conduit comprises at least about 90% by volume helium.
1698. The heating system of claim 1691, wherein a fluid pressure in the space between the electrical conductor and the conduit is at least about 5 atm.
1699. The heating system of claim 1691, wherein a fluid pressure in the space between the electrical conductor and the conduit is at least about 7 atm.
1700. The heating system of claim 1691, wherein a fluid pressure in the space between the electrical conductor and the conduit is at least about 10 atm.
1701. The heating system of claim 1691, further comprising an AC power supply.
2702. The heating system of claim 2691, further comprising a modulated DC
power supply.
1703. The heating system of claim 1691, further comprising a centralizer configured to maintain a separation distance between the electrical conductor and the conduit.
1704. The heating system of claim 1691, wherein the heating system is configured to allow heat to transfer from the heater to a part of a subsurface formation to pyrolyze at least some hydrocarbons in the subsurface formation.
1705. The heating system of claim 1691, wherein the heater is configured to be placed in an opening in a subsurface formation.
1706. The heating system of claim 1691, wherein a resistance of the ferromagnetic material decreases above the selected temperature such that the heater provides the reduced amount of heat above the selected temperature.
1707. A method of heating a subsurface formation, comprising:
providing electrical current to an electrical conductor to provide an electrically resistive heat output, wherein the electrical conductor comprises an electrically resistive ferromagnetic material, wherein a conduit at least partially surrounds the electrical conductor, wherein a fluid is located in a space between the electrical conductor and the conduit, and wherein the fluid has a higher thermal conductivity than air at 1 atm and a temperature in the space; and allowing heat to transfer from the electrical conductor to at least part of the subsurface formation such that the electrical conductor provides a reduced amount of heat above or near a selected temperature.
1708. The method of claim 1707, wherein the electrical conductor at least partially surrounds a non-ferromagnetic material.
1709. The method of claim 1707, wherein the fluid comprises an electrically insulating fluid.
1710. The method of claim 1707, wherein the fluid comprises helium.
1711. The method of claim 1707, wherein the fluid comprises helium, and wherein the space between the electrical conductor and the conduit comprises at least about 50% by volume helium.
1712. The method of claim 1707, wherein the fluid comprises helium, and wherein the space between the electrical conductor and the conduit comprises at least about 75% by volume helium.
1713. The method of claim 1707, wherein the fluid comprises helium, and wherein the space between the electrical conductor and the conduit comprises at least about 90% by volume helium.
1714. The method of claim 1707, wherein a fluid pressure in the space between the electrical conductor and the conduit is at least about 5 atm.
1715. The method of claim 1707, wherein a fluid pressure in the space between the electrical conductor and the conduit is at least about 7 atm.
1716. The method of claim 1707, wherein a fluid pressure in the space between the electrical conductor and the conduit is at least about 10 atm.
1717. The method of claim 1707, further comprising providing the electrical current from an AC power supply.
1718. The method of claim 1707, further comprising providing the electrical current from a modulated DC power supply.
1719. The method of claim 1707, wherein the reduced amount of heat is provided without adjusting the amperage of the electrical current applied to the electrical conductor.
1720. The method of claim 1707, further comprising providing an initial electrically resistive heat output when the electrical conductor providing the heat output is at least about 50 °C below the selected temperature, and automatically providing the reduced amount of heat above or near the selected temperature.
1721. The method of claim 1707, further comprising placing the electrical conductor in a wellbore in the subsurface formation.
1722. The method of claim 1707, wherein heat output from the electrical conductor is substantially constant when a temperature of the electrical conductor is between about 100 °C
and 750 °C.
1723. A heating system, comprising:
an electrical conductor configured to generate an electrically resistive heat output when electrical current is applied to the electrical conductor, wherein the electrical conductor comprises an electrically resistive ferromagnetic material;
a conduit surrounding the electrical conductor;
a fluid located in a space between the electrical conductor and the conduit, wherein the fluid has a higher thermal conductivity than air at 1 atm and a temperature in the space; and wherein the heating system is configured to provide a reduced amount of heat above or near a selected temperature that is about 20% or less of the heat output at about 50 °C
below the selected temperature.
1724. A system configured to heat at least a part of a subsurface formation, comprising:
an electrical power supply, wherein the electrical power supply is configured to provide a modulated electrical current;
one or more electrical conductors configured to be electrically coupled to the electrical power supply and placed in an opening in the formation, wherein at least one of the electrical conductors comprises a heater section, the heater section comprising an electrically resistive ferromagnetic material configured to provide an electrically resistive heat output when the modulated electrical current is applied to the ferromagnetic material, and wherein the heater section is configured to provide a reduced amount of heat near or above a selected temperature during use due to the decreasing electrical resistance of the heater section when the temperature of the ferromagnetic material is near or above the selected temperature; and wherein the system is configured to allow heat to transfer from the heater section to a part of the formation.
1725. The system of claim 1724, wherein the electrical power supply is configured to provide modulated direct current (DC).
1726. The system of claim 1724, wherein the electrical power supply comprises a variable frequency DC
electrical power supply.
1727. The system of claim 1724, wherein the electrical power supply is configured to provide DC, and wherein the electrical power supply is further configured to modulate the frequency of the DC.
1728. The system of claim 1724, wherein the electrical power supply is configured to provide square wave modulated DC.
1729. The system of claim 1724, wherein the heater section automatically provides a reduced amount of heat above or near the selected temperature.
1730. The system of claim 1724, wherein at least a portion of the heater section is positionable adjacent to hydrocarbon material in the formation to raise a temperature of at least some of the hydrocarbon material to or above a pyrolysis temperature.
1731. The system of claim 1724, wherein the heater section is configured to exhibit an increase in operating temperature of less than about 1.5 °C above or near a selected operating temperature when a thermal load proximate the heater section decreases by about 1 watt per meter.
1732. The system of claim 1724, wherein at least one of the electrical conductors is configured to provide a reduced amount of heat above or near the selected temperature that is about 20% or less of the heat output at about 50 °C below the selected temperature.
1733. The system of claim 1724, wherein the electrical resistance of the heater section decreases above the selected temperature to provide the reduced amount of heat.
1734. The system of claim 1724, further comprising a non-ferromagnetic material coupled to the ferromagnetic material, wherein the non-ferromagnetic material has a higher electrical conductivity than the ferromagnetic material.
1735. The system of claim 1724, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1736. The system of claim 1724, wherein the ferromagnetic material has a turndown ratio of at least about 2 to 1.
1737. The system of claim 1724, wherein the ferromagnetic material comprises iron, nickel, chromium, cobalt, tungsten, or a mixture thereof.
1738. The system of claim 1724, wherein at least a portion of at least one electrically resistive ferromagnetic material is longer than about 10 m.
1739. The system of claim 1724, wherein at least one of the electrical conductors is elongated and configured such that only electrically resistive sections at or near the selected temperature will automatically reduce the heat output.
1740. The system of claim 1724, wherein the ferromagnetic material is configured to radiatively heat the formation.
1741. A method for heating a subsurface formation, comprising:
applying modulated electrical current to one or more electrical conductors located in the subsurface formation to provide an electrically resistive heat output, wherein at least one of the electrical conductors comprises an electrically resistive ferromagnetic material that provides heat when modulated electrical current flows through the electrically resistive ferromagnetic material, and wherein such electrical conductor comprising electrically resistive ferromagnetic material provides a reduced amount of heat above or near a selected temperature; and allowing the heat to transfer from the electrically resistive ferromagnetic material to a part of the subsurface formation.
1742. The method of claim 1741, wherein the modulated electrical current comprises modulated direct current (DC).
1743. The method of claim 1741, wherein the modulated electrical current comprises square wave modulated DC.
1744. The method of claim 1741, further comprising varying a frequency of the modulated electrical current.
1745. The method of claim 1741, wherein the electrically resistive ferromagnetic material automatically provides a selected reduced amount of heat above or near a selected temperature.
1746. The method of claim 1741, further comprising placing one or more of the electrical conductors in a wellbore in the formation.
1747. The method of claim 1741, wherein an electrical resistance of the ferromagnetic material decreases above the selected temperature to provide the reduced amount of heat.
1748. The method of claim 1741, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1749. The method of claim 1741, wherein the subsurface formation comprises a hydrocarbon containing formation.
1750. The method of claim 1741, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising heating at least some hydrocarbons in the formation such that at least some of the hydrocarbons are pyrolyzed.
1751. The method of claim 1741, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1752. The method of claim 1741, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising controlling the provided heat to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1753. The method of claim 1741, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising heating at least a portion of the part of the formation to a minimum pyrolysis temperature of about 270 °C.
1754. The method of claim 1741, further comprising controlling a skin depth in the ferromagnetic material by controlling a modulation of the applied electrical current.
1755. The method of claim 1741, further comprising producing fluids from the formation, and blending the produced fluids with hydrocarbons having an API gravity below about 15°.
1756. A system configured to heat at least a part of a subsurface formation, comprising:
an electrical power supply;
one or more electrical conductors configured to be electrically coupled to the electrical power supply and placed in an opening in the formation, wherein at least one of the electrical conductors comprises a heater section, the heater section comprising an electrically resistive ferromagnetic material configured to provide an electrically resistive heat output when electrical current is applied to the ferromagnetic material, and wherein the heater section is configured to provide a reduced amount of heat near or above a selected temperature during use due to the decreasing electrical resistance of the heater section when the temperature of the ferromagnetic material is near or above the selected temperature;
wherein the system is configured to allow heat to transfer from the heater section to a part of the formation;
and wherein the electrical power supply is configured to provide a relatively constant amount of electrical current that remains within about 15% of a selected constant current value when a load of the electrical conductors changes.
1757. The system of claim 1756, wherein the electrical power supply is configured to provide a relatively constant amount of electrical current that remains within about 10% of a selected constant current value when a load of the electrical conductors changes.
1758. The system of claim 1756, wherein the electrical power supply is configured to provide a relatively constant amount of electrical current that remains within about 5% of a selected constant current value when a load of the electrical conductors changes.
1759. The system of claim 1756, wherein the electrical power supply is configured to provide AC.
1760. The system of claim 1756, wherein the electrical power supply is configured to provide modulated direct current (DC).
1761. The system of claim 1756, wherein the electrical power supply comprises a variable frequency DC
electrical power supply.
1762. The system of claim 1756, wherein the electrical power supply is configured to provide DC, and wherein the electrical power supply is configured to modulate the frequency of the DC.
1763. The system of claim 1756, wherein the electrical power supply is configured to provide square wave modulated DC.
1764. The system of claim 1756, further comprising a variable capacitor coupled to the electrical power supply, wherein the variable capacitor is configured to maintain a power factor of the electrical conductors above about 0.85.
1765. The system of claim 1756, wherein the electrical power supply is configured to provide modulated DC in a pre-shaped waveform, and wherein the pre-shaped waveform is shaped to at least partially compensate for phase shift and/or harmonic distortions in the electrical conductors.
1766. The system of claim 1756, wherein the heater section automatically provides a reduced amount of heat above or near the selected temperature.
1767. The system of claim 1756, wherein at least a portion of the heater section is positionable adjacent to hydrocarbon material in the formation to raise a temperature of at least some of the hydrocarbon material to or above a pyrolysis temperature.
1768. The system of claim 1756, wherein the heater section is configured to exhibit an increase in operating temperature of less than about 1.5 °C above or near a selected operating temperature when a thermal load proximate the heater section decreases by about 1 watt per meter.
1769. The system of claim 1756, wherein at least one of the electrical conductors is configured to provide a reduced amount of heat above or near the selected temperature that is about 20% or less of the heat output at about 50 °C below the selected temperature.
1770. The system of claim 1756, wherein the electrical resistance of the heater section decreases above the selected temperature to provide the reduced amount of heat.
1771. The system of claim 1756, further comprising a non-ferromagnetic material coupled to the ferromagnetic material, wherein the non-ferromagnetic material has a higher electrical conductivity than the ferromagnetic material.
1772. The system of claim 1756, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1773. The system of claim 1756, wherein the ferromagnetic material has a turndown ratio of at least about 2 to 1.
1774. The system of claim 1756, wherein the ferromagnetic material comprises iron, nickel, chromium, cobalt, tungsten, or a mixture thereof.
1775. The system of claim 1756, wherein at least a portion of at least one electrically resistive ferromagnetic material is longer than about 10 m.
1776. The system of claim 1756, wherein at least one of the electrical conductors is elongated and configured such that only electrically resistive sections at or near the selected temperature will automatically reduce the heat output.
1777. The system of claim 1756, wherein the ferromagnetic material is configured to radiatively heat the formation.
1778. A method for heating a subsurface formation, comprising:
applying electrical current to one or more electrical conductors located in the subsurface formation to provide an electrically resistive heat output, wherein at least one of the electrical conductors comprises an electrically resistive ferromagnetic material that provides heat when electrical current flows through the electrically resistive ferromagnetic material, and wherein such electrical conductor comprising electrically resistive ferromagnetic material provides a reduced amount of heat above or near a selected temperature; and allowing the heat to transfer from the electrically resistive ferromagnetic material to a part of the subsurface formation; and wherein the applied electrical current remains within about 15% of a selected constant current value when a load of the electrical conductors changes.
1779. The method of claim 1778, wherein the applied electrical current remains within about 10% of a selected constant current value when a load of the electrical conductors changes.
1780. The method of claim 1778, wherein the applied electrical current remains within about 5% of a selected constant current value when a load of the electrical conductors changes.
1781. The method of claim 1778, wherein the electrical current comprises alternating current.
1782. The method of claim 1778, wherein the electrical current comprises modulated direct current (DC).
1783. The method of claim 1778, wherein the electrical current comprises square wave modulated DC.
1784. The method of claim 1778, further comprising varying a frequency of the electrical current.
1785. The method of claim 1778, further comprising applying a capacitive load to the electrical conductors to maintain a power factor of the electrical conductors above about 0.85.
1786. The method of claim 1778, further comprising applying modulated DC
electrical current in a pre-shaped waveform, wherein the pre-shaped waveform is shaped to at least partially compensate for phase shift and/or harmonic distortions in the electrical conductors.
1787. The method of claim 1778, wherein the electrically resistive ferromagnetic material automatically provides a selected reduced amount of heat above or near a selected temperature.
1788. The method of claim 1778, further comprising placing one or more of the electrical conductors in a wellbore in the formation.
1789. The method of claim 1778, wherein an electrical resistance of the ferromagnetic material decreases above the selected temperature to provide the reduced amount of heat.
1790. The method of claim 1778, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1791. The method of claim 1778, wherein the subsurface formation comprises a hydrocarbon containing formation.
1792. The method of claim 1778, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising heating at least some hydrocarbons in the formation such that at least some of the hydrocarbons are pyrolyzed.
1793. The method of claim 1778, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1794. The method of claim 1778, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising controlling the provided heat to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1795. The method of claim 1778, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising heating at least a portion of the part of the formation to a minimum pyrolysis temperature of about 270 °C.
1796. The method of claim 1778, further comprising controlling a skin depth in the ferromagnetic material by controlling a frequency of the applied electrical current.
1797. The method of claim 1778, further comprising producing fluids from the formation, and blending the produced fluids with hydrocarbons having an API gravity below about 15°.
1798. A heating system configured to heat at least a part of a subsurface formation, comprising:
an electrical power supply;
one or more electrical conductors configured to be electrically coupled to the electrical power supply and placed in an opening in the formation, wherein at least one of the electrical conductors comprises a heater section, the heater section comprising an electrically resistive ferromagnetic material configured to provide an electrically resistive heat output when electrical current is applied to the ferromagnetic material, and wherein the heater section is configured to provide a reduced amount of heat near or above a selected temperature during use due to the decreasing electrical resistance of the heater section when the temperature of the ferromagnetic material is near or above the selected temperature;
a variable capacitor, wherein the variable capacitor is configured maintain a power factor of the electrical conductors above about 0.85 during use; and wherein the system is configured to allow heat to transfer from the heater section to a part of the formation.
1799. The system of claim 1798, wherein the variable capacitor is configured maintain the power factor of the electrical conductors above about 0.9 during use.
1800. The system of claim 1798, wherein the variable capacitor is configured maintain the power factor of the electrical conductors above about 0.95 during use.
1801. The system of claim 1798, wherein a capacitance of the variable capacitor is varied to maintain the power factor of the electrical conductors above about 0.85 during use.
1802. The system of claim 1798, wherein the electrical power supply is configured to provide a relatively constant amount of electrical current that remains within about 15% of a selected constant current value when a load of the electrical conductors changes.
1803. The system of claim 1798, wherein the electrical power supply is configured to provide AC.
1804. The system of claim 1798, wherein the electrical power supply is configured to provide modulated direct current (DC).
1805. The system of claim 1798, wherein the electrical power supply comprises a variable frequency DC
electrical power supply.
1806. The system of claim 1798, wherein the electrical power supply is configured to provide DC, and wherein the electrical power supply is configured to modulate the frequency of the DC.
1807. The system of claim 1798, wherein the electrical power supply is configured to provide square wave modulated DC.
1808. The system of claim 1798, wherein the electrical power supply is configured to provide modulated DC in a pre-shaped waveform, and wherein the pre-shaped waveform is shaped to at least partially compensate for phase shift and/or harmonic distortions in the electrical conductors.
1809. The system of claim 1798, wherein the heater section automatically provides a reduced amount of heat above or near the selected temperature.
1810, The system of claim 1798, wherein at least a portion of the heater section is positionable adjacent to hydrocarbon material in the formation to raise a temperature of at least some of the hydrocarbon material to or above a pyrolysis temperature.
1811. The system of claim 1798, wherein the heater section is configured to exhibit an increase in operating temperature of less than about 1.5 °C above or near a selected operating temperature when a thermal load proximate the heater section decreases by about 1 watt per meter.
1812. The system of claim 1798, wherein at least one of the electrical conductors is configured to provide a reduced amount of heat above or near the selected temperature that is about 20% or less of the heat output at about 50 °C below the selected temperature.
1813. The system of claim 1798, wherein the electrical resistance of the heater section decreases above the selected temperature to provide the reduced amount of heat.
1814. The system of claim 1798, further comprising a non-ferromagnetic material coupled to the ferromagnetic material, wherein the non-ferromagnetic material has a higher electrical conductivity than the ferromagnetic material.
1815. The system of claim 1798, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1816. The system of claim 1798, wherein the ferromagnetic material has a turndown ratio of at least about 2 to 1.
1817. The system of claim 1798, wherein the ferromagnetic material comprises iron, nickel, chromium, cobalt, tungsten, or a mixture thereof.
1818. The system of claim 1798, wherein at least a portion of at least one electrically resistive ferromagnetic material is longer than about 10 m.
1819. The system of claim 1798, wherein at least one of the electrical conductors is elongated and configured such that only electrically resistive sections at or near the selected temperature will automatically reduce the heat output.
182. The system of claim 1798, wherein the ferromagnetic material is configured to radiatively heat the formation.
1821. A method for heating a subsurface formation, comprising:
applying electrical current from an electrical power supply to one or more electrical conductors located in the subsurface formation to provide an electrically resistive heat output, wherein at least one of the electrical conductors comprises an electrically resistive ferromagnetic material that provides heat when electrical current flows through the electrically resistive ferromagnetic material, and wherein such electrical conductor comprising electrically resistive ferromagnetic material provides a reduced amount of heat above or near a selected temperature; and allowing the heat to transfer from the electrically resistive ferromagnetic material to a part of the subsurface formation; and applying a capacitive load to the electrical conductors to maintain a power factor of the electrical conductors above about 0.85.
1822. The method of claim 1821, applying the capacitive load to the electrical conductors to maintain the power factor of the electrical conductors above about 0.9.
1823. The method of claim 1821, applying the capacitive load to the electrical conductors to maintain the power factor of the electrical conductors above about 0.95.
1824. The method of claim 1821, further comprising varying the capacitive load to maintain the power factor of the electrical conductors above about 0.85.
1825. The method of claim 1821, wherein the applied electrical current remains within about 15% of a selected constant current value when a load of the electrical conductors changes.
1826. The method of claim 1821, wherein the electrical current comprises alternating current.
1827. The method of claim 1821, wherein the electrical current comprises modulated direct current (DC).
1828. The method of claim 1821, wherein the electrical current comprises square wave modulated DC.
1829. The method of claim 1821, further comprising varying a frequency of the electrical current.
1830. The method of claim 1821, further comprising applying modulated DC
electrical current in a pre-shaped waveform, wherein the pre-shaped waveform is shaped to at least partially compensate for phase shift and/or harmonic distortions in the electrical conductors 1831. The method of claim 1821, wherein the electrically resistive ferromagnetic material automatically provides a selected reduced amount of heat above or near a selected temperature.
1832. The method of claim 1821, further comprising placing one or more of the electrical conductors in a wellbore in the formation.
1833. The method of claim 1821, wherein an electrical resistance of the ferromagnetic material decreases above the selected temperature to provide the reduced amount of heat.
1834. The method of claim 1821, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1835. The method of claim 1821, wherein the subsurface formation comprises a hydrocarbon containing formation.
1836. The method of claim 1821, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising heating at least some hydrocarbons in the formation such that at least some of the hydrocarbons are pyrolyzed.
1837. The method of claim 1821, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1838. The method of claim 1821, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising controlling the provided heat to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1839. The method of claim 1821, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising heating at least a portion of the part of the formation to a minimum pyrolysis temperature of about 270 °C.
1840. The method of claim 1821, further comprising controlling a skin depth in the ferromagnetic material by controlling a frequency of the applied electrical current.
1841. The method of claim 1821, further comprising producing fluids from the formation, and blending the produced fluids with hydrocarbons having an API gravity below about 15°.
1842. A heating system configured to heat at least a part of a subsurface formation, comprising:
an electrical power supply;
one or more electrical conductors configured to be electrically coupled to the electrical power supply and placed in an opening in the formation, wherein at least one of the electrical conductors comprises a heater section, the heater section comprising an electrically resistive ferromagnetic material configured to provide an electrically resistive heat output when electrical current is applied to the ferromagnetic material, and wherein the heater section is configured to provide a reduced amount of heat near or above a selected temperature during use due to the decreasing electrical resistance of the heater section when the temperature of the ferromagnetic material is near or above the selected temperature;
wherein the system is configured to allow heat to transfer from the heater section to a part of the formation;
and wherein the system is configured to allow a frequency of the applied electrical current to be varied.
1843. The system of claim 1842, wherein the frequency of the applied electrical current is configured to be varied based on one or more subsurface conditions at or near the electrical conductors.
1844. The system of claim 1842, wherein the frequency of the applied electrical current is configured to be varied as a function of a temperature at or near the electrical conductors in the subsurface formation.
1845. The system of claim 1842, wherein the frequency of the applied electrical current is configured to be varied to adjust a turndown ratio of the electrical conductors.
1846. The system of claim 1842, wherein the electrical power supply is configured to provide AC.
1847. The system of claim 1842, wherein the electrical power supply is configured to provide modulated direct current (DC).
1848. The system of claim 1842, wherein the electrical power supply comprises a variable frequency DC
electrical power supply.
1849. The system of claim 1842, wherein the electrical power supply is configured to provide DC, and wherein the electrical power supply is further configured to modulate the frequency of the DC.
1850. The system of claim 1842, wherein the electrical power supply is configured to provide square wave modulated DC.
1851. The system of claim 1842, wherein the electrical power supply is configured to provide modulated DC in a pre-shaped waveform, and wherein the pre-shaped waveform is shaped to at least partially compensate for phase shift and/or harmonic distortions in the electrical conductors.
1852. The system of claim 1842, wherein the heater section automatically provides a reduced amount of heat above or near the selected temperature.
1853. The system of claim 1842, wherein at least a portion of the heater section is positionable adjacent to hydrocarbon material in the formation to raise a temperature of at least some of the hydrocarbon material to or above a pyrolysis temperature.
1854. The system of claim 1842, wherein the heater section is configured to exhibit an increase in operating temperature of less than about 1.5 °C above or near a selected operating temperature when a thermal load proximate the heater section decreases by about 1 watt per meter.
1855. The system of claim 1842, wherein at least one of the electrical conductors is configured to provide a reduced amount of heat above or near the selected temperature that is about 20% or less of the heat output at about 50 °C below the selected temperature.
1856. The system of claim 1842, wherein the electrical resistance of the heater section decreases above the selected temperature to provide the reduced amount of heat.
1857. The system of claim 1842, further comprising a non-ferromagnetic material coupled to the ferromagnetic material, wherein the non-ferromagnetic material has a higher electrical conductivity than the ferromagnetic material.
1858. The system of claim 1842, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1859. The system of claim 1842, wherein the ferromagnetic material has a turndown ratio of at least about 2 to 1.
1860. The system of claim 1842, wherein the ferromagnetic material comprises iron, nickel, chromium, cobalt, tungsten, or a mixture thereof.
1861. The system of claim 1842, wherein at least a portion of at least one electrically resistive ferromagnetic material is longer than about 10 m.
1862. The system of claim 1842, wherein at least one of the electrical conductors is elongated and configured such that only electrically resistive sections at or near the selected temperature will automatically reduce the heat output.
1863. The system of claim 1842, wherein the ferromagnetic material is configured to radiatively heat the formation.
1864. A method for heating a subsurface formation, comprising:
applying electrical current to one or more electrical conductors located in the subsurface formation to provide an electrically resistive heat output, wherein at least one of the electrical conductors comprises an electrically resistive ferromagnetic material that provides heat when electrical current flows through the electrically resistive ferromagnetic material, and wherein such electrical conductor comprising electrically resistive ferromagnetic material provides a reduced amount of heat above or near a selected temperature;
allowing the heat to transfer from the electrically resistive ferromagnetic material to a part of the subsurface formation; and varying a frequency of the applied electrical current.
1865. The method of claim 1864, further comprising assessing one or more subsurface conditions at or near the electrical conductors in the subsurface formation and varying the frequency of the applied electrical current based on at least one assessed condition.
1866. The method of claim 1864, further comprising assessing a temperature at or near the electrical conductors in the subsurface formation and varying the frequency of the applied electrical current based on the assessed temperature.
1867. The method of claim 1864, further comprising varying the frequency of the applied electrical current to adjust a turndown ratio of the electrical conductors.
1868. The method of claim 1864, wherein the electrical current comprises alternating current.
1869. The method of claim 1864, wherein the electrical current comprises modulated direct current (DC).
1870. The method of claim 1864, wherein the electrical current comprises square wave modulated DC.
1871. The method of claim 1864, further comprising applying modulated DC
electrical current in a pre-shaped waveform, wherein the pre-shaped waveform is shaped to at least partially compensate for phase shift and/or harmonic distortions in the electrical conductors.
1872. The method of claim 1864, wherein the electrically resistive ferromagnetic material automatically provides a selected reduced amount of heat above or near the selected temperature.
1873. The method of claim 1864, further comprising placing one or more of the electrical conductors in a wellbore in the formation.
1874. The method of claim 1864, wherein an electrical resistance of the ferromagnetic material decreases above the selected temperature to provide the reduced amount of heat.
1875. The method of claim 1864, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1876. The method of claim 1864, wherein the subsurface formation comprises a hydrocarbon containing formation.
1877. The method of claim 1864, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising heating at least some hydrocarbons in the formation such that at least some of the hydrocarbons are pyrolyzed.
1878. The method of claim 2864, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1879. The method of claim 1864, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising controlling the provided heat to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1880. The method of claim 1864, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising heating at least a portion of the part of the formation to a minimum pyrolysis temperature of about 270 °C.
1881. The method of claim 1864, further comprising controlling a skin depth in the ferromagnetic material by controlling a frequency of the applied electrical current.
1882. The method of claim 1864, further comprising producing fluids from the formation, and blending the produced fluids with hydrocarbons having an API gravity below about 15°.
1883. A method for heating a subsurface formation, comprising:
applying substantially non-modulated direct electrical current (DC) to one or more electrical conductors located in the subsurface formation to provide an electrically resistive heat output, wherein at least one of the electrical conductors comprises an electrically resistive ferromagnetic material that provides heat when electrical current flows through the electrically resistive ferromagnetic material;
applying modulated DC or alternating current (AC) to the electrical conductors when a temperature of the electrical conductors approaches a Curie temperature of the electrically resistive ferromagnetic material so that the electrical conductors comprising electrically resistive ferromagnetic material provide a reduced amount of heat above or near a selected temperature; and allowing the heat to transfer from the electrically resistive ferromagnetic material to a part of the subsurface formation.
1884. The method of claim 1883, further comprising varying the frequency of the applied modulated DC or AC
to adjust a turndown ratio of the electrical conductors.
1885. The method of claim 1883, further comprising applying modulated DC in a pre-shaped waveform, wherein the pre-shaped waveform is shaped to at least partially compensate for phase shift and/or harmonic distortions in the electrical conductors.
1886. The method of claim 1883, wherein the electrically resistive ferromagnetic material automatically provides a selected reduced amount of heat above or near the selected temperature.
1887. The method of claim 1883, wherein an electrical resistance of the ferromagnetic material decreases above the selected temperature to provide the reduced amount of heat.
1888. The method of claim 1883, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1889. The method of claim 1883, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising heating at least some hydrocarbons in the formation such that at least some of the hydrocarbons are pyrolyzed.
1890. The method of claim 1883, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1891. The method of claim 1883, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising controlling the provided heat to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1892. The method of claim 1883, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising heating at least a portion of the part of the formation to a minimum pyrolysis temperature of about 270°C.
1893. The method of claim 1883, further comprising controlling a skin depth in the ferromagnetic material by controlling a frequency of the applied modulated DC or AC.
1894. The method of claim 1883, further comprising producing fluids from the formation, and blending the produced fluids with hydrocarbons having an API gravity below about 15°.
1895. A heater, comprising:
an inner electrical conductor;
a ferromagnetic conductor at least partially surrounding the inner electrical conductor, wherein the ferromagnetic conductor is configured to generate an electrically resistive heat output during application of electrical current to the ferromagnetic conductor, and wherein the ferromagnetic conductor comprises electrically resistive ferromagnetic material;
an outer electrical conductor at least partially surrounding the ferromagnetic conductor;
wherein an applied electrical current is configured to propagate through the inner electrical conductor and the outer electrical conductor in substantially the same direction, and wherein the applied electrical current is configured to propagate through the ferromagnetic conductor in a substantially opposite direction from the direction of applied electrical current in the inner electrical conductor and the outer electrical conductor; and wherein the heater is configured to provide a reduced amount of heat above or near a selected temperature.
1896. The heater of claim 1895, wherein the inner electrical conductor and the outer electrical conductor are electrically coupled at one end.
1897. The heater of claim 1895, wherein the inner electrical conductor comprises an electrically resistive, non-ferromagnetic material.
1898. The heater of claim 1895, wherein the outer electrical conductor comprises an electrically resistive, non-ferromagnetic material.
1899. The heater of claim 1895, further comprising an electrical insulator located between the inner electrical conductor and the ferromagnetic conductor.
1900. The heater of claim 1899, wherein the electrical insulator comprises silicon nitride.
1901. The heater of claim 1899, wherein the electrical insulator comprises boron nitride.
1902. The heater of claim 1895, further comprising an electrical insulator located between the ferromagnetic conductor and the outer electrical conductor.
1903. The heater of claim 1902, wherein the electrical insulator comprises silicon nitride.
1904. The heater of claim 1902, wherein the electrical insulator comprises boron nitride.
1905. The heater of claim 1895, wherein the applied electrical current comprises AC.
1906. The heater of claim 1895, wherein the applied electrical current comprises modulated DC.
1907. The heater of claim 1895, further comprising an AC power supply.
1908. The heater of claim 1895, further comprising a modulated DC power supply.
1909. The heater of claim 1895, wherein a thickness of the ferromagnetic conductor is at least about 2 times a skin depth of the applied electrical current.
1910. The heater of claim 1895, wherein the heater is configured to allow heat to transfer from the heater to a part of a subsurface formation to pyrolyze at least some hydrocarbons in the subsurface formation.
1911. The heater of claim 1895, wherein the heater is configured to be placed in an opening in a subsurface formation.
1912. The heater of claim 1895, wherein a resistance of the ferromagnetic material decreases above the selected temperature such that the heater provides the reduced amount of heat above the selected temperature.
1913. The heater of claim 1895, wherein the selected temperature is the Curie temperature of the ferromagnetic material.
1914. A method of heating a subsurface formation, comprising:
providing electrical current in a first direction to a ferromagnetic conductor to provide an electrically resistive heat output, wherein the ferromagnetic conductor comprises electrically resistive ferromagnetic material;
allowing electrical current to propagate in a second direction through an inner electrical conductor and an outer electrical conductor, wherein the ferromagnetic conductor at least partially surrounds the inner electrical conductor and is at least partially surrounded by the outer electrical conductor; and allowing heat to transfer from the ferromagnetic conductor to at least part of the subsurface formation such that the ferromagnetic conductor provides a reduced amount of heat above or near a selected temperature.
1915. The method of claim 1914, wherein the inner electrical conductor comprises an electrically resistive, non-ferromagnetic material.
1916. The method of claim 1914, wherein the outer electrical conductor comprises an electrically resistive, non-ferromagnetic material.
1917. The method of claim 1914, wherein the provided electrical current comprises AC.
1918. The method of claim 1914, wherein the provided electrical current comprises modulated DC.
1919. The method of claim 1914, further comprising providing the electrical current from an AC power supply.
1920. The method of claim 1914, further comprising providing the electrical current from a modulated DC power supply.
1921. The method of claim 1914, wherein the reduced amount of heat is provided without adjusting the amperage of the electrical current applied to the electrical conductor.
1922. The method of claim 1914, further comprising providing an initial electrically resistive heat output when the electrical conductor providing the heat output is at least about 50 °C below the selected temperature, and automatically providing the reduced amount of heat above or near the selected temperature.
1923. The method of claim 1914, further comprising placing the ferromagnetic conductor, the inner electrical conductor, and the outer electrical conductor in a wellbore in the subsurface formation.
1924. The method of claim 1914, wherein the ferromagnetic conductor is separated from the inner electrical conductor and the outer electrical conductor with an electrical insulator.
1925. The method of claim 1914, wherein heat output from the electrical conductor is substantially constant when a temperature of the electrical conductor is between about 100 °C
and 750 °C.
1926. A heater, comprising:
a first electrical conductor, wherein the first electrical conductor is configured to generate an electrically resistive heat output during application of electrical current to the first electrical conductor, and wherein the first electrical conductor comprises electrically resistive ferromagnetic material;
a second electrical conductor electrically coupled to the first electrical conductor, wherein the second electrical conductor comprises a non-ferromagnetic material with a lower electrical resistance than the first electrical conductor;
a support coupled to the first electrical conductor, wherein the support comprises a material with a relatively high creep strength at temperatures near a Curie temperature of the ferromagnetic material in the first electrical conductor; and wherein the heater is configured to provide a reduced amount of heat above or near a selected temperature.
1927. The heater of claim 1926, wherein the support is electrically coupled to the first electrical conductor.
1928. The heater of claim 1926, wherein the first electrical conductor, the second electrical conductor, and the support are metallurgically bonded together.
1929. The heater of claim 1926, wherein the first electrical conductor comprises 446 stainless steel.
1930. The heater of claim 1926, wherein the second electrical conductor comprises copper.
1931. The heater of claim 1926, wherein the support comprises 347H alloy.
1932. The heater of claim 1926, wherein the applied electrical current comprises AC.
1933. The heater of claim 1926, wherein the applied electrical current comprises modulated DC.
1934, The heater of claim 1926, wherein the selected temperature is the Curie temperature of the ferromagnetic material.
1935. The heater of claim 1926, wherein the heater comprises a turndown ratio greater than about 2.
1936. The heater of claim 1926, wherein the heater is configured to allow heat to transfer from the heater to a part of a subsurface formation to pyrolyze at least some hydrocarbons in the subsurface formation.
1937, The heater of claim 1926, wherein a resistance of the ferromagnetic material decreases above the selected temperature such that the heater provides the reduced amount of heat above the selected temperature.
1938. A method for treating a hydrocarbon containing formation, comprising:
providing heat from one or more heaters to at least a portion of the formation;
allowing the heat to transfer from one or more of the heaters to one or more zones of the formation; and controlling heating of the zones of the formation such that a heating rate of one or more zones is maintained below about 20°C/day for at least about 15 days.
1939, The method of claim 1938, further comprising controlling heating of the formation such that a heating rate of one or more zones is maintained below about 10°C/day for at least about 30 days.
1940. The method of claim 1938, further comprising controlling heating of the formation such that a heating rate of one or more zones is maintained below about 5°C/day for at least about 60 days.
1941. The method of claim 1938, further comprising assessing a permeability of the one or more zones in the formation and controlling the heating based on the assessed permeability.
1942. The method of claim 1941, wherein heating is controlled in zones with a permeability less than about 50 µdarcy.
1943. The method of claim 1941, wherein heating is controlled in zones with a permeability less than about 10 µdarcy.
1944. The method of claim 1938, further comprising assessing a clay content of the one or more zones in the formation and controlling the heating based on the assessed clay content.
1945. The method of claim 1944, wherein heating is controlled in zones with greater than about 5% smectite clay content by volume.
1946. The method of claim 1944, further comprising adding a clay stabilizer to zones with a smectite clay content greater than about 5% by volume.
1947. The method of claim 1938, wherein the zones are near one or more wellbores in the formation.
1948. The method of claim 1938, wherein heating is controlled within about 1 m of at least one of wellbore.
1949. The method of claim 1938, wherein heating is controlled within about 0.5 m of at least one of wellbore.
1950. The method of claim 1938, further comprising heating at least some hydrocarbons in the formation such that at least some of the hydrocarbons are pyrolyzed.
1951. The method of claim 1938, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1952. The method of claim 1938, further comprising controlling the provided heat to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1953. The method of claim 1938, further comprising heating at least a portion of the part of the formation to a minimum pyrolysis temperature of about 270 °C.
1954. A method for forming a heater wellbore in a hydrocarbon containing formation, comprising:
forming a wellbore in the formation;
providing an explosive system into the wellbore;
providing a controlled explosion using the explosive system in the wellbore such that at least some of the formation surrounding the wellbore has an increased permeability; and installing a heater in the wellbore.
1955. The method of claim 1954, further comprising removing exploded rubble from the wellbore, wherein the exploded rubble is formed by the controlled explosion.
1956. The method of claim 1954, wherein the controlled explosion comprises an elongated explosion along a portion of the length of the wellbore.
1957. The method of claim 1954, wherein the explosive system comprises an explosive cord system.
1958. The method of claim 1954, further comprising providing heat to the formation using one or more heaters placed in one or more wellbores in the formation.
1959. The method of claim 1954, further comprising providing heat to the formation and controlling heating of a zone of the formation near the wellbore such that a heating rate of the zone is maintained below about 20°C/day for at least about 15 days.
1960. The method of claim 1954, wherein the controlled explosion is provided at or near zones of the formation with a permeability less than about 10 µdarcy.
1961. The method of claim 1954, wherein the controlled explosion is provided at or near zones of the formation with a smectite clay content greater than about 5% by volume.
1962. The method of claim 1954, wherein the controlled explosion creates fractures out to a selected radius of from the wellbore, wherein the selected radius is greater than a coking distance from the wellbore during heating of the formation.
1963. The method of claim 1954, wherein the controlled explosion creates fractures out to a radius greater than a coking distance from the wellbore so that fluids are allowed to flow in the formation substantially coaxially with the wellbore in a region beyond the coking distance.
1964. The method of claim 1954, wherein the controlled explosion creates fractures out to a radius of about 2 m from the wellbore.
1965. The method of claim 1954, wherein the controlled explosion increases the permeability out to a radios of about 0.3 m from the wellbore.
1966. The method of claim 1954, further comprising heating at least some hydrocarbons in the formation such that at least some of the hydrocarbons are pyrolyzed.
1967. The method of claim 1954, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1968. The method of claim 1954, further comprising providing heat to the formation and controlling the provided heat to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1969. The method of claim 1954, further comprising heating at least a portion of the part of the formation to a minimum pyrolysis temperature of about 270 °C.
1970. A method for treating a hydrocarbon containing formation, comprising:
providing heat from one or more heaters to at least a portion of the formation, wherein at least one of the heaters is in at least one wellbore in the formation, wherein at least one of the wellbores has a liner placed between the heater in the wellbore and the formation, wherein the liner comprises openings that are sized such that fluids are allowed to pass through the liner but particles of a selected size are not allowed to pass through the liner;
allowing the heat to transfer from the one or more heaters to a part of the formation; and producing a mixture from the formation.
1971. The method of claim 1970, wherein the liner comprises carbon steel.
1972. The method of claim 1970, wherein the liner comprises a wire mesh.
1973. The method of claim 1970, wherein the liner comprises an expanded tubular.
1974. The method of claim 1970, wherein the liner is configured to inhibit formation material from contacting the heater.
1975. The method of claim 1970, wherein the liner has a diameter that is slightly smaller than a diameter of the wellbore.
1976. The method of claim 1970, wherein the liner is at least slightly deformable to allow particles to be trapped between the liner and a wall of the wellbore.
1977. The method of claim 1970, further comprising controlling heating of a zone of the formation near the wellbore such that a heating rate of the zone is maintained below about 20°C/day for at least about 15 days.
1978. The method of claim 1970, wherein the liner is located at or near zones of the formation with a permeability less than about 10 µdarcy.
1979. The method of claim 1970, wherein the liner is located at or near zones of the formation with a clay content greater than about 5% by volume.
1980. The method of claim 1970, further comprising heating at least some hydrocarbons in the formation such that at least some of the hydrocarbons are pyrolyzed.
1981. The method of claim 1970, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1982. The method of claim 1970, further comprising controlling the provided heat to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1983. The method of claim 1970, further comprising heating at least a portion of the part of the formation to a minimum pyrolysis temperature of about 270 °C.
1984. A method for treating a hydrocarbon containing formation, comprising:
providing heat from one or more heaters to at least a portion of the formation, wherein at least one of the heaters is in at least one wellbore in the formation, and wherein at least one of the wellbores has been sized, at least in part, such that an annulus between the wellbore and a heater in the wellbore has a width that inhibits particles of a selected size from freely moving in the annulus;
allowing the heat to transfer from the one or more heaters to a part of the formation; and producing a mixture from the formation.
1985. The method of claim 1984, wherein the annulus width is less than about 2.5 cm.
1986. The method of claim 1984, wherein the annulus width is less than about 1.5 cm.
1987. The method of claim 1984, further comprising controlling heating of a zone of the formation near the wellbore such that a heating rate of the zone is maintained below about 20°C/day for at least about 15 days.
1988. The method of claim 1984, wherein the annulus width is located at or near zones of the formation with a permeability less than about 10 µdarcy.
1989. The method of claim 1984, wherein the annulus width is located at or near zones of the formation with a clay content greater than about 5% by volume.
1990. The method of claim 1984, further comprising heating at least some hydrocarbons in the formation such that at least some of the hydrocarbons are pyrolyzed.
1991. The method of claim 1984, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1992. The method of claim 1984, further comprising controlling the provided heat to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1993. The method of claim 1984, further comprising heating at least a portion of the part of the formation to a minimum pyrolysis temperature of about 270 °C.
1994. A heating system configurable to heat a subsurface formation, comprising:
an electrical conductor configured to generate an electrically resistive heat output during application of electrical current to the electrical conductor;
an electrical insulator at least partially surrounding and in direct physical contact with the electrical conductor, wherein the electrical insulator comprises a nitride; and a sheath at least partially surrounding and in direct physical contact with the electrical insulator.
1995. The system of claim 1994, wherein the nitride comprises silicon nitride.
1996. The system of claim 1994, wherein the nitride comprises boron nitride.
1997. The system of claim 1994, wherein the electrical conductor comprises a copper-nickel alloy.
1998. The system of claim 1994, wherein the sheath comprises a corrosion-resistant material.
1999. The system of claim 1994, further comprising two additional electrical conductors, wherein the electrical conductor and the two additional electrical conductors are configurable in a 3-phase Wye configuration.
2000. The system of claim 1994, wherein the system is further configured to transfer heat such that the transferred heat can pyrolyze at least some hydrocarbons in a section of the formation.
2001. The system of claim 1994, wherein the electrical conductor comprises ferromagnetic material.
2002. The system of claim 1994, wherein the electrical conductor comprises ferromagnetic material, and wherein the system is configured to provide a reduced amount of heat above or near a selected temperature.
2003. An in situ method for heating a hydrocarbon containing formation, comprising:
applying an electrical current to an electrical conductor to provide heat to at least a portion of the formation, wherein the electrical conductor is located in an opening in the formation, wherein the electrical conductor is in direct physical contact with and at least partially surrounded by a nitride insulation layer, and wherein the nitride insulation layer is in direct physical contact with and at least partially surrounded by a sheath;
and allowing heat to transfer from the electrical conductor to a section of the formation.
2004. The method of claim 2003, wherein the nitride comprises silicon nitride.
2005. The method of claim 2003, wherein the nitride comprises boron nitride.
2006. The method of claim 2003, wherein the electrical conductor comprises a copper-nickel alloy.
2007. The method of claim 2003, wherein the sheath comprises a corrosion-resistant material.
2008. The method of claim 2003, wherein the electrical conductor comprises ferromagnetic material.
2009. The method of claim 2003, wherein the electrical conductor comprises ferromagnetic material, the method further comprising providing a reduced amount of heat above or near a selected temperature.
2010. The method of claim 2003, further comprising heating at least some hydrocarbons in the formation such that at least some of the hydrocarbons are pyrolyzed.
2012. The method of claim 2003, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
2013. The method of claim 2003, further comprising controlling the provided heat to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
2013. The method of claim 2003, further comprising heating at least a part of the formation to a minimum pyrolysis temperature of about 270 °C.
2014. A method for installing a temperature sensor in a conduit in a hydrocarbon containing formation, comprising:
providing a temperature sensor into a conduit in a wellbore in the formation;
providing a pressurized gas to the conduit to move the temperature sensor through the conduit using pressure from the pressurized gas; and locating the temperature sensor at a desired location in the conduit.
2015. The method of claim 2014, further comprising monitoring a temperature of a part of the formation using the temperature sensor.
2016. The method of claim 2014, wherein the temperature sensor comprises a fiber optic temperature sensor.
2017. The method of claim 2014, wherein the temperature sensor comprises a protective sleeve.
2018. The method of claim 2014, wherein the conduit is a center conductor of conductor-in-conduit heater.
2019. The method of claim 2014, wherein the conduit comprises holes at an end of the conduit.
2020. The method of claim 2014, wherein the conduit comprises an open end.
2021. The method of claim 2014, wherein the temperature sensor is configured to be removable from the conduit.
2022. The method of claim 2014, further comprising moving the temperature sensor a desired distance with the pressurized gas.
2023. The method of claim 2014, further comprising providing heat to the formation and heating at least some hydrocarbons in the formation such that at least some of the hydrocarbons are pyrolyzed.
2024. The method of claim 2014, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
2025. The method of claim 2014, further comprising providing heat to the formation and controlling the provided heat to inhibit, production of hydrocarbons from the formation having carbon numbers greater than about 25.
2026. The method of claim 2014, further comprising providing heat to at least a part of the formation to heat the portion to a minimum pyrolysis temperature of about 270 °C.
2027. A method for treating a hydrocarbon containing formation, comprising:
providing heat from one or more heaters to at least a portion of the formation;
allowing the heat to transfer from the one or more heaters to a part of the formation; and producing a mixture from the formation through a production conduit in a production wellbore, wherein the production conduit comprises one or more collection devices located in an overburden section of the production conduit, and wherein the collection devices are configured to collect fluids that condense in the overburden section.
2028. The method of claim 2027, wherein the collection devices comprise baffles.
2029. The method of claim 2027, further comprising collecting condensed fluids in the collection devices.
2030. The method of claim 2027, further comprising removing condensed fluids from the collection devices.
2031. The method of claim 2027, further comprising removing condensed fluids from the collection devices using a pump.
2032. The method of claim 2027, wherein the collection devices inhibit condensed fluids from refluxing into the formation.
2033. The method of claim 2027, wherein the overburden section comprises a depth greater than about 500 feet (about 150 m).
2034. The method of claim 2027, further comprising providing heat from a heater in the production wellbore to maintain at least some of the fluids in a vapor phase below the overburden section.
2035. The method of claim 2027, further comprising producing non-condensed fluids through the production conduit.
2036. The method of claim 2027, further comprising allowing water and high boiling point fluids to condense along the walls of the production conduit in the overburden section.
2037. A method for treating a hydrocarbon containing formation, comprising:
applying electrical current to one or more electrical conductors located in an opening in the formation to provide an electrically resistive heat output;
allowing the heat to transfer from the electrical conductors to a part of the formation containing hydrocarbons so that a viscosity of fluids in the part at or near the opening in the formation is reduced;
providing a gas at one or more locations in the opening to reduce the density of the fluids so that the fluids are lifted in the opening towards the surface of the formation by the formation pressure; and producing the fluids through the opening.
2038. The method of claim 2037, further comprising placing the one or more electrical conductors in the opening.
2039. The method of claim 2037, wherein the viscosity of fluids at or near the opening is reduced to less than about 50 centipoise.
2040. The method of claim 2037, further comprising producing at least some fluids from the opening by pumping the fluids from the opening.
2041. The method of claim 2037, wherein the gas comprises methane.
2042. The method of claim 2037, further comprising producing the fluids from the opening through a conduit located in the opening.
2043. The method of claim 2037, further comprising producing the fluids from the opening through a conduit located in the opening, and providing the gas through one or more valves located along the conduit.
2044. The method of claim 2037, further comprising limiting a temperature in the formation at or near the opening to less than about 250 °C.
2045. The method of claim 2037, further comprising applying AC to the one or more electrical conductors.
2046. The method of claim 2037, further comprising applying modulated DC to the one or more electrical conductors.
2047. The method of claim 2037, wherein at least one of the electrical conductors comprises an electrically resistive ferromagnetic material that provides heat when electrical current flows through the electrically resistive ferromagnetic material, and wherein the electrically resistive ferromagnetic material provides a reduced amount of heat above or near a selected temperature.
2048. The method of claim 2047, wherein the ferromagnetic material automatically provides the reduced amount of heat above or near the selected temperature.
2049. The method of claim 2047, further comprising providing an initial electrically resistive heat output when the electrical conductor providing the heat output is at least about 50 °C below the selected temperature, and automatically providing the reduced amount of heat above or near the selected temperature.
2050. The method of claim 2047, wherein the electrically resistive ferromagnetic material automatically provides a selected reduced amount of heat above or near a selected temperature.
2051. The method of claim 2047, wherein an electrical resistance of the ferromagnetic material decreases above the selected temperature to provide the reduced amount of heat.
2052. The method of claim 2047, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
2053. The method of claim 2047, wherein the selected temperature is less than about 300 °C.
2054. The method of claim 2047, further comprising providing a reduced amount of heat above or near the selected temperature of less than about 200 watts per meter of length of an electrical conductor.
2055. The method of claim 2047, further comprising providing a heat output below the selected temperature of greater than about 300 watts per meter of length of an electrical conductor.
2056. The method of claim 2047, further comprising providing a heat output from at least one of the electrical conductors, wherein an electrical resistance of such electrical conductors above or near the selected temperature is about 80% or less of the electrical resistance of such electrical conductors at about 50 °C below the selected temperature.
2057. The method of claim 2047, further comprising controlling a skin depth in the ferromagnetic material by controlling a modulation of the applied electrical current.
2058. The method of claim 2037, wherein the hydrocarbon containing formation comprises a relatively permeable formation containing heavy hydrocarbons.
353. The method of claim 330, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising controlling a pressure in at least a part of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.
354. The method of claim 330, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising controlling formation conditions such that a produced mixture comprises a partial pressure of H2 greater than about 0.5 bars.
355. The method of claim 330, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising altering a pressure in the formation to inhibit production of hydrocarbons having carbon numbers greater than about 25.
356. The method of claim 330, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising controlling the provided heat to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
357. The method of claim 330, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising heating at least a portion of the part of the formation to a minimum pyrolysis temperature of about 270 °C.
358. The method of claim 330, further comprising controlling a skin depth in the ferromagnetic material by controlling a frequency of the applied AC.
359. The method of claim 330, further comprising increasing the AC applied to at least one of the electrical conductors as the temperature of such electrical conductors increases, and continuing to do so until the temperature is at or near the selected temperature.
360. The method of claim 330, further comprising controlling an amount of current applied to at least one of the electrical conductors to control an amount of heat output from such electrical conductors.
361. The method of claim 330, further comprising increasing an amount of current applied to at least one of the electrical conductors to decrease an amount of heat output from such electrical conductors.
362. The method of claim 330, further comprising decreasing an amount of current applied to at least one of the electrical conductors to increase an amount of heat output from such electrical conductors.
363. The method of claim 330, further comprising producing fluids from the formation, and producing refined products from the produced fluids.
364. The method of claim 330, further comprising producing fluids from the formation, and producing a blending agent from the produced fluids.
365. The method of claim 330, further comprising providing heat from at least one of the electrical conductors to fluids in a wellbore in the formation.
366. The method of claim 330, further comprising producing fluids from the formation, and blending the produced fluids with hydrocarbons having an API gravity below about 15°.
367. A method for heating a subsurface formation, comprising:
applying AC to one or more electrical conductors placed in an opening in the formation, wherein at least one of the electrical conductors comprises one or more electrically resistive sections;
providing an electrically resistive heat output from at least one of the electrically resistive sections, wherein such electrically resistive sections provide a reduced amount of heat above or near a selected temperature that is about 20% or less of the heat output at about 50 °C below the selected temperature; and allowing the heat to transfer from at least one of the electrically resistive sections to at least a part of the formation.
368. The method of claim 367, further comprising applying the AC at a frequency of about 180 Hz.
369. The method of claim 367, further comprising placing one or more of the electrical conductors in the opening.
370. The method of claim 367, further comprising providing an initial electrically resistive heat output when the electrically resistive section providing the heat output is at least about 50 °C below the selected temperature, and automatically providing the reduced amount of heat above or near the selected temperature.
371. The method of claim 367, further comprising providing a reduced amount of heat above or near the selected temperature that is less than about 20% of the heat output at about 40 °C below the selected temperature.
372. The method of claim 367, further comprising providing a reduced amount of heat above or near the selected temperature that is less than about 20% of the heat output at about 30 °C below the selected temperature.
373. The method of claim 367, further comprising providing a reduced amount of heat above or near the selected temperature that is less than about 15% of the heat output at about 50 °C below the selected temperature.
374. The method of claim 367, further comprising providing a reduced amount of heat above or near the selected temperature that is less than about 10% of the heat output at about 50 °C below the selected temperature.
375. The method of claim 367, further comprising allowing the heat to transfer radiatively from at least one of the electrically resistive sections to at least a part of the formation.
376. The method of claim 367, wherein at least one of the electrically resistive sections comprises ferromagnetic material, and wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
377. The method of claim 367, wherein at least one of the electrically resistive sections comprises ferromagnetic material, and wherein the selected temperature is within about 50 °C of the Curie temperature of the ferromagnetic material.
378. The method of claim 367, further comprising providing a relatively constant heat output from one or more of the electrically resistive sections when such electrically resistive sections are in a temperature range between about 100 °C and about 750 °C.
379. The method of claim 367, further comprising automatically decreasing an AC resistance of at least one of the electrically resistive sections when such an electrically resistive section is above the selected temperature to provide the reduced amount of heat above the selected temperature.
380. The method of claim 367, wherein the subsurface formation comprises a hydrocarbon containing formation.
381. The method of claim 367, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising heating at least some hydrocarbons in the formation to pyrolyze at some of the hydrocarbons in the formation.
382. The method of claim 367, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising positioning at least one of the electrically resistive sections proximate a relatively rich zone of the formation.
383. The method of claim 367, further comprising providing a reduced amount of heat of less than about 400 watts per meter of length of the opening above or near the selected temperature.
384. The method of claim 367, further comprising applying AC of at least about 70 amps to at least one of the electrical conductors.
385. A method for heating a subsurface formation, comprising:
applying a current to one or more electrical conductors placed in an opening in the formation, wherein at least one of the electrical conductors comprises one or more electrically resistive sections;
providing an electrically resistive heat output from at least one of the electrically resistive sections, wherein such electrically resistive sections provide a reduced amount of heat above or near a selected temperature that is about 20% or less of the heat output at about 50 °C below the selected temperature; and allowing the heat to transfer from at least one of the electrically resistive sections to at least a part of the formation.
386. The method of claim 385, further comprising applying alternating current to the one or more electrical conductors.
387. The method of claim 385, further comprising applying direct current to the one or more electrical conductors.
388. The method of claim 385, further comprising placing one or more of the electrical conductors in the opening.
389. The method of claim 385, further comprising providing an initial electrically resistive heat output when the electrically resistive section providing the heat output is at least about 50 °C below the selected temperature, and automatically providing the reduced amount of heat above or near the selected temperature.
390. The method of claim 385, further comprising providing a reduced amount of heat above or near the selected temperature that is less than about 20% of the heat output at about 40 °C below the selected temperature.
391. The method of claim 385, further comprising providing a reduced amount of heat above or near the selected temperature that is less than about 20% of the heat output at about 30 °C below the selected temperature.
392. The method of claim 385, further comprising allowing the heat to transfer radiatively from at least one of the electrically resistive sections to at least a part of the formation.
393. The method of claim 385, further comprising automatically decreasing an AC resistance of at least one of the electrically resistive sections when such an electrically resistive section is above the selected temperature to provide the reduced amount of heat above the selected temperature.
394. The method of claim 385, further comprising automatically increasing a resistance of at least one of the electrically resistive sections when such an electrically resistive section is above the selected temperature to provide the reduced amount of heat above the selected temperature.
395. The method of claim 385, further comprising automatically increasing a resistance of at least one of the electrically resistive sections by a factor of at least about 4 when such an electrically resistive section is above the selected temperature to provide the reduced amount of heat above the selected temperature.
396. The method of claim 385, further comprising automatically increasing a resistance of at least one of the electrically resistive sections when such an electrically resistive section is above the selected temperature to provide the reduced amount of heat above the selected temperature such that electrical current propagates through at least one other electrically resistive section.
397. The method of claim 385, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising heating at least some hydrocarbons in the formation to pyrolyze at some of the hydrocarbons in the formation.
