US3905422A - Method for recovering viscous petroleum - Google Patents
Method for recovering viscous petroleum Download PDFInfo
- Publication number
- US3905422A US3905422A US508385A US50838574A US3905422A US 3905422 A US3905422 A US 3905422A US 508385 A US508385 A US 508385A US 50838574 A US50838574 A US 50838574A US 3905422 A US3905422 A US 3905422A
- Authority
- US
- United States
- Prior art keywords
- wells
- well
- injection
- air
- petroleum
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Expired - Lifetime
Links
- 239000003208 petroleum Substances 0.000 title claims abstract description 56
- 238000000034 method Methods 0.000 title claims description 46
- 238000002347 injection Methods 0.000 claims abstract description 81
- 239000007924 injection Substances 0.000 claims abstract description 81
- 238000004519 manufacturing process Methods 0.000 claims abstract description 76
- 238000011084 recovery Methods 0.000 claims abstract description 64
- 230000015572 biosynthetic process Effects 0.000 claims abstract description 61
- 239000012530 fluid Substances 0.000 claims abstract description 52
- 239000011275 tar sand Substances 0.000 claims abstract description 17
- 239000000463 material Substances 0.000 claims description 6
- 230000000149 penetrating effect Effects 0.000 claims description 6
- 239000000203 mixture Substances 0.000 claims description 5
- 239000010426 asphalt Substances 0.000 claims description 3
- 230000006872 improvement Effects 0.000 claims description 3
- 230000001483 mobilizing effect Effects 0.000 claims description 2
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 abstract description 12
- 238000007254 oxidation reaction Methods 0.000 abstract description 4
- 238000005553 drilling Methods 0.000 abstract description 3
- 238000005755 formation reaction Methods 0.000 description 55
- 239000003921 oil Substances 0.000 description 34
- 238000002485 combustion reaction Methods 0.000 description 15
- 230000008569 process Effects 0.000 description 15
- 239000007789 gas Substances 0.000 description 10
- 239000000839 emulsion Substances 0.000 description 9
- 230000000153 supplemental effect Effects 0.000 description 9
- 239000012071 phase Substances 0.000 description 7
- 238000010795 Steam Flooding Methods 0.000 description 6
- 238000010793 Steam injection (oil industry) Methods 0.000 description 6
- 238000011065 in-situ storage Methods 0.000 description 5
- 230000007246 mechanism Effects 0.000 description 4
- 238000010438 heat treatment Methods 0.000 description 3
- 230000035699 permeability Effects 0.000 description 3
- 230000009467 reduction Effects 0.000 description 3
- 244000186140 Asperula odorata Species 0.000 description 2
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 2
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 description 2
- 235000008526 Galium odoratum Nutrition 0.000 description 2
- ATUOYWHBWRKTHZ-UHFFFAOYSA-N Propane Chemical compound CCC ATUOYWHBWRKTHZ-UHFFFAOYSA-N 0.000 description 2
- 239000008186 active pharmaceutical agent Substances 0.000 description 2
- QVGXLLKOCUKJST-UHFFFAOYSA-N atomic oxygen Chemical compound [O] QVGXLLKOCUKJST-UHFFFAOYSA-N 0.000 description 2
- 238000006243 chemical reaction Methods 0.000 description 2
- 239000000295 fuel oil Substances 0.000 description 2
- 230000005484 gravity Effects 0.000 description 2
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- 239000007764 o/w emulsion Substances 0.000 description 2
- 230000003647 oxidation Effects 0.000 description 2
- 239000001301 oxygen Substances 0.000 description 2
- 229910052760 oxygen Inorganic materials 0.000 description 2
- 239000011269 tar Substances 0.000 description 2
- OTMSDBZUPAUEDD-UHFFFAOYSA-N Ethane Chemical compound CC OTMSDBZUPAUEDD-UHFFFAOYSA-N 0.000 description 1
- 239000002253 acid Substances 0.000 description 1
- 238000013459 approach Methods 0.000 description 1
- 239000001273 butane Substances 0.000 description 1
- 239000001569 carbon dioxide Substances 0.000 description 1
- 229910002092 carbon dioxide Inorganic materials 0.000 description 1
- 229910052729 chemical element Inorganic materials 0.000 description 1
- 239000003795 chemical substances by application Substances 0.000 description 1
- 230000006835 compression Effects 0.000 description 1
- 238000007906 compression Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 238000002474 experimental method Methods 0.000 description 1
- 229930195733 hydrocarbon Natural products 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 239000011261 inert gas Substances 0.000 description 1
- 229910052500 inorganic mineral Inorganic materials 0.000 description 1
- 239000011707 mineral Substances 0.000 description 1
- 238000005065 mining Methods 0.000 description 1
- IJDNQMDRQITEOD-UHFFFAOYSA-N n-butane Chemical compound CCCC IJDNQMDRQITEOD-UHFFFAOYSA-N 0.000 description 1
- OFBQJSOFQDEBGM-UHFFFAOYSA-N n-pentane Natural products CCCCC OFBQJSOFQDEBGM-UHFFFAOYSA-N 0.000 description 1
- 239000003345 natural gas Substances 0.000 description 1
- 229910052757 nitrogen Inorganic materials 0.000 description 1
- 238000002360 preparation method Methods 0.000 description 1
- 238000002203 pretreatment Methods 0.000 description 1
- 230000002035 prolonged effect Effects 0.000 description 1
- 230000001902 propagating effect Effects 0.000 description 1
- 239000001294 propane Substances 0.000 description 1
- 239000000700 radioactive tracer Substances 0.000 description 1
- 230000001105 regulatory effect Effects 0.000 description 1
- 230000004044 response Effects 0.000 description 1
- 239000004576 sand Substances 0.000 description 1
- 229920006395 saturated elastomer Polymers 0.000 description 1
- 239000013589 supplement Substances 0.000 description 1
- 238000010408 sweeping Methods 0.000 description 1
- 239000012808 vapor phase Substances 0.000 description 1
Images
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
- E21B43/243—Combustion in situ
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/30—Specific pattern of wells, e.g. optimizing the spacing of wells
Definitions
- Unheated air is injected into the secondary injection wells at a pressure from about 10% to about 90% and preferably around 50% of the pressure at which the thermal recovery fluid is being injected into the central injection wells.
- a pressure gradient is maintained around the production wells which confines the mobilized petroleum and the thermal recovery fluid to the intended pattern.
- a low temperature oxidation reaction also occurs as a consequence of the unheated air injection which pretreats petroleum in the formation between the air pressurization wells and the production wells so that the next phase of oil recovery is improved.
