CA2015459C - Process for confining steam injected into a heavy oil reservoir having a thief zone - Google Patents
Process for confining steam injected into a heavy oil reservoir having a thief zoneInfo
- Publication number
- CA2015459C CA2015459C CA 2015459 CA2015459A CA2015459C CA 2015459 C CA2015459 C CA 2015459C CA 2015459 CA2015459 CA 2015459 CA 2015459 A CA2015459 A CA 2015459A CA 2015459 C CA2015459 C CA 2015459C
- Authority
- CA
- Canada
- Prior art keywords
- reservoir
- pattern
- wells
- steam
- gas
- 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.)
- Expired - Lifetime
Links
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
-
- 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
- E21B43/30—Specific pattern of wells, e.g. optimizing the spacing of wells
Abstract
The process is practised in the context of a pattern of steam injection and oil production wells being completed in the payzone of a reservoir. A laterally extending thief zone, high in the reservoir, is in fluid communication with the payzone. An array of gas injection wells is provided at the perimeter of the pattern. The gas injection wells are adapted to inject non-condensable gas into the thief zone. The process comprises injecting non-condensable gas into the thief zone while steaming and producing the reservoir with the pattern wells. Gas injection is conducted to maintain the pressure in the thief zone at the perimeter of the pattern substantially equal to that within the pattern.
Description
- ~ 2015459 1 ~ Field of the Invention
2 This invention relates to an improvement of a steam
3 injection process for the recovery of oil. More particularly,
4 it relates to injecting non-condensable gas into a thief zone through an array of wells on the perimeter of a pattern of wells, 6 to pressure it up and inhibit the escape of injected steam 7 through that zone.
9 It is conventional practice to inject steam into a heavy oil reservoir to heat the formation and reduce the 11 viscosity of the oil, thereafter producing the oil once its 12 mobility has been improved. Such an operation is commonly 13 referred to as a "thermal project".
14 A problem can arise with respect to a thermal project if a "thief zone" is in communication with the oil reservoir into 16 which the steam is being injected. If this is the case, the 17 injected steam will preferentially move into the thief zone.
18 Heating of the oil-saturated portion of the reservoir is then 19 reduced.
Frequently the thief zone is a laterally extending 21 section of that portion of the oil-containing reservoir that is 22 to be heated. The section typically will have a relatively high 23 gas or water saturation. Often it is located at the top of the 24 reservoir.
A thief zone can also occur in another manner. In 26 heavy oil thermal projects it is common procedure to practice 27 steam injection and oil production in a first area and, when the 28 reservoir underlying the area is producing or depleted, to then ,~
20~54~9 1 expand the project by commencing operations in an adjacent second 2 area. In some cases, the first portion of the reservoir, 3 underlying the first surface area, is in fluid communication with 4 the second portion of the reservoir, which underlies the second surface area. In this situation, steam injected into the second 6 portion of the reservoir may migrate into the depleted first 7 portion. As a result, the depleted first portion of the 8 reservoir constitutes a thief zone for steam being injected into 9 the second portion.
When steam escapes into such a thief zone, it is found 11 that injection pressure diminishes and the temperature in the 12 production zone of the reservoir is relatively low. As a result, 13 the oil production rate also drops off.
14 There is therefore a need for a process that will inhibit losses of injected steam through or into a thief zone.
17 In accordance with the invention, an array of gas 18 injection wells is provided along the perimeter of a pattern 19 comprising steam injection and oil production wells. The steam injection and oil production wells are completed in a heavy oil 21 reservoir, which is in communication with a thief zone. The gas 22 injection wells are completed so that gas injected therethrough 23 will enter the thief zone. (Normally this will be done by 24 perforating the gas injection wells at the thief zone. However, the same end might be achieved by perforating elsewhere in the 26 reservoir and fracturing, to bring the perforations into 27 communication with the thief zone. Both techniques are intended 28 to fall within the scope of the invention.) During the course _LI 201 5459 1 of steam injection, non-condensable gas is injected through the 2 gas injection wells. This injected gas enters the permeable 3 thief zone, increases the pressure within the zone, and functions 4 to inhibit steam from entering or escaping through the zone. The
9 It is conventional practice to inject steam into a heavy oil reservoir to heat the formation and reduce the 11 viscosity of the oil, thereafter producing the oil once its 12 mobility has been improved. Such an operation is commonly 13 referred to as a "thermal project".