398. A method for heating a subsurface formation, comprising:
applying AC to one or more electrical conductors placed in an opening in the formation, wherein at least one of the electrical conductors comprises an electrically resistive ferromagnetic material that provides an electrically resistive heat output when AC is applied to the ferromagnetic material, and wherein AC is applied when the ferromagnetic material is about 50 °C below a Curie temperature of the ferromagnetic material to provide an initial electrically resistive heat output;
allowing the temperature of the ferromagnetic material to approach or rise above the Curie temperature of the ferromagnetic material; and allowing the heat output from at least one of the electrical conductors to decrease below the initial electrically resistive heat output as a result of a change in AC resistance of such electrical conductor caused by the temperature of the ferromagnetic material approaching or rising above the Curie temperature of the ferromagnetic material.
399. The method of claim 398, further comprising applying AC at a frequency of about 180 Hz.
400. The method of claim 398, further comprising placing one or more of the electrical conductors in the opening.
401. The method of claim 398, wherein the decreased heat output is less than about 50% of the initial heat output.
402. The method of claim 398, wherein the decreased heat output is less than about 20% of the initial heat output.
403. The method of claim 398, further comprising allowing the heat to transfer radiatively from at least one of the electrical conductors to at least a part of the formation.
404. The method of claim 398, wherein the subsurface formation comprises a hydrocarbon containing formation.
405. The method of claim 398, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising heating at least some hydrocarbons in the formation to pyrolyze at some of the hydrocarbons in the formation.
406. The method of claim 398, further comprising producing at least some fluids from the formation.
407. The method of claim 398, wherein the declined heat output is less than about 400 watts per meter of length of the opening.
408. The method of claim 398, further comprising applying AC of at least about 70 amps to at least one of the electrical conductors.
409. A heater system, comprising:
an AC supply configured to provide AC at a voltage above about 200 volts;
an electrical conductor comprising one or more ferromagnetic sections, wherein the electrical conductor is electrically coupled to the AC supply, wherein at least one of the ferromagnetic sections is configured to provide an electrically resistive heat output during application of AC to the electrical conductor such that heat can transfer to material adjacent to such ferromagnetic section, and wherein such ferromagnetic section is configured to provide a reduced amount of heat above or near a selected temperature during use; and wherein the selected temperature is at or about the Curie temperature of the ferromagnetic section.
410. The heater system of claim 409, wherein the AC supply is configured to provide the AC at a voltage above about 650 volts.
411. The heater system of claim 409, wherein the AC supply is configured to provide the AC at a voltage above about 1000 volts.
412. The heater system of claim 409, wherein the heater system is configured to provide heat to a subsurface formation.
413. The heater system of claim 409, wherein the heater system is configured to provide heat to a hydrocarbon containing formation.
414. The heater system of claim 409, wherein the heater system is configured to provide heat to a hydrocarbon containing formation, and wherein the heater system is configured to pyrolyze at least some hydrocarbons in the formation.
415. The heater system of claim 409, wherein the heater system is configured to provide heat to contaminated soil, and wherein the heater system is configured to decontaminate at least a portion of the contaminated soil.
416. The heater system of claim 409, wherein the heater system is configured to provide heat to at least a portion of an opening in a subsurface formation.
417. The heater system of claim 409, wherein the heater system comprises three or more electrical conductors, and wherein at least three of the electrical conductors are configured to be coupled in a three-phase electrical configuration.
418. The heater system of claim 409, wherein at least one of the ferromagnetic sections comprises iron, nickel, chromium, cobalt, tungsten, or a mixture thereof.
419. The heater system of claim 409, wherein at least one of the ferromagnetic sections has a thickness of at least about 3/4 of a skin depth of the AC at the Curie temperature of such ferromagnetic sections.
420. The heater system of claim 409, wherein the heat output below the selected temperature is greater than about 400 watts per meter of the electrical conductor.
421. The heater system of claim 409, wherein at least one portion of the electrical conductor is configured to comprise a relatively flat AC resistance profile in a temperature range between about 100 °C and 750 °C.
422. The heater system of claim 409, wherein at least a portion of the electrical conductor is longer than about m.
423. The heater system of claim 409, wherein the heater system is configured to sharply reduce the heat output at or near the selected temperature.
424. The heater system of claim 409, wherein the heater system is configured such that the heat output from at least a portion of the system decreases at or near the selected temperature due to the Curie effect.
425. The heater system of claim 409, wherein the heater system is configured such that an AC resistance of the electrical conductor increases with an increase in temperature up to the selected temperature, and wherein the system is configured such that an AC resistance of the electrical conductor decreases with an increase in temperature from above the selected temperature.
426. The heater system of claim 409, wherein the system is configured to apply AC of at least about 70 amps to the electrical conductor.
427. The heater system of claim 409, wherein at least one of the electrical conductors comprises a turndown ratio of at least about 2 to 1.
428. The heater system of claim 409, wherein the system is configured to apply AC at about 180 Hz.
429. The heater system of claim 409, wherein the heater system is configured to withstand operating temperatures of about 250 °C or above.
430. The heater system of claim 409, wherein the heater system withstands operating temperatures of about 250 °C or above.
431. The heater system of claim 409, wherein the electrical conductor is configured to automatically provide the reduced amount of heat above or near the selected temperature.
432. A method of heating, comprising:
providing an AC at a voltage above about 200 volts to one or more electrical conductors to provide an electrically resistive heat output, wherein at least one of the electrical conductors comprises one or more electrically resistive sections; and wherein at least one of the electrically resistive sections comprises an electrically resistive ferromagnetic material and provides a reduced amount of heat above or near a selected temperature, and wherein the selected temperature is within about 50 °C of the Curie temperature of the ferromagnetic material.
433. The method of claim 432, further comprising providing the AC at a voltage above about 650 volts.
434. The method of claim 432, further comprising providing the AC to at least one of the electrical conductors at or above the selected temperature.
435. The method of claim 432, further comprising providing the AC at a frequency of about 180 Hz.
436. The method of claim 432, further comprising placing one or more of the electrical conductors in a wellbore in a subsurface formation.
437. The method of claim 432, further comprising providing an initial electrically resistive heat output when the electrical conductor providing the heat output is at least about 50 °C
below the selected temperature, and automatically providing the reduced amount of heat above or near the selected temperature.
438. The method of claim 432, further comprising allowing heat to transfer from at least one of the electrically resistive sections to at least a part of a subsurface formation.
439. The method of claim 432, further comprising providing a relatively constant heat output when the ferromagnetic material is in a temperature range between about 300 °C
and about 600 °C.
440. The method of claim 432, further comprising providing a relatively constant heat output when the ferromagnetic material is in a temperature range between about 100 °C
and about 750 °C.
441. The method of claim 432, wherein an AC resistance of at least one of the electrically resistive sections decreases above the selected temperature to provide the reduced amount of heat.
442. The method of claim 432, wherein the electrically resistive ferromagnetic material has a thickness of at least about 3/4 of a skin depth of AC at the Curie temperature of the ferromagnetic material.
443. The method of claim 432, further comprising allowing heat to transfer from at least one of the electrically resistive sections to at least a part of a subsurface formation, wherein the subsurface formation comprises a hydrocarbon containing formation.
444. The method of claim 432, further comprising allowing heat to transfer from at least one of the electrically resistive sections to at least a part of a hydrocarbon containing formation, and further comprising at least some hydrocarbons in the formation.
445. The method of claim 432, wherein the reduced amount of heat is less than about 400 watts per meter of length of an electrical conductor.
446. The method of claim 432, further comprising controlling a skin depth in at least one of the electrically resistive sections by controlling a frequency of the applied AC.
447. The method of claim 432, further comprising applying additional current to at least one of the electrically resistive sections as the temperature of such electrically resistive sections increases until the temperature is at or near the selected temperature.
448. The method of claim 432, wherein an amount of heat output provided from at least one of the electrically resistive sections is determined by an amount of current applied to at least one of the electrical conductors.
449. The method of claim 432, further comprising controlling an amount of heat provided by at least one of the electrically resistive sections by controlling an amount of current applied to at least one of the electrical conductors.
450. The method of claim 432, further comprising applying current of at least about 70 amps to at least one of the electrical conductors.
451. The method of claim 432, further comprising applying current of at least about 100 amps to at least one of the electrical conductors.
452. A heater system, comprising:
an AC supply configured to provide AC at a voltage above about 200 volts;
an electrical conductor coupled to the AC supply, and wherein the electrical conductor comprises one or more electrically resistive sections, wherein at least one of the electrically resistive sections comprises an electrically resistive ferromagnetic material, wherein the electrical conductor is configured to provide an electrically resistive heat output during application of the AC to the electrical conductor, and wherein the electrical conductor is configured to provide a reduced amount of heat above or near a selected temperature that is about 20% or less of the heat output at about 50°C below the selected temperature during use;
and wherein the selected temperature is at or about the Curie temperature of the ferromagnetic material.
453. The heater system of claim 452, wherein the AC supply is configured to provide AC at a voltage above about 650 volts.
454. The heater system of claim 452, wherein the AC supply is configured to provide AC at a voltage above about 1000 volts.
455. The heater system of claim 452, wherein the heater system is configured to provide heat to a subsurface formation.
456. The heater system of claim 452, wherein the heater system is configured to provide heat to a hydrocarbon containing formation.
457. The heater system of claim 452, wherein the heater system is configured to provide heat to a hydrocarbon containing formation, and wherein the system is configured to pyrolyze at least some hydrocarbons in the formation.
458. The heater system of claim 452, wherein the ferromagnetic material comprises iron, nickel, chromium, cobalt, tungsten, or a mixture thereof.
459. The heater system of claim 452, wherein the heat output below the selected temperature is greater than about 400 watts per meter of length of the electrical conductor.
460. The heater system of claim 452, wherein at least one portion of the electrical conductor is configured to comprise a relatively flat AC resistance profile in a temperature range between about 100°C and 750°C.
461. The heater system of claim 452, wherein the heater system is configured to sharply reduce the heat output at or near the selected temperature.
462. The heater system of claim 452, wherein the system is configured to apply AC of at least about 70 amps to the electrical conductor.
463. The heater system of claim 452, wherein at least one of the electrical conductors comprises a turndown ratio of at least about 2 to 1.
464. The heater system of claim 452, wherein the system is configured to apply AC at about 180 Hz.
465. The heater system of claim 452, wherein the electrical conductor is configured to automatically provide the reduced amount of heat above or near the selected temperature.
466. A heater system, comprising:
an AC supply configured to provide AC at a frequency between about 100 Hz and about 1000 Hz;
an electrical conductor electrically coupled to the AC supply, wherein the electrical conductor comprises at least one electrically resistive section configured to provide an electrically resistive heat output during application of the AC to the electrically resistive section during use; and wherein the electrical conductor comprises an electrically resistive ferromagnetic material and is configured to provide a reduced amount of heat above or near a selected temperature, and wherein the selected temperature is within about 50°C of the Curie temperature of the ferromagnetic material.
467. The heater system of claim 466, wherein the AC supply is coupled to a supply of line current, and wherein the AC supply is configured to provide AC at about three times the frequency of the line current.
468. The heater system of claim 466, wherein the AC supply is configured to provide AC with a frequency between about 140 Hz and about 200 Hz.
469. The heater system of claim 466, wherein AC supply is configured to provide AC with a frequency between about 400 Hz and about 550 Hz.
470. The heater system of claim 466, wherein the heater system is configured to provide heat to a subsurface formation.
471. The heater system of claim 466, wherein the heater system is configured to provide heat to a hydrocarbon containing formation, and wherein the heater system is configured to pyrolyze at least some hydrocarbons in the formation.
472. The heater system of claim 466, wherein the heater system is configured to provide heat to contaminated soil, and wherein the heater system is configured to decontaminate at least a portion of the contaminated soil.
473. The heater system of claim 466, wherein the heater system is configured to provide heat to at least a portion of an opening in a subsurface formation.
474. The heater system of claim 466, wherein the ferromagnetic material comprises iron, nickel, chromium, cobalt, tungsten, or a mixture thereof.
475. The heater system of claim 466, wherein a thickness of the ferromagnetic material is at least about 3/4 of a skin depth of the AC at the Curie temperature of the ferromagnetic material.
476. The heater system of claim 466, wherein the heat output below the selected temperature is greater than about 400 watts per meter of the electrical conductor.
477. The heater system of claim 466, wherein at least a portion of at least one of the electrical conductors is configured to comprise a relatively flat AC resistance profile in a temperature range between about 100°C and 750 °C.
478. The heater system of claim 466, wherein at least a portion of at least one of the electrical conductors is longer than about 10 m.
479. The heater system of claim 466, wherein the heater system is configured to sharply reduce the heat output at or near the selected temperature.
480. The heater system of claim 466, wherein the heater system is configured such that the heat output of at least a portion of the system decreases at or near the selected temperature due to the Curie effect.
481. The heater system of claim 466, wherein the system is configured to apply AC of at least about 70 amps to at least one of the electrically resistive sections.
482. The heater system of claim 466, wherein at least one of the electrically resistive sections comprises a turndown ratio of at least about 2 to 1.
483. The heater system of claim 466, wherein the heater system is configured to withstand operating temperatures of about 250°C or above.
484. The heater system of claim 466, wherein the electrical conductor is configured to automatically provide the reduced amount of heat above or near the selected temperature.
485. A method of heating, comprising:
providing AC at a frequency between about 100 Hz and about 1000 Hz to an electrical conductor to provide an electrically resistive heat output, wherein the electrical conductor comprises at least one electrically resistive section; and wherein at least one of the electrically resistive sections comprises an electrically resistive ferromagnetic material and provides a reduced amount of heat above or near a selected temperature, and wherein the selected temperature is within about 50°C of the Curie temperature of the ferromagnetic material.
486. The method of claim 485, further comprising providing the AC to the electrical conductor when the electrical conductor is at or above the selected temperature.
487. The method of claim 485, further comprising placing the electrical conductor in a wellbore in a subsurface formation.
488. The method of claim 485, further comprising providing an initial electrically resistive heat output when the electrical conductor providing the heat output is at least about 50°C
below the selected temperature, and automatically providing the reduced amount of heat above or near the selected temperature.
489. The method of claim 485, further comprising providing the AC at about three times the frequency of line current from an AC supply.
490. The method of claim 485, further comprising providing the AC at a frequency between about 140 Hz and about 200 Hz.
491. The method of claim 485, further comprising providing the AC at a frequency between about 400 Hz and about 550 Hz.
492. The method of claim 485, further comprising providing the AC to the electrical conductor when the electrical conductor is at or above the selected temperature.
493. The method of claim 485, further comprising allowing heat to transfer from at least one of the electrically resistive sections to at least a part of a subsurface formation.
494. The method of claim 485, further comprising providing a relatively constant heat output when the ferromagnetic material is in a temperature range between about 100°C
and 750°C.
495. The method of claim 485, wherein an AC resistance of the electrical conductor decreases above the selected temperature to provide the reduced amount of heat.
496. The method of claim 485, wherein a thickness of the ferromagnetic material is at least about 3/4 of a skin depth of the AC at the Curie temperature of the ferromagnetic material.
497. The method of claim 485, further comprising allowing heat to transfer from the electrical conductor to at least a part of a subsurface formation, wherein the subsurface formation comprises a hydrocarbon containing formation.
498. The method of claim 485, further comprising allowing heat to transfer from the electrical conductor to at least a part of a hydrocarbon containing formation, and pyrolyzing at least some hydrocarbons in the formation.
499. The method of claim 485, further comprising providing a reduced amount of heat above or near the selected temperature of less than about 400 watts per meter of length of the electrical conductor.
500. The method of claim 485, further comprising controlling a skin depth in the electrical conductor by controlling a frequency of the AC applied to the electrical conductor.
501. The method of claim 485, further comprising controlling the heat applied from the electrical conductor by allowing less heat to be applied from any part of the electrical conductor that is at or near the selected temperature.
502. The method of claim 485, further comprising controlling the amount of current applied to the electrical conductor to control an amount of heat provided by at least one of the electrically resistive sections.
503. The method of claim 485, further comprising applying current of at least about 70 amps to the electrical conductor.
504. A heater system, comprising:
an AC supply configured to provide AC at a frequency between about 100 Hz and about 1000 Hz;
an electrical conductor electrically coupled to the AC supply, wherein the electrical conductor comprises at least one electrically resistive section configured to provide an electrically resistive heat output during application of the AC from the AC supply to the electrically resistive section during use;
and wherein the electrical conductor comprises an electrically resistive ferromagnetic material and is configured to provide a reduced amount of heat above or near a selected temperature that is about 20% or less of the heat output at about 50°C below the selected temperature, and wherein the selected temperature is at or about the Curie temperature of the ferromagnetic material.
505. The heater system of claim 504, wherein the AC supply is coupled to a supply of line current, and wherein the AC supply is configured to provide AC at about three times the frequency of the line current.
506. The heater system of claim 504, wherein the frequency is between about 140 Hz and about 200 Hz.
507. The heater system of claim 504, wherein the frequency is between about 400 Hz and about 550 Hz.
508. The heater system of claim 504, wherein the heater system is configured to provide heat to a subsurface formation.
509. The heater system of claim 504, wherein the heater system is configured to provide heat to a hydrocarbon containing formation, and wherein the heater system is configured to pyrolyze at least some hydrocarbons in the formation.
510. The heater system of claim 504, wherein the heater system is configured to provide heat to at least a portion of an opening in a subsurface formation.
511. The heater system of claim 504, wherein the ferromagnetic material comprises iron, nickel, chromium, cobalt, tungsten, or a mixture thereof.
512. The heater system of claim 504, wherein a thickness of the ferromagnetic material is at least about 3/4 of a skin depth of the AC at the Curie temperature of the ferromagnetic material.
513. The heater system of claim 504, wherein the heat output below the selected temperature is greater than about 400 watts per meter of length of the electrical conductor.
514. The heater system of claim 504, wherein at least a portion of at least one of the electrical conductors is configured to comprise a relatively flat AC resistance profile in a temperature range between about 100°C and 750 °C.
515. The heater system of claim 504, wherein the heater system is configured to sharply reduce the heat output at or near the selected temperature.
516. The heater system of claim 504, wherein the system is configured to apply AC of at least about 70 amps to at least one of the electrically resistive sections.
517. The heater system of claim 504, wherein at least one of the electrically resistive sections comprises a turndown ratio of at least about 2 to 1.
518. The heater system of claim 504, wherein the electrical conductor is configured to automatically provide the reduced amount of heat above or near the selected temperature.
519. A heater, comprising:
an electrical conductor configured to generate an electrically resistive heat output during application of AC
to the electrical conductor, wherein the electrical conductor comprises an electrically resistive ferromagnetic material at least partially surrounding a non-ferromagnetic material such that the heater provides a reduced amount of heat above or near a selected temperature;
an electrical insulator at least partially surrounding the electrical conductor; and a sheath at least partially surrounding the electrical insulator.
520. The heater of claim 519, wherein the electrical conductor comprises coextruded ferromagnetic material and non-ferromagnetic material.
521. The heater of claim 519, wherein the electrical insulator comprises a pre-formed electrical insulator.
522. The heater of claim 519, wherein the sheath comprises electrically conductive material.
523. The heater of claim 519, wherein the sheath comprises two or more electrically conductive strips that are longitudinally welded together.
524. The heater of claim 519, wherein the heater comprises one or more portions coupled together, wherein each portion comprises at least a section of the electrical conductor.
525. The heater of claim 519, wherein the heater comprises one or more portions coupled together, wherein each portion comprises at least one section of the electrical conductor, and wherein at least one section of the electrical conductor has been coupled to at least another section of the electrical conductor using a weld.
526. The heater of claim 525, wherein the weld comprises non-ferromagnetic welding material.
527. The heater of claim 519, wherein the heater is configured to allow heat to transfer from the heater to a part of a subsurface formation to pyrolyze at least some hydrocarbons in the subsurface formation.
528. The heater of claim 519, wherein the heater is configured to be placed in an opening in a subsurface formation.
529. The heater of claim 519, wherein heater is configured such that a resistance of the ferromagnetic material decreases above the selected temperature such that the heater provides the reduced amount of heat above the selected temperature.
530. The heater of claim 519, further comprising a second ferromagnetic material coupled to the ferromagnetic material.
531. The heater of claim 519, wherein the heater is configured such that the selected temperature is approximately the Curie temperature of the ferromagnetic material.
532. The heater of claim 519, wherein the ferromagnetic material comprises iron.
533. The heater of claim 519, wherein the reduced amount of heat is less than about 400 watts per meter of length of the heater.
534. The heater of claim 519, wherein the heat output is greater than about 400 watts per meter of length of the heater at about 50 °C below the selected temperature.
535. The heater of claim 519, wherein the heater comprises a relatively flat AC resistance profile in a temperature range between about 100 °C and 750 °C.
536. The heater of claim 519, wherein the heater is an elongated rod, and wherein at least a portion of the elongated rod is longer than about 10 m.
537. The heater of claim 519, wherein the ferromagnetic material comprises a turndown ratio of at least about 2 to 1.
538. The heater of claim 519, wherein the non-ferromagnetic material comprises copper.
539. The heater of claim 519, wherein the electrical conductor, the electrical insulator, and the sheath are portions of an insulated conductor heater.
540. The heater of claim 519, wherein the electrical insulator comprises magnesium oxide.
541. The heater of claim 519, wherein the sheath comprises steel.
542. The heater of claim 519, wherein the sheath comprises copper and steel.
543. The heater of claim 519, wherein the ferromagnetic material is configured to automatically provide the reduced amount of heat above or near the selected temperature that is about 20% or less of the heat output at about 50 °C below the selected temperature.
544. A method of heating a subsurface formation, comprising:
providing AC to an electrical conductor to provide an electrically resistive heat output, wherein the electrical conductor comprises an electrically resistive ferromagnetic material at least partially surrounding a non-ferromagnetic material such that the electrical conductor provides a reduced amount of heat above or near a selected temperature, wherein an electrical insulator at least partially surrounds the electrical conductor, and wherein a sheath at least partially surrounds the electrical insulator; and allowing heat to transfer from the electrical conductor to at least part of the subsurface formation.
545. The method of claim 544, further comprising providing the AC to the electrical conductor when the electrical conductor is at or above the selected temperature.
546. The method of claim 544, further comprising placing the electrical conductor in a wellbore in the subsurface formation.
547. The method of claim 544, further comprising providing an initial electrically resistive heat output when the electrical conductor providing the heat output is at least about 50 °C
below the selected temperature, and automatically providing the reduced amount of heat above or near the selected temperature.
548. The method of claim 544, further comprising providing the AC at a frequency between about 100 Hz and about 1000 Hz.
549. The method of claim 544, further comprising providing a relatively constant heat output when the ferromagnetic material is in a temperature range between about 100 °C
and 750 °C.
550. The method of claim 544, wherein an AC resistance of the electrical conductor decreases above the selected temperature to provide the reduced amount of heat.
551. The method of claim 544, wherein a thickness of the ferromagnetic material is at least about 3/4 of a skin depth of the AC at the Curie temperature of the ferromagnetic material.
552. The method of claim 544, wherein the subsurface formation comprises a hydrocarbon containing formation.
553. The method of claim 544, further comprising allowing heat to transfer from the electrical conductor to at least a part of a hydrocarbon containing formation, and pyrolyzing at least some hydrocarbons in the formation.
554. The method of claim 544, further comprising providing a reduced amount of heat above or near the selected temperature of less than about 400 watts per meter of length of the electrical conductor.
555. The method of claim 544, further comprising controlling a skin depth in the electrical conductor by controlling a frequency of the AC applied to the electrical conductor.
556. The method of claim 544, further comprising controlling the heat applied from the electrical conductor by allowing less heat to be applied from any part of the electrical conductor that is at or near the selected temperature.
557. The method of claim 544, further comprising controlling the amount of current applied to the electrical conductor to control an amount of heat provided by at least one of the electrically resistive sections.
558. The method of claim 544, further comprising applying current of at least about 70 amps to the electrical conductor.
559. A heater, comprising:
an electrical conductor configured to generate an electrically resistive heat output during application of AC
to the electrical conductor, wherein the electrical conductor comprises an electrically resistive ferromagnetic alloy at least partially surrounding a non-ferromagnetic material such that the heater provides a reduced amount of heat above or near a selected temperature, and wherein the ferromagnetic alloy comprises nickel;
an electrical insulator at least partially surrounding the electrical conductor; and a sheath at least partially surrounding the electrical insulator.
560. The heater of claim 559, wherein the electrical insulator comprises a pre-formed electrical insulator.
561. The heater of claim 559, wherein the sheath comprises electrically conductive material.
562. The heater of claim 559, wherein the sheath is formed of electrically conductive strips that are longitudinally welded together.
563. The heater of claim 559, wherein the heater comprises one or more portions coupled together, wherein each portion comprises at least a section of the electrical conductor.
564. The heater of claim 559, wherein the heater comprises one or more portions coupled together, wherein each portion comprises at least one section of the electrical conductor, and wherein at least one section of the electrical conductor has been coupled to at least another section of the electrical conductor using a weld.
565. The heater of claim 564, wherein the weld comprises non-ferromagnetic welding material.
566. The heater of claim 559, wherein the ferromagnetic alloy comprises at least about 25 % by weight nickel.
567. The heater of claim 559, wherein the ferromagnetic alloy comprises less than about 45 % by weight nickel.
568. The heater of claim 559, wherein the ferromagnetic alloy comprises iron.
569. The heater of claim 559, wherein the ferromagnetic alloy comprises chromium.
570. The heater of claim 559, wherein the electrical insulator comprises silicone.
571. The heater of claim 559, wherein the heater is configured to allow heat to transfer from the heater to a part of a subsurface formation to mobilize at least some hydrocarbons in the subsurface formation.
572. The heater of claim 559, wherein the heater is configured to be placed in an opening in a subsurface formation.
573. The heater of claim 559, wherein a resistance of the ferromagnetic alloy decreases above the selected temperature such that the heater provides the reduced amount of heat above the selected temperature.
574. The heater of claim 559, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic alloy.
575. The heater of claim 559, wherein the reduced amount of heat is less than about 200 watts per meter of length of the heater.
576. The heater of claim 559, wherein the heat output is greater than about 300 watts per meter of length of the heater below the selected temperature.
577. The heater of claim 559, wherein the ferromagnetic alloy comprises a turndown ratio of at least about 2 to 1.
578. The heater of claim 559, wherein the non-ferromagnetic material comprises copper.
579. The heater of claim 559, wherein the electrical conductor, the electrical insulator, and the sheath are portions of an insulated conductor heater.
580. The heater of claim 559, wherein a thickness of the ferromagnetic alloy is at least about 3/4 of a skin depth of the AC at the Curie temperature of the ferromagnetic alloy.
581. The heater of claim 559, wherein the sheath comprises steel.
582. The heater of claim 559, wherein the sheath comprises copper and steel.
583. A heater, comprising:
an electrical conductor configured to generate an electrically resistive heat output during application of AC
to the electrical conductor, wherein the electrical conductor comprises an electrically resistive ferromagnetic material at least partially surrounding a non-ferromagnetic material such that the heater provides a reduced amount of heat above or near a selected temperature;
a conduit at least partially surrounding the electrical conductor; and a centralizer configured to maintain a separation distance between the electrical conductor and the conduit.
584. The heater of claim 583, wherein the electrical conductor is formed by a coextrusion process that combines the ferromagnetic material and the non-ferromagnetic material.
585. The heater of claim 583, wherein the centralizer comprises silicon nitride.
586. The heater of claim 583, wherein the conduit comprises electrically conductive material.
587. The neater of claim 583, wherein the heater comprises one or more portions coupled together, wherein each portion comprises at least one section of the electrical conductor, and wherein at least one section of the electrical conductor has been coupled to at least another section of the electrical conductor using a weld.
588. The heater of claim 583, wherein the heater is configured to allow heat to transfer from the heater to a part of a subsurface formation to pyrolyze at least some hydrocarbons in the subsurface formation.
589. The heater of claim 583, wherein the heater is configured to be placed in an opening in a subsurface formation.
590. The heater of claim 583, wherein a resistance of the ferromagnetic material decreases above the selected temperature such that the heater provides the reduced amount of heat above the selected temperature.
591. The heater of claim 583, further comprising a second ferromagnetic material coupled to the ferromagnetic material.
592. The heater of claim 583, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
593. The heater of claim 583, wherein the ferromagnetic material comprises iron.
594. The heater of claim 583, wherein the reduced amount of heat is less than about 400 watts per meter of length of the heater.
595. The heater of claim 583, wherein the heat output below the selected temperature is greater than about 400 watts per meter of length of the heater.
596. The heater of claim 583, wherein the heater comprises a relatively flat AC resistance profile in a temperature range between about 100 °C and 750 °C.
597. The heater of claim 583, wherein at least a portion of the heater is longer than about 10 m.
598. The heater of claim 583, wherein the ferromagnetic material comprises a turndown ratio of at least about 2 to 1.
599. The heater of claim 583, wherein the non-ferromagnetic material comprises copper.
600. A method of heating a subsurface formation, comprising:
providing AC to an electrical conductor to provide an electrically resistive heat output, wherein the electrical conductor comprises an electrically resistive ferromagnetic material at least partially surrounding a non-ferromagnetic material such that the electrical conductor provides a reduced amount of heat above or near a selected temperature, wherein a conduit at least partially surrounds the electrical conductor, and wherein a centralizes maintains a separation distance between the electrical conductor and the conduit; and allowing heat to transfer from the electrical conductor to at least part of the subsurface formation.
601. The method of claim 600, wherein the AC provided to the electrical conductor has a frequency between about 100 Hz and about 1000 Hz.
602. The method of claim 600, wherein the reduced amount of heat is provided without adjusting the amperage of the AC applied to the electrical conductor.
603. The method of claim 600, further comprising providing an initial electrically resistive heat output when the electrical conductor providing the heat output is at least about 50 °C
below the selected temperature, and automatically providing the reduced amount of heat above or near the selected temperature.
604. The method of claim 600, further comprising placing the electrical conductor in a wellbore in the subsurface formation.
605. The method of claim 600, wherein heat output from the electrical conductor is substantially constant when a temperature of the electrical conductor is between about 100 °C and 750 °C.
606. The method of claim 600, wherein an AC resistance of the electrical conductor decreases above the selected temperature to provide the reduced amount of heat.
607. The method of claim 600, wherein a thickness of the ferromagnetic material is at least about 3/4 of a skin depth of the AC at the Curie temperature of the ferromagnetic material.
608. The method of claim 600, further comprising providing a reduced amount of heat above or near the selected temperature of less than about 400 watts per meter of length of the electrical conductor.
609. The method of claim 600, further comprising controlling a skin depth in the electrical conductor by controlling a frequency of the AC applied to the electrical conductor.
610. The method of claim 600, further comprising controlling the heat applied from the electrical conductor by allowing less heat to be applied from any part of the electrical conductor that is at or near the selected temperature.
611. The method of claim 600, further comprising applying current of at least about 70 amps to the electrical conductor.
612. A heater, comprising:
an electrical conductor configured to generate an electrically resistive heat output when AC is applied to the electrical conductor, wherein the electrical conductor comprises an electrically resistive ferromagnetic material at least partially surrounding a non-ferromagnetic material, and wherein the ferromagnetic material is configured to provide a reduced amount of heat above or near a selected temperature that is about 20% or less of the heat output at about 50 °C below the selected temperature;
a conduit at least partially surrounding the electrical conductor; and a centralizer configured to maintain a separation distance between the electrical conductor and the conduit.
613. The heater of claim 612, wherein the centralizes comprises silicon nitride, 614. The heater of claim 612, wherein the heater comprises one or more portions coupled together, wherein each portion comprises at least one section of the electrical conductor, and wherein at least one section of the electrical conductor has been coupled to at least another section of the electrical conductor using a weld.
615. The heater of claim 612, wherein a resistance of the ferromagnetic material decreases above the selected temperature such that the heater provides the reduced amount of heat above the selected temperature.
616. The heater of claim 612, further comprising a second ferromagnetic material coupled to the ferromagnetic material.
617. The heater of claim 612, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
618. The heater of claim 612, wherein the ferromagnetic material comprises iron.
619. The heater of claim 612, wherein the reduced amount of heat is less than about 400 watts per meter of length of the heater.
620. The heater of claim 612, wherein the heat output below the selected temperature is greater than about 400 watts per meter of length of the heater.
621. The heater of claim 612, wherein the heater comprises a relatively flat AC resistance profile in a temperature range between about 100 °C and 750 °C.
622. The heater of claim 612, wherein at least a portion of the heater is longer than about 10 m.
623. The heater of claim 612, wherein the ferromagnetic material comprises a turndown ratio of at least about 2 to 1.
624. The heater of claim 612, wherein the non-ferromagnetic material comprises copper.
625. A system configured to heat a part of a hydrocarbon containing formation, comprising:
a conduit configured to be placed in an opening in the formation, wherein the conduit is configured to allow fluids to be produced from the formation;
one or more electrical conductors configured to be placed in the opening in the formation, wherein at least one of the electrical conductors comprises a heater section, the heater section comprising an electrically resistive ferromagnetic material configured to provide an electrically resistive heat output when AC is applied to the ferromagnetic material, wherein the ferromagnetic material provides a reduced amount of heat above or near a selected temperature during use, and wherein the reduced heat output inhibits a temperature rise of the ferromagnetic material above a temperature that causes undesired degradation of hydrocarbon material adjacent to the ferromagnetic material; and wherein the system is configured to allow heat to transfer from the heater section to a part of the formation such that the heat reduces the viscosity of fluids in the formation and/or fluids at, near, and/or in the opening.
626. The system of claim 625, wherein one or more of the electrical conductors are located inside the conduit.
627. The system of claim 625, wherein one or more of the electrical conductors are located inside the conduit, and wherein such electrical conductors comprise an inner conduit configured to allow fluids to propagate through the inner conduit.
628. The system of claim 625, wherein the system is configured to allow a gas to be provided to the opening, and wherein the gas is configured to reduce the density of fluids to facilitate production of the fluids from the formation.
629. The system of claim 625, further comprising a pump configured to produce fluids from the opening.
630. The system of claim 625, wherein the system is configured to reduce the viscosity of fluids in the formation to less than about 50 centipoise.
631. The system of claim 625, wherein the system is configured such that the ferromagnetic material automatically provides a selected reduced amount of heat above or near the selected temperature.
632. The system of claim 625, wherein the system is configured such that the AC resistance of the ferromagnetic material decreases when the temperature of ferromagnetic material is near or above the selected temperature.
633. The system of claim 625, wherein at least one of the electrical conductors is configured to exhibit an increase in operating temperature of less than about 1.5 °C above or near a selected operating temperature when a thermal load proximate such electrical conductor decreases by about 1 watt per meter of the electrical conductor.
634. The system of claim 625, further comprising a highly electrically conductive material coupled to at least a portion of the ferromagnetic material of an electrical conductor, wherein AC
applied to the electrical conductor substantially flows through the ferromagnetic conductor when a temperature of the ferromagnetic conductor is below the selected temperature, and wherein the AC applied to the conductor is configured to flow through the highly electrically conductive material when the temperature of the ferromagnetic conductor is near or above the selected temperature.
635. The system of claim 625, wherein at least one of the electrical conductors is configured to provide a reduced amount of heat above or near the selected temperature that is about 20% or less of the heat output at about 50 °C below the selected temperature.
636. The system of claim 625, wherein at least one of the electrical conductors is configured such that a decreased AC resistance through such electrical conductor above or near the selected temperature is about 20% or less than the electrical resistance at about 50 °C below the selected temperature.
637. The system of claim 625, wherein an AC resistance of at least one of the electrical conductors above or near the selected temperature is about 80% or less of an AC resistance at about 50 °C below the selected temperature.
638. The system of claim 625, wherein the system is configured such that an AC
resistance of the ferromagnetic material decreases above the selected temperature to provide the reduced amount of heat.
639. The system of claim 625, further comprising a non-ferromagnetic material coupled to the ferromagnetic material, wherein the non-ferromagnetic material has a higher electrical conductivity than the ferromagnetic material.
640. The system of claim 625, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
641. The system of claim 625, wherein the selected temperature is less than about 300 °C.
642. The system of claim 625, wherein the system is configured to limit a temperature in the formation at or near the wellbore to less than about 250 °C.
643. The system of claim 625, wherein the reduced amount of heat is less than about 200 watts per meter of length of the electrical conductor.
644. The system of claim 625, wherein heat output from the ferromagnetic material is greater than about 300 watts per meter of length of the electrical conductor when the temperature of the ferromagnetic material is below the selected temperature during use.
645. The system of claim 625, wherein the ferromagnetic material has a turndown ratio of at least about 2 to 1.
646. The system of claim 625, wherein the ferromagnetic material comprises iron, nickel, chromium, or a mixture thereof.
647. The system of claim 625, wherein the system is configured such that the ferromagnetic material has a thickness of at least about 3/4 of a skin depth of AC at the Curie temperature of the ferromagnetic material.
648. The system of claim 625, wherein at least one of the electrical conductors comprises ferromagnetic material and non-ferromagnetic electrically conductive material.
649. The system of claim 625, wherein the hydrocarbon containing formation comprises a relatively permeable formation containing heavy hydrocarbons.
650. The system of claim 625, wherein the electrically resistive ferromagnetic material is elongated and at least a portion of the ferromagnetic material is longer than about 10 m.
651. The system of claim 625, wherein the system is configured to sharply reduce the heat output at or near the selected temperature.
652. The system of claim 625, wherein at least one of the electrical conductors is elongated and configured such that only electrically resistive sections at or near the selected temperature will automatically reduce the heat output.
653. The system of claim 625, wherein the system is configured such that an AC
resistance of at least one of the electrical conductors increases with an increase in temperature up to the selected temperature.
654. The system of claim 625, wherein the system is configured such that an AC
resistance of at least one of the electrical conductors decreases with an increase in temperature above the selected temperature.
655. The system of claim 625, wherein the system is configured such that at least about 70 amps is applied to at least one of the electrical conductors.
656. The system of claim 625, wherein the system is configured such that a frequency of the AC is about 180 Hz.
657. The system of claim 625, wherein the system is configured such that a frequency of the AC is about 60 Hz.
658. The system of claim 625, wherein the ferromagnetic material is positioned in the opening in the formation, and wherein at least a portion of the opening in the formation adjacent to the ferromagnetic material comprises one or more openings for allowing fluids to enter the wellbore.
659. A method for treating a hydrocarbon containing formation, comprising:
applying AC to one or more electrical conductors located in an opening in the formation to provide an electrically resistive heat output, wherein at least one of the electrical conductors comprises an electrically resistive ferromagnetic material that provides heat when AC flows through the electrically resistive ferromagnetic material, and wherein the electrically resistive ferromagnetic material provides a reduced amount of heat above or near a selected temperature;
allowing the heat to transfer from the electrically resistive ferromagnetic material to a part of the formation so that a viscosity of fluids at or near the opening in the formation is reduced; and producing the fluids through the opening.
660. The method of claim 659, wherein the ferromagnetic material automatically provides the reduced amount of heat above or near the selected temperature.
661. The method of claim 659, further comprising placing the one or more electrical conductors in the opening.
662. The method of claim 659, further comprising providing an initial electrically resistive heat output when the electrical conductor providing the heat output is at least about 50 °C
below the selected temperature, and automatically providing the reduced amount of heat above or near the selected temperature.
663. The method of claim 659, wherein the viscosity of fluids at or near the opening is reduced to less than about 50 centipoise.
664. The method of claim 659, further comprising providing a gas to the opening that reduces the density of the fluids so that the fluids are pushed out of the opening to the surface of the formation by the formation pressure.
665. The method of claim 659, further comprising producing the fluids from the opening by pumping the fluids from the opening.
666. The method of claim 659, further comprising producing the fluids from the opening through the electrical conductors.
667. The method of claim 659, further comprising producing the fluids from the opening through a conduit located in the opening.
668. The method of claim 659, further comprising limiting a temperature in the formation at or near the opening to less than about 250 °C.
669. The method of claim 659, wherein the electrically resistive ferromagnetic material automatically provides a selected reduced amount of heat above or near a selected temperature.
670. The method of claim 659, wherein an AC resistance of the ferromagnetic material decreases above the selected temperature to provide the reduced amount of heat.
671. The method of claim 659, wherein a thickness of the ferromagnetic material is greater than about 3/4 of a skin depth of the AC at the Curie temperature of the ferromagnetic material.
672. The method of claim 659, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
673. The method of claim 659, wherein the selected temperature is less than about 300 °C.
674. The method of claim 659, further comprising providing a reduced amount of heat above or near the selected temperature of less than about 200 watts per meter of length of an electrical conductor.
675. The method of claim 659, further comprising providing a heat output below the selected temperature of greater than about 300 watts per meter of length of an electrical conductor.
676. The method of claim 659, further comprising controlling the amount of current applied to the electrical conductors to control the amount of heat provided by the ferromagnetic material.
677. The method of claim 659, further comprising applying an AC of at least about 70 amps to the electrical conductors.
678. The method of claim 659, further comprising providing a heat output from at least one of the electrical conductors, wherein an AC resistance of such electrical conductors above or near the selected temperature is about 80% or less of the AC resistance of such electrical conductors at about 50 °C below the selected temperature.
679. The method of claim 659, further comprising controlling a skin depth in the ferromagnetic material by controlling a frequency of the applied AC.
680. The method of claim 659, further comprising increasing the AC applied to at least one of the electrical conductors as the temperature of such electrical conductors increases, and continuing to do so until the temperature is at or near the selected temperature.
681. The method of claim 659, further comprising controlling an amount of current applied to at least one of the electrical conductors to control an amount of heat output from such electrical conductors.
682. The method of claim 659, further comprising increasing an amount of current applied to at least one of the electrical conductors to decrease an amount of heat output from such electrical conductors.
683. The method of claim 659, further comprising decreasing an amount of current applied to at least one of the electrical conductors to increase an amount of heat output from such electrical conductors.
684. The method of claim 659, wherein the hydrocarbon containing formation comprises a relatively permeable formation containing heavy hydrocarbons.
685. A method for treating a hydrocarbon containing formation, comprising:
applying AC to one or more electrical conductors located in an opening in the formation to provide an electrically resistive heat output, wherein at least one of the electrical conductors comprises an electrically resistive ferromagnetic material that provides heat when AC flows through the electrically resistive ferromagnetic material, and wherein the electrically resistive ferromagnetic material provides a reduced amount of heat above or near a selected temperature;
allowing the heat to transfer from the electrically resistive ferromagnetic material to a part of the formation to enhance radial flow of fluids from portions of the formation surrounding the opening to the opening; and producing the fluids through the opening.
686. The method of claim 685, wherein the ferromagnetic material automatically provides the reduced amount of heat above or near the selected temperature.
687. The method of claim 685, further comprising placing one or more of the electrical conductors in the opening.
688. The method of claim 685, further comprising providing an initial electrically resistive heat output when the electrical conductor providing the heat output is at least about 50°C
below the selected temperature, and automatically providing the reduced amount of heat above or near the selected temperature.
689. The method of claim 685, wherein the viscosity of fluids at or near the opening is reduced to less than about 50 centipoise.
690. The method of claim 685, further comprising producing the fluids from the opening by pumping the fluids from the opening.
691. The method of claim 685, further comprising producing the fluids from the opening through the electrical conductors.
692. The method of claim 685, further comprising producing the fluids from the opening through a conduit located in the opening.
693. The method of claim 685, further comprising limiting a temperature in the formation at or near the opening to less than about 250 °C.
694. The method of claim 685, wherein the electrically resistive ferromagnetic material automatically provides a selected reduced amount of heat above or near a selected temperature.
695. The method of claim 685, wherein an AC resistance of the ferromagnetic material decreases above the selected temperature to provide the reduced amount of heat.
696. The method of claim 685, wherein a thickness of the ferromagnetic material is greater than about 3/4 of a skin depth of AC at the Curie temperature of the ferromagnetic material.
697. The method of claim 685, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
698. The method of claim 685, wherein the selected temperature is less than about 300 °C.
699. The method of claim 685, further comprising providing a reduced amount of heat above or near the selected temperature of less than about 200 watts per meter of length of an electrical conductor.
700. The method of claim 685, further comprising providing a heat output below the selected temperature of greater than about 300 watts per meter of length of an electrical conductor.
701. The method of claim 685, further comprising controlling the amount of current applied to the electrical conductors to control the amount of heat provided by the ferromagnetic material.
702. The method of claim 685, further comprising applying an AC of at least about 70 amps to the electrical conductors.
703. The method of claim 685, further comprising providing a heat output from at least one of the electrical conductors, wherein an AC resistance of such electrical conductors above or near the selected temperature is about 80% or less of the AC resistance of such electrical conductors at about 50°C below the selected temperature.
704. The method of claim 685, further comprising controlling a skin depth in the ferromagnetic material by controlling a frequency of the applied AC.
705. The method of claim 685, further comprising increasing the amount of AC
applied to at least one of the electrical conductors as the temperature of such electrical conductors increases, and continuing to do so until the temperature is at or near the selected temperature.
706. The method of claim 685, further comprising controlling an amount of current applied to at least one of the electrical conductors to control an amount of heat output from such electrical conductors.
707. The method of claim 685, further comprising increasing an amount of current applied to at least one of the electrical conductors to decrease an amount of heat output from such electrical conductors.
708. The method of claim 685, further comprising decreasing an amount of current applied to at least one of the electrical conductors to increase an amount of heat output from such electrical conductors.
709. The method of claim 685, wherein the hydrocarbon containing formation comprises a relatively permeable formation containing heavy hydrocarbons.
710. A method for heating a hydrocarbon containing formation, comprising:
applying AC to one or more electrical conductors placed in an opening in the formation, wherein at least one of the electrical conductors comprises one or more electrically resistive sections;
providing a heat output from at least one of the electrically resistive sections, wherein such electrically resistive sections provide a reduced amount of heat above or near a selected temperature that is about 20% or less of the heat output at about 50 °C below the selected temperature;
allowing the heat to transfer from at least one of the electrically resistive sections to at least a part of the formation such that a temperature in the formation at or near the opening is maintained between about 150 °C and about 250 °C to reduce a viscosity of fluids at or near the opening in the formation; and producing the reduced viscosity fluids through the opening.
711. The method of claim 710, wherein the viscosity of fluids at or near the opening is reduced to less than about 50 centipoise.
712. The method of claim 710, further comprising placing one or more of the electrical conductors in the opening.
713. The method of claim 710, further comprising providing an initial electrically resistive heat output when the electrically resistive section providing the heat output is at least about 50 °C below the selected temperature, and automatically providing the reduced amount of heat above or near the selected temperature.
714. The method of claim 710, further comprising providing a gas to the opening that reduces the density of the reduced viscosity fluids so that the reduced viscosity fluids are pushed out of the opening to the surface of the formation by the formation pressure.
715. The method of claim 710, further comprising producing the reduced viscosity fluids from the opening by pumping the reduced viscosity fluids from the opening.
716. The method of claim 710, further comprising producing the reduced viscosity fluids from the opening through the electrical conductors.
717. The method of claim 710, further comprising producing the reduced viscosity fluids from the opening through a conduit located in the opening.
718. The method of claim 710, further comprising providing a reduced amount of heat above or near the selected temperature that is less than about 20% of the heat output at about 40 °C below the selected temperature.
719. The method of claim 710, further comprising providing a reduced amount of heat above or near the selected temperature that is less than about 20% of the heat output at about 30 °C below the selected temperature.
720. The method of claim 710, further comprising providing a reduced amount of heat above or near the selected temperature that is less than about 15% of the heat output at about 50°C below the selected temperature.
721. The method of claim 710, further comprising providing a reduced amount of heat above or near the selected temperature that is less than about 10% of the heat output at about 50°C below the selected temperature.
722. The method of claim 710, wherein at least one electrically resistive section comprises ferromagnetic material, and wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
723. The method of claim 710, wherein the selected temperature is less than about 300 °C.
724. The method of claim 710, further comprising automatically decreasing an AC resistance of at least one of the electrically resistive sections when such electrically resistive sections are above the selected temperature to provide the reduced amount of heat above the selected temperature.
725. The method of claim 710, further comprising providing a reduced amount of heat above or near the selected temperature of less than about 200 watts per meter of length of an electrical conductor.
726. The method of claim 710, further comprising applying AC of at least about 70 amps to at least one of the electrical conductors.
727. The method of claim 710, wherein the hydrocarbon containing formation comprises a relatively permeable formation containing heavy hydrocarbons.
728. The method of claim 710, wherein the electrically resistive sections are configured to automatically provide the reduced amount of heat above or near the selected temperature.
729. The method of claim 710, wherein the electrically resistive sections automatically provide a selected reduced amount of heat above or near a selected temperature.
730. A system for treating a formation in situ, comprising:
five or more oxidizers configured to be placed in an opening in the formation;
one or more conduits, wherein at least one of the conduits is configured to provide at least oxidizing fluid to the oxidizers, and wherein at least one of the conduits is configured to provide at least fuel to the oxidizers;
wherein the oxidizers are configured to allow combustion of a mixture of the fuel and the oxidizing fluid to produce heat and exhaust gas; and wherein the oxidizers and the conduit configured to provide at least the oxidizing fluid to the oxidizers are configured such that at least a portion of exhaust gas from at least one of the oxidizers is mixed with at least a portion of the oxidizing fluid provided to at least another one of the oxidizers.
731. The system of claim 730, wherein the system comprises ten or more oxidizers configured to be placed in the opening in the formation.
732. The system of claim 730, further comprising a flameless distributed combustors placed in the opening in the formation.
733. The system of claim 730, wherein at least one of the oxidizers comprises a mixing chamber, and wherein the mixing chamber comprises orifices.
734. The system of claim 730, wherein at least one of the oxidizers comprises a mixing chamber, and wherein the mixing chamber comprises at least one static mixer.
735. The system of claim 730, wherein at least one of the oxidizers comprises a constriction configured to increase a flow velocity of the mixture of the fuel and the oxidizing fluid.
736. The system of claim 730, wherein at least one of the oxidizers comprises a mixing chamber and a screen, and wherein the screen is configured such that a flow velocity of fluid through the mixing chamber exceeds a flow velocity of fluid through the screen.
737. The system of claim 730, wherein at least one of the oxidizers comprises a mixing chamber and a screen, and wherein an effective diameter of the screen exceeds an effective diameter of the mixing chamber.
738. The system of claim 730, wherein at least one of the oxidizers comprises a screen, and wherein the screen comprises openings.
739. The system of claim 730, wherein at least one of the oxidizers is positioned in the conduit configured to provide at least oxidizing fluid to the oxidizers.
740. The system of claim 730, wherein a spacing between a terminal oxidizer and the oxidizer adjacent to the terminal oxidizer exceeds a spacing between other pairs of adjacent oxidizers in the system.
741. The system of claim 730, wherein a terminal oxidizer is a catalytic oxidizer.
742. The system of claim 730, wherein a terminal oxidizer is configured to reach a higher peak temperature than the other oxidizers in the system.
743. The system of claim 730, wherein a terminal oxidizer is configured to consume more oxidizing fluid than each of the other oxidizers in the system.
744. The system of claim 730, wherein a terminal oxidizer is configured to oxidize more fuel than each of the other oxidizers in the system.
745. The system of claim 730, wherein the one or more conduits comprise a fuel conduit and an oxidizer conduit, and wherein the fuel conduit is positioned substantially concentrically in the oxidizer conduit.
746. The system of claim 730, wherein the one or more conduits comprise a fuel conduit and an oxidizer conduit, and wherein the fuel conduit and the oxidizers are positioned substantially concentrically in the oxidizer conduit.
747. The system of claim 730, wherein the one or more conduits comprise a fuel conduit and an oxidizer conduit, and wherein the fuel conduit is substantially parallel to the oxidizer conduit.
748. The system of claim 730, wherein the one or more conduits comprise a fuel conduit and an oxidizer conduit, wherein the fuel conduit is substantially parallel to the oxidizer conduit, and wherein the oxidizers are positioned between the fuel conduit and the oxidizer conduit.
749. The system of claim 730, wherein the conduit configured to provide at least the fuel to the oxidizers comprises a catalytic inner surface.
750. The system of claim 730, wherein the conduit configured to provide at least the fuel to the oxidizers is further configured such that at least a portion of exhaust gas from at least one of the oxidizers is mixed with at least a portion of the fuel provided to at least another one of the oxidizers.
751. The system of claim 730, wherein the conduit configured to provide at least the fuel to the oxidizers is further configured such that at least a portion of exhaust gas from at least one of the oxidizers is mixed with at least a portion of the fuel provided to at least another one of the oxidizers.
752. The system of claim 730, further comprising a venturi device coupled to the conduit configured to provide at least the fuel to the oxidizers, wherein the venturi device is configured to provide at least a portion of the exhaust gas from at least one of the oxidizers to the conduit configured to provide at least the fuel to the oxidizers, and wherein the venturi device is further configured to increase a velocity of the fuel flow.
753. The system of claim 730, further comprising a valve coupled to the conduit configured to provide at least the fuel to the oxidizers, wherein the valve is configured to control fuel flow to at least one of the oxidizers.
754. The system of claim 730, further comprising a valve coupled to the conduit configured to provide at least the fuel to the oxidizers, wherein the valve is configured to control fuel flow to at least one of the oxidizers, and wherein the valve is a self-regulating valve.
755. The system of claim 730, wherein one or more of the conduits are configured such that at least a portion of the exhaust gas heats at least a portion of the formation.
756. The system of claim 730, further comprising a membrane positioned in the conduit configured to provide at least oxidizing fluid to the oxidizers, wherein the membrane is configured to increase a concentration of oxygen in the oxidizing fluid.
757. The system of claim 730, further comprising a membrane positioned in the conduit configured to provide at least oxidizing fluid to the oxidizers, wherein the membrane is configured to increase a concentration of oxygen in the oxidizing fluid, and wherein the system is further configured to allow heat to transfer from the exhaust gas to the membrane to increase a concentration of oxygen in the oxidizing fluid.
758. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers.
759. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, and wherein at least one of the oxidizers comprises a catalytic surface proximate one of the ignition sources.
760. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least of the ignition sources comprises an electrical ignition source.
761. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a spark plug, and wherein a voltage of less than about 3000 V is provided to the spark plug.
762. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a spark plug, and wherein a voltage of less than about 1000 V is provided to the spark plug.
763. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a glow plug.
764. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a glow plug, and wherein a voltage of less than about 1000 V is provided to the glow plug.
765. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a glow plug, and wherein a voltage of less than about 630 V is provided to the glow plug.
766. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a glow plug, and wherein a voltage of less than about 120 V is provided to the glow plug.
767. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a glow plug, and wherein a voltage between about V and about 120 V is provided to the glow plug.
768. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a catalytic glow plug.
769. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a temperature limited heater.
770. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a cable with one or more igniter sections.
771. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a cable with one or more igniter sections, and wherein at least one of the igniter sections comprises a temperature limited heater.
772. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a ferromagnetic material.
773. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a mechanical ignition source.
774. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a mechanical ignition source, and wherein the mechanical ignition source is configured to be driven by a fluid.
775. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a mechanical ignition source, and wherein the mechanical ignition source includes a flint stone.
776. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises an electrical generator.
777. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises an electrical generator, and wherein the electrical generator is configured to be driven by a fluid.
778. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a pilot light.
779. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a fireball.
780. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a flame front.
781. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a fireflood.
782. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises catalytic material.
783. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a pyrophoric fluid provided proximate such oxidizers.
784. The system of claim 730, further comprising one or more ignition sources proximate at least one of the oxidizers, wherein at least one of the ignition sources comprises a pellet launching system, one or more explosive pellets, and one or more points of ignition.
785. A method of treating a formation in situ, comprising:
providing fuel to a series of oxidizers positioned in an opening in the formation;
providing oxidizing fluid to the series of oxidizers positioned in the opening in the formation;
mixing at least a portion of the fuel with at least a portion of the oxidizing fluid to form a fuel/oxidizing fluid mixture;
igniting the fuel/oxidizing fluid mixture at or near the oxidizers;
allowing the fuel/oxidizing fluid mixture to react in the oxidizers to produce heat and exhaust gas;
mixing at least a portion of the exhaust gas from one or more of the oxidizers with the oxidizing fluid provided to another one or more of the oxidizers; and allowing heat to transfer from the exhaust gas to a portion of the formation.
786. The method of claim 785, further comprising establishing a pyrolysis zone in at least a portion of the formation.
787. The method of claim 785, further comprising mixing at least a portion of the exhaust gas with at least a portion of the fuel provided to at least one of the oxidizers.
788. The method of claim 785, further comprising introducing at least a portion of the exhaust gas into a flow of at least a portion of the oxidizing fluid to increase a flow velocity of the oxidizing fluid.
789. The method of claim 785, further comprising enriching the oxidizing fluid to increase an oxygen content of the oxidizing fluid.
790. The method of claim 785, further comprising controlling a flow rate of fuel to at least one of the oxidizers.
791. The method of claim 785, further comprising controlling a flow rate of oxidizing fluid to at least one of the oxidizers.
792. The method of claim 785, further comprising providing steam to the fuel to inhibit coking.
793. A system for treating a formation in situ, comprising:
one or more heater assemblies positionable in an opening in the formation, wherein each heater assembly comprises one or more heaters, and wherein the heaters are configured to transfer heat to the formation to establish a pyrolysis zone in the formation;
an optical sensor array positionable along a length of at least one of the heater assemblies, wherein the optical sensor array is configured to transmit one or more signals; and one or more instruments configured to receive at least one of the signals transmitted by the optical sensor array.
794. The system of claim 793, wherein the optical sensor array is configured to operate when a temperature in the opening is up to about 700°C.
795. The system of claim 793, wherein at least one heater assembly comprises an oxidizer positioned in the opening in the formation, and further comprising one or more ignition sources configured to ignite at least one of the oxidizers, and wherein at least one of the instruments is configured to monitor at least one of the oxidizers to determine if such oxidizers are ignited.
796. The system of claim 793, wherein the oxidizers are configured such that heat from at least one of the ignited oxidizers ignites at least one of the oxidizers that is not ignited.
797. The system of claim 793, further comprising a control system in communication with one of the instruments and at least one of the ignition sources, wherein the control system is configured to activate one of the ignition sources to ignite at least one of the oxidizers based on the communication from the instrument.
798. The system of claim 793, further comprising a sleeve positionable adjacent one of the heater assemblies, wherein the optical sensor array is at least partially positionable in the sleeve.