- This invention pertains to an oil recovery process and more particularly to a supplemental oil recovery pro-' cess for use in recovering viscous petroleum from subterranean formations including tar sand deposits. Still more particularly, this invention pertains to a method for pretreating a section of the formation immediately surrounding a pattern being subjected to a supplemental oil recovery process in order to confine the recovery e fluid in the pattern and also to pretreat'the formation in preparation for the second phase of the oil recovery process.
- water drive or water injection may be utilized to driveor displace oil toward a production well. This is commonly referred to as secondary recovery. 4
- viscous oil or heavy oil or low APl gravity oil is defined as petroleum whose API gravity is lessthan about 12 API.
- bitumen sand or tar sand deposit such' as those located in the western United States and in Alberta, Canada.
- the bituminous petroleum contained in tar sand deposits is essentially immobile at formation temperature. and so substantial supplemental treatment must be applied to bituminous petroleum in order to render it sufficiently mobile that it will move to a production well so that it may be recovered to the surface of the earth.
- my invention comprises a process for recovering viscous petroleum from the subterranean formation' wherein at least one injection well is drilled in the formation and a plurality of production wells are arranged symetrically around the production well, and a thermal recovery fluid such as 'steam,heated air, a mixture of steam and air orhot'water isinjected into the injection'well to heatthe formation withinthe pattern defined by the production wells so as to'mobilize the viscous petroleum contained in the formation within the-pattern.
- a thermal recovery fluid such as 'steam,heated air, a mixture of steam and air orhot'water
- a plurality' of air pressurization wells are drilled around the production wells in a generally sym'etrical fashion, and air is injected into the air pressurization wells at a pressure from about 10% to about 90% of the pressure at'which the thermal recovery fluid is being introduced into the injection well.
- a pressure gradi' ent formed around the pattern which serves toconfine the thermal recovery fluid, thereby improving the capture efficiency of and thermal 'effieiency of the thermal recovery operation.
- Air injection also pre-exposes the subterranean formation to air at a low temperature, thereby pretreating the formation so as to render it more responsive to oil recovery by thermal means such as steam, in situ combustion, or low-temperature oxidation recovery.
- the production wells are converted to thermal recovery fluid injection wells and the air pressurization wells are converted to new production wells. and the thermal recovery operation is extended outward to the area previously pretreated by air pressurization.
- FIG. 1 illustrates in plan view a four well pattern for practicing my invention comprising one thermal recovery fluid injection well. one production well. and two air pressurization wells. 3
- FIG. 2 depicts in plan view a field being exploited by means of a thermal drive in which a central thermal recovery fluid injection well is surrounded by four production wells. and located around the four production wells are eight air pressurization wells for use in practicing the process of my invention.
- my invention involves the drilling of one or v more wells in an area of the formation remote froma swept area between the injection well and production well for the purpose of injecting unheated air intothe formation to create the desired pressure gradients.
- the wells will be located on the opposite side of the production well from the injection well. so as to form an encircling pressure gradient when unheated air is injected into the additional air pressurization wells.
- the thermal recovery fluid injected into well I. which may be air or steam or amixture of airand steam or hot water. it sweeps the formation to form the expected tear shaped swept area 2 and ultimately the injected fluid breaks through into production well-3.
- oil-in-watcr emulsions are very low in viscosity and are very readily resolved into their sepa' rate phases by contacting the emulsion with a mineral acid.
- Pretrcating the bituminous petroleum with unheated air causes a preference for oil-in-water emulsions which explains the reduction in pressure required to drive the bituminous petroleum toward the production well.
- the shape of the swept area in a conventional inverted five spot pattern is approximately as is shown in FIG. 2 by dotted line 11. It can be secnthat thev swept area cusps outward as the injected fluid approaches the production well. with the result thatnot quite all of the square pattern is swept by the fluid. Nonetheless. relatively high sweep efficiency is realized. Frequently. the five spot pattern is part of an even larger pattern in which there are many contiguous five spot patterns. The performance'of a I field may be analyzed by examining only the single five spot element. however. and so only one five spot ele ment is shown in FIG. 2.
- FIG. 2 An application ofv the process of my invention to a supplemental oil recovery process employing a five spot pattern is shown in FIG. 2.
- the air pressurization wells ll. 12. I3. 14, I5, l6. l7 and 18 are drilled around production wells 7, 8. 9 and I0.
- the spacing between the inncrgrid and the outer grid can vary, it is convenient to make the spacing somewhat equal for reasons that will be explained later.
- air pressurization may similarly be initiated in wells 1l-18.
- Injection may be initiated simultaneously into all the wells, or it is sometimes satisfactory to inject into only part of the wells initially, after which unheated air injection is switched to the other wells. For example, injection may initially be into wells 11, 13, and 17 for a period of time, after which injection is switched to wells 12, 14, 16 and 18.
- the pressure at which air is injection into the air pressurization wells surrounding the production wells may be maintained between about 10% and about 90% of the pressure at which the thermal recovery fluid is injected into injection well 6. l have found that in an especially preferred embodiment, the pressure in the air pressurization wells is maintained at approximately 50% of the pressure at which steam is being injected into the steam injection wells. Since production wells 7, 8, 9 and 10 are at a pressure much lower than central injection well 6 and also lower than air pressurization wells ll-l8, there will be a positive pressure gradient not only between central injection well 6 and production wells 7, 8, 9 and 10, but there will also be a similarly positive pressure gradient between air pressurization wells 1 l-18 and production wells 7-10. Thus there will be some flow of air from air pressurization wells into the production wells.
- the pressure at which unheated air is injected into air pressurization wells 11-18 is maintained at the lowest level which will give a slight indication of gas being produced at production wells 7-10, indicating that a slow movement of unheated air through the formation is being accomplished. This can be facilitated by adding a small amount of a readily detectable material to the injected air to function as a tracer.
- the supplemental heating step may be terminated and the injection of unheated air into well 6 is sufficient to maintain the in situ combustion reaction which propagates through the formation toward production wells 7, 8, 9 and 10.
- unheated air is being injected into well 6 and also unheated air is being injected at a lower pressure into air pressurization wells "-18; however, a totally different kind of reaction is occurring as a consequence of injection of unheated air into well 6 from that which is occurring as a consequence of injection of unheated air into wells 1 l-18.
- controlled combustion reaction in which the temperature of the combustion front propagating outwardly from injection well 6 is regulated by the injection of water or steam simultaneously or intermittently with the injection of air into the formation after the combustion reaction has been initiated.
