US3838737A - Petroleum production technique - Google Patents
Petroleum production technique Download PDFInfo
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- US3838737A US3838737A US00357405A US35740573A US3838737A US 3838737 A US3838737 A US 3838737A US 00357405 A US00357405 A US 00357405A US 35740573 A US35740573 A US 35740573A US 3838737 A US3838737 A US 3838737A
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- 239000003208 petroleum Substances 0.000 title claims abstract description 56
- 238000000034 method Methods 0.000 title claims abstract description 40
- 238000004519 manufacturing process Methods 0.000 title claims abstract description 18
- 239000002904 solvent Substances 0.000 claims abstract description 95
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 54
- 239000012530 fluid Substances 0.000 claims abstract description 43
- 239000000203 mixture Substances 0.000 claims abstract description 9
- QGJOPFRUJISHPQ-UHFFFAOYSA-N Carbon disulfide Chemical compound S=C=S QGJOPFRUJISHPQ-UHFFFAOYSA-N 0.000 claims description 48
- 150000008280 chlorinated hydrocarbons Chemical class 0.000 claims description 12
- 241000237858 Gastropoda Species 0.000 claims description 10
- 238000006073 displacement reaction Methods 0.000 abstract description 14
- 238000002347 injection Methods 0.000 abstract description 11
- 239000007924 injection Substances 0.000 abstract description 11
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 description 5
- 229910052799 carbon Inorganic materials 0.000 description 5
- 229930195733 hydrocarbon Natural products 0.000 description 5
- 150000002430 hydrocarbons Chemical class 0.000 description 5
- 238000011084 recovery Methods 0.000 description 5
- 239000007789 gas Substances 0.000 description 4
- 239000003921 oil Substances 0.000 description 4
- UHOVQNZJYSORNB-UHFFFAOYSA-N Benzene Chemical compound C1=CC=CC=C1 UHOVQNZJYSORNB-UHFFFAOYSA-N 0.000 description 3
- 239000004215 Carbon black (E152) Substances 0.000 description 3
- YXFVVABEGXRONW-UHFFFAOYSA-N Toluene Chemical compound CC1=CC=CC=C1 YXFVVABEGXRONW-UHFFFAOYSA-N 0.000 description 3
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 description 2
- YMWUJEATGCHHMB-UHFFFAOYSA-N Dichloromethane Chemical compound ClCCl YMWUJEATGCHHMB-UHFFFAOYSA-N 0.000 description 2
- 230000015572 biosynthetic process Effects 0.000 description 2
- 239000003795 chemical substances by application Substances 0.000 description 2
- 150000008282 halocarbons Chemical class 0.000 description 2
- 238000000926 separation method Methods 0.000 description 2
- VZGDMQKNWNREIO-UHFFFAOYSA-N tetrachloromethane Chemical compound ClC(Cl)(Cl)Cl VZGDMQKNWNREIO-UHFFFAOYSA-N 0.000 description 2
- CTQNGGLPUBDAKN-UHFFFAOYSA-N O-Xylene Chemical compound CC1=CC=CC=C1C CTQNGGLPUBDAKN-UHFFFAOYSA-N 0.000 description 1
- NINIDFKCEFEMDL-UHFFFAOYSA-N Sulfur Chemical compound [S] NINIDFKCEFEMDL-UHFFFAOYSA-N 0.000 description 1
- 150000001338 aliphatic hydrocarbons Chemical class 0.000 description 1
- 238000004458 analytical method Methods 0.000 description 1
- 238000013459 approach Methods 0.000 description 1
- 150000004945 aromatic hydrocarbons Chemical class 0.000 description 1
- 239000010426 asphalt Substances 0.000 description 1
- 239000012267 brine Substances 0.000 description 1
- 238000004364 calculation method Methods 0.000 description 1
- 229910002092 carbon dioxide Inorganic materials 0.000 description 1
- 239000001569 carbon dioxide Substances 0.000 description 1
- 239000003054 catalyst Substances 0.000 description 1
- 238000006243 chemical reaction Methods 0.000 description 1
- 239000000571 coke Substances 0.000 description 1
- 238000004891 communication Methods 0.000 description 1
- 239000010779 crude oil Substances 0.000 description 1
- 238000004090 dissolution Methods 0.000 description 1
- 230000002349 favourable effect Effects 0.000 description 1
- 229910052736 halogen Inorganic materials 0.000 description 1
- 150000002367 halogens Chemical class 0.000 description 1
- 230000001939 inductive effect Effects 0.000 description 1
- 239000003350 kerosene Substances 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 239000002574 poison Substances 0.000 description 1
- 231100000614 poison Toxicity 0.000 description 1
- 230000002028 premature Effects 0.000 description 1
- 238000005204 segregation Methods 0.000 description 1