799. The system of claim 793, wherein the optical sensor array comprises a high temperature resistant material.
800. The system of claim 793, wherein the optical sensor array comprises gold.
801. The system of claim 793, wherein the optical sensor array is a high temperature rated optical fiber.
802. The system of claim 793, wherein the optical sensor array is a high temperature rated fiber optic cable.
803. The system of claim 793, wherein at least one of the instruments is configured to analyze a Raman backscattering component of at least one of the signals.
804. The system of claim 793, wherein at least one of the instruments is configured to analyze a Brillouin backscattering component of at least one of the signals.
805. The system of claim 793, wherein at least one of the instruments is configured to analyze a Brillouin backscattering component of at least one of the signals and a Raman backscattering component of at least one of the signals.
806. The system of claim 793, wherein at least one of the instruments is configured to analyze a Rayleigh component of at least one of the signals.
807. The system of claim 793, further comprising a laser configured such that output from the laser is transmitted through the optical sensor array to produce a signal.
808. The system of claim 793, wherein at least one of the instruments is configured to provide a profile of pressure adjacent to at least one of the heater assemblies.
809. The system of claim 793 wherein at least one of the instruments is configured to provide a profile of temperature adjacent to at least one of the heater assemblies.
810. The system of claim 793, wherein at least one of the signals from at least one of the units indicates a temperature and a position of at least one heater in at least one of the heater assemblies.
811. The system of claim 793, wherein at least one of the signals from at least one of the units indicates temperature and strain at one or more locations along at least one of the heater assemblies.
812. The system of claim 793, wherein at least one of the signals from at least one of the units indicates temperature and pressure at one or more locations along at least one of the heater assemblies.
813. The system of claim 793, wherein at least one of the signals from at least one of the units indicates a gas composition at one or more locations along at least one of the heater assemblies.
814. The system of claim 793, further comprising a control system in communication with one of the instruments, wherein the control system is configured to control one or more operating parameters of at least one of the heater assemblies based on communication from at least one of the instruments.
815. A method of monitoring an environment in an opening in a formation, comprising:
providing heat from a heater assembly in the opening of the formation;
repetitively monitoring one or more parameters at two or more locations along a length of the heater assembly with a sensor array;
analyzing at least one of the parameters to assess conditions in the opening of the formation; and using information from the analysis of at least one of the parameters to alter conditions in the opening of the formation, 816. The method of claim 815, wherein repetitively monitoring the one or more parameters comprises continuously monitoring the one or more parameters.
817. The method of claim 815, wherein the optical sensor array is used when a temperature in the opening is up to about 700 °C.
818. The method of claim 815, further comprising monitoring temperature.
819. The method of claim 815, further comprising monitoring pressure.
820. The method of claim 815, further comprising monitoring strain.
821. The method of claim 815, further comprising monitoring gas composition.
822. The method of claim 815, further comprising monitoring temperature and strain.
823. The method of claim 815, further comprising monitoring temperature and pressure.
824. A method for forming a wellbore in a hydrocarbon containing formation, comprising:
forming a first opening of the wellbore beginning at the earth's surface and ending underground;
forming a second opening of the wellbore beginning at the earth's surface and ending underground proximate the first opening; and coupling the openings underground using an expandable conduit.
825. The method of claim 824, further comprising aligning the first opening and the second opening underground using magnetic tracking of a magnet source in the first opening.
826. The method of claim 824, wherein at least a portion of the wellbore is formed substantially horizontally in a hydrocarbon layer of the formation.
827. The method of claim 824, wherein the openings begin substantially in an overburden of the formation.
828. The method of claim 824, wherein the openings begin substantially in an overburden of the formation, and placing reinforcing material in the overburden portions of the openings.
829. The method of claim 824, further comprising forming the first opening by drilling from the earth's surface with machinery located proximate the location of the first opening.
830. The method of claim 824, further comprising coupling the first and second openings by placing an expandable conduit partially in the first opening, partially in the second opening, and in a space between the first and second openings, and then expanding the expandable conduit.
831. The method of claim 824, further comprising forming the second opening by drilling from the earth's surface with machinery located proximate the location of the second opening.
832. The method of claim 824, further comprising placing a casing in the first opening.
833. The method of claim 824, further comprising sealing the expandable conduit to the first opening and the second opening.
834. The method of claim 824, further comprising placing one or more heaters in the wellbore or coupling one or more heaters to the wellbore, wherein at least one of the heaters is configured to provide or transfer heat to at least part of the formation to pyrolyze at least some hydrocarbons in the formation.
835. The method of claim 834, wherein at least one of the heaters comprises one or more oxidizers located in the wellbore.
836. The method of claim 834, wherein at least one of the heaters comprises one or more oxidizers located on the earth's surface, wherein at least one of the oxidizers is coupled to the wellbore.
837. The method of claim 824, further comprising forming a second wellbore in the formation using, at least in part, a magnetic field produced in the wellbore, wherein the second wellbore begins and ends at different locations on the earth's surface.
838. The method of claim 824, further comprising forming at least part of the first opening at an angle with respect to the earth's surface, wherein the angle is between about 25°
and about 90°.
839. The method of claim 824, further comprising forming at least part of the second opening at an angle with respect to the earth's surface, wherein the angle is between about 25°
and about 90°.
840. A system configured to heat at least a part of a subsurface formation, comprising:
one or more electrical conductors configured to be placed in an opening in the formation, wherein at least one electrical conductor comprises at least one electrically resistive portion configured to provide a heat output when alternating current is applied through such electrically resistive portion, and wherein at least one of such electrically resistive portions comprises one or more ferromagnetic materials, and is configured, when above or near a selected temperature and when alternating current is applied, to inherently provide a reduced heat output; and wherein the system is configured to allow heat to transfer from at least one of the electrically resistive portions to at least a part of the subsurface formation.
841. The system of claim 840, wherein at least one electrical conductor is configured to propagate electrical current out of the opening.
842. The system of claim 840, wherein at least one electrical conductor is configured to propagate electrical current into the opening.
843. The system of claim 840, wherein the subsurface formation comprises a hydrocarbon containing formation.
844. The system of claim 840, wherein the subsurface formation comprises a hydrocarbon containing formation, and wherein the system is configured to pyrolyze at least some hydrocarbons in the formation.
845. The system of claim 840, wherein the subsurface formation comprises contaminated soil.
846. The system of claim 840, wherein the subsurface formation comprises contaminated soil, and wherein the system is configured to remediate at least a portion of the contaminated soil.
847. The system of claim 840, wherein the system is configured to provide heat to at least a portion of the opening in the formation.
848. The system of claim 840, further comprising a deformation resistant container, wherein at least a portion of the system is located in the deformation resistant container, and wherein the selected temperature is selected such that the deformation resistant container has a creep-rupture strength of at least about 3000 psi at 100,000 hours at the selected temperature.
849. The system of claim 848, wherein the deformation resistant container comprises an alloy, and the alloy comprises iron, chromium, nickel, manganese, carbon, and tantalum.
850. The system of claim 840, wherein three or more electrical conductors are configured to be coupled in a three-phase electrical configuration.
851. The system of claim 840, wherein at least one electrical conductor comprises an inner conductor and at least one electrical conductor comprises an outer conductor.
852. The system of claim 840, further comprising an electrically insulating material placed between at least two electrical conductors.
853. The system of claim 852, wherein the electrically insulating material comprises ceramic.
854. The system of claim 840, further comprising an electrically insulating material, comprising a packed powder, placed between at least two electrical conductors.
855. The system of claim 840, further comprising a flexible electrically insulating material placed between at least two electrical conductors.
856. The system of claim 840, wherein at least one electrically resistive portion comprises an AC resistance that decreases at, near, or above the selected temperature such that the at least one electrically resistive portion provides the reduced heat output above the selected temperature.
857. The system of claim 840, wherein at least one ferromagnetic material comprises iron, nickel, chromium, cobalt, tungsten, or mixtures thereof.
858. The system of claim 840, wherein at least one ferromagnetic material has a thickness that is at least about 3/4 of a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
859. The system of claim 840, wherein at least one ferromagnetic material has a thickness that is at least about 3/4 of a skin depth of the alternating current at the Curie temperature of the ferromagnetic material, and wherein the ferromagnetic material is coupled to a more conductive material such that, at the Curie temperature of the ferromagnetic material, the electrically resistive portion has a higher conductivity than the electrically resistive portion would if the ferromagnetic material were used, in the same or greater thickness, without the more conductive material.
860. The system of claim 840, wherein at least one electrically resistive portion comprises a first ferromagnetic material with a first Curie temperature, and a second ferromagnetic material with a second Curie temperature.
861. The system of claim 840, wherein at least one ferromagnetic material has a thickness that is at least about a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
862. The system of claim 840, wherein at least one ferromagnetic material has a thickness at least about 1.5 times greater than a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
863. The system of claim 840, wherein at least one ferromagnetic material is coupled to a higher conductivity material.
864. The system of claim 840, wherein at least one ferromagnetic material is coupled to a higher conductivity non-ferromagnetic material.
865. The system of claim 840, wherein the selected temperature is approximately the Curie temperature of at least one ferromagnetic material.
866. The system of claim 840, wherein at least one electrically resistive portion comprises ferromagnetic material and non-ferromagnetic electrically conductive material.
867. The system of claim 840, wherein the subsurface formation comprises a hydrocarbon containing formation, and wherein at least one electrically resistive portion is located proximate a relatively rich zone of the formation.
868. The system of claim 840, wherein at least one electrically resistive portion is located proximate a hot spot of the formation.
869. The system of claim 840, wherein at least one electrically resistive portion comprises carbon steel.
870. The system of claim 840, wherein at least one electrically resistive portion comprises iron.
871. The system of claim 840, wherein at least one ferromagnetic material is coupled to a corrosion resistant material.
872. The system of claim 840, further comprising a corrosion resistant material coated on at least one ferromagnetic material.
873. The system of claim 840, wherein the electrically resistive portion comprises one or more bends.
874. The system of claim 840, wherein the electrically resistive portion comprises a helically shaped portion.
875. The system of claim 840, wherein the electrically resistive portion is part of an insulated conductor heater.
876. The system of claim 840, wherein the electrically resistive portion comprises a thickness of ferromagnetic material, and such ferromagnetic material is coupled to a thickness of a more conductive material, and wherein the thickness of the ferromagnetic material and the thickness of the more conductive material have been selected such that the electrically resistive portion provides a selected resistance profile as a function of temperature.
877. The system of claim 840, wherein the electrically resistive portion comprises a thickness of a ferromagnetic material, and such ferromagnetic material comprises iron, nickel, chromium, cobalt, or mixtures thereof, and such ferromagnetic material is coupled to a thickness of a more conductive material, and wherein the thickness of the ferromagnetic material and the thickness of the more conductive material have been selected such that the electrically resistive portion provides a selected resistance profile as a function of temperature.
878. The system of claim 840, wherein the electrically resistive portion comprises a thickness of a ferromagnetic material, and such ferromagnetic material comprises a first Curie temperature material and a second Curie temperature material, and such ferromagnetic material is coupled to a thickness of a more conductive material, and wherein the thickness of the ferromagnetic material and the thickness of the more conductive material have been selected such that the electrically resistive portion provides a selected resistance profile as a function of temperature.
879. The system of claim 840, wherein the electrically resistive portion comprises a thickness of a ferromagnetic material, and such ferromagnetic material is coupled to a thickness of a more conductive material, and wherein the thickness and skin depth characteristics of the ferromagnetic material, and the thickness of the more conductive material, have been selected such that the electrically resistive portion provides a selected resistance profile as a function of temperature.
880. The system of claim 840, wherein the electrically resistive portion is part of an insulated conductor heater, and the insulated conductor heater is frictionally secured against a cased or open wellbore.
881. The system of claim 840, wherein the electrically resistive portion is part of a conductor-in-conduit heater.
882. The system of claim 840, wherein at least one electrical conductor is electrically coupled to the earth, and wherein electrical current is propagated from the electrical conductor to the earth.
883. The system of claim 840, wherein the reduced heat output is less than about 400 watts per meter.
884. The system of claim 840, wherein at least one electrical conductor comprises at least one section configured to comprise a relatively flat AC resistance profile in a temperature range between about 100 °C and 750 °C.
885. The system of claim 840, wherein at least one electrical conductor comprises at least one section configured to comprise a relatively flat AC resistance profile in a temperature range between about 100 °C and 700 °C, and a relatively sharp resistance profile at a temperature above about 700 °C and less than about 850 °C.
886. The system of claim 840, wherein at least one electrical conductor comprises at least one section configured to comprise a relatively flat AC resistance profile in a temperature range between about 300 °C and 600 °C.
887. The system of claim 840, wherein at least one electrical conductor is greater than about 10 m in length.
888. The system of claim 840, wherein at least one electrical conductor is greater than about 50 m in length.
889. The system of claim 840, wherein at least one electrical conductor is greater than about 100 m in length.
890. The system of claim 840, wherein the system is configured to reduce the heat output such that the system does not overheat in the opening.
891. The system of claim 840, wherein the system is configured to sharply reduce the heat output at or near the selected temperature.
892. The system of claim 840, wherein at least one electrically resistive portion comprises drawn iron.
893. The system of claim 840, wherein at least one electrically resistive portion comprises a ferromagnetic material drawn together or against a more conductive material.
894. The system of claim 840, wherein at least one electrically resistive portion comprises an elongated conduit comprising iron, wherein a center of the conduit is lined or filled with a material comprising copper or aluminum.
895. The system of claim 840, wherein at least one electrically resistive portion comprises an elongated conduit comprising iron, wherein a center of the conduit is filled with a material comprising stranded copper.
896. The system of claim 840, wherein at least one electrically resistive portion comprises an elongated conduit comprising iron, wherein a center of the conduit is lined or filled with a material comprising copper or aluminum, and wherein the copper or aluminum was melted in a center of the conduit and allowed to harden.
897. The system of claim 840, wherein at least one electrically resistive portion comprises an elongated conduit comprising a center portion and an outer portion, and wherein the diameter of the center portion is at least about 0.5 cm and comprises iron.
898. The system of claim 840, wherein at least one electrically resistive portion comprises an elongated conduit comprising a center portion and an outer portion.
899. The system of claim 840, wherein at least one electrically resistive portion comprises an elongated conduit comprising a center portion and an outer portion, wherein the center portion comprises a ferromagnetic material, and wherein a diameter of the center portion is at least about 3/4 of a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
900. The system of claim 840, wherein at least one of the electrically resistive portions comprises a composite material, wherein the composite material comprises a first material that has a resistance that declines when heated to the selected temperature, and wherein the composite material includes a second material that is more electrically conductive than the first material, and wherein the first material is coupled to the second material.
901. The system of claim 840, wherein the system is configured such that, at or near the selected temperature, the heat output of at least a portion of the system declines due to the Curie effect of at least one ferromagnetic material.
902. The system of claim 840, wherein the heat output is reduced below the rate at which the formation will absorb or transfer heat, thereby inhibiting overheating of the formation.
903. The system of claim 840, wherein the electrically resistive portion comprises a magnetic material that, at or near the selected temperature, becomes substantially nonmagnetic.
904. The system of claim 840, wherein the electrically resistive portion is elongated, and configured such that only portions of the electrically resistive portion that are at or near the selected temperature will inherently reduce heat output.
905. The system of claim 840, wherein the system comprises a heater which in turn comprises one or more of the electrically resistive portions.
906. The system of claim 840, configured such that when a temperature of at least one electrically resistive portion is below the selected temperature, and such temperature increases, then an AC resistance of such electrically resistive portion increases.
907. The system of claim 840, configured such that when a temperature of at least one electrically resistive portion is above the selected temperature, and such temperature increases, then an AC resistance of such electrically resistive portion decreases.
908. The system of claim 840, configured that when a temperature of at least one electrically resistive portion is below the selected temperature, and such temperature increases, then an AC
resistance of such electrically resistive portion gradually decreases.
909. The system of claim 840, configured such that when a temperature of at least one electrically resistive portion is above the selected temperature, and such temperature increases, then an AC resistance of such electrically resistive portion sharply decreases.
910. The system of claim 840, configured such that when a temperature of at least one electrically resistive portion is below the selected temperature, and such temperature increases, then an AC resistance of such electrically resistive portion increases, and when a temperature of at least one electrically resistive portion is above the selected temperature, and such temperature increases, then an AC resistance of such electrically resistive portion decreases.
911. The system of claim 840, configured such that when a temperature of at least one electrically resistive portion is below the selected temperature, and such temperature increases, then an AC resistance of such electrically resistive portion increases, and when a temperature of at least one electrically resistive portion is above the selected temperature, and such temperature increases, then an AC resistance of such electrically resistive portion decreases, and wherein the selected temperature is a temperature above the boiling point of water but below a failure temperature of one or more system components.
912. The system of claim 840, configured such that when a temperature of at least one electrically resistive portion is above the selected temperature, and such temperature increases, then an AC resistance of such electrically resistive portion gradually decreases.
913. The system of claim 840, wherein the amount of heat output provided from at least one electrically resistive portion is configured to be determined by the amount of current applied to such electrically resistive portion below the selected temperature.
914. The system of claim 840, wherein the amount of current applied to at least one electrically resistive portion is configured to be increased to decrease the amount of heat output from such electrically resistive portion below the selected temperature.
915. The system of claim 840, wherein the amount of current applied to at least one electrically resistive portion is configured to be decreased to increase the amount of heat output from such electrically resistive portion below the selected temperature.
916. The system of claim 840, wherein the amount of current applied to at least one electrically resistive portion is at least about 70 amps.
917. The system of claim 840, wherein the amount of current applied to at least one electrically resistive portion is at least about 100 amps.
918. The system of claim 840, wherein at least one electrically resistive portion comprises a turndown ratio of at least about 2 to 1.
919. The system of claim 840, wherein the applied current comprises alternating current operating at about 180 Hz AC frequency.
920. The system of claim 840, wherein the applied current comprises alternating current operating at about 60 Hz AC frequency.
921. The system of claim 840, wherein the opening comprises an uncased wellbore.
922. The system of claim 840, wherein the system is configured to radiatively heat the formation in the opening.
923. The system of claim 840, further comprising a fluid placed in the opening, wherein the system is configured to heat the fluid such that the fluid inhibits the opening from collapsing the system.
924. The system of claim 923, wherein the fluid comprises salt.
925. The system of claim 840, wherein the system is configured to withstand operating temperatures of about 250 °C or above.
926. The system of claim 840, wherein the system withstands operating temperatures of about 250 °C or above.
927. The system of claim 840, wherein at least one electrically resistive portion is located in an overburden of the formation.
928. The system of claim 840, wherein at least one electrically resistive portion located in an overburden of the formation is configured to inhibit fluid reflux in the overburden during use.
929. The system of claim 840, wherein at least one electrically resistive portion is coupled to a cable, and wherein the cable comprises a plurality of copper wires coated with an oxidation resistant alloy.
930. The system of claim 929, wherein the oxidation resistant alloy comprises stainless steel.
931. The system of claim 929, wherein the cable is a furnace cable.
932. The system of claim 929, wherein at least a portion of the cable is located inside at least a portion of an electrically resistive portion.
933. The system of claim 929, wherein the cable is electrically insulated with a material comprising mica.
934. The system of claim 929, wherein the cable is electrically insulated with a fiber comprising ceramic and mineral.
935. A method for heating a subsurface formation, comprising:
applying an alternating electrical current to one or more electrical conductors placed in an opening in the formation;
providing a heat output from at least one electrical conductor, wherein at least one electrical conductor comprises one or more electrically resistive portions, wherein at least one electrically resistive portion comprises one or more ferromagnetic materials, and wherein at least one of such electrically resistive portions is configured, when above or near a selected temperature, to inherently provide a reduced heat output; and allowing the heat to transfer from one or more electrically resistive portions to at least a part of the formation.
936. The method of claim 935, further comprising applying the alternating electrical current to the one or more electrical conductors at about 180 Hz operating frequency.
937. The method of claim 935, wherein the heat is allowed to transfer radiatively from the one or more electrically resistive portions to at least a part of the formation.
938. The method of claim 935, wherein the selected temperature is approximately the Curie temperature of at least one ferromagnetic material.
939. The method of claim 935, further comprising providing a relatively constant heat output in a temperature range between about 300 °C and 600 °C.
940. The method of claim 935, further comprising providing a relatively constant heat output in a temperature range between about 100 °C and 750 °C.
941. The method of claim 935, wherein at least one electrically resistive portion comprises an AC resistance that decreases above the selected temperature such that the electrically resistive portion provides the reduced heat output above the selected temperature.
942. The method of claim 935, wherein at least one ferromagnetic material has a thickness of at least about 3/4 of a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
943. The method of claim 935, wherein the subsurface formation comprises a hydrocarbon containing formation.
944. The method of claim 935, wherein the subsurface formation comprises a hydrocarbon containing formation, the method further comprising pyrolyzing at least some hydrocarbons in the formation.
945. The method of claim 935, wherein the subsurface formation comprises contaminated soil.
946. The method of claim 935, wherein the subsurface formation comprises contaminated soil, the method further comprising remediating at least a portion of the contaminated soil.
947. The method of claim 935, wherein the subsurface formation comprises a hydrocarbon containing formation, the method further comprising locating at least one electrically resistive portion proximate a relatively rich zone of the formation.
948. The method of claim 935, further comprising locating at least one electrically resistive portion proximate a hot spot of the formation.
949. The method of claim 935, wherein the subsurface formation comprises a hydrocarbon containing formation, the method further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
950. The method of claim 935, wherein the subsurface formation comprises a hydrocarbon containing formation, the method further comprising controlling a pressure within at least a part of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.
951. The method of claim 935, wherein the subsurface formation comprises a hydrocarbon containing formation, the method further comprising controlling formation conditions such that a produced mixture comprises a partial pressure of HZ within the mixture greater than about 0.5 bars.
952. The method of claim 935, wherein the subsurface formation comprises a hydrocarbon containing formation, the method further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
953. The method of claim 935, wherein the subsurface formation comprises a hydrocarbon containing formation, the method wherein at least a portion of the part of the formation is heated to a minimum pyrolysis temperature of about 270 °C.
954. The method of claim 935, wherein the reduced heat output is less than about 400 watts per meter.
955. The method of claim 935, further comprising controlling a skin depth in at least one electrically resistive portion by controlling a frequency of alternating current applied to at least one electrically resistive portion.
956. The method of claim 935, further comprising applying additional power to at least one electrically resistive portion as the temperature of the electrically resistive portion increases, and continuing to do so until the temperature is at or near the selected temperature.
957. The method of claim 935, wherein the subsurface formation contains at least two portions with different thermal conductivities, and further comprising applying heat to such portions with an electrically resistive portion that is proximate to such portions, and further comprising inherently allowing less heat to be applied from a part of an electrically resistive portion that is proximate a portion of the formation with a lower thermal conductivity.
958. The method of claim 935, wherein the subsurface formation contains at least two portions with different thermal conductivities, and further comprising applying heat to such portions with an electrically resistive portion that is proximate to such portions, and further comprising inherently allowing less heat to be applied from a part of the electrically resistive portion that is proximate a portion of the formation with a lower thermal conductivity while also allowing more heat to be applied from a part of the electrically resistive portion that is proximate a portion of the formation with a higher thermal conductivity.
959. The method of claim 935, wherein the subsurface formation contains at least two layers with different thermal conductivities, and further comprising applying heat to such layers with an electrically resistive portion that is proximate to such layers, and further comprising inherently allowing less heat to be applied from a part of an electrically resistive portion that is proximate a layer of the formation with a lower thermal conductivity.
960. The method of claim 935, wherein the subsurface formation contains at least two layers with different thermal conductivities, and further comprising applying heat to such layers with an electrically resistive portion that is proximate to such layers, and further comprising inherently allowing less heat to be applied from a part of the electrically resistive portion that is proximate a layer of the formation with a lower thermal conductivity while also allowing more heat to be applied from a part of the electrically resistive portion that is proximate a layer of the formation with a higher thermal conductivity.
961. The method of claim 935, further comprising controlling the heat applied from an electrically resistive portion by allowing less heat to be applied from any part of the electrically resistive portion that is at or near the selected temperature.
962. The method of claim 935, wherein an amount of heat output provided from at least one electrically resistive portion is determined by the amount of current applied to the electrical conductors.
963. The method of claim 935, further comprising controlling the amount of current applied to the electrical conductors to control an amount of heat provided by at least one electrically resistive portion.
964. The method of claim 935, further comprising increasing the amount of current applied to the electrical conductors to decrease an amount of heat provided by at least one electrically resistive portion.
965. The method of claim 935, further comprising decreasing the amount of current applied to the electrical conductors to increase an amount of heat provided by at least one electrically resistive portion.
966. The method of claim 935, further comprising applying at least about 70 amps of current to electrical conductors.
967. The method of claim 935, further comprising applying at least about 100 amps of current to electrical conductors.
968. The method of claim 935, further comprising producing fluids from the formation, and producing refined products from the produced fluids.
969. The method of claim 935, further comprising producing fluids from the formation, and producing a blending agent from the produced fluids.
970. The method of claim 935, further comprising producing fluids from the formation, and blending the produced fluids with hydrocarbons having an API gravity below about 15°.
971. A system configured to heat at least a part of a subsurface formation, comprising:
one or more electrical conductors configured to be placed in an opening in the formation, wherein at least one electrical conductor comprises at least one electrically resistive portion configured to provide a heat output when an alternating current is applied through such electrically resistive portion, and wherein at least one of such electrically resistive portions is configured, when operating above or near a selected temperature and when alternating current is applied, to only increase in operating temperature by less than about 1.5 °C when the thermal load decreases by about 1 watt per meter proximate to the one or more electrically resistive portions; and wherein the system is configured to allow heat to transfer from at least one of the electrically resistive portions to at least a part of the formation.
972. The system of claim 971, wherein the subsurface formation comprises a hydrocarbon containing formation.
973. The system of claim 971, wherein the subsurface formation comprises a hydrocarbon containing formation, and wherein the system is configured to pyrolyze at least some hydrocarbons in the formation.
974. The system of claim 971, wherein the subsurface formation comprises contaminated soil.
975. The system of claim 971, wherein the subsurface formation comprises contaminated soil, and wherein the system is configured to remediate at least a portion of the contaminated soil.
976. The system of claim 971, wherein the system is configured to provide heat to at least a portion of the opening in the formation.
977. The system of claim 971, wherein three or more electrical conductors are configured to be coupled in a three-phase electrical configuration.
978. The system of claim 971, further comprising an electrically insulating material placed between at least two electrical conductors.
979. The system of claim 971, wherein at least one electrically resistive portion comprises a ferromagnetic material.
980. The system of claim 971, wherein at least one electrically resistive portion comprises a ferromagnetic material comprising iron, nickel, chromium, cobalt, tungsten, or mixtures thereof.
981. The system of claim 971, wherein at least one electrically resistive portion comprises a ferromagnetic material with a thickness that is at least about 3/4 of a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
982. The system of claim 971, wherein at least one electrically resistive portion comprises a first ferromagnetic material with a first Curie temperature, and a second ferromagnetic material with a second Curie temperature.
983. The system of claim 971, wherein at least one electrically resistive portion comprises ferromagnetic material coupled to a higher conductivity non-ferromagnetic material.
984. The system of claim 971, wherein at least one electrically resistive portion comprises ferromagnetic material, and wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
985. The system of claim 971, wherein the electrically resistive portion comprises a thickness of ferromagnetic material, and such ferromagnetic material is coupled to a thickness of a more conductive material, and wherein the thickness of the ferromagnetic material and the thickness of the more conductive material have been selected such that the electrically resistive portion provides a selected resistance profile as a function of temperature.
986. The system of claim 971, wherein the heat output is greater than about 400 watts per meter below the selected temperature.
987. The system of claim 971, wherein at least one electrical conductor comprises at least one section configured to comprise a relatively flat AC resistance profile in a temperature range between about 100 °C and 750 °C.
988. The system of claim 971, wherein at least one electrical conductor is greater than about 10 m in length.
989. The system of claim 971, wherein the system is configured to sharply reduce the heat output at or near the selected temperature.
990. The system of claim 971, wherein the system is configured such that, at or near the selected temperature, the heat output of at least a portion of the system declines due to the Curie effect.
991. The system of claim 971, wherein the system comprises a heater which in turn comprises one or more of the electrically resistive portions.
992. The system of claim 971, configured such that when a temperature of at least one electrically resistive portion is below the selected temperature, and such temperature increases, then an AC resistance of such electrically resistive portion increases, and when a temperature of at least one electrically resistive portion is above the selected temperature, and such temperature increases, then an AC resistance of such electrically resistive portion decreases.
993. The system of claim 971, wherein the amount of heat output provided from at least one electrically resistive portion is configured to be determined by the amount of current applied to such electrically resistive portion below the selected temperature.
994. The system of claim 971, wherein the amount of current applied to at least one electrically resistive portion is at least about 70 amps.
995. The system of claim 971, wherein at least one electrically resistive portion comprises a turndown ratio of at least about 2 to 1.
996. The system of claim 971, wherein the applied current comprises alternating current operating at about 180 Hz AC frequency.
997. The system of claim 971, wherein the opening comprises an uncased wellbore.
998. The system of claim 971, wherein the system is configured to radiatively heat the formation in the opening.
999. The system of claim 971, wherein the system is configured to withstand operating temperatures of about 250 °C or above.
1000. The system of claim 971, wherein the system withstands operating temperatures of about 250 °C or above.
1001. The system of claim 971, wherein at least one electrically resistive portion is configured to inherently provide a decreased heat output above or near the selected temperature.
1002. The system of claim 971, wherein at least one electrically resistive portion is configured to inherently provide a heat output above or near the selected temperature that is about 20%
or less of the heat output at about 50 °C below the selected temperature.
1003. A heater system, comprising:
an AC supply configured to provide alternating current at a voltage above about 650 volts;
an electrical conductor comprising at least one electrically resistive portion configured to provide a heat output during application of the alternating electrical current to the electrically resistive portion during use; and wherein the electrical conductor comprises a ferromagnetic material and is configured to provide a reduced heat output above or near a selected temperature, wherein the selected temperature is at or about the Curie temperature of the ferromagnetic material.
1004. The heater system of claim 1003, wherein the voltage is above about 1000 volts.
1005. The heater system of claim 1003, wherein the heater is configured to provide heat to a subsurface formation.
1006. The heater system of claim 1003, wherein the heater is configured to provide heat to a hydrocarbon containing formation.
1007. The heater system of claim 1003, wherein the heater is configured to provide heat to a hydrocarbon containing formation, and wherein the system is configured to pyrolyze at least some hydrocarbons in the formation.
1008. The heater system of claim 1003, wherein the heater is configured to provide heat to contaminated soil.
1009. The heater system of claim 1003, wherein the heater is configured to provide heat to contaminated soil, and wherein the system is configured to remediate at least a portion of the contaminated soil.
1010. The heater system of claim 1003, wherein the system is configured to provide heat to at least a portion of an opening in a subsurface formation.
1011. The heater system of claim 1003, wherein three or more electrical conductors are configured to be coupled in a three-phase electrical configuration.
1012. The heater system of claim 1003, wherein the ferromagnetic material comprises iron, nickel, chromium, cobalt, tungsten, or mixtures thereof.
1013. The heater system of claim 1003, wherein the ferromagnetic material has a thickness that is at least about 3/4 of a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
1014. The heater system of claim 1003, further comprising a higher conductivity non-ferromagnetic material coupled to the ferromagnetic material.
1015. The heater system of claim 1003, wherein the heat output is greater than about 400 watts per meter below the selected temperature.
1016. The heater system of claim 1003, wherein the electrical conductor comprises at least one section configured to comprise a relatively flat AC resistance profile in a temperature range between about 100 °C and 750 °C.
1017. The heater system of claim 1003, wherein the electrical conductor is greater than about 10 m in length.
1018. The heater system of claim 1003, wherein the system is configured to sharply reduce the heat output at or near the selected temperature.
1019. The heater system of claim 1003, wherein the system is configured such that, at or near the selected temperature, the heat output of at least a portion of the system declines due to the Curie effect.
1020. The heater system of claim 1003, configured such that when a temperature of the electrical conductor is below the selected temperature, and such temperature increases, then an AC
resistance of the electrical conductor increases, and when a temperature of the electrical conductor is above the selected temperature, and such temperature increases, then an AC resistance of the electrical conductor decreases.
1021. The heater system of claim 1003, wherein the amount of current applied to the electrical conductor is at least about 70 amps.
1022. The heater system of claim 1003, wherein the electrical conductor comprises a turndown ratio of at least about 2 to 1.
1023. The heater system of claim 1003, wherein the alternating current comprises alternating current operating at about 180 Hz AC frequency.
1024. The heater system of claim 1003, wherein the system is configured to withstand operating temperatures of about 250 °C or above.
1025. The heater system of claim 1003, wherein the system withstands operating temperatures of about 250 °C or above.
1026. The heater system of claim 1003, wherein the electrical conductor is configured to inherently provide a decreased heat output above or near the selected temperature.
1027. The heater system of claim 1003, wherein the electrical conductor is configured to inherently provide a heat output above or near the selected temperature that is about 20% or less of the heat output at about 50 °C below the selected temperature.
102. A method of heating, comprising:
providing an alternating current at a voltage above about 650 volts to an electrical conductor comprising at least one electrically resistive portion to provide a heat output; and wherein at least one electrically resistive portion comprises a ferromagnetic material and is configured to provide a reduced heat output above or near a selected temperature, and wherein the selected temperature is at or about the Curie temperature of the ferromagnetic material.
1029. The method of heating of claim 1028, further comprising providing the alternating current to the electrical conductor when the electrical conductor is at or above the selected temperature.
1030. The method of heating of claim 1028, further comprising applying the alternating electrical current to the one or more electrical conductors at about 180 Hz operating frequency.
1031. The method of heating of claim 1028, further comprising allowing heat to transfer from at least one electrically resistive portion to at least a part of a subsurface formation.
1032. The method of heating of claim 1028, further comprising providing a relatively constant heat output in a temperature range between about 300 °C and 600 °C.
1033. The method of heating of claim 1028, further comprising providing a relatively constant heat output in a temperature range between about 100 °C and 750 °C.
1034. The method of heating of claim 1028, wherein at least one electrically resistive portion comprises an AC
resistance that decreases above the selected temperature such that the electrically resistive portion provides the reduced heat output above the selected temperature.
1035. The method of heating of claim 1028, wherein at least one ferromagnetic material has a thickness of at least about 3/4 of a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
1036. The method of heating of claim 1028, further comprising allowing heat to transfer from at least one electrically resistive portion to at least a part of a subsurface formation, wherein the subsurface formation comprises a hydrocarbon containing formation.
1037. The method of heating of claim 1028, further comprising allowing heat to transfer from at least one electrically resistive portion to at least a part of a hydrocarbon containing formation, and pyrolyzing at least some hydrocarbons in the formation.
1038. The method of heating of claim 1028, wherein the reduced heat output is less than about 400 watts per meter.
1039. The method of heating of claim 1028, further comprising controlling a skin depth in at least one electrically resistive portion by controlling a frequency of alternating current applied to at least one electrically resistive portion.
1040. The method of heating of claim 1028, further comprising applying additional power to at least one electrically resistive portion as the temperature of the electrically resistive portion increases, and continuing to do so until the temperature is at or near the selected temperature.
1041. The method of heating of claim 1028, further comprising controlling the heat applied from an electrically resistive portion by allowing less heat to be applied from any part of the electrically resistive portion that is at or near the selected temperature.
1042. The method of heating of claim 1028, wherein an amount of heat output provided from at least one electrically resistive portion is determined by the amount of current applied to the electrical conductors.
1043. The method of heating of claim 1028, further comprising controlling the amount of current applied to the electrical conductors to control an amount of heat provided by at least one electrically resistive portion.
1044. The method of heating of claim 1028, further comprising applying at least about 70 amps of current to the electrical conductors.
1045. The method of heating of claim 1028, further comprising applying at least about 100 amps of current to the electrical conductors.
1046. A system configured to heat at least a part of a subsurface formation, comprising:
one or more electrical conductors configured to be placed in an opening in the formation, wherein at least one electrical conductor comprises at least one electrically resistive portion that comprises at least one ferromagnetic material, and is configured to provide a heat output when an alternating current is provided to such electrically resistive portion, and wherein at least one of such electrically resistive portions is configured, when above or near a selected temperature, to inherently exhibit a decreased AC
resistance; and wherein the system is configured to allow heat to transfer from at least one of the electrically resistive portions to at least a part of the formation.
1047. The system of claim 1046, wherein the subsurface formation comprises a hydrocarbon containing formation.
1048. The system of claim 1046, wherein the subsurface formation comprises a hydrocarbon containing formation, and wherein the system is configured to pyrolyze at least some hydrocarbons in the formation.
1049. The system of claim 1046, wherein the subsurface formation comprises contaminated soil.
1050. The system of claim 1046, wherein the subsurface formation comprises contaminated soil, and wherein the system is configured to remediate at least a portion of the contaminated soil.
1051. The system of claim 1046, wherein the system is configured to provide heat to at least a portion of the opening in the formation.
1052. The system of claim 1046, wherein the decreased AC resistance is less than about 80% of the AC
resistance at about 50 °C below the selected temperature.
1053. The system of claim 1046, wherein three or more electrical conductors are configured to be coupled in a three-phase electrical configuration.
1054. The system of claim 1046, further comprising an electrically insulating material placed between at least two electrical conductors.
1055. The system of claim 1046, wherein at least one ferromagnetic material comprises iron, nickel, chromium, cobalt, tungsten, or mixtures thereof.
1056. The system of claim 1046, wherein at least one ferromagnetic material has a thickness that is at least about 3/4 of a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
1057. The system of claim 1046, wherein at least one electrically resistive portion comprises ferromagnetic material coupled to a higher conductivity non-ferromagnetic material.
1058. The system of claim 1046, wherein the selected temperature is approximately the Curie temperature of at least one ferromagnetic material.
1059. The system of claim 1046, wherein the electrically resistive portion comprises a thickness of ferromagnetic material, and such ferromagnetic material is coupled to a thickness of a more conductive material, and wherein the thickness of the ferromagnetic material and the thickness of the more conductive material have been selected such that the electrically resistive portion provides a selected resistance profile as a function of temperature.
1060. The system of claim 1046, wherein the heat output is greater than about 400 watts per meter below the selected temperature.
1061. The system of claim 1046, wherein at least one electrical conductor comprises at least one section configured to comprise a relatively flat AC resistance profile in a temperature range between about 100 °C and 750 °C.
1062. The system of claim 1046, wherein at least one electrical conductor is greater than about 10 m in length.
1063. The system of claim 1046, wherein the system is configured to sharply reduce the heat output at or near the selected temperature.
1064. The system of claim 1046, wherein the system is configured such that, at or near the selected temperature, the heat output of at least a portion of the system declines due to the Curie effect.
1065. The system of claim 1046, wherein the amount of heat output provided from at least one electrically resistive portion is configured to be determined by the amount of current applied to such electrically resistive portion below the selected temperature.
1066. The system of claim 1046, wherein the amount of current applied to at least one electrically resistive portion is at least about 70 amps.
1067. The system of claim 1,046, wherein at least one electrically resistive portion comprises a turndown ratio of at least about 2 to 1.
1068. The system of claim 1046, wherein the applied current comprises alternating current operating at about 180 Hz AC frequency.
1069. The system of claim 1046, wherein the opening comprises an uncased wellbore.
1070. The system of claim 1046, wherein the system is configured to radiatively heat the formation in the opening.
1071. The system of claim 1046, wherein the system is configured to withstand operating temperatures of about 250 °C or above.
1072. The system of claim 1046, wherein at least one electrically resistive portion is configured to inherently provide a decreased heat output above or near the selected temperature.
1073. The system of claim 1046, wherein at least one electrically resistive portion is configured to inherently provide a heat output above or near the selected temperature that is about 20%
or less of the heat output at about 50 °C below the selected temperature.
1074. A subsurface heating system, comprising:
one or more electrical conductors configured to be placed in an opening in the subsurface, wherein at least one electrical conductor comprises at least one electrically resistive portion configured to provide a heat output when an alternating current is applied through such electrically resistive portion, and wherein at least one of such electrically resistive portions is configured, when above or near a selected temperature, to provide a reduced heat output that is about 20% or less of the heat output provided at about 50 °C below the selected temperature; and wherein the system is configured to allow heat to transfer from at least one of the electrically resistive portions to at least a part of the subsurface.
1075. The system of claim 1074, wherein the subsurface comprises a hydrocarbon containing formation.
1076. The system of claim 1074, wherein the subsurface comprises a hydrocarbon containing formation, and wherein the system is configured to pyrolyze at least some hydrocarbons in the formation.
1077. The system of claim 1074, wherein the subsurface comprises contaminated soil.
1078. The system of claim 1074, wherein the subsurface comprises contaminated soil, and wherein the system is configured to remediate at least a portion of the contaminated soil.
1079. The system of claim 1074, wherein the system is configured to provide heat to at least a portion of the opening in the subsurface.
1080. The system of claim 1074, wherein the reduced heat output is less than about 20% of the heat output at about 40 °C below the selected temperature.
1081. The system of claim 1074, wherein the reduced heat output is less than about 20% of the heat output at about 30 °C below the selected temperature.
1082. The system of claim 1074, wherein the reduced heat output is less than about 15% of the heat output at about 50 °C below the selected temperature.
1083. The system of claim 1074, wherein the reduced heat output is less than about 10% of the heat output at about 50 °C below the selected temperature.
1084. The system of claim 1074, wherein three or more electrical conductors are configured to be coupled in a three-phase electrical configuration.
1085. The system of claim 1074, wherein at least one electrically resistive portion has an AC resistance that decreases at, near, or above the selected temperature such that the heat output provided by at least one electrically resistive portion decreases above or near the selected temperature.
1086. The system of claim 1074, wherein at least one electrically resistive portion comprises a ferromagnetic material.
1087. The system of claim 1074, wherein at least one electrically resistive portion comprises a ferromagnetic material comprising iron, nickel, chromium, cobalt, tungsten, or mixtures thereof.
1088. The system of claim 1074, wherein at least one electrically resistive portion comprises a ferromagnetic material with a thickness that is at least about 3/4 of a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
1089. The system of claim 1074, wherein at least one electrically resistive portion comprises a first ferromagnetic material with a first Curie temperature, and a second ferromagnetic material with a second Curie temperature.
1090. The system of claim 1074, wherein at least one electrically resistive portion comprises ferromagnetic material coupled to a higher conductivity non-ferromagnetic material.
1091. The system of claim 1074, wherein at least one electrically resistive portion comprises ferromagnetic material, and wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1092. The system of claim 1074, wherein the electrically resistive portion comprises a thickness of ferromagnetic material, and such ferromagnetic material is coupled to a thickness of a more conductive material, and wherein the thickness of the ferromagnetic material and the thickness of the more conductive material have been selected such that the electrically resistive portion provides a selected resistance profile as a function of temperature.
1093. The system of claim 1074, wherein the heat output is greater than about 400 watts per meter below the selected temperature.
1094. The system of claim 1074, wherein at least one electrical conductor comprises at least one section configured to comprise a relatively flat AC resistance profile in a temperature range between about 100 °C and 750 °C.
1095. The system of claim 1074, wherein at Least one electrical conductor is greater than about 10 m in length.
1096. The system of claim 1074, wherein the system is configured to sharply reduce the heat output at or near the selected temperature.
1097. The system of claim 1074, wherein the system is configured such that, at or near the selected temperature, the heat output of at least a portion of the system declines due to the Curie effect.
1098. The system of claim 1074, configured such that when a temperature of at least one electrically resistive portion is below the selected temperature, and such temperature increases, then an AC resistance of such electrically resistive portion increases, and when a temperature of at least one electrically resistive portion is above the selected temperature, and such temperature increases, then an AC resistance of such electrically resistive portion decreases.
1099. The system of claim 1074, wherein the amount of heat output provided from at least one electrically resistive portion is configured to be determined by the amount of current applied to such electrically resistive portion below the selected temperature.
1100. The system of claim 1074, wherein the amount of current applied to at least one electrically resistive portion is at least about 70 amps.
1101. The system of claim 1074, wherein at least one electrically resistive portion comprises a turndown ratio of at least about 2 to 1.
1102. The system of claim 1074, wherein the applied current comprises alternating current operating at about 180 Hz AC frequency.
1103. The system of claim 1074, wherein the opening comprises an uncased wellbore.
1104. The system of claim 1074, wherein the system is configured to withstand operating temperatures of about 250 °C or above.
1105. The system of claim 1074, wherein at least one electrically resistive portion comprises a decreased AC
resistance above or near the selected temperature that is less than about 80%
of an AC resistance at about 50 °C
below the selected temperature.
1106. A wellbore heating system, comprising:
one or more electrical conductors configured to be placed in the wellbore in the formation, wherein at least one electrical conductor comprises at least one electrically resistive portion configured to provide a heat output when alternating current is applied through such electrically resistive portion, and wherein at least one of such electrically resistive portions is configured such that the electric resistance though the electrically resistive portion decreases by at least about 20% when above or near a selected temperature, as compared to the electrical resistance at about 50 °C below the selected temperature; and wherein the system is configured to allow heat to transfer from at least one of the electrically resistive portions to at least a part of the wellbore.
1107. The system of claim 1106, wherein the decreased electrical resistance provides a decreased heat output when above or near the selected temperature.
110. The system of claim 1106, wherein the electric resistance though the electrically resistive portion decreases by at least about 30% when above or near a selected temperature, as compared to the electrical resistance at about 50 °C below the selected temperature.
1109. The system of claim 1106, wherein the electric resistance though the electrically resistive portion decreases by at least about 40% when above or near a selected temperature, as compared to the electrical resistance at about 50 °C below the selected temperature.
1110. The system of claim 1106, wherein the electric resistance through the electrically resistive portion decreases by at least about 50% when above or near a selected temperature, as compared to the electrical resistance at about 50 °C below the selected temperature.
1111. The system of claim 1106, wherein the wellbore is located in a subsurface formation.
1112. The system of claim 1106, wherein the wellbore is located in a hydrocarbon containing formation, and wherein the system is configured to pyrolyze at least some hydrocarbons in the formation.
1113. The system of claim 1106, wherein the wellbore is located in contaminated soil.
1114. The system of claim 1106, wherein the wellbore is located in contaminated soil, and wherein the system is configured to remediate at least a portion of the contaminated soil.
1115. The system of claim 1106, wherein three or more electrical conductors are configured to be coupled in a three-phase electrical configuration.
1116. The system of claim 1106, further comprising an electrically insulating material placed between at least two electrical conductors.
1117. The system of claim 1106, wherein at least one electrically resistive portion comprises a ferromagnetic material.
111. The system of claim 1106, wherein at least one electrically resistive portion comprises a ferromagnetic material comprising iron, nickel, chromium, cobalt, tungsten, or mixtures thereof.
1119. The system of claim 1106, wherein at least one electrically resistive portion comprises a ferromagnetic material with a thickness that is at least about 3/4 of a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
1120. The system of claim 1206, wherein at least one electrically resistive portion comprises a first ferromagnetic material with a first Curie temperature, and a second ferromagnetic material with a second Curie temperature.
1121. The system of claim 1106, wherein at least one electrically resistive portion comprises ferromagnetic material coupled to a higher conductivity non-ferromagnetic material.
1122. The system of claim 1106, wherein at least one electrically resistive portion comprises ferromagnetic material, and wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1123. The system of claim 1106, wherein the electrically resistive portion comprises a thickness of ferromagnetic material, and such ferromagnetic material is coupled to a thickness of a more conductive material, and wherein the thickness of the ferromagnetic material and the thickness of the more conductive material have been selected such that the electrically resistive portion provides a selected resistance profile as a function of temperature.
1124. The system of claim 1106, wherein the heat output is greater than about 400 watts per meter below the selected temperature.
1125. The system of claim 1106, wherein at least one electrical conductor comprises at least one section configured to comprise a relatively flat AC resistance profile in a temperature range between about 100 °C and 750 °C.
1126. The system of claim 1106, wherein at least one electrical conductor is greater than about 10 m in length.
1127. The system of claim 1106, wherein the system is configured to sharply reduce the heat output at or near the selected temperature.
112. The system of claim 1106, wherein the system is configured such that, at or near the selected temperature, the heat output of at least a portion of the system declines due to the Curie effect.
1129. The system of claim 1106, wherein the amount of heat output provided from at least one electrically resistive portion is configured to be determined by the amount of current applied to such electrically resistive portion below the selected temperature.
1130. The system of claim 1106, wherein the amount of current applied to at least one electrically resistive portion is at least about 70 amps.
1131. The system of claim 1106, wherein at least one electrically resistive portion comprises a turndown ratio of at least about 2 to 1.
1132. The system of claim 1106, wherein the applied current comprises alternating current operating at about 180 Hz AC frequency.
1133. The system of claim 1106, wherein the wellbore comprises an uncased wellbore.
1134. The system of claim 1106, wherein the system is configured to withstand operating temperatures of about 250 °C or above.
1135. The system of claim 1106, wherein at least one electrically resistive portion is configured to provide a reduced heat output above or near the selected temperature that is less than about 20% of the heat output provided at about 50 °C below the selected temperature.
1136. A wellbore heating system, comprising:
one or more electrical conductors configured to be placed in the wellbore in the formation, wherein at least one electrical conductor comprises at least one electrically resistive portion configured to provide a heat output when alternating current is applied through such electrically resistive portion, and wherein at least one of such electrically resistive portions has, when above or near a selected temperature, a decreased AC resistance that is about 80% or less of an AC resistance at about 50 °C below the selected temperature; and wherein the system is configured to allow heat to transfer from at least one of the electrically resistive portions to at least a part of the wellbore.
1137. The system of claim 1136, wherein the wellbore is located in a subsurface formation.
1138. The system of claim 1136, wherein the wellbore is located in a hydrocarbon containing formation, and wherein the system is configured to pyrolyze at least some hydrocarbons in the formation.
1139. The system of claim 1136, wherein the wellbore is located in contaminated soil.
1140. The system of claim 1136, wherein the wellbore is located in contaminated soil, and wherein the system is configured to remediate at least a portion of the contaminated soil.
1141. The system of claim 1236, wherein the decreased AC resistance is about 70% or less of the AC resistance at about 50 °C below the selected temperature.
1142. The system of claim 1136, wherein the decreased AC resistance is about 60% or less of the AC resistance at about 50 °C below the selected temperature.
1143. The system of claim 1136, wherein the decreased AC resistance is about 50% or less of the AC resistance at about 50 °C below the selected temperature.
1144. The system of claim 1136, wherein the decreased AC resistance is about 80% or less of the AC resistance at about 40 °C below the selected temperature.
1145. The system of claim 1136, wherein the decreased AC resistance is about 80% or less of the AC resistance at about 30 °C below the selected temperature.
1146. The system of claim 1136, wherein three or more electrical conductors are configured to be coupled in a three-phase electrical configuration.
1147. The system of claim 1136, further comprising an electrically insulating material placed between at least two electrical conductors.
1148. The system of claim 1136, wherein at least one electrically resistive portion comprises a ferromagnetic material.
1149. The system of claim 1136, wherein at least one electrically resistive portion comprises a ferromagnetic material comprising iron, nickel, chromium, cobalt, tungsten, or mixtures thereof.
1150. The system of claim 1136, wherein at least one electrically resistive portion comprises a ferromagnetic material with a thickness that is at least about 3/4 of a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
1151. The system of claim 1136, wherein at least one electrically resistive portion comprises a first ferromagnetic material with a first Curie temperature, and a second ferromagnetic material with a second Curie temperature.
1152. The system of claim 1136, wherein at least one electrically resistive portion comprises ferromagnetic material coupled to a higher conductivity non-ferromagnetic material.
1153. The system of claim 1136, wherein at least one electrically resistive portion comprises ferromagnetic material, and wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1154. The system of claim 1136, wherein the electrically resistive portion comprises a thickness of ferromagnetic material, and such ferromagnetic material is coupled to a thickness of a more conductive material, and wherein the thickness of the ferromagnetic material and the thickness of the more conductive material have been selected such that the electrically resistive portion provides a selected resistance profile as a function of temperature.
1155. The system of claim 1136, wherein the heat output is greater than about 400 watts per meter below the selected temperature.
1156. The system of claim 1136, wherein at least one electrical conductor comprises at least one section configured to comprise a relatively flat AC resistance profile in a temperature range between about 100 °C and 750 °C.
1157. The system of claim 1136, wherein at least one electrical conductor is greater than about 10 m in length.
1158. The system of claim 1136, wherein the system is configured to sharply reduce the heat output at or near the selected temperature.
1159. The system of claim 1136, wherein the system is configured such that, at or near the selected temperature, the heat output of at least a portion of the system declines due to the Curie effect.
1160. The system of claim 1136, wherein the amount of heat output provided from at least one electrically resistive portion is configured to be determined by the amount of current applied to such electrically resistive portion below the selected temperature.
1161. The system of claim 1136, wherein the amount of current applied to at least one electrically resistive portion is at least about 70 amps.
1162. The system of claim 1136, wherein at least one electrically resistive portion comprises a turndown ratio of at least about 2 to 1.
1163. The system of claim 1136, wherein the applied current comprises alternating current operating at about 180 Hz AC frequency.
1164. The system of claim 1136, wherein the wellbore comprises an uncased wellbore.
1165. The system of claim 1136, wherein the system is configured to withstand operating temperatures of about 250 °C or above.
1166. The system of claim 1136, wherein at least one electrically resistive portion is configured to provide a reduced heat output above or near the selected temperature that is less than about 20% of the heat output provided at about 50 °C below the selected temperature.
1167. A method for heating a subsurface formation, comprising:
applying an alternating electrical current to one or more electrical conductors placed in an opening in the formation, wherein at least one electrical conductor comprises one or more electrically resistive portions, and wherein at least one electrically resistive portion comprises one or more ferromagnetic materials;
providing a heat output from at least one electrically resistive portion, wherein at least one of such electrically resistive portions is configured, when above or near a selected temperature, to inherently exhibit a decreased AC resistance; and allowing the heat to transfer from one or more electrically resistive portions to at least a part of the formation.
1168. The method of claim 1167, further comprising applying the alternating electrical current to the one or more electrical conductors at about 180 Hz operating frequency.
1169. The method of claim 1167, wherein the heat is allowed to transfer radiatively from the one or more electrically resistive portions to at least a part of the formation.
1170. The method of claim 1167, wherein the selected temperature is approximately the Curie temperature of at least one ferromagnetic material.
1171. The method of claim 1167, further comprising providing a relatively constant heat output in a temperature range between about 100 °C and 750 °C.
1172. The method of claim 1167, wherein at least one electrically resistive portion comprises an AC resistance that decreases above the selected temperature such that the electrically resistive portion provides the reduced heat output above the selected temperature.
1173. The method of claim 1167, wherein the subsurface formation comprises a hydrocarbon containing formation.
1174. The method of claim 1167, wherein the subsurface formation comprises a hydrocarbon containing formation, the method further comprising pyrolyzing at least some hydrocarbons in the formation.
1175. The method of claim 1167, wherein the subsurface formation comprises a hydrocarbon containing formation, the method further comprising locating at least one electrically resistive portion proximate a relatively rich zone of the formation.
1176. The method of claim 1167, wherein the reduced heat output is less than about 400 watts per meter.
1177. The method of claim 1167, further comprising applying at least about 70 amps of current to the electrical conductors.
1178. The method of claim 1167, further comprising producing fluids from the formation, and producing refined products from the produced fluids.
1179. The method of claim 1167, further comprising producing fluids from the formation, and producing a blending agent from the produced fluids.
1180. The method of claim 1167, further comprising producing fluids from the formation, and blending the produced fluids with hydrocarbons having an API gravity below about 15°.
1181. A method for heating a subsurface formation, comprising:
applying an alternating electrical current to one or more electrical conductors placed in an opening in the formation, wherein at least one electrical conductor comprises one or more electrically resistive portions;
providing a heat output from at least one electrically resistive portion, wherein at least one of such electrically resistive portions is configured, when above or near a selected temperature, to provide a heat output that is about 20% or less of the heat output at about 50 °C below the selected temperature; and allowing the heat to transfer from one or more electrically resistive portions to at least a part of the formation.
1182. The method of claim 118I, further comprising applying the alternating electrical current to the one or more electrical conductors at about 180 Hz operating frequency.
1183. The method of claim 1181, wherein the reduced heat output is less than about 20% of the heat output at about 40 °C below the selected temperature.
1184. The method of claim 1181, wherein the reduced heat output is less than about 20% of the heat output at about 30 °C below the selected temperature.
1185. The method of claim 1181, wherein the reduced heat output is less than about 15% of the heat output at about 50 °C below the selected temperature.
116. The method of claim 1281, wherein the reduced heat output is less than about 10% of the heat output at about 50 °C below the selected temperature.
1187. The method of claim 1181, wherein the heat is allowed to transfer radiatively from the one or more electrically resistive portions to at least a part of the formation.
118. The method of claim 1181, wherein the selected temperature is approximately the Curie temperature of at least one ferromagnetic material.
119. The method of claim 1181, further comprising providing a relatively constant heat output in a temperature range between about 100 °C and 750 °C.
1190. The method of claim 1181, wherein at least one electrically resistive portion comprises an AC resistance that decreases above the selected temperature such that the electrically resistive portion provides the reduced heat output above the selected temperature.
1191. The method of claim 1181, wherein the subsurface formation comprises a hydrocarbon containing formation.
1192. The method of claim 1181, wherein the subsurface formation comprises a hydrocarbon containing formation, the method further comprising pyrolyzing at least some hydrocarbons in the formation.
1193. The method of claim 1181, wherein the subsurface formation comprises a hydrocarbon containing formation, the method further comprising locating at least one electrically resistive portion proximate a relatively rich zone of the formation.
1194. The method of claim 1181, wherein the reduced heat output is less than about 400 watts per meter.
1195. The method of claim 1181, further comprising applying at least about 70 amps of current to the electrical conductors.
1196. A method for heating a subsurface formation, comprising:
applying an alternating electrical current to one or more electrical conductors placed in an opening in the formation, wherein at least one electrical conductor comprises one or more electrically resistive portions;
providing a heat output from at least one electrically resistive portion, wherein at least one of such electrically resistive portions, when above or near a selected temperature, has a decreased AC resistance that is about 80% or less of the AC resistance at about 50 °C below the selected temperature; and allowing the heat to transfer from one or more electrically resistive portions to at least a part of the formation.
1197. The method of claim 1196, further comprising applying the alternating electrical current to the one or more electrical conductors at about 180 Hz operating frequency.
1198. The method of claim 1296, wherein the decreased AC resistance is about 70% or less of the AC resistance at about 50 °C below the selected temperature.