- This type of process appears to be more suitable for use in recovering viscous asphaltic petroleum from tar sand deposits than either steam flooding or in situ combustion alone.
- the application of the process of my invention to a formation being exploited by means of controlled combustion would entail in one example, the simultaneous injection of steam and air into well 6 while unheated air is being injected at a reduced pressure into wells ll-l8 to maintain the desired pressure gradients around production wells 7-10.
- the process of my invention may also be used with other patterns, such as a seven-well delta pattern, a hexagonal pattern, or other arrangements of a plurality of production wells around one or more central injection wells.
- gases other than air For example, carbon dioxide, natural gas, other gaseous hydrocarbons such as ethane, propane, or butane, as well as inert gases such as nitrogen may be injected into wells 1l-18 at a pressure below the pressure at which the thermal fluid is being injected into central injection well 6, in order to create the gas saturated zone and to establish the confining pressure gradients around the production wells.
- gases other than air or oxygen containing gases will not achieve the low temperature oxidation pretreatment of the bituminous petroleum as is achieved when air is injected into the outer wells.
- the especially preferred embodiment employs the injection of unheated air or an oxygen containing gas into pressurization wells 11-18.
- unheated air it is meant that the air is not deliberately heated prior to injection. Some heating occurs in the compression of air, however.
- unheated air means air having a temperature below about 400F and preferably below about 200F.
- a one-half acre five spot pattern was drilled in the Athabasca tar sand deposit consisting of a central injection well and four surrounding production wells essentially as shown in FIG. 2.
- eight air pressurization wells drilled around the small pilot, with the expectation that these wells would later be used in an expanded pilot, and so were completed so that they may serve as air pressurization wells initially and as production wells in the later stages of the operation.
- Well spacing was chosen so that wells 12, 14, 16 and 18 defined a five acre pattern and wells 11, 13, 15 and 17 defined a 10 acre pattern.
- a mixture of steam and air was injected into the central injection well 6, the ratio of steam to air being approximately 0.4 barrels of steam (as water) per thousand standard cubic feet of air.
- the injection rate was increased from a fairly low initial level to the maximum rate at which air and steam could be injected into the central injection well, and was maintained in the later stages of the operation at a fairly constant level of about 500,000 standard cubic feet of air per day. While steam and air were being injected into central injection well 6 for the purpose of causing a controlledcornbustion reaction to propagate through the formation toward the four outer production wells'7, 8, 9 and 10, air was injected into the outer ring of air pressurization wells. Air was injected sequentially into the eight outer air pressurization wells rather than simultaneously in this particular pilot because of equipment limitations.
- thermo recovery fluid is a mixture of air and steam.
- a method of recovering bitumen from a tar sand deposit comprising 7 a. penetrating the tar sand injection well; w
Abstract
The efficiency of an oil recovery process, being applied to a subterranean, viscous petroleum containing formation such as a tar sand deposit involving the injection of a thermal recovery fluid such as steam, heated air or hot water into an injection well to mobilize and displace petroleum toward a production well is improved by drilling a series of secondary injection wells or pressurization wells around the production wells. Unheated air is injected into the secondary injection wells at a pressure from about 10% to about 90% and preferably around 50% of the pressure at which the thermal recovery fluid is being injected into the central injection wells. A pressure gradient is maintained around the production wells which confines the mobilized petroleum and the thermal recovery fluid to the intended pattern. A low temperature oxidation reaction also occurs as a consequence of the unheated air injection which pretreats petroleum in the formation between the air pressurization wells and the production wells so that the next phase of oil recovery is improved.
Description
United States Patent [19] Woodward [4 1 Sept. 16, 1975 [54] METHOD FOR RECOVERING VISCOUS PETROLEUM [75] Inventor: Charles D. Woodward, Houston,
Tex.
[73] Assignee: Texaco Inc., New York, NY.
[22] Filed: Sept. 23, 1974 [21] Appl. No.: 508,385
[52] US. Cl. 166/245; 166/256; 166/272 [51] Int. Cl. E21B 43/24 [58] Field of Search 166/256, 272, 259, 245, 166/268 [56] References Cited UNITED STATES PATENTS 2,994,376 8/1961 Crawford et a1 166/256 X 3,007,521 11/1961 Trantham et a1. 166/256 X 3,032,102 5/1962 Parker 166/256 X 3,113,619 12/1963 Reichle 166/256 X 3,172,467 3/1965 Trantham et a1. 166/256 X 3,253,652 5/1966 Connally Jr et al. 166/256 X 3,288,212 11/1966 OBrien et a1. 166/245 3,472,318 10/1969 Woodward 166/256 X Primary ExaminerStephen J. Novosad Attorney, Agent, or FirmT. H. Whaley; C. G. Ries; Jack H. Park 57 ABSTRACT The efficiency of an oil recovery process, being applied to a subterranean, viscous petroleum containing formation such as a tar sand deposit involving the injection of a thermal recovery fluid such as steam, heated air or hot water into an injection well to mobilize and displace petroleum toward a production well is improved by drilling a series of secondary injection wells or pressurization wells around the production wells. Unheated air is injected into the secondary injection wells at a pressure from about 10% to about 90% and preferably around 50% of the pressure at which the thermal recovery fluid is being injected into the central injection wells. A pressure gradient is maintained around the production wells which confines the mobilized petroleum and the thermal recovery fluid to the intended pattern. A low temperature oxidation reaction also occurs as a consequence of the unheated air injection which pretreats petroleum in the formation between the air pressurization wells and the production wells so that the next phase of oil recovery is improved.
11 Claims, 2 Drawing Figures 1 METHOD FOR RECOVERING 'VISCOUS PETROLEUM CROSS REFERENCE TO RELATED APPLICATIONS This application is related to commonly owned application Ser. No. 493,286, filed July 3l. 1974.
BACKGROUND OF THE INVENTION 1. Field of the Invention This invention pertains to an oil recovery process and more particularly to a supplemental oil recovery pro-' cess for use in recovering viscous petroleum from subterranean formations including tar sand deposits. Still more particularly, this invention pertains to a method for pretreating a section of the formation immediately surrounding a pattern being subjected to a supplemental oil recovery process in order to confine the recovery e fluid in the pattern and also to pretreat'the formation in preparation for the second phase of the oil recovery process.