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 description 1
- 239000011877 solvent mixture Substances 0.000 description 1
- 229910052717 sulfur Inorganic materials 0.000 description 1
- 239000011593 sulfur Substances 0.000 description 1
- 239000011275 tar sand Substances 0.000 description 1
- 230000007704 transition Effects 0.000 description 1
- 238000005292 vacuum distillation Methods 0.000 description 1
- 239000008096 xylene Substances 0.000 description 1
Images
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK 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
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK 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
- E21B43/162—Injecting fluid from longitudinally spaced locations in injection well
Definitions
- a first solvent, more dense than water, is l 1 0 earc 6/ injected into the reservoir near the top of the reservoir, and a second solvent, less dense than water, is 56 R f Ct d injected into the reservoir near or at the bottom of the l 1 e erences reservoir. Both solvents are followed by water.
- solvent for the petroleum is introduced into the reservoir and driven through the reservoir. Dissolution of the petroleum by the solvent permits no two phase system between the solvent and the petroleum to exist at the conditions of temperature and pressure existing in the reservoir. Therefore, the retentive forces of capillarity and interfacial tension are nonexistent. These forces decrease the displacement efficiency of a recovery process where the driving fluid or displacing agent and the petroleum exist as two phases in the reservoir.
- the solvent In a miscible flood process the solvent has the capability of mixing completely with the petroleum in the reservoir. A transition zone is formed at the leading edge of the solvent between the solvent and the petroleum in which miscibility exists between the solvent and the petroleum.
- the solvent is normally injected as a slug followed by another fluid such as a gas or an aqueous fluid to drive the solvent slug and the petroleum through the reservoir.
- the ideal sought after is piston-like displacement. That is, the displacing fluids should ideally present a flat front to the petroleum in the reservoir and displace it uniformly through the reservoir. Most miscible solvent slugs are followed by an aqueous fluid to drive them through the reservoir. Moreover, most miscible solvent injection methods have heretofore involved only light hydrocarbons with densities less than water. Problems have arisen with such processes, however.
- the invention is a throughput method for the miscible displacement of petroleum from a subterranean reservoir involving at least one injection point high in the reservoir and at least one injection point low in the reservoir.
- a petroleum solvent more dense than water is injected into the injection point high in the reservoir followed by a driving fluid.
- a petroleum solvent less dense than water is injected into the injection point low in the reservoir followed by a driving fluid.
- the two solvent slugs are driven through the reservoir forcing petroleum to a production well where it is produced.
- FIG. 1 shows a hydrocarbon reservoir penetrated by an injection well and a production well at the beginning of a flood.
- FIG. 2 shows the same wells at an intermediate point of the flood.
- FIG. 3 shows the same wells near the end of the flood.
- Well 11 equipped with conventional equipment which prevents fluid communication between fluids in the annulus l5 and the tubing 16.
- Well 12 has at least one set of perforations 17.
- a fluid 18 more dense and preferably of lower viscosity than water is injected into the reservoir 10 through the upper perforations 13 via annulus 15 of well 11.
- a fluid 19 less dense and preferably of lower viscosity than water is injected into reservoir 10 through the lower perforations 14 via the tubing 16 of well 11. The fluid 18 tends to flow downward in the reservoir while the fluid 19 tends to rise in the reservoir.
- An aqueous fluid injected into both upper and lower perforations following the solvents displaces the solvent heavier than water 18 downward and the solvent lighter than water 19 upward as the fluids flow horizontally toward the producing well 12.