14 A problem can arise with respect to a thermal project if a "thief zone" is in communication with the oil reservoir into 16 which the steam is being injected. If this is the case, the 17 injected steam will preferentially move into the thief zone.
18 Heating of the oil-saturated portion of the reservoir is then 19 reduced.
Frequently the thief zone is a laterally extending 21 section of that portion of the oil-containing reservoir that is 22 to be heated. The section typically will have a relatively high 23 gas or water saturation. Often it is located at the top of the 24 reservoir.
A thief zone can also occur in another manner. In 26 heavy oil thermal projects it is common procedure to practice 27 steam injection and oil production in a first area and, when the 28 reservoir underlying the area is producing or depleted, to then ,~
20~54~9 1 expand the project by commencing operations in an adjacent second 2 area. In some cases, the first portion of the reservoir, 3 underlying the first surface area, is in fluid communication with 4 the second portion of the reservoir, which underlies the second surface area. In this situation, steam injected into the second 6 portion of the reservoir may migrate into the depleted first 7 portion. As a result, the depleted first portion of the 8 reservoir constitutes a thief zone for steam being injected into 9 the second portion.
When steam escapes into such a thief zone, it is found 11 that injection pressure diminishes and the temperature in the 12 production zone of the reservoir is relatively low. As a result, 13 the oil production rate also drops off.
14 There is therefore a need for a process that will inhibit losses of injected steam through or into a thief zone.
17 In accordance with the invention, an array of gas 18 injection wells is provided along the perimeter of a pattern 19 comprising steam injection and oil production wells. The steam injection and oil production wells are completed in a heavy oil 21 reservoir, which is in communication with a thief zone. The gas 22 injection wells are completed so that gas injected therethrough 23 will enter the thief zone. (Normally this will be done by 24 perforating the gas injection wells at the thief zone. However, the same end might be achieved by perforating elsewhere in the 26 reservoir and fracturing, to bring the perforations into 27 communication with the thief zone. Both techniques are intended 28 to fall within the scope of the invention.) During the course _LI 201 5459 1 of steam injection, non-condensable gas is injected through the 2 gas injection wells. This injected gas enters the permeable 3 thief zone, increases the pressure within the zone, and functions 4 to inhibit steam from entering or escaping through the zone. The
5 following results follow:
6 - oil production increases, as the steam heat is
7 better contained in the oil-saturated portion of
8 the reservoir within the pattern; and
9 - the reservoir operating temperature and pressure in the pattern increase.
11 Preferably, the gas is injected at a rate such that 12 the pressure in the reservoir at the gas injection wells is 13 substantially equalized with the pressure in the steam zone 14 within the pattern.
Preferably, the gas used for injection is selected from 16 the group consisting of flue gas, carbon dioxide, and natural 17 gas.
19 Figure 1 is a schematic showing the patterns and the confining array of gas injection wells, which were used in 21 demonstrating the invention at a pilot project;
22 Figure 2 illustrates with logs the nature of the 23 reservoir in the pilot test area;
24 Figure 3 is a plot showing steam injection and bitumen (i.e. heavy oil) production rates for the B pattern of the pilot 26 test. Arrows on the plot indicate when the injection well BIl 27 was started up, when BIl injection was switched from hot water 28 to steam, when the middle zone was completed, when injection 29 wells BI8 and BI9 -~- 2o~s4s9 1 ~ were started up, when the high steam rate test was conducted, and 2 when outside gas injection began; and 3 Figure 4 is a plot of gas injection rate through the 4 wells identified on the plot.
DESCRIPTION OF THE PREF~RRED ~MBODIMENT
6 The invention is exemplified by the following example 7 based on a pilot test conducted in the Kearl Lake region of 8 Alberta.