2. Description of the Prior Art When oil is discovered in subterranean reservoirs, certain conditions must be present in order to be able to recover the oil from the formation. It is necessary that the oil viscosity be sufficiently low that it is mobile, e.g. that it will flow if sufficient force is applied to it. Moreover, the formation must have adequate permeability or flow channels so that fluids may move from one point in the formation to another. Finally, some drive force must exist naturally or be supplied to the formation in order to move the formation petroleum to gas, gas cap or bottom water drive is present, oil may flow spontaneously without the application of any additional drive force and this phase of oil recovery is referred to as primary recovery. When the oil viscosity is sufficiently low and there exists satisfactory formation permeability but insufficient natural energy exists to cause it to flow to the surface of the earth, water drive or water injection may be utilized to driveor displace oil toward a production well. This is commonly referred to as secondary recovery. 4
There are many formations throughout the world which contain petroleum whose viscosity is so great that the petroleum will not move even if sufficient natural or artificial drive force is applied to it, even though the formation permeability is adequate. This petroleuum is commonly referred to as viscous oil or heavy oil or low APl gravity oil. Forthe purpose of this application, viscous petroleum or heavyoil is defined as petroleum whose API gravity is lessthan about 12 API. The most extreme example of viscous petroleum containing formations are the so called bitumen sand or tar sand deposit such' as those located in the western United States and in Alberta, Canada. The bituminous petroleum contained in tar sand deposits is essentially immobile at formation temperature. and so substantial supplemental treatment must be applied to bituminous petroleum in order to render it sufficiently mobile that it will move to a production well so that it may be recovered to the surface of the earth.
One of the most popular methods for recovering viscous petroleum such as bituminous petroleum from subterranean formations such as tar sand deposits which are too deep to permit strip mining thereof, is
steam flooding. Steam is injected into one well and travels to a remotely located well from which it is recovered to the surface'of the earth. The principal effect of steam injection is the increase in petroleum temperature which reduces the viscosity of the petroleum. Although the viscosity of bituminous petroleum in a tar sand deposit is in the range of millions of centipoise at normal I formation temperatures, the viscositytemperature relationship is exceedingly sharp, and the viscosity of the bituminous petroleum is reduced to only a few centipoise at around 300F.
Numerous problems prevent effective utilization of steam injection in tar sand deposits. Because of the fact that steam is principally in the vapor phase when it is injected into the formation, the steam does not displace petroleum'in a piston-like fashion, and much loss of the injected steam to the surrounding formation beyond the confines of the pattern being utilized in the supplemental oil recovery process occurs, with the attendant loss of thermal efficiency. Moreover, because of the extremely high viscosity of bituminous petroleum. the viscosity reduction resulting from petroleum being eontacted with steam is frequently not sufficient to mobilize the highly viscous petroleum, and some form of pretreatment must be utilized.
Even though the petroleum viscosity is reduced as a consequence of being heated with steam, bituminous petroleum is quite prone to form high viscosity waterin-oil emulsions, which are viscous and difficult to displace through the formation.
In view of the foregoing discussion, it is apparent that there is a substantial unfulfilled need for a method of conducting a steam flooding operation in viscous petroleum'containing formation so as to minimize the-loss of injected steam to the surrounding formation-beyond the confines of the pattern of the wells being utilized in the supplemental oil recovery process, and further to pretreat the formation so as 'to-improve-the efficiency of the steam flooding operation and to minimize the formation of water-in-oil emulsions;
SUMMARY OF THE INVENTION Briefly, my invention comprises a process for recovering viscous petroleum from the subterranean formation' wherein at least one injection well is drilled in the formation and a plurality of production wells are arranged symetrically around the production well, and a thermal recovery fluid such as 'steam,heated air, a mixture of steam and air orhot'water isinjected into the injection'well to heatthe formation withinthe pattern defined by the production wells so as to'mobilize the viscous petroleum contained in the formation within the-pattern. A plurality' of air pressurization wells are drilled around the production wells in a generally sym'etrical fashion, and air is injected into the air pressurization wells at a pressure from about 10% to about 90% of the pressure at'which the thermal recovery fluid is being introduced into the injection well. As a consequence ofthe air pressurization step, a pressure gradi' ent formed around the pattern which serves toconfine the thermal recovery fluid, thereby improving the capture efficiency of and thermal 'effieiency of the thermal recovery operation. Air injection also pre-exposes the subterranean formation to air at a low temperature, thereby pretreating the formation so as to render it more responsive to oil recovery by thermal means such as steam, in situ combustion, or low-temperature oxidation recovery. After the main thermal recovery fluid has broken through at the production wells in the pattern, the production wells are converted to thermal recovery fluid injection wells and the air pressurization wells are converted to new production wells. and the thermal recovery operation is extended outward to the area previously pretreated by air pressurization.
BRIEF DESCRIPTION OF THE DRAWING FIG. 1 illustrates in plan view a four well pattern for practicing my invention comprising one thermal recovery fluid injection well. one production well. and two air pressurization wells. 3
FIG. 2 depicts in plan view a field being exploited by means of a thermal drive in which a central thermal recovery fluid injection well is surrounded by four production wells. and located around the four production wells are eight air pressurization wells for use in practicing the process of my invention. X
DESCRIPTION OF THE PREFERRED EMBODIMENTS Briefly. my invention involves the drilling of one or v more wells in an area of the formation remote froma swept area between the injection well and production well for the purpose of injecting unheated air intothe formation to create the desired pressure gradients. As can be seen from FIG. I. the wells will be located on the opposite side of the production well from the injection well. so as to form an encircling pressure gradient when unheated air is injected into the additional air pressurization wells. After the thermal recovery fluid injected into well I. which may be air or steam or amixture of airand steam or hot water. it sweeps the formation to form the expected tear shaped swept area 2 and ultimately the injected fluid breaks through into production well-3. Once the thermal recove y. fluid has broken through at the production well. that phase of the production operation is concluded and generally little or no additional oil will berecovered by continuing injection of thermal recovery fluid into well I. If additional air pressurization wells 4 and 5.are drilled and unheated, air is injected into wells 4 and 5, during the period when thermal recovery fluid is traversing through the formation from injection well I to produc-- tion well 3. the formation between air pressurization wells 4 and 5 and production well 3 will havebcen pretreated as a consequence of'unheated air injection into wells 4 and 5. Several benefits result from this pretreat ment process. The pressure gradients created around wells 4 and S confine the recovery fluid so as to avoid its loss into the formation, and similarly. avoid the movement of mobilized petroleum from the formation away from the vicinity of production well 3. Thus the pressure gradients assist in improving the-thermal efflciency and capture efficiency of the supplemental oil recovery operation. In addition. a gas saturation is established in that portion of the formation between wells 3, 4. and 5. which will improve the receptivity of the oil formation tothe subsequent injection of thermal recovery fluid in the next phase of the recovery program. Additionally. it has been