CA1197457A - Viscous oil recovery method - Google Patents
Viscous oil recovery methodInfo
- Publication number
- CA1197457A CA1197457A CA000419671A CA419671A CA1197457A CA 1197457 A CA1197457 A CA 1197457A CA 000419671 A CA000419671 A CA 000419671A CA 419671 A CA419671 A CA 419671A CA 1197457 A CA1197457 A CA 1197457A
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- Canada
- Prior art keywords
- steam
- oil
- production
- well
- amount
- 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
VISCOUS OIL RECOVERY METHOD
ABSTRACT OF THE DISCLOSURE
In a thermal method for the recovery of oil from a subterranean, viscous oil-containing formation, a predetermined amount of steam in an amount not greater than 1.0 pore volume is injected into the formation via an injection well and oil is produced from the formation via a production well. The injection well is then shut in for a variable time to allow the injected steam to dissipate its heat throughout the formation and reduce oil viscosity while continuing production of oil. A predetermined amount of hot water or low quality steam in an amount not greater than 1.0 pore volume is.
injected into the formation with continued production but avoiding steam breakthrough. Thereafter, production is continued until there is an unfavorable amount of water or steam in the fluids recovered.
ABSTRACT OF THE DISCLOSURE
In a thermal method for the recovery of oil from a subterranean, viscous oil-containing formation, a predetermined amount of steam in an amount not greater than 1.0 pore volume is injected into the formation via an injection well and oil is produced from the formation via a production well. The injection well is then shut in for a variable time to allow the injected steam to dissipate its heat throughout the formation and reduce oil viscosity while continuing production of oil. A predetermined amount of hot water or low quality steam in an amount not greater than 1.0 pore volume is.
injected into the formation with continued production but avoiding steam breakthrough. Thereafter, production is continued until there is an unfavorable amount of water or steam in the fluids recovered.
Description
~1974~7 13b.9 ~l -~L~ETI iOD
~1~ I~ON
l. Field o~ the Invention ~_O
This invention relates to a prseess ~or recover~ng oil from a subterranean, viscous oil-cont ining ~ormatIon. More particularly, ~hia invention relates to a thernlal method o~ recov~ring oil ~ron~ a vlscous oil containing ~ormat:i on, especially a highly viscous tar sand deposit, employing a sequ~nce o~
10 manipulative s~eps wlth steam and h~t water to obtain maxlmum heat uti:lization and oil recoveryO .
~1~ I~ON
l. Field o~ the Invention ~_O
This invention relates to a prseess ~or recover~ng oil from a subterranean, viscous oil-cont ining ~ormatIon. More particularly, ~hia invention relates to a thernlal method o~ recov~ring oil ~ron~ a vlscous oil containing ~ormat:i on, especially a highly viscous tar sand deposit, employing a sequ~nce o~
10 manipulative s~eps wlth steam and h~t water to obtain maxlmum heat uti:lization and oil recoveryO .
2. 9~.
Increasing worldwide de~and ~or :petr~leum 15 p:coducts, combined with continuo~sly increasing prices ~or petroleum and products recovered there~rom7 has prompted a renewed ~nteresk in the sol~rces o~
hydrocarbons which ar~ less accsssible than crude oil o~
the Middle East and other oountries. One o~ the largest 20 deposits o~ suoh sources o~ hydrocarbons comprises tar sands and oil shale deposits found in Northern Alberta, Canada, and in the Midwest and Western states of the United States. While the estimated deposits o~
hydrocarbons contained in tar sands are enormous ~e.g~ 9 2~ the estimated total o~ the deposits in Qlberta, Canada is 250 b~llion barrels of synthetic crude equivalent), only a small proportion o~ such deposits can be recovered by currently available mining technologies (e.g., by strip mining~. For example, in 1974 it was 30 estimated that not more than about 10% o~ the then estimated 250 billion barrels of synl:hetic crude ~.
J ~ ;
13~9 _~_ equivalent nf deposits ln Alberta, Canada was recoverable by th~ then available mining technologies.
(5ee SYNTHETIC FUELS, March 1947, pages 3 1 through ~-14). The remaining about gO% o~ the deposits must be recovered by various in situ techniques such as electrical resistance heatin~, steam in~ ction and in-situ ~orw rd and reverse combustion.
