CA2120797A1 - Well completions with expandable casing portions - Google Patents
Well completions with expandable casing portionsInfo
- Publication number
- CA2120797A1 CA2120797A1 CA002120797A CA2120797A CA2120797A1 CA 2120797 A1 CA2120797 A1 CA 2120797A1 CA 002120797 A CA002120797 A CA 002120797A CA 2120797 A CA2120797 A CA 2120797A CA 2120797 A1 CA2120797 A1 CA 2120797A1
- Authority
- CA
- Canada
- Prior art keywords
- casing
- opening
- well
- subsurface formation
- formation
- 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.)
- Abandoned
Links
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- 230000033001 locomotion Effects 0.000 claims abstract description 10
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- 230000006378 damage Effects 0.000 claims description 9
- 238000005755 formation reaction Methods 0.000 claims 21
- 238000010276 construction Methods 0.000 claims 1
- 238000003825 pressing Methods 0.000 claims 1
- 206010017076 Fracture Diseases 0.000 description 51
- 208000010392 Bone Fractures Diseases 0.000 description 47
- 238000004891 communication Methods 0.000 description 8
- 230000010485 coping Effects 0.000 description 5
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- 229930195733 hydrocarbon Natural products 0.000 description 1
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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
- E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
- E21B17/02—Couplings; joints
- E21B17/08—Casing joints
-
- 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
- E21B43/11—Perforators; Permeators
- E21B43/114—Perforators using direct fluid action on the wall to be perforated, e.g. abrasive jets
-
- 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
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
Abstract
Abstract Of The Disclosure Expandable casing portions are provided, such as casing slip joints or expansion joints, on opposite sides of a fracture initiation location to accommodate casing and formation movement during fracturing of a well. The fracture initiation location may be provided by forming openings through the well casing and then forming fan-shaped slots in the formation surrounding the casing. These slots may be formed by a hydraulic jet which is directed through the opening and then pivoted generally about the point of the opening. These fan-shaped slots circumscribe an angle about the axis of the casing substantially greater than the angle circumscribed by the opening itself through which the slot was formed. These techniques are particularly applicable to fracturing of horizontal wells, but are also useful on vertical wells.
Description
2~2~7~7 W13LL COP~PLE:TION~; WIl~I E~PAND~BLg CASING PORTIONS
This i8 a continuation in part of co-pending ~pplication Serial No. 07/953,671, filed Septamber 29, 1992.
Ba~qr~und Of Tho I~vQntion 1. Fiold Of The InYe~tion The pre~ent invention relate~ generally to the completion of oil and gas wells through fracturing oper~tion~, and more particularly, but not by way of limitation, to the completion of wells in which the formation tends to open up in ths direction of the wellbore.
2. Doscription Of The Prior Art Several different technigues are currently u~ed for the completion of horizontal well~.
A first, very common manner of completing a horizontal well is to case and cemont the vertical portion of the well and to leave the horizontal portion of the well which run~
through the producing formation as an open hole, i.e., that is without any casing in place therein. Hydrocarbon fluids in the formation are produced into the open hole and then through the casing in the vertical portion of the well.
A second technique which is commonly u~ed for the completion of horizontal well8 i~ to place a length of slotted caelng in the horizontal portion of the well. The purpose of the slotted ca~ing i~ to pre~ent the open hole ~rom collapsing. A gravol pack may be placed around the slotted casing. The slotted casing may run for extended length~
through the formation, for example as long as one mile.
A third technigue which i3 sometimes used to complete .
2~2~7~7 horizontal well8 i8 to C~ment casing in both the vertical and horizontal portio~ of the well and then to provide communication between the horizontal portion of the casi~g and the producing formation by mean~ of perfor~tions or caslng valve~. The formation may al~o be fractured by creating fracture~ initiating at the location of the perforation~ or the casing valve~.
In this third technique, the formation of perforations is often done through u~ of explosive charge~ which are carried by a perforating gun. The explosive charges crsate holes which penetrate the side wall of the casing and penetrate the c~ment ~urrounding the casing. Typically, the holes will be ln a pattern extending over a ~ubstantial length of the ca~lng.
When the communication betwaen the casing and the producing fonmRtion is provided by ca~ing valve~, tho~e valves may be like tho~e seen in U. S. Patent No. 4,949,788 to Szarka et al., U. S. Patent No. 4,979,561 to Szarka, U. S. Patent No.
4,991,653 to Sahwegman, U. S. Patent No. 5,029,644 to Szarka et al., and U. S. Patent No. 4,991,654 to 8randell et al., all as~igned to the as0ignee of the pre~ent invention. Such casing valves al~o provide a large number of radial bore type openings communicating the ca~ing bore with the ~urrounding formation.
When utilizing either perforated caRing or ca~ing Yalves like those just described, the fracturing fluid enters the formation through a large multitude of ~mall radial bores at . .
2~ 2~7~7 a variety of longitudinal position~ along the casing and there is no accurate control over where the fracture will initiate and in what direction the fracture will initiate.
In the context of ~ub~tantially deviated or horizontal wells, the cementing of ca~ing into the horizontal portion of the well followed by subsequent fracture treatment~ ha~ not been as ~ucce~sful as desired when u~lng existing techniques, e~pecially when multiple zone fracturing i~ involved.
Su~m~ry Of The In~Rntion It ha~ been determined that ona of the rea~on~ fracturing of horizontal well8 has not been completely satisfactory in the past i8 that when a fracture radiatec outward in a plane tran~vor~e to and preferably perpendicular to the longitudinal axl~ of the ca~ing, the subsurface formation tends to move on either side of the fracture in a direction generally parallel to the longitudinal axis of the ca~ing, but the ca~ing its21f cannot move. Thu~, the relative mov~ment between the ~ubsurface formation and the ca~ing often cau~es a destruction of the bond between the casing and the surrounding cement.
Thi~ destruction of the cement/casing bond may extend for large distances thus providing a path of communication between adjacent eub~urface formatione which are to be fractuxed.
The improved fracturing technique of the preEent invention eliminatas this problem. This i~ accomplished by providing expandable casins portions adjacent the location where the fracture is to be initiated. Preferably, Ruch expandable CaBing portionc are pro~ided on both sides of the ~ 212~7'37 fracture initiation location. The expandable ca~ing portion~
allow the ca~ing to ~ove with the expanding formation when fracturing occur~. This aid~ in preventing a de~truc~ion o$
the bond between the c~ment and the ca~ing. Preferably, the U~Q of expandable ca~ing portions i8 accompanied by the provi~ion of a mean~ for directing the initial direction of fractu_e initiation ~o that the fracture initiate~ in a plane generally perpendicular to the longitudinal axi~ of the casing.
It has been deter~ined that another rea~on fracturing of hoxizontal wells ha~ not been co~pletely ~aticfactory in the pa~t is that the ~tressee which are created withln the formation immediately ~urrounding the casing and cement in a horizontal well are uuch th~t quite often the fracture will not radiate outward in a plane perpendicular to the axis of the well as ic ~oct de~irable, but instead quite often the fracture will run parallel to the ca~ing and thu~ will allow communication between adjacent formation~
The present invention include~ an improved method for initially communicating the ca~ing bore with the surrounding formation co ac to provide a predetermined point of initiation of the fracture and ~o as to provide directional guidance to the fracture when it i8 initiated.
This method i~ accompli~hzd by inserting a hydraulic ~etting tool into the ca~ing. One or more opening~ are formed through the cas~ng, and preferably tho~e opening~ are formed by the hydraulic ~etting tool it6elf.
2~2~7~7 The hydraulic jetting tool i8 then u~ed to direct a hydraulic jet through the opening ~n the ca~ing and the jetting tool i~ pivoted ~o a~ to cut one or more fan-~haped slot~ in the aurrounding formation in a plane tran~ver~e to the longitudinal axis of the casing. Each of the~e fan-shaped ~lot~ circ~mscribes a ~ubstantially larger arc ~bout the axi8 of the caslng than does the opening through ~hich the slot wa~
cut.
Prefer~bly these fan-~haped slots lie in a plane sub~tantially perpendicular to the longitudinal axi~ of the ca~ing.
Sub~equently, when fracturing fluid i~ applied under pro~ure to the fsn-~haped slot~, the fracture will initiate in the plane of the fan-shaped elcte and will at leaEt initially radiate outward from the wellbore along that plane.
This will occur regardle~a of the orientation of the natural lea0t principal stre~ axi~ within the ~urrounding formation.
The provi~ion of the fan-~haped ~lot~ will allow initiation of the fr~lcture and allow it to move outward away from the wellbors ~ufficiently ~o that the direction of the fracture will not be controllod by the local ~tre~se~
immediatoly ~urrounding the cAsing and wellbore which might otherwi~e cau~e the fracture to follow the wellbore.
Numeroun objects, features and advantage~ of the present invontion will be readily apparent to tho~e ~killed in the art upon a reading of the following dl~closure when taken in conjunction with the accompanying drawing~.
212~7~7 Brief De~cription 0~ Thn Dr~i~s FIG. 1 i~ an elevation sch~matic ~ectioned view of a well having a horizontal portion which has b~en ca~ed and cemented.
The formation i~ ~hown as having had radially extending fan-~3hap2d slot~ cut therein.
FIG. 2 i8 a schematic view taken along line 2-2 of FIG.
1 $n a plane perpendi~ular to the longltudinal axis of the wellbore ~howing four fan-~hapedl310ts ~urrounding the cal3ing.
FIG. 2A il3 a view ~imilar to FIG. 2, ~howing a pattern of eight radially extending bores located ln a ~ommon plane perpendicular to the axi~ of the wellbore.
FIG. 3 is a schomatic illustration of the problem pre0ent in the prlor art when multiple zon~s of a horizontal well are fractur~d, with tho fracture propagating parallel to the wellbore oo that the zones communicate with each other.
FI~. 4 i8 a schematic illustration of the manner in whic~
fracturos will propagate from the well utilizing the fan-shapsd slots of the present invention when the least principal stres~ of the surrounding formation lies genQrally parallel to the longitudinal axil3 of the wellbore.