discovered that bituminous petroleum such as is found in tar sand deposits is benefici- I atcd by a prior contact with unheated air, for a prolonged period of time. Numerous benefits result from such prior contact. including increased oil recovery cfficieney and a reduction in the pressure gradientbetween wells necessary to drive the fluid toward the production well. Additionally. it has been observed that the pretreatment wih unheated air causes an additional improvement in the response of bituminous petroleum such as .tar sands to steam flooding where the principle mechanism for transporting viscous petroleum through the porous formation involves the formation of a low viscosity oil-in-water emulsion. In application of a steam drive to a tar sandmleposit which has not been pretreated with untreated air. both oil-in-water emulsions and water-in-oil emulsions are formed. Water-inoil emulsions have relatively high viscosities and require additional treatment in order to break the emulsions. whereas oil-in-watcr emulsions are very low in viscosity and are very readily resolved into their sepa' rate phases by contacting the emulsion with a mineral acid. Pretrcating the bituminous petroleum with unheated air causes a preference for oil-in-water emulsions which explains the reduction in pressure required to drive the bituminous petroleum toward the production well. i
While the above described process'contemplates the simplest method of applying the process of my invention. ordinarily supplemental oil recovery of the type wherein a thermal recovery fluid such as steam or hot water or heated air forin situ combustion is injected into the formation involves the use of a pattern in order to achieve greater sweep efficiency. The most common type of pattern is so called inverted five spot. such as is shown in FIG. 2. In a simple five spot pattern. an injection well 6 is located in the center of the square grid and four production wells 7, 8. 9 and 10 are located on the corners of the square. Thus steam is injected into the central injection well and moves outwardly toward the four production wells. sweeping nearly all of the area within the square whose corners are defined by production wells 7. 8. 9 and I0. The shape of the swept area in a conventional inverted five spot pattern is approximately as is shown in FIG. 2 by dotted line 11. It can be secnthat thev swept area cusps outward as the injected fluid approaches the production well. with the result thatnot quite all of the square pattern is swept by the fluid. Nonetheless. relatively high sweep efficiency is realized. Frequently. the five spot pattern is part of an even larger pattern in which there are many contiguous five spot patterns. The performance'of a I field may be analyzed by examining only the single five spot element. however. and so only one five spot ele ment is shown in FIG. 2.
An application ofv the process of my invention to a supplemental oil recovery process employing a five spot pattern is shown in FIG. 2. The air pressurization wells ll. 12. I3. 14, I5, l6. l7 and 18 are drilled around production wells 7, 8. 9 and I0. Although the. spacing between the inncrgrid and the outer grid can vary, it is convenient to make the spacing somewhat equal for reasons that will be explained later.
In the pattern as shown in FIG. 2, when steam injection is initiated into steam injection well 6, air pressurization may similarly be initiated in wells 1l-18. Injection may be initiated simultaneously into all the wells, or it is sometimes satisfactory to inject into only part of the wells initially, after which unheated air injection is switched to the other wells. For example, injection may initially be into wells 11, 13, and 17 for a period of time, after which injection is switched to wells 12, 14, 16 and 18.
The pressure at which air is injection into the air pressurization wells surrounding the production wells may be maintained between about 10% and about 90% of the pressure at which the thermal recovery fluid is injected into injection well 6. l have found that in an especially preferred embodiment, the pressure in the air pressurization wells is maintained at approximately 50% of the pressure at which steam is being injected into the steam injection wells. Since production wells 7, 8, 9 and 10 are at a pressure much lower than central injection well 6 and also lower than air pressurization wells ll-l8, there will be a positive pressure gradient not only between central injection well 6 and production wells 7, 8, 9 and 10, but there will also be a similarly positive pressure gradient between air pressurization wells 1 l-18 and production wells 7-10. Thus there will be some flow of air from air pressurization wells into the production wells.
In one embodiment of the process of my invention, the pressure at which unheated air is injected into air pressurization wells 11-18 is maintained at the lowest level which will give a slight indication of gas being produced at production wells 7-10, indicating that a slow movement of unheated air through the formation is being accomplished. This can be facilitated by adding a small amount of a readily detectable material to the injected air to function as a tracer.
While the above described method of applying the process of my invention has generally referred to the use of steam injection, it is to be understood that it is not so limited. The same procedure may be used in an in situ combustion operation, in which heated air is injected into central injection well 6 to initiate a combustion reaction within the formation, which propagates through the formation toward production wells 7-10. Unheated air is similarly injected into wells 11-18, which will not result in the same combustion reaction as occurs within the central pattern, since the oil temperature is never raised to a point at which the combustion reaction is initiated. Once the in situ combustion reaction has been initiated by heating the air being injected into well 6 or by direct application of heat to the oil formation while injecting unheated air, the supplemental heating step may be terminated and the injection of unheated air into well 6 is sufficient to maintain the in situ combustion reaction which propagates through the formation toward production wells 7, 8, 9 and 10. Thus after the initial ignition step, unheated air is being injected into well 6 and also unheated air is being injected at a lower pressure into air pressurization wells "-18; however, a totally different kind of reaction is occurring as a consequence of injection of unheated air into well 6 from that which is occurring as a consequence of injection of unheated air into wells 1 l-18.
The above described process may similarly be used in the application of a modified combustion process.
known as a controlled combustion reaction, in which the temperature of the combustion front propagating outwardly from injection well 6 is regulated by the injection of water or steam simultaneously or intermittently with the injection of air into the formation after the combustion reaction has been initiated. This type of process appears to be more suitable for use in recovering viscous asphaltic petroleum from tar sand deposits than either steam flooding or in situ combustion alone. Thus the application of the process of my invention to a formation being exploited by means of controlled combustion would entail in one example, the simultaneous injection of steam and air into well 6 while unheated air is being injected at a reduced pressure into wells ll-l8 to maintain the desired pressure gradients around production wells 7-10.
The process of my invention may also be used with other patterns, such as a seven-well delta pattern, a hexagonal pattern, or other arrangements of a plurality of production wells around one or more central injection wells.
While air is the especially preferred fluid for injection into pressurization wells 11-18, certain benefits of the process of my invention may be realized by injecting gases other than air into pressurization wells 11-18. For example, carbon dioxide, natural gas, other gaseous hydrocarbons such as ethane, propane, or butane, as well as inert gases such as nitrogen may be injected into wells 1l-18 at a pressure below the pressure at which the thermal fluid is being injected into central injection well 6, in order to create the gas saturated zone and to establish the confining pressure gradients around the production wells. The use of gases other than air or oxygen containing gases will not achieve the low temperature oxidation pretreatment of the bituminous petroleum as is achieved when air is injected into the outer wells. Accordingly, the especially preferred embodiment employs the injection of unheated air or an oxygen containing gas into pressurization wells 11-18.