Of the a~orementioned in-situ recovQry methods, steam ~looding h~s been a widely-appl.ied method ~or heavy oiI recovery. Problems arlse, however9 when one attempts to ~pply the process to heavy oil re~ervoirs with very low transmissibility such as tar sand d@posits. In such cases, because o~ the un~avorable mobility ratio, steam channelling and grav~y overrlde often r~sult in early steam breakthrough and leave a lar~e port~on o~ the reservoir unswept~ Th~ key to a s~cces~ful steam ~looding lies in striking-a good balance between the rate of displacement and the ra~e o~
heat transfer ~hich lowers the oil viscosity to a more ~avorable mob~lity r~tio. ~ccordinglyj this invention provides an improved thermal system ~or e~fectively _ -reeovering oil ~rom subterranean ~ormations such as tar sand deposits.
~
~ e have discovered that viscous oil may be recovered ~rom a subterrane~n, visoous oi1-containing formation especially a hi~hly viscous tar sand deposit, . penetrated by at least one injection well and a spaced apart praduction well employing 1n~ection o~ a predetermined amount o~ steam, shutting-in the injection well ~or a variable time, and injection o~ a predeterminecl am~unt of hot water or low quality st@am with no int~rruption o~ production during these steps 5~
1349 .-3 and avoiding steam breakthrough. Init:ially a predetermined amount o~ steam in an amount not greater than 1.0 pore volume is injeeted lnt~ the ~ormation via an inJection well and tluids including oil are recovered ~rom the ~ormation vI~ a production well. Therea~t2r, the injection well is shut-in and production ls continued ~or a period o~ time between 1 to la days per ~oot o~ ~orm~tion thlckens~ or until the produ~tion welL
pressure declines to a valu@ w;ithin the range n~
one-third to two-thirds o~ said pressure at the time the ~njection welI is shut-in. Thcrea~t~r, a predet~rmin~d amaunt o~ hot water or low qua:Lity steam in an amount not ~reater thhn-l.O pore volume is injeoted into the ~ormation and produot~on is c~ntinued until there is an un~avorable ~mount o~ st am or wat~r in the ~luids recovere~ ~rom the ~ormation via the produe~ion well.
~ y pract~o~ng the method according to the invention, maximu~_h~ne~it o~ the heat eontent o~ the steam is obtained with enhanced oiL r~coveryO
~RIEF DESCRIPTION OF THE DRAWING
The attached Figure illustrates the production o~ oil versus _ime ~or a run involving injection o~
~team7 a run employin~ in~ection of stea~ ~or a fixed peri3d o~ time, and a run employing lnJection oP steam ~or a ~ixed period o~ t~me subsequently Pollowed by iniection o~ hot ~ater ~or a ~ixed period o~ time, This invent~on relates to a thermal recovery method ~or the recovery o~ oil ~rom a subterr~nean, viscous oil-containing ~ormation as a ~ar sand ~ormation penetrated by at least one injection well and a spaced apart production well. While recovery o~ the type _ _. .... .. ... .
.J ' -~o~s~
1349 _~
contemplated by th~ pressnt lnventiorl may be carried out by employing only two wells, it is to be understood that the invention is not limited to ~ny partieular nu~ber o~
wells.
In a preferred embod.iment o~ the Invention; a predeter~in~d amount o~ steamy not ~reater than l,U pore volume~ is injected In~o the ~ormation via the in,~ection welL afld ~luids including oil are reeovered ~rom the ~armation via the pro~uction well. The amount o~ steam.
iniected will vary depending ~pon the khlckness o~ the ~ormation~ the viscosity nf th~ oiI9 the porosity o~ the ~ormation, the amount. o~ water in the ~ormation) and the well pattern.
Therea~ter, the ln~ection well is shut-ln and productlon o~ ~luid~ including olI via th~ production well is continued ~or a predetermin~d pe~iod: o~ tlme~
During the time that the in~ection w~ll is shut in and produoti~n is:continued, the in~ected steam ~rom the Initial step eondens~s in the ~ormation and the resulting heat fs allowed to dissipate into the ~ormation reducing the visoosity o~ the oil. As the heated z~ne expands,. the rate o~ produotion Increases and the pressure o~ the ~ormation ~ill gradually decline. An important aspect o~ the process of the invention during injection well shut-in and production is to avoid steam breakthrough so that ma~imum bene~it o~ the injected steam is obtained.