9 The reservoir at the pilot site, depicted in Figure 2, has two pay zones, a lower zone 1 and a middle zone 2. The 11 middle pay zone 1 is approximately 35 m thick and has a sand 12 region 3 at its upper end. This region 3 is approximately 10 m 13 thick and has significantly higher water saturation than the pay 14 zone 2. The region 3 constitutes a thief zone for steam injected through perforations in the pay zones 1,2.
16 The bitumen in the pay zone 2 is effectively immobile 17 at initial reservoir conditions.
18 A steam drive pilot was initiated in an A pattern 19 consisting of steam injection wells and production wells. The layout of the A pattern wells is shown in Figure 1. Each well 21 is identified as to pattern (A), nature (injection (I), 22 production (P)or observation (O)) and number. The A pattern was 23 an inverted 7-spot with peripheral steam injection to enclose the 24 pattern and make it equivalent to an inner pattern in a commercial project. The pattern covered 5.37 acres.
26 At the same time that the A pattern was drilled, an 27 adjacent B pattern was also drilled. The B pattern was 28 originally an inverted 5-spot surrounded by 8 steam injection 29 wells. It was decided to delay start-up of the B pattern to gain operating experience on the A pattern.
~, 201S~S9 1 A steam drive was initiated in December, 1981, in the 2 A pattern and continued for 5 years. Steam was injected into 3 the AI wells and fluid was produced from the AP wells.
4 It became clear that a large volume of steam was being lost from the A pattern, as the steam-oil ratio was very high.
6 As a result of the A pattern experience, changes were 7 made to the B pattern prior to its start-up. It was decided not 8 to inject steam into the peripheral wells of the B pattern.
9 Instead the B pattern was converted from a 5-spot to a 9-spot.
Start-up of the BI1 pattern occurred in February, 1985, 11 and start-up of the patterns of BI8 and BI9 was initiated in 12 September, 1987. Steam was injected through the 3 injection 13 wells and fluid produced from the 12 production wells in 14 conventional fashion.
Wells BI2, BI3, BI4, BI5, BI6 and BI7 were also 16 completed in the reservoir as observation wells and were used to 17 monitor temperature and pressure outside the B pattern.
18 The chronology of operations in the B pattern and the 19 effect on bitumen production is shown in Figure 3. Hot water injection was initiated into the lower zone 1 of the BI1 pattern 21 in February, 1985. Steam injection into the lower zone 1 of the 22 BI1 pattern began in August, 1985. Middle zone 2 operations 23 began in December, 1986. The BI8 and BI9 patterns were added in 24 September, 1987.
A high rate steam test was conducted in the summer of 26 1988 in which the steam injection rate was approximately doubled 27 for a period of about two months.
28 The outside gas injection test was begun in April, 29 1989, with the injection of natural gas into wells BI2, BI4 and BI6 following perforation of those wells in the region 3 of the ~1_ 2015~59 1 middle zone 2. Gas injection into wells BI7 and AI2 was 2 initiated a few months later, as shown in Figure 4.
3 As shown in Figure 3, the high rate steam test resulted 4 in a significant increase in bitumen production rates, but the steam-oil ratio did not improve.
6 After the high rate steam test, the bitumen production 7 rate fell considerably until March, 1989, when the steam 8 stimulation of some production wells began in anticipation of the 9 outside gas injection test.
As stated, the outside gas injection test began in 11 April 1989, and is still continuing. During the outside gas 12 injection test, the steam injection rate was held constant at a 13 rate of only about 60% of that during the high rate steam test.
14 The bitumen production rate during the outside gas injection test started to increase significantly within one month, and, over the 16 eight month period since gas injection began, the bitumen 17 production rate has, on average, been more than 80~ higher than 18 that prior to gas injection.
19 The instantaneous steam-oil ratio during the outside gas injection test also improved considerably over that observed 21 prior to outside gas injection.
22 No detrimental effects of outside gas injection have 23 been observed. There has been no noticeable increase in gas 24 production at the production wells. The injected gas remains near the top of the pay zone 2 due to gravity effects, while 26 liquids are produced through perforated intervals near the base 27 of the pay zone.