- Aqueous fluid displacement of the solvents is very efficient due to the favorable viscosity contrast, water viscosity being higher than either solvent viscosity.
- FIG. 2 shows the relative position of the solvent slugs after solvent injection has been terminated and an aqueous fluid has been injected for a short period of time.
- the aqueous fluid 20 is now forming a bank behind the solvents and is drivingthe solvents in a vertical slug through the reservoir.
- a particularly preferred embodiment of our invention is to design the solvent slugs so that a mixture of the solvents will have a density substantially equal to water. Thus, with no density difference between the solvent mixture and the displacing water, no segregation will occur, the slug retainsits identity and the petroleum displacement approaches a piston-like configuration.
- injection of the two solvents in different wells may provide substantially the same advantage of injection of both solvents in the same well.
- the character of the reservoir and location of the wells will enable one skilled in the art to choose a configuration that will most likely provide optimum performance.
- the solvents for use in our invention are of two general types, more dense than water and less dense than water. Those which are more dense than water should ideally also be substantially chemically inert to water and have solubility characteristics whichenable them to dissolve adequate amounts of petroleum. It is preferred that the more dense solvent have a viscosity less than water. Ideally, the solvent should be completely miscible with the petroleum so that the interface between the leading edge of the solvent and the petroleum is removed. Examples of specific solvents include but are not limited to carbon disulfide and chlorinated hydrocarbons such as methylene dichloride and carbon tetrachloride.
- carbon disulfide is the preferred heavier than water solvent because of its unique properties or ease of manufacture and recovery.
- bitumen is more soluble in carbon disulfide than in other solvents and certain bitumens may only be soluble to any appreciable extend in carbon disulfide.
- carbon disulfide is preferred. lt is a characteristic of covalently bonded halogens such as those found in halogenated hydrocarbons that they tend to poison some refinery catalysts.
- Carbon disulfide does not and in addition is quite easily removed from recovered crude by physical separation processes to be reused again, leaving the crude substantially free of carbon disulflde.
- Carbon disulflde may also have a great economic advantage over halogenated hydrocarbons since it may be manufactured by the reaction between coke (carbon) and sulfur which are often found in excess near petroleum-producing areas.
- the solvent less dense than water to be used in our invention includes any aromatic or aliphatic hydrocarbon which will solubilize partially or completely the crude petroleum to be recovered.
- suitable solvents include light crude oil and partially refined fractions thereof, e.g., side cuts from fractionating columns, gas oils, kerosene, naphthas, straight-run gasoline, and liquifled petroleum gases. Pure components of any of the above are also suitable, for example, toluene, xylene, and benzene.
- the size of solvent slug to be used will depend on the solvents chosen and the degree of recovery desired. The degree of recovery desired is a matter of economics and may be determined by those skilled in the art without engaging in inventive effort. As an aid in determining the size of slug needed the following procedure may be used but is not intended to limit the scope of our invention or tie it to any routine calculation procedure.
- the size of a slug of petroleum solvent for example, may be calculated by a formula such as:
- Routine laboratory experimentation may be used to determine the solubility of a given crude petroleum in the solvents used and core analysis will yield information on the amount of crude per acre foot of formation. Thus, the size of solvent slug for any field may be determined.
- the driving fluid for use in our invention may be gaseous or liquid.
- gases including light hydrocarbons and carbon dioxide may be used for the process of our invention.
- Aqueous fluids are particularly preferred driving fluids in the process of our invention.
- Water, brine and thickened aqueous fluids are all suitable aqueous fluids for the process of our invention.
- a method for producingpetroleum from a subterranean reservoir which comprises:
- a method as in claim 1 wherein the solvent more dense than water comprises carbon disulfide.
- a method as in claim 1 wherein the solvent more dense than water comprises chlorinated hydrocarbons.
- a method as in claim 1 wherein the solvent more dense than water comprises mixtures of carbon disultide and chlorinated hydrocarbons.
- a method for producing petroleum from a subterranean reservoir which comprises:
- a method as in claim 5 wherein the solvent more dense than water comprises carbon disulfide.