1199. The method of claim 1196, wherein the decreased AC resistance is about 60% or less of the AC resistance at about 50 °C below the selected temperature.
1200. The method of claim 1196, wherein the decreased AC resistance is about 50% or less of the AC resistance at about 50 °C below the selected temperature.
1201. The method of claim 1196, wherein the decreased AC resistance is about 80% or less of the AC resistance at about 40 °C below the selected temperature.
1202. The method of claim 1196, wherein the decreased AC resistance is about 80% or less of the AC resistance at about 30 °C below the selected temperature.
1203. The method of claim 1196, wherein the heat is allowed to transfer radiatively from the one or more electrically resistive portions to at least a part of the formation.
1204. The method of claim 1196, wherein the selected temperature is approximately the Curia temperature of at least one ferromagnetic material.
1205. The method of claim 1196, further comprising providing a relatively constant heat output in a temperature range between about 100 °C and 750 °C.
1206. The method of claim 1196, wherein at least one electrically resistive portion comprises an AC resistance that decreases above the selected temperature such that the electrically resistive portion provides the reduced heat output above the selected temperature.
1207. The method of claim 1196, wherein the subsurface formation comprises a hydrocarbon containing formation.
1208. The method of claim 1196, wherein the subsurface formation comprises a hydrocarbon containing formation, the method further comprising pyrolyzing at least some hydrocarbons in the formation.
1209. The method of claim 1196, wherein the subsurface formation comprises a hydrocarbon containing formation, the method further comprising locating at least one electrically resistive portion proximate a relatively rich zone of the formation.
1210. The method of claim 1196, wherein the reduced heat output is less than about 400 watts per meter.
1211. The method of claim 1196, further comprising applying at least about 70 amps of current to electrical conductors.
1212. A system configured to heat at least a part of a subsurface formation, comprising:
one or more electrical conductors configured to be placed in an opening in the formation, wherein at least one electrical conductor comprises an electrically resistive ferromagnetic material configured to provide, when energized by an alternating current, a reduced heat output above or near a selected temperature; and wherein the system is configured to allow heat to transfer from the electrical conductors to a part of the formation.
1213. The system of claim 1212, wherein the subsurface formation comprises a hydrocarbon containing formation.
1214. The system of claim 1212, wherein the subsurface formation comprises a hydrocarbon containing formation, and wherein the system is configured to pyrolyze at least some hydrocarbons in the formation.
1215. The system of claim 1212, wherein the subsurface formation comprises contaminated soil.
1216. The system of claim 1212, wherein the subsurface formation comprises contaminated soil, and wherein the system is configured to remediate at least a portion of the contaminated soil.
1217. The system of claim 1212, wherein the system is configured to provide heat to at least a portion of the opening in the formation.
1218. The system of claim 1212, wherein three or more electrical conductors are configured to be coupled in a three-phase electrical configuration.
1219. The system of claim 1212, wherein at least one electrical conductor comprises an inner conductor and at least one electrical conductor comprises an outer conductor.
1220. The system of claim 1212, further comprising an electrically insulating material placed between at least two electrical conductors.
1221. The system of claim 1212, wherein the ferromagnetic material comprises an AC resistance that decreases above the selected temperature such that the system provides the reduced heat output above the selected temperature.
1222. The system of claim 1212, further comprising a higher conductivity non-ferromagnetic material coupled to the ferromagnetic material.
1223. The system of claim 1212, further comprising a second ferromagnetic material coupled to the ferromagnetic material.
1224. The system of claim 1212, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1225. The system of claim 1212, wherein at least one electrical conductor is electrically coupled to the earth, and wherein electrical current is propagated from the electrical conductor to the earth.
1226. The system of claim 1212, wherein the reduced heat output is less than about 400 watts per meter.
1227. The system of claim 1212, wherein the heat output is greater than about 400 watts per meter below the selected temperature.
1228. The system of claim 1212, wherein at least one electrical conductor comprises at least one section configured to comprise a relatively flat AC resistance profile in a temperature range between about 100 °C and 750 °C.
1229. The system of claim 1212, wherein at least one electrical conductor is greater than about 10 m in length.
1230. The system of claim 1212, wherein the amount of current applied to the ferromagnetic material is at least about 70 amps.
1231. The system of claim 1212, wherein the ferromagnetic material comprises a turndown ratio of at least about 2 to 1.
1232. A method for heating a subsurface formation, comprising:
applying an alternating electrical current to one or more electrical conductors placed in an opening in the formation, wherein at least one electrical conductor comprises a ferromagnetic material;
providing a heat output, wherein the ferromagnetic material is configured to provide a reduced heat output above or near a selected temperature; and allowing the heat to transfer from the one or more electrical conductors to a part of the formation.
1233. The method of claim 1232, further comprising providing a relatively constant heat output in a temperature range between about 100 °C and 750 °C.
1234. The method of claim 1232, wherein the ferromagnetic material comprises an AC resistance that decreases above the selected temperature such that the ferromagnetic material provides the reduced heat output above the selected temperature.
1235. The method of claim 1232, wherein the ferromagnetic material comprises a thickness greater than about 3/4 of a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
1236. The method of claim 1232, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1237. The method of claim 1232, wherein the subsurface formation comprises a hydrocarbon containing formation.
1238. The method of claim 1232, wherein the subsurface formation comprises a hydrocarbon containing formation, the method further comprising pyrolyzing at least some hydrocarbons in the formation.
1239. The method of claim 1232, wherein the reduced heat output is less than about 400 watts per meter.
1240. The method of claim 1232, wherein the heat output is greater than about 400 watts per meter below the selected temperature.
1241. The method of claim 1232, further comprising controlling the amount of current applied to the ferromagnetic material to control the amount of heat provided by the ferromagnetic material.
1242. The method of claim 1232, further comprising applying at least about 70 amps of current to the ferromagnetic material.
1243. A system configured to heat at least a part of a subsurface formation, comprising:
one or more electrical conductors configured to be placed in an opening in the formation, wherein at least one electrical conductor comprises a ferromagnetic material configured to provide a reduced heat output above or near a selected temperature, wherein at least one electrical conductor is electrically coupled to the earth, and wherein alternating electrical current propagates from the electrical conductor to the earth; and wherein the system is configured to allow heat to transfer from the electrical conductors to a part of the formation.
1244. The system of claim 1243, wherein at least one electrical conductor is electrically coupled to the earth through an electrical contacting section.
1245. The system of claim 1243, wherein the electrical contacting section comprises a second opening coupled to the opening.
1246. The system of claim 1243, wherein the electrical contacting section comprises a second opening coupled to the opening and having a larger diameter than the opening.
1247. The system of claim 1243, wherein the electrical contacting section comprises a second opening coupled to the opening, and wherein the second opening is filled with a material that enhances electrical contact between at least one electrical conductor and the earth.
1248. The system of claim 1243, wherein at least one electrical conductor is configured to propagate electrical current into the opening.
1249. The system of claim 1243, wherein at least one electrical conductor is configured to propagate electrical current out of the opening.
1250. The system of claim 1243, wherein three or more electrical conductors are configured to be coupled in a three-phase electrical configuration.
1251. The system of claim 1243, wherein at least one electrical conductor comprises an inner conductor and at least one electrical conductor comprises an outer conductor.
1252. The system of claim 1243, further comprising an electrically insulating material placed between at least two electrical conductors.
1253. The system of claim 1243, wherein the ferromagnetic material comprises a resistance that decreases above the selected temperature such that the system provides the reduced heat output above the selected temperature.
1254. The system of claim 1243, wherein the ferromagnetic material comprises a thickness greater than about 3/a of a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
1255. The system of claim 1243, further comprising a higher conductivity material coupled to the ferromagnetic material.
1256. The system of claim 1243, further comprising a higher conductivity non-ferromagnetic material coupled to the ferromagnetic material.
1257. The system of claim 1243, further comprising a second ferromagnetic material coupled to the ferromagnetic material.
1258. The system of claim 1243, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1259. The system of claim 1243, wherein the ferromagnetic material comprises iron.
1260. The system of claim 1243, wherein the reduced heat output is less than about 400 watts per meter.
1261. The system of claim 1243, wherein the heat output is greater than about 400 watts per meter below the selected temperature.
1262. The system of claim 1243, wherein at least one electrical conductor comprises at least one section configured to comprise a relatively flat AC resistance profile in a temperature range between about 100 °C and 750 °C.
1263. The system of claim 1243, wherein at least one electrical conductor is greater than about 10 m in length.
1264. The system of claim 1243, wherein the amount of current applied to the ferromagnetic material is at least about 70 amps.
1265. The system of claim 1243, wherein the ferromagnetic material comprises a turndown ratio of at least about 2 to 1.
1266. The system of claim 1243, wherein the subsurface formation comprises a hydrocarbon containing formation.
1267. The system of claim 1243, wherein the subsurface formation comprises a hydrocarbon containing formation, and wherein the system is configured to pyrolyze at least some hydrocarbons in the formation.
1268. The system of claim 1243, wherein the subsurface formation comprises contaminated soil.
1269. The system of claim 1243, wherein the subsurface formation comprises contaminated soil, and wherein the system is configured to remediate at least a portion of the contaminated soil.
1270. The system of claim 1243, wherein the system is configured to provide heat to at least a portion of the opening in the formation.
1271. A method for heating a subsurface formation, comprising:
applying an alternating electrical current to one or more electrical conductors placed in an opening in the formation, wherein at least one electrical conductor comprises a ferromagnetic material;
providing a heat output from the ferromagnetic material, wherein the ferromagnetic material is configured to provide a reduced heat output above or near a selected temperature, wherein at least one electrical conductor is electrically coupled to the earth, and wherein electrical current propagates from the electrical conductor to the earth;
and allowing the heat to transfer from the one or more electrical conductors to a part of the formation.
1272. The method of claim 1271, further comprising allowing the electrical current to propagate through at least one electrical conductor into the opening.
1273. The method of claim 1271, further comprising providing a relatively constant heat output in a temperature range between about 100 °C and 750 °C.
1274. The method of claim 1271, wherein the ferromagnetic material comprises a resistance that decreases above the selected temperature such that the ferromagnetic material provides the reduced heat output above the selected temperature.
1275. The method of claim 1271, wherein the ferromagnetic material comprises a thickness greater than about 3/4 of a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
1276. The method of claim 1271, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1277. The method of claim 1271, wherein the subsurface formation comprises a hydrocarbon containing formation.
1278. The method of claim 1271, wherein the subsurface formation comprises a hydrocarbon containing formation, the method further comprising pyrolyzing at least some hydrocarbons in the formation.
1279. The method of claim 1271, wherein the reduced heat output is less than about 400 watts per meter.
1280. The method of claim 1271, wherein the heat output is greater than about 400 watts per meter below the selected temperature.
1281. The method of claim 1271, wherein the amount of heat output provided from the ferromagnetic material is determined by the amount of current applied to the ferromagnetic material.
1282. The method of claim 1271, further comprising controlling the amount of current applied to the ferromagnetic material to control the amount of heat provided by the ferromagnetic material.
1283. The method of claim 1271, further comprising applying at least about 70 amps of current to the ferromagnetic material.
1284. A heater system, comprising:
an AC supply configured to provide alternating current at a frequency between about 100 Hz and about 600 Hz;
an electrical conductor comprising at least one electrically resistive portion configured to provide a heat output during application of the alternating electrical current to the electrically resistive portion during use; and wherein the electrical conductor comprises a ferromagnetic material and is configured to provide a reduced heat output above or near a selected temperature, and wherein the selected temperature is at or about the Curie temperature of the ferromagnetic material.
1285. The heater system of claim 1284, wherein the AC supply is coupled to a supply of line current, and wherein the AC supply is configured to provide alternating current at about three times the frequency of the line current.
1286. The heater system of claim 1284, wherein the frequency is between about 140 Hz and about 200 Hz.
1287. The heater system of claim 1284, wherein the frequency is between about 400 Hz and about 550 Hz.
1288. The heater system of claim 1284, wherein the heater is configured to provide heat to a subsurface formation.
1289. The heater system of claim 1284, wherein the heater is configured to provide heat to a hydrocarbon containing formation, and wherein the system is configured to pyrolyze at least some hydrocarbons in the formation.
1290. The heater system of claim 1284, wherein the heater is configured to provide heat to contaminated soil, and wherein the system is configured to remediate at least a portion of the contaminated soil.
1291. The heater system of claim 1284, wherein the system is configured to provide heat to at least a portion of an opening in a subsurface formation.
1292. The heater system of claim 1284, wherein the ferromagnetic material comprises iron, nickel, chromium, cobalt, tungsten, or mixtures thereof.
1293. The heater system of claim 1284, wherein the ferromagnetic material has a thickness that is at least about 3/4 of a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
1294. The heater system of claim 1284, wherein the ferromagnetic material is coupled to a higher conductivity non-ferromagnetic material.
1295. The heater system of claim 1284, wherein the heat output is greater than about 400 watts per meter below the selected temperature.
1296. The heater system of claim 1284, wherein at least one electrical conductor comprises at least one section configured to comprise a relatively flat AC resistance profile in a temperature range between about 100 °C and 750 °C.
1297. The heater system of claim 1284, wherein at least one electrical conductor is greater than about 10 m in length.
129. The heater system of claim 1284, wherein the system is configured to sharply reduce the heat output at or near the selected temperature.
1299. The heater system of claim 1284, wherein the system is configured such that, at or near the selected temperature, the heat output of at least a portion of the system declines due to the Curie effect.
1300. The heater system of claim 1284, wherein the amount of heat output provided from at least one electrically resistive portion is configured to be determined by the amount of current applied to such electrically resistive portion below the selected temperature.
1301. The heater system of claim 1284, wherein the amount of current applied to at least one electrically resistive portion is at least about 70 amps.
1302. The heater system of claim 1284, wherein at least one electrically resistive portion comprises a turndown ratio of at least about 2 to 1.
1303. The heater system of claim 1284, wherein the heater system is configured to withstand operating temperatures of about 250 °C or above.
1304. The heater system of claim 1284, wherein the electrical conductor is configured to inherently provide a decreased heat output above or near the selected temperature.
1305. The heater system of claim 1284, wherein the electrical conductor is configured to inherently provide a heat output above or near the selected temperature that is about 20% or less of the heat output at about 50 °C below the selected temperature.
1306. A method of heating, comprising:
providing an alternating current at a frequency between about 100 Hz and about 600 Hz to an electrical conductor comprising at least one electrically resistive portion to provide a heat output; and wherein the electrical conductor comprises a ferromagnetic material and is configured to provide a reduced heat output above or near a selected temperature, and wherein the selected temperature is at or about the Curie temperature of the ferromagnetic material.
1307. The method of heating of claim 1306, further comprising providing the alternating current to the electrical conductor when the electrical conductor is at or above the selected temperature.
1308. The method of heating of claim 1306, further comprising providing the alternating current at about three times the frequency of line current from an AC supply.
1309. The method of heating of claim 1306, wherein the frequency is between about 140 Hz and about 200 Hz.
1310. The method of heating of claim 1306, wherein the frequency is between about 400 Hz and about 550 Hz.
1311. The method of heating of claim 1306, further comprising providing the alternating current to the electrical conductor when the electrical conductor is at or above the selected temperature.
1312. The method of heating of claim 1306, further comprising allowing heat to transfer from at least one electrically resistive portion to at least a part of a subsurface formation.
1313. The method of heating of claim 1306, further comprising providing a relatively constant heat output in a temperature range between about 100 °C and 750 °C.
1314. The method of heating of claim 1306, wherein the electrical conductor comprises an AC resistance that decreases above the selected temperature such that the electrical conductor provides the reduced heat output above the selected temperature.
1315. The method of heating of claim 1306, wherein the ferromagnetic material has a thickness of at least about 3/4 of a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
1316. The method of heating of claim 1306, further comprising allowing heat to transfer from the electrical conductor to at least a part of a subsurface formation, wherein the subsurface formation comprises a hydrocarbon containing formation.
1317. The method of heating of claim 1306, further comprising allowing heat to transfer from the electrical conductor to at least a part of a hydrocarbon containing formation, and pyrolyzing at least some hydrocarbons in the formation.
1318. The method of heating of claim 1306, wherein the reduced heat output is less than about 400 watts per meter.
1319. The method of heating of claim 1306, further comprising controlling a skin depth in the electrical conductor by controlling a frequency of alternating current applied to the electrical conductor.
1320. The method of heating of claim 1306, further comprising controlling the heat applied from the electrical conductor by allowing less heat to be applied from any part of the electrical conductor that is at or near the selected temperature.
1321. The method of heating of claim 1306, further comprising controlling the amount of current applied to the electrical conductor to control an amount of heat provided by at least one electrically resistive portion.
1322. The method of heating of claim 1306, further comprising applying at least about 70 amps of current to the electrical conductor.
1323. A heater, comprising:
an electrical conductor configured to generate heat during application of electrical current to the electrical conductor, wherein the electrical conductor is configured to provide a heat output of at least about 400 watts per meter during use below a selected temperature; and wherein the electrical conductor comprises a ferromagnetic material that, when alternating current is applied to it, a skin depth of such alternating current is greater than about 3/4 of the skin depth of the alternating current at the Curie temperature of the ferromagnetic material, such that the heater provides a reduced heat output above or near the selected temperature.
1324. The heater of claim 1323, wherein the heater is configured to provide heat to a subsurface formation.
1325. The heater of claim 1323, wherein the heater is configured to provide heat to a hydrocarbon containing formation, and wherein the system is configured to pyrolyze at least some hydrocarbons in the formation.
1326. The heater of claim 1323, wherein the heater is configured to provide heat to contaminated soil, and wherein the system is configured to remediate at least a portion of the contaminated soil.
1327. The heater of claim 1323, wherein the heater is configured to provide heat to at least a portion of an opening in a subsurface formation.
1328. The heater of claim 1323, further comprising two additional electrical conductors configured to generate heat during application of electrical current to the two additional electrical conductors, wherein the electrical conductor and the two additional electrical conductors are configured to be coupled in a three-phase electrical configuration.
1329. The heater of claim 1323, further comprising at least one additional electrical conductor.
1330. The heater of claim 1323, further comprising at least one additional electrical conductor and an electrically insulating material placed between the electrical conductor and at least one additional electrical conductor.
1331. The heater of claim 1323, wherein a resistance of the ferromagnetic material decreases above the selected temperature such that the heater provides the reduced heat output above the selected temperature.
1332. The heater of claim 1323, further comprising a higher conductivity material coupled to the ferromagnetic material.
1333. The heater of claim 1323, further comprising a higher conductivity non-ferromagnetic material coupled to the ferromagnetic material.
1334. The heater of claim 1323, further comprising a second ferromagnetic material coupled to the ferromagnetic material.
1335. The heater of claim 1323, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1336. The heater of claim 1323, wherein the ferromagnetic material comprises iron.
1337. The heater of claim 1323, wherein the reduced heat output is less than about 400 watts per meter.
1338. The heater of claim 1323, wherein the heater comprises a relatively flat AC resistance profile in a temperature range between about 100 °C and 750 °C.
1339. The heater of claim 1323, wherein the heater is greater than about 10 m in length.
1340. The heater of claim 1323, wherein the amount of heat output provided from the ferromagnetic material is configured to be determined by an amount of current applied to the ferromagnetic material.
1341. The heater of claim 1323, wherein the amount of current applied to the ferromagnetic material is at least about 70 amps.
2342. The heater of claim 1323, wherein the ferromagnetic material comprises a turndown ratio of at least about 2 to 1.
1343. The heater of claim 1323, wherein the heater is configured to be used to provide heat in a chemical plant.
1344. The heater of claim 1323, wherein the heater is configured to be used to provide heat to a reactor tube.
1345. The heater of claim 1323, wherein the heater is configured to be used to provide heat to a distillation column.
1346. The heater of claim 1323, wherein the heater is configured to be used to provide heat to a coker.
1347. The heater of claim 1323, wherein the heater comprises a 100,000 hour creep strength of at least about 3,000 psi at 650 °C.
1348. The heater of claim 1323, wherein the heater comprises an outside diameter of less than about 5 cm.
1349. A method, comprising:
applying an alternating electrical current to one or more electrical conductors, wherein at least one electrical conductor comprises a ferromagnetic material; and providing a heat output from the ferromagnetic material, wherein the ferromagnetic material is configured to provide a reduced beat output above or near a selected temperature, wherein the heat output is at least about 400 watts per meter below the selected temperature.
1350. The method of claim 1349, further comprising providing the alternating current to the electrical conductor when the electrical conductor is at or above the selected temperature.
1351. The method of claim 1349, further comprising applying the alternating electrical current to the one or more electrical conductors at about 180 Hz operating frequency.
1352. The method of claim 1349, further comprising allowing heat to transfer from at least one electrical conductor to at least a part of a subsurface formation.
1353. The method of claim 1349, further comprising providing a relatively constant heat output in a temperature range between about 300 °C and 600 °C.
1354. The method of claim 1349, further comprising providing a relatively constant heat output in a temperature range between about 100 °C and 750 °C.
1355. The method of claim 1349, wherein at least one electrical conductor comprises an AC resistance that decreases above the selected temperature such that the electrical conductor provides the reduced heat output above the selected temperature.
1356. The method of claim 1349, wherein the ferromagnetic material has a thickness of at least about 3/4 of a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
1357. The method of claim 1349, further comprising allowing heat to transfer from at least one electrical conductor to at least a part of a subsurface formation, wherein the subsurface formation comprises a hydrocarbon containing formation.
135. The method of claim 1349, further comprising allowing heat to transfer from at least one electrical conductor to at least a part of a hydrocarbon containing formation, and pyrolyzing at least some hydrocarbons in the formation.
1359. The method of claim 1349, wherein the reduced heat output is less than about 400 watts per meter.
1360. The method of claim 1349, further comprising controlling a skin depth in at least one electrical conductor by controlling a frequency of alternating current applied to at least one electrical conductor.
1361. The method of claim 1349, further comprising applying additional power to at least one electrical conductor as the temperature of the electrical conductor increases, and continuing to do so until the temperature is at or near the selected temperature.
1362. The method of claim 1349, further comprising controlling the heat applied from an electrical conductor by allowing less heat to be applied from any part of the electrical conductor that is at or near the selected temperature.
1363. The method of claim 1349, further comprising controlling the amount of current applied to the electrical conductors to control an amount of heat provided by at least one electrically resistive portion.
1364. The method of claim 1349, further comprising applying at least about 70 amps of current to the electrical conductors.
1365. A heater, comprising:
an electrical conductor;
an electrical insulator at least partially surrounding the electrical conductor;
a sheath at least partially surrounding the electrical insulator;
a conduit configured to generate a heat output during application of alternating electrical current to the conduit, wherein the electrical conductor, the electrical insulator, and the sheath are at least partially located inside the conduit; and wherein the conduit comprises a ferromagnetic material such that the heater provides a reduced heat output above or near a selected temperature.
1366. The heater of claim 1365, wherein the amount of current applied to the conduit is at least about 70 amps.
1367. The heater of claim 1365, wherein the heat output below the selected temperature is configured to be increased by decreasing the amount of current applied to the conduit.
1368. The heater of claim 1365, wherein the heat output below the selected temperature is configured to be decreased by increasing the amount of current applied to the conduit.
1369. The heater of claim 1365, wherein the heater is configured to allow heat to transfer from the heater to a part of a subsurface formation to pyrolyze at least some hydrocarbons in the subsurface formation.
1370. The heater of claim 1365, wherein the heater is configured to be placed in an opening in a subsurface formation.
1371. The heater of claim 1365, wherein a resistance of the ferromagnetic material decreases above the selected temperature such that the heater provides the reduced heat output above the selected temperature.
1372. The heater of claim 1365, further comprising a second ferromagnetic material coupled to the ferromagnetic material.
1373. The heater of claim 1365, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1374. The heater of claim 1365, wherein the ferromagnetic material comprises iron.
1375. The heater of claim 1365, wherein the reduced heat output is less than about 400 watts per meter.
1376. The heater of claim 1365, wherein the heat output is greater than about 400 watts per meter below the selected temperature.
1377. The heater of claim 1365, wherein the heater comprises a relatively flat AC resistance profile in a temperature range between about 100 °C and 750 °C.
1378. The heater of claim 1365, wherein the heater is greater than about 10 m in length.
1379. The heater of claim 1365, wherein the ferromagnetic material comprises a turndown ratio of at least about 2 to 1.
1380. The heater of claim 1365, wherein the heater comprises an outside diameter of less than about 5 cm.
1381. The heater of claim 1365, wherein the electrical conductor comprises copper.
1382. The heater of claim 1365, wherein the electrical conductor comprises stranded copper.
1383. The heater of claim 1365, wherein the electrical conductor comprises stranded copper coated with steel.
1384. The heater of claim 1365, wherein the electrical conductor, the electrical insulator, and the sheath are portions of a furnace cable.
1385. The heater of claim 1365, wherein the electrical conductor, the electrical insulator, and the sheath are portions of an insulated conductor heater.
1386. The heater of claim 1365, wherein a thickness of the conduit is at least about 3/4 of a skin depth of alternating current at the Curie temperature of the ferromagnetic material.
1387. The heater of claim 1365, wherein the electrical insulator comprises magnesium oxide.
1388. The heater of claim 1365, wherein the sheath comprises steel.
1389. The heater of claim 1365, further comprising a low electrical resistance metal coupled to at least a portion of the outside of the ferromagnetic material.
1390. The heater of claim 1389, further comprising a protective sheath coupled to the outside of at least a portion of the low electrical resistance metal.
1391. The heater of claim 1390, wherein the protective sheath comprises a second ferromagnetic material.
1392. The heater of claim 1390, wherein the protective sheath comprises a second ferromagnetic material, and wherein the second ferromagnetic material has a Curie temperature above the selected temperature.
1393. The heater of claim 1365, further comprising an electrically conductive lining placed on the inside of a portion of the conduit in an overburden section of a subsurface formation.
1394. The heater of claim 1365, further comprising a copper lining placed on the inside of a portion of the conduit in an overburden section of a subsurface formation.
1395. The heater of claim 1365, wherein the ferromagnetic material is configured to inherently provide the reduced heat output above or near the selected temperature that is about 20%
or less of the heat output at about 50 °C below the selected temperature.
1396. The heater of claim 1365, further comprising a deformation resistant container, wherein at least a portion of the system is located in the deformation resistant container, and wherein the selected temperature is selected such that the deformation resistant container has a creep-rupture strength of at least about 3000 psi at 100,000 hours at the selected temperature.
1397. The heater of claim 1365, wherein the deformation resistant container comprises an alloy, and the alloy comprises iron, chromium, nickel, manganese, carbon, and tantalum.
1398. A system configured to heat at least a part of a subsurface formation, comprising:
one or more electrical conductors configured to be placed in an opening in the formation, wherein at least one electrical conductor comprises at least one electrically resistive portion configured to provide a heat output when alternating current is applied through such electrically resistive portion, and wherein at least one of such electrically resistive portions comprises one or more ferromagnetic materials, and is configured, when above or near a selected temperature and when alternating current is applied, to inherently provide a reduced heat output;
a combustion heater placed in the opening in the formation; and wherein the system is configured to allow heat to transfer from at least one of the electrically resistive portions to at least a part of the formation.
1399. The system of claim 1398, wherein the combustion heater comprises a natural distributed combustor.
1400. The system of claim 1398, wherein the combustion heater comprises a flameless distributed combustor.
1401. The system of claim 1398, wherein at least one electrical conductor is configured to provide heat to maintain combustion in the combustion heater during use.
1402. The system of claim 1398, wherein the subsurface formation comprises a hydrocarbon containing formation.
1403. The system of claim 1398, wherein the subsurface formation comprises a hydrocarbon containing formation, and wherein the system is configured to pyrolyze at least some hydrocarbons in the formation.
1404. The system of claim 1398, wherein the subsurface formation comprises contaminated soil.
1405. The system of claim 1398, wherein the subsurface formation comprises contaminated soil, and wherein the system is configured to remediate at least a portion of the contaminated soil.
1406. The system of claim 1398, wherein the system is configured to provide heat to at least a portion of the opening in the formation.
1407. The system of claim 1398, wherein at least one of the electrically resistive portions is configured to provide heat to ignite at least part of the combustion heater.
1408. The system of claim 1398, wherein at least one of the electrically resistive portions is configured to be an ignition source for at least part of the combustion heater.
1409. The system of claim 1398, wherein the system is configured such that at least one electrically resistive portion maintains a minimum temperature of the system above an auto-ignition temperature of a combustion mixture being provided to at least part of the combustion heater.
1410. A heater for a subsurface formation, comprising:
an electrical conductor configured to generate a heat output during application of alternating electrical current to the electrical conductor;
wherein the electrical conductor comprises a ferromagnetic material, wherein the ferromagnetic material provides, when alternating current is applied to it, a reduced heat output above or near a selected temperature, and wherein the ferromagnetic material comprises a turndown ratio of at least 2:1;
and wherein the heater is configured to heat at least a part of a subsurface formation.
1411. The heater of claim 1410, wherein the amount of current applied to the electrical conductor is at least about 70 amps.
1412. The heater of claim 1410, wherein the ferromagnetic material has a thickness greater than a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
1413. The heater of claim 1410, wherein the heat output below the selected temperature is configured to be increased by decreasing the amount of current applied to the electrical conductor.
1414. The heater of claim 1410, wherein the heat output below the selected temperature is configured to be decreased by increasing the amount of current applied to the electrical conductor.
1415. The heater of claim 1410, wherein the heater is configured to provide heat to a subsurface formation.
1416. The heater of claim 1410, wherein the heater is configured to provide heat to a hydrocarbon containing formation, and wherein the system is configured to pyrolyze at least some hydrocarbons in the formation.
1417. The heater of claim 1410, wherein the heater is configured to provide heat to contaminated soil, and wherein the system is configured to remediate at least a portion of the contaminated soil.
1418. The heater of claim 1410, wherein the heater is configured to provide heat to at least a portion of an opening in a subsurface formation.
1419. The heater of claim 1410, further comprising at least one additional electrical conductor.
1420. The heater of claim 1410, further comprising at least one additional electrical conductor and an electrically insulating material placed between the electrical conductor and at least one additional electrical conductor.
1421. The heater of claim 1410, wherein a resistance of the ferromagnetic material decreases above a selected temperature of the ferromagnetic material such that the heater provides the reduced heat output above the selected temperature.
1422. The heater of claim 1410, further comprising a higher conductivity non-ferromagnetic material coupled to the ferromagnetic material.
1423. The heater of claim 1410, further comprising a second ferromagnetic material coupled to the ferromagnetic material.
1424. The heater of claim 1410, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1425. The heater of claim 1410, wherein the reduced heat output is less than about 400 watts per meter.
1426. The heater of claim 1410, wherein the heat output is greater than about 400 watts per meter below the selected temperature.
1427. The heater of claim 1410, wherein the heater is greater than about 10 m in length.
1428. The heater of claim 1410, wherein the ferromagnetic material comprises a turndown ratio of at least about 3 to 1.
1429. The heater of claim 1410, wherein the ferromagnetic material comprises a turndown ratio of at least about to 1.
1430. The heater of claim 1410, wherein the heater comprises an outside diameter of less than about 5 cm.
1431. A heater for a subsurface formation, comprising:
at least one section comprising a first electrical conductor configured to generate a heat output during application of an alternating electrical current to the first electrical conductor;
wherein the first electrical conductor comprises a ferromagnetic material, and the heater provides, when an alternating current is applied to it, a reduced heat output above or near a selected temperature;
at least one section comprising a second electrical conductor, wherein the second electrical conductor comprises a highly electrically conductive material, wherein at least a portion of the first electrical conductor is electrically coupled to at least a portion of the second electrical conductor such that a majority of the electrical current does not flow through the second electrical conductor below the selected temperature, and such that, at the selected temperature, a majority of the electrical current flows through the second electrical conductor; and wherein the heater is configured to heat at least part of a subsurface formation.
1432. The heater of claim 1431, wherein at least one section comprising the first electrical conductor is electrically coupled to at least one section comprising the second electrical conductor.
1433. The heater of claim 1431, wherein at least one section comprising the first electrical conductor is coupled between at least two sections comprising the second electrical conductor.
1434. The heater of claim 1431, wherein at least one section comprising the second electrical conductor is coupled between at least two sections comprising the first electrical conductor.
1435. The heater of claim 1431, wherein at least one section comprising the first electrical conductor is located proximate a portion of a subsurface formation selected for heating.
1436. The heater of claim 1431, wherein at least one section comprising the second electrical conductor is located proximate a portion of a subsurface formation selected to not be heated.
1437. The heater of claim 1431, wherein the second electrical conductor comprises copper.
1438. The heater of claim 1431, wherein the amount of current applied to the first electrical conductor is at least about 70 amps.
1439. The heater of claim 1431, wherein the ferromagnetic material has a thickness greater than a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
1440. The heater of claim 1431, wherein the heat output below the selected temperature is configured to be increased by decreasing the amount of current applied to the first electrical conductor.
1441. The heater of claim 1431, wherein the heat output below the selected temperature is configured to be decreased by increasing the amount of current applied to the first electrical conductor.
1442. The heater of claim 1431, wherein the heater is configured to provide heat to a subsurface formation.
1443. The heater of claim 1431, wherein the heater is configured to provide heat to a hydrocarbon containing formation, and wherein the system is configured to pyrolyze at least some hydrocarbons in the formation.
1444. The heater of claim 1431, wherein the heater is configured to provide heat to contaminated soil, and wherein the system is configured to remediate at least a portion of the contaminated soil.
1445. The heater of claim 1431, wherein the heater is configured to provide heat to at least a portion of an opening in a subsurface formation.
1446. The heater of claim 1431, further comprising at least one additional electrical conductor coupled to the first electrical conductor.
1447. The heater of claim 1431, further comprising at least one additional electrical conductor coupled to the first electrical conductor and an electrically insulating material placed between the first electrical conductor and at least one additional electrical conductor.
1448. The heater of claim 1431, wherein a resistance of the ferromagnetic material decreases above a selected temperature of the ferromagnetic material such that the heater provides the reduced heat output above the selected temperature.
1449. The heater of claim 1431, further comprising a higher conductivity non-ferromagnetic material coupled to the ferromagnetic material.
1450. The heater of claim 1431, further comprising a second ferromagnetic material coupled to the ferromagnetic material.
1451. The heater of claim 1431, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1452. The heater of claim 1431, wherein the reduced heat output is less than about 400 watts per meter.
1453. The heater of claim 1431, wherein the heat output is greater than about 400 watts per meter below the selected temperature.
1454. The heater of claim 1431, wherein the heater is greater than about 10 m in length.
1455. The heater of claim 1431, wherein the ferromagnetic material comprises a turndown ratio of at least about 2 to 1.
1456. The heater of claim 1431, wherein the heater comprises an outside diameter of less than about 5 cm.
1457. A heater for a subsurface formation, comprising:
a first elongated electrical conductor configured to generate a heat output during application of an alternating electrical current to the first electrical conductor, wherein the first electrical conductor comprises a ferromagnetic material, and the first elongated electrical conductor provides, when an alternating current is applied to it, a reduced heat output above or near a selected temperature;
a second elongated electrical conductor comprising a highly electrically conductive material, wherein at least a significant length of the first electrical conductor is electrically coupled to the second electrical conductor;
and wherein the heater is configured to heat at least part of a subsurface formation.
1458. The heater of claim 1457, wherein the second elongated electrical conductor comprises copper.
1459. The heater of claim 1457, wherein the amount of current applied to the first elongated electrical conductor is at least about 70 amps.
1460. The heater of claim 1457, wherein the ferromagnetic material has a thickness greater than a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
1461. The heater of claim 1457, wherein the heat output below the selected-temperature is configured to be increased by decreasing the amount of current applied to the first elongated electrical conductor.
1462. The heater of claim 1457, wherein the heat output below the selected temperature is configured to be decreased by increasing the amount of current applied to the first elongated electrical conductor.
1463. The heater of claim 1457, wherein the heater is configured to provide heat to a subsurface formation.
1464. The heater of claim 1457, wherein the heater is configured to provide heat to a hydrocarbon containing formation, and wherein the system is configured to pyrolyze at least some hydrocarbons in the formation.
1465. The heater of claim 1457, wherein the heater is configured to provide heat to contaminated soil, and wherein the system is configured to remediate at least a portion of the contaminated soil.
1466. The heater of claim 1457, wherein the heater is configured to provide heat to at least a portion of an opening in a subsurface formation.
1467. The heater of claim 1457, further comprising at least one additional electrical conductor coupled to the first elongated electrical conductor.
1468. The heater of claim 1457, further comprising at least one additional electrical conductor coupled to the first elongated electrical conductor and an electrically insulating material placed between the first elongated electrical conductor and at least one additional electrical conductor.
1469. The heater of claim 1457, wherein a resistance of the ferromagnetic material decreases above a selected temperature of the ferromagnetic material such that the heater provides the reduced heat output above the selected temperature.
1470. The heater of claim 1457, further comprising a higher conductivity non-ferromagnetic material coupled to the ferromagnetic material.
1471. The heater of claim 1457, further comprising a second ferromagnetic material coupled to the ferromagnetic material.
1472. The heater of claim 1457, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1473. The heater of claim 1457, wherein the reduced heat output is less than about 400 watts per meter.
1474. The heater of claim 1457, wherein the heat output is greater than about 400 watts per meter below the selected temperature.
1475. The heater of claim 1457, wherein the heater is greater than about 10 m in length.
1476. The heater of claim 1457, wherein the ferromagnetic material comprises a turndown ratio of at least about 2 to 1.
1477. The heater of claim 1457, wherein the heater comprises an outside diameter of less than about 5 cm.
1478. The heater of claim 1457, wherein the first elongated electrical conductor and the second elongated electrical conductor are electrically coupled such that a majority of the electrical current does not flow through the second elongated electrical conductor below the selected temperature, and such that, near or above the selected temperature, a majority of the electrical current flows through the second elongated electrical conductor.
1479. A method for heating fluids in a wellbore, comprising:
applying alternating electrical current to one or more electrical conductors placed in a wellbore, wherein at least one electrical conductor comprises one or more electrically resistive portions; and providing heat from at least one electrically resistive portion to fluids in the wellbore, wherein at least one of such electrically resistive portions is configured, when above or near a selected temperature, to inherently provide a reduced heat output.
1480. The method of claim 1479, further comprising producing fluids through the opening in the formation.
1481. The method of claim 1480, wherein the produced fluids comprise at least some hydrocarbons from the formation.
1482. The method of claim 1480, wherein the produced fluids comprise at least some pyrolyzed hydrocarbons from the formation.
1483. The method of claim 1479, further comprising providing a relatively constant heat output in a temperature range between about 300 °C and 600 °C.
1484. The method of claim 1479, further comprising providing a relatively constant heat output in a temperature range between about 100 °C and 750 °C.
1485. The method of claim 1479, wherein at least one electrically conductive portion comprises a resistance that decreases above the selected temperature such that the electrically conductive portion provides the reduced heat output above the selected temperature.
1486. The method of claim 1479, wherein at least one electrically conductive portion comprises ferromagnetic material with a thickness greater than about 3/4 of a skin depth of the alternating current at the Curie temperature of the ferromagnetic material.
1487. The method of claim 1479, wherein at least one electrically conductive portion comprises ferromagnetic material.
1488. The method of claim 1479, further comprising allowing heat to transfer from the wellbore to at least a part of a hydrocarbon containing formation, and pyrolyzing at least some hydrocarbons in the hydrocarbon containing formation.
1489. The method of claim 1479, wherein the reduced heat output is less than about 400 watts per meter.
1490. The method of claim 1479, wherein the heat output is greater than about 400 watts per meter below the selected temperature.
1491. The method of claim 1479, further comprising controlling a skin depth in at least one electrically resistive portion by controlling a frequency of alternating current applied to at least one electrically resistive portion.
1492. The method of claim 1479, further comprising applying additional power to at least one electrically resistive portion as the temperature of the electrically resistive portion increases, and continuing to do so until the temperature is at or near the selected temperature.
1493. The method of claim 1479, wherein the amount of heat output provided from at least one electrically resistive portion is determined by the amount of current applied to such electrically resistive portion.
1494. The method of claim 1479, further comprising controlling the amount of current applied to at least one electrically resistive portion to control the amount of heat provided by such electrically resistive portion.
1495. The method of claim 1479, farther comprising increasing the amount of current applied to at least one electrically resistive portion to decrease the amount of heat provided by such electrically resistive portion.
1496. The method of claim 1479, further comprising decreasing the amount of current applied to at least one electrically resistive portion to increase the amount of heat provided by such electrically resistive portion.
1497. The method of claim 1479, further comprising applying at least about 70 amps of current to at least one electrically resistive portion.
1498. A system configured to insulate an overburden of at least a part of a hydrocarbon containing formation, comprising:
an opening in a part of the formation;
a first conduit located in the opening;
an insulating material located between the first conduit and the overburden;
a second conduit located inside the first conduit With an annular region between the first and second conduits; and at least one baffle in the annular region.
1499. The system of claim 1498, wherein the insulating material is cement.
1500. The system of claim 1498, wherein the insulting material is foamed cement.
1501. The system of claim 1500, wherein the cement is foamed with nitrogen.
1502. The system of claim 1498, wherein the first conduit extends through the overburden of the formation.
1503. The system of claim 1498, wherein at least one baffle is positioned at a bottom of the first conduit and seals the annular region.
1504. The system of claim 1498, wherein a pressure in the annular region is maintained below about 2 bar.
1505. The system of claim 1498, further comprising a gas placed in the annular region.
1506. The system of claim 1505, wherein the gas comprises air.
1507. The system of claim 1505, wherein the gas comprises nitrogen.
1508. A method whereby heat transfer between an overburden of at least a part of a hydrocarbon containing formation and a conduit positioned in an opening in a part of the formation is decreased, comprising:
locating an insulating material between a first conduit and the overburden;
locating a second conduit inside the first conduit and forming an annular region between the first and second conduits; and positioning at least one baffle in the annular region.
1509. The method of claim 1508, wherein the insulating material is cement.
1510. The method of claim 1508, wherein the insulting material is foamed cement.
1511. The method of claim 1510, wherein the foamed cement is foamed with nitrogen.
1512. The method of claim 1508, wherein the first conduit extends through the overburden.
1513. The method of claim 1508, further comprising sealing the annular region with at least one baffle positioned at a bottom of the first conduit.
1514. The method of claim 1508, further comprising maintaining a pressure in the annular region below about 1 bar.
1515. The method of claim 1508, further comprising providing a gas to the annular region.
1516. The method of claim 1515, wherein the gas comprises air.
1517. The method of claim 1515, wherein the gas comprises nitrogen.
1518. A system configured to reduce a temperature of at least a part of a hydrocarbon containing formation, comprising:
an opening in a part of the formation;
a first conduit located in the opening;
a second conduit located inside the first conduit with an annular region between the first and second conduits;
a third conduit located inside the second conduit;
at least one baffle located in the annular region; and at least one refrigerant configured to be provided through the second and third conduits.
1519. The system of claim 1518, wherein the first conduit extends through an overburden section.
1520. The system of claim 1518, wherein the baffle is positioned at a bottom of the first conduit and seals the annular region.
1521. The system of claim 1518, wherein the annular region contains a gas.
1522. The system of claim 1521, wherein the gas comprises air.
1523. The system of claim 1521, wherein the gas comprises nitrogen.
1524. The system of claim 1518, wherein a pressure in the annular region is maintained below 1 bar.
1525. The system of claim 1518, wherein the first conduit is fixed in place with cement.
1526. The system of claim 1518, wherein the first conduit is fixed in place with foamed cement.
1527. The system of claim 1526, wherein the foamed cement comprises cement foamed with nitrogen.
1528. A method configured to reduce the temperature of at least a part of a hydrocarbon containing formation, comprising:
locating a first conduit in an opening in a part of the formation;
positioning a second conduit inside the first conduit;
positioning a third conduit inside the second conduit;
providing an annular region between the first and second conduits;
positioning a baffle in the annular region; and providing refrigerant to the second conduit.
1529. The system of claim 1528, wherein the first conduit extends through an overburden section.
1530. The system of claim 1528, wherein the baffle is positioned at a bottom of the first conduit and seals the annular region.
1531. The system of claim 1528, wherein the annular region contains a gas.
1532. The system of claim 1531, wherein the gas comprises air.
1533. The system of claim 1531, wherein the gas comprises nitrogen.
1534. The system of claim 1528, wherein a pressure in the annular region is maintained below 1 bar.
1535. The system of claim 1528, wherein the first conduit is fixed in place with cement.
1536. The system of claim 1528, wherein the first conduit is fixed in place with foamed cement.
1537. The system of claim 1536, wherein the foamed cement comprises cement foamed with nitrogen.
1538. The system of claim 1528, wherein the refrigerant exits a bottom of the second conduit, enters a bottom of the third conduit, and exits a top of the third conduit.
1539. A method of treating a hydrocarbon containing formation, comprising:
providing a first barrier to a first portion of the formation, wherein the first portion comprises methane;
removing water from the first portion;
producing fluids from the first portion, wherein produced fluids from the first portion comprise methane;
providing a second barrier to a second portion of the formation, wherein the second portion comprises methane;
removing water from the second portion, and then transferring at least a portion of such water to the first portion; and producing fluids from the second portion, wherein produced fluids from the second portion comprise methane.
1540. A method of treating a hydrocarbon containing formation, comprising:
providing a first barrier to a first portion of the formation;
removing water from the first portion;
providing a second barrier to a second portion of the formation, wherein the second portion comprises methane;
removing water from the second portion, and then transferring at least a portion of such water to the first portion; and producing fluids from the second portion, wherein produced fluids comprise methane.
1541. The method of claim 1540, wherein the first and second portions are substantially adjacent each other.
1542. The method of claim 1540, wherein providing a first barrier comprises:
providing refrigerant to a plurality of freeze wells to form a low temperature zone around the first portion;
and lowering a temperature within the low temperature zone to a temperature less than about a freezing temperature of water.
1543. The method of claim 1540, wherein providing a second barrier comprises:
providing refrigerant to a plurality of freeze wells to form a low temperature zone around the second portion; and lowering a temperature within the low temperature zone to a temperature less than about a freezing temperature of water.
1544. The method of claim 1540, wherein providing a first barrier comprises providing refrigerant to a plurality of freeze wells to form a frozen barrier zone and wherein the frozen barrier zone at least partially inhibits fluids from flowing into or out of the portion.
1545. The method of claim 1540, wherein providing a second barrier comprises providing refrigerant to a plurality of freeze wells to form a frozen barrier zone and wherein the frozen barrier zone at least partially inhibits fluids from flowing into or out of the portion.
2546. The method of claim 1540, further comprising:
providing heat from one or more heaters to at least one portion of the formation; and allowing the heat to transfer from at least one of the heaters to a part of the formation.
1547. The method of claim 1540, wherein an average temperature of at least one portion of the formation is less than about a boiling point of water at formation conditions.
1548. The method of claim 1540, wherein an average temperature of at least one portion of the formation is less than about 100 °C.
1549. A method of recovering methane from a hydrocarbon containing formation, comprising:
providing a barrier to a first portion of the formation, wherein the first portion comprises methane;
removing water from the first portion and then transferring at least a portion of such water to a second portion of the formation; and producing fluids from the first portion, wherein the produced fluids comprise methane.
1550. The method of claim 1549, wherein providing a barrier comprises:
providing refrigerant to a plurality of freeze wells to form a low temperature zone around the portion; and lowering a temperature within the low temperature zone to a temperature less than about a freezing temperature of water.
1551. The method of claim 1549, wherein providing a barrier comprises providing refrigerant to a plurality of freeze wells to form a frozen barrier zone and wherein the frozen barrier zone at least partially inhibits fluids from flowing into or out of the portion.
1552. The method of claim 1549, further comprising:
providing heat from one or more heaters to at least one portion of the formation; and allowing the heat to transfer from at least one of the heaters to a part of the formation.
1553. The method of claim 1549, wherein an average temperature of at least one portion of the formation is less than about a boiling point of water at formation conditions.
1554. The method of claim 1549, wherein an average temperature of at least one portion of the formation is less than about 100 °C.
1555. A method of treating a hydrocarbon containing formation, comprising:
assessing a thickness of a portion of the formation to be treated, wherein such portion comprises methane;
using such thickness to determine a number of barrier wells to provide to the portion of the formation;
providing a plurality of barrier wells to the portion of the formation;
removing water from a portion of the formation; and producing fluids from a portion of the formation, wherein the produced fluids comprise methane.
1556. The method of claim 1555, wherein providing at least one barrier comprises:
providing refrigerant to a plurality of freeze wells to form a low temperature zone around the portion; and lowering a temperature within the low temperature zone to a temperature less than about a freezing temperature of water.
1557. The method of claim 1555, wherein providing at least one barrier comprises providing refrigerant to a plurality of freeze wells to form a frozen barrier zone and wherein the frozen barrier zone at least partially inhibits fluids from flowing into or out of the portion.
1558. The method of claim 1555, further comprising:
providing heat from one or more heaters to at least one portion of the formation; and allowing the heat to transfer from at least one of the heaters to a part of the formation.
1559. The method of claim 1555, wherein an average temperature of at least one portion of the formation is less than about a boiling point of water at formation conditions.
1560. The method of claim 1555, wherein an average temperature of at least one portion of the formation is less than about 100 °C.
1561. A method of treating a hydrocarbon containing formation, comprising:
providing a first barrier to a first portion of the formation, wherein the first portion comprises methane;
providing a second barrier to a second portion of the formation, wherein at least a part of the first portion is positioned substantially between the second portion and a surface of the formation;
removing water from the first portion;
producing fluids from the first portion, wherein produced fluids from the first portion comprise methane;
removing water from the second portion of the formation, and then transferring at least a portion of such water to the first portion of the formation; and producing fluids from the second portion, wherein produced fluids from the second portion comprise methane.
1562. The method of claim 1561, wherein providing the first barrier comprises providing refrigerant to a plurality of freeze wells to form a frozen barrier zone and wherein the frozen barrier zone at least partially inhibits fluids from flowing into or out of the portion.
1563. The method of claim 1561, further comprising:
providing heat from one or more heaters to at least one portion of the formation; and allowing the heat to transfer from at least one of the heaters to a part of the formation.
1564. The method of claim 1561, wherein an average temperature of at least one portion of the formation is less than about a boiling point of water at formation conditions.
1565. The method of claim 1561, wherein an average temperature of at least one portion of the formation is less than about 100 °C.
1566. A method of in situ sequestration of carbon dioxide within a hydrocarbon containing formation, comprising:
storing carbon dioxide within at least one portion of the formation, wherein at least some methane has been produced from the portion of the formation prior to storing the carbon dioxide within the portion of the formation, and wherein the portion of the formation has been at least partially isolated from other subsurface areas using a barrier wall.
1567. The method of claim 1566, wherein water has been removed from the portion of the formation after the barrier wall was in place.
1568. The method of claim 1566, wherein the carbon dioxide is stored within a spent portion of the formation.
1569. The method of claim 1568, wherein the spent portion of the formation comprises hydrocarbon containing material within a section of the formation that has been heated and from which condensable hydrocarbons have been produced, and wherein the spent portion of the formation is at a temperature at which carbon dioxide adsorbs onto the hydrocarbon containing material.
1570. The method of claim 1566, further comprising raising a water level within the portion to inhibit migration of the carbon dioxide from the portion.
1571. The method of claim 1566, further comprising using the carbon dioxide to displace methane.
1572. The method of claim 1566, wherein the portion of the formation is more than about 760 m below ground surface.
1573. The method of claim 1566, further comprising adsorbing a portion of the carbon dioxide within the portion.
1574. A method of in situ sequestration of carbon dioxide within a hydrocarbon containing formation, comprising:
producing fluids from at least a portion of the formation, wherein produced fluids comprise methane, and wherein the portion of the formation has been at least partially isolated from other subsurface areas using a barrier wall; and storing carbon dioxide within the portion.
1575. The method of claim 1574, wherein water has been removed from the portion of the formation after the barrier wall was in place.
1576. The method of claim 1574, wherein the carbon dioxide is stored within a spent portion of the formation.
1577. The method of claim 1576, wherein the spent portion of the formation comprises hydrocarbon containing material within a section of the formation that has been heated and from which condensable hydrocarbons have been produced, and wherein the spent portion of the formation is at a temperature at which carbon dioxide adsorbs onto the hydrocarbon containing material.
1578. The method of claim 1574, further comprising raising a water level within the portion to inhibit migration of the carbon dioxide from the portion.
1579. The method of claim 1574, further comprising using the carbon dioxide to displace methane.
1580. The method of claim 1574, wherein the portion of the formation is more than about 760 m below ground surface.
1581. The method of claim 1574, further comprising adsorbing a portion of the carbon dioxide within the portion.
1582. The method of claim 1574, wherein producing fluids from the formation comprises removing pyrolyzation products from the formation.
1583. The method of claim 1574, wherein producing fluids from the formation comprises heating a portion of the formation to a temperature sufficient to generate synthesis gas; introducing a synthesis gas generating fluid into the part of the formation; and removing synthesis gas from the formation.
1584. A method of in situ sequestration of carbon dioxide within a hydrocarbon containing formation, comprising:
providing heat from one or more heaters to at least one portion of the formation, wherein the portion comprises methane, and wherein the portion of the formation has been at least partially isolated from other subsurface areas using a barrier wall;
allowing the heat to transfer from the one or more heaters to a part of the formation;
producing fluids from the formation, wherein produced fluids comprise methane;
allowing the portion to cool; and storing carbon dioxide within the portion.
1585. The method of claim 1584, wherein water has been removed from the portion of the formation after the barrier wall was in place.
1586. The method of claim 1584, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the part of the formation.
1587. The method of claim 1584, wherein the carbon dioxide is stored within a spent portion of the formation.
1588. The method of claim 1587, wherein the spent portion of the formation comprises hydrocarbon containing material within a section of the formation that has been heated and from which condensable hydrocarbons have been produced, and wherein the spent portion of the formation is at a temperature at which carbon dioxide adsorbs onto the hydrocarbon containing material.
1589. The method of claim 1587, wherein the spent portion of the formation comprises a substantially uniform permeability created by heating the spent formation and removing fluid during formation of the spent portion.
1590. The method of claim 1584, further comprising raising a water level within the portion to inhibit migration of the carbon dioxide from the portion.
1591. The method of claim 1584, further comprising using the carbon dioxide to displace methane.
1592. The method of claim 1584, wherein the portion of the formation is more than about 750 m below ground surface.
1593. The method of claim 1584, further comprising adsorbing a portion of the carbon dioxide within the portion.
1594. The method of claim 1584, wherein producing fluids from the formation comprises removing pyrolyzation products from the formation.
1595. The method of claim 1584, wherein heating the part of the formation comprises introducing an oxidizing fluid into the part of the formation, reacting the oxidizing fluid within the part of the formation to heat the part of the formation.
1596. The method of claim 1584, wherein heating the part of the formation comprises:
heating hydrocarbon containing material adjacent to one or more wellbores to a temperature sufficient to support oxidation of the hydrocarbon containing material with an oxidant;
introducing the oxidant to hydrocarbon containing material adjacent to one or more wellbores to oxidize hydrocarbons and produce heat; and conveying produced heat to the portion.
1597. The method of claim 1584, wherein at least one of the heaters comprises an electrical heater.
1598. The method of claim 1584, wherein at least one of the heaters comprises a flameless distributed combustor.
1599. The method of claim 1598, wherein a portion of fuel for one or more flameless distributed combustors is obtained from the formation.
1600. The method of claim 1584, wherein at least one of the heaters comprises a heater well in the formation through which heat transfer fluid is circulated.
1601. The method of claim 1600, wherein the heat transfer fluid comprises combustion products.
1602. The method of claim 1600, wherein the heat transfer fluid comprises steam.
1603. The method of claim 1584, further comprising:
producing condensable hydrocarbons under pressure; and generating electricity by passing a portion of the produced fluids through a turbine.
1604. The method of claim 1584, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.
1605. The method of claim 1584, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units of heaters are repeated over an area of the formation to form a repetitive pattern of units.
1606. A method of treating a hydrocarbon containing formation in situ, comprising:
providing heat from one or more heaters to at least one portion of the formation, wherein the formation comprises sub-bituminous coal;
allowing the heat to transfer from the one or more heaters to a part of the formation;
providing H2 to the part of the formation; and producing fluids from the formation.
1607. The method of claim 1606, wherein a portion of the formation comprises methane.
1608. The method of claim 1606, wherein the sub-bituminous coal has a vitrinite reflectance of less than about 0.5%.
1609. The method of claim 1606, wherein produced fluids comprise methane.
1610. The method of claim 1606, wherein one or more heaters comprise at least two heaters, and wherein superposition of heat from at least two heaters pyrolyzes at least some hydrocarbons within the part of the formation.
1611. The method of claim 1606, further comprising maintaining a temperature within the part of the formation within a pyrolysis temperature range.
1612. The method of claim 1606, wherein at least one of the heaters comprises an electrical heater.
1613. The method of claim 1606, wherein at least one of the heaters comprises a surface burner.
1614. The method of claim 1606, wherein at least one of the heaters comprises a flameless distributed combustor.
1615. The method of claim 1606, wherein at least one of the heaters comprises a natural distributed combustor.
1616. The method of claim 1606, further comprising controlling a pressure and a temperature within at least a majority of the part of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.
1617. The method of claim 1606, further comprising controlling the heat such that an average heating rate of the part of the formation is less than about 1 °C per day during pyrolysis.
1618. The method of claim 1606, wherein providing heat from the one or more heaters to at least a portion of formation comprises:
heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C v.rho.B, wherein .rho.B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10 °C/day.
1619. The method of claim 1606, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.
1620. The method of claim 1606, wherein providing heat from the one or more heaters comprises heating the part of the formation such that a thermal conductivity of at least a portion of the part of the formation is greater than about 0.5 W/(m °C).
1621. The method of claim 1606, further comprising producing a mixture comprising condensable hydrocarbons having an API gravity of at least about 25°.
1622. The method of claim 1606, further comprising producing a mixture comprising condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.
1623. The method of claim 1606, further comprising producing a mixture comprising non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
1624. The method of claim 1606, further comprising producing a mixture comprising condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.
1625. The method of claim 1606, further comprising producing a mixture comprising condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
1626. The method of claim 1606, further comprising producing a mixture comprising condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
1627. The method of claim 1606, further comprising producing a mixture comprising condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.
