CA1214988A - Cyclical steam flooding method for viscous oil recovery - Google Patents
Cyclical steam flooding method for viscous oil recoveryInfo
- Publication number
- CA1214988A CA1214988A CA000451188A CA451188A CA1214988A CA 1214988 A CA1214988 A CA 1214988A CA 000451188 A CA000451188 A CA 000451188A CA 451188 A CA451188 A CA 451188A CA 1214988 A CA1214988 A CA 1214988A
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- steam
- injection
- well
- production
- rate
- 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.)
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Abstract
CYCLICAL STEAM FLOODING METHOD
FOR VISCOUS OIL RECOVERY
ASTRACT
Viscous oil is recovered from a subterranean, viscous oil containing, permeable formation, penetrated by at least one injection well and at least one spaced-apart production well in which a fluid communication path exists or in which a fluid communicaton path is first established between the wells. The method involves a cyclical pressurization-drawdown program in which initially steam is injected into the injection well at a predetermined rate and fluids including oil are produced from the production well at a restricted flow rate equal to a value 50 percent or less than the flow rate of the steam being injected into the injection well. Steam injection and restricted production is continued until the wellhead temperature of the fluids is within the range of 175 to 250°F. Thereafter, the drawdown phase begins by increasing production to a maximum value and simultaneously reducing the injection rate of steam to a value about 20 percent of the original injection rate until the oil content in the produced fluids decreases to an unfavorable level. This sequence is repeated for a plurality of cycles until the desired oil recovery has been attained.
FOR VISCOUS OIL RECOVERY
ASTRACT
Viscous oil is recovered from a subterranean, viscous oil containing, permeable formation, penetrated by at least one injection well and at least one spaced-apart production well in which a fluid communication path exists or in which a fluid communicaton path is first established between the wells. The method involves a cyclical pressurization-drawdown program in which initially steam is injected into the injection well at a predetermined rate and fluids including oil are produced from the production well at a restricted flow rate equal to a value 50 percent or less than the flow rate of the steam being injected into the injection well. Steam injection and restricted production is continued until the wellhead temperature of the fluids is within the range of 175 to 250°F. Thereafter, the drawdown phase begins by increasing production to a maximum value and simultaneously reducing the injection rate of steam to a value about 20 percent of the original injection rate until the oil content in the produced fluids decreases to an unfavorable level. This sequence is repeated for a plurality of cycles until the desired oil recovery has been attained.
Description
s3~
21~
CYCLICAL STEAM FLOODING METrOD
fOR VI~COUS OIL RECOVERY ~
This invention relates to a thermal method for recovering oil from a subterranean, viscous oil-containing, permeable formation, including tar sand deposits. Still more specifically, this method involves a cyclical steam flood process for recovering oil from tar sand formations penetrated by at least two wells, a fluid communication path extending through the formation between the wells, and employing injection of steam with specific pressurization and drawdown cycles which are sequentially repeated.
Increasing worldwide demand for petroleum products, combined with continuously increasing prices for petroleum and products r~covered therefrom, has prompted a renewed interest in the sources of hydrocarbons which are less accessible than crude oil of the Middle East and other countries. One of the largest deposits of such sources of hydrocarbons comprises tar sands and oil shale deposits found in Northern Alberta, Canada9 and in the Midwest and Western states of the United States. While the estimated deposits of hydrccarbons contained in tar sands are enormous (eOg., the estimated total of the deposits in Alberta9 Canada is 250 billion barrels of synthetic crude equivalent), only a small proportion of such deposits can be recovered by currently available mining technologies (e.g., by strip mining).
For examole9 in 1974 it was estimated that not more than about lO~ of the then estimated 250 billion barrels of synthetic crude equivalent of deposits in Alberta, Canada was recoverable by the then available mining technologies. (See SYNTHETIC FUELS, March 1947, pages 3-l through 3-14). The remaining about 90~ of the deposits must be recovered by various in-situ techniques such as electrical resistance heating, st~am injection and in-situ forward and reverse combustion.
Accordingly, this invention provides an improved thermal method for effectively recovering oil from a subterranean, viscous oil-containing, permeable formation employing a cyclical pressurization~drawdown program.