- a method as in claim 5 wherein the solvent more dense than water comprises chlorinated hydrocarbons.
- a method as in claim 5 wherein the solvent more dense than water comprises mixtures of carbon disulfide and chlorinated hydrocarbons.
- a method for producing petroleum from a subterranean reservoir which comprises:
- a method as in claim 10 wherein the solvent more dense than water is selected from the group consisting of carbon disulflde and chlorinated hydrocarbons and the driving fluids are aqueous fluids.
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- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
Abstract
A method for the miscible displacement of petroleum from a subterranean reservoir is provided. The method involves injecting two miscible fluids into an injection well and producing petroleum from a production well. A first solvent, more dense than water, is injected into the reservoir near the top of the reservoir, and a second solvent, less dense than water, is injected into the reservoir near or at the bottom of the reservoir. Both solvents are followed by water. The first solvent will tend to flow downward and the second solvent will tend to rise. The solvents will blend and provide piston-like displacement through the reservoir.
Description
unltea mates l'atent Allen et al. 1 Oct. 1, 1974 15 PETROLEUM PRODUCTION TECHNIQUE 3.729.053 4/1973 Froning 166/273 [75] Inventors: Joseph C. Allen, Bellaire; Jack F.
Tate Houston Tex Primary Examiner-James A. Leppink [73] Assignee Texaco Inc New York N Y Attorney, Agent, or Firm-T. H. Whaley; C. G. Ries [22] Filed: May 4, 1973 [57] ABSTRACT [21] Appl. No.: 357,405 A method for the miscible displacement of petroleum from a subterranean reservoir is provided. The 52 U S Cl ,2 l66/274 method involves injecting two miscible fluids into an Ezlb 43/16 injection well and producing petroleum from a prod 5 306 273 duction well. A first solvent, more dense than water, is l 1 0 earc 6/ injected into the reservoir near the top of the reservoir, and a second solvent, less dense than water, is 56 R f Ct d injected into the reservoir near or at the bottom of the l 1 e erences reservoir. Both solvents are followed by water. The
UNITED STATES PATENTS first solvent will tend to flow downward and the sec- 3,003,554 10/1961 Craig, Jr. et al. 166/274 ond solvent will tend to rise. The solvents will blend 3,047,063 7/1962 Connally, Jr. et al. 166/273 and provide piston-like displacement through the res 3,221,810 12/1965 Marx 166/269 ervoir 3,369,601 2/1968 Bond et al.. 166/274 3,565,175 2/1971 Wilson 166/269 11 Claims, 3 Drawing Figures PETROLEUM PRODUCTION TECHNIQUE BACKGROUND OF THE INVENTION 1. Field of the Invention This invention relates to a process for recovering petroleum by miscible displacement.
2. Description of the Prior Art Various methods for inducing the recovery of petroleum from underground reservoirs are in existence. These methods include injecting water, .steam or some aqueous based mixture to drive the oil from the reservoir. These displacement processes are inefficient. The inefficiency of these displacement processes is partly due to the retentive forces of capillarity and interfacial tension. Miscible flooding provides a method for efficiently displacing the petroleum from a reservoir.
In miscible flooding, solvent for the petroleum is introduced into the reservoir and driven through the reservoir. Dissolution of the petroleum by the solvent permits no two phase system between the solvent and the petroleum to exist at the conditions of temperature and pressure existing in the reservoir. Therefore, the retentive forces of capillarity and interfacial tension are nonexistent. These forces decrease the displacement efficiency of a recovery process where the driving fluid or displacing agent and the petroleum exist as two phases in the reservoir.
In a miscible flood process the solvent has the capability of mixing completely with the petroleum in the reservoir. A transition zone is formed at the leading edge of the solvent between the solvent and the petroleum in which miscibility exists between the solvent and the petroleum. For economic reasons the solvent is normally injected as a slug followed by another fluid such as a gas or an aqueous fluid to drive the solvent slug and the petroleum through the reservoir.