1628. The method of claim 1606, further comprising producing a mixture comprising condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.
1629. The method of claim 1606, further comprising producing a mixture comprising condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
1630. The method of claim 1606, further comprising producing a mixture comprising condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.
1631. The method of claim 1606, further comprising producing a mixture comprising condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.
1632. The method of claim 1606, further comprising producing a mixture comprising a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.
1633. The method of claim 1606, further comprising producing a mixture comprising ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.
1634. The method of claim 1606, further comprising producing a mixture comprising ammonia, and wherein the ammonia is used to produce fertilizer.
1635. The method of claim 1606, further comprising controlling a pressure within at least a majority of the part of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.
1636. The method of claim 1606, further comprising controlling formation conditions to produce a mixture, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
1637. The method of claim 1606, wherein a partial pressure of H2 within a produced fluid is measured when the produced fluid is at a production well.
1638. The method of claim 1606, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1639. The method of claim 1606, further comprising:
providing hydrogen (H2) to a heated section to hydrogenate hydrocarbons within the heated section; and heating a portion of the section with heat from hydrogenation.
1640. The method of claim 1606, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the part of the formation to greater than about 100 millidarcy.
1641. The method of claim 1606, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the part of the formation.
1642. The method of claim 1606, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.
1643. The method of claim 1606, further comprising producing a mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.
1644. The method of claim 1606, wherein at least about 20 heaters are disposed in the formation for each production well.
1645. The method of claim 1606, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.
1646. The method of claim 1606, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
1647. The method of claim 1606, further comprising providing at least one barrier wall to inhibit fluids flowing into or out of the portion.
1648. A method of treating a hydrocarbon containing formation in situ, comprising:
producing fluids from the formation, wherein the produced fluids comprise methane;
separating H2 from the produced fluids or converting at least some of the produced fluids to H2; and providing at least some of the separated or converted H2 to the portion of the formation.
1649. The method of claim 1648, further comprising controlling a pressure and a temperature within at least a majority of a part of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.
1650. The method of claim 1648, further comprising controlling formation conditions to produce the fluids, wherein a partial pressure of H2 within the fluids is greater than about 0.5 bars.
1651. The method of claim 1648, wherein a partial pressure of H2 within the fluids is measured when the fluids are at a production well.
1652. The method of claim 1648, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1653. A method of treating a hydrocarbon containing formation in situ, comprising:
producing fluids from the formation, wherein the produced fluids comprise methane;
separating H2 from the produced fluids or converting at least some of the produced fluids to H2;
providing heat from one or more heaters to at least one portion of the formation, wherein the portion comprises methane;
allowing the heat to transfer from the one or more heaters to a part of the formation; and providing at least some of the separated or converted H2 to the portion of the formation.
1654. The method of claim 1653, further comprising controlling a pressure and a temperature within at least a majority of a part of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.
1655. The method of claim 1653, further comprising controlling formation conditions to produce the fluids, wherein a partial pressure of H2 within the fluids is greater than about 0.5 bars.
1656. The method of claim 1653, wherein a partial pressure of H2 within the fluids is measured when the fluids are at a production well.
1657. The method of claim 1653, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1658. A method of treating a hydrocarbon containing formation in situ, comprising:
providing at least one barrier wall to at least a portion of the formation;
reducing a pressure in the portion of the formation in a controlled manner, wherein the portion of the formation comprises methane; and producing fluids from the formation, wherein the produced fluids comprise methane.
1659. The method of claim 1658, further comprising:
providing heat from one or more heaters to at least a portion of the formation; and allowing the heat to transfer from the one or more heaters to a part of the formation.
1660. The method of claim 1658, further comprising reducing the pressure below atmospheric pressure.
1661. The method of claim 1658, wherein reducing the pressure comprises removing water from the portion of the formation.
1662. The method of claim 1661, wherein removing water from the portion of the formation comprises using one or more dewatering wells.
1663. The method of claim 1658, wherein reducing the pressure comprises drawing up to a vacuum.
1664. The method of claim 1658, wherein reducing the pressure comprises drawing a vacuum.
1665. The method of claim 1658, further comprising providing a barrier to a portion of the formation.
1666. The method of claim 1665, wherein providing a barrier comprises:
providing refrigerant to a plurality of freeze wells to form a low temperature zone around the portion; and lowering a temperature within the low temperature zone to a temperature less than about a freezing temperature of water.
1667. The method of claim 1665, wherein providing a barrier comprises providing refrigerant to a plurality of freeze wells to form a frozen barrier zone and wherein the frozen barrier zone at least partially inhibits fluids from flowing into or out of the portion.
1668. The method of claim 1658, wherein an average temperature of at least one portion of the formation is less than about a boiling point of water at formation conditions.
1669. The method of claim 1658, wherein an average temperature of at least one portion of the formation is less than about 100°C.
1670. The method of claim 1658, further comprising:
providing a barrier to a portion of the formation; and removing water from the portion.
1671. A method of treating a hydrocarbon containing formation in situ, comprising:
providing a barrier to at least a portion of the formation, wherein the barrier inhibits fluids from flowing into or out of the portion;
removing at least some water from the portion;
reducing a pressure in the portion of the formation, wherein the portion of the formation comprises methane; and producing fluids from the formation, wherein the produced fluids comprise methane.
1672. The method of claim 1671, further comprising:
providing heat from one or more heaters to at least a portion of the formation; and allowing the heat to transfer from the one or more heaters to a part of the formation.
1673. The method of claim 1671, further comprising reducing the pressure below atmospheric pressure.
1674. The method of claim 1671, wherein the methane produced is coal bed methane.
1675. The method of claim 1671, wherein removing the water comprises pumping water from the portion of the formation.
1676. The method of claim 1675, wherein removing water from the portion of the formation comprises using one or more dewatering wells.
1677. The method of claim 1671, wherein reducing the pressure comprises drawing a vacuum.
1678. The method of claim 1671, wherein providing a barrier comprises:
providing refrigerant to a plurality of freeze wells to form a low temperature zone around at least a portion of the portion; and lowering a temperature within the low temperature zone to a temperature less than about a freezing temperature of water.
1679. The method of claim 1671, wherein providing a barrier comprises providing refrigerant to a plurality of freeze wells to form a frozen barrier zone and wherein the frozen barrier zone at least partially inhibits fluids from flowing into or out of the portion.
1680. The method of claim 1671, wherein an average temperature of at least one portion of the formation is less than about a boiling point of water at formation conditions.
1681. The method of claim 1671, wherein an average temperature of at least one portion of the formation is less than about 100 °C.
1682. A method of treating a hydrocarbon containing formation in situ, comprising:
providing a first barrier to a first portion of the formation, wherein the first portion comprises methane;
removing water from the first portion;
producing fluids from the first portion, wherein produced fluids from the first portion comprise methane;
providing a second barrier to a second portion of the formation, wherein the second portion comprises methane;
removing water from the second portion, and then transferring at least a portion of such water to the first portion;
providing carbon dioxide to the second portion of the formation; and producing fluids from the second portion, wherein produced fluids from the second portion comprise methane.
1683. The method of claim 1682, further comprising providing carbon dioxide to the first portion of the formation.
1684. The method of claim 1683, wherein at least some of the carbon dioxide provided to the first portion displaces methane.
1685. The method of claim 1682, wherein at least some of the carbon dioxide displaces methane.
1686. The method of claim 1682, wherein providing a first barrier comprises:
providing refrigerant to a plurality of freeze wells to form a low temperature zone around the first portion;
and lowering a temperature within the low temperature zone to a temperature less than about a freezing temperature of water.
1687. The method of claim 1682, wherein providing a second barrier comprises:
providing refrigerant to a plurality of freeze wells to form a low temperature zone around the second portion; and lowering a temperature within the low temperature zone to a temperature less than about a freezing temperature of water.
1688. The method of claim 1682, wherein providing a first barrier comprises providing refrigerant to a plurality of freeze wells to form a frozen barrier zone and wherein the frozen barrier zone at least partially inhibits fluids from flowing into or out of the portion.
1689. The method of claim 1682, wherein providing a second barrier comprises providing refrigerant to a plurality of freeze wells to form a frozen barrier zone and wherein the frozen barrier zone at least partially inhibits fluids from flowing into or out of the portion.
1690. The method of claim 1682, further comprising:
providing heat from one or more heaters to at least one portion of the formation; and allowing the heat to transfer from at least one of the heaters to a part of the formation.
1691. A heating system, comprising:
an electrical conductor configured to generate an electrically resistive heat output during application of electrical current to the electrical conductor, wherein the electrical conductor comprises an electrically resistive ferromagnetic material;
a conduit at least partially surrounding the electrical conductor;
a fluid located in a space between the electrical conductor and the conduit, wherein the fluid has a higher thermal conductivity than air at 1 atm and a temperature in the space; and wherein the heating system is configured to provide a reduced amount of heat above or near a selected temperature.
1692. The heating system of claim 1691, wherein the electrical conductor at least partially surrounds a non-ferromagnetic material.
1693. The heating system of claim 1691, wherein the fluid comprises an electrically insulating fluid.
1694. The heating system of claim 1691, wherein the fluid comprises helium.
1695. The heating system of claim 1691, wherein the fluid comprises helium, and wherein the space between the electrical conductor and the conduit comprises at least about 50% by volume helium.
1696. The heating system of claim 1691, wherein the fluid comprises helium, and wherein the space between the electrical conductor and the conduit comprises at least about 75% by volume helium.
1697. The heating system of claim 1691, wherein the fluid comprises helium, and wherein the space between the electrical conductor and the conduit comprises at least about 90% by volume helium.
1698. The heating system of claim 1691, wherein a fluid pressure in the space between the electrical conductor and the conduit is at least about 5 atm.
1699. The heating system of claim 1691, wherein a fluid pressure in the space between the electrical conductor and the conduit is at least about 7 atm.
1700. The heating system of claim 1691, wherein a fluid pressure in the space between the electrical conductor and the conduit is at least about 10 atm.
1701. The heating system of claim 1691, further comprising an AC power supply.
2702. The heating system of claim 2691, further comprising a modulated DC
power supply.
1703. The heating system of claim 1691, further comprising a centralizer configured to maintain a separation distance between the electrical conductor and the conduit.
1704. The heating system of claim 1691, wherein the heating system is configured to allow heat to transfer from the heater to a part of a subsurface formation to pyrolyze at least some hydrocarbons in the subsurface formation.
1705. The heating system of claim 1691, wherein the heater is configured to be placed in an opening in a subsurface formation.
1706. The heating system of claim 1691, wherein a resistance of the ferromagnetic material decreases above the selected temperature such that the heater provides the reduced amount of heat above the selected temperature.
1707. A method of heating a subsurface formation, comprising:
providing electrical current to an electrical conductor to provide an electrically resistive heat output, wherein the electrical conductor comprises an electrically resistive ferromagnetic material, wherein a conduit at least partially surrounds the electrical conductor, wherein a fluid is located in a space between the electrical conductor and the conduit, and wherein the fluid has a higher thermal conductivity than air at 1 atm and a temperature in the space; and allowing heat to transfer from the electrical conductor to at least part of the subsurface formation such that the electrical conductor provides a reduced amount of heat above or near a selected temperature.
1708. The method of claim 1707, wherein the electrical conductor at least partially surrounds a non-ferromagnetic material.
1709. The method of claim 1707, wherein the fluid comprises an electrically insulating fluid.
1710. The method of claim 1707, wherein the fluid comprises helium.
1711. The method of claim 1707, wherein the fluid comprises helium, and wherein the space between the electrical conductor and the conduit comprises at least about 50% by volume helium.
1712. The method of claim 1707, wherein the fluid comprises helium, and wherein the space between the electrical conductor and the conduit comprises at least about 75% by volume helium.
1713. The method of claim 1707, wherein the fluid comprises helium, and wherein the space between the electrical conductor and the conduit comprises at least about 90% by volume helium.
1714. The method of claim 1707, wherein a fluid pressure in the space between the electrical conductor and the conduit is at least about 5 atm.
1715. The method of claim 1707, wherein a fluid pressure in the space between the electrical conductor and the conduit is at least about 7 atm.
1716. The method of claim 1707, wherein a fluid pressure in the space between the electrical conductor and the conduit is at least about 10 atm.
1717. The method of claim 1707, further comprising providing the electrical current from an AC power supply.
1718. The method of claim 1707, further comprising providing the electrical current from a modulated DC power supply.
1719. The method of claim 1707, wherein the reduced amount of heat is provided without adjusting the amperage of the electrical current applied to the electrical conductor.
1720. The method of claim 1707, further comprising providing an initial electrically resistive heat output when the electrical conductor providing the heat output is at least about 50 °C below the selected temperature, and automatically providing the reduced amount of heat above or near the selected temperature.
1721. The method of claim 1707, further comprising placing the electrical conductor in a wellbore in the subsurface formation.
1722. The method of claim 1707, wherein heat output from the electrical conductor is substantially constant when a temperature of the electrical conductor is between about 100 °C
and 750 °C.
1723. A heating system, comprising:
an electrical conductor configured to generate an electrically resistive heat output when electrical current is applied to the electrical conductor, wherein the electrical conductor comprises an electrically resistive ferromagnetic material;
a conduit surrounding the electrical conductor;
a fluid located in a space between the electrical conductor and the conduit, wherein the fluid has a higher thermal conductivity than air at 1 atm and a temperature in the space; and wherein the heating system is configured to provide a reduced amount of heat above or near a selected temperature that is about 20% or less of the heat output at about 50 °C
below the selected temperature.
1724. A system configured to heat at least a part of a subsurface formation, comprising:
an electrical power supply, wherein the electrical power supply is configured to provide a modulated electrical current;
one or more electrical conductors configured to be electrically coupled to the electrical power supply and placed in an opening in the formation, wherein at least one of the electrical conductors comprises a heater section, the heater section comprising an electrically resistive ferromagnetic material configured to provide an electrically resistive heat output when the modulated electrical current is applied to the ferromagnetic material, and wherein the heater section is configured to provide a reduced amount of heat near or above a selected temperature during use due to the decreasing electrical resistance of the heater section when the temperature of the ferromagnetic material is near or above the selected temperature; and wherein the system is configured to allow heat to transfer from the heater section to a part of the formation.
1725. The system of claim 1724, wherein the electrical power supply is configured to provide modulated direct current (DC).
1726. The system of claim 1724, wherein the electrical power supply comprises a variable frequency DC
electrical power supply.
1727. The system of claim 1724, wherein the electrical power supply is configured to provide DC, and wherein the electrical power supply is further configured to modulate the frequency of the DC.
1728. The system of claim 1724, wherein the electrical power supply is configured to provide square wave modulated DC.
1729. The system of claim 1724, wherein the heater section automatically provides a reduced amount of heat above or near the selected temperature.
1730. The system of claim 1724, wherein at least a portion of the heater section is positionable adjacent to hydrocarbon material in the formation to raise a temperature of at least some of the hydrocarbon material to or above a pyrolysis temperature.
1731. The system of claim 1724, wherein the heater section is configured to exhibit an increase in operating temperature of less than about 1.5 °C above or near a selected operating temperature when a thermal load proximate the heater section decreases by about 1 watt per meter.
1732. The system of claim 1724, wherein at least one of the electrical conductors is configured to provide a reduced amount of heat above or near the selected temperature that is about 20% or less of the heat output at about 50 °C below the selected temperature.
1733. The system of claim 1724, wherein the electrical resistance of the heater section decreases above the selected temperature to provide the reduced amount of heat.
1734. The system of claim 1724, further comprising a non-ferromagnetic material coupled to the ferromagnetic material, wherein the non-ferromagnetic material has a higher electrical conductivity than the ferromagnetic material.
1735. The system of claim 1724, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1736. The system of claim 1724, wherein the ferromagnetic material has a turndown ratio of at least about 2 to 1.
1737. The system of claim 1724, wherein the ferromagnetic material comprises iron, nickel, chromium, cobalt, tungsten, or a mixture thereof.
1738. The system of claim 1724, wherein at least a portion of at least one electrically resistive ferromagnetic material is longer than about 10 m.
1739. The system of claim 1724, wherein at least one of the electrical conductors is elongated and configured such that only electrically resistive sections at or near the selected temperature will automatically reduce the heat output.
1740. The system of claim 1724, wherein the ferromagnetic material is configured to radiatively heat the formation.
1741. A method for heating a subsurface formation, comprising:
applying modulated electrical current to one or more electrical conductors located in the subsurface formation to provide an electrically resistive heat output, wherein at least one of the electrical conductors comprises an electrically resistive ferromagnetic material that provides heat when modulated electrical current flows through the electrically resistive ferromagnetic material, and wherein such electrical conductor comprising electrically resistive ferromagnetic material provides a reduced amount of heat above or near a selected temperature; and allowing the heat to transfer from the electrically resistive ferromagnetic material to a part of the subsurface formation.
1742. The method of claim 1741, wherein the modulated electrical current comprises modulated direct current (DC).
1743. The method of claim 1741, wherein the modulated electrical current comprises square wave modulated DC.
1744. The method of claim 1741, further comprising varying a frequency of the modulated electrical current.
1745. The method of claim 1741, wherein the electrically resistive ferromagnetic material automatically provides a selected reduced amount of heat above or near a selected temperature.
1746. The method of claim 1741, further comprising placing one or more of the electrical conductors in a wellbore in the formation.
1747. The method of claim 1741, wherein an electrical resistance of the ferromagnetic material decreases above the selected temperature to provide the reduced amount of heat.
1748. The method of claim 1741, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1749. The method of claim 1741, wherein the subsurface formation comprises a hydrocarbon containing formation.
1750. The method of claim 1741, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising heating at least some hydrocarbons in the formation such that at least some of the hydrocarbons are pyrolyzed.
1751. The method of claim 1741, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1752. The method of claim 1741, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising controlling the provided heat to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1753. The method of claim 1741, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising heating at least a portion of the part of the formation to a minimum pyrolysis temperature of about 270 °C.
1754. The method of claim 1741, further comprising controlling a skin depth in the ferromagnetic material by controlling a modulation of the applied electrical current.
1755. The method of claim 1741, further comprising producing fluids from the formation, and blending the produced fluids with hydrocarbons having an API gravity below about 15°.
1756. A system configured to heat at least a part of a subsurface formation, comprising:
an electrical power supply;
one or more electrical conductors configured to be electrically coupled to the electrical power supply and placed in an opening in the formation, wherein at least one of the electrical conductors comprises a heater section, the heater section comprising an electrically resistive ferromagnetic material configured to provide an electrically resistive heat output when electrical current is applied to the ferromagnetic material, and wherein the heater section is configured to provide a reduced amount of heat near or above a selected temperature during use due to the decreasing electrical resistance of the heater section when the temperature of the ferromagnetic material is near or above the selected temperature;
wherein the system is configured to allow heat to transfer from the heater section to a part of the formation;
and wherein the electrical power supply is configured to provide a relatively constant amount of electrical current that remains within about 15% of a selected constant current value when a load of the electrical conductors changes.
1757. The system of claim 1756, wherein the electrical power supply is configured to provide a relatively constant amount of electrical current that remains within about 10% of a selected constant current value when a load of the electrical conductors changes.
1758. The system of claim 1756, wherein the electrical power supply is configured to provide a relatively constant amount of electrical current that remains within about 5% of a selected constant current value when a load of the electrical conductors changes.
1759. The system of claim 1756, wherein the electrical power supply is configured to provide AC.
1760. The system of claim 1756, wherein the electrical power supply is configured to provide modulated direct current (DC).
1761. The system of claim 1756, wherein the electrical power supply comprises a variable frequency DC
electrical power supply.
1762. The system of claim 1756, wherein the electrical power supply is configured to provide DC, and wherein the electrical power supply is configured to modulate the frequency of the DC.
1763. The system of claim 1756, wherein the electrical power supply is configured to provide square wave modulated DC.
1764. The system of claim 1756, further comprising a variable capacitor coupled to the electrical power supply, wherein the variable capacitor is configured to maintain a power factor of the electrical conductors above about 0.85.
1765. The system of claim 1756, wherein the electrical power supply is configured to provide modulated DC in a pre-shaped waveform, and wherein the pre-shaped waveform is shaped to at least partially compensate for phase shift and/or harmonic distortions in the electrical conductors.
1766. The system of claim 1756, wherein the heater section automatically provides a reduced amount of heat above or near the selected temperature.
1767. The system of claim 1756, wherein at least a portion of the heater section is positionable adjacent to hydrocarbon material in the formation to raise a temperature of at least some of the hydrocarbon material to or above a pyrolysis temperature.
1768. The system of claim 1756, wherein the heater section is configured to exhibit an increase in operating temperature of less than about 1.5 °C above or near a selected operating temperature when a thermal load proximate the heater section decreases by about 1 watt per meter.
1769. The system of claim 1756, wherein at least one of the electrical conductors is configured to provide a reduced amount of heat above or near the selected temperature that is about 20% or less of the heat output at about 50 °C below the selected temperature.
1770. The system of claim 1756, wherein the electrical resistance of the heater section decreases above the selected temperature to provide the reduced amount of heat.
1771. The system of claim 1756, further comprising a non-ferromagnetic material coupled to the ferromagnetic material, wherein the non-ferromagnetic material has a higher electrical conductivity than the ferromagnetic material.
1772. The system of claim 1756, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1773. The system of claim 1756, wherein the ferromagnetic material has a turndown ratio of at least about 2 to 1.
1774. The system of claim 1756, wherein the ferromagnetic material comprises iron, nickel, chromium, cobalt, tungsten, or a mixture thereof.
1775. The system of claim 1756, wherein at least a portion of at least one electrically resistive ferromagnetic material is longer than about 10 m.
1776. The system of claim 1756, wherein at least one of the electrical conductors is elongated and configured such that only electrically resistive sections at or near the selected temperature will automatically reduce the heat output.
1777. The system of claim 1756, wherein the ferromagnetic material is configured to radiatively heat the formation.
1778. A method for heating a subsurface formation, comprising:
applying electrical current to one or more electrical conductors located in the subsurface formation to provide an electrically resistive heat output, wherein at least one of the electrical conductors comprises an electrically resistive ferromagnetic material that provides heat when electrical current flows through the electrically resistive ferromagnetic material, and wherein such electrical conductor comprising electrically resistive ferromagnetic material provides a reduced amount of heat above or near a selected temperature; and allowing the heat to transfer from the electrically resistive ferromagnetic material to a part of the subsurface formation; and wherein the applied electrical current remains within about 15% of a selected constant current value when a load of the electrical conductors changes.
1779. The method of claim 1778, wherein the applied electrical current remains within about 10% of a selected constant current value when a load of the electrical conductors changes.
1780. The method of claim 1778, wherein the applied electrical current remains within about 5% of a selected constant current value when a load of the electrical conductors changes.
1781. The method of claim 1778, wherein the electrical current comprises alternating current.
1782. The method of claim 1778, wherein the electrical current comprises modulated direct current (DC).
1783. The method of claim 1778, wherein the electrical current comprises square wave modulated DC.
1784. The method of claim 1778, further comprising varying a frequency of the electrical current.
1785. The method of claim 1778, further comprising applying a capacitive load to the electrical conductors to maintain a power factor of the electrical conductors above about 0.85.
1786. The method of claim 1778, further comprising applying modulated DC
electrical current in a pre-shaped waveform, wherein the pre-shaped waveform is shaped to at least partially compensate for phase shift and/or harmonic distortions in the electrical conductors.
1787. The method of claim 1778, wherein the electrically resistive ferromagnetic material automatically provides a selected reduced amount of heat above or near a selected temperature.
1788. The method of claim 1778, further comprising placing one or more of the electrical conductors in a wellbore in the formation.
1789. The method of claim 1778, wherein an electrical resistance of the ferromagnetic material decreases above the selected temperature to provide the reduced amount of heat.
1790. The method of claim 1778, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1791. The method of claim 1778, wherein the subsurface formation comprises a hydrocarbon containing formation.
1792. The method of claim 1778, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising heating at least some hydrocarbons in the formation such that at least some of the hydrocarbons are pyrolyzed.
1793. The method of claim 1778, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1794. The method of claim 1778, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising controlling the provided heat to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1795. The method of claim 1778, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising heating at least a portion of the part of the formation to a minimum pyrolysis temperature of about 270 °C.
1796. The method of claim 1778, further comprising controlling a skin depth in the ferromagnetic material by controlling a frequency of the applied electrical current.
1797. The method of claim 1778, further comprising producing fluids from the formation, and blending the produced fluids with hydrocarbons having an API gravity below about 15°.
1798. A heating system configured to heat at least a part of a subsurface formation, comprising:
an electrical power supply;
one or more electrical conductors configured to be electrically coupled to the electrical power supply and placed in an opening in the formation, wherein at least one of the electrical conductors comprises a heater section, the heater section comprising an electrically resistive ferromagnetic material configured to provide an electrically resistive heat output when electrical current is applied to the ferromagnetic material, and wherein the heater section is configured to provide a reduced amount of heat near or above a selected temperature during use due to the decreasing electrical resistance of the heater section when the temperature of the ferromagnetic material is near or above the selected temperature;
a variable capacitor, wherein the variable capacitor is configured maintain a power factor of the electrical conductors above about 0.85 during use; and wherein the system is configured to allow heat to transfer from the heater section to a part of the formation.
1799. The system of claim 1798, wherein the variable capacitor is configured maintain the power factor of the electrical conductors above about 0.9 during use.
1800. The system of claim 1798, wherein the variable capacitor is configured maintain the power factor of the electrical conductors above about 0.95 during use.
1801. The system of claim 1798, wherein a capacitance of the variable capacitor is varied to maintain the power factor of the electrical conductors above about 0.85 during use.
1802. The system of claim 1798, wherein the electrical power supply is configured to provide a relatively constant amount of electrical current that remains within about 15% of a selected constant current value when a load of the electrical conductors changes.
1803. The system of claim 1798, wherein the electrical power supply is configured to provide AC.
1804. The system of claim 1798, wherein the electrical power supply is configured to provide modulated direct current (DC).
1805. The system of claim 1798, wherein the electrical power supply comprises a variable frequency DC
electrical power supply.
1806. The system of claim 1798, wherein the electrical power supply is configured to provide DC, and wherein the electrical power supply is configured to modulate the frequency of the DC.
1807. The system of claim 1798, wherein the electrical power supply is configured to provide square wave modulated DC.
1808. The system of claim 1798, wherein the electrical power supply is configured to provide modulated DC in a pre-shaped waveform, and wherein the pre-shaped waveform is shaped to at least partially compensate for phase shift and/or harmonic distortions in the electrical conductors.
1809. The system of claim 1798, wherein the heater section automatically provides a reduced amount of heat above or near the selected temperature.
1810, The system of claim 1798, wherein at least a portion of the heater section is positionable adjacent to hydrocarbon material in the formation to raise a temperature of at least some of the hydrocarbon material to or above a pyrolysis temperature.
1811. The system of claim 1798, wherein the heater section is configured to exhibit an increase in operating temperature of less than about 1.5 °C above or near a selected operating temperature when a thermal load proximate the heater section decreases by about 1 watt per meter.
1812. The system of claim 1798, wherein at least one of the electrical conductors is configured to provide a reduced amount of heat above or near the selected temperature that is about 20% or less of the heat output at about 50 °C below the selected temperature.
1813. The system of claim 1798, wherein the electrical resistance of the heater section decreases above the selected temperature to provide the reduced amount of heat.
1814. The system of claim 1798, further comprising a non-ferromagnetic material coupled to the ferromagnetic material, wherein the non-ferromagnetic material has a higher electrical conductivity than the ferromagnetic material.
1815. The system of claim 1798, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1816. The system of claim 1798, wherein the ferromagnetic material has a turndown ratio of at least about 2 to 1.
1817. The system of claim 1798, wherein the ferromagnetic material comprises iron, nickel, chromium, cobalt, tungsten, or a mixture thereof.
1818. The system of claim 1798, wherein at least a portion of at least one electrically resistive ferromagnetic material is longer than about 10 m.
1819. The system of claim 1798, wherein at least one of the electrical conductors is elongated and configured such that only electrically resistive sections at or near the selected temperature will automatically reduce the heat output.
182. The system of claim 1798, wherein the ferromagnetic material is configured to radiatively heat the formation.
1821. A method for heating a subsurface formation, comprising:
applying electrical current from an electrical power supply to one or more electrical conductors located in the subsurface formation to provide an electrically resistive heat output, wherein at least one of the electrical conductors comprises an electrically resistive ferromagnetic material that provides heat when electrical current flows through the electrically resistive ferromagnetic material, and wherein such electrical conductor comprising electrically resistive ferromagnetic material provides a reduced amount of heat above or near a selected temperature; and allowing the heat to transfer from the electrically resistive ferromagnetic material to a part of the subsurface formation; and applying a capacitive load to the electrical conductors to maintain a power factor of the electrical conductors above about 0.85.
1822. The method of claim 1821, applying the capacitive load to the electrical conductors to maintain the power factor of the electrical conductors above about 0.9.
1823. The method of claim 1821, applying the capacitive load to the electrical conductors to maintain the power factor of the electrical conductors above about 0.95.
1824. The method of claim 1821, further comprising varying the capacitive load to maintain the power factor of the electrical conductors above about 0.85.
1825. The method of claim 1821, wherein the applied electrical current remains within about 15% of a selected constant current value when a load of the electrical conductors changes.
1826. The method of claim 1821, wherein the electrical current comprises alternating current.
1827. The method of claim 1821, wherein the electrical current comprises modulated direct current (DC).
1828. The method of claim 1821, wherein the electrical current comprises square wave modulated DC.
1829. The method of claim 1821, further comprising varying a frequency of the electrical current.
1830. The method of claim 1821, further comprising applying modulated DC
electrical current in a pre-shaped waveform, wherein the pre-shaped waveform is shaped to at least partially compensate for phase shift and/or harmonic distortions in the electrical conductors 1831. The method of claim 1821, wherein the electrically resistive ferromagnetic material automatically provides a selected reduced amount of heat above or near a selected temperature.
1832. The method of claim 1821, further comprising placing one or more of the electrical conductors in a wellbore in the formation.
1833. The method of claim 1821, wherein an electrical resistance of the ferromagnetic material decreases above the selected temperature to provide the reduced amount of heat.
1834. The method of claim 1821, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1835. The method of claim 1821, wherein the subsurface formation comprises a hydrocarbon containing formation.
1836. The method of claim 1821, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising heating at least some hydrocarbons in the formation such that at least some of the hydrocarbons are pyrolyzed.
1837. The method of claim 1821, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1838. The method of claim 1821, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising controlling the provided heat to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1839. The method of claim 1821, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising heating at least a portion of the part of the formation to a minimum pyrolysis temperature of about 270 °C.
1840. The method of claim 1821, further comprising controlling a skin depth in the ferromagnetic material by controlling a frequency of the applied electrical current.
1841. The method of claim 1821, further comprising producing fluids from the formation, and blending the produced fluids with hydrocarbons having an API gravity below about 15°.
1842. A heating system configured to heat at least a part of a subsurface formation, comprising:
an electrical power supply;
one or more electrical conductors configured to be electrically coupled to the electrical power supply and placed in an opening in the formation, wherein at least one of the electrical conductors comprises a heater section, the heater section comprising an electrically resistive ferromagnetic material configured to provide an electrically resistive heat output when electrical current is applied to the ferromagnetic material, and wherein the heater section is configured to provide a reduced amount of heat near or above a selected temperature during use due to the decreasing electrical resistance of the heater section when the temperature of the ferromagnetic material is near or above the selected temperature;
wherein the system is configured to allow heat to transfer from the heater section to a part of the formation;
and wherein the system is configured to allow a frequency of the applied electrical current to be varied.
1843. The system of claim 1842, wherein the frequency of the applied electrical current is configured to be varied based on one or more subsurface conditions at or near the electrical conductors.
1844. The system of claim 1842, wherein the frequency of the applied electrical current is configured to be varied as a function of a temperature at or near the electrical conductors in the subsurface formation.
1845. The system of claim 1842, wherein the frequency of the applied electrical current is configured to be varied to adjust a turndown ratio of the electrical conductors.
1846. The system of claim 1842, wherein the electrical power supply is configured to provide AC.
1847. The system of claim 1842, wherein the electrical power supply is configured to provide modulated direct current (DC).
1848. The system of claim 1842, wherein the electrical power supply comprises a variable frequency DC
electrical power supply.
1849. The system of claim 1842, wherein the electrical power supply is configured to provide DC, and wherein the electrical power supply is further configured to modulate the frequency of the DC.
1850. The system of claim 1842, wherein the electrical power supply is configured to provide square wave modulated DC.
1851. The system of claim 1842, wherein the electrical power supply is configured to provide modulated DC in a pre-shaped waveform, and wherein the pre-shaped waveform is shaped to at least partially compensate for phase shift and/or harmonic distortions in the electrical conductors.
1852. The system of claim 1842, wherein the heater section automatically provides a reduced amount of heat above or near the selected temperature.
1853. The system of claim 1842, wherein at least a portion of the heater section is positionable adjacent to hydrocarbon material in the formation to raise a temperature of at least some of the hydrocarbon material to or above a pyrolysis temperature.
1854. The system of claim 1842, wherein the heater section is configured to exhibit an increase in operating temperature of less than about 1.5 °C above or near a selected operating temperature when a thermal load proximate the heater section decreases by about 1 watt per meter.
1855. The system of claim 1842, wherein at least one of the electrical conductors is configured to provide a reduced amount of heat above or near the selected temperature that is about 20% or less of the heat output at about 50 °C below the selected temperature.
1856. The system of claim 1842, wherein the electrical resistance of the heater section decreases above the selected temperature to provide the reduced amount of heat.
1857. The system of claim 1842, further comprising a non-ferromagnetic material coupled to the ferromagnetic material, wherein the non-ferromagnetic material has a higher electrical conductivity than the ferromagnetic material.
1858. The system of claim 1842, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1859. The system of claim 1842, wherein the ferromagnetic material has a turndown ratio of at least about 2 to 1.
1860. The system of claim 1842, wherein the ferromagnetic material comprises iron, nickel, chromium, cobalt, tungsten, or a mixture thereof.
1861. The system of claim 1842, wherein at least a portion of at least one electrically resistive ferromagnetic material is longer than about 10 m.
1862. The system of claim 1842, wherein at least one of the electrical conductors is elongated and configured such that only electrically resistive sections at or near the selected temperature will automatically reduce the heat output.
1863. The system of claim 1842, wherein the ferromagnetic material is configured to radiatively heat the formation.
1864. A method for heating a subsurface formation, comprising:
applying electrical current to one or more electrical conductors located in the subsurface formation to provide an electrically resistive heat output, wherein at least one of the electrical conductors comprises an electrically resistive ferromagnetic material that provides heat when electrical current flows through the electrically resistive ferromagnetic material, and wherein such electrical conductor comprising electrically resistive ferromagnetic material provides a reduced amount of heat above or near a selected temperature;
allowing the heat to transfer from the electrically resistive ferromagnetic material to a part of the subsurface formation; and varying a frequency of the applied electrical current.
1865. The method of claim 1864, further comprising assessing one or more subsurface conditions at or near the electrical conductors in the subsurface formation and varying the frequency of the applied electrical current based on at least one assessed condition.
1866. The method of claim 1864, further comprising assessing a temperature at or near the electrical conductors in the subsurface formation and varying the frequency of the applied electrical current based on the assessed temperature.
1867. The method of claim 1864, further comprising varying the frequency of the applied electrical current to adjust a turndown ratio of the electrical conductors.
1868. The method of claim 1864, wherein the electrical current comprises alternating current.
1869. The method of claim 1864, wherein the electrical current comprises modulated direct current (DC).
1870. The method of claim 1864, wherein the electrical current comprises square wave modulated DC.
1871. The method of claim 1864, further comprising applying modulated DC
electrical current in a pre-shaped waveform, wherein the pre-shaped waveform is shaped to at least partially compensate for phase shift and/or harmonic distortions in the electrical conductors.
1872. The method of claim 1864, wherein the electrically resistive ferromagnetic material automatically provides a selected reduced amount of heat above or near the selected temperature.
1873. The method of claim 1864, further comprising placing one or more of the electrical conductors in a wellbore in the formation.
1874. The method of claim 1864, wherein an electrical resistance of the ferromagnetic material decreases above the selected temperature to provide the reduced amount of heat.
1875. The method of claim 1864, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1876. The method of claim 1864, wherein the subsurface formation comprises a hydrocarbon containing formation.
1877. The method of claim 1864, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising heating at least some hydrocarbons in the formation such that at least some of the hydrocarbons are pyrolyzed.
1878. The method of claim 2864, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1879. The method of claim 1864, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising controlling the provided heat to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1880. The method of claim 1864, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising heating at least a portion of the part of the formation to a minimum pyrolysis temperature of about 270 °C.
1881. The method of claim 1864, further comprising controlling a skin depth in the ferromagnetic material by controlling a frequency of the applied electrical current.
1882. The method of claim 1864, further comprising producing fluids from the formation, and blending the produced fluids with hydrocarbons having an API gravity below about 15°.
1883. A method for heating a subsurface formation, comprising:
applying substantially non-modulated direct electrical current (DC) to one or more electrical conductors located in the subsurface formation to provide an electrically resistive heat output, wherein at least one of the electrical conductors comprises an electrically resistive ferromagnetic material that provides heat when electrical current flows through the electrically resistive ferromagnetic material;
applying modulated DC or alternating current (AC) to the electrical conductors when a temperature of the electrical conductors approaches a Curie temperature of the electrically resistive ferromagnetic material so that the electrical conductors comprising electrically resistive ferromagnetic material provide a reduced amount of heat above or near a selected temperature; and allowing the heat to transfer from the electrically resistive ferromagnetic material to a part of the subsurface formation.
1884. The method of claim 1883, further comprising varying the frequency of the applied modulated DC or AC
to adjust a turndown ratio of the electrical conductors.
1885. The method of claim 1883, further comprising applying modulated DC in a pre-shaped waveform, wherein the pre-shaped waveform is shaped to at least partially compensate for phase shift and/or harmonic distortions in the electrical conductors.
1886. The method of claim 1883, wherein the electrically resistive ferromagnetic material automatically provides a selected reduced amount of heat above or near the selected temperature.
1887. The method of claim 1883, wherein an electrical resistance of the ferromagnetic material decreases above the selected temperature to provide the reduced amount of heat.
1888. The method of claim 1883, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
1889. The method of claim 1883, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising heating at least some hydrocarbons in the formation such that at least some of the hydrocarbons are pyrolyzed.
1890. The method of claim 1883, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1891. The method of claim 1883, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising controlling the provided heat to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1892. The method of claim 1883, wherein the subsurface formation comprises a hydrocarbon containing formation, and further comprising heating at least a portion of the part of the formation to a minimum pyrolysis temperature of about 270°C.
1893. The method of claim 1883, further comprising controlling a skin depth in the ferromagnetic material by controlling a frequency of the applied modulated DC or AC.
1894. The method of claim 1883, further comprising producing fluids from the formation, and blending the produced fluids with hydrocarbons having an API gravity below about 15°.
1895. A heater, comprising:
an inner electrical conductor;
a ferromagnetic conductor at least partially surrounding the inner electrical conductor, wherein the ferromagnetic conductor is configured to generate an electrically resistive heat output during application of electrical current to the ferromagnetic conductor, and wherein the ferromagnetic conductor comprises electrically resistive ferromagnetic material;
an outer electrical conductor at least partially surrounding the ferromagnetic conductor;
wherein an applied electrical current is configured to propagate through the inner electrical conductor and the outer electrical conductor in substantially the same direction, and wherein the applied electrical current is configured to propagate through the ferromagnetic conductor in a substantially opposite direction from the direction of applied electrical current in the inner electrical conductor and the outer electrical conductor; and wherein the heater is configured to provide a reduced amount of heat above or near a selected temperature.
1896. The heater of claim 1895, wherein the inner electrical conductor and the outer electrical conductor are electrically coupled at one end.
1897. The heater of claim 1895, wherein the inner electrical conductor comprises an electrically resistive, non-ferromagnetic material.
1898. The heater of claim 1895, wherein the outer electrical conductor comprises an electrically resistive, non-ferromagnetic material.
1899. The heater of claim 1895, further comprising an electrical insulator located between the inner electrical conductor and the ferromagnetic conductor.
1900. The heater of claim 1899, wherein the electrical insulator comprises silicon nitride.
1901. The heater of claim 1899, wherein the electrical insulator comprises boron nitride.
1902. The heater of claim 1895, further comprising an electrical insulator located between the ferromagnetic conductor and the outer electrical conductor.
1903. The heater of claim 1902, wherein the electrical insulator comprises silicon nitride.
1904. The heater of claim 1902, wherein the electrical insulator comprises boron nitride.
1905. The heater of claim 1895, wherein the applied electrical current comprises AC.
1906. The heater of claim 1895, wherein the applied electrical current comprises modulated DC.
1907. The heater of claim 1895, further comprising an AC power supply.
1908. The heater of claim 1895, further comprising a modulated DC power supply.
1909. The heater of claim 1895, wherein a thickness of the ferromagnetic conductor is at least about 2 times a skin depth of the applied electrical current.
1910. The heater of claim 1895, wherein the heater is configured to allow heat to transfer from the heater to a part of a subsurface formation to pyrolyze at least some hydrocarbons in the subsurface formation.
1911. The heater of claim 1895, wherein the heater is configured to be placed in an opening in a subsurface formation.
1912. The heater of claim 1895, wherein a resistance of the ferromagnetic material decreases above the selected temperature such that the heater provides the reduced amount of heat above the selected temperature.
1913. The heater of claim 1895, wherein the selected temperature is the Curie temperature of the ferromagnetic material.
1914. A method of heating a subsurface formation, comprising:
providing electrical current in a first direction to a ferromagnetic conductor to provide an electrically resistive heat output, wherein the ferromagnetic conductor comprises electrically resistive ferromagnetic material;
allowing electrical current to propagate in a second direction through an inner electrical conductor and an outer electrical conductor, wherein the ferromagnetic conductor at least partially surrounds the inner electrical conductor and is at least partially surrounded by the outer electrical conductor; and allowing heat to transfer from the ferromagnetic conductor to at least part of the subsurface formation such that the ferromagnetic conductor provides a reduced amount of heat above or near a selected temperature.
1915. The method of claim 1914, wherein the inner electrical conductor comprises an electrically resistive, non-ferromagnetic material.
1916. The method of claim 1914, wherein the outer electrical conductor comprises an electrically resistive, non-ferromagnetic material.
1917. The method of claim 1914, wherein the provided electrical current comprises AC.
1918. The method of claim 1914, wherein the provided electrical current comprises modulated DC.
1919. The method of claim 1914, further comprising providing the electrical current from an AC power supply.
1920. The method of claim 1914, further comprising providing the electrical current from a modulated DC power supply.
1921. The method of claim 1914, wherein the reduced amount of heat is provided without adjusting the amperage of the electrical current applied to the electrical conductor.
1922. The method of claim 1914, further comprising providing an initial electrically resistive heat output when the electrical conductor providing the heat output is at least about 50 °C below the selected temperature, and automatically providing the reduced amount of heat above or near the selected temperature.
1923. The method of claim 1914, further comprising placing the ferromagnetic conductor, the inner electrical conductor, and the outer electrical conductor in a wellbore in the subsurface formation.
1924. The method of claim 1914, wherein the ferromagnetic conductor is separated from the inner electrical conductor and the outer electrical conductor with an electrical insulator.
1925. The method of claim 1914, wherein heat output from the electrical conductor is substantially constant when a temperature of the electrical conductor is between about 100 °C
and 750 °C.
1926. A heater, comprising:
a first electrical conductor, wherein the first electrical conductor is configured to generate an electrically resistive heat output during application of electrical current to the first electrical conductor, and wherein the first electrical conductor comprises electrically resistive ferromagnetic material;
a second electrical conductor electrically coupled to the first electrical conductor, wherein the second electrical conductor comprises a non-ferromagnetic material with a lower electrical resistance than the first electrical conductor;
a support coupled to the first electrical conductor, wherein the support comprises a material with a relatively high creep strength at temperatures near a Curie temperature of the ferromagnetic material in the first electrical conductor; and wherein the heater is configured to provide a reduced amount of heat above or near a selected temperature.
1927. The heater of claim 1926, wherein the support is electrically coupled to the first electrical conductor.
1928. The heater of claim 1926, wherein the first electrical conductor, the second electrical conductor, and the support are metallurgically bonded together.
1929. The heater of claim 1926, wherein the first electrical conductor comprises 446 stainless steel.
1930. The heater of claim 1926, wherein the second electrical conductor comprises copper.
1931. The heater of claim 1926, wherein the support comprises 347H alloy.
1932. The heater of claim 1926, wherein the applied electrical current comprises AC.
1933. The heater of claim 1926, wherein the applied electrical current comprises modulated DC.
1934, The heater of claim 1926, wherein the selected temperature is the Curie temperature of the ferromagnetic material.
1935. The heater of claim 1926, wherein the heater comprises a turndown ratio greater than about 2.
1936. The heater of claim 1926, wherein the heater is configured to allow heat to transfer from the heater to a part of a subsurface formation to pyrolyze at least some hydrocarbons in the subsurface formation.
1937, The heater of claim 1926, wherein a resistance of the ferromagnetic material decreases above the selected temperature such that the heater provides the reduced amount of heat above the selected temperature.
1938. A method for treating a hydrocarbon containing formation, comprising:
providing heat from one or more heaters to at least a portion of the formation;
allowing the heat to transfer from one or more of the heaters to one or more zones of the formation; and controlling heating of the zones of the formation such that a heating rate of one or more zones is maintained below about 20°C/day for at least about 15 days.
1939, The method of claim 1938, further comprising controlling heating of the formation such that a heating rate of one or more zones is maintained below about 10°C/day for at least about 30 days.
1940. The method of claim 1938, further comprising controlling heating of the formation such that a heating rate of one or more zones is maintained below about 5°C/day for at least about 60 days.
1941. The method of claim 1938, further comprising assessing a permeability of the one or more zones in the formation and controlling the heating based on the assessed permeability.
1942. The method of claim 1941, wherein heating is controlled in zones with a permeability less than about 50 µdarcy.
1943. The method of claim 1941, wherein heating is controlled in zones with a permeability less than about 10 µdarcy.
1944. The method of claim 1938, further comprising assessing a clay content of the one or more zones in the formation and controlling the heating based on the assessed clay content.
1945. The method of claim 1944, wherein heating is controlled in zones with greater than about 5% smectite clay content by volume.
1946. The method of claim 1944, further comprising adding a clay stabilizer to zones with a smectite clay content greater than about 5% by volume.
1947. The method of claim 1938, wherein the zones are near one or more wellbores in the formation.
1948. The method of claim 1938, wherein heating is controlled within about 1 m of at least one of wellbore.
1949. The method of claim 1938, wherein heating is controlled within about 0.5 m of at least one of wellbore.
1950. The method of claim 1938, further comprising heating at least some hydrocarbons in the formation such that at least some of the hydrocarbons are pyrolyzed.
1951. The method of claim 1938, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1952. The method of claim 1938, further comprising controlling the provided heat to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1953. The method of claim 1938, further comprising heating at least a portion of the part of the formation to a minimum pyrolysis temperature of about 270 °C.
1954. A method for forming a heater wellbore in a hydrocarbon containing formation, comprising:
forming a wellbore in the formation;
providing an explosive system into the wellbore;
providing a controlled explosion using the explosive system in the wellbore such that at least some of the formation surrounding the wellbore has an increased permeability; and installing a heater in the wellbore.
1955. The method of claim 1954, further comprising removing exploded rubble from the wellbore, wherein the exploded rubble is formed by the controlled explosion.
1956. The method of claim 1954, wherein the controlled explosion comprises an elongated explosion along a portion of the length of the wellbore.
1957. The method of claim 1954, wherein the explosive system comprises an explosive cord system.
1958. The method of claim 1954, further comprising providing heat to the formation using one or more heaters placed in one or more wellbores in the formation.
1959. The method of claim 1954, further comprising providing heat to the formation and controlling heating of a zone of the formation near the wellbore such that a heating rate of the zone is maintained below about 20°C/day for at least about 15 days.
1960. The method of claim 1954, wherein the controlled explosion is provided at or near zones of the formation with a permeability less than about 10 µdarcy.
1961. The method of claim 1954, wherein the controlled explosion is provided at or near zones of the formation with a smectite clay content greater than about 5% by volume.
1962. The method of claim 1954, wherein the controlled explosion creates fractures out to a selected radius of from the wellbore, wherein the selected radius is greater than a coking distance from the wellbore during heating of the formation.
1963. The method of claim 1954, wherein the controlled explosion creates fractures out to a radius greater than a coking distance from the wellbore so that fluids are allowed to flow in the formation substantially coaxially with the wellbore in a region beyond the coking distance.
1964. The method of claim 1954, wherein the controlled explosion creates fractures out to a radius of about 2 m from the wellbore.
1965. The method of claim 1954, wherein the controlled explosion increases the permeability out to a radios of about 0.3 m from the wellbore.
1966. The method of claim 1954, further comprising heating at least some hydrocarbons in the formation such that at least some of the hydrocarbons are pyrolyzed.
1967. The method of claim 1954, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1968. The method of claim 1954, further comprising providing heat to the formation and controlling the provided heat to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1969. The method of claim 1954, further comprising heating at least a portion of the part of the formation to a minimum pyrolysis temperature of about 270 °C.
1970. A method for treating a hydrocarbon containing formation, comprising:
providing heat from one or more heaters to at least a portion of the formation, wherein at least one of the heaters is in at least one wellbore in the formation, wherein at least one of the wellbores has a liner placed between the heater in the wellbore and the formation, wherein the liner comprises openings that are sized such that fluids are allowed to pass through the liner but particles of a selected size are not allowed to pass through the liner;
allowing the heat to transfer from the one or more heaters to a part of the formation; and producing a mixture from the formation.
1971. The method of claim 1970, wherein the liner comprises carbon steel.
1972. The method of claim 1970, wherein the liner comprises a wire mesh.
1973. The method of claim 1970, wherein the liner comprises an expanded tubular.
1974. The method of claim 1970, wherein the liner is configured to inhibit formation material from contacting the heater.
1975. The method of claim 1970, wherein the liner has a diameter that is slightly smaller than a diameter of the wellbore.
1976. The method of claim 1970, wherein the liner is at least slightly deformable to allow particles to be trapped between the liner and a wall of the wellbore.
1977. The method of claim 1970, further comprising controlling heating of a zone of the formation near the wellbore such that a heating rate of the zone is maintained below about 20°C/day for at least about 15 days.
1978. The method of claim 1970, wherein the liner is located at or near zones of the formation with a permeability less than about 10 µdarcy.
1979. The method of claim 1970, wherein the liner is located at or near zones of the formation with a clay content greater than about 5% by volume.
1980. The method of claim 1970, further comprising heating at least some hydrocarbons in the formation such that at least some of the hydrocarbons are pyrolyzed.
1981. The method of claim 1970, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1982. The method of claim 1970, further comprising controlling the provided heat to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1983. The method of claim 1970, further comprising heating at least a portion of the part of the formation to a minimum pyrolysis temperature of about 270 °C.
1984. A method for treating a hydrocarbon containing formation, comprising:
providing heat from one or more heaters to at least a portion of the formation, wherein at least one of the heaters is in at least one wellbore in the formation, and wherein at least one of the wellbores has been sized, at least in part, such that an annulus between the wellbore and a heater in the wellbore has a width that inhibits particles of a selected size from freely moving in the annulus;
allowing the heat to transfer from the one or more heaters to a part of the formation; and producing a mixture from the formation.
1985. The method of claim 1984, wherein the annulus width is less than about 2.5 cm.
1986. The method of claim 1984, wherein the annulus width is less than about 1.5 cm.
1987. The method of claim 1984, further comprising controlling heating of a zone of the formation near the wellbore such that a heating rate of the zone is maintained below about 20°C/day for at least about 15 days.
1988. The method of claim 1984, wherein the annulus width is located at or near zones of the formation with a permeability less than about 10 µdarcy.
1989. The method of claim 1984, wherein the annulus width is located at or near zones of the formation with a clay content greater than about 5% by volume.
1990. The method of claim 1984, further comprising heating at least some hydrocarbons in the formation such that at least some of the hydrocarbons are pyrolyzed.
1991. The method of claim 1984, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1992. The method of claim 1984, further comprising controlling the provided heat to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1993. The method of claim 1984, further comprising heating at least a portion of the part of the formation to a minimum pyrolysis temperature of about 270 °C.
1994. A heating system configurable to heat a subsurface formation, comprising:
an electrical conductor configured to generate an electrically resistive heat output during application of electrical current to the electrical conductor;
an electrical insulator at least partially surrounding and in direct physical contact with the electrical conductor, wherein the electrical insulator comprises a nitride; and a sheath at least partially surrounding and in direct physical contact with the electrical insulator.
1995. The system of claim 1994, wherein the nitride comprises silicon nitride.
1996. The system of claim 1994, wherein the nitride comprises boron nitride.
1997. The system of claim 1994, wherein the electrical conductor comprises a copper-nickel alloy.
1998. The system of claim 1994, wherein the sheath comprises a corrosion-resistant material.
1999. The system of claim 1994, further comprising two additional electrical conductors, wherein the electrical conductor and the two additional electrical conductors are configurable in a 3-phase Wye configuration.
2000. The system of claim 1994, wherein the system is further configured to transfer heat such that the transferred heat can pyrolyze at least some hydrocarbons in a section of the formation.
2001. The system of claim 1994, wherein the electrical conductor comprises ferromagnetic material.
2002. The system of claim 1994, wherein the electrical conductor comprises ferromagnetic material, and wherein the system is configured to provide a reduced amount of heat above or near a selected temperature.
2003. An in situ method for heating a hydrocarbon containing formation, comprising:
applying an electrical current to an electrical conductor to provide heat to at least a portion of the formation, wherein the electrical conductor is located in an opening in the formation, wherein the electrical conductor is in direct physical contact with and at least partially surrounded by a nitride insulation layer, and wherein the nitride insulation layer is in direct physical contact with and at least partially surrounded by a sheath;
and allowing heat to transfer from the electrical conductor to a section of the formation.
2004. The method of claim 2003, wherein the nitride comprises silicon nitride.
2005. The method of claim 2003, wherein the nitride comprises boron nitride.
2006. The method of claim 2003, wherein the electrical conductor comprises a copper-nickel alloy.
2007. The method of claim 2003, wherein the sheath comprises a corrosion-resistant material.
2008. The method of claim 2003, wherein the electrical conductor comprises ferromagnetic material.
2009. The method of claim 2003, wherein the electrical conductor comprises ferromagnetic material, the method further comprising providing a reduced amount of heat above or near a selected temperature.
2010. The method of claim 2003, further comprising heating at least some hydrocarbons in the formation such that at least some of the hydrocarbons are pyrolyzed.
2012. The method of claim 2003, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
2013. The method of claim 2003, further comprising controlling the provided heat to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
2013. The method of claim 2003, further comprising heating at least a part of the formation to a minimum pyrolysis temperature of about 270 °C.
2014. A method for installing a temperature sensor in a conduit in a hydrocarbon containing formation, comprising:
providing a temperature sensor into a conduit in a wellbore in the formation;
providing a pressurized gas to the conduit to move the temperature sensor through the conduit using pressure from the pressurized gas; and locating the temperature sensor at a desired location in the conduit.
2015. The method of claim 2014, further comprising monitoring a temperature of a part of the formation using the temperature sensor.
2016. The method of claim 2014, wherein the temperature sensor comprises a fiber optic temperature sensor.
2017. The method of claim 2014, wherein the temperature sensor comprises a protective sleeve.
2018. The method of claim 2014, wherein the conduit is a center conductor of conductor-in-conduit heater.
2019. The method of claim 2014, wherein the conduit comprises holes at an end of the conduit.
2020. The method of claim 2014, wherein the conduit comprises an open end.
2021. The method of claim 2014, wherein the temperature sensor is configured to be removable from the conduit.
2022. The method of claim 2014, further comprising moving the temperature sensor a desired distance with the pressurized gas.
2023. The method of claim 2014, further comprising providing heat to the formation and heating at least some hydrocarbons in the formation such that at least some of the hydrocarbons are pyrolyzed.
2024. The method of claim 2014, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
2025. The method of claim 2014, further comprising providing heat to the formation and controlling the provided heat to inhibit, production of hydrocarbons from the formation having carbon numbers greater than about 25.
2026. The method of claim 2014, further comprising providing heat to at least a part of the formation to heat the portion to a minimum pyrolysis temperature of about 270 °C.
2027. A method for treating a hydrocarbon containing formation, comprising:
providing heat from one or more heaters to at least a portion of the formation;
allowing the heat to transfer from the one or more heaters to a part of the formation; and producing a mixture from the formation through a production conduit in a production wellbore, wherein the production conduit comprises one or more collection devices located in an overburden section of the production conduit, and wherein the collection devices are configured to collect fluids that condense in the overburden section.
2028. The method of claim 2027, wherein the collection devices comprise baffles.
2029. The method of claim 2027, further comprising collecting condensed fluids in the collection devices.
2030. The method of claim 2027, further comprising removing condensed fluids from the collection devices.
2031. The method of claim 2027, further comprising removing condensed fluids from the collection devices using a pump.
2032. The method of claim 2027, wherein the collection devices inhibit condensed fluids from refluxing into the formation.
2033. The method of claim 2027, wherein the overburden section comprises a depth greater than about 500 feet (about 150 m).
2034. The method of claim 2027, further comprising providing heat from a heater in the production wellbore to maintain at least some of the fluids in a vapor phase below the overburden section.
2035. The method of claim 2027, further comprising producing non-condensed fluids through the production conduit.
2036. The method of claim 2027, further comprising allowing water and high boiling point fluids to condense along the walls of the production conduit in the overburden section.
2037. A method for treating a hydrocarbon containing formation, comprising:
applying electrical current to one or more electrical conductors located in an opening in the formation to provide an electrically resistive heat output;
allowing the heat to transfer from the electrical conductors to a part of the formation containing hydrocarbons so that a viscosity of fluids in the part at or near the opening in the formation is reduced;
providing a gas at one or more locations in the opening to reduce the density of the fluids so that the fluids are lifted in the opening towards the surface of the formation by the formation pressure; and producing the fluids through the opening.
2038. The method of claim 2037, further comprising placing the one or more electrical conductors in the opening.
2039. The method of claim 2037, wherein the viscosity of fluids at or near the opening is reduced to less than about 50 centipoise.