``~`' ~
F-2161 - ~ -Tne present invention relates to a cyclical steam flooding method for recovering highly viscous oil from a subterranean, viscous oil-containing, permeable formation9 including a tar sand deposit, employing a specific prograrn of injecting steam to pressurize the formation followed Dy a drawdown phase. The formation is penetrated by at least one injection well and at least one spaced-apart production well~ both wells being in fluid communication with a substantial portion of the forrnation. Either a naturally occurring or artificially induced fluid communication path exists oetween the injection well and the production well. Each cycle of my process involves two stepc. The ~irst step involves injecting steam into the injection well at a predetermined flow rate, preferably at least 500 bbls/day, and producing fluids including oil from the formation via the production well at a restricted flow rate equal to a value 50 percent or less than the flow rate of the steam being injected into the injection well. Injection of steam and restricted produotion is continued until the wellhead temperature of the produced fluids rises to a temperature within the range of 175 to 25û~F. Thereafter the second step is begun wherein fluid production is increased to the maximum value and simultaneously reducing the steam injection rate to a value about 20 percent of the original injection rateO The second step is continued until the content of oil in the produced fluids is unfavorable. Thereafter the steps are repeated for a plurality of cycles until the desired oil recovery has been attained.
In the drawings appended to this specification:
Figure 1 illustrates a subterranean, viscous oil containing foTmation penetrated by an injection well and a spaced-apart production well, a fluid communication path located in the middle zone of the formation such that well-to-well communication is established, and the first phase of my process involving steam injection into the injection well and restricted production from the production well for pressure development in the formation.
Figure 2 illustrates the drawdown or second phase of my process in which the injection rate o~ steam is reduced with a simultaneous rapid production rate.
F-2161 - 3 ~
Figure 3 is a schema~ic representatlon of the method cycles and the corresponding pressure curve.
The process of my invention a~plies to a subterranean, viscous oil-containing formation such as a tar sand deposit with high conductivity, areally extensive microstructures or thie~ zones~ or if the formation does not possess naturally occurring permeability to steam, then a suitable communication path or zone of high fluid transmissability is formed prior ~o the aoplication of the main portion of my invention.
Referring to Figure 1, there is shown a subterranean, viscous oil-containing, permeable formation 10 penetrated by at least one injection well 12 and at least one spaced-apart production well 14.
The injection well 12 and production well 14 are in fluid communication with a substantial portion of the formation by means of perforations 16. While recovery of the t~pe contemplated by the present invention may be carried out by employing only two wells, it is to be understood that the invention is not limited to any particular number of wells. The invention may be practical using a variety of well patterns as is well known in the art of oil recovery, such as an inverted five spot pattern in which an injection well is surrounded with four production wells, or in a line drive arrangement in which a series of aligned injection wells and a series of aligned production wells are utili~ed. Any number of wells which may be arranged according to any pattern may be applied in using the preCent method as illustrated in U.S. Patent No. 37927~716 to Burdyn et al9 issued December 23, 1975. m e injection well 12 and production well 14 may be spaced-apart a predetermined distance depending upon the particular well pattern selected which may vary from about 200 to about 1000 feet. A naturally occurring or artificially induced fluid ccmmunication path 18 exists between the injection well 12 and the production well 1~. As illustrated in Figure 1, this fluid communication path 18 consists of at least one horizontal micro-structure or fracture such that well-to-well fluid communication is established. Fluid com~unication can be induced by forming at least one horizontal fracture in the 3~
F 2161 - ~ ~
s~
formation by the use of hydraulic fracturing fluids -thereby establishing fluid communication channels through the formation between the injection well and the production well and the fracture can be expanded by subsequent treatment such as by injecting solvents into one or both of the wells to enter the -thief or communication channels in a repetitive fashion until adequate communication between the wells is established.