In displacement processes in general, the ideal sought after is piston-like displacement. That is, the displacing fluids should ideally present a flat front to the petroleum in the reservoir and displace it uniformly through the reservoir. Most miscible solvent slugs are followed by an aqueous fluid to drive them through the reservoir. Moreover, most miscible solvent injection methods have heretofore involved only light hydrocarbons with densities less than water. Problems have arisen with such processes, however.
In a vertical miscible flood, for example, using a light hydrocarbon solvent slug followed by water, the water will tend to finger throughthe less dense solvent, destroying piston-like displacement and resulting in premature breakthrough of the displacing medium water. In horizontal miscible flooding the light hydrocarbon solvents will tend to override the petroleum in the reservoir and leave much of it unrecovered,
SUMMARY OF THE INVENTION The invention is a throughput method for the miscible displacement of petroleum from a subterranean reservoir involving at least one injection point high in the reservoir and at least one injection point low in the reservoir. A petroleum solvent more dense than water is injected into the injection point high in the reservoir followed by a driving fluid. A petroleum solvent less dense than water is injected into the injection point low in the reservoir followed by a driving fluid. The two solvent slugs are driven through the reservoir forcing petroleum to a production well where it is produced.
BRIEF DESCRIPTION OF THE DRAWINGS FIG. 1 shows a hydrocarbon reservoir penetrated by an injection well and a production well at the beginning of a flood.
FIG. 2 shows the same wells at an intermediate point of the flood.
FIG. 3 shows the same wells near the end of the flood.
DESCRIPTION OF THE PREFERRED EMBODIMENTS rations 14. Well 11 equipped with conventional equipment which prevents fluid communication between fluids in the annulus l5 and the tubing 16. Well 12 has at least one set of perforations 17. A fluid 18 more dense and preferably of lower viscosity than water is injected into the reservoir 10 through the upper perforations 13 via annulus 15 of well 11. A fluid 19 less dense and preferably of lower viscosity than water is injected into reservoir 10 through the lower perforations 14 via the tubing 16 of well 11. The fluid 18 tends to flow downward in the reservoir while the fluid 19 tends to rise in the reservoir. An aqueous fluid injected into both upper and lower perforations following the solvents displaces the solvent heavier than water 18 downward and the solvent lighter than water 19 upward as the fluids flow horizontally toward the producing well 12. Aqueous fluid displacement of the solvents is very efficient due to the favorable viscosity contrast, water viscosity being higher than either solvent viscosity.
FIG. 2 shows the relative position of the solvent slugs after solvent injection has been terminated and an aqueous fluid has been injected for a short period of time. The aqueous fluid 20 is now forming a bank behind the solvents and is drivingthe solvents in a vertical slug through the reservoir.
As the solvent slug migrates through the reservoir the two solvents become mixed with each other due to density differences. This is depicted in FIG. 3.
A particularly preferred embodiment of our invention is to design the solvent slugs so that a mixture of the solvents will have a density substantially equal to water. Thus, with no density difference between the solvent mixture and the displacing water, no segregation will occur, the slug retainsits identity and the petroleum displacement approaches a piston-like configuration. g
The above description is only typical, and many variations will be obvious to one skilled in the art after reference to the teachings contained herein. For example, injection of the two solvents in different wells may provide substantially the same advantage of injection of both solvents in the same well. The character of the reservoir and location of the wells will enable one skilled in the art to choose a configuration that will most likely provide optimum performance.
The solvents for use in our invention are of two general types, more dense than water and less dense than water. Those which are more dense than water should ideally also be substantially chemically inert to water and have solubility characteristics whichenable them to dissolve adequate amounts of petroleum. It is preferred that the more dense solvent have a viscosity less than water. Ideally, the solvent should be completely miscible with the petroleum so that the interface between the leading edge of the solvent and the petroleum is removed. Examples of specific solvents include but are not limited to carbon disulfide and chlorinated hydrocarbons such as methylene dichloride and carbon tetrachloride.