2040. The method of claim 2037, further comprising producing at least some fluids from the opening by pumping the fluids from the opening.
2041. The method of claim 2037, wherein the gas comprises methane.
2042. The method of claim 2037, further comprising producing the fluids from the opening through a conduit located in the opening.
2043. The method of claim 2037, further comprising producing the fluids from the opening through a conduit located in the opening, and providing the gas through one or more valves located along the conduit.
2044. The method of claim 2037, further comprising limiting a temperature in the formation at or near the opening to less than about 250 °C.
2045. The method of claim 2037, further comprising applying AC to the one or more electrical conductors.
2046. The method of claim 2037, further comprising applying modulated DC to the one or more electrical conductors.
2047. The method of claim 2037, wherein at least one of the electrical conductors comprises an electrically resistive ferromagnetic material that provides heat when electrical current flows through the electrically resistive ferromagnetic material, and wherein the electrically resistive ferromagnetic material provides a reduced amount of heat above or near a selected temperature.
2048. The method of claim 2047, wherein the ferromagnetic material automatically provides the reduced amount of heat above or near the selected temperature.
2049. The method of claim 2047, further comprising providing an initial electrically resistive heat output when the electrical conductor providing the heat output is at least about 50 °C below the selected temperature, and automatically providing the reduced amount of heat above or near the selected temperature.
2050. The method of claim 2047, wherein the electrically resistive ferromagnetic material automatically provides a selected reduced amount of heat above or near a selected temperature.
2051. The method of claim 2047, wherein an electrical resistance of the ferromagnetic material decreases above the selected temperature to provide the reduced amount of heat.
2052. The method of claim 2047, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.
2053. The method of claim 2047, wherein the selected temperature is less than about 300 °C.
2054. The method of claim 2047, further comprising providing a reduced amount of heat above or near the selected temperature of less than about 200 watts per meter of length of an electrical conductor.
2055. The method of claim 2047, further comprising providing a heat output below the selected temperature of greater than about 300 watts per meter of length of an electrical conductor.
2056. The method of claim 2047, further comprising providing a heat output from at least one of the electrical conductors, wherein an electrical resistance of such electrical conductors above or near the selected temperature is about 80% or less of the electrical resistance of such electrical conductors at about 50 °C below the selected temperature.
2057. The method of claim 2047, further comprising controlling a skin depth in the ferromagnetic material by controlling a modulation of the applied electrical current.
2058. The method of claim 2037, wherein the hydrocarbon containing formation comprises a relatively permeable formation containing heavy hydrocarbons.
Applications Claiming Priority (5)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US46527903P | 2003-04-24 | 2003-04-24 | |
| US60/465,279 | 2003-04-24 | ||
| US51459303P | 2003-10-24 | 2003-10-24 | |
| US60/514,593 | 2003-10-24 | ||
| PCT/US2004/012784 WO2004097159A2 (en) | 2003-04-24 | 2004-04-23 | Thermal processes for subsurface formations |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CA2524689A1 true CA2524689A1 (en) | 2004-11-11 |
| CA2524689C CA2524689C (en) | 2012-05-22 |
Family
ID=33423552
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA2524689A Active CA2524689C (en) | 2003-04-24 | 2004-04-23 | Thermal processes for subsurface formations |
Country Status (6)
| Country | Link |
|---|---|
| US (6) | US7121342B2 (en) |
| AU (1) | AU2004235350B8 (en) |
| CA (1) | CA2524689C (en) |
| GB (6) | GB2430455B (en) |
| NZ (2) | NZ567052A (en) |
| WO (1) | WO2004097159A2 (en) |
Families Citing this family (264)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US20020038069A1 (en) | 2000-04-24 | 2002-03-28 | Wellington Scott Lee | In situ thermal processing of a coal formation to produce a mixture of olefins, oxygenated hydrocarbons, and aromatic hydrocarbons |
| US6994169B2 (en) | 2001-04-24 | 2006-02-07 | Shell Oil Company | In situ thermal processing of an oil shale formation with a selected property |
| US8764978B2 (en) | 2001-07-16 | 2014-07-01 | Foret Plasma Labs, Llc | System for treating a substance with wave energy from an electrical arc and a second source |
| US7622693B2 (en) | 2001-07-16 | 2009-11-24 | Foret Plasma Labs, Llc | Plasma whirl reactor apparatus and methods of use |
| AU2002363073A1 (en) | 2001-10-24 | 2003-05-06 | Shell Internationale Research Maatschappij B.V. | Method and system for in situ heating a hydrocarbon containing formation by a u-shaped opening |
| CA2503394C (en) | 2002-10-24 | 2011-06-14 | Shell Canada Limited | Temperature limited heaters for heating subsurface formations or wellbores |
| JP2006523294A (en) * | 2003-01-22 | 2006-10-12 | ヴァスト・パワー・システムズ・インコーポレーテッド | Reactor |
| US6977396B2 (en) * | 2003-02-19 | 2005-12-20 | Lumileds Lighting U.S., Llc | High-powered light emitting device with improved thermal properties |
| AU2004235350B8 (en) | 2003-04-24 | 2013-03-07 | Shell Internationale Research Maatschappij B.V. | Thermal processes for subsurface formations |
| US8296968B2 (en) * | 2003-06-13 | 2012-10-30 | Charles Hensley | Surface drying apparatus and method |
| US7331385B2 (en) * | 2003-06-24 | 2008-02-19 | Exxonmobil Upstream Research Company | Methods of treating a subterranean formation to convert organic matter into producible hydrocarbons |
| US7188532B2 (en) * | 2003-09-08 | 2007-03-13 | Jentek Sensors, Inc. | Self-monitoring metals, alloys and materials |
| WO2005045192A1 (en) * | 2003-11-03 | 2005-05-19 | Exxonmobil Upstream Research Company | Hydrocarbon recovery from impermeable oil shales |
| JP4794550B2 (en) * | 2004-04-23 | 2011-10-19 | シエル・インターナシヨナル・リサーチ・マートスハツペイ・ベー・ヴエー | Temperature limited heater used to heat underground formations |
| US7832256B2 (en) * | 2004-06-22 | 2010-11-16 | Bp Corporation North America Inc. | Method and apparatus for detecting the presence or absence of fluids in a pipeline |
| WO2006014293A2 (en) * | 2004-07-02 | 2006-02-09 | Aqualizer, Llc | Moisture condensation control system |
| US7685737B2 (en) | 2004-07-19 | 2010-03-30 | Earthrenew, Inc. | Process and system for drying and heat treating materials |
| US7024800B2 (en) | 2004-07-19 | 2006-04-11 | Earthrenew, Inc. | Process and system for drying and heat treating materials |
| FR2875260B1 (en) * | 2004-09-13 | 2006-10-27 | Inst Francais Du Petrole | SYSTEM FOR NEUTRALIZING LIQUID PLUG FORMATION IN AN UPPER COLUMN |
| DE102005000782A1 (en) * | 2005-01-05 | 2006-07-20 | Voith Paper Patent Gmbh | Drying cylinder for use in the production or finishing of fibrous webs, e.g. paper, comprises heating fluid channels between a supporting structure and a thin outer casing |
| US7891416B2 (en) * | 2005-01-11 | 2011-02-22 | Amp-Lift Group Llc | Apparatus for treating fluid streams cross-reference to related applications |
| CA2601359A1 (en) * | 2005-03-10 | 2006-09-21 | Shell Internationale Research Maatschappij B.V. | A heat transfer system for the combustion of a fuel and heating of a process fluid and a process that uses same |
| JP5000633B2 (en) * | 2005-03-10 | 2012-08-15 | シエル・インターナシヨネイル・リサーチ・マーチヤツピイ・ベー・ウイ | Start-up method for direct heating system for flameless combustion of fuel and direct heating of process fluid |
| KR101228392B1 (en) * | 2005-03-10 | 2013-02-01 | 쉘 인터내셔날 리써취 마트샤피지 비.브이. | A multi-tube heat transfer system for the combustion of a fuel and heating of a process fluid and the use thereof |
| NZ562249A (en) * | 2005-04-22 | 2010-11-26 | Shell Int Research | Double barrier system with fluid head monitored in inter-barrier and outer zones |
| US7942197B2 (en) * | 2005-04-22 | 2011-05-17 | Shell Oil Company | Methods and systems for producing fluid from an in situ conversion process |
| CN101316982B (en) * | 2005-10-24 | 2012-06-20 | 国际壳牌研究有限公司 | Cogeneration systems and processes for treating hydrocarbon containing formations |
| US7559367B2 (en) | 2005-10-24 | 2009-07-14 | Shell Oil Company | Temperature limited heater with a conduit substantially electrically isolated from the formation |
| US7809538B2 (en) | 2006-01-13 | 2010-10-05 | Halliburton Energy Services, Inc. | Real time monitoring and control of thermal recovery operations for heavy oil reservoirs |
| US7610692B2 (en) | 2006-01-18 | 2009-11-03 | Earthrenew, Inc. | Systems for prevention of HAP emissions and for efficient drying/dehydration processes |
| CN101421488B (en) * | 2006-02-16 | 2012-07-04 | 雪佛龙美国公司 | Kerogen extraction from subterranean oil shale resources |
| EP2010755A4 (en) | 2006-04-21 | 2016-02-24 | Shell Int Research | Time sequenced heating of multiple layers in a hydrocarbon containing formation |
| US7644993B2 (en) * | 2006-04-21 | 2010-01-12 | Exxonmobil Upstream Research Company | In situ co-development of oil shale with mineral recovery |
| US7662275B2 (en) * | 2006-05-19 | 2010-02-16 | Colorado School Of Mines | Methods of managing water in oil shale development |
| US7677673B2 (en) * | 2006-09-26 | 2010-03-16 | Hw Advanced Technologies, Inc. | Stimulation and recovery of heavy hydrocarbon fluids |
| US7770643B2 (en) | 2006-10-10 | 2010-08-10 | Halliburton Energy Services, Inc. | Hydrocarbon recovery using fluids |
| US7832482B2 (en) | 2006-10-10 | 2010-11-16 | Halliburton Energy Services, Inc. | Producing resources using steam injection |
| JO2982B1 (en) * | 2006-10-13 | 2016-03-15 | Exxonmobil Upstream Res Co | Optimized well spacing for in situ shale oil development |
| WO2008048454A2 (en) * | 2006-10-13 | 2008-04-24 | Exxonmobil Upstream Research Company | Combined development of oil shale by in situ heating with a deeper hydrocarbon resource |
| WO2008048448A2 (en) * | 2006-10-13 | 2008-04-24 | Exxonmobil Upstream Research Company | Heating an organic-rich rock formation in situ to produce products with improved properties |
| CA2858464A1 (en) * | 2006-10-13 | 2008-04-24 | Exxonmobil Upstream Research Company | Improved method of developing a subsurface freeze zone using formation fractures |
| AU2007313395B2 (en) | 2006-10-13 | 2013-11-07 | Exxonmobil Upstream Research Company | Enhanced shale oil production by in situ heating using hydraulically fractured producing wells |
| WO2008051834A2 (en) | 2006-10-20 | 2008-05-02 | Shell Oil Company | Heating hydrocarbon containing formations in a spiral startup staged sequence |
| DE102006052634A1 (en) * | 2006-11-08 | 2008-05-15 | Robert Bosch Gmbh | Fuel heater |
| US20100212893A1 (en) * | 2006-11-14 | 2010-08-26 | Behdad Moini Araghi | Catalytic down-hole upgrading of heavy oil and oil sand bitumens |
| US7464755B2 (en) | 2006-12-12 | 2008-12-16 | Schlumberger Technology Corporation | Methods and systems for sampling heavy oil reservoirs |
| JP5060791B2 (en) * | 2007-01-26 | 2012-10-31 | 独立行政法人森林総合研究所 | Method for drying wood, method for penetrating chemicals into wood and drying apparatus |
| US7862706B2 (en) * | 2007-02-09 | 2011-01-04 | Red Leaf Resources, Inc. | Methods of recovering hydrocarbons from water-containing hydrocarbonaceous material using a constructed infrastructure and associated systems |
| JO2601B1 (en) * | 2007-02-09 | 2011-11-01 | ريد لييف ريسورسيز ، انك. | Methods Of Recovering Hydrocarbons From Hydrocarbonaceous Material Using A Constructed Infrastructure And Associated Systems |
| WO2008111037A2 (en) * | 2007-03-12 | 2008-09-18 | Geomage 2003 Ltd | A method for identifying and analyzing faults/fractures using reflected and diffracted waves |
| US8087460B2 (en) | 2007-03-22 | 2012-01-03 | Exxonmobil Upstream Research Company | Granular electrical connections for in situ formation heating |
| CN101636555A (en) | 2007-03-22 | 2010-01-27 | 埃克森美孚上游研究公司 | Resistive heater for in situ formation heating |
| CA2905364C (en) * | 2007-03-26 | 2017-05-02 | J. I. Livingstone Enterprises Ltd. | Drilling, completing and stimulating a hydrocarbon production well |
| AU2008242808B2 (en) | 2007-04-20 | 2011-09-22 | Shell Internationale Research Maatschappij B.V. | Varying properties of in situ heat treatment of a tar sands formation based on assessed viscosities |
| CN101680285B (en) * | 2007-05-15 | 2013-05-15 | 埃克森美孚上游研究公司 | Downhole burners for in situ conversion of organic-rich rock formations |
| US8151877B2 (en) * | 2007-05-15 | 2012-04-10 | Exxonmobil Upstream Research Company | Downhole burner wells for in situ conversion of organic-rich rock formations |
| US7579833B2 (en) * | 2007-05-18 | 2009-08-25 | Baker Hughes Incorporated | Water mapping using surface NMR |
| BRPI0810590A2 (en) | 2007-05-25 | 2014-10-21 | Exxonmobil Upstream Res Co | IN SITU METHOD OF PRODUCING HYDROCARBON FLUIDS FROM A ROCK FORMATION RICH IN ORGANIC MATTER |
| US8146664B2 (en) * | 2007-05-25 | 2012-04-03 | Exxonmobil Upstream Research Company | Utilization of low BTU gas generated during in situ heating of organic-rich rock |
| US7731421B2 (en) * | 2007-06-25 | 2010-06-08 | Schlumberger Technology Corporation | Fluid level indication system and technique |
| US7909094B2 (en) * | 2007-07-06 | 2011-03-22 | Halliburton Energy Services, Inc. | Oscillating fluid flow in a wellbore |
| US20110122727A1 (en) * | 2007-07-06 | 2011-05-26 | Gleitman Daniel D | Detecting acoustic signals from a well system |
| AR067576A1 (en) * | 2007-07-20 | 2009-10-14 | Shell Int Research | A NON-FLAMMABLE COMBUSTION HEATER AND METHOD FOR PROVIDING HEAT TO A DUCT |
| AR067577A1 (en) * | 2007-07-20 | 2009-10-14 | Shell Int Research | A NON-FLAMMABLE COMBUSTION HEATER AND METHOD FOR PROVIDING HEAT TO A PROCESS CONDUCT |
| RU2010106143A (en) * | 2007-07-20 | 2011-08-27 | Шелл Интернэшнл Рисерч Маатсхаппий Б.В. (NL) | FLAMELESS GASOLINE HEATER |
| US8276666B2 (en) * | 2007-08-08 | 2012-10-02 | Halliburton Energy Services Inc. | Sealant compositions and methods of use |
| US20090038801A1 (en) * | 2007-08-08 | 2009-02-12 | Ravi Krishna M | Sealant Compositions and Methods of Use |
| US7630865B2 (en) * | 2007-09-11 | 2009-12-08 | Geomage (2003) Ltd | Complex analysis of kinematics for non-hyperbolic moveout corrections |
| US7705513B1 (en) * | 2007-09-24 | 2010-04-27 | United States Of America As Represented By The United States Department Of Energy | Thermal to electricity conversion using thermal magnetic properties |
| US8555969B2 (en) | 2007-10-12 | 2013-10-15 | Schlumberger Technology Corporation | Methods and apparatus to change the mobility of formation fluids using thermal and non-thermal stimulation |
| US9051820B2 (en) | 2007-10-16 | 2015-06-09 | Foret Plasma Labs, Llc | System, method and apparatus for creating an electrical glow discharge |
| US8278810B2 (en) * | 2007-10-16 | 2012-10-02 | Foret Plasma Labs, Llc | Solid oxide high temperature electrolysis glow discharge cell |
| US9185787B2 (en) | 2007-10-16 | 2015-11-10 | Foret Plasma Labs, Llc | High temperature electrolysis glow discharge device |
| US9761413B2 (en) | 2007-10-16 | 2017-09-12 | Foret Plasma Labs, Llc | High temperature electrolysis glow discharge device |
| US8810122B2 (en) | 2007-10-16 | 2014-08-19 | Foret Plasma Labs, Llc | Plasma arc torch having multiple operating modes |
| US9516736B2 (en) | 2007-10-16 | 2016-12-06 | Foret Plasma Labs, Llc | System, method and apparatus for recovering mining fluids from mining byproducts |
| US8074439B2 (en) | 2008-02-12 | 2011-12-13 | Foret Plasma Labs, Llc | System, method and apparatus for lean combustion with plasma from an electrical arc |
| US9560731B2 (en) | 2007-10-16 | 2017-01-31 | Foret Plasma Labs, Llc | System, method and apparatus for an inductively coupled plasma Arc Whirl filter press |
| US9445488B2 (en) | 2007-10-16 | 2016-09-13 | Foret Plasma Labs, Llc | Plasma whirl reactor apparatus and methods of use |
| US9230777B2 (en) | 2007-10-16 | 2016-01-05 | Foret Plasma Labs, Llc | Water/wastewater recycle and reuse with plasma, activated carbon and energy system |
| US11806686B2 (en) | 2007-10-16 | 2023-11-07 | Foret Plasma Labs, Llc | System, method and apparatus for creating an electrical glow discharge |
| US10267106B2 (en) | 2007-10-16 | 2019-04-23 | Foret Plasma Labs, Llc | System, method and apparatus for treating mining byproducts |
| WO2009052042A1 (en) | 2007-10-19 | 2009-04-23 | Shell Oil Company | Cryogenic treatment of gas |
| US7905288B2 (en) * | 2007-11-27 | 2011-03-15 | Los Alamos National Security, Llc | Olefin metathesis for kerogen upgrading |
| US8082995B2 (en) * | 2007-12-10 | 2011-12-27 | Exxonmobil Upstream Research Company | Optimization of untreated oil shale geometry to control subsidence |
| WO2009079588A1 (en) * | 2007-12-18 | 2009-06-25 | Technology International, Inc. | Method for enhancing low frequency output of impulsive type seismic energy sources for use while drilling |
| US8201625B2 (en) * | 2007-12-26 | 2012-06-19 | Schlumberger Technology Corporation | Borehole imaging and orientation of downhole tools |
| US8003844B2 (en) * | 2008-02-08 | 2011-08-23 | Red Leaf Resources, Inc. | Methods of transporting heavy hydrocarbons |
| US8904749B2 (en) | 2008-02-12 | 2014-12-09 | Foret Plasma Labs, Llc | Inductively coupled plasma arc device |
| US10244614B2 (en) | 2008-02-12 | 2019-03-26 | Foret Plasma Labs, Llc | System, method and apparatus for plasma arc welding ceramics and sapphire |
| AU2009223647B2 (en) * | 2008-03-12 | 2011-10-27 | Shell Internationale Research Maatschappij B.V. | Monitoring system for well casing |
| US8209126B2 (en) * | 2008-04-01 | 2012-06-26 | Geo{umlaut over (m)}age (2003) Ltd. | Wavefront-defined Radon transform |
| EA019751B1 (en) | 2008-04-18 | 2014-06-30 | Шелл Интернэшнл Рисерч Маатсхаппий Б.В. | Method and system for treating a subsurface hydrocarbon containing formation |
| EP2279539A1 (en) * | 2008-05-15 | 2011-02-02 | Johnson Controls Saft Advanced Power Solutions LLC | Battery system |
| CN102037211B (en) * | 2008-05-23 | 2014-12-17 | 埃克森美孚上游研究公司 | Field management for substantially constant composition gas generation |
| US9267330B2 (en) * | 2008-08-20 | 2016-02-23 | Foro Energy, Inc. | Long distance high power optical laser fiber break detection and continuity monitoring systems and methods |
| CA2734672C (en) * | 2008-08-27 | 2017-01-03 | Shell Internationale Research Maatschappij B.V. | Monitoring system for well casing |
| US8261832B2 (en) | 2008-10-13 | 2012-09-11 | Shell Oil Company | Heating subsurface formations with fluids |
| PE20120701A1 (en) * | 2009-02-12 | 2012-07-04 | Red Leaf Resources Inc | BARRIER AND VAPOR COLLECTION SYSTEM FOR ENCAPSULATED CONTROL INFRASTRUCTURES |
| US8349171B2 (en) | 2009-02-12 | 2013-01-08 | Red Leaf Resources, Inc. | Methods of recovering hydrocarbons from hydrocarbonaceous material using a constructed infrastructure and associated systems maintained under positive pressure |
| US8323481B2 (en) | 2009-02-12 | 2012-12-04 | Red Leaf Resources, Inc. | Carbon management and sequestration from encapsulated control infrastructures |
| US8490703B2 (en) * | 2009-02-12 | 2013-07-23 | Red Leaf Resources, Inc | Corrugated heating conduit and method of using in thermal expansion and subsidence mitigation |
| US8365478B2 (en) | 2009-02-12 | 2013-02-05 | Red Leaf Resources, Inc. | Intermediate vapor collection within encapsulated control infrastructures |
| CA2753441A1 (en) | 2009-02-12 | 2010-08-19 | Red Leaf Resources, Inc. | Articulated conduit linkage system |
| BRPI1008449A2 (en) * | 2009-02-12 | 2019-09-24 | Red Leaf Resources Inc | convection heating systems for recovering hydrocarbons from permeability control infrastructure |
| US8366917B2 (en) * | 2009-02-12 | 2013-02-05 | Red Leaf Resources, Inc | Methods of recovering minerals from hydrocarbonaceous material using a constructed infrastructure and associated systems |
| BRPI1008388A2 (en) * | 2009-02-23 | 2017-06-27 | Exxonmobil Upstream Res Co | method and system for recovering hydrocarbons from a subsurface formation in a development area, and method for treating water in a water treatment facility |
| US8448707B2 (en) | 2009-04-10 | 2013-05-28 | Shell Oil Company | Non-conducting heater casings |
| US20100312480A1 (en) * | 2009-04-24 | 2010-12-09 | Hansteen Fredrik | Method for monitoring fluid flow in a multi-layered system |
| WO2010129174A1 (en) * | 2009-05-05 | 2010-11-11 | Exxonmobil Upstream Research Company | Converting organic matter from a subterranean formation into producible hydrocarbons by controlling production operations based on availability of one or more production resources |
| US8025445B2 (en) * | 2009-05-29 | 2011-09-27 | Baker Hughes Incorporated | Method of deployment for real time casing imaging |
| KR101034722B1 (en) * | 2009-07-07 | 2011-05-17 | 경희대학교 산학협력단 | Measurement method for a granular compaction pile using crosshole seismic testing |
| WO2011017413A2 (en) * | 2009-08-05 | 2011-02-10 | Shell Oil Company | Use of fiber optics to monitor cement quality |
| WO2011017416A2 (en) | 2009-08-05 | 2011-02-10 | 5Shell Oil Company | Systems and methods for monitoring a well |
| DE102009037375B3 (en) * | 2009-08-12 | 2011-03-03 | Beru Ag | glow plug |
| US20120152011A1 (en) * | 2009-09-03 | 2012-06-21 | Mario Zamora | Scale-Up Device For Testing Bit Balling Characteristics |
| US8356935B2 (en) | 2009-10-09 | 2013-01-22 | Shell Oil Company | Methods for assessing a temperature in a subsurface formation |
| US9466896B2 (en) | 2009-10-09 | 2016-10-11 | Shell Oil Company | Parallelogram coupling joint for coupling insulated conductors |
| US8816203B2 (en) | 2009-10-09 | 2014-08-26 | Shell Oil Company | Compacted coupling joint for coupling insulated conductors |
| AP3601A (en) | 2009-12-03 | 2016-02-24 | Red Leaf Resources Inc | Methods and systems for removing fines from hydrocarbon-containing fluids |
| JP4988811B2 (en) * | 2009-12-15 | 2012-08-01 | インターナショナル・ビジネス・マシーンズ・コーポレーション | Modeling system processing system, method and program |
| WO2011084640A2 (en) | 2009-12-16 | 2011-07-14 | Red Leaf Resources, Inc. | Method for the removal and condensation of vapors |
| US8863839B2 (en) | 2009-12-17 | 2014-10-21 | Exxonmobil Upstream Research Company | Enhanced convection for in situ pyrolysis of organic-rich rock formations |
| CN102834585B (en) * | 2010-04-09 | 2015-06-17 | 国际壳牌研究有限公司 | Low temperature inductive heating of subsurface formations |
| US8833453B2 (en) | 2010-04-09 | 2014-09-16 | Shell Oil Company | Electrodes for electrical current flow heating of subsurface formations with tapered copper thickness |
| US9033042B2 (en) | 2010-04-09 | 2015-05-19 | Shell Oil Company | Forming bitumen barriers in subsurface hydrocarbon formations |
| US8939207B2 (en) | 2010-04-09 | 2015-01-27 | Shell Oil Company | Insulated conductor heaters with semiconductor layers |
| US8967259B2 (en) | 2010-04-09 | 2015-03-03 | Shell Oil Company | Helical winding of insulated conductor heaters for installation |
| US8739874B2 (en) | 2010-04-09 | 2014-06-03 | Shell Oil Company | Methods for heating with slots in hydrocarbon formations |
| WO2011127257A1 (en) * | 2010-04-09 | 2011-10-13 | Shell Oil Company | Insulating blocks and methods for installation in insulated conductor heaters |
| US8631866B2 (en) | 2010-04-09 | 2014-01-21 | Shell Oil Company | Leak detection in circulated fluid systems for heating subsurface formations |
| US8430174B2 (en) | 2010-09-10 | 2013-04-30 | Halliburton Energy Services, Inc. | Anhydrous boron-based timed delay plugs |
| US8408287B2 (en) * | 2010-06-03 | 2013-04-02 | Electro-Petroleum, Inc. | Electrical jumper for a producing oil well |
| US9933541B2 (en) * | 2010-06-22 | 2018-04-03 | Schlumberger Technology Corporation | Determining resistivity anisotropy and formation structure for vertical wellbore sections |
| BR112013001022A2 (en) | 2010-08-30 | 2016-05-24 | Exxonmobil Upstream Res Compony | olefin reduction for in situ pyrolysis oil generation |
| CA2806173C (en) | 2010-08-30 | 2017-01-31 | Exxonmobil Upstream Research Company | Wellbore mechanical integrity for in situ pyrolysis |
| US8437998B2 (en) * | 2010-09-27 | 2013-05-07 | Exxonmobil Upstream Research Company | Hybrid method for full waveform inversion using simultaneous and sequential source method |
| US8764406B2 (en) * | 2010-10-04 | 2014-07-01 | William K. Filippi | Fluid level control mechanism |
| US8943686B2 (en) | 2010-10-08 | 2015-02-03 | Shell Oil Company | Compaction of electrical insulation for joining insulated conductors |
| US8857051B2 (en) * | 2010-10-08 | 2014-10-14 | Shell Oil Company | System and method for coupling lead-in conductor to insulated conductor |
| US8586867B2 (en) | 2010-10-08 | 2013-11-19 | Shell Oil Company | End termination for three-phase insulated conductors |
| CA2818692C (en) | 2010-11-22 | 2019-02-19 | Advanced Combustion Energy Systems, Inc. | Combustion thermal generator and systems and methods for enhanced oil recovery |
| US8833443B2 (en) | 2010-11-22 | 2014-09-16 | Halliburton Energy Services, Inc. | Retrievable swellable packer |
| KR101772661B1 (en) | 2010-11-29 | 2017-09-13 | 삼성디스플레이 주식회사 | Organic light emitting diode display |
| US8902078B2 (en) | 2010-12-08 | 2014-12-02 | Halliburton Energy Services, Inc. | Systems and methods for well monitoring |
| US8776518B1 (en) | 2010-12-11 | 2014-07-15 | Underground Recovery, LLC | Method for the elimination of the atmospheric release of carbon dioxide and capture of nitrogen from the production of electricity by in situ combustion of fossil fuels |
| US9033033B2 (en) | 2010-12-21 | 2015-05-19 | Chevron U.S.A. Inc. | Electrokinetic enhanced hydrocarbon recovery from oil shale |
| US8839860B2 (en) | 2010-12-22 | 2014-09-23 | Chevron U.S.A. Inc. | In-situ Kerogen conversion and product isolation |
| CN103380266A (en) * | 2011-02-18 | 2013-10-30 | 领潮能源有限公司 | Igniting an underground coal seam in an underground coal gasification process, ucg |
| US20120215447A1 (en) * | 2011-02-22 | 2012-08-23 | Chevron U.S.A. Inc. | Method for determining paleo-pore pressure |
| US9016370B2 (en) | 2011-04-08 | 2015-04-28 | Shell Oil Company | Partial solution mining of hydrocarbon containing layers prior to in situ heat treatment |
| AU2012240160B2 (en) | 2011-04-08 | 2015-02-19 | Shell Internationale Research Maatschappij B.V. | Systems for joining insulated conductors |
| GB201207054D0 (en) * | 2011-09-06 | 2012-06-06 | British American Tobacco Co | Heating smokeable material |
| KR102353233B1 (en) | 2011-09-06 | 2022-01-18 | 니코벤처스 트레이딩 리미티드 | Heating smokable material |
| EP2753200B1 (en) | 2011-09-06 | 2017-12-27 | British American Tobacco (Investments) Limited | Heating smokeable material |
| JP5808490B2 (en) | 2011-09-06 | 2015-11-10 | ブリティッシュ アメリカン タバコ （インヴェストメンツ） リミテッドＢｒｉｔｉｓｈ Ａｍｅｒｉｃａｎｔｏｂａｃｃｏ （Ｉｎｖｅｓｔｍｅｎｔｓ） Ｌｉｍｉｔｅｄ | Smoking material heating |
| EP2753201B1 (en) | 2011-09-06 | 2016-02-24 | British American Tobacco (Investments) Limited | Heating smokable material |
| JO3141B1 (en) | 2011-10-07 | 2017-09-20 | Shell Int Research | Integral splice for insulated conductors |
| CN103958824B (en) | 2011-10-07 | 2016-10-26 | 国际壳牌研究有限公司 | Regulate for heating the thermal expansion of the circulation of fluid system of subsurface formations |
| US9080917B2 (en) | 2011-10-07 | 2015-07-14 | Shell Oil Company | System and methods for using dielectric properties of an insulated conductor in a subsurface formation to assess properties of the insulated conductor |
| JO3139B1 (en) | 2011-10-07 | 2017-09-20 | Shell Int Research | Forming insulated conductors using a final reduction step after heat treating |
| WO2013066772A1 (en) | 2011-11-04 | 2013-05-10 | Exxonmobil Upstream Research Company | Multiple electrical connections to optimize heating for in situ pyrolysis |
| KR101248531B1 (en) * | 2011-12-05 | 2013-04-03 | 한국지질자원연구원 | Apparatus and method for measuring porosity and permeability of dioxide carbon underground storage medium |
| US8701788B2 (en) | 2011-12-22 | 2014-04-22 | Chevron U.S.A. Inc. | Preconditioning a subsurface shale formation by removing extractible organics |
| US9181467B2 (en) | 2011-12-22 | 2015-11-10 | Uchicago Argonne, Llc | Preparation and use of nano-catalysts for in-situ reaction with kerogen |
| US8851177B2 (en) | 2011-12-22 | 2014-10-07 | Chevron U.S.A. Inc. | In-situ kerogen conversion and oxidant regeneration |
| CA2862463A1 (en) | 2012-01-23 | 2013-08-01 | Genie Ip B.V. | Heater pattern for in situ thermal processing of a subsurface hydrocarbon containing formation |
| US9605524B2 (en) | 2012-01-23 | 2017-03-28 | Genie Ip B.V. | Heater pattern for in situ thermal processing of a subsurface hydrocarbon containing formation |
| CA2811666C (en) | 2012-04-05 | 2021-06-29 | Shell Internationale Research Maatschappij B.V. | Compaction of electrical insulation for joining insulated conductors |
| GB201207039D0 (en) | 2012-04-23 | 2012-06-06 | British American Tobacco Co | Heating smokeable material |
| WO2013165711A1 (en) | 2012-05-04 | 2013-11-07 | Exxonmobil Upstream Research Company | Systems and methods of detecting an intersection between a wellbore and a subterranean structure that includes a marker material |
| US8992771B2 (en) | 2012-05-25 | 2015-03-31 | Chevron U.S.A. Inc. | Isolating lubricating oils from subsurface shale formations |
| GB2503903B (en) * | 2012-07-11 | 2015-08-26 | Schlumberger Holdings | Fracture monitoring and characterisation |
| US20140027121A1 (en) * | 2012-07-26 | 2014-01-30 | WestFire Energy Ltd. | Method for hydraulically fracturing a subterranean reservoir |
| US10081759B2 (en) | 2012-10-09 | 2018-09-25 | Eric John Wernimont | Method, apparatus, and composition for increased recovery of hydrocarbons by paraffin and asphaltene control from reaction of fuels and selective oxidizers in the subterranean environment |
| US8807822B2 (en) * | 2012-10-11 | 2014-08-19 | Halliburton Energy Services, Inc. | Method and apparatus for mixing fluid flow in a wellbore using a static mixer |
| US11199301B2 (en) | 2012-11-17 | 2021-12-14 | Fred Metsch Pereira | Luminous fluid sculptures |
| EP2920506A4 (en) | 2012-11-17 | 2016-10-26 | Fred Pereira | Luminuous fluid sculptures |
| WO2014093560A1 (en) | 2012-12-11 | 2014-06-19 | Foret Plasma Labs, Llc | High temperature countercurrent vortex reactor system, method and apparatus |
| US9699879B2 (en) | 2013-03-12 | 2017-07-04 | Foret Plasma Labs, Llc | Apparatus and method for sintering proppants |
| US9373492B2 (en) * | 2013-03-14 | 2016-06-21 | The University Of North Carolina At Chapel Hill | Microscale mass spectrometry systems, devices and related methods |
| US10215399B2 (en) | 2013-03-14 | 2019-02-26 | The Babcock & Wilcox Company | Small supercritical once-thru steam generator |
| US10316644B2 (en) | 2013-04-04 | 2019-06-11 | Shell Oil Company | Temperature assessment using dielectric properties of an insulated conductor heater with selected electrical insulation |
| US9382765B2 (en) | 2013-07-15 | 2016-07-05 | Harris Corporation | Apparatus for recovering hydrocarbon resources including ferrofluid source and related methods |
| GB201414850D0 (en) * | 2013-08-21 | 2014-10-01 | Genie Ip Bv | Method and system for heating a bed of rocks containing sulfur-rich type iis kerogen |
| WO2015060919A1 (en) | 2013-10-22 | 2015-04-30 | Exxonmobil Upstream Research Company | Systems and methods for regulating an in situ pyrolysis process |
| AU2014343927C1 (en) | 2013-10-29 | 2017-09-21 | Nicoventures Trading Limited | Apparatus for heating smokable material |
| US9394772B2 (en) | 2013-11-07 | 2016-07-19 | Exxonmobil Upstream Research Company | Systems and methods for in situ resistive heating of organic matter in a subterranean formation |
| US20190249532A1 (en) * | 2013-12-12 | 2019-08-15 | Rustem Latipovich ZLAVDINOV | System for locking interior door latches |
| US10273790B2 (en) | 2014-01-14 | 2019-04-30 | Precision Combustion, Inc. | System and method of producing oil |
| EP3099889B1 (en) * | 2014-01-28 | 2020-07-01 | C6 Technologies AS | Downhole tractor with redundant motor drives with independent circuit breakers |
| EP3137731A4 (en) | 2014-01-31 | 2018-02-28 | Harry Bailey Curlett | Method and system for subsurface resource production |
| CA3176275A1 (en) | 2014-02-18 | 2015-08-18 | Athabasca Oil Corporation | Cable-based well heater |
| AU2015241248B2 (en) | 2014-04-04 | 2017-03-16 | Shell Internationale Research Maatschappij B.V. | Traveling unit and work vehicle |
| US9451792B1 (en) * | 2014-09-05 | 2016-09-27 | Atmos Nation, LLC | Systems and methods for vaporizing assembly |
| WO2016061422A1 (en) * | 2014-10-17 | 2016-04-21 | Geophysical Technology, Inc. | Deployment netting for geophysical sensor or geophysical sensor recording node |
| US9644466B2 (en) | 2014-11-21 | 2017-05-09 | Exxonmobil Upstream Research Company | Method of recovering hydrocarbons within a subsurface formation using electric current |
| US10400563B2 (en) | 2014-11-25 | 2019-09-03 | Salamander Solutions, LLC | Pyrolysis to pressurise oil formations |
| US9765606B2 (en) | 2015-01-20 | 2017-09-19 | Baker Hughes | Subterranean heating with dual-walled coiled tubing |
| WO2016172714A1 (en) * | 2015-04-23 | 2016-10-27 | E-Flux, Llc | Establishment of contaminant degradation rates in soils using temperature gradients, associated methods, systems and devices |
| US10746718B2 (en) | 2015-04-23 | 2020-08-18 | E-Flux, Llc | Establishment of contaminant degradation rates in soils using temperature gradients |
| EP3298379A1 (en) * | 2015-05-20 | 2018-03-28 | Saudi Arabian Oil Company | Sampling techniques to detect hydrocarbon seepage |
| GB201511349D0 (en) | 2015-06-29 | 2015-08-12 | Nicoventures Holdings Ltd | Electronic aerosol provision systems |
| US20170055584A1 (en) | 2015-08-31 | 2017-03-02 | British American Tobacco (Investments) Limited | Article for use with apparatus for heating smokable material |
| US11924930B2 (en) | 2015-08-31 | 2024-03-05 | Nicoventures Trading Limited | Article for use with apparatus for heating smokable material |
| RU2610945C1 (en) * | 2015-12-10 | 2017-02-17 | Ильдар Зафирович Денисламов | Method of determination of deposit volume in well flow column |
| WO2017151640A1 (en) * | 2016-02-29 | 2017-09-08 | XDI Holdings, LLC | Continuous chamber capillary control system, method, and apparatus |
| US10641481B2 (en) * | 2016-05-03 | 2020-05-05 | Energy Analyst Llc | Systems and methods for generating superheated steam with variable flue gas for enhanced oil recovery |
| NO343262B1 (en) * | 2016-07-22 | 2019-01-14 | Norges Miljoe Og Biovitenskapelige Univ Nmbu | Solar thermal collecting and storage |
| GB201612945D0 (en) | 2016-07-26 | 2016-09-07 | British American Tobacco Investments Ltd | Method of generating aerosol |
| US20180045032A1 (en) * | 2016-08-12 | 2018-02-15 | Well Innovation As | Downhole monitoring device arranged in-line with a sucker rod string |
| US11090703B2 (en) | 2016-08-19 | 2021-08-17 | Corigin International Institute | Soil restoration method and structure |
| US11099584B2 (en) * | 2017-03-27 | 2021-08-24 | Saudi Arabian Oil Company | Method and apparatus for stabilizing gas/liquid flow in a vertical conduit |
| CA2972203C (en) | 2017-06-29 | 2018-07-17 | Exxonmobil Upstream Research Company | Chasing solvent for enhanced recovery processes |
| CA2974712C (en) | 2017-07-27 | 2018-09-25 | Imperial Oil Resources Limited | Enhanced methods for recovering viscous hydrocarbons from a subterranean formation as a follow-up to thermal recovery processes |
| CA2978157C (en) | 2017-08-31 | 2018-10-16 | Exxonmobil Upstream Research Company | Thermal recovery methods for recovering viscous hydrocarbons from a subterranean formation |
| CA2983541C (en) | 2017-10-24 | 2019-01-22 | Exxonmobil Upstream Research Company | Systems and methods for dynamic liquid level monitoring and control |
| CN107880862B (en) * | 2017-11-07 | 2018-08-10 | 西南石油大学 | A kind of sealing agent and preparation method thereof improving bearing capacity |
| US10137486B1 (en) * | 2018-02-27 | 2018-11-27 | Chevron U.S.A. Inc. | Systems and methods for thermal treatment of contaminated material |
| DE102018111816B4 (en) * | 2018-05-16 | 2021-01-21 | Anton Paar Provetec Gmbh | Preparation of a distillation measurement |
| US20190368310A1 (en) * | 2018-05-31 | 2019-12-05 | Baker Hughes, A Ge Company, Llc | Autonomous valve, system, and method |
| CN109322660B (en) * | 2018-08-13 | 2021-11-12 | 中国石油天然气集团有限公司 | Signal excitation device of horizontal main ground stress direction measurement while drilling system |
| CN109237513B (en) * | 2018-08-29 | 2024-01-26 | 西安石油大学 | Multistage solid fuel igniter for deep well |
| CN108979606B (en) * | 2018-09-30 | 2023-09-12 | 北京科技大学 | Shale gas yield increasing device |
| US11053775B2 (en) * | 2018-11-16 | 2021-07-06 | Leonid Kovalev | Downhole induction heater |
| CN109736765B (en) * | 2019-01-15 | 2021-06-25 | 辽宁大学 | Method for preventing and treating composite power disaster by integrating liquid injection and extraction in coal seam hydraulic slotting mining |
| CN110029984B (en) * | 2019-04-08 | 2021-11-23 | 中国石油集团渤海钻探工程有限公司 | Method for calculating high-pressure physical properties of crude oil based on formation parameters and degassed oil analysis data |
| US11434754B2 (en) | 2019-05-28 | 2022-09-06 | Erdos Miller, Inc. | Automated telemetry for switching transmission modes of a downhole device |
| US10711530B1 (en) * | 2019-05-28 | 2020-07-14 | Basin Drilling Tools LP | Contact module for communicating with a downhole device |
| US11153206B2 (en) | 2019-05-28 | 2021-10-19 | Black Diamond Oilfield Rentals, LLC | Contact module for communicating with a downhole device |
| CN110127619A (en) * | 2019-05-31 | 2019-08-16 | 温州市康之本制氧科技有限公司 | The efficient oxygen generation system of matrix form integration PSA |
| CN110424964B (en) * | 2019-08-21 | 2021-05-07 | 中国矿业大学(北京) | Coal rock interface identification method |
| CN110939424B (en) * | 2019-11-27 | 2022-04-12 | 西安物华巨能爆破器材有限责任公司 | Well-free underground coal gasification ignition method |
| CN110965964B (en) * | 2019-12-16 | 2021-10-12 | 临沂矿业集团菏泽煤电有限公司 | Gas extraction method for ultra-thick coal seam |
| CN111022021A (en) * | 2020-01-02 | 2020-04-17 | 吉林大学 | Oil shale in-situ heating method for coping with thermal expansion characteristics of oil shale formation |
| CN111119830B (en) * | 2020-01-02 | 2021-09-21 | 山东科技大学 | Hot dry rock thermal reservoir transformation method for preventing induced earthquake |
| US11163091B2 (en) * | 2020-01-23 | 2021-11-02 | Saudi Arabian Oil Company | In-situ hydrocarbon detection and monitoring |
| US11220893B2 (en) | 2020-01-23 | 2022-01-11 | Saudi Arabian Oil Company | Laser array for heavy hydrocarbon heating |
| US11560785B2 (en) * | 2020-01-28 | 2023-01-24 | Enverus, Inc. | Determining spacing between wellbores |
| US11661827B2 (en) * | 2020-02-12 | 2023-05-30 | Pcs Ferguson, Inc. | Gas lift valve aging process and apparatus |
| CN111472722B (en) * | 2020-03-12 | 2022-02-01 | 中国石油天然气股份有限公司 | Method and device for predicting layered gas production capacity of coal bed gas co-production well |
| CN111594133B (en) * | 2020-07-08 | 2022-03-11 | 西南石油大学 | Woven well pattern for developing multilayer low-permeability oil and gas reservoir based on multi-horizontal-seam bow-shaped well |
| US11352867B2 (en) | 2020-08-26 | 2022-06-07 | Saudi Arabian Oil Company | Enhanced hydrocarbon recovery with electric current |
| CN112067787B (en) * | 2020-08-31 | 2022-11-18 | 新疆东鲁水控农业发展有限公司 | Agricultural environment soil's restoration test device |
| US11255184B1 (en) * | 2020-10-20 | 2022-02-22 | Saudi Arabian Oil Company | Determining a subterranean formation breakdown pressure |
| JP1714442S (en) | 2020-10-30 | 2022-05-10 | Smoking aerosol generator | |
| JP1714443S (en) | 2020-10-30 | 2022-05-10 | Smoking aerosol generator | |
| USD990765S1 (en) | 2020-10-30 | 2023-06-27 | Nicoventures Trading Limited | Aerosol generator |
| JP1714440S (en) | 2020-10-30 | 2022-05-10 | Smoking aerosol generator | |
| JP1715888S (en) | 2020-10-30 | 2022-05-25 | Smoking aerosol generator | |
| JP1714441S (en) | 2020-10-30 | 2022-05-10 | Smoking aerosol generator | |
| CN112664176B (en) * | 2020-12-28 | 2022-12-09 | 西安交通大学 | Supercritical multi-element thermal fluid huff and puff oil production test simulation device and method |
| CN112324409B (en) * | 2020-12-31 | 2021-07-06 | 西南石油大学 | Method for producing solvent in situ in oil layer to recover thick oil |
| US11391135B1 (en) | 2021-01-04 | 2022-07-19 | Saudi Arabian Oil Company | Fracturing a subsurface formation based on the required breakdown pressure |
| US11608723B2 (en) | 2021-01-04 | 2023-03-21 | Saudi Arabian Oil Company | Stimulated water injection processes for injectivity improvement |
| US11814954B2 (en) | 2021-02-04 | 2023-11-14 | Black Diamond Oilfield Rentals LLC | Optimization of automated telemetry for a downhole device |
| CA3174170A1 (en) * | 2021-02-08 | 2022-08-11 | Eva VINEGAR | Hydrogen production, storage and recovery |
| CN112983376B (en) * | 2021-03-05 | 2022-03-04 | 中国矿业大学 | In-situ methane explosion energy-gathering perforation device with molecular sieve |
| CN113075108B (en) * | 2021-03-26 | 2022-02-08 | 西南石油大学 | Rock core multiple stress sensitivity test method considering irreducible water saturation |
| US11229962B1 (en) | 2021-04-08 | 2022-01-25 | Black Diamond Oilfield Rentals, LLC | System, method and apparatus for fin cutter for downhole tool |
| USD989384S1 (en) | 2021-04-30 | 2023-06-13 | Nicoventures Trading Limited | Aerosol generator |
| US11421148B1 (en) | 2021-05-04 | 2022-08-23 | Saudi Arabian Oil Company | Injection of tailored water chemistry to mitigate foaming agents retention on reservoir formation surface |
| CN113252421B (en) * | 2021-06-17 | 2021-09-21 | 西南石油大学 | Device and method for measuring trace carbon isotopes and heavy components in natural gas |
| WO2023063995A1 (en) * | 2021-10-14 | 2023-04-20 | Aera Energy Llc | Sequestration chamber and method of construction |
Family Cites Families (856)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US2734579A (en) | 1956-02-14 | Production from bituminous sands | ||
| US94813A (en) | 1869-09-14 | Improvement in torpedoes for oil-wells | ||
| SE123138C1 (en) | 1948-01-01 | |||
| CA899987A (en) | 1972-05-09 | Chisso Corporation | Method for controlling heat generation locally in a heat-generating pipe utilizing skin effect current | |
| US48994A (en) | 1865-07-25 | Improvement in devices for oil-wells | ||
| US326439A (en) | 1885-09-15 | Protecting wells | ||
| SE123136C1 (en) | 1948-01-01 | |||
| US2732195A (en) | 1956-01-24 | Ljungstrom | ||
| SE126674C1 (en) | 1949-01-01 | |||
| US345586A (en) | 1886-07-13 | Oil from wells | ||
| US760304A (en) | 1903-10-24 | 1904-05-17 | Frank S Gilbert | Heater for oil-wells. |
| US1342741A (en) | 1918-01-17 | 1920-06-08 | David T Day | Process for extracting oils and hydrocarbon material from shale and similar bituminous rocks |
| US1269747A (en) | 1918-04-06 | 1918-06-18 | Lebbeus H Rogers | Method of and apparatus for treating oil-shale. |
| GB156396A (en) | 1919-12-10 | 1921-01-13 | Wilson Woods Hoover | An improved method of treating shale and recovering oil therefrom |
| US1457479A (en) | 1920-01-12 | 1923-06-05 | Edson R Wolcott | Method of increasing the yield of oil wells |
| US1510655A (en) | 1922-11-21 | 1924-10-07 | Clark Cornelius | Process of subterranean distillation of volatile mineral substances |
| US1634236A (en) | 1925-03-10 | 1927-06-28 | Standard Dev Co | Method of and apparatus for recovering oil |
| US1646599A (en) | 1925-04-30 | 1927-10-25 | George A Schaefer | Apparatus for removing fluid from wells |
| US1666488A (en) | 1927-02-05 | 1928-04-17 | Crawshaw Richard | Apparatus for extracting oil from shale |
| US1681523A (en) | 1927-03-26 | 1928-08-21 | Patrick V Downey | Apparatus for heating oil wells |
| US1812267A (en) * | 1928-07-28 | 1931-06-30 | Standard Oil Dev Co | Process for operating oil and gas wells under reduced pressure |
| US1913395A (en) | 1929-11-14 | 1933-06-13 | Lewis C Karrick | Underground gasification of carbonaceous material-bearing substances |
| US2244255A (en) | 1939-01-18 | 1941-06-03 | Electrical Treating Company | Well clearing system |
| US2244256A (en) | 1939-12-16 | 1941-06-03 | Electrical Treating Company | Apparatus for clearing wells |
| US2319702A (en) | 1941-04-04 | 1943-05-18 | Socony Vacuum Oil Co Inc | Method and apparatus for producing oil wells |
| US2365591A (en) | 1942-08-15 | 1944-12-19 | Ranney Leo | Method for producing oil from viscous deposits |
| US2423674A (en) | 1942-08-24 | 1947-07-08 | Johnson & Co A | Process of catalytic cracking of petroleum hydrocarbons |
| US2381256A (en) | 1942-10-06 | 1945-08-07 | Texas Co | Process for treating hydrocarbon fractions |
| US2390770A (en) | 1942-10-10 | 1945-12-11 | Sun Oil Co | Method of producing petroleum |
| US2375689A (en) | 1943-12-27 | 1945-05-08 | David H Reeder | Apparatus for mining coal |
| US2484063A (en) | 1944-08-19 | 1949-10-11 | Thermactor Corp | Electric heater for subsurface materials |
| US2472445A (en) | 1945-02-02 | 1949-06-07 | Thermactor Company | Apparatus for treating oil and gas bearing strata |
| US2481051A (en) * | 1945-12-15 | 1949-09-06 | Texaco Development Corp | Process and apparatus for the recovery of volatilizable constituents from underground carbonaceous formations |
| US2444755A (en) | 1946-01-04 | 1948-07-06 | Ralph M Steffen | Apparatus for oil sand heating |
| US2634961A (en) | 1946-01-07 | 1953-04-14 | Svensk Skifferolje Aktiebolage | Method of electrothermal production of shale oil |
| US2466945A (en) | 1946-02-21 | 1949-04-12 | In Situ Gases Inc | Generation of synthesis gas |
| US2497868A (en) | 1946-10-10 | 1950-02-21 | Dalin David | Underground exploitation of fuel deposits |
| US2939689A (en) | 1947-06-24 | 1960-06-07 | Svenska Skifferolje Ab | Electrical heater for treating oilshale and the like |
| US2786660A (en) | 1948-01-05 | 1957-03-26 | Phillips Petroleum Co | Apparatus for gasifying coal |
| US2548360A (en) | 1948-03-29 | 1951-04-10 | Stanley A Germain | Electric oil well heater |
| US2584605A (en) | 1948-04-14 | 1952-02-05 | Edmund S Merriam | Thermal drive method for recovery of oil |
| US2685930A (en) | 1948-08-12 | 1954-08-10 | Union Oil Co | Oil well production process |
| US2630307A (en) | 1948-12-09 | 1953-03-03 | Carbonic Products Inc | Method of recovering oil from oil shale |
| US2595979A (en) | 1949-01-25 | 1952-05-06 | Texas Co | Underground liquefaction of coal |
| US2642943A (en) | 1949-05-20 | 1953-06-23 | Sinclair Oil & Gas Co | Oil recovery process |
| US2593477A (en) | 1949-06-10 | 1952-04-22 | Us Interior | Process of underground gasification of coal |
| GB674082A (en) | 1949-06-15 | 1952-06-18 | Nat Res Dev | Improvements in or relating to the underground gasification of coal |
| US2670802A (en) | 1949-12-16 | 1954-03-02 | Thermactor Company | Reviving or increasing the production of clogged or congested oil wells |
| US2623596A (en) | 1950-05-16 | 1952-12-30 | Atlantic Refining Co | Method for producing oil by means of carbon dioxide |
| US2707029A (en) * | 1950-07-28 | 1955-04-26 | Carroll H Van Hartesveldt | Apparatus for obtaining liquids from deep wells |
| US2714930A (en) | 1950-12-08 | 1955-08-09 | Union Oil Co | Apparatus for preventing paraffin deposition |
| US2695163A (en) | 1950-12-09 | 1954-11-23 | Stanolind Oil & Gas Co | Method for gasification of subterranean carbonaceous deposits |
| GB697189A (en) | 1951-04-09 | 1953-09-16 | Nat Res Dev | Improvements relating to the underground gasification of coal |
| US2630306A (en) | 1952-01-03 | 1953-03-03 | Socony Vacuum Oil Co Inc | Subterranean retorting of shales |
| US2777679A (en) * | 1952-03-07 | 1957-01-15 | Svenska Skifferolje Ab | Recovering sub-surface bituminous deposits by creating a frozen barrier and heating in situ |
| US2780450A (en) | 1952-03-07 | 1957-02-05 | Svenska Skifferolje Ab | Method of recovering oil and gases from non-consolidated bituminous geological formations by a heating treatment in situ |
| US2789805A (en) | 1952-05-27 | 1957-04-23 | Svenska Skifferolje Ab | Device for recovering fuel from subterraneous fuel-carrying deposits by heating in their natural location using a chain heat transfer member |
| US2780449A (en) | 1952-12-26 | 1957-02-05 | Sinclair Oil & Gas Co | Thermal process for in-situ decomposition of oil shale |
| US2825408A (en) | 1953-03-09 | 1958-03-04 | Sinclair Oil & Gas Company | Oil recovery by subsurface thermal processing |
| US2771954A (en) | 1953-04-29 | 1956-11-27 | Exxon Research Engineering Co | Treatment of petroleum production wells |
| US2703621A (en) | 1953-05-04 | 1955-03-08 | George W Ford | Oil well bottom hole flow increasing unit |
| US2743906A (en) * | 1953-05-08 | 1956-05-01 | William E Coyle | Hydraulic underreamer |
| US2803305A (en) | 1953-05-14 | 1957-08-20 | Pan American Petroleum Corp | Oil recovery by underground combustion |
| US2914309A (en) | 1953-05-25 | 1959-11-24 | Svenska Skifferolje Ab | Oil and gas recovery from tar sands |
| US2902270A (en) * | 1953-07-17 | 1959-09-01 | Svenska Skifferolje Ab | Method of and means in heating of subsurface fuel-containing deposits "in situ" |
| US2890754A (en) * | 1953-10-30 | 1959-06-16 | Svenska Skifferolje Ab | Apparatus for recovering combustible substances from subterraneous deposits in situ |
| US2890755A (en) | 1953-12-19 | 1959-06-16 | Svenska Skifferolje Ab | Apparatus for recovering combustible substances from subterraneous deposits in situ |
| US2841375A (en) | 1954-03-03 | 1958-07-01 | Svenska Skifferolje Ab | Method for in-situ utilization of fuels by combustion |
| US2794504A (en) | 1954-05-10 | 1957-06-04 | Union Oil Co | Well heater |
| US2793696A (en) | 1954-07-22 | 1957-05-28 | Pan American Petroleum Corp | Oil recovery by underground combustion |
| US2787325A (en) | 1954-12-24 | 1957-04-02 | Pure Oil Co | Selective treatment of geological formations |
| US2801699A (en) | 1954-12-24 | 1957-08-06 | Pure Oil Co | Process for temporarily and selectively sealing a well |
| US2923535A (en) | 1955-02-11 | 1960-02-02 | Svenska Skifferolje Ab | Situ recovery from carbonaceous deposits |
| US2799341A (en) | 1955-03-04 | 1957-07-16 | Union Oil Co | Selective plugging in oil wells |
| US2801089A (en) | 1955-03-14 | 1957-07-30 | California Research Corp | Underground shale retorting process |
| US2862558A (en) | 1955-12-28 | 1958-12-02 | Phillips Petroleum Co | Recovering oils from formations |
| US2819761A (en) | 1956-01-19 | 1958-01-14 | Continental Oil Co | Process of removing viscous oil from a well bore |
| US2857002A (en) | 1956-03-19 | 1958-10-21 | Texas Co | Recovery of viscous crude oil |
| US2906340A (en) | 1956-04-05 | 1959-09-29 | Texaco Inc | Method of treating a petroleum producing formation |
| US2991046A (en) | 1956-04-16 | 1961-07-04 | Parsons Lional Ashley | Combined winch and bollard device |
| US2889882A (en) | 1956-06-06 | 1959-06-09 | Phillips Petroleum Co | Oil recovery by in situ combustion |
| US3120264A (en) | 1956-07-09 | 1964-02-04 | Texaco Development Corp | Recovery of oil by in situ combustion |
| US3016053A (en) | 1956-08-02 | 1962-01-09 | George J Medovick | Underwater breathing apparatus |
| US2997105A (en) * | 1956-10-08 | 1961-08-22 | Pan American Petroleum Corp | Burner apparatus |
| US2932352A (en) | 1956-10-25 | 1960-04-12 | Union Oil Co | Liquid filled well heater |
| US2804149A (en) | 1956-12-12 | 1957-08-27 | John R Donaldson | Oil well heater and reviver |
| US2952449A (en) | 1957-02-01 | 1960-09-13 | Fmc Corp | Method of forming underground communication between boreholes |