FIG. 5 i~ a view 13imilar to FIG. 4 showing the manner in which fractures will propagate from the well utilizing the fan-shaped slotl3 of the present invention when the least principal stre~ of the surrounding formation liel3 at an angle substantially tranl3verse to the longitudinal axil3 of the wellbore. The fracture~ initially propagate outward in a plane perpendicular to the wellbore and then turn in a 7 21207~7 direction perpendicular to the lea~t principal ~tre~ in the surrounding formation.
FIG. 6 is a ~ch~Iatic ~ectioned view of a portion of a horizontal well having a fir~t embodiment of the expandable ca~ing portions located in the Gasing on oppo~ite aide~ of the location of the fan-0haped ~lot~.
FIG. 7 is a achematic 0ectloned view of a portion of a horizontal well having an alternate embodiment of the expandable casing portions positioned in the casing on opposite side~ of ~ha location of the fan-~haped slot~.
FIG. 8 show~ the alternate embodiment expandable casing portion in an expanded position.
FIG. 9 is a se~tioned elevation view of an alternative apparatus for cutting the fan-shaped ~lota.
FI~. 10 is a ViQW similar to FIG. 1 illu~trating tho use of tho invention in co~bination with slotted cas~ng in an open borehole in parts of the horizontal portion of the well.
D~tailed Des~riptio~ Of The Preferred Eobodi~enta Referring now to the drawings, and particularly to PIG.
1, a well is ehown and generally de~ignated by the numeral 10.
The well is formed by a wellbore 12 which extends downward from the earth'~ surface 14. The wellbore 12 is illustrated a~ havlng an lnitial, generally vertical portion 16 and a lower, generally horizontal portion 18, but the invention may be applicable to other well confiyurations.
The well 10 includes a casing string 20 which i3 located within the wellbore 12 and cemented in place therein by cement 8 2~2~7~7 22.
The horizontal portion 18 of wellbore 12 in ~hown a~
inter~ecting a ~ubterranean ~ormation 23 in which are located two imaginary zones which are to be fractured. The zone~ are outlined in phantom line~ and are generally deæignated by the :~
numeral~ 24 and 26. ~ :
A hydraulic jetting tool ~chamatically illustrated and designated by the numeral 28 ha~ been lowered into the casing 20 on a tubing string 30. A conventional wellhead 32 i8 located at the upper end of the w811 at the earth'a ~urface.
A ~ource of high pre~sure fluid 33 i0 connected to the tubing string 30 to provide hydraulic fluid under high pressure to the hydraulic jetting tool 28.
In the first zone 24, two fan-~haped ~lot~ 34A and 34C
are shown ln crosu ~ection extending through the c~ment 22 into the surrounding zone 24. The ~lots have been cut by the hydraulic ~etting tool 28 in a manner further de~cribed below.
FIG. 2 is a cro~-sectio~al view taken along line 2-2 of FIG. 1 and ~howing a preferred pattern of fan shaped ~lots including four fan-~haped ~lots 34A, 34B, 34C and 34D.
A~ ~een in FIG. 2, thsre i~ associated with each of the fan-ehaped ~lot~ 34A, 34B, 34C and 34D an opening 36 formed through the casing 20. The~e opening~ are designated by the numeral~ 36A, 36B, 36C and 36D, re~pectively.
The fan-shaped i810t~ 34 are ahown as lying in a plane ~ubstantially perpendicular to a longitudinal axi~ 38 of the horizontal portion of the aasing 20. ~: :
- 9 2~2~79~
In F~G. 2, the hydraulic jetting tool 28 ia shown in po~ition for formation of the opening 36A and radial fan-~haped ~lot 34A.
Preferably, the opening 36A i~ for~ed through the ca~ing 20 by the hydraulic jetting action of jetting tool 2~. ~hen, using the opening 36A a~ a ba~e or pivot point, ths hydraulic jetting tool 28 i~ rotated bac~ and forth through an arc corresponding to an angle 37 formed by the fan-shaped slot about ths point of the opening 36A ao that the hydraulic jet which shoots through the opening 36A will cut the fan-~haped slot 34A.
As i8 apparent in FIG. 2, the fan-~haped ~lot 34A
circumscrlbes a sub~tantially larger arc about the axis 38 of caslng 20 than doe~ the small open~ng 36A through which the fan-shaped slot 34A was cut.
In it~ broadeet terms, the fan-shaped slot concept doe~
not reguire that the pivotal ba6e of ~he slot 34 be located at the opening 36. It is reguired, however, that the slots be formed in a manner such t~at the ~tructural integrity of the casing 18 malntained.
Although it is preferred to form the opening~ 36 by the hydraullc jetting action ju~t de~cribed, it is also within the ecope of the pre~ent invention to u~e preformed holes, such as those which would be provided by a ca~ing valve like that shown in Brandell et al., U. S. Patent No. 4r991~654~ in which caue the jetting tool 28 would be located adjacent an existing hole provided in the ca~ing valve and the fan-shaped ~lot~
212~7~7 would be cut through the existing holeR of the ca~ing valve.
It is also within the ~cope of the preeent invention to cut the fan-shaped slots 34 in planea other than plane~
perpendicular to the longitudinal axi~ 38. Al~o, the fan-shaped ~lot~ may be cut in a vertical portion rather than a hor~zontal portion of the well.
Furthermore, it i~ possible to cut the fan-shaped ~lots 34 to modify the well 10 for rea~ons other than fracturing the well. For example, the fan-shaped ~lots 34 may be utilized as a substitute for perfcration~ communicating the casing bore with the ~urrounding formation.
~ y forming the fan-shaped slotc 34 a~ shown in FIG. 2 wherein each ~lot 34 circumscribes a ~ubatantially larger arc bout the lon~itudinal axis 38 than doe~ the opening 36 through which the clot i~ formed, the integrity of the ca~ing, i.e., the structural ~trength of the casing, is mzintained.
FIG. 3 illustrates a probl~m which occurs with prior art fracturing techniques for horizontal wells. It will be appreclated that FI~. 3 is a very schematic illustration.
FIG. 3 generally sho~ws the WQll ca~ing 20 cemented in place within the wellbore 12 by cement 22.
Two subsurface zones to be fractured, such as zones 24 and 26 are illustrated. The location of opening~ ~uch as perforation~, casing valvee or the like at locations adjacent zones 24 and 26 are ~chematically illustrated by the opening~
39 and 40, respectively. The opening~ 39 and 40 are only schematically repre~entative of some type of communication 11 212~7~7 between the caeing bore and the zone~ 24 and 26, re~pectively, which iB pre~ent prior to the fracturing of the well.
One problem which often occur~ when fracturing horizontal wells i~ that, when the fracture is initiated, the fracture will prop gate generally parallel to the longitudinal axi~ 38 of the ca~ing 20. Thi~ occurs due to the local stre~e~
immediately ~urrounding the ca~ing 20 and cement 22, and often it occurs around the cement/formation bond, and thu~ w~ll create a fracture space generally de~ignated at 42 which generally follows the wellbore and may in fact provide communication batween the two sub~urface zone~ 24 and 26.
Thus even if individual fracturing jobs are performed on the two zones 24 and 26, if a path of communication is fo~med botweon those zone~, it may be that one or both ~f the zones wlll not be satisfactorily fractured, and of course individual production from the zones will not be possible. When the second zone i~ being fractured, a~ soon a~ the fracture space 42 co....unicates with another previously opened or fractured area, typically fracture growth will cea~e because the surface pump supplying the fracturing fluid will typically not have ~uffic~ent fluid flo~w to maintain fracturing pres~ure~ once the fr~cture is opened to a large, previou~ly opened zone.
This problem iQ avoided by the u~e of the fan-shaped slots previously described as is schematically illu~trated in FIGS. 4 and 5.
FIG. 4 schematically illu~trates the ~ituation which will occur when utilizing the method of the pre~ent invention, - 12 21207~7 when the least principal ~xe89 axia 41 naturally pre~ent in the surrounding formation~ lies generally parallel to the longitudinal axis 38 of the ca~ing 20. If the opening~
generally represented at 39 and 40 are for~ed utilizing the fan-shaped ~lots illustrated in FIGS. 1 and 2, then the resulting fractures 43 and 44, respectively, will initiate in the plane of the fan-shaped alots 34 and will continue to radiate radially outward in generally that same plane a~
illustrated in FIG. 4. Thsre will bs no int0rcom~unication between tho zone~ 24 and 26 and each zons will be fractured in the de~ired manner.
FIG. 5 cimilarly illu~trateu what will happen when ~he least principal ~tress axis 48 i8 transverse to the longltudinal axis 38.
Again, the fractures will initiate and initially propagate outward in radial plane~ as indicated at 50 and 52, and will then turn in a direction generally perpendicular to the least principal 13tre88 axi8 48 as indicated at 54 and 56, respectively.
Thus, in both of the cases ahown in FIGS. 4 and 5, the fracture will initiate in the plans defined by the fan-~haped ~lots and will initially propagate a sufficient di~tance outward away from the casing 20 BO that the local ~tre~e~
around the casing 20 will not determine the ultimate direction of propagation of the fracture. Ths ultimate direction of propagation of the fracture will be determined by the least principal stres~ axis 41 or 48 present in the ~urrounding ;'' 2~2~797 formation.
The fan-~haped 810t8 34 ean be de~cribed a~ creating a localized least principal ~tre~s axis or direction in the fo~tion ~ub~tantially parallel to the longltudinal axi~ 38 thereby aidi~g subseq~ent fracture initiation in a plane generally perpendicular to the longitudinal axi~ 38.
The well 10 ha~ been de~cribed herein as a ~b~tant~ally deviated well or horizontal well. It will be appreciated that the well need not be axactly horizontal to benefit from the preaent invention. Furthermore, even some sub~tantially ~ertical wells may in come ca~e~ benefit from the use of the pre~ent invention. Ae used herein, the term highly deviated or substantially deviated well generally refers to a well the axis of whlch is devlated greater than 45 from a vertical direction.
The Use Of ~Dandabls Ca~i~g Portionc FIGS. 6 and 7 illustrate another aspect of the pre~ient invention, which improves the succe~s of fracturing operations on horizontal well~ by the u~e of expandable ca~ing joint~.