In certain applications carbon disulfide is the preferred heavier than water solvent because of its unique properties or ease of manufacture and recovery. In the case of tar sand oil, for example, the bitumen is more soluble in carbon disulfide than in other solvents and certain bitumens may only be soluble to any appreciable extend in carbon disulfide. Also, where the recovered crude is to be catalytically treated in a refinery, for example, carbon disulfide is preferred. lt is a characteristic of covalently bonded halogens such as those found in halogenated hydrocarbons that they tend to poison some refinery catalysts. Carbon disulfide does not and in addition is quite easily removed from recovered crude by physical separation processes to be reused again, leaving the crude substantially free of carbon disulflde. Carbon disulflde may also have a great economic advantage over halogenated hydrocarbons since it may be manufactured by the reaction between coke (carbon) and sulfur which are often found in excess near petroleum-producing areas.
It is also within the scope of our invention to use as the heavy solvent a blend of carbon disulfide with another component, mutually soluble in carbon disulfide such as a chlorinated hydrocarbon. These materials should also be easily removed from recovered oil by physical separation techniques such as vacuum distillation.
The solvent less dense than water to be used in our invention includes any aromatic or aliphatic hydrocarbon which will solubilize partially or completely the crude petroleum to be recovered. Examples of suitable solvents include light crude oil and partially refined fractions thereof, e.g., side cuts from fractionating columns, gas oils, kerosene, naphthas, straight-run gasoline, and liquifled petroleum gases. Pure components of any of the above are also suitable, for example, toluene, xylene, and benzene.
The size of solvent slug to be used will depend on the solvents chosen and the degree of recovery desired. The degree of recovery desired is a matter of economics and may be determined by those skilled in the art without engaging in inventive effort. As an aid in determining the size of slug needed the following procedure may be used but is not intended to limit the scope of our invention or tie it to any routine calculation procedure. The size of a slug of petroleum solvent, for example, may be calculated by a formula such as:
amount ofcrude per acre-foot of formation degree of depletion desired (decimal) Routine laboratory experimentation may be used to determine the solubility of a given crude petroleum in the solvents used and core analysis will yield information on the amount of crude per acre foot of formation. Thus, the size of solvent slug for any field may be determined.
The driving fluid for use in our invention may be gaseous or liquid. For example, gases including light hydrocarbons and carbon dioxide may be used for the process of our invention. Aqueous fluids are particularly preferred driving fluids in the process of our invention. Water, brine and thickened aqueous fluids are all suitable aqueous fluids for the process of our invention.
We claim:
1. A method for producingpetroleum from a subterranean reservoir which comprises:
injecting a slug of petroleum solvent more dense than water into the upper portion of the reservoir followed by a driving fluid,
injecting a slug of petroleum solvent less dense than water into the lower portion of the reservoir followed by a driving fluid and driving these solvents through the reservoir toward a production point where petroleum is produced.
2. A method as in claim 1 wherein the solvent more dense than water comprises carbon disulfide.
3. A method as in claim 1 wherein the solvent more dense than water comprises chlorinated hydrocarbons.
4. A method as in claim 1 wherein the solvent more dense than water comprises mixtures of carbon disultide and chlorinated hydrocarbons.
5. A method for producing petroleum from a subterranean reservoir which comprises:
injecting a slug of petroleum solvent more dense than water into the upper portion of the reservoir followed by an aqueous driving fluid, I
injecting a slug of petroleum solvent less dense than water into the lower portion of the reservoir followed by an-aqueous fluid and forcing these solvents through the reservoir with an aqueous driving fluid toward a production point where petroleum is produced.
6. A method as in claim 5 wherein the solvent more dense than water comprises carbon disulfide.
7. A method as in claim 5 wherein the solvent more dense than water comprises chlorinated hydrocarbons.
8. A method as in claim 5 wherein the solvent more dense than water comprises mixtures of carbon disulfide and chlorinated hydrocarbons.
9. A method as in claim 5 wherein the solvent slugs, if blended, would have a density about equal to the aqueous driving fluid.
10. A method for producing petroleum from a subterranean reservoir which comprises:
simultaneously injecting a slug of petroleum solvent more dense than water into the upper portion of the reservoir and a slug of petroleum solvent less dense than water into the lower portion of the reservoir, both solvent slugs followed by a driving fluid and driving these solvent slugs through the reservoir toward a production point where petroleum is produced.