The process of my invention comprises a series of cycles, each cycle consisting of two parts. The first step of the cycle is a pressurization phase wherein steam is injec-ted into the formation 10 via the injection well 12 at a predetermined flow rate, preferably at least 500 bbls/day9 and fluids including oil are produced from the formation via the production well 14 with restriction of the flow rate in order to increase the pressure in the communication path 18 and the portion of the formation adjacent thereto. The rate of flow of fluids from the production well 14 during this step is restricted to 50 percent or less of the steam injection rateO The injected steam is saturated and the preferred steam quality is from 50 to about 95 percent. As illustrated in Figure 1, the injected steam migrates as shown by the arrows both horizontally and immediately above and below the communication path 18 to form a steam-swept zone 20 which mobilizes viscous oil by reducing its viscosity and displaces the mobilized oil through the formation 10 toward the production well 14 for recovery. During the pressurization phase, the temperature of the fluids recovered from the production well 14 at the wellhead is monitored. Injection of steam and restricted production of fluids including oil is continued until the wellhead temperature of produced fluids is within the range of 175 to 250F. Once the produced fluids reach this temperature, the first step is concluded.
Thereafter, the second step of the cycle is initiated wherein the fluid production rate is increased to the maximum value and simultaneously reducing the injection rate of steam to a value about 20 percent of the original injection rate at which steam was injected into the injection well 12. For example, if the original steam injection rate was 500 bbls/day, the steam injection rate is reduced to about 100 bbls/day. During this second drawdown phase, the steam from the steam-swept zone 20 migrates toward the communication path 18 as shown by the arrows in figure 2 and the formation pressure is significantly decreased. The drawdown phase is continued until the produced fluids from the production well 14 contain an unfavorable amount of oil. The oil recovery process is continued with a plurality of cycles comprising pressurization and drawdown.
The pressure response behavior of the formation during the pressurization-drawdown cycles is shown graphically in Figure 3 wherein curve 1 represents the pressurization phase with restricted flow rate of fluids from the production well and curve 2 represents the drawdown phase of the cycle wherein steam injection is restricted and production is rapid. During the pressurization phase as shown by curve 1, the formation is pressurized to a value above the formation pressure and during the withdrawal phase as shown by curve 2 the formation pressure is significantly decreased. During the injection phase the steam is forced above and below the steamed zone and a small pressure gradient exists between the steamed and unsteamed zones as well as the normal gradient near the wells. lhese gradients are reversed during the drawdown phase of the process. This reversal of the pressure gradients forces the oil into the communication path and hence into the production well for recovery.
From the foregoing specification one skilled in the art can readily ascertain the essential features of this invention and without departing from the spirit and scope thereof can adapt it to various diverse applications. It is my intention and desire that my invention be limited only by those restrictions or limitations as are contained in the claims appended immediately hereinafter below.
21~
CYCLICAL STEAM FLOODING METrOD
fOR VI~COUS OIL RECOVERY ~
This invention relates to a thermal method for recovering oil from a subterranean, viscous oil-containing, permeable formation, including tar sand deposits. Still more specifically, this method involves a cyclical steam flood process for recovering oil from tar sand formations penetrated by at least two wells, a fluid communication path extending through the formation between the wells, and employing injection of steam with specific pressurization and drawdown cycles which are sequentially repeated.
Increasing worldwide demand for petroleum products, combined with continuously increasing prices for petroleum and products r~covered therefrom, has prompted a renewed interest in the sources of hydrocarbons which are less accessible than crude oil of the Middle East and other countries. One of the largest deposits of such sources of hydrocarbons comprises tar sands and oil shale deposits found in Northern Alberta, Canada9 and in the Midwest and Western states of the United States. While the estimated deposits of hydrccarbons contained in tar sands are enormous (eOg., the estimated total of the deposits in Alberta9 Canada is 250 billion barrels of synthetic crude equivalent), only a small proportion of such deposits can be recovered by currently available mining technologies (e.g., by strip mining).
For examole9 in 1974 it was estimated that not more than about lO~ of the then estimated 250 billion barrels of synthetic crude equivalent of deposits in Alberta, Canada was recoverable by the then available mining technologies. (See SYNTHETIC FUELS, March 1947, pages 3-l through 3-14). The remaining about 90~ of the deposits must be recovered by various in-situ techniques such as electrical resistance heating, st~am injection and in-situ forward and reverse combustion.
Accordingly, this invention provides an improved thermal method for effectively recovering oil from a subterranean, viscous oil-containing, permeable formation employing a cyclical pressurization~drawdown program.