By the term unheated air it is meant that the air is not deliberately heated prior to injection. Some heating occurs in the compression of air, however. As used herein, unheated air means air having a temperature below about 400F and preferably below about 200F.
FIELD EXAMPLE In order to demonstrate the operability of the process of my invention, and further to supplement the disclosure contained above, the following description of a field experiment is presented.
A one-half acre five spot pattern was drilled in the Athabasca tar sand deposit consisting of a central injection well and four surrounding production wells essentially as shown in FIG. 2. Similarly, eight air pressurization wells drilled around the small pilot, with the expectation that these wells would later be used in an expanded pilot, and so were completed so that they may serve as air pressurization wells initially and as production wells in the later stages of the operation. Well spacing was chosen so that wells 12, 14, 16 and 18 defined a five acre pattern and wells 11, 13, 15 and 17 defined a 10 acre pattern. A mixture of steam and air was injected into the central injection well 6, the ratio of steam to air being approximately 0.4 barrels of steam (as water) per thousand standard cubic feet of air. The injection rate was increased from a fairly low initial level to the maximum rate at which air and steam could be injected into the central injection well, and was maintained in the later stages of the operation at a fairly constant level of about 500,000 standard cubic feet of air per day. While steam and air were being injected into central injection well 6 for the purpose of causing a controlledcornbustion reaction to propagate through the formation toward the four outer production wells'7, 8, 9 and 10, air was injected into the outer ring of air pressurization wells. Air was injected sequentially into the eight outer air pressurization wells rather than simultaneously in this particular pilot because of equipment limitations. Nevertheless, during the course of the operation, unheated air was injected into each of the outer wells for the purpose of pretreating the formation between these outer pressurization wells and the middle ring of production wells. After the controlled combustion front reached the four production wells, these wells were converted to steam-air injection wells and a mixture of steam and air was injected into these four original production wells simultaneous with the continued injection of steam and air into the original central injection well. Outer wells l2, l4, l6 and 18 which are originally used as air pressurization wells were converted to oil production wells, and oil recovery was obtained from these outer wells. It was noted that the produced fluid was predominantly in the form of a low viscosity oil-in-water emulsion, and a relatively low pressure gradient was maintained between the central injection wells and the outer production wells in the second stage of the operation.
While my invention has been describes in terms of a number of specific illustrative examples, it is not so limited since many variations thereover will be immedi ately apparent to those persons skilled in the related art without departing from the'true spirit and scope of my 7 invention. Similarly, while several mechanisms have been described for the purpose of explaining'the benefits resulting from the application of the process of my invention, it-is not necessarily represented hereby that these are the only or even the principal mechanisms responsible for such benefits, and I do not wish to be bound by any particular explanation of the mechanisms involved. It is mydesire and intention that my invention be limited and restricted only by those limitations and restrictions that appear in the claims appended immediately hereinafter below.
I claim:
1. In a method of recovering petroleum from a subterranean petroleum containing formation penetrated by at least one injection well and by atleast one production well, of the type wherein thermal recovery fluid is introduced into the injection well and petroleum is recovered from the remotely located production well, wherein the improvement for increasing the capture efficiency of the oil recovery operation and for pretreating a portion of the formation for the next phase of the oil recovery'method comprises:
a. completing at least one gas pressurization well in the formation on the opposite side of the production well from the thermal recovery fluid injection well,
b. introducing a gaseous material into the pressurization well at a pressure less than the pressure at which the thermal'recovery fluid is introduced into the injection well for the purpose of pretreating the formation petroleum and creating a pressure gradient around the additional well which serves to confine the injected fluid in mobilized petroleum, and
c. recovering petroleum from the production well.
2. A method as recited in claim 1 wherein the fluid injection into the pressurization well is air.
3. A method as recited in claim 1 wherein the tem- '6. A method as recited in claim 1 wherein the thermal recovery fluid is steam.
7. A method as recited in claim 1 wherein the thermal recovery fluid is heated air. I
8. A method as recited in claim 1 wherein the thermal recovery fluid is a mixture of air and steam.
9. A method as recited in claim 1 wherein a plurality of production wells are drilled around-at least one cen trally located injection well, and a pluralityof pressurization wells are drilled around the pattern definedby the production wells. I v
10. A method as recited in claim 9 wherein the pressurization wellsare later converted to production wells after the oil mobilizing fluid has broken through into the production wells.
1 l. A method of recovering bitumen from a tar sand deposit comprising 7 a. penetrating the tar sand injection well; w
b. penetrating the tar sand deposit with a plurality of production wells equally spaced around the injection well;
c. penetrating the formation with a plurality of air pressurization wells located at a greater distance from the injection wells than the production wells;
d. introducing a thermal recovery fluid into the injection well;
e. recovering petroleum from the production wells;
and I g f. injecting air into the outer pressurization wells at a pressure between about 10% and about of the pressure at which the thermal recovery fluidis injected into the central injection well and at a temperature below 400F.
deposit with at leastone
Claims (11)
1. IN A METHOD FOR RECOVERING PETROLEUM FROM A SUBTERRANEAN PETROLEUM CONTAINING FORMATION PENETRATED BY AT LEAST ONE INJECTION WELL AND BY AT LEAST ONE PRODUCTION WELL, OF THE TYPE WHEREIN THERMAL RECOVERY FLUID IS INTRODUCED INTO THE INJECTION WELL AND PETROLEUM IS REMOVED FROM THE REMOTELY LOCATED PRODUCTION WELL, WHEREIN THE IMPROVEMENT FOR INCREACING THE CAPTURE EFFICIENCY OF THE OIL RECOVERY OPERATION AND FOR PRETREATING A PORTION FOR THE NEXT PHASE OF THE OIL RECOVERY METHOD COMPRISES: A. COMPLETELY AT LEAST ONE GAS PRESSURIZATION WELL IN THE FORMATION ON THE OPPOSITE SIDE OF THE PRODUCTION WELL FROM THE THERMAL RECOVERY FLUID INJECTION WELL, B. INTRODUCING A GASEOUS MATERIAL INTO THE PRESSURIZATION WELL AT A PRESSURE LESS THAN THE PRESSURE AT WHICH THE THERMAL RECOVERY FLUID IS INTRODUCED INTO THE INJECTION WELL FOR THE PURPOSE OF PRETREATING THE FORMATION PETROLEUM AND CREATING A PRESSURE GRADIENT AROUND THE ADDITIONAL WELL WHICH SERVES TO CONFINE THE INJECTED FLUID IN MOBILIZED PERTOLEUM, AND C. RECOVERING PETROLEUM FROM THE PRODUCTION WELL,
2. A method as recited in claim 1 wherein the fluid injection into the pressurization well is air.
3. A method as recited in claim 1 wherein the temperature of the gaseous material is below 400*F.
4. A method as recited in claim 1 wherein the temperature of the gaseous material is below 200*F.
5. A method as recited in claim 1 wherein the pressure at which the gaseous material is injected into the pressurization well is from about 10% to about 90% of the pressure at which the thermal recovery fluid is injected into the injection well.