11. A method as in claim 10 wherein the solvent more dense than water is selected from the group consisting of carbon disulflde and chlorinated hydrocarbons and the driving fluids are aqueous fluids.
Claims (11)
1. A METHOD FOR PRODUCING PETROLEUM FROM A SUBTERRANEAN RESERVOIR WHICH COMPRISES: INJECTING A SLUG OF PETROLEUM SOLVENT MORE DENSE THAN WATER INTO THE UPPER PORTION OF THE RESERVOIR FOLLOWED BY A DRIVING FLUID, INJECTING A SLUG OF PETROLEUM SOLVENT LESS DENSE THAN WATER INTO THE LOWER PORTION OF THE RESERVOIR FOLLOWED BY A DRIVING FLUID AND DRIVING THESE SOLVENTS THROUGH THE RESERVOIR TOWARD A PRODUCTION POINT WHERE PETROLEUM IS PRODUCED.
2. A method as in claim 1 wherein the solvent more dense than water comprises carbon disulfide.
3. A method as in claim 1 wherein the solvent more dense than water comprises chlorinated hydrocarbons.
4. A method as in claim 1 wherein the solvent more dense than water comprises mixtures of carbon disulfide and chlorinated hydrocarbons.
5. A method for producing petroleum from a subterranean reservoir which comprises: injecting a slug of petroleum solvent more dense than water into the upper portion of the reservoir followed by an aqueous driving fluid, injecting a slug of petroleum solvent less dense than water into the lower portion of the reservoir followed by an aqueous fluid and forcing these solvents through the reservoir with an aqueous driving fluid toward a production point where petroleum is produced.
6. A method as in claim 5 wherein the solvent more dense than water comprises carbon disulfide.
7. A method as in claim 5 wherein the solvent more dense than water comprises chlorinated hydrocarbons.
8. A method as in claim 5 wherein the solvent more dense than water comprises mixtures of carbon disulfide and chlorinated hydrocarbons.
9. A method as in claim 5 wherein the solvent slugs, if blended, would have a density about equal to the aqueous driving fluid.
10. A method for producing petroleum from a subterranean reservoir which comprises: simultaneously injecting a slug of petroleum solvent more dense than water into the upper portion of the reservoir and a slug of petroleum solvent less dense than water into the lower portion of the reservoir, both solvent slugs followed by a driving fluid and driving these solvent slugs through the reservoir toward a production point where petroleum is produced.
11. A method as in claim 10 wherein the solvent more dense than water is selected from the group consisting of carbon disulfide and chlorinated hydrocarbons and the driving fluids are aqueous fluids.
Priority Applications (2)
Application Number | Priority Date | Filing Date | Title |
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US00357405A US3838737A (en) | 1973-05-04 | 1973-05-04 | Petroleum production technique |
CA198,270A CA1002873A (en) | 1973-05-04 | 1974-04-26 | Petroleum production technique |
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US00357405A US3838737A (en) | 1973-05-04 | 1973-05-04 | Petroleum production technique |
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US3838737A true US3838737A (en) | 1974-10-01 |
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US00357405A Expired - Lifetime US3838737A (en) | 1973-05-04 | 1973-05-04 | Petroleum production technique |
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Cited By (6)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4109720A (en) * | 1973-10-15 | 1978-08-29 | Texaco Inc. | Combination solvent-noncondensible gas injection method for recovering petroleum from viscous petroleum-containing formations including tar sand deposits |
US4223728A (en) * | 1978-11-30 | 1980-09-23 | Garrett Energy Research & Engineering Inc. | Method of oil recovery from underground reservoirs |
US4304302A (en) * | 1979-10-29 | 1981-12-08 | Texaco Inc. | Method for injecting a two phase fluid into a subterranean reservoir |