``~`' ~
F-2161 - ~ -Tne present invention relates to a cyclical steam flooding method for recovering highly viscous oil from a subterranean, viscous oil-containing, permeable formation9 including a tar sand deposit, employing a specific prograrn of injecting steam to pressurize the formation followed Dy a drawdown phase. The formation is penetrated by at least one injection well and at least one spaced-apart production well~ both wells being in fluid communication with a substantial portion of the forrnation. Either a naturally occurring or artificially induced fluid communication path exists oetween the injection well and the production well. Each cycle of my process involves two stepc. The ~irst step involves injecting steam into the injection well at a predetermined flow rate, preferably at least 500 bbls/day, and producing fluids including oil from the formation via the production well at a restricted flow rate equal to a value 50 percent or less than the flow rate of the steam being injected into the injection well. Injection of steam and restricted produotion is continued until the wellhead temperature of the produced fluids rises to a temperature within the range of 175 to 25û~F. Thereafter the second step is begun wherein fluid production is increased to the maximum value and simultaneously reducing the steam injection rate to a value about 20 percent of the original injection rateO The second step is continued until the content of oil in the produced fluids is unfavorable. Thereafter the steps are repeated for a plurality of cycles until the desired oil recovery has been attained.
In the drawings appended to this specification:
Figure 1 illustrates a subterranean, viscous oil containing foTmation penetrated by an injection well and a spaced-apart production well, a fluid communication path located in the middle zone of the formation such that well-to-well communication is established, and the first phase of my process involving steam injection into the injection well and restricted production from the production well for pressure development in the formation.
Figure 2 illustrates the drawdown or second phase of my process in which the injection rate o~ steam is reduced with a simultaneous rapid production rate.
F-2161 - 3 ~
Figure 3 is a schema~ic representatlon of the method cycles and the corresponding pressure curve.
The process of my invention a~plies to a subterranean, viscous oil-containing formation such as a tar sand deposit with high conductivity, areally extensive microstructures or thie~ zones~ or if the formation does not possess naturally occurring permeability to steam, then a suitable communication path or zone of high fluid transmissability is formed prior ~o the aoplication of the main portion of my invention.
Referring to Figure 1, there is shown a subterranean, viscous oil-containing, permeable formation 10 penetrated by at least one injection well 12 and at least one spaced-apart production well 14.
The injection well 12 and production well 14 are in fluid communication with a substantial portion of the formation by means of perforations 16. While recovery of the t~pe contemplated by the present invention may be carried out by employing only two wells, it is to be understood that the invention is not limited to any particular number of wells. The invention may be practical using a variety of well patterns as is well known in the art of oil recovery, such as an inverted five spot pattern in which an injection well is surrounded with four production wells, or in a line drive arrangement in which a series of aligned injection wells and a series of aligned production wells are utili~ed. Any number of wells which may be arranged according to any pattern may be applied in using the preCent method as illustrated in U.S. Patent No. 37927~716 to Burdyn et al9 issued December 23, 1975. m e injection well 12 and production well 14 may be spaced-apart a predetermined distance depending upon the particular well pattern selected which may vary from about 200 to about 1000 feet. A naturally occurring or artificially induced fluid ccmmunication path 18 exists between the injection well 12 and the production well 1~. As illustrated in Figure 1, this fluid communication path 18 consists of at least one horizontal micro-structure or fracture such that well-to-well fluid communication is established. Fluid com~unication can be induced by forming at least one horizontal fracture in the 3~
F 2161 - ~ ~
s~
formation by the use of hydraulic fracturing fluids -thereby establishing fluid communication channels through the formation between the injection well and the production well and the fracture can be expanded by subsequent treatment such as by injecting solvents into one or both of the wells to enter the -thief or communication channels in a repetitive fashion until adequate communication between the wells is established.
The process of my invention comprises a series of cycles, each cycle consisting of two parts. The first step of the cycle is a pressurization phase wherein steam is injec-ted into the formation 10 via the injection well 12 at a predetermined flow rate, preferably at least 500 bbls/day9 and fluids including oil are produced from the formation via the production well 14 with restriction of the flow rate in order to increase the pressure in the communication path 18 and the portion of the formation adjacent thereto. The rate of flow of fluids from the production well 14 during this step is restricted to 50 percent or less of the steam injection rateO The injected steam is saturated and the preferred steam quality is from 50 to about 95 percent. As illustrated in Figure 1, the injected steam migrates as shown by the arrows both horizontally and immediately above and below the communication path 18 to form a steam-swept zone 20 which mobilizes viscous oil by reducing its viscosity and displaces the mobilized oil through the formation 10 toward the production well 14 for recovery. During the pressurization phase, the temperature of the fluids recovered from the production well 14 at the wellhead is monitored. Injection of steam and restricted production of fluids including oil is continued until the wellhead temperature of produced fluids is within the range of 175 to 250F. Once the produced fluids reach this temperature, the first step is concluded.