-g~ 2015459 1Prior to outside gas injection, the region 3 allowed 2 fluids to flow out of the B Pattern. In particular, steam, hot 3 water and hot bitumen flowed out of the B pattern during steam 4 injection within the pattern. This was evidenced by temperature and pressure measurements at the observation wells outside the 6 pattern and by the fact that the pressure within the pattern 7 remained low. When the steam injection rate was increased in the 8 B pattern, a temperature response could be detected even within 9 the A pattern.
10At the time gas injection began into region 3 through 11 wells outside the B pattern, the pressure within the B pattern 12 was only about 800 kPa. The native reservoir pressure is about 13 300 kPa. Within three months of the commencement of outside gas 14 injection, the pressure within the B pattern increased from 800 kPa to over 1000 kPa and the pressure within the A pattern 16increased from about 400 kPa to over 900 kPa. Within the B
17 pattern, the temperature increased along with the pressure as 18 determined by saturated steam conditions within the B pattern.
11 Preferably, the gas is injected at a rate such that 12 the pressure in the reservoir at the gas injection wells is 13 substantially equalized with the pressure in the steam zone 14 within the pattern.
Preferably, the gas used for injection is selected from 16 the group consisting of flue gas, carbon dioxide, and natural 17 gas.
19 Figure 1 is a schematic showing the patterns and the confining array of gas injection wells, which were used in 21 demonstrating the invention at a pilot project;
22 Figure 2 illustrates with logs the nature of the 23 reservoir in the pilot test area;
24 Figure 3 is a plot showing steam injection and bitumen (i.e. heavy oil) production rates for the B pattern of the pilot 26 test. Arrows on the plot indicate when the injection well BIl 27 was started up, when BIl injection was switched from hot water 28 to steam, when the middle zone was completed, when injection 29 wells BI8 and BI9 -~- 2o~s4s9 1 ~ were started up, when the high steam rate test was conducted, and 2 when outside gas injection began; and 3 Figure 4 is a plot of gas injection rate through the 4 wells identified on the plot.
DESCRIPTION OF THE PREF~RRED ~MBODIMENT
6 The invention is exemplified by the following example 7 based on a pilot test conducted in the Kearl Lake region of 8 Alberta.
9 The reservoir at the pilot site, depicted in Figure 2, has two pay zones, a lower zone 1 and a middle zone 2. The 11 middle pay zone 1 is approximately 35 m thick and has a sand 12 region 3 at its upper end. This region 3 is approximately 10 m 13 thick and has significantly higher water saturation than the pay 14 zone 2. The region 3 constitutes a thief zone for steam injected through perforations in the pay zones 1,2.
16 The bitumen in the pay zone 2 is effectively immobile 17 at initial reservoir conditions.
18 A steam drive pilot was initiated in an A pattern 19 consisting of steam injection wells and production wells. The layout of the A pattern wells is shown in Figure 1. Each well 21 is identified as to pattern (A), nature (injection (I), 22 production (P)or observation (O)) and number. The A pattern was 23 an inverted 7-spot with peripheral steam injection to enclose the 24 pattern and make it equivalent to an inner pattern in a commercial project. The pattern covered 5.37 acres.
26 At the same time that the A pattern was drilled, an 27 adjacent B pattern was also drilled. The B pattern was 28 originally an inverted 5-spot surrounded by 8 steam injection 29 wells. It was decided to delay start-up of the B pattern to gain operating experience on the A pattern.
~, 201S~S9 1 A steam drive was initiated in December, 1981, in the 2 A pattern and continued for 5 years. Steam was injected into 3 the AI wells and fluid was produced from the AP wells.
4 It became clear that a large volume of steam was being lost from the A pattern, as the steam-oil ratio was very high.
6 As a result of the A pattern experience, changes were 7 made to the B pattern prior to its start-up. It was decided not 8 to inject steam into the peripheral wells of the B pattern.
9 Instead the B pattern was converted from a 5-spot to a 9-spot.
Start-up of the BI1 pattern occurred in February, 1985, 11 and start-up of the patterns of BI8 and BI9 was initiated in 12 September, 1987. Steam was injected through the 3 injection 13 wells and fluid produced from the 12 production wells in 14 conventional fashion.