| US3127936A (en) | 1957-07-26 | 1964-04-07 | Svenska Skifferolje Ab | Method of in situ heating of subsurface preferably fuel containing deposits |
| US2942223A (en) | 1957-08-09 | 1960-06-21 | Gen Electric | Electrical resistance heater |
| US2906337A (en) | 1957-08-16 | 1959-09-29 | Pure Oil Co | Method of recovering bitumen |
| US3007521A (en) | 1957-10-28 | 1961-11-07 | Phillips Petroleum Co | Recovery of oil by in situ combustion |
| US3010516A (en) | 1957-11-18 | 1961-11-28 | Phillips Petroleum Co | Burner and process for in situ combustion |
| US2954826A (en) | 1957-12-02 | 1960-10-04 | William E Sievers | Heated well production string |
| US2994376A (en) | 1957-12-27 | 1961-08-01 | Phillips Petroleum Co | In situ combustion process |
| US3061009A (en) | 1958-01-17 | 1962-10-30 | Svenska Skifferolje Ab | Method of recovery from fossil fuel bearing strata |
| US3062282A (en) | 1958-01-24 | 1962-11-06 | Phillips Petroleum Co | Initiation of in situ combustion in a carbonaceous stratum |
| US3051235A (en) * | 1958-02-24 | 1962-08-28 | Jersey Prod Res Co | Recovery of petroleum crude oil, by in situ combustion and in situ hydrogenation |
| US3004603A (en) | 1958-03-07 | 1961-10-17 | Phillips Petroleum Co | Heater |
| US3032102A (en) | 1958-03-17 | 1962-05-01 | Phillips Petroleum Co | In situ combustion method |
| US3004596A (en) | 1958-03-28 | 1961-10-17 | Phillips Petroleum Co | Process for recovery of hydrocarbons by in situ combustion |
| US3004601A (en) | 1958-05-09 | 1961-10-17 | Albert G Bodine | Method and apparatus for augmenting oil recovery from wells by refrigeration |
| US3048221A (en) | 1958-05-12 | 1962-08-07 | Phillips Petroleum Co | Hydrocarbon recovery by thermal drive |
| US3026940A (en) | 1958-05-19 | 1962-03-27 | Electronic Oil Well Heater Inc | Oil well temperature indicator and control |
| US3010513A (en) | 1958-06-12 | 1961-11-28 | Phillips Petroleum Co | Initiation of in situ combustion in carbonaceous stratum |
| US2958519A (en) | 1958-06-23 | 1960-11-01 | Phillips Petroleum Co | In situ combustion process |
| US3044545A (en) | 1958-10-02 | 1962-07-17 | Phillips Petroleum Co | In situ combustion process |
| US3050123A (en) | 1958-10-07 | 1962-08-21 | Cities Service Res & Dev Co | Gas fired oil-well burner |
| US2950240A (en) | 1958-10-10 | 1960-08-23 | Socony Mobil Oil Co Inc | Selective cracking of aliphatic hydrocarbons |
| US2974937A (en) | 1958-11-03 | 1961-03-14 | Jersey Prod Res Co | Petroleum recovery from carbonaceous formations |
| US2998457A (en) | 1958-11-19 | 1961-08-29 | Ashland Oil Inc | Production of phenols |
| US2970826A (en) * | 1958-11-21 | 1961-02-07 | Texaco Inc | Recovery of oil from oil shale |
| US3036632A (en) | 1958-12-24 | 1962-05-29 | Socony Mobil Oil Co Inc | Recovery of hydrocarbon materials from earth formations by application of heat |
| US2969226A (en) | 1959-01-19 | 1961-01-24 | Pyrochem Corp | Pendant parting petro pyrolysis process |
| US3051234A (en) * | 1959-01-22 | 1962-08-28 | Jersey Prod Res Co | Oil displacement by water containing suspended clay |
| US3017168A (en) | 1959-01-26 | 1962-01-16 | Phillips Petroleum Co | In situ retorting of oil shale |
| US3110345A (en) | 1959-02-26 | 1963-11-12 | Gulf Research Development Co | Low temperature reverse combustion process |
| US3113619A (en) | 1959-03-30 | 1963-12-10 | Phillips Petroleum Co | Line drive counterflow in situ combustion process |
| US3113620A (en) | 1959-07-06 | 1963-12-10 | Exxon Research Engineering Co | Process for producing viscous oil |
| US3181613A (en) | 1959-07-20 | 1965-05-04 | Union Oil Co | Method and apparatus for subterranean heating |
| US3113623A (en) | 1959-07-20 | 1963-12-10 | Union Oil Co | Apparatus for underground retorting |
| US3116792A (en) | 1959-07-27 | 1964-01-07 | Phillips Petroleum Co | In situ combustion process |
| US3132692A (en) | 1959-07-27 | 1964-05-12 | Phillips Petroleum Co | Use of formation heat from in situ combustion |
| US3079085A (en) | 1959-10-21 | 1963-02-26 | Clark | Apparatus for analyzing the production and drainage of petroleum reservoirs, and the like |
| US3095031A (en) | 1959-12-09 | 1963-06-25 | Eurenius Malte Oscar | Burners for use in bore holes in the ground |
| US3131763A (en) | 1959-12-30 | 1964-05-05 | Texaco Inc | Electrical borehole heater |
| US3163745A (en) | 1960-02-29 | 1964-12-29 | Socony Mobil Oil Co Inc | Heating of an earth formation penetrated by a well borehole |
| US3127935A (en) | 1960-04-08 | 1964-04-07 | Marathon Oil Co | In situ combustion for oil recovery in tar sands, oil shales and conventional petroleum reservoirs |
| US3137347A (en) | 1960-05-09 | 1964-06-16 | Phillips Petroleum Co | In situ electrolinking of oil shale |
| US3139928A (en) | 1960-05-24 | 1964-07-07 | Shell Oil Co | Thermal process for in situ decomposition of oil shale |
| US3058730A (en) | 1960-06-03 | 1962-10-16 | Fmc Corp | Method of forming underground communication between boreholes |
| US3106244A (en) | 1960-06-20 | 1963-10-08 | Phillips Petroleum Co | Process for producing oil shale in situ by electrocarbonization |
| US3142336A (en) | 1960-07-18 | 1964-07-28 | Shell Oil Co | Method and apparatus for injecting steam into subsurface formations |
| US3084919A (en) | 1960-08-03 | 1963-04-09 | Texaco Inc | Recovery of oil from oil shale by underground hydrogenation |
| US3105545A (en) | 1960-11-21 | 1963-10-01 | Shell Oil Co | Method of heating underground formations |
| US3164207A (en) | 1961-01-17 | 1965-01-05 | Wayne H Thessen | Method for recovering oil |
| US3138203A (en) | 1961-03-06 | 1964-06-23 | Jersey Prod Res Co | Method of underground burning |
| US3191679A (en) | 1961-04-13 | 1965-06-29 | Wendell S Miller | Melting process for recovering bitumens from the earth |
| US3207220A (en) | 1961-06-26 | 1965-09-21 | Chester I Williams | Electric well heater |
| US3114417A (en) | 1961-08-14 | 1963-12-17 | Ernest T Saftig | Electric oil well heater apparatus |
| US3246695A (en) | 1961-08-21 | 1966-04-19 | Charles L Robinson | Method for heating minerals in situ with radioactive materials |
| US3057404A (en) | 1961-09-29 | 1962-10-09 | Socony Mobil Oil Co Inc | Method and system for producing oil tenaciously held in porous formations |
| US3183675A (en) | 1961-11-02 | 1965-05-18 | Conch Int Methane Ltd | Method of freezing an earth formation |
| US3170842A (en) | 1961-11-06 | 1965-02-23 | Phillips Petroleum Co | Subcritical borehole nuclear reactor and process |
| US3209825A (en) | 1962-02-14 | 1965-10-05 | Continental Oil Co | Low temperature in-situ combustion |
| US3205946A (en) | 1962-03-12 | 1965-09-14 | Shell Oil Co | Consolidation by silica coalescence |
| US3165154A (en) | 1962-03-23 | 1965-01-12 | Phillips Petroleum Co | Oil recovery by in situ combustion |
| US3149670A (en) | 1962-03-27 | 1964-09-22 | Smclair Res Inc | In-situ heating process |
| US3149672A (en) | 1962-05-04 | 1964-09-22 | Jersey Prod Res Co | Method and apparatus for electrical heating of oil-bearing formations |
| US3208531A (en) | 1962-08-21 | 1965-09-28 | Otis Eng Co | Inserting tool for locating and anchoring a device in tubing |
| US3182721A (en) | 1962-11-02 | 1965-05-11 | Sun Oil Co | Method of petroleum production by forward in situ combustion |
| US3288648A (en) * | 1963-02-04 | 1966-11-29 | Pan American Petroleum Corp | Process for producing electrical energy from geological liquid hydrocarbon formation |
| US3258069A (en) | 1963-02-07 | 1966-06-28 | Shell Oil Co | Method for producing a source of energy from an overpressured formation |
| US3205942A (en) | 1963-02-07 | 1965-09-14 | Socony Mobil Oil Co Inc | Method for recovery of hydrocarbons by in situ heating of oil shale |
| US3221505A (en) | 1963-02-20 | 1965-12-07 | Gulf Research Development Co | Grouting method |
| US3221811A (en) | 1963-03-11 | 1965-12-07 | Shell Oil Co | Mobile in-situ heating of formations |
| US3250327A (en) * | 1963-04-02 | 1966-05-10 | Socony Mobil Oil Co Inc | Recovering nonflowing hydrocarbons |
| US3244231A (en) | 1963-04-09 | 1966-04-05 | Pan American Petroleum Corp | Method for catalytically heating oil bearing formations |
| US3241611A (en) | 1963-04-10 | 1966-03-22 | Equity Oil Company | Recovery of petroleum products from oil shale |
| GB959945A (en) | 1963-04-18 | 1964-06-03 | Conch Int Methane Ltd | Constructing a frozen wall within the ground |
| US3237689A (en) * | 1963-04-29 | 1966-03-01 | Clarence I Justheim | Distillation of underground deposits of solid carbonaceous materials in situ |
| US3223166A (en) | 1963-05-27 | 1965-12-14 | Pan American Petroleum Corp | Method of controlled catalytic heating of a subsurface formation |
| US3205944A (en) | 1963-06-14 | 1965-09-14 | Socony Mobil Oil Co Inc | Recovery of hydrocarbons from a subterranean reservoir by heating |
| US3233668A (en) | 1963-11-15 | 1966-02-08 | Exxon Production Research Co | Recovery of shale oil |
| US3285335A (en) * | 1963-12-11 | 1966-11-15 | Exxon Research Engineering Co | In situ pyrolysis of oil shale formations |
| US3273640A (en) | 1963-12-13 | 1966-09-20 | Pyrochem Corp | Pressure pulsing perpendicular permeability process for winning stabilized primary volatiles from oil shale in situ |
| US3303883A (en) | 1964-01-06 | 1967-02-14 | Mobil Oil Corp | Thermal notching technique |
| US3275076A (en) | 1964-01-13 | 1966-09-27 | Mobil Oil Corp | Recovery of asphaltic-type petroleum from a subterranean reservoir |
| US3342258A (en) | 1964-03-06 | 1967-09-19 | Shell Oil Co | Underground oil recovery from solid oil-bearing deposits |
| US3294167A (en) | 1964-04-13 | 1966-12-27 | Shell Oil Co | Thermal oil recovery |
| US3284281A (en) | 1964-08-31 | 1966-11-08 | Phillips Petroleum Co | Production of oil from oil shale through fractures |
| US3302707A (en) * | 1964-09-30 | 1967-02-07 | Mobil Oil Corp | Method for improving fluid recoveries from earthen formations |
| US3310109A (en) | 1964-11-06 | 1967-03-21 | Phillips Petroleum Co | Process and apparatus for combination upgrading of oil in situ and refining thereof |
| US3380913A (en) | 1964-12-28 | 1968-04-30 | Phillips Petroleum Co | Refining of effluent from in situ combustion operation |
| US3332480A (en) * | 1965-03-04 | 1967-07-25 | Pan American Petroleum Corp | Recovery of hydrocarbons by thermal methods |
| US3338306A (en) | 1965-03-09 | 1967-08-29 | Mobil Oil Corp | Recovery of heavy oil from oil sands |
| US3358756A (en) * | 1965-03-12 | 1967-12-19 | Shell Oil Co | Method for in situ recovery of solid or semi-solid petroleum deposits |
| US3262741A (en) | 1965-04-01 | 1966-07-26 | Pittsburgh Plate Glass Co | Solution mining of potassium chloride |
| DE1242535B (en) | 1965-04-13 | 1967-06-22 | Deutsche Erdoel Ag | Process for the removal of residual oil from oil deposits |
| US3316344A (en) | 1965-04-26 | 1967-04-25 | Central Electr Generat Board | Prevention of icing of electrical conductors |
| US3342267A (en) | 1965-04-29 | 1967-09-19 | Gerald S Cotter | Turbo-generator heater for oil and gas wells and pipe lines |
| US3278234A (en) | 1965-05-17 | 1966-10-11 | Pittsburgh Plate Glass Co | Solution mining of potassium chloride |
| US3352355A (en) | 1965-06-23 | 1967-11-14 | Dow Chemical Co | Method of recovery of hydrocarbons from solid hydrocarbonaceous formations |
| US3346044A (en) | 1965-09-08 | 1967-10-10 | Mobil Oil Corp | Method and structure for retorting oil shale in situ by cycling fluid flows |
| US3349845A (en) | 1965-10-22 | 1967-10-31 | Sinclair Oil & Gas Company | Method of establishing communication between wells |
| US3379248A (en) | 1965-12-10 | 1968-04-23 | Mobil Oil Corp | In situ combustion process utilizing waste heat |
| US3454365A (en) | 1966-02-18 | 1969-07-08 | Phillips Petroleum Co | Analysis and control of in situ combustion of underground carbonaceous deposit |
| US3386508A (en) * | 1966-02-21 | 1968-06-04 | Exxon Production Research Co | Process and system for the recovery of viscous oil |
| US3362751A (en) * | 1966-02-28 | 1968-01-09 | Tinlin William | Method and system for recovering shale oil and gas |
| US3595082A (en) | 1966-03-04 | 1971-07-27 | Gulf Oil Corp | Temperature measuring apparatus |
| US3410977A (en) | 1966-03-28 | 1968-11-12 | Ando Masao | Method of and apparatus for heating the surface part of various construction materials |
| DE1615192B1 (en) | 1966-04-01 | 1970-08-20 | Chisso Corp | Inductively heated heating pipe |
| US3410796A (en) | 1966-04-04 | 1968-11-12 | Gas Processors Inc | Process for treatment of saline waters |
| US3513913A (en) | 1966-04-19 | 1970-05-26 | Shell Oil Co | Oil recovery from oil shales by transverse combustion |
| US3372754A (en) * | 1966-05-31 | 1968-03-12 | Mobil Oil Corp | Well assembly for heating a subterranean formation |
| US3399623A (en) * | 1966-07-14 | 1968-09-03 | James R. Creed | Apparatus for and method of producing viscid oil |
| US3412011A (en) * | 1966-09-02 | 1968-11-19 | Phillips Petroleum Co | Catalytic cracking and in situ combustion process for producing hydrocarbons |
| NL153755C (en) | 1966-10-20 | 1977-11-15 | Stichting Reactor Centrum | METHOD FOR MANUFACTURING AN ELECTRIC HEATING ELEMENT, AS WELL AS HEATING ELEMENT MANUFACTURED USING THIS METHOD. |
| US3465819A (en) * | 1967-02-13 | 1969-09-09 | American Oil Shale Corp | Use of nuclear detonations in producing hydrocarbons from an underground formation |
| US3389975A (en) | 1967-03-10 | 1968-06-25 | Sinclair Research Inc | Process for the recovery of aluminum values from retorted shale and conversion of sodium aluminate to sodium aluminum carbonate hydroxide |
| NL6803827A (en) | 1967-03-22 | 1968-09-23 | ||
| US3622071A (en) | 1967-06-08 | 1971-11-23 | Combustion Eng | Crude petroleum transmission system |
| US3528501A (en) | 1967-08-04 | 1970-09-15 | Phillips Petroleum Co | Recovery of oil from oil shale |
| US3434541A (en) * | 1967-10-11 | 1969-03-25 | Mobil Oil Corp | In situ combustion process |
| US3485300A (en) * | 1967-12-20 | 1969-12-23 | Phillips Petroleum Co | Method and apparatus for defoaming crude oil down hole |
| US3477058A (en) | 1968-02-01 | 1969-11-04 | Gen Electric | Magnesia insulated heating elements and methods of production |
| US3580987A (en) | 1968-03-26 | 1971-05-25 | Pirelli | Electric cable |
| US3455383A (en) | 1968-04-24 | 1969-07-15 | Shell Oil Co | Method of producing fluidized material from a subterranean formation |
| US3578080A (en) * | 1968-06-10 | 1971-05-11 | Shell Oil Co | Method of producing shale oil from an oil shale formation |
| US3497000A (en) | 1968-08-19 | 1970-02-24 | Pan American Petroleum Corp | Bottom hole catalytic heater |
| US3529682A (en) * | 1968-10-03 | 1970-09-22 | Bell Telephone Labor Inc | Location detection and guidance systems for burrowing device |
| US3537528A (en) * | 1968-10-14 | 1970-11-03 | Shell Oil Co | Method for producing shale oil from an exfoliated oil shale formation |
| US3593789A (en) * | 1968-10-18 | 1971-07-20 | Shell Oil Co | Method for producing shale oil from an oil shale formation |
| US3502372A (en) | 1968-10-23 | 1970-03-24 | Shell Oil Co | Process of recovering oil and dawsonite from oil shale |
| US3565171A (en) * | 1968-10-23 | 1971-02-23 | Shell Oil Co | Method for producing shale oil from a subterranean oil shale formation |
| US3629551A (en) | 1968-10-29 | 1971-12-21 | Chisso Corp | Controlling heat generation locally in a heat-generating pipe utilizing skin-effect current |
| US3501201A (en) | 1968-10-30 | 1970-03-17 | Shell Oil Co | Method of producing shale oil from a subterranean oil shale formation |
| US3617471A (en) | 1968-12-26 | 1971-11-02 | Texaco Inc | Hydrotorting of shale to produce shale oil |
| US3593790A (en) | 1969-01-02 | 1971-07-20 | Shell Oil Co | Method for producing shale oil from an oil shale formation |
| US3614986A (en) * | 1969-03-03 | 1971-10-26 | Electrothermic Co | Method for injecting heated fluids into mineral bearing formations |
| US3562401A (en) | 1969-03-03 | 1971-02-09 | Union Carbide Corp | Low temperature electric transmission systems |
| US3542131A (en) * | 1969-04-01 | 1970-11-24 | Mobil Oil Corp | Method of recovering hydrocarbons from oil shale |
| US3547192A (en) * | 1969-04-04 | 1970-12-15 | Shell Oil Co | Method of metal coating and electrically heating a subterranean earth formation |
| US3618663A (en) | 1969-05-01 | 1971-11-09 | Phillips Petroleum Co | Shale oil production |
| US3605890A (en) | 1969-06-04 | 1971-09-20 | Chevron Res | Hydrogen production from a kerogen-depleted shale formation |
| US3572838A (en) | 1969-07-07 | 1971-03-30 | Shell Oil Co | Recovery of aluminum compounds and oil from oil shale formations |
| US3526095A (en) | 1969-07-24 | 1970-09-01 | Ralph E Peck | Liquid gas storage system |
| US3599714A (en) | 1969-09-08 | 1971-08-17 | Roger L Messman | Method of recovering hydrocarbons by in situ combustion |
| US3547193A (en) | 1969-10-08 | 1970-12-15 | Electrothermic Co | Method and apparatus for recovery of minerals from sub-surface formations using electricity |
| US3661423A (en) | 1970-02-12 | 1972-05-09 | Occidental Petroleum Corp | In situ process for recovery of carbonaceous materials from subterranean deposits |
| USRE27309E (en) | 1970-05-07 | 1972-03-14 | Gas in | |
| US3759574A (en) | 1970-09-24 | 1973-09-18 | Shell Oil Co | Method of producing hydrocarbons from an oil shale formation |
| US4305463A (en) | 1979-10-31 | 1981-12-15 | Oil Trieval Corporation | Oil recovery method and apparatus |
| US3679812A (en) | 1970-11-13 | 1972-07-25 | Schlumberger Technology Corp | Electrical suspension cable for well tools |
| US3680633A (en) | 1970-12-28 | 1972-08-01 | Sun Oil Co Delaware | Situ combustion initiation process |
| US3675715A (en) | 1970-12-30 | 1972-07-11 | Forrester A Clark | Processes for secondarily recovering oil |
| US3775185A (en) | 1971-01-13 | 1973-11-27 | United Aircraft Corp | Fuel cell utilizing fused thallium oxide electrolyte |
| US3700280A (en) * | 1971-04-28 | 1972-10-24 | Shell Oil Co | Method of producing oil from an oil shale formation containing nahcolite and dawsonite |
| US3870063A (en) | 1971-06-11 | 1975-03-11 | John T Hayward | Means of transporting crude oil through a pipeline |
| US3770398A (en) | 1971-09-17 | 1973-11-06 | Cities Service Oil Co | In situ coal gasification process |
| US3812913A (en) | 1971-10-18 | 1974-05-28 | Sun Oil Co | Method of formation consolidation |
| US3893918A (en) * | 1971-11-22 | 1975-07-08 | Engineering Specialties Inc | Method for separating material leaving a well |
| US3766982A (en) | 1971-12-27 | 1973-10-23 | Justheim Petrol Co | Method for the in-situ treatment of hydrocarbonaceous materials |
| US3759328A (en) * | 1972-05-11 | 1973-09-18 | Shell Oil Co | Laterally expanding oil shale permeabilization |
| US3794116A (en) | 1972-05-30 | 1974-02-26 | Atomic Energy Commission | Situ coal bed gasification |
| US3779602A (en) * | 1972-08-07 | 1973-12-18 | Shell Oil Co | Process for solution mining nahcolite |
| US3757860A (en) * | 1972-08-07 | 1973-09-11 | Atlantic Richfield Co | Well heating |
| CA983704A (en) | 1972-08-31 | 1976-02-17 | Joseph D. Robinson | Method for determining distance and direction to a cased well bore |
| US3809159A (en) | 1972-10-02 | 1974-05-07 | Continental Oil Co | Process for simultaneously increasing recovery and upgrading oil in a reservoir |
| US3804172A (en) * | 1972-10-11 | 1974-04-16 | Shell Oil Co | Method for the recovery of oil from oil shale |
| US3804169A (en) * | 1973-02-07 | 1974-04-16 | Shell Oil Co | Spreading-fluid recovery of subterranean oil |
| US3947683A (en) | 1973-06-05 | 1976-03-30 | Texaco Inc. | Combination of epithermal and inelastic neutron scattering methods to locate coal and oil shale zones |
| US4076761A (en) | 1973-08-09 | 1978-02-28 | Mobil Oil Corporation | Process for the manufacture of gasoline |
| US3874733A (en) | 1973-08-29 | 1975-04-01 | Continental Oil Co | Hydraulic method of mining and conveying coal in substantially vertical seams |
| US3881551A (en) | 1973-10-12 | 1975-05-06 | Ruel C Terry | Method of extracting immobile hydrocarbons |
| US3853185A (en) | 1973-11-30 | 1974-12-10 | Continental Oil Co | Guidance system for a horizontal drilling apparatus |
| US3907045A (en) * | 1973-11-30 | 1975-09-23 | Continental Oil Co | Guidance system for a horizontal drilling apparatus |
| US3882941A (en) | 1973-12-17 | 1975-05-13 | Cities Service Res & Dev Co | In situ production of bitumen from oil shale |
| US4037655A (en) | 1974-04-19 | 1977-07-26 | Electroflood Company | Method for secondary recovery of oil |
| US4199025A (en) | 1974-04-19 | 1980-04-22 | Electroflood Company | Method and apparatus for tertiary recovery of oil |
| US3922148A (en) | 1974-05-16 | 1975-11-25 | Texaco Development Corp | Production of methane-rich gas |
| US3948755A (en) | 1974-05-31 | 1976-04-06 | Standard Oil Company | Process for recovering and upgrading hydrocarbons from oil shale and tar sands |
| ZA753184B (en) | 1974-05-31 | 1976-04-28 | Standard Oil Co | Process for recovering upgraded hydrocarbon products |
| US3892270A (en) | 1974-06-06 | 1975-07-01 | Chevron Res | Production of hydrocarbons from underground formations |
| US4006778A (en) | 1974-06-21 | 1977-02-08 | Texaco Exploration Canada Ltd. | Thermal recovery of hydrocarbon from tar sands |
| US4026357A (en) | 1974-06-26 | 1977-05-31 | Texaco Exploration Canada Ltd. | In situ gasification of solid hydrocarbon materials in a subterranean formation |
| US4029360A (en) * | 1974-07-26 | 1977-06-14 | Occidental Oil Shale, Inc. | Method of recovering oil and water from in situ oil shale retort flue gas |
| US4005752A (en) | 1974-07-26 | 1977-02-01 | Occidental Petroleum Corporation | Method of igniting in situ oil shale retort with fuel rich flue gas |
| US4014575A (en) * | 1974-07-26 | 1977-03-29 | Occidental Petroleum Corporation | System for fuel and products of oil shale retort |
| US3941421A (en) | 1974-08-13 | 1976-03-02 | Occidental Petroleum Corporation | Apparatus for obtaining uniform gas flow through an in situ oil shale retort |
| GB1454324A (en) | 1974-08-14 | 1976-11-03 | Iniex | Recovering combustible gases from underground deposits of coal or bituminous shale |
| US3947656A (en) | 1974-08-26 | 1976-03-30 | Fast Heat Element Manufacturing Co., Inc. | Temperature controlled cartridge heater |
| US3948319A (en) | 1974-10-16 | 1976-04-06 | Atlantic Richfield Company | Method and apparatus for producing fluid by varying current flow through subterranean source formation |
| AR205595A1 (en) | 1974-11-06 | 1976-05-14 | Haldor Topsoe As | PROCEDURE FOR PREPARING GASES RICH IN METHANE |
| US3933447A (en) | 1974-11-08 | 1976-01-20 | The United States Of America As Represented By The United States Energy Research And Development Administration | Underground gasification of coal |
| US4138442A (en) | 1974-12-05 | 1979-02-06 | Mobil Oil Corporation | Process for the manufacture of gasoline |
| US3952802A (en) | 1974-12-11 | 1976-04-27 | In Situ Technology, Inc. | Method and apparatus for in situ gasification of coal and the commercial products derived therefrom |
| US3986556A (en) | 1975-01-06 | 1976-10-19 | Haynes Charles A | Hydrocarbon recovery from earth strata |
| US4042026A (en) | 1975-02-08 | 1977-08-16 | Deutsche Texaco Aktiengesellschaft | Method for initiating an in-situ recovery process by the introduction of oxygen |
| US3972372A (en) | 1975-03-10 | 1976-08-03 | Fisher Sidney T | Exraction of hydrocarbons in situ from underground hydrocarbon deposits |
| US4096163A (en) | 1975-04-08 | 1978-06-20 | Mobil Oil Corporation | Conversion of synthesis gas to hydrocarbon mixtures |
| US3924680A (en) | 1975-04-23 | 1975-12-09 | In Situ Technology Inc | Method of pyrolysis of coal in situ |
| US3973628A (en) | 1975-04-30 | 1976-08-10 | New Mexico Tech Research Foundation | In situ solution mining of coal |
| US4016239A (en) | 1975-05-22 | 1977-04-05 | Union Oil Company Of California | Recarbonation of spent oil shale |
| US3987851A (en) | 1975-06-02 | 1976-10-26 | Shell Oil Company | Serially burning and pyrolyzing to produce shale oil from a subterranean oil shale |
| US3986557A (en) * | 1975-06-06 | 1976-10-19 | Atlantic Richfield Company | Production of bitumen from tar sands |
| US3950029A (en) * | 1975-06-12 | 1976-04-13 | Mobil Oil Corporation | In situ retorting of oil shale |
| US3993132A (en) | 1975-06-18 | 1976-11-23 | Texaco Exploration Canada Ltd. | Thermal recovery of hydrocarbons from tar sands |
| US4069868A (en) | 1975-07-14 | 1978-01-24 | In Situ Technology, Inc. | Methods of fluidized production of coal in situ |
| BE832017A (en) | 1975-07-31 | 1975-11-17 | NEW PROCESS FOR EXPLOITATION OF A COAL OR LIGNITE DEPOSIT BY UNDERGROUND GASING UNDER HIGH PRESSURE | |
| US4199024A (en) * | 1975-08-07 | 1980-04-22 | World Energy Systems | Multistage gas generator |
| US3954140A (en) | 1975-08-13 | 1976-05-04 | Hendrick Robert P | Recovery of hydrocarbons by in situ thermal extraction |
| US3986349A (en) | 1975-09-15 | 1976-10-19 | Chevron Research Company | Method of power generation via coal gasification and liquid hydrocarbon synthesis |
| US3994340A (en) | 1975-10-30 | 1976-11-30 | Chevron Research Company | Method of recovering viscous petroleum from tar sand |
| US3994341A (en) | 1975-10-30 | 1976-11-30 | Chevron Research Company | Recovering viscous petroleum from thick tar sand |
| US4087130A (en) | 1975-11-03 | 1978-05-02 | Occidental Petroleum Corporation | Process for the gasification of coal in situ |
| US4018280A (en) | 1975-12-10 | 1977-04-19 | Mobil Oil Corporation | Process for in situ retorting of oil shale |
| US3992474A (en) * | 1975-12-15 | 1976-11-16 | Uop Inc. | Motor fuel production with fluid catalytic cracking of high-boiling alkylate |
| US4019575A (en) | 1975-12-22 | 1977-04-26 | Chevron Research Company | System for recovering viscous petroleum from thick tar sand |
| US3999607A (en) | 1976-01-22 | 1976-12-28 | Exxon Research And Engineering Company | Recovery of hydrocarbons from coal |
| US4031956A (en) | 1976-02-12 | 1977-06-28 | In Situ Technology, Inc. | Method of recovering energy from subsurface petroleum reservoirs |
| US4008762A (en) | 1976-02-26 | 1977-02-22 | Fisher Sidney T | Extraction of hydrocarbons in situ from underground hydrocarbon deposits |
| US4010800A (en) | 1976-03-08 | 1977-03-08 | In Situ Technology, Inc. | Producing thin seams of coal in situ |
| US4048637A (en) | 1976-03-23 | 1977-09-13 | Westinghouse Electric Corporation | Radar system for detecting slowly moving targets |
| DE2615874B2 (en) | 1976-04-10 | 1978-10-19 | Deutsche Texaco Ag, 2000 Hamburg | Application of a method for extracting crude oil and bitumen from underground deposits by means of a combustion front in deposits of any content of intermediate hydrocarbons in the crude oil or bitumen |
| GB1544245A (en) | 1976-05-21 | 1979-04-19 | British Gas Corp | Production of substitute natural gas |
| US4049053A (en) | 1976-06-10 | 1977-09-20 | Fisher Sidney T | Recovery of hydrocarbons from partially exhausted oil wells by mechanical wave heating |
| US4193451A (en) | 1976-06-17 | 1980-03-18 | The Badger Company, Inc. | Method for production of organic products from kerogen |
| US4487257A (en) | 1976-06-17 | 1984-12-11 | Raytheon Company | Apparatus and method for production of organic products from kerogen |
| US4067390A (en) | 1976-07-06 | 1978-01-10 | Technology Application Services Corporation | Apparatus and method for the recovery of fuel products from subterranean deposits of carbonaceous matter using a plasma arc |
| US4057293A (en) | 1976-07-12 | 1977-11-08 | Garrett Donald E | Process for in situ conversion of coal or the like into oil and gas |
| US4043393A (en) | 1976-07-29 | 1977-08-23 | Fisher Sidney T | Extraction from underground coal deposits |
| US4091869A (en) | 1976-09-07 | 1978-05-30 | Exxon Production Research Company | In situ process for recovery of carbonaceous materials from subterranean deposits |
| US4065183A (en) * | 1976-11-15 | 1977-12-27 | Trw Inc. | Recovery system for oil shale deposits |
| US4083604A (en) * | 1976-11-15 | 1978-04-11 | Trw Inc. | Thermomechanical fracture for recovery system in oil shale deposits |
| US4064943A (en) | 1976-12-06 | 1977-12-27 | Shell Oil Co | Plugging permeable earth formation with wax |
| US4084637A (en) | 1976-12-16 | 1978-04-18 | Petro Canada Exploration Inc. | Method of producing viscous materials from subterranean formations |
| US4089374A (en) | 1976-12-16 | 1978-05-16 | In Situ Technology, Inc. | Producing methane from coal in situ |
| US4093026A (en) | 1977-01-17 | 1978-06-06 | Occidental Oil Shale, Inc. | Removal of sulfur dioxide from process gas using treated oil shale and water |
| DE2705129C3 (en) | 1977-02-08 | 1979-11-15 | Deutsche Texaco Ag, 2000 Hamburg | Seismic procedure to control underground processes |
| US4277416A (en) | 1977-02-17 | 1981-07-07 | Aminoil, Usa, Inc. | Process for producing methanol |
| US4151877A (en) * | 1977-05-13 | 1979-05-01 | Occidental Oil Shale, Inc. | Determining the locus of a processing zone in a retort through channels |
| US4099567A (en) | 1977-05-27 | 1978-07-11 | In Situ Technology, Inc. | Generating medium BTU gas from coal in situ |
| US4169506A (en) | 1977-07-15 | 1979-10-02 | Standard Oil Company (Indiana) | In situ retorting of oil shale and energy recovery |
| US4140180A (en) | 1977-08-29 | 1979-02-20 | Iit Research Institute | Method for in situ heat processing of hydrocarbonaceous formations |
| US4144935A (en) | 1977-08-29 | 1979-03-20 | Iit Research Institute | Apparatus and method for in situ heat processing of hydrocarbonaceous formations |
| NL181941C (en) | 1977-09-16 | 1987-12-01 | Ir Arnold Willem Josephus Grup | METHOD FOR UNDERGROUND GASULATION OF COAL OR BROWN. |
| US4125159A (en) | 1977-10-17 | 1978-11-14 | Vann Roy Randell | Method and apparatus for isolating and treating subsurface stratas |
| SU915451A1 (en) * | 1977-10-21 | 1988-08-23 | Vnii Ispolzovania | Method of underground gasification of fuel |
| US4119349A (en) * | 1977-10-25 | 1978-10-10 | Gulf Oil Corporation | Method and apparatus for recovery of fluids produced in in-situ retorting of oil shale |
| US4114688A (en) | 1977-12-05 | 1978-09-19 | In Situ Technology Inc. | Minimizing environmental effects in production and use of coal |
| US4158467A (en) | 1977-12-30 | 1979-06-19 | Gulf Oil Corporation | Process for recovering shale oil |
| US4148359A (en) | 1978-01-30 | 1979-04-10 | Shell Oil Company | Pressure-balanced oil recovery process for water productive oil shale |
| DE2812490A1 (en) | 1978-03-22 | 1979-09-27 | Texaco Ag | PROCEDURE FOR DETERMINING THE SPATIAL EXTENSION OF SUBSEQUENT REACTIONS |
| US4162707A (en) * | 1978-04-20 | 1979-07-31 | Mobil Oil Corporation | Method of treating formation to remove ammonium ions |
| US4160479A (en) | 1978-04-24 | 1979-07-10 | Richardson Reginald D | Heavy oil recovery process |
| US4197911A (en) | 1978-05-09 | 1980-04-15 | Ramcor, Inc. | Process for in situ coal gasification |
| US4228853A (en) | 1978-06-21 | 1980-10-21 | Harvey A Herbert | Petroleum production method |
| US4186801A (en) | 1978-12-18 | 1980-02-05 | Gulf Research And Development Company | In situ combustion process for the recovery of liquid carbonaceous fuels from subterranean formations |
| US4185692A (en) | 1978-07-14 | 1980-01-29 | In Situ Technology, Inc. | Underground linkage of wells for production of coal in situ |
| US4167213A (en) * | 1978-07-17 | 1979-09-11 | Standard Oil Company (Indiana) | Method for determining the position and inclination of a flame front during in situ combustion of a rubbled oil shale retort |
| US4184548A (en) | 1978-07-17 | 1980-01-22 | Standard Oil Company (Indiana) | Method for determining the position and inclination of a flame front during in situ combustion of an oil shale retort |
| US4183405A (en) | 1978-10-02 | 1980-01-15 | Magnie Robert L | Enhanced recoveries of petroleum and hydrogen from underground reservoirs |
| US4446917A (en) * | 1978-10-04 | 1984-05-08 | Todd John C | Method and apparatus for producing viscous or waxy crude oils |
| US4311340A (en) | 1978-11-27 | 1982-01-19 | Lyons William C | Uranium leeching process and insitu mining |
| US4457365A (en) | 1978-12-07 | 1984-07-03 | Raytheon Company | In situ radio frequency selective heating system |
| US4299086A (en) | 1978-12-07 | 1981-11-10 | Gulf Research & Development Company | Utilization of energy obtained by substoichiometric combustion of low heating value gases |
| US4265307A (en) | 1978-12-20 | 1981-05-05 | Standard Oil Company | Shale oil recovery |
| US4194562A (en) | 1978-12-21 | 1980-03-25 | Texaco Inc. | Method for preconditioning a subterranean oil-bearing formation prior to in-situ combustion |
| US4274487A (en) | 1979-01-11 | 1981-06-23 | Standard Oil Company (Indiana) | Indirect thermal stimulation of production wells |
| US4232902A (en) | 1979-02-09 | 1980-11-11 | Ppg Industries, Inc. | Solution mining water soluble salts at high temperatures |
| US4324292A (en) | 1979-02-21 | 1982-04-13 | University Of Utah | Process for recovering products from oil shale |
| US4260192A (en) * | 1979-02-21 | 1981-04-07 | Occidental Research Corporation | Recovery of magnesia from oil shale |
| US4289354A (en) | 1979-02-23 | 1981-09-15 | Edwin G. Higgins, Jr. | Borehole mining of solid mineral resources |
| US4243511A (en) * | 1979-03-26 | 1981-01-06 | Marathon Oil Company | Process for suppressing carbonate decomposition in vapor phase water retorting |
| US4248306A (en) * | 1979-04-02 | 1981-02-03 | Huisen Allan T Van | Geothermal petroleum refining |
| US4282587A (en) | 1979-05-21 | 1981-08-04 | Daniel Silverman | Method for monitoring the recovery of minerals from shallow geological formations |
| US4234230A (en) * | 1979-07-11 | 1980-11-18 | The Superior Oil Company | In situ processing of mined oil shale |
| US4290650A (en) | 1979-08-03 | 1981-09-22 | Ppg Industries Canada Ltd. | Subterranean cavity chimney development for connecting solution mined cavities |
| US4228854A (en) | 1979-08-13 | 1980-10-21 | Alberta Research Council | Enhanced oil recovery using electrical means |
| US4701587A (en) | 1979-08-31 | 1987-10-20 | Metcal, Inc. | Shielded heating element having intrinsic temperature control |
| US4256945A (en) * | 1979-08-31 | 1981-03-17 | Iris Associates | Alternating current electrically resistive heating element having intrinsic temperature control |
| US4327805A (en) | 1979-09-18 | 1982-05-04 | Carmel Energy, Inc. | Method for producing viscous hydrocarbons |
| US4549396A (en) | 1979-10-01 | 1985-10-29 | Mobil Oil Corporation | Conversion of coal to electricity |
| US4250230A (en) | 1979-12-10 | 1981-02-10 | In Situ Technology, Inc. | Generating electricity from coal in situ |
| US4250962A (en) | 1979-12-14 | 1981-02-17 | Gulf Research & Development Company | In situ combustion process for the recovery of liquid carbonaceous fuels from subterranean formations |
| US4260018A (en) | 1979-12-19 | 1981-04-07 | Texaco Inc. | Method for steam injection in steeply dipping formations |
| US4359687A (en) | 1980-01-25 | 1982-11-16 | Shell Oil Company | Method and apparatus for determining shaliness and oil saturations in earth formations using induced polarization in the frequency domain |
| US4398151A (en) | 1980-01-25 | 1983-08-09 | Shell Oil Company | Method for correcting an electrical log for the presence of shale in a formation |
| US4285547A (en) * | 1980-02-01 | 1981-08-25 | Multi Mineral Corporation | Integrated in situ shale oil and mineral recovery process |
| USRE30738E (en) | 1980-02-06 | 1981-09-08 | Iit Research Institute | Apparatus and method for in situ heat processing of hydrocarbonaceous formations |
| US4303126A (en) * | 1980-02-27 | 1981-12-01 | Chevron Research Company | Arrangement of wells for producing subsurface viscous petroleum |
| US4319635A (en) * | 1980-02-29 | 1982-03-16 | P. H. Jones Hydrogeology, Inc. | Method for enhanced oil recovery by geopressured waterflood |
| US4375302A (en) | 1980-03-03 | 1983-03-01 | Nicholas Kalmar | Process for the in situ recovery of both petroleum and inorganic mineral content of an oil shale deposit |
| US4502010A (en) | 1980-03-17 | 1985-02-26 | Gearhart Industries, Inc. | Apparatus including a magnetometer having a pair of U-shaped cores for extended lateral range electrical conductivity logging |
| US4323848A (en) | 1980-03-17 | 1982-04-06 | Cornell Research Foundation, Inc. | Plural sensor magnetometer arrangement for extended lateral range electrical conductivity logging |
| US4445574A (en) * | 1980-03-24 | 1984-05-01 | Geo Vann, Inc. | Continuous borehole formed horizontally through a hydrocarbon producing formation |
| US4417782A (en) | 1980-03-31 | 1983-11-29 | Raychem Corporation | Fiber optic temperature sensing |
| CA1168283A (en) | 1980-04-14 | 1984-05-29 | Hiroshi Teratani | Electrode device for electrically heating underground deposits of hydrocarbons |
| US4273188A (en) | 1980-04-30 | 1981-06-16 | Gulf Research & Development Company | In situ combustion process for the recovery of liquid carbonaceous fuels from subterranean formations |
| US4306621A (en) | 1980-05-23 | 1981-12-22 | Boyd R Michael | Method for in situ coal gasification operations |
| US4409090A (en) | 1980-06-02 | 1983-10-11 | University Of Utah | Process for recovering products from tar sand |
| CA1165361A (en) | 1980-06-03 | 1984-04-10 | Toshiyuki Kobayashi | Electrode unit for electrically heating underground hydrocarbon deposits |
| US4381641A (en) | 1980-06-23 | 1983-05-03 | Gulf Research & Development Company | Substoichiometric combustion of low heating value gases |
| US4401099A (en) * | 1980-07-11 | 1983-08-30 | W.B. Combustion, Inc. | Single-ended recuperative radiant tube assembly and method |
| US4299285A (en) | 1980-07-21 | 1981-11-10 | Gulf Research & Development Company | Underground gasification of bituminous coal |
| US4396062A (en) | 1980-10-06 | 1983-08-02 | University Of Utah Research Foundation | Apparatus and method for time-domain tracking of high-speed chemical reactions |
| FR2491945B1 (en) | 1980-10-13 | 1985-08-23 | Ledent Pierre | PROCESS FOR PRODUCING A HIGH HYDROGEN GAS BY SUBTERRANEAN COAL GASIFICATION |
| US4353418A (en) | 1980-10-20 | 1982-10-12 | Standard Oil Company (Indiana) | In situ retorting of oil shale |
| US4384613A (en) | 1980-10-24 | 1983-05-24 | Terra Tek, Inc. | Method of in-situ retorting of carbonaceous material for recovery of organic liquids and gases |
| US4372398A (en) | 1980-11-04 | 1983-02-08 | Cornell Research Foundation, Inc. | Method of determining the location of a deep-well casing by magnetic field sensing |
| US4366864A (en) | 1980-11-24 | 1983-01-04 | Exxon Research And Engineering Co. | Method for recovery of hydrocarbons from oil-bearing limestone or dolomite |
| US4401163A (en) | 1980-12-29 | 1983-08-30 | The Standard Oil Company | Modified in situ retorting of oil shale |
| US4385661A (en) * | 1981-01-07 | 1983-05-31 | The United States Of America As Represented By The United States Department Of Energy | Downhole steam generator with improved preheating, combustion and protection features |
| US4448251A (en) | 1981-01-08 | 1984-05-15 | Uop Inc. | In situ conversion of hydrocarbonaceous oil |
| US4423311A (en) | 1981-01-19 | 1983-12-27 | Varney Sr Paul | Electric heating apparatus for de-icing pipes |
| US4333764A (en) * | 1981-01-21 | 1982-06-08 | Shell Oil Company | Nitrogen-gas-stabilized cement and a process for making and using it |
| US4366668A (en) | 1981-02-25 | 1983-01-04 | Gulf Research & Development Company | Substoichiometric combustion of low heating value gases |
| US4363361A (en) | 1981-03-19 | 1982-12-14 | Gulf Research & Development Company | Substoichiometric combustion of low heating value gases |
| US4390067A (en) | 1981-04-06 | 1983-06-28 | Exxon Production Research Co. | Method of treating reservoirs containing very viscous crude oil or bitumen |
| US4399866A (en) | 1981-04-10 | 1983-08-23 | Atlantic Richfield Company | Method for controlling the flow of subterranean water into a selected zone in a permeable subterranean carbonaceous deposit |
| US4444255A (en) | 1981-04-20 | 1984-04-24 | Lloyd Geoffrey | Apparatus and process for the recovery of oil |
| US4380930A (en) | 1981-05-01 | 1983-04-26 | Mobil Oil Corporation | System for transmitting ultrasonic energy through core samples |
| US4429745A (en) | 1981-05-08 | 1984-02-07 | Mobil Oil Corporation | Oil recovery method |
| US4378048A (en) | 1981-05-08 | 1983-03-29 | Gulf Research & Development Company | Substoichiometric combustion of low heating value gases using different platinum catalysts |
| US4384614A (en) | 1981-05-11 | 1983-05-24 | Justheim Pertroleum Company | Method of retorting oil shale by velocity flow of super-heated air |
| US4384948A (en) | 1981-05-13 | 1983-05-24 | Ashland Oil, Inc. | Single unit RCC |
| US4437519A (en) | 1981-06-03 | 1984-03-20 | Occidental Oil Shale, Inc. | Reduction of shale oil pour point |
| US4443762A (en) | 1981-06-12 | 1984-04-17 | Cornell Research Foundation, Inc. | Method and apparatus for detecting the direction and distance to a target well casing |
| US4463807A (en) | 1981-06-15 | 1984-08-07 | In Situ Technology, Inc. | Minimizing subsidence effects during production of coal in situ |
| US4448252A (en) | 1981-06-15 | 1984-05-15 | In Situ Technology, Inc. | Minimizing subsidence effects during production of coal in situ |
| US4428700A (en) | 1981-08-03 | 1984-01-31 | E. R. Johnson Associates, Inc. | Method for disposing of waste materials |
| US4456065A (en) | 1981-08-20 | 1984-06-26 | Elektra Energie A.G. | Heavy oil recovering |
| US4344483A (en) | 1981-09-08 | 1982-08-17 | Fisher Charles B | Multiple-site underground magnetic heating of hydrocarbons |
| US4452491A (en) | 1981-09-25 | 1984-06-05 | Intercontinental Econergy Associates, Inc. | Recovery of hydrocarbons from deep underground deposits of tar sands |
| US4425967A (en) | 1981-10-07 | 1984-01-17 | Standard Oil Company (Indiana) | Ignition procedure and process for in situ retorting of oil shale |
| US4605680A (en) | 1981-10-13 | 1986-08-12 | Chevron Research Company | Conversion of synthesis gas to diesel fuel and gasoline |
| US4401162A (en) | 1981-10-13 | 1983-08-30 | Synfuel (An Indiana Limited Partnership) | In situ oil shale process |
| US4410042A (en) | 1981-11-02 | 1983-10-18 | Mobil Oil Corporation | In-situ combustion method for recovery of heavy oil utilizing oxygen and carbon dioxide as initial oxidant |
| US4444258A (en) | 1981-11-10 | 1984-04-24 | Nicholas Kalmar | In situ recovery of oil from oil shale |
| US4418752A (en) * | 1982-01-07 | 1983-12-06 | Conoco Inc. | Thermal oil recovery with solvent recirculation |
| FR2519688A1 (en) | 1982-01-08 | 1983-07-18 | Elf Aquitaine | SEALING SYSTEM FOR DRILLING WELLS IN WHICH CIRCULATES A HOT FLUID |
| DE3202492C2 (en) | 1982-01-27 | 1983-12-01 | Veba Oel Entwicklungsgesellschaft mbH, 4660 Gelsenkirchen-Buer | Process for increasing the yield of hydrocarbons from a subterranean formation |
| US4397732A (en) | 1982-02-11 | 1983-08-09 | International Coal Refining Company | Process for coal liquefaction employing selective coal feed |
| US4476927A (en) | 1982-03-31 | 1984-10-16 | Mobil Oil Corporation | Method for controlling H2 /CO ratio of in-situ coal gasification product gas |
| US4530401A (en) | 1982-04-05 | 1985-07-23 | Mobil Oil Corporation | Method for maximum in-situ visbreaking of heavy oil |
| CA1196594A (en) | 1982-04-08 | 1985-11-12 | Guy Savard | Recovery of oil from tar sands |
| US4537252A (en) | 1982-04-23 | 1985-08-27 | Standard Oil Company (Indiana) | Method of underground conversion of coal |
| US4491179A (en) | 1982-04-26 | 1985-01-01 | Pirson Sylvain J | Method for oil recovery by in situ exfoliation drive |
| US4455215A (en) | 1982-04-29 | 1984-06-19 | Jarrott David M | Process for the geoconversion of coal into oil |
| US4412585A (en) | 1982-05-03 | 1983-11-01 | Cities Service Company | Electrothermal process for recovering hydrocarbons |
| US4415034A (en) * | 1982-05-03 | 1983-11-15 | Cities Service Company | Electrode well completion |
| US4524826A (en) | 1982-06-14 | 1985-06-25 | Texaco Inc. | Method of heating an oil shale formation |
| US4457374A (en) | 1982-06-29 | 1984-07-03 | Standard Oil Company | Transient response process for detecting in situ retorting conditions |
| US4442896A (en) * | 1982-07-21 | 1984-04-17 | Reale Lucio V | Treatment of underground beds |
| US4407973A (en) | 1982-07-28 | 1983-10-04 | The M. W. Kellogg Company | Methanol from coal and natural gas |
| US4931171A (en) | 1982-08-03 | 1990-06-05 | Phillips Petroleum Company | Pyrolysis of carbonaceous materials |
| US4479541A (en) | 1982-08-23 | 1984-10-30 | Wang Fun Den | Method and apparatus for recovery of oil, gas and mineral deposits by panel opening |
| US4460044A (en) | 1982-08-31 | 1984-07-17 | Chevron Research Company | Advancing heated annulus steam drive |
| US4544478A (en) * | 1982-09-03 | 1985-10-01 | Chevron Research Company | Process for pyrolyzing hydrocarbonaceous solids to recover volatile hydrocarbons |
| US4458767A (en) | 1982-09-28 | 1984-07-10 | Mobil Oil Corporation | Method for directionally drilling a first well to intersect a second well |
| US4695713A (en) | 1982-09-30 | 1987-09-22 | Metcal, Inc. | Autoregulating, electrically shielded heater |
| US4927857A (en) | 1982-09-30 | 1990-05-22 | Engelhard Corporation | Method of methanol production |
| US4498531A (en) * | 1982-10-01 | 1985-02-12 | Rockwell International Corporation | Emission controller for indirect fired downhole steam generators |
| US4485869A (en) | 1982-10-22 | 1984-12-04 | Iit Research Institute | Recovery of liquid hydrocarbons from oil shale by electromagnetic heating in situ |
| ATE21340T1 (en) | 1982-11-22 | 1986-08-15 | Shell Int Research | PROCESS FOR THE MANUFACTURE OF A FISCHER-TROPSCH CATALYST, THE CATALYST MANUFACTURED IN THIS WAY AND ITS USE IN THE MANUFACTURE OF HYDROCARBONS. |
| US4498535A (en) | 1982-11-30 | 1985-02-12 | Iit Research Institute | Apparatus and method for in situ controlled heat processing of hydrocarbonaceous formations with a controlled parameter line |
| US4474238A (en) * | 1982-11-30 | 1984-10-02 | Phillips Petroleum Company | Method and apparatus for treatment of subsurface formations |
| US4752673A (en) | 1982-12-01 | 1988-06-21 | Metcal, Inc. | Autoregulating heater |
| US4529939A (en) | 1983-01-10 | 1985-07-16 | Kuckes Arthur F | System located in drill string for well logging while drilling |
| US4483398A (en) | 1983-01-14 | 1984-11-20 | Exxon Production Research Co. | In-situ retorting of oil shale |
| US4501326A (en) | 1983-01-17 | 1985-02-26 | Gulf Canada Limited | In-situ recovery of viscous hydrocarbonaceous crude oil |
| US4609041A (en) * | 1983-02-10 | 1986-09-02 | Magda Richard M | Well hot oil system |
| US4640352A (en) | 1983-03-21 | 1987-02-03 | Shell Oil Company | In-situ steam drive oil recovery process |
| US4886118A (en) * | 1983-03-21 | 1989-12-12 | Shell Oil Company | Conductively heating a subterranean oil shale to create permeability and subsequently produce oil |
| US4458757A (en) | 1983-04-25 | 1984-07-10 | Exxon Research And Engineering Co. | In situ shale-oil recovery process |
| US4524827A (en) | 1983-04-29 | 1985-06-25 | Iit Research Institute | Single well stimulation for the recovery of liquid hydrocarbons from subsurface formations |
| US4545435A (en) | 1983-04-29 | 1985-10-08 | Iit Research Institute | Conduction heating of hydrocarbonaceous formations |
| US4518548A (en) | 1983-05-02 | 1985-05-21 | Sulcon, Inc. | Method of overlaying sulphur concrete on horizontal and vertical surfaces |
| US5073625A (en) | 1983-05-26 | 1991-12-17 | Metcal, Inc. | Self-regulating porous heating device |
| US4794226A (en) | 1983-05-26 | 1988-12-27 | Metcal, Inc. | Self-regulating porous heater device |
| EP0130671A3 (en) * | 1983-05-26 | 1986-12-17 | Metcal Inc. | Multiple temperature autoregulating heater |
| DE3319732A1 (en) | 1983-05-31 | 1984-12-06 | Kraftwerk Union AG, 4330 Mülheim | MEDIUM-POWER PLANT WITH INTEGRATED COAL GASIFICATION SYSTEM FOR GENERATING ELECTRICITY AND METHANOL |
| US4583046A (en) | 1983-06-20 | 1986-04-15 | Shell Oil Company | Apparatus for focused electrode induced polarization logging |
| US4658215A (en) | 1983-06-20 | 1987-04-14 | Shell Oil Company | Method for induced polarization logging |
| US4717814A (en) | 1983-06-27 | 1988-01-05 | Metcal, Inc. | Slotted autoregulating heater |
| US4439307A (en) * | 1983-07-01 | 1984-03-27 | Dravo Corporation | Heating process gas for indirect shale oil retorting through the combustion of residual carbon in oil depleted shale |
| US4524113A (en) | 1983-07-05 | 1985-06-18 | United Technologies Corporation | Direct use of methanol fuel in a molten carbonate fuel cell |
| US4985313A (en) | 1985-01-14 | 1991-01-15 | Raychem Limited | Wire and cable |
| US5209987A (en) | 1983-07-08 | 1993-05-11 | Raychem Limited | Wire and cable |
| US4598392A (en) | 1983-07-26 | 1986-07-01 | Mobil Oil Corporation | Vibratory signal sweep seismic prospecting method and apparatus |
| US4501445A (en) | 1983-08-01 | 1985-02-26 | Cities Service Company | Method of in-situ hydrogenation of carbonaceous material |
| US4538682A (en) * | 1983-09-08 | 1985-09-03 | Mcmanus James W | Method and apparatus for removing oil well paraffin |
| IN161735B (en) | 1983-09-12 | 1988-01-30 | Shell Int Research | |
| US4573530A (en) | 1983-11-07 | 1986-03-04 | Mobil Oil Corporation | In-situ gasification of tar sands utilizing a combustible gas |
| US4489782A (en) | 1983-12-12 | 1984-12-25 | Atlantic Richfield Company | Viscous oil production using electrical current heating and lateral drain holes |
| US4598772A (en) * | 1983-12-28 | 1986-07-08 | Mobil Oil Corporation | Method for operating a production well in an oxygen driven in-situ combustion oil recovery process |
| US4540882A (en) | 1983-12-29 | 1985-09-10 | Shell Oil Company | Method of determining drilling fluid invasion |
| US4571491A (en) | 1983-12-29 | 1986-02-18 | Shell Oil Company | Method of imaging the atomic number of a sample |
| US4635197A (en) | 1983-12-29 | 1987-01-06 | Shell Oil Company | High resolution tomographic imaging method |
| US4542648A (en) | 1983-12-29 | 1985-09-24 | Shell Oil Company | Method of correlating a core sample with its original position in a borehole |
| US4613754A (en) | 1983-12-29 | 1986-09-23 | Shell Oil Company | Tomographic calibration apparatus |
| US4583242A (en) | 1983-12-29 | 1986-04-15 | Shell Oil Company | Apparatus for positioning a sample in a computerized axial tomographic scanner |
| US4662439A (en) | 1984-01-20 | 1987-05-05 | Amoco Corporation | Method of underground conversion of coal |
| US4623401A (en) | 1984-03-06 | 1986-11-18 | Metcal, Inc. | Heat treatment with an autoregulating heater |
| US4644283A (en) | 1984-03-19 | 1987-02-17 | Shell Oil Company | In-situ method for determining pore size distribution, capillary pressure and permeability |
| US4637464A (en) | 1984-03-22 | 1987-01-20 | Amoco Corporation | In situ retorting of oil shale with pulsed water purge |
| US4552214A (en) | 1984-03-22 | 1985-11-12 | Standard Oil Company (Indiana) | Pulsed in situ retorting in an array of oil shale retorts |
| US4570715A (en) | 1984-04-06 | 1986-02-18 | Shell Oil Company | Formation-tailored method and apparatus for uniformly heating long subterranean intervals at high temperature |
| US4577690A (en) | 1984-04-18 | 1986-03-25 | Mobil Oil Corporation | Method of using seismic data to monitor firefloods |
| US5055180A (en) | 1984-04-20 | 1991-10-08 | Electromagnetic Energy Corporation | Method and apparatus for recovering fractions from hydrocarbon materials, facilitating the removal and cleansing of hydrocarbon fluids, insulating storage vessels, and cleansing storage vessels and pipelines |
| US4592423A (en) | 1984-05-14 | 1986-06-03 | Texaco Inc. | Hydrocarbon stratum retorting means and method |
| US4597441A (en) | 1984-05-25 | 1986-07-01 | World Energy Systems, Inc. | Recovery of oil by in situ hydrogenation |