6. A method as recited in claim 1 wherein the thermal recovery fluid is steam.
7. A method as recited in claim 1 wherein the thermal recovery fluid is heated air.
8. A method as recited in claim 1 wherein the thermal recovery fluid is a mixture of air and steam.
9. A method as recited in claim 1 wherein a plurality of production wells are drilled around at least one centrally located injection well, and a plurality of pressurization wells are drilled around the pattern defined by the production wells.
10. A method as recited in claim 9 wherein the pressurization wells are later converted to production wells after the oil mobilizing fluid has broken through into the production wells.
11. A method of recovering bitumen from a tar sand deposit comprising a. penetrating the tar sand deposit with at least one injection well; b. penetrating the tar sand deposit with a plurality of production wells equally spaced around the injection well; c. penetrating the formation with a plurality of air pressurization wells located at a greater distance from the injection wells than the production wells; d. introducing a thermal recovery fluid into the injection well; e. recovering petroleum from the production wells; and f. injecting air into the outer pressurization wells at a pressure between about 10% and about 90% of the pressure at which the thermal recovery fluid is injected into the central injection well and at a temperature below 400*F.
Priority Applications (4)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US508385A US3905422A (en) | 1974-09-23 | 1974-09-23 | Method for recovering viscous petroleum |
CA229,677A CA1027854A (en) | 1974-09-23 | 1975-06-19 | Method for recovering viscous petroleum |
YU02124/75A YU212475A (en) | 1974-09-23 | 1975-08-20 | Process for the exploitation of naphtha |
BR7505749*A BR7505749A (en) | 1974-09-23 | 1975-09-08 | PROCESS FOR RECOVERING PETROLEUM FROM AN UNDERGROUND FORMATION CONTAINING PETROLEUM |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US508385A US3905422A (en) | 1974-09-23 | 1974-09-23 | Method for recovering viscous petroleum |
Publications (1)
Publication Number | Publication Date |
---|---|
US3905422A true US3905422A (en) | 1975-09-16 |
Family
ID=24022550
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US508385A Expired - Lifetime US3905422A (en) | 1974-09-23 | 1974-09-23 | Method for recovering viscous petroleum |
Country Status (4)
Country | Link |
---|---|
US (1) | US3905422A (en) |
BR (1) | BR7505749A (en) |
CA (1) | CA1027854A (en) |
YU (1) | YU212475A (en) |
Cited By (16)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4194562A (en) * | 1978-12-21 | 1980-03-25 | Texaco Inc. | Method for preconditioning a subterranean oil-bearing formation prior to in-situ combustion |
US4366863A (en) * | 1980-09-29 | 1983-01-04 | Texaco Inc. | Enhanced oil recovery operations |
US4474238A (en) * | 1982-11-30 | 1984-10-02 | Phillips Petroleum Company | Method and apparatus for treatment of subsurface formations |
US4641709A (en) * | 1985-05-17 | 1987-02-10 | Conoco Inc. | Controlling steam distribution |
US4687057A (en) * | 1985-08-14 | 1987-08-18 | Conoco, Inc. | Determining steam distribution |
US7640987B2 (en) | 2005-08-17 | 2010-01-05 | Halliburton Energy Services, Inc. | Communicating fluids with a heated-fluid generation system |
US7770643B2 (en) | 2006-10-10 | 2010-08-10 | Halliburton Energy Services, Inc. | Hydrocarbon recovery using fluids |
US7809538B2 (en) | 2006-01-13 | 2010-10-05 | Halliburton Energy Services, Inc. | Real time monitoring and control of thermal recovery operations for heavy oil reservoirs |
US7832482B2 (en) | 2006-10-10 | 2010-11-16 | Halliburton Energy Services, Inc. | Producing resources using steam injection |
US9163491B2 (en) | 2011-10-21 | 2015-10-20 | Nexen Energy Ulc | Steam assisted gravity drainage processes with the addition of oxygen |
US9803456B2 (en) | 2011-07-13 | 2017-10-31 | Nexen Energy Ulc | SAGDOX geometry for impaired bitumen reservoirs |
US10487636B2 (en) | 2017-07-27 | 2019-11-26 | Exxonmobil Upstream Research Company | Enhanced methods for recovering viscous hydrocarbons from a subterranean formation as a follow-up to thermal recovery processes |
US11002123B2 (en) | 2017-08-31 | 2021-05-11 | Exxonmobil Upstream Research Company | Thermal recovery methods for recovering viscous hydrocarbons from a subterranean formation |
US11142681B2 (en) | 2017-06-29 | 2021-10-12 | Exxonmobil Upstream Research Company | Chasing solvent for enhanced recovery processes |
US11261725B2 (en) | 2017-10-24 | 2022-03-01 | Exxonmobil Upstream Research Company | Systems and methods for estimating and controlling liquid level using periodic shut-ins |
CN114607328A (en) * | 2022-04-11 | 2022-06-10 | 西南石油大学 | Method for exploiting thick oil by huff and puff through low-temperature oxidation air injection assisted by solvent |
Citations (8)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US2994376A (en) * | 1957-12-27 | 1961-08-01 | Phillips Petroleum Co | In situ combustion process |
US3007521A (en) * | 1957-10-28 | 1961-11-07 | Phillips Petroleum Co | Recovery of oil by in situ combustion |
US3032102A (en) * | 1958-03-17 | 1962-05-01 | Phillips Petroleum Co | In situ combustion method |
US3113619A (en) * | 1959-03-30 | 1963-12-10 | Phillips Petroleum Co | Line drive counterflow in situ combustion process |
US3172467A (en) * | 1962-10-08 | 1965-03-09 | Phillips Petroleum Co | Method of reversing in situ combustion frontal movement |
US3253652A (en) * | 1963-06-24 | 1966-05-31 | Socony Mobil Oil Co Inc | Recovery method for petroleum oil |
US3288212A (en) * | 1964-05-21 | 1966-11-29 | Union Oil Co | Secondary oil recovery method |
US3472318A (en) * | 1967-06-29 | 1969-10-14 | Texaco Inc | Hydrocarbon production by secondary recovery |