Production is co.ntinued while the injection ~ell is shut-in with no steam breakthrough until the:
pressure at the production well has decreased to a value within the range o~ one-third to two-thirds o~ said pressure at the time the in~ection well was shut-in.
Alternatively, this step is continued for a predetermined time period o~ 1 to 10 days per ~uot of formation thickness.
_ . , 1349 -5~
ThereaPter, productiorl o~ ~lulds including o:Ll via the produced well is continued and a predetermlned amount o~ a thermal ~luid such as hot ~ater or low quality steam is in~ected into the ~ormation via the in~ectlon well. The quality o~ the steam is not greater than 20%. The amouni: o~ hot water or low quality steam in~ected during this step o~ t:he proGess will be an amount not ~reater than 1. 0 pore volume. The ln jected thermal ~luid pressurizes the ~ormation and increase~
produGtlon ol~ oilO ~t is pre~'erred during this step to in,~eot hot water as ~he thermall ~luid bec~us~, unlike steam, it will not override the ~ormatian~ In additlon~
hot water will soavenge heat from the steam previously inJected in the ~ormation causing the stea~ to condense and thereby deterring steam channelllng. This results in an exterlde~ production time by delaying steam br2akthrough. Thus by our process the maxlmum use o~
the heat of steam is obtained resulting in increased oil production ~
Ther~a~ter, production of ~luids includ~ ng oil is continued until the ~luid produced contains an un~avorable amount o~ water or steam7 pr~rably at least 90%, at which point production is terminated.
Utilizing a computational model and c~mputer program, we will demonstrate the e~ectiveness o~ cur method. The reservoir data used in the computational model is as ~ollows: Two wells separated by 467 feet are sunk into a reservoir 150 feet thick and containlng a heavy crude having a viscosity o~ 61,900 cp at a reservoir temperature of 55F. The bottom 20 ~eet is a water sand with a water saturation o~ 0. 88. A~ter approximately ~ive years o~ cyclic steam stimulation in both wells9 the system is converted to steam ~lood by making one we.ll an injection well and the other a J -~
5~
1349 ~6~
produrtion we11. Three computer simulation runs were conducted and the results are shown by the graphical representation o~ the attached Figure.
Run 1 represents a straight steam f100d~
Saturated steam at 681 psia and a quality o~ 78X was injected in one well at a constant rate of 85 barrels per day whi1e the other well was placed on production.
Steam breakthrough occurred after 647 days, at which time the cumulative oil produotion was 65~3 stock tank barre1s (ST~) and the oi1/h0at input ratio was 0~3257 ST~/MM 6tu.
In Run 2, steam injectlon was terminated a~ter 220 days. A total o~ 659980 ST~ (CWE) o~ steam at a quality o~ 78% and ~ pressure o~ 681 psia was injected into the reservoir over the 220 day period. Steam breakthrough occurred after 739 days, at w.hi~h time-th~
cumulative oil production was 26,400 5TB and the oil/heat input r~ti~-~.0950 ST~/MM Btu.
In Run 3, steam was in~ected ~or 22U days as in Run 2. A~ter a soaking period o~ 280 days, hot water with 1% steam at ~40 psia was injected at a constant rate of 85 barrels per day ~rom 500 to 600 days o~ the operation. Steam breakthrough occurred a~ter 775 days, at which time the cumulative oil production was 29t390 ST~ and the oil/heat input ratio 1.1630 STB/MM Btu. Run
Increasing worldwide de~and ~or :petr~leum 15 p:coducts, combined with continuo~sly increasing prices ~or petroleum and products recovered there~rom7 has prompted a renewed ~nteresk in the sol~rces o~
hydrocarbons which ar~ less accsssible than crude oil o~
the Middle East and other oountries. One o~ the largest 20 deposits o~ suoh sources o~ hydrocarbons comprises tar sands and oil shale deposits found in Northern Alberta, Canada, and in the Midwest and Western states of the United States. While the estimated deposits o~
hydrocarbons contained in tar sands are enormous ~e.g~ 9 2~ the estimated total o~ the deposits in Qlberta, Canada is 250 b~llion barrels of synthetic crude equivalent), only a small proportion o~ such deposits can be recovered by currently available mining technologies (e.g., by strip mining~. For example, in 1974 it was 30 estimated that not more than about 10% o~ the then estimated 250 billion barrels of synl:hetic crude ~.