| US4663711A (en) | 1984-06-22 | 1987-05-05 | Shell Oil Company | Method of analyzing fluid saturation using computerized axial tomography |
| US4577503A (en) | 1984-09-04 | 1986-03-25 | International Business Machines Corporation | Method and device for detecting a specific acoustic spectral feature |
| US4576231A (en) | 1984-09-13 | 1986-03-18 | Texaco Inc. | Method and apparatus for combating encroachment by in situ treated formations |
| US4597444A (en) | 1984-09-21 | 1986-07-01 | Atlantic Richfield Company | Method for excavating a large diameter shaft into the earth and at least partially through an oil-bearing formation |
| US4691771A (en) | 1984-09-25 | 1987-09-08 | Worldenergy Systems, Inc. | Recovery of oil by in-situ combustion followed by in-situ hydrogenation |
| US4616705A (en) * | 1984-10-05 | 1986-10-14 | Shell Oil Company | Mini-well temperature profiling process |
| US4598770A (en) | 1984-10-25 | 1986-07-08 | Mobil Oil Corporation | Thermal recovery method for viscous oil |
| US4572299A (en) | 1984-10-30 | 1986-02-25 | Shell Oil Company | Heater cable installation |
| US4634187A (en) * | 1984-11-21 | 1987-01-06 | Isl Ventures, Inc. | Method of in-situ leaching of ores |
| US4669542A (en) | 1984-11-21 | 1987-06-02 | Mobil Oil Corporation | Simultaneous recovery of crude from multiple zones in a reservoir |
| US4585066A (en) | 1984-11-30 | 1986-04-29 | Shell Oil Company | Well treating process for installing a cable bundle containing strands of changing diameter |
| US4704514A (en) | 1985-01-11 | 1987-11-03 | Egmond Cor F Van | Heating rate variant elongated electrical resistance heater |
| US4645906A (en) | 1985-03-04 | 1987-02-24 | Thermon Manufacturing Company | Reduced resistance skin effect heat generating system |
| US4698583A (en) | 1985-03-26 | 1987-10-06 | Raychem Corporation | Method of monitoring a heater for faults |
| US4785163A (en) | 1985-03-26 | 1988-11-15 | Raychem Corporation | Method for monitoring a heater |
| US4670634A (en) | 1985-04-05 | 1987-06-02 | Iit Research Institute | In situ decontamination of spills and landfills by radio frequency heating |
| EP0199566A3 (en) | 1985-04-19 | 1987-08-26 | RAYCHEM GmbH | Sheet heater |
| US4671102A (en) | 1985-06-18 | 1987-06-09 | Shell Oil Company | Method and apparatus for determining distribution of fluids |
| US4626665A (en) | 1985-06-24 | 1986-12-02 | Shell Oil Company | Metal oversheathed electrical resistance heater |
| US4623444A (en) | 1985-06-27 | 1986-11-18 | Occidental Oil Shale, Inc. | Upgrading shale oil by a combination process |
| US4605489A (en) | 1985-06-27 | 1986-08-12 | Occidental Oil Shale, Inc. | Upgrading shale oil by a combination process |
| US4662438A (en) | 1985-07-19 | 1987-05-05 | Uentech Corporation | Method and apparatus for enhancing liquid hydrocarbon production from a single borehole in a slowly producing formation by non-uniform heating through optimized electrode arrays surrounding the borehole |
| US4719423A (en) | 1985-08-13 | 1988-01-12 | Shell Oil Company | NMR imaging of materials for transport properties |
| US4728892A (en) | 1985-08-13 | 1988-03-01 | Shell Oil Company | NMR imaging of materials |
| US4778586A (en) | 1985-08-30 | 1988-10-18 | Resource Technology Associates | Viscosity reduction processing at elevated pressure |
| US4683947A (en) | 1985-09-05 | 1987-08-04 | Air Products And Chemicals Inc. | Process and apparatus for monitoring and controlling the flammability of gas from an in-situ combustion oil recovery project |
| US4662437A (en) | 1985-11-14 | 1987-05-05 | Atlantic Richfield Company | Electrically stimulated well production system with flexible tubing conductor |
| CA1253555A (en) | 1985-11-21 | 1989-05-02 | Cornelis F.H. Van Egmond | Heating rate variant elongated electrical resistance heater |
| US4662443A (en) | 1985-12-05 | 1987-05-05 | Amoco Corporation | Combination air-blown and oxygen-blown underground coal gasification process |
| US4849611A (en) | 1985-12-16 | 1989-07-18 | Raychem Corporation | Self-regulating heater employing reactive components |
| US4730162A (en) | 1985-12-31 | 1988-03-08 | Shell Oil Company | Time-domain induced polarization logging method and apparatus with gated amplification level |
| US4706751A (en) | 1986-01-31 | 1987-11-17 | S-Cal Research Corp. | Heavy oil recovery process |
| US4694907A (en) | 1986-02-21 | 1987-09-22 | Carbotek, Inc. | Thermally-enhanced oil recovery method and apparatus |
| US4640353A (en) | 1986-03-21 | 1987-02-03 | Atlantic Richfield Company | Electrode well and method of completion |
| US4734115A (en) | 1986-03-24 | 1988-03-29 | Air Products And Chemicals, Inc. | Low pressure process for C3+ liquids recovery from process product gas |
| US4700142A (en) | 1986-04-04 | 1987-10-13 | Vector Magnetics, Inc. | Method for determining the location of a deep-well casing by magnetic field sensing |
| US4651825A (en) | 1986-05-09 | 1987-03-24 | Atlantic Richfield Company | Enhanced well production |
| US4702758A (en) | 1986-05-29 | 1987-10-27 | Shell Western E&P Inc. | Turbine cooling waxy oil |
| US4814587A (en) | 1986-06-10 | 1989-03-21 | Metcal, Inc. | High power self-regulating heater |
| US4682652A (en) | 1986-06-30 | 1987-07-28 | Texaco Inc. | Producing hydrocarbons through successively perforated intervals of a horizontal well between two vertical wells |
| US4893504A (en) | 1986-07-02 | 1990-01-16 | Shell Oil Company | Method for determining capillary pressure and relative permeability by imaging |
| US4769602A (en) | 1986-07-02 | 1988-09-06 | Shell Oil Company | Determining multiphase saturations by NMR imaging of multiple nuclides |
| US4716960A (en) | 1986-07-14 | 1988-01-05 | Production Technologies International, Inc. | Method and system for introducing electric current into a well |
| US4818370A (en) | 1986-07-23 | 1989-04-04 | Cities Service Oil And Gas Corporation | Process for converting heavy crudes, tars, and bitumens to lighter products in the presence of brine at supercritical conditions |
| US4849360A (en) * | 1986-07-30 | 1989-07-18 | International Technology Corporation | Apparatus and method for confining and decontaminating soil |
| US4772634A (en) | 1986-07-31 | 1988-09-20 | Energy Research Corporation | Apparatus and method for methanol production using a fuel cell to regulate the gas composition entering the methanol synthesizer |
| US4744245A (en) | 1986-08-12 | 1988-05-17 | Atlantic Richfield Company | Acoustic measurements in rock formations for determining fracture orientation |
| US4696345A (en) | 1986-08-21 | 1987-09-29 | Chevron Research Company | Hasdrive with multiple offset producers |
| US4728412A (en) | 1986-09-19 | 1988-03-01 | Amoco Corporation | Pour-point depression of crude oils by addition of tar sand bitumen |
| US4769606A (en) | 1986-09-30 | 1988-09-06 | Shell Oil Company | Induced polarization method and apparatus for distinguishing dispersed and laminated clay in earth formations |
| US4791373A (en) | 1986-10-08 | 1988-12-13 | Kuckes Arthur F | Subterranean target location by measurement of time-varying magnetic field vector in borehole |
| US4737267A (en) | 1986-11-12 | 1988-04-12 | Duo-Ex Coproration | Oil shale processing apparatus and method |
| US5340467A (en) | 1986-11-24 | 1994-08-23 | Canadian Occidental Petroleum Ltd. | Process for recovery of hydrocarbons and rejection of sand |
| US4983319A (en) | 1986-11-24 | 1991-01-08 | Canadian Occidental Petroleum Ltd. | Preparation of low-viscosity improved stable crude oil transport emulsions |
| US5316664A (en) | 1986-11-24 | 1994-05-31 | Canadian Occidental Petroleum, Ltd. | Process for recovery of hydrocarbons and rejection of sand |
| CA1288043C (en) | 1986-12-15 | 1991-08-27 | Peter Van Meurs | Conductively heating a subterranean oil shale to create permeabilityand subsequently produce oil |
| US4831600A (en) * | 1986-12-31 | 1989-05-16 | Schlumberger Technology Corporation | Borehole logging method for fracture detection and evaluation |
| US4766958A (en) * | 1987-01-12 | 1988-08-30 | Mobil Oil Corporation | Method of recovering viscous oil from reservoirs with multiple horizontal zones |
| US4793656A (en) | 1987-02-12 | 1988-12-27 | Shell Mining Company | In-situ coal drying |
| US4756367A (en) | 1987-04-28 | 1988-07-12 | Amoco Corporation | Method for producing natural gas from a coal seam |
| US4817711A (en) | 1987-05-27 | 1989-04-04 | Jeambey Calhoun G | System for recovery of petroleum from petroleum impregnated media |
| US4818371A (en) * | 1987-06-05 | 1989-04-04 | Resource Technology Associates | Viscosity reduction by direct oxidative heating |
| US4787452A (en) | 1987-06-08 | 1988-11-29 | Mobil Oil Corporation | Disposal of produced formation fines during oil recovery |
| US4821798A (en) * | 1987-06-09 | 1989-04-18 | Ors Development Corporation | Heating system for rathole oil well |
| US4856341A (en) | 1987-06-25 | 1989-08-15 | Shell Oil Company | Apparatus for analysis of failure of material |
| US4884455A (en) | 1987-06-25 | 1989-12-05 | Shell Oil Company | Method for analysis of failure of material employing imaging |
| US4827761A (en) | 1987-06-25 | 1989-05-09 | Shell Oil Company | Sample holder |
| US4776638A (en) | 1987-07-13 | 1988-10-11 | University Of Kentucky Research Foundation | Method and apparatus for conversion of coal in situ |
| US4848924A (en) | 1987-08-19 | 1989-07-18 | The Babcock & Wilcox Company | Acoustic pyrometer |
| CA1254505A (en) | 1987-10-02 | 1989-05-23 | Ion I. Adamache | Exploitation method for reservoirs containing hydrogen sulphide |
| US4828031A (en) * | 1987-10-13 | 1989-05-09 | Chevron Research Company | In situ chemical stimulation of diatomite formations |
| US4762425A (en) | 1987-10-15 | 1988-08-09 | Parthasarathy Shakkottai | System for temperature profile measurement in large furnances and kilns and method therefor |
| US4815791A (en) * | 1987-10-22 | 1989-03-28 | The United States Of America As Represented By The Secretary Of The Interior | Bedded mineral extraction process |
| US5306640A (en) | 1987-10-28 | 1994-04-26 | Shell Oil Company | Method for determining preselected properties of a crude oil |
| US4987368A (en) | 1987-11-05 | 1991-01-22 | Shell Oil Company | Nuclear magnetism logging tool using high-temperature superconducting squid detectors |
| US4842448A (en) | 1987-11-12 | 1989-06-27 | Drexel University | Method of removing contaminants from contaminated soil in situ |
| US4808925A (en) * | 1987-11-19 | 1989-02-28 | Halliburton Company | Three magnet casing collar locator |
| US4845434A (en) | 1988-01-22 | 1989-07-04 | Vector Magnetics | Magnetometer circuitry for use in bore hole detection of AC magnetic fields |
| US4823890A (en) * | 1988-02-23 | 1989-04-25 | Longyear Company | Reverse circulation bit apparatus |
| US4883582A (en) * | 1988-03-07 | 1989-11-28 | Mccants Malcolm T | Vis-breaking heavy crude oils for pumpability |
| US4866983A (en) | 1988-04-14 | 1989-09-19 | Shell Oil Company | Analytical methods and apparatus for measuring the oil content of sponge core |
| US4815790A (en) | 1988-05-13 | 1989-03-28 | Natec, Ltd. | Nahcolite solution mining process |
| US4885080A (en) | 1988-05-25 | 1989-12-05 | Phillips Petroleum Company | Process for demetallizing and desulfurizing heavy crude oil |
| US4842070A (en) | 1988-09-15 | 1989-06-27 | Amoco Corporation | Procedure for improving reservoir sweep efficiency using paraffinic or asphaltic hydrocarbons |
| US4928765A (en) | 1988-09-27 | 1990-05-29 | Ramex Syn-Fuels International | Method and apparatus for shale gas recovery |
| US4856587A (en) | 1988-10-27 | 1989-08-15 | Nielson Jay P | Recovery of oil from oil-bearing formation by continually flowing pressurized heated gas through channel alongside matrix |
| US5064006A (en) | 1988-10-28 | 1991-11-12 | Magrange, Inc | Downhole combination tool |
| US4848460A (en) | 1988-11-04 | 1989-07-18 | Western Research Institute | Contained recovery of oily waste |
| US5065501A (en) | 1988-11-29 | 1991-11-19 | Amp Incorporated | Generating electromagnetic fields in a self regulating temperature heater by positioning of a current return bus |
| US4974425A (en) | 1988-12-08 | 1990-12-04 | Concept Rkk, Limited | Closed cryogenic barrier for containment of hazardous material migration in the earth |
| US4860544A (en) | 1988-12-08 | 1989-08-29 | Concept R.K.K. Limited | Closed cryogenic barrier for containment of hazardous material migration in the earth |
| US4933640A (en) | 1988-12-30 | 1990-06-12 | Vector Magnetics | Apparatus for locating an elongated conductive body by electromagnetic measurement while drilling |
| US5103920A (en) * | 1989-03-01 | 1992-04-14 | Patton Consulting Inc. | Surveying system and method for locating target subterranean bodies |
| CA2015318C (en) | 1990-04-24 | 1994-02-08 | Jack E. Bridges | Power sources for downhole electrical heating |
| US4895206A (en) | 1989-03-16 | 1990-01-23 | Price Ernest H | Pulsed in situ exothermic shock wave and retorting process for hydrocarbon recovery and detoxification of selected wastes |
| US4913065A (en) | 1989-03-27 | 1990-04-03 | Indugas, Inc. | In situ thermal waste disposal system |
| US5059303A (en) | 1989-06-16 | 1991-10-22 | Amoco Corporation | Oil stabilization |
| US5041210A (en) * | 1989-06-30 | 1991-08-20 | Marathon Oil Company | Oil shale retorting with steam and produced gas |
| DE3922612C2 (en) | 1989-07-10 | 1998-07-02 | Krupp Koppers Gmbh | Process for the production of methanol synthesis gas |
| US4982786A (en) | 1989-07-14 | 1991-01-08 | Mobil Oil Corporation | Use of CO2 /steam to enhance floods in horizontal wellbores |
| US5050386A (en) | 1989-08-16 | 1991-09-24 | Rkk, Limited | Method and apparatus for containment of hazardous material migration in the earth |
| US5097903A (en) | 1989-09-22 | 1992-03-24 | Jack C. Sloan | Method for recovering intractable petroleum from subterranean formations |
| US5305239A (en) | 1989-10-04 | 1994-04-19 | The Texas A&M University System | Ultrasonic non-destructive evaluation of thin specimens |
| US4926941A (en) | 1989-10-10 | 1990-05-22 | Shell Oil Company | Method of producing tar sand deposits containing conductive layers |
| US4984594A (en) | 1989-10-27 | 1991-01-15 | Shell Oil Company | Vacuum method for removing soil contamination utilizing surface electrical heating |
| US5656239A (en) | 1989-10-27 | 1997-08-12 | Shell Oil Company | Method for recovering contaminants from soil utilizing electrical heating |
| US5229102A (en) | 1989-11-13 | 1993-07-20 | Medalert, Inc. | Catalytic ceramic membrane steam-hydrocarbon reformer |
| US5082055A (en) | 1990-01-24 | 1992-01-21 | Indugas, Inc. | Gas fired radiant tube heater |
| US5020596A (en) | 1990-01-24 | 1991-06-04 | Indugas, Inc. | Enhanced oil recovery system with a radiant tube heater |
| US5011329A (en) | 1990-02-05 | 1991-04-30 | Hrubetz Exploration Company | In situ soil decontamination method and apparatus |
| CA2009782A1 (en) | 1990-02-12 | 1991-08-12 | Anoosh I. Kiamanesh | In-situ tuned microwave oil extraction process |
| US5027896A (en) * | 1990-03-21 | 1991-07-02 | Anderson Leonard M | Method for in-situ recovery of energy raw material by the introduction of a water/oxygen slurry |
| GB9007147D0 (en) | 1990-03-30 | 1990-05-30 | Framo Dev Ltd | Thermal mineral extraction system |
| US5014788A (en) | 1990-04-20 | 1991-05-14 | Amoco Corporation | Method of increasing the permeability of a coal seam |
| CA2015460C (en) | 1990-04-26 | 1993-12-14 | Kenneth Edwin Kisman | Process for confining steam injected into a heavy oil reservoir |
| US5126037A (en) | 1990-05-04 | 1992-06-30 | Union Oil Company Of California | Geopreater heating method and apparatus |
| US5032042A (en) | 1990-06-26 | 1991-07-16 | New Jersey Institute Of Technology | Method and apparatus for eliminating non-naturally occurring subsurface, liquid toxic contaminants from soil |
| US5201219A (en) | 1990-06-29 | 1993-04-13 | Amoco Corporation | Method and apparatus for measuring free hydrocarbons and hydrocarbons potential from whole core |
| US5054551A (en) * | 1990-08-03 | 1991-10-08 | Chevron Research And Technology Company | In-situ heated annulus refining process |
| US5109928A (en) | 1990-08-17 | 1992-05-05 | Mccants Malcolm T | Method for production of hydrocarbon diluent from heavy crude oil |
| US5060726A (en) | 1990-08-23 | 1991-10-29 | Shell Oil Company | Method and apparatus for producing tar sand deposits containing conductive layers having little or no vertical communication |
| US5046559A (en) | 1990-08-23 | 1991-09-10 | Shell Oil Company | Method and apparatus for producing hydrocarbon bearing deposits in formations having shale layers |
| BR9004240A (en) | 1990-08-28 | 1992-03-24 | Petroleo Brasileiro Sa | ELECTRIC PIPE HEATING PROCESS |
| US5085276A (en) * | 1990-08-29 | 1992-02-04 | Chevron Research And Technology Company | Production of oil from low permeability formations by sequential steam fracturing |
| US5074365A (en) | 1990-09-14 | 1991-12-24 | Vector Magnetics, Inc. | Borehole guidance system having target wireline |
| US5066852A (en) | 1990-09-17 | 1991-11-19 | Teledyne Ind. Inc. | Thermoplastic end seal for electric heating elements |
| US5207273A (en) | 1990-09-17 | 1993-05-04 | Production Technologies International Inc. | Method and apparatus for pumping wells |
| US5182427A (en) | 1990-09-20 | 1993-01-26 | Metcal, Inc. | Self-regulating heater utilizing ferrite-type body |
| JPH04272680A (en) | 1990-09-20 | 1992-09-29 | Thermon Mfg Co | Switch-controlled-zone type heating cable and assembling method thereof |
| US5400430A (en) * | 1990-10-01 | 1995-03-21 | Nenniger; John E. | Method for injection well stimulation |
| US5517593A (en) | 1990-10-01 | 1996-05-14 | John Nenniger | Control system for well stimulation apparatus with response time temperature rise used in determining heater control temperature setpoint |
| FR2669077B2 (en) | 1990-11-09 | 1995-02-03 | Institut Francais Petrole | METHOD AND DEVICE FOR PERFORMING INTERVENTIONS IN WELLS OR HIGH TEMPERATURES. |
| US5060287A (en) | 1990-12-04 | 1991-10-22 | Shell Oil Company | Heater utilizing copper-nickel alloy core |
| US5065818A (en) | 1991-01-07 | 1991-11-19 | Shell Oil Company | Subterranean heaters |
| US5217076A (en) | 1990-12-04 | 1993-06-08 | Masek John A | Method and apparatus for improved recovery of oil from porous, subsurface deposits (targevcir oricess) |
| US5190405A (en) | 1990-12-14 | 1993-03-02 | Shell Oil Company | Vacuum method for removing soil contaminants utilizing thermal conduction heating |
| SU1836876A3 (en) | 1990-12-29 | 1994-12-30 | Смешанное научно-техническое товарищество по разработке техники и технологии для подземной электроэнергетики | Process of development of coal seams and complex of equipment for its implementation |
| US5289882A (en) | 1991-02-06 | 1994-03-01 | Boyd B. Moore | Sealed electrical conductor method and arrangement for use with a well bore in hazardous areas |
| US5261490A (en) | 1991-03-18 | 1993-11-16 | Nkk Corporation | Method for dumping and disposing of carbon dioxide gas and apparatus therefor |
| AU659170B2 (en) | 1991-06-17 | 1995-05-11 | Electric Power Research Institute, Inc. | Power plant utilizing compressed air energy storage and saturation |
| DK0519573T3 (en) | 1991-06-21 | 1995-07-03 | Shell Int Research | Hydrogenation catalyst and process |
| IT1248535B (en) | 1991-06-24 | 1995-01-19 | Cise Spa | SYSTEM TO MEASURE THE TRANSFER TIME OF A SOUND WAVE |
| US5133406A (en) | 1991-07-05 | 1992-07-28 | Amoco Corporation | Generating oxygen-depleted air useful for increasing methane production |
| US5189283A (en) | 1991-08-28 | 1993-02-23 | Shell Oil Company | Current to power crossover heater control |
| US5168927A (en) | 1991-09-10 | 1992-12-08 | Shell Oil Company | Method utilizing spot tracer injection and production induced transport for measurement of residual oil saturation |
| US5218301A (en) | 1991-10-04 | 1993-06-08 | Vector Magnetics | Method and apparatus for determining distance for magnetic and electric field measurements |
| US5347070A (en) | 1991-11-13 | 1994-09-13 | Battelle Pacific Northwest Labs | Treating of solid earthen material and a method for measuring moisture content and resistivity of solid earthen material |
| US5349859A (en) | 1991-11-15 | 1994-09-27 | Scientific Engineering Instruments, Inc. | Method and apparatus for measuring acoustic wave velocity using impulse response |
| EP0547961B1 (en) * | 1991-12-16 | 1996-03-27 | Institut Français du Pétrole | Active or passive surveillance system for underground formation by means of fixed stations |
| CA2058255C (en) | 1991-12-20 | 1997-02-11 | Roland P. Leaute | Recovery and upgrading of hydrocarbons utilizing in situ combustion and horizontal wells |
| US5246071A (en) | 1992-01-31 | 1993-09-21 | Texaco Inc. | Steamflooding with alternating injection and production cycles |
| ES2090854T3 (en) | 1992-02-04 | 1996-10-16 | Air Prod & Chem | PROCEDURE TO PRODUCE METHANOL IN LIQUID PHASE WITH RICH IN CO. |
| US5420402A (en) | 1992-02-05 | 1995-05-30 | Iit Research Institute | Methods and apparatus to confine earth currents for recovery of subsurface volatiles and semi-volatiles |
| US5211230A (en) | 1992-02-21 | 1993-05-18 | Mobil Oil Corporation | Method for enhanced oil recovery through a horizontal production well in a subsurface formation by in-situ combustion |
| GB9207174D0 (en) | 1992-04-01 | 1992-05-13 | Raychem Sa Nv | Method of forming an electrical connection |
| US5255740A (en) | 1992-04-13 | 1993-10-26 | Rrkt Company | Secondary recovery process |
| US5305212A (en) | 1992-04-16 | 1994-04-19 | Vector Magnetics, Inc. | Alternating and static magnetic field gradient measurements for distance and direction determination |
| US5258755A (en) | 1992-04-27 | 1993-11-02 | Vector Magnetics, Inc. | Two-source magnetic field guidance system |
| US5332036A (en) | 1992-05-15 | 1994-07-26 | The Boc Group, Inc. | Method of recovery of natural gases from underground coal formations |
| US5366012A (en) | 1992-06-09 | 1994-11-22 | Shell Oil Company | Method of completing an uncased section of a borehole |
| US5297626A (en) | 1992-06-12 | 1994-03-29 | Shell Oil Company | Oil recovery process |
| US5226961A (en) | 1992-06-12 | 1993-07-13 | Shell Oil Company | High temperature wellbore cement slurry |
| US5392854A (en) | 1992-06-12 | 1995-02-28 | Shell Oil Company | Oil recovery process |
| US5255742A (en) | 1992-06-12 | 1993-10-26 | Shell Oil Company | Heat injection process |
| US5236039A (en) | 1992-06-17 | 1993-08-17 | General Electric Company | Balanced-line RF electrode system for use in RF ground heating to recover oil from oil shale |
| US5295763A (en) | 1992-06-30 | 1994-03-22 | Chambers Development Co., Inc. | Method for controlling gas migration from a landfill |
| US5305829A (en) * | 1992-09-25 | 1994-04-26 | Chevron Research And Technology Company | Oil production from diatomite formations by fracture steamdrive |
| US5229583A (en) | 1992-09-28 | 1993-07-20 | Shell Oil Company | Surface heating blanket for soil remediation |
| US5343152A (en) | 1992-11-02 | 1994-08-30 | Vector Magnetics | Electromagnetic homing system using MWD and current having a funamental wave component and an even harmonic wave component being injected at a target well |
| US5485089A (en) | 1992-11-06 | 1996-01-16 | Vector Magnetics, Inc. | Method and apparatus for measuring distance and direction by movable magnetic field source |
| US5339904A (en) | 1992-12-10 | 1994-08-23 | Mobil Oil Corporation | Oil recovery optimization using a well having both horizontal and vertical sections |
| CA2096034C (en) * | 1993-05-07 | 1996-07-02 | Kenneth Edwin Kisman | Horizontal well gravity drainage combustion process for oil recovery |
| US5360067A (en) | 1993-05-17 | 1994-11-01 | Meo Iii Dominic | Vapor-extraction system for removing hydrocarbons from soil |
| US5325918A (en) * | 1993-08-02 | 1994-07-05 | The United States Of America As Represented By The United States Department Of Energy | Optimal joule heating of the subsurface |
| US5377756A (en) * | 1993-10-28 | 1995-01-03 | Mobil Oil Corporation | Method for producing low permeability reservoirs using a single well |
| US5566755A (en) | 1993-11-03 | 1996-10-22 | Amoco Corporation | Method for recovering methane from a solid carbonaceous subterranean formation |
| US5388643A (en) | 1993-11-03 | 1995-02-14 | Amoco Corporation | Coalbed methane recovery using pressure swing adsorption separation |
| US5388641A (en) | 1993-11-03 | 1995-02-14 | Amoco Corporation | Method for reducing the inert gas fraction in methane-containing gaseous mixtures obtained from underground formations |
| US5388640A (en) | 1993-11-03 | 1995-02-14 | Amoco Corporation | Method for producing methane-containing gaseous mixtures |
| US5388645A (en) | 1993-11-03 | 1995-02-14 | Amoco Corporation | Method for producing methane-containing gaseous mixtures |
| US5388642A (en) | 1993-11-03 | 1995-02-14 | Amoco Corporation | Coalbed methane recovery using membrane separation of oxygen from air |
| US5512830A (en) | 1993-11-09 | 1996-04-30 | Vector Magnetics, Inc. | Measurement of vector components of static field perturbations for borehole location |
| US5589775A (en) | 1993-11-22 | 1996-12-31 | Vector Magnetics, Inc. | Rotating magnet for distance and direction measurements from a first borehole to a second borehole |
| US5411086A (en) * | 1993-12-09 | 1995-05-02 | Mobil Oil Corporation | Oil recovery by enhanced imbitition in low permeability reservoirs |
| US5435666A (en) | 1993-12-14 | 1995-07-25 | Environmental Resources Management, Inc. | Methods for isolating a water table and for soil remediation |
| US5433271A (en) * | 1993-12-20 | 1995-07-18 | Shell Oil Company | Heat injection process |
| US5404952A (en) * | 1993-12-20 | 1995-04-11 | Shell Oil Company | Heat injection process and apparatus |
| US5411089A (en) | 1993-12-20 | 1995-05-02 | Shell Oil Company | Heat injection process |
| US5541517A (en) | 1994-01-13 | 1996-07-30 | Shell Oil Company | Method for drilling a borehole from one cased borehole to another cased borehole |
| US5411104A (en) | 1994-02-16 | 1995-05-02 | Conoco Inc. | Coalbed methane drilling |
| CA2144597C (en) | 1994-03-18 | 1999-08-10 | Paul J. Latimer | Improved emat probe and technique for weld inspection |
| US5415231A (en) | 1994-03-21 | 1995-05-16 | Mobil Oil Corporation | Method for producing low permeability reservoirs using steam |
| US5439054A (en) | 1994-04-01 | 1995-08-08 | Amoco Corporation | Method for treating a mixture of gaseous fluids within a solid carbonaceous subterranean formation |
| US5431224A (en) | 1994-04-19 | 1995-07-11 | Mobil Oil Corporation | Method of thermal stimulation for recovery of hydrocarbons |
| US5484020A (en) * | 1994-04-25 | 1996-01-16 | Shell Oil Company | Remedial wellbore sealing with unsaturated monomer system |
| US5409071A (en) | 1994-05-23 | 1995-04-25 | Shell Oil Company | Method to cement a wellbore |
| US5503226A (en) | 1994-06-22 | 1996-04-02 | Wadleigh; Eugene E. | Process for recovering hydrocarbons by thermally assisted gravity segregation |
| WO1996002831A1 (en) | 1994-07-18 | 1996-02-01 | The Babcock & Wilcox Company | Sensor transport system for flash butt welder |
| US5402847A (en) | 1994-07-22 | 1995-04-04 | Conoco Inc. | Coal bed methane recovery |
| US5632336A (en) | 1994-07-28 | 1997-05-27 | Texaco Inc. | Method for improving injectivity of fluids in oil reservoirs |
| US5747750A (en) * | 1994-08-31 | 1998-05-05 | Exxon Production Research Company | Single well system for mapping sources of acoustic energy |
| US5525322A (en) | 1994-10-12 | 1996-06-11 | The Regents Of The University Of California | Method for simultaneous recovery of hydrogen from water and from hydrocarbons |
| US5553189A (en) | 1994-10-18 | 1996-09-03 | Shell Oil Company | Radiant plate heater for treatment of contaminated surfaces |
| US5497087A (en) | 1994-10-20 | 1996-03-05 | Shell Oil Company | NMR logging of natural gas reservoirs |
| US5624188A (en) | 1994-10-20 | 1997-04-29 | West; David A. | Acoustic thermometer |
| US5498960A (en) | 1994-10-20 | 1996-03-12 | Shell Oil Company | NMR logging of natural gas in reservoirs |
| US5513710A (en) | 1994-11-07 | 1996-05-07 | Vector Magnetics, Inc. | Solenoid guide system for horizontal boreholes |
| US5515931A (en) | 1994-11-15 | 1996-05-14 | Vector Magnetics, Inc. | Single-wire guidance system for drilling boreholes |
| US5554453A (en) | 1995-01-04 | 1996-09-10 | Energy Research Corporation | Carbonate fuel cell system with thermally integrated gasification |
| CA2209947C (en) | 1995-01-12 | 1999-06-01 | Baker Hughes Incorporated | A measurement-while-drilling acoustic system employing multiple, segmented transmitters and receivers |
| US6088294A (en) | 1995-01-12 | 2000-07-11 | Baker Hughes Incorporated | Drilling system with an acoustic measurement-while-driving system for determining parameters of interest and controlling the drilling direction |
| US6065538A (en) * | 1995-02-09 | 2000-05-23 | Baker Hughes Corporation | Method of obtaining improved geophysical information about earth formations |
| DE19505517A1 (en) * | 1995-02-10 | 1996-08-14 | Siegfried Schwert | Procedure for extracting a pipe laid in the ground |
| CA2152521C (en) | 1995-03-01 | 2000-06-20 | Jack E. Bridges | Low flux leakage cables and cable terminations for a.c. electrical heating of oil deposits |
| US5621844A (en) | 1995-03-01 | 1997-04-15 | Uentech Corporation | Electrical heating of mineral well deposits using downhole impedance transformation networks |
| US5935421A (en) | 1995-05-02 | 1999-08-10 | Exxon Research And Engineering Company | Continuous in-situ combination process for upgrading heavy oil |
| US5911898A (en) | 1995-05-25 | 1999-06-15 | Electric Power Research Institute | Method and apparatus for providing multiple autoregulated temperatures |
| US5571403A (en) | 1995-06-06 | 1996-11-05 | Texaco Inc. | Process for extracting hydrocarbons from diatomite |
| US6170264B1 (en) | 1997-09-22 | 2001-01-09 | Clean Energy Systems, Inc. | Hydrocarbon combustion power generation system with CO2 sequestration |
| US6015015A (en) | 1995-06-20 | 2000-01-18 | Bj Services Company U.S.A. | Insulated and/or concentric coiled tubing |
| US5626191A (en) | 1995-06-23 | 1997-05-06 | Petroleum Recovery Institute | Oilfield in-situ combustion process |
| US5899958A (en) | 1995-09-11 | 1999-05-04 | Halliburton Energy Services, Inc. | Logging while drilling borehole imaging and dipmeter device |
| US5759022A (en) * | 1995-10-16 | 1998-06-02 | Gas Research Institute | Method and system for reducing NOx and fuel emissions in a furnace |
| US5767584A (en) | 1995-11-14 | 1998-06-16 | Grow International Corp. | Method for generating electrical power from fuel cell powered cars parked in a conventional parking lot |
| KR100445853B1 (en) | 1995-12-27 | 2004-10-15 | 쉘 인터내셔날 리써취 마트샤피지 비.브이. | Flameless combustor |
| US5725059A (en) | 1995-12-29 | 1998-03-10 | Vector Magnetics, Inc. | Method and apparatus for producing parallel boreholes |
| US5751895A (en) | 1996-02-13 | 1998-05-12 | Eor International, Inc. | Selective excitation of heating electrodes for oil wells |
| US5676212A (en) | 1996-04-17 | 1997-10-14 | Vector Magnetics, Inc. | Downhole electrode for well guidance system |
| US5826655A (en) | 1996-04-25 | 1998-10-27 | Texaco Inc | Method for enhanced recovery of viscous oil deposits |
| US5652389A (en) | 1996-05-22 | 1997-07-29 | The United States Of America As Represented By The Secretary Of Commerce | Non-contact method and apparatus for inspection of inertia welds |
| US5769569A (en) | 1996-06-18 | 1998-06-23 | Southern California Gas Company | In-situ thermal desorption of heavy hydrocarbons in vadose zone |
| US5828797A (en) | 1996-06-19 | 1998-10-27 | Meggitt Avionics, Inc. | Fiber optic linked flame sensor |
| EA001466B1 (en) | 1996-06-21 | 2001-04-23 | Синтролеум Корпорейшн | Synthesis gas production system and method |
| MY118075A (en) | 1996-07-09 | 2004-08-30 | Syntroleum Corp | Process for converting gas to liquids |
| US5826653A (en) | 1996-08-02 | 1998-10-27 | Scientific Applications & Research Associates, Inc. | Phased array approach to retrieve gases, liquids, or solids from subaqueous geologic or man-made formations |
| US6079499A (en) * | 1996-10-15 | 2000-06-27 | Shell Oil Company | Heater well method and apparatus |
| US6056057A (en) * | 1996-10-15 | 2000-05-02 | Shell Oil Company | Heater well method and apparatus |
| US5861137A (en) | 1996-10-30 | 1999-01-19 | Edlund; David J. | Steam reformer with internal hydrogen purification |
| US5955039A (en) | 1996-12-19 | 1999-09-21 | Siemens Westinghouse Power Corporation | Coal gasification and hydrogen production system and method |
| US5862858A (en) * | 1996-12-26 | 1999-01-26 | Shell Oil Company | Flameless combustor |
| US6427124B1 (en) | 1997-01-24 | 2002-07-30 | Baker Hughes Incorporated | Semblance processing for an acoustic measurement-while-drilling system for imaging of formation boundaries |
| US6039121A (en) * | 1997-02-20 | 2000-03-21 | Rangewest Technologies Ltd. | Enhanced lift method and apparatus for the production of hydrocarbons |
| GB9704181D0 (en) * | 1997-02-28 | 1997-04-16 | Thompson James | Apparatus and method for installation of ducts |
| US5999489A (en) | 1997-03-21 | 1999-12-07 | Tomoseis Inc. | High vertical resolution crosswell seismic imaging |
| US5923170A (en) | 1997-04-04 | 1999-07-13 | Vector Magnetics, Inc. | Method for near field electromagnetic proximity determination for guidance of a borehole drill |
| US5926437A (en) | 1997-04-08 | 1999-07-20 | Halliburton Energy Services, Inc. | Method and apparatus for seismic exploration |
| US5984578A (en) | 1997-04-11 | 1999-11-16 | New Jersey Institute Of Technology | Apparatus and method for in situ removal of contaminants using sonic energy |
| EP1355167A3 (en) | 1997-05-02 | 2004-05-19 | Baker Hughes Incorporated | An injection well with a fibre optic cable to measure fluorescence of bacteria present |
| US5802870A (en) | 1997-05-02 | 1998-09-08 | Uop Llc | Sorption cooling process and system |
| AU8103998A (en) | 1997-05-07 | 1998-11-27 | Shell Internationale Research Maatschappij B.V. | Remediation method |
| US6023554A (en) | 1997-05-20 | 2000-02-08 | Shell Oil Company | Electrical heater |
| ID22887A (en) | 1997-06-05 | 1999-12-16 | Shell Int Research | REPAIR METHOD |
| US6102122A (en) | 1997-06-11 | 2000-08-15 | Shell Oil Company | Control of heat injection based on temperature and in-situ stress measurement |
| US6112808A (en) | 1997-09-19 | 2000-09-05 | Isted; Robert Edward | Method and apparatus for subterranean thermal conditioning |
| US5984010A (en) | 1997-06-23 | 1999-11-16 | Elias; Ramon | Hydrocarbon recovery systems and methods |
| CA2208767A1 (en) | 1997-06-26 | 1998-12-26 | Reginald D. Humphreys | Tar sands extraction process |
| US5891829A (en) * | 1997-08-12 | 1999-04-06 | Intevep, S.A. | Process for the downhole upgrading of extra heavy crude oil |
| US5868202A (en) | 1997-09-22 | 1999-02-09 | Tarim Associates For Scientific Mineral And Oil Exploration Ag | Hydrologic cells for recovery of hydrocarbons or thermal energy from coal, oil-shale, tar-sands and oil-bearing formations |
| US6187465B1 (en) | 1997-11-07 | 2001-02-13 | Terry R. Galloway | Process and system for converting carbonaceous feedstocks into energy without greenhouse gas emissions |
| US6354373B1 (en) | 1997-11-26 | 2002-03-12 | Schlumberger Technology Corporation | Expandable tubing for a well bore hole and method of expanding |
| FR2772137B1 (en) * | 1997-12-08 | 1999-12-31 | Inst Francais Du Petrole | SEISMIC MONITORING METHOD OF AN UNDERGROUND ZONE DURING OPERATION ALLOWING BETTER IDENTIFICATION OF SIGNIFICANT EVENTS |
| EP1060326B1 (en) | 1997-12-11 | 2003-04-02 | Alberta Research Council, Inc. | Oilfield in situ hydrocarbon upgrading process |
| US6152987A (en) | 1997-12-15 | 2000-11-28 | Worcester Polytechnic Institute | Hydrogen gas-extraction module and method of fabrication |
| US6094048A (en) | 1997-12-18 | 2000-07-25 | Shell Oil Company | NMR logging of natural gas reservoirs |
| US6026914A (en) | 1998-01-28 | 2000-02-22 | Alberta Oil Sands Technology And Research Authority | Wellbore profiling system |
| MA24902A1 (en) | 1998-03-06 | 2000-04-01 | Shell Int Research | ELECTRIC HEATER |
| US6269876B1 (en) * | 1998-03-06 | 2001-08-07 | Shell Oil Company | Electrical heater |
| US6540018B1 (en) * | 1998-03-06 | 2003-04-01 | Shell Oil Company | Method and apparatus for heating a wellbore |
| US6035701A (en) | 1998-04-15 | 2000-03-14 | Lowry; William E. | Method and system to locate leaks in subsurface containment structures using tracer gases |
| US6244338B1 (en) | 1998-06-23 | 2001-06-12 | The University Of Wyoming Research Corp., | System for improving coalbed gas production |
| US6016868A (en) | 1998-06-24 | 2000-01-25 | World Energy Systems, Incorporated | Production of synthetic crude oil from heavy hydrocarbons recovered by in situ hydrovisbreaking |
| US6016867A (en) | 1998-06-24 | 2000-01-25 | World Energy Systems, Incorporated | Upgrading and recovery of heavy crude oils and natural bitumens by in situ hydrovisbreaking |
| US6769805B2 (en) * | 1998-08-25 | 2004-08-03 | Sensor Highway Limited | Method of using a heater with a fiber optic string in a wellbore |
| NO984235L (en) * | 1998-09-14 | 2000-03-15 | Cit Alcatel | Heating system for metal pipes for crude oil transport |
| US6388947B1 (en) | 1998-09-14 | 2002-05-14 | Tomoseis, Inc. | Multi-crosswell profile 3D imaging and method |
| US6192748B1 (en) | 1998-10-30 | 2001-02-27 | Computalog Limited | Dynamic orienting reference system for directional drilling |
| US5968349A (en) | 1998-11-16 | 1999-10-19 | Bhp Minerals International Inc. | Extraction of bitumen from bitumen froth and biotreatment of bitumen froth tailings generated from tar sands |
| US20040035582A1 (en) * | 2002-08-22 | 2004-02-26 | Zupanick Joseph A. | System and method for subterranean access |
| US6681855B2 (en) * | 2001-10-19 | 2004-01-27 | Cdx Gas, L.L.C. | Method and system for management of by-products from subterranean zones |
| US6609761B1 (en) | 1999-01-08 | 2003-08-26 | American Soda, Llp | Sodium carbonate and sodium bicarbonate production from nahcolitic oil shale |
| US6078868A (en) | 1999-01-21 | 2000-06-20 | Baker Hughes Incorporated | Reference signal encoding for seismic while drilling measurement |
| US6109358A (en) * | 1999-02-05 | 2000-08-29 | Conor Pacific Environmental Technologies Inc. | Venting apparatus and method for remediation of a porous medium |
| US6429784B1 (en) * | 1999-02-19 | 2002-08-06 | Dresser Industries, Inc. | Casing mounted sensors, actuators and generators |
| US6155117A (en) | 1999-03-18 | 2000-12-05 | Mcdermott Technology, Inc. | Edge detection and seam tracking with EMATs |
| US6561269B1 (en) | 1999-04-30 | 2003-05-13 | The Regents Of The University Of California | Canister, sealing method and composition for sealing a borehole |
| US6234259B1 (en) | 1999-05-06 | 2001-05-22 | Vector Magnetics Inc. | Multiple cam directional controller for steerable rotary drill |
| US6269310B1 (en) | 1999-08-25 | 2001-07-31 | Tomoseis Corporation | System for eliminating headwaves in a tomographic process |
| US6193010B1 (en) | 1999-10-06 | 2001-02-27 | Tomoseis Corporation | System for generating a seismic signal in a borehole |
| US6196350B1 (en) | 1999-10-06 | 2001-03-06 | Tomoseis Corporation | Apparatus and method for attenuating tube waves in a borehole |
| US6288372B1 (en) | 1999-11-03 | 2001-09-11 | Tyco Electronics Corporation | Electric cable having braidless polymeric ground plane providing fault detection |
| US6353706B1 (en) | 1999-11-18 | 2002-03-05 | Uentech International Corporation | Optimum oil-well casing heating |
| US6422318B1 (en) * | 1999-12-17 | 2002-07-23 | Scioto County Regional Water District #1 | Horizontal well system |
| FI19992831A (en) * | 1999-12-30 | 2001-07-01 | Nokia Networks Oy | ISDN layer |
| US6679332B2 (en) * | 2000-01-24 | 2004-01-20 | Shell Oil Company | Petroleum well having downhole sensors, communication and power |
| WO2001065055A1 (en) | 2000-03-02 | 2001-09-07 | Shell Internationale Research Maatschappij B.V. | Controlled downhole chemical injection |
| US7259688B2 (en) * | 2000-01-24 | 2007-08-21 | Shell Oil Company | Wireless reservoir production control |
| US6633236B2 (en) | 2000-01-24 | 2003-10-14 | Shell Oil Company | Permanent downhole, wireless, two-way telemetry backbone using redundant repeaters |
| US20020036085A1 (en) | 2000-01-24 | 2002-03-28 | Bass Ronald Marshall | Toroidal choke inductor for wireless communication and control |
| US7170424B2 (en) * | 2000-03-02 | 2007-01-30 | Shell Oil Company | Oil well casting electrical power pick-off points |
| EG22420A (en) * | 2000-03-02 | 2003-01-29 | Shell Int Research | Use of downhole high pressure gas in a gas - lift well |
| US6357526B1 (en) | 2000-03-16 | 2002-03-19 | Kellogg Brown & Root, Inc. | Field upgrading of heavy oil and bitumen |
| US6632047B2 (en) | 2000-04-14 | 2003-10-14 | Board Of Regents, The University Of Texas System | Heater element for use in an in situ thermal desorption soil remediation system |
| US6485232B1 (en) | 2000-04-14 | 2002-11-26 | Board Of Regents, The University Of Texas System | Low cost, self regulating heater for use in an in situ thermal desorption soil remediation system |
| US6918444B2 (en) | 2000-04-19 | 2005-07-19 | Exxonmobil Upstream Research Company | Method for production of hydrocarbons from organic-rich rock |
| GB0009662D0 (en) | 2000-04-20 | 2000-06-07 | Scotoil Group Plc | Gas and oil production |
| US20030075318A1 (en) | 2000-04-24 | 2003-04-24 | Keedy Charles Robert | In situ thermal processing of a coal formation using substantially parallel formed wellbores |
| US6588504B2 (en) | 2000-04-24 | 2003-07-08 | Shell Oil Company | In situ thermal processing of a coal formation to produce nitrogen and/or sulfur containing formation fluids |
| US20030066642A1 (en) | 2000-04-24 | 2003-04-10 | Wellington Scott Lee | In situ thermal processing of a coal formation producing a mixture with oxygenated hydrocarbons |
| US20020038069A1 (en) | 2000-04-24 | 2002-03-28 | Wellington Scott Lee | In situ thermal processing of a coal formation to produce a mixture of olefins, oxygenated hydrocarbons, and aromatic hydrocarbons |
| US6715546B2 (en) | 2000-04-24 | 2004-04-06 | Shell Oil Company | In situ production of synthesis gas from a hydrocarbon containing formation through a heat source wellbore |
| US6698515B2 (en) | 2000-04-24 | 2004-03-02 | Shell Oil Company | In situ thermal processing of a coal formation using a relatively slow heating rate |
| US6715548B2 (en) | 2000-04-24 | 2004-04-06 | Shell Oil Company | In situ thermal processing of a hydrocarbon containing formation to produce nitrogen containing formation fluids |
| US7011154B2 (en) * | 2000-04-24 | 2006-03-14 | Shell Oil Company | In situ recovery from a kerogen and liquid hydrocarbon containing formation |
| US7096953B2 (en) * | 2000-04-24 | 2006-08-29 | Shell Oil Company | In situ thermal processing of a coal formation using a movable heating element |
| US20030085034A1 (en) | 2000-04-24 | 2003-05-08 | Wellington Scott Lee | In situ thermal processing of a coal formation to produce pyrolsis products |
| US6584406B1 (en) * | 2000-06-15 | 2003-06-24 | Geo-X Systems, Ltd. | Downhole process control method utilizing seismic communication |
| GB2383633A (en) * | 2000-06-29 | 2003-07-02 | Paulo S Tubel | Method and system for monitoring smart structures utilizing distributed optical sensors |
| US6585046B2 (en) | 2000-08-28 | 2003-07-01 | Baker Hughes Incorporated | Live well heater cable |
| US6412559B1 (en) | 2000-11-24 | 2002-07-02 | Alberta Research Council Inc. | Process for recovering methane and/or sequestering fluids |
| US20020112987A1 (en) * | 2000-12-15 | 2002-08-22 | Zhiguo Hou | Slurry hydroprocessing for heavy oil upgrading using supported slurry catalysts |
| US20020112890A1 (en) * | 2001-01-22 | 2002-08-22 | Wentworth Steven W. | Conduit pulling apparatus and method for use in horizontal drilling |
| US20020153141A1 (en) * | 2001-04-19 | 2002-10-24 | Hartman Michael G. | Method for pumping fluids |
| US6466020B2 (en) | 2001-03-19 | 2002-10-15 | Vector Magnetics, Llc | Electromagnetic borehole surveying method |
| CA2668391C (en) * | 2001-04-24 | 2011-10-11 | Shell Canada Limited | In situ recovery from a tar sands formation |
| US6782947B2 (en) | 2001-04-24 | 2004-08-31 | Shell Oil Company | In situ thermal processing of a relatively impermeable formation to increase permeability of the formation |
| US6994169B2 (en) | 2001-04-24 | 2006-02-07 | Shell Oil Company | In situ thermal processing of an oil shale formation with a selected property |
| US7055600B2 (en) * | 2001-04-24 | 2006-06-06 | Shell Oil Company | In situ thermal recovery from a relatively permeable formation with controlled production rate |
| US20030029617A1 (en) * | 2001-08-09 | 2003-02-13 | Anadarko Petroleum Company | Apparatus, method and system for single well solution-mining |
| US6591908B2 (en) | 2001-08-22 | 2003-07-15 | Alberta Science And Research Authority | Hydrocarbon production process with decreasing steam and/or water/solvent ratio |
| US7077199B2 (en) | 2001-10-24 | 2006-07-18 | Shell Oil Company | In situ thermal processing of an oil reservoir formation |
| US7090013B2 (en) * | 2001-10-24 | 2006-08-15 | Shell Oil Company | In situ thermal processing of a hydrocarbon containing formation to produce heated fluids |
| US7165615B2 (en) * | 2001-10-24 | 2007-01-23 | Shell Oil Company | In situ recovery from a hydrocarbon containing formation using conductor-in-conduit heat sources with an electrically conductive material in the overburden |
| US6969123B2 (en) * | 2001-10-24 | 2005-11-29 | Shell Oil Company | Upgrading and mining of coal |
| US7104319B2 (en) * | 2001-10-24 | 2006-09-12 | Shell Oil Company | In situ thermal processing of a heavy oil diatomite formation |
| AU2002363073A1 (en) * | 2001-10-24 | 2003-05-06 | Shell Internationale Research Maatschappij B.V. | Method and system for in situ heating a hydrocarbon containing formation by a u-shaped opening |
| US6679326B2 (en) * | 2002-01-15 | 2004-01-20 | Bohdan Zakiewicz | Pro-ecological mining system |
| US6684948B1 (en) * | 2002-01-15 | 2004-02-03 | Marshall T. Savage | Apparatus and method for heating subterranean formations using fuel cells |
| CA2473323C (en) * | 2002-01-17 | 2010-08-03 | Presssol Ltd. | Two string drilling system |
| WO2003062590A1 (en) | 2002-01-22 | 2003-07-31 | Presssol Ltd. | Two string drilling system using coil tubing |
| US6958195B2 (en) * | 2002-02-19 | 2005-10-25 | Utc Fuel Cells, Llc | Steam generator for a PEM fuel cell power plant |
| US6702011B2 (en) | 2002-04-22 | 2004-03-09 | James B. Crawford | Combined nitrogen treatment system and coiled tubing system in one tractor/trailer apparatus |
| US6942037B1 (en) | 2002-08-15 | 2005-09-13 | Clariant Finance (Bvi) Limited | Process for mitigation of wellbore contaminants |
| US7204327B2 (en) * | 2002-08-21 | 2007-04-17 | Presssol Ltd. | Reverse circulation directional and horizontal drilling using concentric drill string |
| CA2503394C (en) * | 2002-10-24 | 2011-06-14 | Shell Canada Limited | Temperature limited heaters for heating subsurface formations or wellbores |
| US7048051B2 (en) | 2003-02-03 | 2006-05-23 | Gen Syn Fuels | Recovery of products from oil shale |
| AU2004235350B8 (en) * | 2003-04-24 | 2013-03-07 | Shell Internationale Research Maatschappij B.V. | Thermal processes for subsurface formations |
| US6951250B2 (en) | 2003-05-13 | 2005-10-04 | Halliburton Energy Services, Inc. | Sealant compositions and methods of using the same to isolate a subterranean zone from a disposal well |
| US7147057B2 (en) | 2003-10-06 | 2006-12-12 | Halliburton Energy Services, Inc. | Loop systems and methods of using the same for conveying and distributing thermal energy into a wellbore |
| JP4794550B2 (en) * | 2004-04-23 | 2011-10-19 | シエル・インターナシヨナル・リサーチ・マートスハツペイ・ベー・ヴエー | Temperature limited heater used to heat underground formations |
| US7942197B2 (en) | 2005-04-22 | 2011-05-17 | Shell Oil Company | Methods and systems for producing fluid from an in situ conversion process |
| NZ562249A (en) * | 2005-04-22 | 2010-11-26 | Shell Int Research | Double barrier system with fluid head monitored in inter-barrier and outer zones |
| US20060175061A1 (en) | 2005-08-30 | 2006-08-10 | Crichlow Henry B | Method for Recovering Hydrocarbons from Subterranean Formations |
| US7559367B2 (en) | 2005-10-24 | 2009-07-14 | Shell Oil Company | Temperature limited heater with a conduit substantially electrically isolated from the formation |
| EP2010755A4 (en) | 2006-04-21 | 2016-02-24 | Shell Int Research | Time sequenced heating of multiple layers in a hydrocarbon containing formation |
| JO2982B1 (en) | 2006-10-13 | 2016-03-15 | Exxonmobil Upstream Res Co | Optimized well spacing for in situ shale oil development |
| WO2008051834A2 (en) | 2006-10-20 | 2008-05-02 | Shell Oil Company | Heating hydrocarbon containing formations in a spiral startup staged sequence |
| AU2008242808B2 (en) | 2007-04-20 | 2011-09-22 | Shell Internationale Research Maatschappij B.V. | Varying properties of in situ heat treatment of a tar sands formation based on assessed viscosities |
| WO2009052042A1 (en) | 2007-10-19 | 2009-04-23 | Shell Oil Company | Cryogenic treatment of gas |
| EA019751B1 (en) | 2008-04-18 | 2014-06-30 | Шелл Интернэшнл Рисерч Маатсхаппий Б.В. | Method and system for treating a subsurface hydrocarbon containing formation |
| US8277642B2 (en) | 2008-06-02 | 2012-10-02 | Korea Technology Industries, Co., Ltd. | System for separating bitumen from oil sands |
| US8261832B2 (en) | 2008-10-13 | 2012-09-11 | Shell Oil Company | Heating subsurface formations with fluids |
| US8448707B2 (en) | 2009-04-10 | 2013-05-28 | Shell Oil Company | Non-conducting heater casings |
| US9033042B2 (en) | 2010-04-09 | 2015-05-19 | Shell Oil Company | Forming bitumen barriers in subsurface hydrocarbon formations |
| US8739874B2 (en) | 2010-04-09 | 2014-06-03 | Shell Oil Company | Methods for heating with slots in hydrocarbon formations |
-
2004
- 2004-04-23 AU AU2004235350A patent/AU2004235350B8/en not_active Ceased
- 2004-04-23 NZ NZ567052A patent/NZ567052A/en not_active IP Right Cessation
- 2004-04-23 NZ NZ543753A patent/NZ543753A/en not_active IP Right Cessation
- 2004-04-23 US US10/831,351 patent/US7121342B2/en not_active Expired - Fee Related
- 2004-04-23 WO PCT/US2004/012784 patent/WO2004097159A2/en active Application Filing
- 2004-04-23 CA CA2524689A patent/CA2524689C/en active Active
- 2004-04-24 GB GB0620426A patent/GB2430455B/en not_active Expired - Fee Related
- 2004-04-24 GB GB0521393A patent/GB2417970A/en not_active Withdrawn
- 2004-04-24 GB GB0620367A patent/GB2430218B/en not_active Expired - Fee Related
-
2006
- 2006-10-13 GB GB0620368A patent/GB2430219B/en not_active Expired - Fee Related
- 2006-10-13 GB GB0620366A patent/GB2430217A/en not_active Withdrawn
- 2006-10-13 GB GB0620424A patent/GB2430454B/en not_active Expired - Fee Related
- 2006-10-17 US US11/582,567 patent/US7360588B2/en not_active Expired - Fee Related
-
2008
- 2008-04-07 US US12/080,928 patent/US7640980B2/en not_active Expired - Fee Related
-
2010
- 2010-01-04 US US12/651,728 patent/US7942203B2/en not_active Expired - Fee Related
-
2011
- 2011-05-17 US US13/109,828 patent/US8579031B2/en not_active Expired - Fee Related
-
2013
- 2013-11-12 US US14/078,116 patent/US20140182843A1/en not_active Abandoned
Also Published As
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CA2524689A1 (en) | Thermal processes for subsurface formations | |
| US7121341B2 (en) | Conductor-in-conduit temperature limited heaters | |
| US7370704B2 (en) | Triaxial temperature limited heater | |
| AU2007249074B2 (en) | Thermal processes for subsurface formations |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| EEER | Examination request |