In the embodiment illuatrated in FIG. 6, the expandable ca~ing portions are characterized by casing ~lip joint~, and in FIG.
7, the expandable casing portions are characterized by expansion ~oint~ which function in a bellows-type manner.
The preferred orientation of fracture~ radiating outward from a horizontal well are gsnsrally like tho~e de~cribed above with regard to FIGS. 4 and 5. One additional probl~m that occurs, however, particularly in connection with ~ 2120~97 horizontal well~, i8 that when the fracture radiate~ outward in a plane perpsndicular to the axis 38 of the well, this causes the ~urrounding rock formation to move in a direction parallel to the axis 38 of the well. Referring for example to the fracture 43 ~een in FIG. 4, that portion of the fonmation to th~ right of the fracture 43 would move to the right, and that portion of the formation to the left of fracture 43 would move to the left relatively ~peaking. Tha ca~lng 20, however, cannot move in either direction, and it cannot ~tretch ~ufficiently to accommodate the movemant of the surrounding formation. Thus, the movement of the surrounding formation relative to the casing may cause the bond between the c~ment 22 and the casing 20 to break down. This i8 particularly a problem when the fracturing of multiple ~ubsurface zones ia lnvolved, ~ince thi~ breakdown of the c~ment-to-casing bond will allow a path of communication between multiple zone~
which were intended to be isolated from each other by the cement.
The formation and cement will attempt to move relative to the casing 20. Sin~ca the cement generally has low shear strength of about 300 p~i and a modulue of cla~ticity of about 1,000,000 psi, it can be predicted that the bond between the cement and cauing will fail. The length of cuch a failure can be predicted by the following formula:
L = FW x 2/S
Where FW i~ the maximum fracture width during pumping, E is the modulus of ela~ticity, and S i~ the ~hear ~trength of the 2~797 cement bond. Xn a typical ~ituation, the de~trllction length, that is, the length over which the ca~ing/cement bond i~
destroyed, can exceed 800 feet. Thi~ can become a major cau~e of zone co~munication and will make fracturing treatments of closely ~paced zones le~s effective. Therefore, it iB
important to provide a meana whereby thi~ hreakdown of the cement/ca~ing bo~d will not ocaur.
In FIG. 6, fir~t and ~econd ca~ing slip joints 55 and 57 are provided on opposite side~ of the fan-shaped ~lot~ 34.
Then, when fracturing fluid i~ pu~ped into th¢ ~an-~haped ~lot~ 34 to crea~e and propagate a fracture like fracture 43 ~een in FIG. 4, the ~lip joint~ 55 and 57 will allow movement of the casing 20 on opposite side~ of the fracture along with the ~urrounding formation, thu~ preventing the destruct~on of the bond between the casing 20 and cement 22 ~urrounding the casing during the fracturing operation.
The ea~ing ~lip jointP 55 and 57 are schematically illu~trated in FIG. 6. Each include~ two telescoping portion~
euch a~ 58 and 60, preferably including ~liding seals auch as 62 and 64.
Whsn the ca~ing 20 i~ placed in the wellbore 12 and prior to plac~ment of the c~ment 22 around the ca~ing 20, ~teps should be taken to insure that the slip ~oints 55 and 57 are in a substantially collap~ed po~ition a~ shown in FIG. 6 ~o that there will be ~ufficient travel in the jointE to allow the necessary movement of the CaBing. Thi~ can be accompli~hed by ~etting down weight on the ca~ing 20 after it r~ ~
16 2~ 2~7~7 ;:
has been placed in the wellbors and before the cement 22 i9 placed or at lea~t before the cement 22 ha~ opportunity to ~et up.
Although two 81ip joint~ 55 and 57 are shown in FIG. 6 on oppoeite longitu~inal sidea of the openings 36, it will he appreciated that in many in~tances, a ~ingl~ 81ip joint will ~uffice to allow the neces~ary movament of the ca~ing. It iE
preferred, however, to provide ca~ing alip joints on both si~ea of the opening~ 36 to in~ure that any debonding of t~e cement 22 and ca~ing 20 which may initiate ad~acent the openings 36 will terminate when it reaches e$ther of the 81ip joint~ 55 and 57 and will not propagate beyond the ~lip Joint~. Thi~ prevente any destruction of the cement/ca~ing bond on a side of the elip joint~ longitudinally oppoaite the oponing~ 36.
In FIG. 7, another embodiment of the expandable casing portions i~ ~hown and characteriz~d by first and ~econd ca~ing expan~ion ~oints 200 and 202 which are pro~ided on oppo~ite ~idee of the fan-shaped ~lot~ 34. When fracturing fluid i3 pumped into the fan-~haped ~lot~ 34 to create and propagate a fracture like fracture 43 ~een in FIG. 4, the expan~ion ~oint~
200 and 202 will allow movement of the ca~ing 20 on oppo~ite ~ide~ of the fracture along with the ~urrounding formation, thua preventing th~ de~truction of the bond between a ca~ing 20 and cament 22 aurrounding the ca~ing during the fracturing operation.
Casing joints 200 and 202 are schematically illu~trated ~120~97 in FIG. 7. Each i8 generally tubular in configuration and has a plurality of annular, outer grooves 204 defined therein and a corresponding plurality oF annular, inner groove~ 206 defined therein. Inner groo~e~ 206 are ~taggered with re6pect to outer groove~ 204 ~uch that the outer and inner groove0 are alternately positioned a~ sho~n in FIG. 7.
Thus, each of casing expan~ion joint~ 200 and 202 ~ay be ~aid to compriae a plurality of outer wall ~egmznt~ 208 between corresponding pairs of outer groovs~ 204, and similarly, a plurality of inner wall ~egment~ 210 between corresponding pair~ of inner groo~ee 206. It will be aeen that an inner groove 206 i~ locat~d radially inwardly from each outer wall segment 208, and an outer groove 204 is located radlally outwardly from each inner wall se~ment 210.
Preferably, the outside diameter of i~ner groove~ 206 ~8 so~ewhat larger than the inside diameter o~ outer grooves 204 such that an annular, i~ter~ediate wall segment 212 is formed between ad~acent inner and outer groove~. It will be 3een that lntermediate wall segments 212 thus interconnect outsr wall segments 208 and inner wall aegment~ 210.
Caslng expanslon ~olnts 200 and 202 are posltioned in the caslng 20 as shown ln FIG. 7, and the c~ment 22 18 placed around the casing in the normal manner. It is not nece6~ary in this alternate embodiment to set down weight on the casing 20 after it has been placed ln the wellbore and before the cement 18 placed, as i~ nece~ary to cGllap~e the casing slip ~olnt~ S5 and 57 of tho first embodiment shown in FIG. 6.
r~
2~2~7~7 The configuration of ca~ing expan3ion joints 200 and 202 i8 such that each ca~ing expansion joint provide~ a controlled weakensd sQction of tha ca~ing string. During fracturing, casing expansion jointæ 20~ and 202 ~llow mov~ment of the casing 20 on oppo~ite ~ide~ of the fracture by the expan~ion of the ca~ing sxpan~ion joint~. RePerring to FIG. 8, thi~
expansion is illu~trated. Intermediate wall ~eg~ents 212 provide the controlled weak point in ca~ing expansion joints 200 and 202, and expan~ion thereof re~ult~ in deflection of the intermediate wall segment~ in a bellows-like manner. That i~, inner groove0 206 and outer grooves 204 are widened ~uch that intermediate wall segments 212 will generally extend annularly between outer wall segments 208 and inner wall oogment~ 210. Thu~, there i8 movement allowed in the ca~ing a~ the fracture is propagated which prevents the de~truction of the bond between the casing 20 and c~ment 22 surrou~ding the ca~ing. Al~o, in the ~bodiment of FIGS. 7 and 8, no sealing means is re~uired as in the slip ~oint configuration of FIG. 6.
The formation of the $an-shaped elot~ 34 can be generally described as form~ng a cavity 34 in the formation 23 and ther~by crenting in the ~ubsurface formation 23 ad~acent the cavity 34 a localized lea~t principal stre~0 direction ~ubctantially parallel to the longitudinal axis 38 of the ca~ing 20. Thu~, the fracture such as 43 (see FIG. 4) will initiate in a plane generally perpendicular to the longitudinal axi~ 38.
212~797 ~9 It will be appreciated that the a~pect of the present invention utilizing the expandablc c~sirlg portions may be used without the u~e of the fan-shaped 810t~ de~cribed in FIGS. 1 and 2. The u~e of the fan-~haped slot~ i~ the preferred ma~ner of initiat~ng fra~tures in com~ination with ths sxpandable ca~ing portion~. Other meana may be u~ed, howe~er, for initiating the fracture in the preferr~d direction, that is, in a plane radiating outward generally perpendicular to the lo~gitudinal axis 38.
For example, FIG. 2A ia a view similar to FIG. 2 which illustrates an alternative m~thod of initiating the fracture in the pre~erred direction.
In FIG. 2A, a hydraulic j~tting teol 100 ha~ four jets 102, 104, 106 and 108 which nre locatod in a common plan~ and ~paced at 90 ~bout the longitudinal axis of the tool 100.
The ~etting tool 100 may be located within the ca~ing 20 and used to jet a first sot of four radial bores or cavitie~ 110, 112, 114 and 116. If more cavities are de~ired, the jetting tool 100 can then be rotated 45 to jet a ~econd set of four radial bores 118, 120, 122 and 124.
Then when hydraulic fracturing fluid is applied under~
pressure to the radial bores 110-124, a fracture will tend to initiate generally in the plane containing the radial bore~
110-124.
A~paratus For Formina Fan-Shaped Slot~
In FIG. 2, one form of apparatu3 28 for forming the fan~
sh~ped ~lot~ 34 is sch~matically illu~trated. The apparatus 2~2~7.~7 28 include~ a hou~ing 126 having a jet nozzle 128 on one side thereof. A po~itioning whesl 130 i~ carried by a tele~coping member 132 which extends when the telescoping ~ember 132 i8 filled with hydraulic ~luid under pre~ure.