J ~ ;
13~9 _~_ equivalent nf deposits ln Alberta, Canada was recoverable by th~ then available mining technologies.
(5ee SYNTHETIC FUELS, March 1947, pages 3 1 through ~-14). The remaining about gO% o~ the deposits must be recovered by various in situ techniques such as electrical resistance heatin~, steam in~ ction and in-situ ~orw rd and reverse combustion.
Of the a~orementioned in-situ recovQry methods, steam ~looding h~s been a widely-appl.ied method ~or heavy oiI recovery. Problems arlse, however9 when one attempts to ~pply the process to heavy oil re~ervoirs with very low transmissibility such as tar sand d@posits. In such cases, because o~ the un~avorable mobility ratio, steam channelling and grav~y overrlde often r~sult in early steam breakthrough and leave a lar~e port~on o~ the reservoir unswept~ Th~ key to a s~cces~ful steam ~looding lies in striking-a good balance between the rate of displacement and the ra~e o~
heat transfer ~hich lowers the oil viscosity to a more ~avorable mob~lity r~tio. ~ccordinglyj this invention provides an improved thermal system ~or e~fectively _ -reeovering oil ~rom subterranean ~ormations such as tar sand deposits.
~
~ e have discovered that viscous oil may be recovered ~rom a subterrane~n, visoous oi1-containing formation especially a hi~hly viscous tar sand deposit, . penetrated by at least one injection well and a spaced apart praduction well employing 1n~ection o~ a predetermined amount o~ steam, shutting-in the injection well ~or a variable time, and injection o~ a predeterminecl am~unt of hot water or low quality st@am with no int~rruption o~ production during these steps 5~
1349 .-3 and avoiding steam breakthrough. Init:ially a predetermined amount o~ steam in an amount not greater than 1.0 pore volume is injeeted lnt~ the ~ormation via an inJection well and tluids including oil are recovered ~rom the ~ormation vI~ a production well. Therea~t2r, the injection well is shut-in and production ls continued ~or a period o~ time between 1 to la days per ~oot o~ ~orm~tion thlckens~ or until the produ~tion welL
pressure declines to a valu@ w;ithin the range n~
one-third to two-thirds o~ said pressure at the time the ~njection welI is shut-in. Thcrea~t~r, a predet~rmin~d amaunt o~ hot water or low qua:Lity steam in an amount not ~reater thhn-l.O pore volume is injeoted into the ~ormation and produot~on is c~ntinued until there is an un~avorable ~mount o~ st am or wat~r in the ~luids recovere~ ~rom the ~ormation via the produe~ion well.
~ y pract~o~ng the method according to the invention, maximu~_h~ne~it o~ the heat eontent o~ the steam is obtained with enhanced oiL r~coveryO
~RIEF DESCRIPTION OF THE DRAWING
The attached Figure illustrates the production o~ oil versus _ime ~or a run involving injection o~
~team7 a run employin~ in~ection of stea~ ~or a fixed peri3d o~ time, and a run employing lnJection oP steam ~or a ~ixed period o~ t~me subsequently Pollowed by iniection o~ hot ~ater ~or a ~ixed period o~ time, This invent~on relates to a thermal recovery method ~or the recovery o~ oil ~rom a subterr~nean, viscous oil-containing ~ormation as a ~ar sand ~ormation penetrated by at least one injection well and a spaced apart production well. While recovery o~ the type _ _. .... .. ... .
.J ' -~o~s~
1349 _~
contemplated by th~ pressnt lnventiorl may be carried out by employing only two wells, it is to be understood that the invention is not limited to ~ny partieular nu~ber o~
wells.
In a preferred embod.iment o~ the Invention; a predeter~in~d amount o~ steamy not ~reater than l,U pore volume~ is injected In~o the ~ormation via the in,~ection welL afld ~luids including oil are reeovered ~rom the ~armation via the pro~uction well. The amount o~ steam.
iniected will vary depending ~pon the khlckness o~ the ~ormation~ the viscosity nf th~ oiI9 the porosity o~ the ~ormation, the amount. o~ water in the ~ormation) and the well pattern.