Wells BI2, BI3, BI4, BI5, BI6 and BI7 were also 16 completed in the reservoir as observation wells and were used to 17 monitor temperature and pressure outside the B pattern.
18 The chronology of operations in the B pattern and the 19 effect on bitumen production is shown in Figure 3. Hot water injection was initiated into the lower zone 1 of the BI1 pattern 21 in February, 1985. Steam injection into the lower zone 1 of the 22 BI1 pattern began in August, 1985. Middle zone 2 operations 23 began in December, 1986. The BI8 and BI9 patterns were added in 24 September, 1987.
A high rate steam test was conducted in the summer of 26 1988 in which the steam injection rate was approximately doubled 27 for a period of about two months.
28 The outside gas injection test was begun in April, 29 1989, with the injection of natural gas into wells BI2, BI4 and BI6 following perforation of those wells in the region 3 of the ~1_ 2015~59 1 middle zone 2. Gas injection into wells BI7 and AI2 was 2 initiated a few months later, as shown in Figure 4.
3 As shown in Figure 3, the high rate steam test resulted 4 in a significant increase in bitumen production rates, but the steam-oil ratio did not improve.
6 After the high rate steam test, the bitumen production 7 rate fell considerably until March, 1989, when the steam 8 stimulation of some production wells began in anticipation of the 9 outside gas injection test.
As stated, the outside gas injection test began in 11 April 1989, and is still continuing. During the outside gas 12 injection test, the steam injection rate was held constant at a 13 rate of only about 60% of that during the high rate steam test.
14 The bitumen production rate during the outside gas injection test started to increase significantly within one month, and, over the 16 eight month period since gas injection began, the bitumen 17 production rate has, on average, been more than 80~ higher than 18 that prior to gas injection.
19 The instantaneous steam-oil ratio during the outside gas injection test also improved considerably over that observed 21 prior to outside gas injection.
22 No detrimental effects of outside gas injection have 23 been observed. There has been no noticeable increase in gas 24 production at the production wells. The injected gas remains near the top of the pay zone 2 due to gravity effects, while 26 liquids are produced through perforated intervals near the base 27 of the pay zone.
-g~ 2015459 1Prior to outside gas injection, the region 3 allowed 2 fluids to flow out of the B Pattern. In particular, steam, hot 3 water and hot bitumen flowed out of the B pattern during steam 4 injection within the pattern. This was evidenced by temperature and pressure measurements at the observation wells outside the 6 pattern and by the fact that the pressure within the pattern 7 remained low. When the steam injection rate was increased in the 8 B pattern, a temperature response could be detected even within 9 the A pattern.
10At the time gas injection began into region 3 through 11 wells outside the B pattern, the pressure within the B pattern 12 was only about 800 kPa. The native reservoir pressure is about 13 300 kPa. Within three months of the commencement of outside gas 14 injection, the pressure within the B pattern increased from 800 kPa to over 1000 kPa and the pressure within the A pattern 16increased from about 400 kPa to over 900 kPa. Within the B
17 pattern, the temperature increased along with the pressure as 18 determined by saturated steam conditions within the B pattern.
Claims (5)
PROPERTY OR PRIVILEGE IS CLAIMED ARE DEFINED AS FOLLOWS:
1. A method for recovering heavy oil, that is effectively immobile at reservoir conditions, from a reservoir using a pattern of steam injection and oil production wells, said reservoir being in fluid-communication with a laterally extending thief zone high in the reservoir, an array of gas injection wells being located at the perimeter of the pattern and being completed so as to be in fluid communication with the thief zone, said method comprising:
injecting steam into the payzone of the reservoir through the steam injection wells, to heat the oil in the reservoir and render it mobile;
producing heated oil through the production wells; and during the course of steam injection, injecting non-condensable gas through the gas injection wells so that it enters the thief zone;
the non-condensable gas being injected at a rate and in an amount sufficient to maintain the pressure in the thief zone at the gas injection wells about equal with the pressure in the payzone of the reservoir within the pattern.
injecting steam into the payzone of the reservoir through the steam injection wells, to heat the oil in the reservoir and render it mobile;
producing heated oil through the production wells; and during the course of steam injection, injecting non-condensable gas through the gas injection wells so that it enters the thief zone;
the non-condensable gas being injected at a rate and in an amount sufficient to maintain the pressure in the thief zone at the gas injection wells about equal with the pressure in the payzone of the reservoir within the pattern.