When the apparatu~ 28 is ~ir~t located within the ca~ing 20 at the desirod location ~or creat$on of a fan-ahaped slot, hydraulic pressure i~ applied to the apparatua 28 thua cau~ing the tele~coping membsr 132 to extend the positioning wheffl 130 thu~ pushing the jot nozzle 128 up against the in~lde of the casing 20. Hydraulic fluid axiting the ~et nozzle 128 will ~oon form the opening such aE 36A in the casing 20. ~he tip of the ~et nozzle 128 will anter the opening 36A. Then, the apparatus 28 may be pivote~ bac~ and forth through a sl4w ~weeping motion o~ approximately 40 total movement. Using the opening 36A a~ the pivot point for the tip of the jet nozzle 128, thi~ back-and-forth sweeping motion will form the fan-shaped slot 34A.
FIG. 9 illu~trate~ an alternative ~hodiment o~ a hydrnulic ~etting tool for cutting the fan-~haped ~lots. The hydraullc ~etting tool of FIG. 9 i~ generally deaignated by the numeral 134. The apparatus 134 includes a housing 136 having an upper end wlth an upper end openlng 138 adapted to be connected to a conventional tubing ~trlng ~uch as 30 (aee FIG. 1) on which the zpparatu~ 134 i8 lowered into the well.
The tubing strlng 30 will preferably carry a centralizer ~not ohown) located a short distance above the upper end of the apparatu~ 134 80 that the apparatu~ 134 will have it~
2~2a797 longitudinal axi~ 140 locat~d generally centrally within the casing 20.
The hou~ing 136 ha~ an irregular paa~age 142 defined therethrough. The irregular pa~age 142 include~ an eccentrically off~et lower portion 144. A hollow shaPt 146 ha~ it~ upper end portion received within a bore 1~8 of eccentrie pa~sage portion 144 with an O-ring ~eal 150 being provided therebetween. An ~nd cap 152 i~ attached to housing 136 by bolts ~uch as 154 to hold the hollow ~haft 146 in plac~
relative to hou~ng 136.
A nozzle holder 156 i~ concentrically received about the lower end portion of hollow shaft 146 and is rotatably mount~d relative to end cap 152 by a swivel ~chematically illu~trated and gsnerally designated by the numeral 158. The hollow sha~t 146 hns an open lower end 160 co...unicatad with a ~avity 162 defined in the nozzle holder 156.
A laterally extendable tele~coping noz~le 164 i~ alao recelved in cavity 162. T~le~coping nozzle 164 include~ an outer portion 166, an intermediate portion 168, and an innermost portion 170.
When hydraul~c ~luid under pressure i~ providad to the cavity 162, the differential pre~eures acting on the innermost portion 170 and intermediate portion 168 of tele~coping nozzle 164 will cause the innermo~t portion 170 to move to the ls~t relative to intsrm~diate portion 168, and will cause the int0rmsdiate portion 168 to extend to the left relative to outer portion 164, ~o that an open outer end 172 of the ~12~7 tele~Goping nozzle 164 will extend to the position ~ho~n in phantom lines in FIG. 9.
Thu~, to uae the apparatus 134 of FIG. 9, the apparatus i~ lowered into the well on tha tubing ntring 30 until it i8 ad~acent the location where it i~ de~ired to cut the fan-shaped ~lot~. Then hydraulic fluid under pre~ure ia provided through tubing string 30 to the apparatu~ 134 to cau~ the telescoping nozzle 164 to extend outward to the po~ition ahown in phantom line8 in FIG. 9 wherein the open outer end 172 will be ad~acent the inn~r wall of the casing 20. Ths hydraulic fluid exit~ng the open end 172 will soon create an opening 36 in the wall of ca~ing 20 through which the outer end 172 of the inner nozzle portion 170 will extend. Then, the apparatu~
134 ~8 continuously rotatad about lts longitudinal axi~ 140 by rotating tubing string 30. The eccentric location o~ nozzle holder 156 will thu~ cau~e the nozzle 164 to pivot back and forth through an angle about tha opening 36 which form~ the pi~ot point for the outer end 172 of the telescoping nozzle 164. As the apparatus 134 rotates, the nozzle 164 will partially collapse and then extand ~o that open end 172 ~tays in opening 36.
After a first fan-shaped 810t auch as 34A ha~ been formed, hydraulic pre~eure i~ released while the apparatus 134 is rotated through an angle of approximately 90. Then hydraulic pressure is again applied and the tele3coping nozzle 174 will again be pre~ed against the inner w211 of casing 20 ~nd the process i~ repeated to for~ another fan-~haped slot 212~7~7 ~uch as 34B.
The ~mbodim~nt of FIG. 10 FIG. 10 is a view ~imilar to FIG. 2 ~howing the u~e of certain aspscts of the present invention in connection with a well wherein the horl~ontal portion of the well include~
portions of slotted caslng ~eparated by portion~ of ~olid ca~ing incorporating ~lip joint~ and utilizing the radial slotting technique~ of the pre~ent invention.
In FIG. 10, the horizontal portion of the well include~
first, second and third segments of slotted casing designated as 172, 174 and 176, respectively. Those ~egment~ of ~lotted casing are surrounding by open portion~ of the borehole 12 ~o that the borehole 12 freely com~u~icates with the interior o~
the slotted caaing through slots such as generally ds~i~nated as 178. Tho borehole surrounding the slotted casing ~egment~
may be gravel packed.
Located between the segments of ~lottsd casing are fir~t and second segments of solid ca~ing 180 and 182. Each segment of solld casing includes expandable casing portions such as previously described with regard to FIGS. 6 and 7.
The wellbore adjacent each of the segments 180 and 182 of aolid casing is ~pot-cemented as indicated at 184 and 186, respectively. The segments of ~olid casing ar0 then communlcated with the zones 24 and 26, re~pectively, through the use of the radial ~lotting techniques previously de0cribed wherein alots 34 and openings 36 are formed through the solid casing at location~ between the expandable casing portions.
,f , ~l2n~7 Then, a ~traddle packer ~not shown) can be low~red on tubing ~tring into th~ casing ~o a~ to fracture the zone~ of intere~t 24 and 26 individually through their fan-chaped ~lot~
34. Ths expandable caaing portion~, along with the fan-Rhaped 810t8 34, will cau6e ~he fracture~ to radiate outward into the zone~ 24 and 26 while tha spot-cQment 184 and 186 will still provide isolation between the zones 24 and 26.
Thus it i~ seen that the pre~ent i~vention readily achieve~ the ends and advantagsæ mentioned ae well a3 tho~e inherent therein. While certain preferrsd Qmbodiment~ of the invention have been illustrated and described for purpose~ of the pre~ent disclosure, numerou~ change~ may be made by those ~killed in the art which changes are oncompa~ed within the ~cope and ~pirit of the pre~ent invention as defined by th~
apponded claims.
This i8 a continuation in part of co-pending ~pplication Serial No. 07/953,671, filed Septamber 29, 1992.
Ba~qr~und Of Tho I~vQntion 1. Fiold Of The InYe~tion The pre~ent invention relate~ generally to the completion of oil and gas wells through fracturing oper~tion~, and more particularly, but not by way of limitation, to the completion of wells in which the formation tends to open up in ths direction of the wellbore.
2. Doscription Of The Prior Art Several different technigues are currently u~ed for the completion of horizontal well~.
A first, very common manner of completing a horizontal well is to case and cemont the vertical portion of the well and to leave the horizontal portion of the well which run~
through the producing formation as an open hole, i.e., that is without any casing in place therein. Hydrocarbon fluids in the formation are produced into the open hole and then through the casing in the vertical portion of the well.
A second technique which is commonly u~ed for the completion of horizontal well8 i~ to place a length of slotted caelng in the horizontal portion of the well. The purpose of the slotted ca~ing i~ to pre~ent the open hole ~rom collapsing. A gravol pack may be placed around the slotted casing. The slotted casing may run for extended length~
through the formation, for example as long as one mile.
A third technigue which i3 sometimes used to complete .
2~2~7~7 horizontal well8 i8 to C~ment casing in both the vertical and horizontal portio~ of the well and then to provide communication between the horizontal portion of the casi~g and the producing formation by mean~ of perfor~tions or caslng valve~. The formation may al~o be fractured by creating fracture~ initiating at the location of the perforation~ or the casing valve~.
In this third technique, the formation of perforations is often done through u~ of explosive charge~ which are carried by a perforating gun. The explosive charges crsate holes which penetrate the side wall of the casing and penetrate the c~ment ~urrounding the casing. Typically, the holes will be ln a pattern extending over a ~ubstantial length of the ca~lng.
When the communication betwaen the casing and the producing fonmRtion is provided by ca~ing valve~, tho~e valves may be like tho~e seen in U. S. Patent No. 4,949,788 to Szarka et al., U. S. Patent No. 4,979,561 to Szarka, U. S. Patent No.
4,991,653 to Sahwegman, U. S. Patent No. 5,029,644 to Szarka et al., and U. S. Patent No. 4,991,654 to 8randell et al., all as~igned to the as0ignee of the pre~ent invention. Such casing valves al~o provide a large number of radial bore type openings communicating the ca~ing bore with the ~urrounding formation.
When utilizing either perforated caRing or ca~ing Yalves like those just described, the fracturing fluid enters the formation through a large multitude of ~mall radial bores at . .
2~ 2~7~7 a variety of longitudinal position~ along the casing and there is no accurate control over where the fracture will initiate and in what direction the fracture will initiate.
In the context of ~ub~tantially deviated or horizontal wells, the cementing of ca~ing into the horizontal portion of the well followed by subsequent fracture treatment~ ha~ not been as ~ucce~sful as desired when u~lng existing techniques, e~pecially when multiple zone fracturing i~ involved.
Su~m~ry Of The In~Rntion It ha~ been determined that ona of the rea~on~ fracturing of horizontal well8 has not been completely satisfactory in the past i8 that when a fracture radiatec outward in a plane tran~vor~e to and preferably perpendicular to the longitudinal axl~ of the ca~ing, the subsurface formation tends to move on either side of the fracture in a direction generally parallel to the longitudinal axis of the ca~ing, but the ca~ing its21f cannot move. Thu~, the relative mov~ment between the ~ubsurface formation and the ca~ing often cau~es a destruction of the bond between the casing and the surrounding cement.