Therea~ter, the ln~ection well is shut-ln and productlon o~ ~luid~ including olI via th~ production well is continued ~or a predetermin~d pe~iod: o~ tlme~
During the time that the in~ection w~ll is shut in and produoti~n is:continued, the in~ected steam ~rom the Initial step eondens~s in the ~ormation and the resulting heat fs allowed to dissipate into the ~ormation reducing the visoosity o~ the oil. As the heated z~ne expands,. the rate o~ produotion Increases and the pressure o~ the ~ormation ~ill gradually decline. An important aspect o~ the process of the invention during injection well shut-in and production is to avoid steam breakthrough so that ma~imum bene~it o~ the injected steam is obtained.
Production is co.ntinued while the injection ~ell is shut-in with no steam breakthrough until the:
pressure at the production well has decreased to a value within the range o~ one-third to two-thirds o~ said pressure at the time the in~ection well was shut-in.
Alternatively, this step is continued for a predetermined time period o~ 1 to 10 days per ~uot of formation thickness.
_ . , 1349 -5~
ThereaPter, productiorl o~ ~lulds including o:Ll via the produced well is continued and a predetermlned amount o~ a thermal ~luid such as hot ~ater or low quality steam is in~ected into the ~ormation via the in~ectlon well. The quality o~ the steam is not greater than 20%. The amouni: o~ hot water or low quality steam in~ected during this step o~ t:he proGess will be an amount not ~reater than 1. 0 pore volume. The ln jected thermal ~luid pressurizes the ~ormation and increase~
produGtlon ol~ oilO ~t is pre~'erred during this step to in,~eot hot water as ~he thermall ~luid bec~us~, unlike steam, it will not override the ~ormatian~ In additlon~
hot water will soavenge heat from the steam previously inJected in the ~ormation causing the stea~ to condense and thereby deterring steam channelllng. This results in an exterlde~ production time by delaying steam br2akthrough. Thus by our process the maxlmum use o~
the heat of steam is obtained resulting in increased oil production ~
Ther~a~ter, production of ~luids includ~ ng oil is continued until the ~luid produced contains an un~avorable amount o~ water or steam7 pr~rably at least 90%, at which point production is terminated.
Utilizing a computational model and c~mputer program, we will demonstrate the e~ectiveness o~ cur method. The reservoir data used in the computational model is as ~ollows: Two wells separated by 467 feet are sunk into a reservoir 150 feet thick and containlng a heavy crude having a viscosity o~ 61,900 cp at a reservoir temperature of 55F. The bottom 20 ~eet is a water sand with a water saturation o~ 0. 88. A~ter approximately ~ive years o~ cyclic steam stimulation in both wells9 the system is converted to steam ~lood by making one we.ll an injection well and the other a J -~
5~
1349 ~6~
produrtion we11. Three computer simulation runs were conducted and the results are shown by the graphical representation o~ the attached Figure.
Run 1 represents a straight steam f100d~
Saturated steam at 681 psia and a quality o~ 78X was injected in one well at a constant rate of 85 barrels per day whi1e the other well was placed on production.
Steam breakthrough occurred after 647 days, at which time the cumulative oil produotion was 65~3 stock tank barre1s (ST~) and the oi1/h0at input ratio was 0~3257 ST~/MM 6tu.
In Run 2, steam injectlon was terminated a~ter 220 days. A total o~ 659980 ST~ (CWE) o~ steam at a quality o~ 78% and ~ pressure o~ 681 psia was injected into the reservoir over the 220 day period. Steam breakthrough occurred after 739 days, at w.hi~h time-th~
cumulative oil production was 26,400 5TB and the oil/heat input r~ti~-~.0950 ST~/MM Btu.
In Run 3, steam was in~ected ~or 22U days as in Run 2. A~ter a soaking period o~ 280 days, hot water with 1% steam at ~40 psia was injected at a constant rate of 85 barrels per day ~rom 500 to 600 days o~ the operation. Steam breakthrough occurred a~ter 775 days, at which time the cumulative oil production was 29t390 ST~ and the oil/heat input ratio 1.1630 STB/MM Btu. Run
3 clearly shows that there is a substantial improvement in oil recovery e~iciency over that af a convzntional steam flood process (Run 1) and also shows an overall increase in production over Run 2 employing injection o~
a slug o~ steam.