Thereafter, the second step of the cycle is initiated wherein the fluid production rate is increased to the maximum value and simultaneously reducing the injection rate of steam to a value about 20 percent of the original injection rate at which steam was injected into the injection well 12. For example, if the original steam injection rate was 500 bbls/day, the steam injection rate is reduced to about 100 bbls/day. During this second drawdown phase, the steam from the steam-swept zone 20 migrates toward the communication path 18 as shown by the arrows in figure 2 and the formation pressure is significantly decreased. The drawdown phase is continued until the produced fluids from the production well 14 contain an unfavorable amount of oil. The oil recovery process is continued with a plurality of cycles comprising pressurization and drawdown.
The pressure response behavior of the formation during the pressurization-drawdown cycles is shown graphically in Figure 3 wherein curve 1 represents the pressurization phase with restricted flow rate of fluids from the production well and curve 2 represents the drawdown phase of the cycle wherein steam injection is restricted and production is rapid. During the pressurization phase as shown by curve 1, the formation is pressurized to a value above the formation pressure and during the withdrawal phase as shown by curve 2 the formation pressure is significantly decreased. During the injection phase the steam is forced above and below the steamed zone and a small pressure gradient exists between the steamed and unsteamed zones as well as the normal gradient near the wells. lhese gradients are reversed during the drawdown phase of the process. This reversal of the pressure gradients forces the oil into the communication path and hence into the production well for recovery.
From the foregoing specification one skilled in the art can readily ascertain the essential features of this invention and without departing from the spirit and scope thereof can adapt it to various diverse applications. It is my intention and desire that my invention be limited only by those restrictions or limitations as are contained in the claims appended immediately hereinafter below.
Claims (8)
1. A method for recovering viscous oil from a subterranean, viscous oil-containing, permeable formation, including a tar sand deposit, said formation penetrated by at least one injection well and by at least one production well, said injection well and production well being in fluid communication with a substantial portion of the formation,comprising:
(a) injecting steam at a predetermined flow rate into the formation via said injection well;
(b) producing fluids including oil from the formation via said production well at a restricted flow rate equal to a value 50 percent or less than the flow rate of the steam being injected into the injection well;
(c) continuing injecting steam and producing fluids at a restricted value until the wellhead temperature of the produced fluids from the production well reaches a temperature within the range of 175 to 250°F;
(d) thereafter increasing the fluid production rate to the maximum value and simultaneously reducing the injection rate of steam to a value about 20 percent of the original injection rate at which steam was injected into the injection well;
(e) continuing production of fluids including oil from the formation via said production well at a high rate and injecting steam into the injection well until the oil content in the produced fluids is unfavorable; and (f) repeating steps (a) through (e) at least once.
(a) injecting steam at a predetermined flow rate into the formation via said injection well;
(b) producing fluids including oil from the formation via said production well at a restricted flow rate equal to a value 50 percent or less than the flow rate of the steam being injected into the injection well;
(c) continuing injecting steam and producing fluids at a restricted value until the wellhead temperature of the produced fluids from the production well reaches a temperature within the range of 175 to 250°F;
(d) thereafter increasing the fluid production rate to the maximum value and simultaneously reducing the injection rate of steam to a value about 20 percent of the original injection rate at which steam was injected into the injection well;
(e) continuing production of fluids including oil from the formation via said production well at a high rate and injecting steam into the injection well until the oil content in the produced fluids is unfavorable; and (f) repeating steps (a) through (e) at least once.
2. The method of Claim 1 wherein the injection and production well are spaced-apart a predetermined distance.
3. The method of Claim 1 wherein the injection steam is saturated and the steam quality is from 50 percent to about 95 percent.