Thi~ destruction of the cement/casing bond may extend for large distances thus providing a path of communication between adjacent eub~urface formatione which are to be fractuxed.
The improved fracturing technique of the preEent invention eliminatas this problem. This i~ accomplished by providing expandable casins portions adjacent the location where the fracture is to be initiated. Preferably, Ruch expandable CaBing portionc are pro~ided on both sides of the ~ 212~7'37 fracture initiation location. The expandable ca~ing portion~
allow the ca~ing to ~ove with the expanding formation when fracturing occur~. This aid~ in preventing a de~truc~ion o$
the bond between the c~ment and the ca~ing. Preferably, the U~Q of expandable ca~ing portions i8 accompanied by the provi~ion of a mean~ for directing the initial direction of fractu_e initiation ~o that the fracture initiate~ in a plane generally perpendicular to the longitudinal axi~ of the casing.
It has been deter~ined that another rea~on fracturing of hoxizontal wells ha~ not been co~pletely ~aticfactory in the pa~t is that the ~tressee which are created withln the formation immediately ~urrounding the casing and cement in a horizontal well are uuch th~t quite often the fracture will not radiate outward in a plane perpendicular to the axis of the well as ic ~oct de~irable, but instead quite often the fracture will run parallel to the ca~ing and thu~ will allow communication between adjacent formation~
The present invention include~ an improved method for initially communicating the ca~ing bore with the surrounding formation co ac to provide a predetermined point of initiation of the fracture and ~o as to provide directional guidance to the fracture when it i8 initiated.
This method i~ accompli~hzd by inserting a hydraulic ~etting tool into the ca~ing. One or more opening~ are formed through the cas~ng, and preferably tho~e opening~ are formed by the hydraulic ~etting tool it6elf.
2~2~7~7 The hydraulic jetting tool i8 then u~ed to direct a hydraulic jet through the opening ~n the ca~ing and the jetting tool i~ pivoted ~o a~ to cut one or more fan-~haped slot~ in the aurrounding formation in a plane tran~ver~e to the longitudinal axis of the casing. Each of the~e fan-shaped ~lot~ circ~mscribes a ~ubstantially larger arc ~bout the axi8 of the caslng than does the opening through ~hich the slot wa~
cut.
Prefer~bly these fan-~haped slots lie in a plane sub~tantially perpendicular to the longitudinal axi~ of the ca~ing.
Sub~equently, when fracturing fluid i~ applied under pro~ure to the fsn-~haped slot~, the fracture will initiate in the plane of the fan-shaped elcte and will at leaEt initially radiate outward from the wellbore along that plane.
This will occur regardle~a of the orientation of the natural lea0t principal stre~ axi~ within the ~urrounding formation.
The provi~ion of the fan-~haped ~lot~ will allow initiation of the fr~lcture and allow it to move outward away from the wellbors ~ufficiently ~o that the direction of the fracture will not be controllod by the local ~tre~se~
immediatoly ~urrounding the cAsing and wellbore which might otherwi~e cau~e the fracture to follow the wellbore.
Numeroun objects, features and advantage~ of the present invontion will be readily apparent to tho~e ~killed in the art upon a reading of the following dl~closure when taken in conjunction with the accompanying drawing~.
212~7~7 Brief De~cription 0~ Thn Dr~i~s FIG. 1 i~ an elevation sch~matic ~ectioned view of a well having a horizontal portion which has b~en ca~ed and cemented.
The formation i~ ~hown as having had radially extending fan-~3hap2d slot~ cut therein.
FIG. 2 i8 a schematic view taken along line 2-2 of FIG.
1 $n a plane perpendi~ular to the longltudinal axis of the wellbore ~howing four fan-~hapedl310ts ~urrounding the cal3ing.
FIG. 2A il3 a view ~imilar to FIG. 2, ~howing a pattern of eight radially extending bores located ln a ~ommon plane perpendicular to the axi~ of the wellbore.
FIG. 3 is a schomatic illustration of the problem pre0ent in the prlor art when multiple zon~s of a horizontal well are fractur~d, with tho fracture propagating parallel to the wellbore oo that the zones communicate with each other.
FI~. 4 i8 a schematic illustration of the manner in whic~
fracturos will propagate from the well utilizing the fan-shapsd slots of the present invention when the least principal stres~ of the surrounding formation lies genQrally parallel to the longitudinal axil3 of the wellbore.
FIG. 5 i~ a view 13imilar to FIG. 4 showing the manner in which fractures will propagate from the well utilizing the fan-shaped slotl3 of the present invention when the least principal stre~ of the surrounding formation liel3 at an angle substantially tranl3verse to the longitudinal axil3 of the wellbore. The fracture~ initially propagate outward in a plane perpendicular to the wellbore and then turn in a 7 21207~7 direction perpendicular to the lea~t principal ~tre~ in the surrounding formation.
FIG. 6 is a ~ch~Iatic ~ectioned view of a portion of a horizontal well having a fir~t embodiment of the expandable ca~ing portions located in the Gasing on oppo~ite aide~ of the location of the fan-0haped ~lot~.
FIG. 7 is a achematic 0ectloned view of a portion of a horizontal well having an alternate embodiment of the expandable casing portions positioned in the casing on opposite side~ of ~ha location of the fan-~haped slot~.
FIG. 8 show~ the alternate embodiment expandable casing portion in an expanded position.
FIG. 9 is a se~tioned elevation view of an alternative apparatus for cutting the fan-shaped ~lota.
FI~. 10 is a ViQW similar to FIG. 1 illu~trating tho use of tho invention in co~bination with slotted cas~ng in an open borehole in parts of the horizontal portion of the well.
D~tailed Des~riptio~ Of The Preferred Eobodi~enta Referring now to the drawings, and particularly to PIG.
1, a well is ehown and generally de~ignated by the numeral 10.
The well is formed by a wellbore 12 which extends downward from the earth'~ surface 14. The wellbore 12 is illustrated a~ havlng an lnitial, generally vertical portion 16 and a lower, generally horizontal portion 18, but the invention may be applicable to other well confiyurations.
The well 10 includes a casing string 20 which i3 located within the wellbore 12 and cemented in place therein by cement 8 2~2~7~7 22.
The horizontal portion 18 of wellbore 12 in ~hown a~
inter~ecting a ~ubterranean ~ormation 23 in which are located two imaginary zones which are to be fractured. The zone~ are outlined in phantom line~ and are generally deæignated by the :~
numeral~ 24 and 26. ~ :
A hydraulic jetting tool ~chamatically illustrated and designated by the numeral 28 ha~ been lowered into the casing 20 on a tubing string 30. A conventional wellhead 32 i8 located at the upper end of the w811 at the earth'a ~urface.
A ~ource of high pre~sure fluid 33 i0 connected to the tubing string 30 to provide hydraulic fluid under high pressure to the hydraulic jetting tool 28.
In the first zone 24, two fan-~haped ~lot~ 34A and 34C
are shown ln crosu ~ection extending through the c~ment 22 into the surrounding zone 24. The ~lots have been cut by the hydraulic ~etting tool 28 in a manner further de~cribed below.
FIG. 2 is a cro~-sectio~al view taken along line 2-2 of FIG. 1 and ~howing a preferred pattern of fan shaped ~lots including four fan-~haped ~lots 34A, 34B, 34C and 34D.
A~ ~een in FIG. 2, thsre i~ associated with each of the fan-ehaped ~lot~ 34A, 34B, 34C and 34D an opening 36 formed through the casing 20. The~e opening~ are designated by the numeral~ 36A, 36B, 36C and 36D, re~pectively.
The fan-shaped i810t~ 34 are ahown as lying in a plane ~ubstantially perpendicular to a longitudinal axi~ 38 of the horizontal portion of the aasing 20. ~: :
- 9 2~2~79~
In F~G. 2, the hydraulic jetting tool 28 ia shown in po~ition for formation of the opening 36A and radial fan-~haped ~lot 34A.
Preferably, the opening 36A i~ for~ed through the ca~ing 20 by the hydraulic jetting action of jetting tool 2~. ~hen, using the opening 36A a~ a ba~e or pivot point, ths hydraulic jetting tool 28 i~ rotated bac~ and forth through an arc corresponding to an angle 37 formed by the fan-shaped slot about ths point of the opening 36A ao that the hydraulic jet which shoots through the opening 36A will cut the fan-~haped slot 34A.
As i8 apparent in FIG. 2, the fan-~haped ~lot 34A
circumscrlbes a sub~tantially larger arc about the axis 38 of caslng 20 than doe~ the small open~ng 36A through which the fan-shaped slot 34A was cut.
In it~ broadeet terms, the fan-shaped slot concept doe~
not reguire that the pivotal ba6e of ~he slot 34 be located at the opening 36. It is reguired, however, that the slots be formed in a manner such t~at the ~tructural integrity of the casing 18 malntained.
Although it is preferred to form the opening~ 36 by the hydraullc jetting action ju~t de~cribed, it is also within the ecope of the pre~ent invention to u~e preformed holes, such as those which would be provided by a ca~ing valve like that shown in Brandell et al., U. S. Patent No. 4r991~654~ in which caue the jetting tool 28 would be located adjacent an existing hole provided in the ca~ing valve and the fan-shaped ~lot~
212~7~7 would be cut through the existing holeR of the ca~ing valve.
It is also within the ~cope of the preeent invention to cut the fan-shaped slots 34 in planea other than plane~
perpendicular to the longitudinal axi~ 38. Al~o, the fan-shaped ~lot~ may be cut in a vertical portion rather than a hor~zontal portion of the well.
Furthermore, it i~ possible to cut the fan-shaped ~lots 34 to modify the well 10 for rea~ons other than fracturing the well. For example, the fan-shaped ~lots 34 may be utilized as a substitute for perfcration~ communicating the casing bore with the ~urrounding formation.
~ y forming the fan-shaped slotc 34 a~ shown in FIG. 2 wherein each ~lot 34 circumscribes a ~ubatantially larger arc bout the lon~itudinal axis 38 than doe~ the opening 36 through which the clot i~ formed, the integrity of the ca~ing, i.e., the structural ~trength of the casing, is mzintained.