By the texm "pore volume" as used herein is m~ant that volume o~ the portion o~ the ~ormation underlying the well pattern employed, as described in greater detail. in U.S. Patent No. 3,927,716 to ~urdny et al.
a slug o~ steam.
By the texm "pore volume" as used herein is m~ant that volume o~ the portion o~ the ~ormation underlying the well pattern employed, as described in greater detail. in U.S. Patent No. 3,927,716 to ~urdny et al.
Claims (6)
1. In a method for the recovery of oil from a subterranean, viscous oil-containing formation penetrated by at least one injection well and a spaced apart production well comprising:
(a) injecting a predetermined amount of steam into the formation via said injection well and recovering fluids including oil from the formation via said production well;
(b) thereafter shutting in said injection well and continuing to recover fluids including oil from the production well but without steam breakthrough until the pressure at the production well declines to a value within the range of one-third to two-thirds of said pressure at the time said injection well is shut-in;
.
(c) thereafter injecting a predetermined amount of a thermal recovery fluid comprising hot water into the formation via said injection well; and (d) continuing to recover fluids including oil from the formation via said production well until the recovered fluids contain an unfavorable amount of steam or water.
(a) injecting a predetermined amount of steam into the formation via said injection well and recovering fluids including oil from the formation via said production well;
(b) thereafter shutting in said injection well and continuing to recover fluids including oil from the production well but without steam breakthrough until the pressure at the production well declines to a value within the range of one-third to two-thirds of said pressure at the time said injection well is shut-in;
.
(c) thereafter injecting a predetermined amount of a thermal recovery fluid comprising hot water into the formation via said injection well; and (d) continuing to recover fluids including oil from the formation via said production well until the recovered fluids contain an unfavorable amount of steam or water.
2. The method of Claim 1 wherein the amount of steam injected during step (a) is not greater than 1,0 pore volume.
3. The method of Claim 1 wherein production is continued during step (b) but without steam breakthrough for a period of time between 1 to 10 days per foot of formation thickness.
4. The method of Claim 1 wherein the amount of hot water injected during step (c) is not greater than 1.0 pore volume.
5. The method of Claim 1 wherein the thermal fluid injected during step (c) is steam having a quality not greater than 20%.
; .
; .
6. The method of Claim 1 wherein production is continued during step (d) until the fluids being recovered contain at least 90% water or steam.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA000419671A CA1197457A (en) | 1983-01-18 | 1983-01-18 | Viscous oil recovery method |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA000419671A CA1197457A (en) | 1983-01-18 | 1983-01-18 | Viscous oil recovery method |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CA1197457A true CA1197457A (en) | 1985-12-03 |
Family
ID=4124371
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA000419671A Expired CA1197457A (en) | 1983-01-18 | 1983-01-18 | Viscous oil recovery method |
Country Status (1)
| Country | Link |
|---|---|
| CA (1) | CA1197457A (en) |
Cited By (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US5020596A (en) * | 1990-01-24 | 1991-06-04 | Indugas, Inc. | Enhanced oil recovery system with a radiant tube heater |
| US5082055A (en) * | 1990-01-24 | 1992-01-21 | Indugas, Inc. | Gas fired radiant tube heater |
| CN105089590A (en) * | 2014-05-08 | 2015-11-25 | 中国石油化工股份有限公司 | Method for improving yield of common heavy oil reservoir after water flooding |
-
1983
- 1983-01-18 CA CA000419671A patent/CA1197457A/en not_active Expired
Cited By (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US5020596A (en) * | 1990-01-24 | 1991-06-04 | Indugas, Inc. | Enhanced oil recovery system with a radiant tube heater |
| US5082055A (en) * | 1990-01-24 | 1992-01-21 | Indugas, Inc. | Gas fired radiant tube heater |
| CN105089590A (en) * | 2014-05-08 | 2015-11-25 | 中国石油化工股份有限公司 | Method for improving yield of common heavy oil reservoir after water flooding |
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