WO2005102491A1 (en) * | 2004-04-21 | 2005-11-03 | Prime Services Limited | Process for separating one or more solids from water miscible fluids and an apparatus therefor |
US20080087425A1 (en) * | 2006-08-10 | 2008-04-17 | Chia-Fu Hsu | Methods for producing oil and/or gas |
CN102119258A (en) * | 2008-07-14 | 2011-07-06 | 国际壳牌研究有限公司 | Systems and methods for producing oil and/or gas |
Families Citing this family (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
CA2688937C (en) | 2009-12-21 | 2017-08-15 | N-Solv Corporation | A multi-step solvent extraction process for heavy oil reservoirs |
Citations (6)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3003554A (en) * | 1957-12-05 | 1961-10-10 | Pan American Petroleum Corp | Secondary recovery process with controlled density fluid drive |
US3047063A (en) * | 1959-07-17 | 1962-07-31 | Socony Mobil Oil Co Inc | Recovery of petroleum oil |
US3221810A (en) * | 1964-03-11 | 1965-12-07 | Phillips Petroleum Co | Sweep efficiency in miscible fluid floods |
US3369601A (en) * | 1965-01-21 | 1968-02-20 | Union Oil Co | Secondary recovery method |
US3565175A (en) * | 1969-10-16 | 1971-02-23 | Union Oil Co | Method for reducing gravity segregation of an aqueous flooding fluid |
US3729053A (en) * | 1972-01-05 | 1973-04-24 | Amoco Prod Co | Method for increasing permeability of oil-bearing formations |
-
1973
- 1973-05-04 US US00357405A patent/US3838737A/en not_active Expired - Lifetime
-
1974
- 1974-04-26 CA CA198,270A patent/CA1002873A/en not_active Expired
Patent Citations (6)
Publication number | Priority date | Publication date | Assignee | Title |
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US3003554A (en) * | 1957-12-05 | 1961-10-10 | Pan American Petroleum Corp | Secondary recovery process with controlled density fluid drive |
US3047063A (en) * | 1959-07-17 | 1962-07-31 | Socony Mobil Oil Co Inc | Recovery of petroleum oil |
US3221810A (en) * | 1964-03-11 | 1965-12-07 | Phillips Petroleum Co | Sweep efficiency in miscible fluid floods |
US3369601A (en) * | 1965-01-21 | 1968-02-20 | Union Oil Co | Secondary recovery method |
US3565175A (en) * | 1969-10-16 | 1971-02-23 | Union Oil Co | Method for reducing gravity segregation of an aqueous flooding fluid |
US3729053A (en) * | 1972-01-05 | 1973-04-24 | Amoco Prod Co | Method for increasing permeability of oil-bearing formations |
Cited By (10)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4109720A (en) * | 1973-10-15 | 1978-08-29 | Texaco Inc. | Combination solvent-noncondensible gas injection method for recovering petroleum from viscous petroleum-containing formations including tar sand deposits |
US4223728A (en) * | 1978-11-30 | 1980-09-23 | Garrett Energy Research & Engineering Inc. | Method of oil recovery from underground reservoirs |
US4304302A (en) * | 1979-10-29 | 1981-12-08 | Texaco Inc. | Method for injecting a two phase fluid into a subterranean reservoir |
WO2005102491A1 (en) * | 2004-04-21 | 2005-11-03 | Prime Services Limited | Process for separating one or more solids from water miscible fluids and an apparatus therefor |
US20100264091A1 (en) * | 2004-04-21 | 2010-10-21 | Cameron International Corporation | Process for Separating One or More Solids From Water Miscible Fluids and an Apparatus Therefor |
US8728321B2 (en) | 2004-04-21 | 2014-05-20 | Cameron International Corporation | Process for separating one or more solids from water miscible fluids and an apparatus therefor |
US20080087425A1 (en) * | 2006-08-10 | 2008-04-17 | Chia-Fu Hsu | Methods for producing oil and/or gas |
US8136592B2 (en) * | 2006-08-10 | 2012-03-20 | Shell Oil Company | Methods for producing oil and/or gas |
US8596371B2 (en) | 2006-08-10 | 2013-12-03 | Shell Oil Company | Methods for producing oil and/or gas |
CN102119258A (en) * | 2008-07-14 | 2011-07-06 | 国际壳牌研究有限公司 | Systems and methods for producing oil and/or gas |
Also Published As
Publication number | Publication date |
---|---|
CA1002873A (en) | 1977-01-04 |
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