FIG. 3 illustrates a probl~m which occurs with prior art fracturing techniques for horizontal wells. It will be appreclated that FI~. 3 is a very schematic illustration.
FIG. 3 generally sho~ws the WQll ca~ing 20 cemented in place within the wellbore 12 by cement 22.
Two subsurface zones to be fractured, such as zones 24 and 26 are illustrated. The location of opening~ ~uch as perforation~, casing valvee or the like at locations adjacent zones 24 and 26 are ~chematically illustrated by the opening~
39 and 40, respectively. The opening~ 39 and 40 are only schematically repre~entative of some type of communication 11 212~7~7 between the caeing bore and the zone~ 24 and 26, re~pectively, which iB pre~ent prior to the fracturing of the well.
One problem which often occur~ when fracturing horizontal wells i~ that, when the fracture is initiated, the fracture will prop gate generally parallel to the longitudinal axi~ 38 of the ca~ing 20. Thi~ occurs due to the local stre~e~
immediately ~urrounding the ca~ing 20 and cement 22, and often it occurs around the cement/formation bond, and thu~ w~ll create a fracture space generally de~ignated at 42 which generally follows the wellbore and may in fact provide communication batween the two sub~urface zone~ 24 and 26.
Thus even if individual fracturing jobs are performed on the two zones 24 and 26, if a path of communication is fo~med botweon those zone~, it may be that one or both ~f the zones wlll not be satisfactorily fractured, and of course individual production from the zones will not be possible. When the second zone i~ being fractured, a~ soon a~ the fracture space 42 co....unicates with another previously opened or fractured area, typically fracture growth will cea~e because the surface pump supplying the fracturing fluid will typically not have ~uffic~ent fluid flo~w to maintain fracturing pres~ure~ once the fr~cture is opened to a large, previou~ly opened zone.
This problem iQ avoided by the u~e of the fan-shaped slots previously described as is schematically illu~trated in FIGS. 4 and 5.
FIG. 4 schematically illu~trates the ~ituation which will occur when utilizing the method of the pre~ent invention, - 12 21207~7 when the least principal ~xe89 axia 41 naturally pre~ent in the surrounding formation~ lies generally parallel to the longitudinal axis 38 of the ca~ing 20. If the opening~
generally represented at 39 and 40 are for~ed utilizing the fan-shaped ~lots illustrated in FIGS. 1 and 2, then the resulting fractures 43 and 44, respectively, will initiate in the plane of the fan-shaped alots 34 and will continue to radiate radially outward in generally that same plane a~
illustrated in FIG. 4. Thsre will bs no int0rcom~unication between tho zone~ 24 and 26 and each zons will be fractured in the de~ired manner.
FIG. 5 cimilarly illu~trateu what will happen when ~he least principal ~tress axis 48 i8 transverse to the longltudinal axis 38.
Again, the fractures will initiate and initially propagate outward in radial plane~ as indicated at 50 and 52, and will then turn in a direction generally perpendicular to the least principal 13tre88 axi8 48 as indicated at 54 and 56, respectively.
Thus, in both of the cases ahown in FIGS. 4 and 5, the fracture will initiate in the plans defined by the fan-~haped ~lots and will initially propagate a sufficient di~tance outward away from the casing 20 BO that the local ~tre~e~
around the casing 20 will not determine the ultimate direction of propagation of the fracture. Ths ultimate direction of propagation of the fracture will be determined by the least principal stres~ axis 41 or 48 present in the ~urrounding ;'' 2~2~797 formation.
The fan-~haped 810t8 34 ean be de~cribed a~ creating a localized least principal ~tre~s axis or direction in the fo~tion ~ub~tantially parallel to the longltudinal axi~ 38 thereby aidi~g subseq~ent fracture initiation in a plane generally perpendicular to the longitudinal axi~ 38.
The well 10 ha~ been de~cribed herein as a ~b~tant~ally deviated well or horizontal well. It will be appreciated that the well need not be axactly horizontal to benefit from the preaent invention. Furthermore, even some sub~tantially ~ertical wells may in come ca~e~ benefit from the use of the pre~ent invention. Ae used herein, the term highly deviated or substantially deviated well generally refers to a well the axis of whlch is devlated greater than 45 from a vertical direction.
The Use Of ~Dandabls Ca~i~g Portionc FIGS. 6 and 7 illustrate another aspect of the pre~ient invention, which improves the succe~s of fracturing operations on horizontal well~ by the u~e of expandable ca~ing joint~.
In the embodiment illuatrated in FIG. 6, the expandable ca~ing portions are characterized by casing ~lip joint~, and in FIG.
7, the expandable casing portions are characterized by expansion ~oint~ which function in a bellows-type manner.
The preferred orientation of fracture~ radiating outward from a horizontal well are gsnsrally like tho~e de~cribed above with regard to FIGS. 4 and 5. One additional probl~m that occurs, however, particularly in connection with ~ 2120~97 horizontal well~, i8 that when the fracture radiate~ outward in a plane perpsndicular to the axis 38 of the well, this causes the ~urrounding rock formation to move in a direction parallel to the axis 38 of the well. Referring for example to the fracture 43 ~een in FIG. 4, that portion of the fonmation to th~ right of the fracture 43 would move to the right, and that portion of the formation to the left of fracture 43 would move to the left relatively ~peaking. Tha ca~lng 20, however, cannot move in either direction, and it cannot ~tretch ~ufficiently to accommodate the movemant of the surrounding formation. Thus, the movement of the surrounding formation relative to the casing may cause the bond between the c~ment 22 and the casing 20 to break down. This i8 particularly a problem when the fracturing of multiple ~ubsurface zones ia lnvolved, ~ince thi~ breakdown of the c~ment-to-casing bond will allow a path of communication between multiple zone~
which were intended to be isolated from each other by the cement.
The formation and cement will attempt to move relative to the casing 20. Sin~ca the cement generally has low shear strength of about 300 p~i and a modulue of cla~ticity of about 1,000,000 psi, it can be predicted that the bond between the cement and cauing will fail. The length of cuch a failure can be predicted by the following formula:
L = FW x 2/S
Where FW i~ the maximum fracture width during pumping, E is the modulus of ela~ticity, and S i~ the ~hear ~trength of the 2~797 cement bond. Xn a typical ~ituation, the de~trllction length, that is, the length over which the ca~ing/cement bond i~
destroyed, can exceed 800 feet. Thi~ can become a major cau~e of zone co~munication and will make fracturing treatments of closely ~paced zones le~s effective. Therefore, it iB
important to provide a meana whereby thi~ hreakdown of the cement/ca~ing bo~d will not ocaur.
In FIG. 6, fir~t and ~econd ca~ing slip joints 55 and 57 are provided on opposite side~ of the fan-shaped ~lot~ 34.
Then, when fracturing fluid i~ pu~ped into th¢ ~an-~haped ~lot~ 34 to crea~e and propagate a fracture like fracture 43 ~een in FIG. 4, the ~lip joint~ 55 and 57 will allow movement of the casing 20 on opposite side~ of the fracture along with the ~urrounding formation, thu~ preventing the destruct~on of the bond between the casing 20 and cement 22 ~urrounding the casing during the fracturing operation.
The ea~ing ~lip jointP 55 and 57 are schematically illu~trated in FIG. 6. Each include~ two telescoping portion~
euch a~ 58 and 60, preferably including ~liding seals auch as 62 and 64.
Whsn the ca~ing 20 i~ placed in the wellbore 12 and prior to plac~ment of the c~ment 22 around the ca~ing 20, ~teps should be taken to insure that the slip ~oints 55 and 57 are in a substantially collap~ed po~ition a~ shown in FIG. 6 ~o that there will be ~ufficient travel in the jointE to allow the necessary movement of the CaBing. Thi~ can be accompli~hed by ~etting down weight on the ca~ing 20 after it r~ ~
16 2~ 2~7~7 ;:
has been placed in the wellbors and before the cement 22 i9 placed or at lea~t before the cement 22 ha~ opportunity to ~et up.
Although two 81ip joint~ 55 and 57 are shown in FIG. 6 on oppoeite longitu~inal sidea of the openings 36, it will he appreciated that in many in~tances, a ~ingl~ 81ip joint will ~uffice to allow the neces~ary movament of the ca~ing. It iE
preferred, however, to provide ca~ing alip joints on both si~ea of the opening~ 36 to in~ure that any debonding of t~e cement 22 and ca~ing 20 which may initiate ad~acent the openings 36 will terminate when it reaches e$ther of the 81ip joint~ 55 and 57 and will not propagate beyond the ~lip Joint~. Thi~ prevente any destruction of the cement/ca~ing bond on a side of the elip joint~ longitudinally oppoaite the oponing~ 36.
In FIG. 7, another embodiment of the expandable casing portions i~ ~hown and characteriz~d by first and ~econd ca~ing expan~ion ~oints 200 and 202 which are pro~ided on oppo~ite ~idee of the fan-shaped ~lot~ 34. When fracturing fluid i3 pumped into the fan-~haped ~lot~ 34 to create and propagate a fracture like fracture 43 ~een in FIG. 4, the expan~ion ~oint~
200 and 202 will allow movement of the ca~ing 20 on oppo~ite ~ide~ of the fracture along with the ~urrounding formation, thua preventing th~ de~truction of the bond between a ca~ing 20 and cament 22 aurrounding the ca~ing during the fracturing operation.
Casing joints 200 and 202 are schematically illu~trated ~120~97 in FIG. 7. Each i8 generally tubular in configuration and has a plurality of annular, outer grooves 204 defined therein and a corresponding plurality oF annular, inner groove~ 206 defined therein. Inner groo~e~ 206 are ~taggered with re6pect to outer groove~ 204 ~uch that the outer and inner groove0 are alternately positioned a~ sho~n in FIG. 7.
Thus, each of casing expan~ion joint~ 200 and 202 ~ay be ~aid to compriae a plurality of outer wall ~egmznt~ 208 between corresponding pairs of outer groovs~ 204, and similarly, a plurality of inner wall ~egment~ 210 between corresponding pair~ of inner groo~ee 206. It will be aeen that an inner groove 206 i~ locat~d radially inwardly from each outer wall segment 208, and an outer groove 204 is located radlally outwardly from each inner wall se~ment 210.