2. The method as set forth in claim 1 wherein:
the non-condensable gas injected is selected from the group consisting of natural gas, flue gas and carbon dioxide.
the non-condensable gas injected is selected from the group consisting of natural gas, flue gas and carbon dioxide.
3. The method as set forth in claim 2 wherein:
the production wells are perforated low in the payzone of the reservoir.
the production wells are perforated low in the payzone of the reservoir.
4. The method as set forth in claim 3 wherein:
the gas injection wells are perforated at the thief zone so that the non-condensable gas is injected directly into that zone.
the gas injection wells are perforated at the thief zone so that the non-condensable gas is injected directly into that zone.
5. The method as set forth in claims 1, 2, 3 or 4 wherein:
steam and gas injection are continued simultaneously after heat breakthrough at the production wells.
steam and gas injection are continued simultaneously after heat breakthrough at the production wells.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA 2015459 CA2015459C (en) | 1990-04-26 | 1990-04-26 | Process for confining steam injected into a heavy oil reservoir having a thief zone |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA 2015459 CA2015459C (en) | 1990-04-26 | 1990-04-26 | Process for confining steam injected into a heavy oil reservoir having a thief zone |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CA2015459C true CA2015459C (en) | 1995-08-15 |
Family
ID=4144838
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA 2015459 Expired - Lifetime CA2015459C (en) | 1990-04-26 | 1990-04-26 | Process for confining steam injected into a heavy oil reservoir having a thief zone |
Country Status (1)
| Country | Link |
|---|---|
| CA (1) | CA2015459C (en) |
Cited By (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US7527096B2 (en) | 2005-01-26 | 2009-05-05 | Nexen Inc. | Methods of improving heavy oil production |
| US8387691B2 (en) | 2008-10-17 | 2013-03-05 | Athabasca Oils Sands Corporation | Low pressure recovery process for acceleration of in-situ bitumen recovery |
| US8424602B2 (en) | 2009-02-06 | 2013-04-23 | Thimm Petroleum Technologies Inc. | Gas-assisted process for in-situ bitumen recovery from carbonate reservoirs |
| CN106121641A (en) * | 2016-07-26 | 2016-11-16 | 中国石油天然气股份有限公司 | Thief's recognition methods of layer and device in oil reservoir |
| US11326431B2 (en) | 2019-02-01 | 2022-05-10 | Cenovus Energy Inc. | Dense aqueous gravity displacement of heavy oil |
-
1990
- 1990-04-26 CA CA 2015459 patent/CA2015459C/en not_active Expired - Lifetime
Cited By (7)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US7527096B2 (en) | 2005-01-26 | 2009-05-05 | Nexen Inc. | Methods of improving heavy oil production |
| US7717175B2 (en) | 2005-01-26 | 2010-05-18 | Nexen Inc. | Methods of improving heavy oil production |
| US8387691B2 (en) | 2008-10-17 | 2013-03-05 | Athabasca Oils Sands Corporation | Low pressure recovery process for acceleration of in-situ bitumen recovery |
| US8424602B2 (en) | 2009-02-06 | 2013-04-23 | Thimm Petroleum Technologies Inc. | Gas-assisted process for in-situ bitumen recovery from carbonate reservoirs |
| CN106121641A (en) * | 2016-07-26 | 2016-11-16 | 中国石油天然气股份有限公司 | Thief's recognition methods of layer and device in oil reservoir |
| CN106121641B (en) * | 2016-07-26 | 2019-06-11 | 中国石油天然气股份有限公司 | The recognition methods of crafty layer and device in oil reservoir |
| US11326431B2 (en) | 2019-02-01 | 2022-05-10 | Cenovus Energy Inc. | Dense aqueous gravity displacement of heavy oil |
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