-
1974
- 1974-09-23 US US508385A patent/US3905422A/en not_active Expired - Lifetime
-
1975
- 1975-06-19 CA CA229,677A patent/CA1027854A/en not_active Expired
- 1975-08-20 YU YU02124/75A patent/YU212475A/en unknown
- 1975-09-08 BR BR7505749*A patent/BR7505749A/en unknown
Patent Citations (8)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3007521A (en) * | 1957-10-28 | 1961-11-07 | Phillips Petroleum Co | Recovery of oil by in situ combustion |
US2994376A (en) * | 1957-12-27 | 1961-08-01 | Phillips Petroleum Co | In situ combustion process |
US3032102A (en) * | 1958-03-17 | 1962-05-01 | Phillips Petroleum Co | In situ combustion method |
US3113619A (en) * | 1959-03-30 | 1963-12-10 | Phillips Petroleum Co | Line drive counterflow in situ combustion process |
US3172467A (en) * | 1962-10-08 | 1965-03-09 | Phillips Petroleum Co | Method of reversing in situ combustion frontal movement |
US3253652A (en) * | 1963-06-24 | 1966-05-31 | Socony Mobil Oil Co Inc | Recovery method for petroleum oil |
US3288212A (en) * | 1964-05-21 | 1966-11-29 | Union Oil Co | Secondary oil recovery method |
US3472318A (en) * | 1967-06-29 | 1969-10-14 | Texaco Inc | Hydrocarbon production by secondary recovery |
Cited By (16)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4194562A (en) * | 1978-12-21 | 1980-03-25 | Texaco Inc. | Method for preconditioning a subterranean oil-bearing formation prior to in-situ combustion |
US4366863A (en) * | 1980-09-29 | 1983-01-04 | Texaco Inc. | Enhanced oil recovery operations |
US4474238A (en) * | 1982-11-30 | 1984-10-02 | Phillips Petroleum Company | Method and apparatus for treatment of subsurface formations |
US4641709A (en) * | 1985-05-17 | 1987-02-10 | Conoco Inc. | Controlling steam distribution |
US4687057A (en) * | 1985-08-14 | 1987-08-18 | Conoco, Inc. | Determining steam distribution |
US7640987B2 (en) | 2005-08-17 | 2010-01-05 | Halliburton Energy Services, Inc. | Communicating fluids with a heated-fluid generation system |
US7809538B2 (en) | 2006-01-13 | 2010-10-05 | Halliburton Energy Services, Inc. | Real time monitoring and control of thermal recovery operations for heavy oil reservoirs |
US7832482B2 (en) | 2006-10-10 | 2010-11-16 | Halliburton Energy Services, Inc. | Producing resources using steam injection |
US7770643B2 (en) | 2006-10-10 | 2010-08-10 | Halliburton Energy Services, Inc. | Hydrocarbon recovery using fluids |
US9803456B2 (en) | 2011-07-13 | 2017-10-31 | Nexen Energy Ulc | SAGDOX geometry for impaired bitumen reservoirs |
US9163491B2 (en) | 2011-10-21 | 2015-10-20 | Nexen Energy Ulc | Steam assisted gravity drainage processes with the addition of oxygen |
US11142681B2 (en) | 2017-06-29 | 2021-10-12 | Exxonmobil Upstream Research Company | Chasing solvent for enhanced recovery processes |
US10487636B2 (en) | 2017-07-27 | 2019-11-26 | Exxonmobil Upstream Research Company | Enhanced methods for recovering viscous hydrocarbons from a subterranean formation as a follow-up to thermal recovery processes |
US11002123B2 (en) | 2017-08-31 | 2021-05-11 | Exxonmobil Upstream Research Company | Thermal recovery methods for recovering viscous hydrocarbons from a subterranean formation |
US11261725B2 (en) | 2017-10-24 | 2022-03-01 | Exxonmobil Upstream Research Company | Systems and methods for estimating and controlling liquid level using periodic shut-ins |
CN114607328A (en) * | 2022-04-11 | 2022-06-10 | 西南石油大学 | Method for exploiting thick oil by huff and puff through low-temperature oxidation air injection assisted by solvent |
Also Published As
Publication number | Publication date |
---|---|
CA1027854A (en) | 1978-03-14 |
YU212475A (en) | 1982-02-28 |
BR7505749A (en) | 1976-08-03 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
US4127170A (en) | Viscous oil recovery method | |
US4324291A (en) | Viscous oil recovery method | |
US3905422A (en) | Method for recovering viscous petroleum | |
US4691771A (en) | Recovery of oil by in-situ combustion followed by in-situ hydrogenation | |
US4597441A (en) | Recovery of oil by in situ hydrogenation | |
US2897894A (en) | Recovery of oil from subterranean reservoirs | |
US3908762A (en) | Method for establishing communication path in viscous petroleum-containing formations including tar sand deposits for use in oil recovery operations | |
US4127172A (en) | Viscous oil recovery method | |
US4727937A (en) | Steamflood process employing horizontal and vertical wells | |
US4327805A (en) | Method for producing viscous hydrocarbons | |
US4856587A (en) | Recovery of oil from oil-bearing formation by continually flowing pressurized heated gas through channel alongside matrix | |
US3948323A (en) | Thermal injection process for recovery of heavy viscous petroleum | |
US3554285A (en) | Production and upgrading of heavy viscous oils | |
US2885002A (en) | Recovering oil after secondary recovery | |
US4487260A (en) | In situ production of hydrocarbons including shale oil | |
US3441083A (en) | Method of recovering hydrocarbon fluids from a subterranean formation | |
CA1299091C (en) | Solvent flooding with a horizontal injection well in gas flooded reservoirs | |
US3847219A (en) | Producing oil from tar sand | |
US4121661A (en) | Viscous oil recovery method | |
CA1053573A (en) | Method for recovering viscous petroleum from unconsolidated mineral formations | |
US4124071A (en) | High vertical and horizontal conformance viscous oil recovery method | |
US3113616A (en) | Method of uniform secondary recovery | |
US3512585A (en) | Method of recovering hydrocarbons by in situ vaporization of connate water | |
US4961467A (en) | Enhanced oil recovery for oil reservoir underlain by water | |
US4649997A (en) | Carbon dioxide injection with in situ combustion process for heavy oils |