Preferably, the outside diameter of i~ner groove~ 206 ~8 so~ewhat larger than the inside diameter o~ outer grooves 204 such that an annular, i~ter~ediate wall segment 212 is formed between ad~acent inner and outer groove~. It will be 3een that lntermediate wall segments 212 thus interconnect outsr wall segments 208 and inner wall aegment~ 210.
Caslng expanslon ~olnts 200 and 202 are posltioned in the caslng 20 as shown ln FIG. 7, and the c~ment 22 18 placed around the casing in the normal manner. It is not nece6~ary in this alternate embodiment to set down weight on the casing 20 after it has been placed ln the wellbore and before the cement 18 placed, as i~ nece~ary to cGllap~e the casing slip ~olnt~ S5 and 57 of tho first embodiment shown in FIG. 6.
r~
2~2~7~7 The configuration of ca~ing expan3ion joints 200 and 202 i8 such that each ca~ing expansion joint provide~ a controlled weakensd sQction of tha ca~ing string. During fracturing, casing expansion jointæ 20~ and 202 ~llow mov~ment of the casing 20 on oppo~ite ~ide~ of the fracture by the expan~ion of the ca~ing sxpan~ion joint~. RePerring to FIG. 8, thi~
expansion is illu~trated. Intermediate wall ~eg~ents 212 provide the controlled weak point in ca~ing expansion joints 200 and 202, and expan~ion thereof re~ult~ in deflection of the intermediate wall segment~ in a bellows-like manner. That i~, inner groove0 206 and outer grooves 204 are widened ~uch that intermediate wall segments 212 will generally extend annularly between outer wall segments 208 and inner wall oogment~ 210. Thu~, there i8 movement allowed in the ca~ing a~ the fracture is propagated which prevents the de~truction of the bond between the casing 20 and c~ment 22 surrou~ding the ca~ing. Al~o, in the ~bodiment of FIGS. 7 and 8, no sealing means is re~uired as in the slip ~oint configuration of FIG. 6.
The formation of the $an-shaped elot~ 34 can be generally described as form~ng a cavity 34 in the formation 23 and ther~by crenting in the ~ubsurface formation 23 ad~acent the cavity 34 a localized lea~t principal stre~0 direction ~ubctantially parallel to the longitudinal axis 38 of the ca~ing 20. Thu~, the fracture such as 43 (see FIG. 4) will initiate in a plane generally perpendicular to the longitudinal axi~ 38.
212~797 ~9 It will be appreciated that the a~pect of the present invention utilizing the expandablc c~sirlg portions may be used without the u~e of the fan-shaped 810t~ de~cribed in FIGS. 1 and 2. The u~e of the fan-~haped slot~ i~ the preferred ma~ner of initiat~ng fra~tures in com~ination with ths sxpandable ca~ing portion~. Other meana may be u~ed, howe~er, for initiating the fracture in the preferr~d direction, that is, in a plane radiating outward generally perpendicular to the lo~gitudinal axis 38.
For example, FIG. 2A ia a view similar to FIG. 2 which illustrates an alternative m~thod of initiating the fracture in the pre~erred direction.
In FIG. 2A, a hydraulic j~tting teol 100 ha~ four jets 102, 104, 106 and 108 which nre locatod in a common plan~ and ~paced at 90 ~bout the longitudinal axis of the tool 100.
The ~etting tool 100 may be located within the ca~ing 20 and used to jet a first sot of four radial bores or cavitie~ 110, 112, 114 and 116. If more cavities are de~ired, the jetting tool 100 can then be rotated 45 to jet a ~econd set of four radial bores 118, 120, 122 and 124.
Then when hydraulic fracturing fluid is applied under~
pressure to the radial bores 110-124, a fracture will tend to initiate generally in the plane containing the radial bore~
110-124.
A~paratus For Formina Fan-Shaped Slot~
In FIG. 2, one form of apparatu3 28 for forming the fan~
sh~ped ~lot~ 34 is sch~matically illu~trated. The apparatus 2~2~7.~7 28 include~ a hou~ing 126 having a jet nozzle 128 on one side thereof. A po~itioning whesl 130 i~ carried by a tele~coping member 132 which extends when the telescoping ~ember 132 i8 filled with hydraulic ~luid under pre~ure.
When the apparatu~ 28 is ~ir~t located within the ca~ing 20 at the desirod location ~or creat$on of a fan-ahaped slot, hydraulic pressure i~ applied to the apparatua 28 thua cau~ing the tele~coping membsr 132 to extend the positioning wheffl 130 thu~ pushing the jot nozzle 128 up against the in~lde of the casing 20. Hydraulic fluid axiting the ~et nozzle 128 will ~oon form the opening such aE 36A in the casing 20. ~he tip of the ~et nozzle 128 will anter the opening 36A. Then, the apparatus 28 may be pivote~ bac~ and forth through a sl4w ~weeping motion o~ approximately 40 total movement. Using the opening 36A a~ the pivot point for the tip of the jet nozzle 128, thi~ back-and-forth sweeping motion will form the fan-shaped slot 34A.
FIG. 9 illu~trate~ an alternative ~hodiment o~ a hydrnulic ~etting tool for cutting the fan-~haped ~lots. The hydraullc ~etting tool of FIG. 9 i~ generally deaignated by the numeral 134. The apparatus 134 includes a housing 136 having an upper end wlth an upper end openlng 138 adapted to be connected to a conventional tubing ~trlng ~uch as 30 (aee FIG. 1) on which the zpparatu~ 134 i8 lowered into the well.
The tubing strlng 30 will preferably carry a centralizer ~not ohown) located a short distance above the upper end of the apparatu~ 134 80 that the apparatu~ 134 will have it~
2~2a797 longitudinal axi~ 140 locat~d generally centrally within the casing 20.
The hou~ing 136 ha~ an irregular paa~age 142 defined therethrough. The irregular pa~age 142 include~ an eccentrically off~et lower portion 144. A hollow shaPt 146 ha~ it~ upper end portion received within a bore 1~8 of eccentrie pa~sage portion 144 with an O-ring ~eal 150 being provided therebetween. An ~nd cap 152 i~ attached to housing 136 by bolts ~uch as 154 to hold the hollow ~haft 146 in plac~
relative to hou~ng 136.
A nozzle holder 156 i~ concentrically received about the lower end portion of hollow shaft 146 and is rotatably mount~d relative to end cap 152 by a swivel ~chematically illu~trated and gsnerally designated by the numeral 158. The hollow sha~t 146 hns an open lower end 160 co...unicatad with a ~avity 162 defined in the nozzle holder 156.
A laterally extendable tele~coping noz~le 164 i~ alao recelved in cavity 162. T~le~coping nozzle 164 include~ an outer portion 166, an intermediate portion 168, and an innermost portion 170.
When hydraul~c ~luid under pressure i~ providad to the cavity 162, the differential pre~eures acting on the innermost portion 170 and intermediate portion 168 of tele~coping nozzle 164 will cause the innermo~t portion 170 to move to the ls~t relative to intsrm~diate portion 168, and will cause the int0rmsdiate portion 168 to extend to the left relative to outer portion 164, ~o that an open outer end 172 of the ~12~7 tele~Goping nozzle 164 will extend to the position ~ho~n in phantom lines in FIG. 9.
Thu~, to uae the apparatus 134 of FIG. 9, the apparatus i~ lowered into the well on tha tubing ntring 30 until it i8 ad~acent the location where it i~ de~ired to cut the fan-shaped ~lot~. Then hydraulic fluid under pre~ure ia provided through tubing string 30 to the apparatu~ 134 to cau~ the telescoping nozzle 164 to extend outward to the po~ition ahown in phantom line8 in FIG. 9 wherein the open outer end 172 will be ad~acent the inn~r wall of the casing 20. Ths hydraulic fluid exit~ng the open end 172 will soon create an opening 36 in the wall of ca~ing 20 through which the outer end 172 of the inner nozzle portion 170 will extend. Then, the apparatu~
134 ~8 continuously rotatad about lts longitudinal axi~ 140 by rotating tubing string 30. The eccentric location o~ nozzle holder 156 will thu~ cau~e the nozzle 164 to pivot back and forth through an angle about tha opening 36 which form~ the pi~ot point for the outer end 172 of the telescoping nozzle 164. As the apparatus 134 rotates, the nozzle 164 will partially collapse and then extand ~o that open end 172 ~tays in opening 36.
After a first fan-shaped 810t auch as 34A ha~ been formed, hydraulic pre~eure i~ released while the apparatus 134 is rotated through an angle of approximately 90. Then hydraulic pressure is again applied and the tele3coping nozzle 174 will again be pre~ed against the inner w211 of casing 20 ~nd the process i~ repeated to for~ another fan-~haped slot 212~7~7 ~uch as 34B.
The ~mbodim~nt of FIG. 10 FIG. 10 is a view ~imilar to FIG. 2 ~howing the u~e of certain aspscts of the present invention in connection with a well wherein the horl~ontal portion of the well include~
portions of slotted caslng ~eparated by portion~ of ~olid ca~ing incorporating ~lip joint~ and utilizing the radial slotting technique~ of the pre~ent invention.
In FIG. 10, the horizontal portion of the well include~
first, second and third segments of slotted casing designated as 172, 174 and 176, respectively. Those ~egment~ of ~lotted casing are surrounding by open portion~ of the borehole 12 ~o that the borehole 12 freely com~u~icates with the interior o~
the slotted caaing through slots such as generally ds~i~nated as 178. Tho borehole surrounding the slotted casing ~egment~
may be gravel packed.
Located between the segments of ~lottsd casing are fir~t and second segments of solid ca~ing 180 and 182. Each segment of solld casing includes expandable casing portions such as previously described with regard to FIGS. 6 and 7.
The wellbore adjacent each of the segments 180 and 182 of aolid casing is ~pot-cemented as indicated at 184 and 186, respectively. The segments of ~olid casing ar0 then communlcated with the zones 24 and 26, re~pectively, through the use of the radial ~lotting techniques previously de0cribed wherein alots 34 and openings 36 are formed through the solid casing at location~ between the expandable casing portions.