4. The method of Claim 1 wherein the steam injection rate during step (a) is at least 500 bbs/day.
5. A method for recovering viscous oil from a subterranean, viscous oil-containing, permeable formation, including a tar sand deposit, said formation penetrated by at least one injection well and by at least one production well, said injection well and production well being in fluid communication with a substantial portion of the formation, comprising:
(a) forming a high permeability fluid communication path through said formation between said injection well and said production well;
(b) injecting steam at a predetermined flow rate into said fluid communication path via said injection well;
(c) producing fluids including oil from the formation via said production well at a restricted flow rate equal to a value 50 percent or less than the flow rate of the steam being injected into the injection well;
(d) continuing injecting steam and producing fluids at a restricted value until the wellhead temperature of the produced fluids from the production well reaches a temperature within the range of 175 to 250°F;
(e) thereafter increasing the fluid production rate to the maximum value and simultaneously reducing the injection rate of steam to a value about 20 percent of the original injection rate at which steam was injected into the injection well;
(f) continuing production of fluids including oil from the formation via said production well at a high rate and injecting steam into the injection well until the oil content in the produced fluids is unfavorable; and (g) repeating steps (b) through (f) at least once.
(a) forming a high permeability fluid communication path through said formation between said injection well and said production well;
(b) injecting steam at a predetermined flow rate into said fluid communication path via said injection well;
(c) producing fluids including oil from the formation via said production well at a restricted flow rate equal to a value 50 percent or less than the flow rate of the steam being injected into the injection well;
(d) continuing injecting steam and producing fluids at a restricted value until the wellhead temperature of the produced fluids from the production well reaches a temperature within the range of 175 to 250°F;
(e) thereafter increasing the fluid production rate to the maximum value and simultaneously reducing the injection rate of steam to a value about 20 percent of the original injection rate at which steam was injected into the injection well;
(f) continuing production of fluids including oil from the formation via said production well at a high rate and injecting steam into the injection well until the oil content in the produced fluids is unfavorable; and (g) repeating steps (b) through (f) at least once.
6. The method of Claim 5 wherein the injection steam is saturated and the steam quality is from 50 percent to about 95 percent.
7. The method of Claim 5 wherein the steam injection rate during step (b) is at least 500 bbls/day.
8. The method of Claim 5 wherein the injection well and production well are spaced-apart a predetermined distance.
Applications Claiming Priority (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US48198083A | 1983-04-04 | 1983-04-04 | |
| US481,980 | 1983-04-04 |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CA1214988A true CA1214988A (en) | 1986-12-09 |
Family
ID=23914162
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA000451188A Expired CA1214988A (en) | 1983-04-04 | 1984-04-03 | Cyclical steam flooding method for viscous oil recovery |
Country Status (1)
| Country | Link |
|---|---|
| CA (1) | CA1214988A (en) |
Cited By (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US10012064B2 (en) | 2015-04-09 | 2018-07-03 | Highlands Natural Resources, Plc | Gas diverter for well and reservoir stimulation |
| US10344204B2 (en) | 2015-04-09 | 2019-07-09 | Diversion Technologies, LLC | Gas diverter for well and reservoir stimulation |
| US10982520B2 (en) | 2016-04-27 | 2021-04-20 | Highland Natural Resources, PLC | Gas diverter for well and reservoir stimulation |
-
1984
- 1984-04-03 CA CA000451188A patent/CA1214988A/en not_active Expired
Cited By (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US10012064B2 (en) | 2015-04-09 | 2018-07-03 | Highlands Natural Resources, Plc | Gas diverter for well and reservoir stimulation |
| US10344204B2 (en) | 2015-04-09 | 2019-07-09 | Diversion Technologies, LLC | Gas diverter for well and reservoir stimulation |
| US10385258B2 (en) | 2015-04-09 | 2019-08-20 | Highlands Natural Resources, Plc | Gas diverter for well and reservoir stimulation |
| US10385257B2 (en) | 2015-04-09 | 2019-08-20 | Highands Natural Resources, PLC | Gas diverter for well and reservoir stimulation |
| US10982520B2 (en) | 2016-04-27 | 2021-04-20 | Highland Natural Resources, PLC | Gas diverter for well and reservoir stimulation |
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