,f , ~l2n~7 Then, a ~traddle packer ~not shown) can be low~red on tubing ~tring into th~ casing ~o a~ to fracture the zone~ of intere~t 24 and 26 individually through their fan-chaped ~lot~
34. Ths expandable caaing portion~, along with the fan-Rhaped 810t8 34, will cau6e ~he fracture~ to radiate outward into the zone~ 24 and 26 while tha spot-cQment 184 and 186 will still provide isolation between the zones 24 and 26.
Thus it i~ seen that the pre~ent i~vention readily achieve~ the ends and advantagsæ mentioned ae well a3 tho~e inherent therein. While certain preferrsd Qmbodiment~ of the invention have been illustrated and described for purpose~ of the pre~ent disclosure, numerou~ change~ may be made by those ~killed in the art which changes are oncompa~ed within the ~cope and ~pirit of the pre~ent invention as defined by th~
apponded claims.
Claims (21)
1. A method of fracturing a subsurface formation of a well having a well casing cemented in a borehole intersecting said subsurface formation, comprising:
(a) providing an opening through said casing communicating an interior of said casing with said subsurface formation;
(b) providing at least a first expandable casing portion in said casing;
(c) communicating a fracturing fluid through said opening to said subsurface formation;
(d) applying pressure to said fracturing fluid and through said opening to said subsurface formation;
(e) initiating a fracture in said subsurface formation adjacent said opening;
(f) during step (e), allowing said casing to move with said subsurface formation by means of expansion of said first expandable casing portion; and (g) thereby preventing destruction of a bond between said casing and cement surrounding said casing during step (e).
(a) providing an opening through said casing communicating an interior of said casing with said subsurface formation;
(b) providing at least a first expandable casing portion in said casing;
(c) communicating a fracturing fluid through said opening to said subsurface formation;
(d) applying pressure to said fracturing fluid and through said opening to said subsurface formation;
(e) initiating a fracture in said subsurface formation adjacent said opening;
(f) during step (e), allowing said casing to move with said subsurface formation by means of expansion of said first expandable casing portion; and (g) thereby preventing destruction of a bond between said casing and cement surrounding said casing during step (e).
2. The method of claim 1, wherein:
in step (a), said opening is provided in a highly deviated portion of said well.
in step (a), said opening is provided in a highly deviated portion of said well.
3. The method of claim 2, wherein:
in step (a), said opening is provided in a substantially horizontal portion of said well.
in step (a), said opening is provided in a substantially horizontal portion of said well.
4. The method of claim 1, wherein:
step (b) includes providing a second expandable casing portion in said casing, said first and second expandable casing portions being on opposite longitudinal sides of said opening.
step (b) includes providing a second expandable casing portion in said casing, said first and second expandable casing portions being on opposite longitudinal sides of said opening.
5. The method of claim 1, wherein:
step (g) includes terminating any destruction of said bond at said expandable casing portion and thereby preventing any destruction of said bond on a side of said expandable casing portion longitudinally opposite said opening.
step (g) includes terminating any destruction of said bond at said expandable casing portion and thereby preventing any destruction of said bond on a side of said expandable casing portion longitudinally opposite said opening.
6. The method of claim 1 further comprising:
forming said opening in a cavity in said formation and thereby creating in said subsurface formation adjacent said cavity a localized least principal stress direction substantially parallel to the longitudinal axis of said casing: and in step (e), initiating said fracture at said cavity in a plane generally perpendicular to said longitudinal axis.
forming said opening in a cavity in said formation and thereby creating in said subsurface formation adjacent said cavity a localized least principal stress direction substantially parallel to the longitudinal axis of said casing: and in step (e), initiating said fracture at said cavity in a plane generally perpendicular to said longitudinal axis.
7. The method of claim 6, wherein:
said forming of said cavity includes forming a fan-shaped slot in said formation, said fan-shaped slot circumscribing a substantially larger arc about said axis than does the opening through which said slot was formed.
said forming of said cavity includes forming a fan-shaped slot in said formation, said fan-shaped slot circumscribing a substantially larger arc about said axis than does the opening through which said slot was formed.
8. The method of claim 6, wherein:
said forming of said cavity includes forming a plurality of radially extending holes in said formations said holes lying generally in said plane perpendicular to said longitudinal axis.
said forming of said cavity includes forming a plurality of radially extending holes in said formations said holes lying generally in said plane perpendicular to said longitudinal axis.
9. The method of claim 1, wherein:
said first expandable casing portion is made of one-piece construction.
said first expandable casing portion is made of one-piece construction.
10. The method of claim 1 wherein:
in step (b), said first expandable casing portion is provided as an expansion joint defining a plurality of alternating inner and outer grooves therein such that said expansion joint may expand in a bellows-like manner.
in step (b), said first expandable casing portion is provided as an expansion joint defining a plurality of alternating inner and outer grooves therein such that said expansion joint may expand in a bellows-like manner.
11. A method of fracturing a subsurface formation of a well having a well casing cemented in a borehole intersecting the subsurface formation, said method comprising:
(a) providing an opening through said casing communicating an interior of said casing with said subsurface formation;
(b) providing at least a first bellows-type expansion joint in said casing;
(c) communicating a fracturing fluid under pressure through said opening to said subsurface formation;
(d) initiating a fracture in said subsurface formation adjacent said opening;
(e) during step (b), allowing expansion of said first expansion joint and thereby allowing movement of said casing with said subsurface formation; and (f) thereby preventing destruction of a bond between said casing and cement surrounding said casing during step (d).
(a) providing an opening through said casing communicating an interior of said casing with said subsurface formation;
(b) providing at least a first bellows-type expansion joint in said casing;
(c) communicating a fracturing fluid under pressure through said opening to said subsurface formation;
(d) initiating a fracture in said subsurface formation adjacent said opening;
(e) during step (b), allowing expansion of said first expansion joint and thereby allowing movement of said casing with said subsurface formation; and (f) thereby preventing destruction of a bond between said casing and cement surrounding said casing during step (d).
12. The method of claim 11 wherein:
in step (a), said opening is provided in a highly deviated portion of said well.
in step (a), said opening is provided in a highly deviated portion of said well.
13. The method of claim 11 wherein:
in step (a), said opening is provided in a substantially horizontal portion of said well.
in step (a), said opening is provided in a substantially horizontal portion of said well.
14. The method of claim 10 wherein:
step (b) further includes providing a second bellows-type expansion joint in said casing, said first and second expansion joints being disposed on opposite longitudinal sides of said opening.
step (b) further includes providing a second bellows-type expansion joint in said casing, said first and second expansion joints being disposed on opposite longitudinal sides of said opening.
15. The method of claim 14 wherein said first and second expansion joints allow expansion in opposite directions.
16. The method of claim 11, wherein:
step (f) includes terminating any destruction of said bond at said expansion joint and thereby preventing any destruction of said bond on the side of said expansion joint longitudinally opposite said opening.
step (f) includes terminating any destruction of said bond at said expansion joint and thereby preventing any destruction of said bond on the side of said expansion joint longitudinally opposite said opening.
17. The method of claim 11 further comprising:
forming said opening in a cavity in said formation and thereby creating said subsurface formation adjacent said cavity a localized least principal stress direction substantially parallel to the longitudinal axis of said casing; and in said step (d), initiating said fracture at said cavity in a plane generally perpendicular to said longitudinal axis.
forming said opening in a cavity in said formation and thereby creating said subsurface formation adjacent said cavity a localized least principal stress direction substantially parallel to the longitudinal axis of said casing; and in said step (d), initiating said fracture at said cavity in a plane generally perpendicular to said longitudinal axis.
18. The method of claim 16, wherein:
said forming of said cavity includes forming a fan-shaped slot in said formation, said fan-shaped slot circumscribing a substantially larger arc about said axis than does the opening through which said slot is formed.
said forming of said cavity includes forming a fan-shaped slot in said formation, said fan-shaped slot circumscribing a substantially larger arc about said axis than does the opening through which said slot is formed.
19. The method of claim 17, wherein:
said forming of said cavity includes forming a plurality of radially extending holes in said formation, said holes lying generally in said plane perpendicular to said longitudinal axis.
said forming of said cavity includes forming a plurality of radially extending holes in said formation, said holes lying generally in said plane perpendicular to said longitudinal axis.
20. The method of claim 11, wherein:
in step (b), said expansion joint is provided as a generally tubular member having a plurality of alternating inner and outer grooves defined therein, such that as said casing joint is expanded in step (e), said inner and outer grooves are generally widened.
in step (b), said expansion joint is provided as a generally tubular member having a plurality of alternating inner and outer grooves defined therein, such that as said casing joint is expanded in step (e), said inner and outer grooves are generally widened.
21. The method of claim 20 wherein said expansion joint is provided such that an outer diameter of said inner grooves is greater than an inner diameter of said outer grooves.
Applications Claiming Priority (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US08/129,922 US5325923A (en) | 1992-09-29 | 1993-09-30 | Well completions with expandable casing portions |
| US08/129,922 | 1993-09-30 |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CA2120797A1 true CA2120797A1 (en) | 1995-03-31 |
Family
ID=22442222
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA002120797A Abandoned CA2120797A1 (en) | 1993-09-30 | 1994-04-07 | Well completions with expandable casing portions |
Country Status (3)
| Country | Link |
|---|---|
| US (1) | US5325923A (en) |
| EP (1) | EP0646695A1 (en) |
| CA (1) | CA2120797A1 (en) |
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| US3580334A (en) * | 1970-01-22 | 1971-05-25 | Shell Oil Co | Method for preventing deformation in a well casing |
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-
1993
- 1993-09-30 US US08/129,922 patent/US5325923A/en not_active Expired - Fee Related
-
1994
- 1994-04-07 CA CA002120797A patent/CA2120797A1/en not_active Abandoned
- 1994-06-09 EP EP94304171A patent/EP0646695A1/en not_active Withdrawn
Also Published As
| Publication number | Publication date |
|---|---|
| EP0646695A1 (en) | 1995-04-05 |
| US5325923A (en) | 1994-07-05 |
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| FZDE | Discontinued |