US3104702A - Recovery of cellar oil - Google Patents

Recovery of cellar oil Download PDF

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Publication number
US3104702A
US3104702A US54902A US5490260A US3104702A US 3104702 A US3104702 A US 3104702A US 54902 A US54902 A US 54902A US 5490260 A US5490260 A US 5490260A US 3104702 A US3104702 A US 3104702A
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oil
water
well pipe
perforations
reservoir
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US54902A
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Merwin H Gaskell
Donald C Lindley
Jr Frederick M Perkins
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Jersey Production Research Co
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Jersey Production Research Co
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    • 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
    • E21B43/20—Displacing by water

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  • the method of the invention comprises the simultaneous injection of water and production of fluid from a single well in which the lower portion of the productive formation or interval of the well is completed for water injection and the upper portion thereof is completed for production.
  • the fluid production rate is maintained equal to the water injection rate to prevent the 'oil level from falling below the well or rising into the gas cap.
  • FIG. 1 is a cross-sectional view of the earths subsurface showing a well penetrating an inclined reservoir and illustrating the mechanics of operation when water is initially injected;
  • FIG. 2 is ⁇ a view similar to that shown in FIG. 1 illustrating the mechanics of operation during simultaneous oil production and water injection;
  • FIG. 3 is a graph showing plots of oil production rate and water-oil ratio vs. water injection rate.
  • the prototype reservoir and the fluids were selected to have the dimensions and physical properties shown 1n the following Table I.
  • the model properties alsogshown in Table I were chosen to satisfy the prototype scaling requirements shown in Table I.
  • the clear 'lucite model formed as a rectangular parallelepiped 36 inches long, 36 inches wide, and 0.95 inch thick, was supported at a dip of 30 degree to the horizontal by a wooden frame. With the model in this position, the well was drilled vertically through the geometric center of the sand. The model well bore was scaled to represent a 9-inch well bore and was perforated along the top and bottom third of its length; the middle third was not perforated.
  • the sand packed in the model was a round-grained quartz (Ottawa), 20 to 30' mesh sand.
  • the 'oil phase was a white mineral oil with a density of 0.812 gin/cc.
  • the aqueous phase was a solution of sodium nitrate, glycerol, xylene 'sulfonate spent-caustic product, and
  • polyethylene glycol 300 The sodium nitrate was added to give a density of 1.253 gm./cc., glycerol was added to give a viscosity of 4.24 cp., and xylene sulfonate spentcaustic product and polyethylene glycol 5300 were added to lower the interfiacial tension to 4.26 dyne/om.
  • the sand nearest the bottom of the model had a high water saturation and a low oil saturation. Above this was a small region of sand with a high oil saturation and a low water saturation. The very top portion of the sand was predominantly saturated with gas, with low saturations of oil and water.
  • the model was under vacuum, as it had to be maintained at subatmospheric pressure at all times to prevent its being deformed.
  • the model was prepared for the each succeeding experiment without changing its 30-degree angle of dip by first allowing all the mobile liquid to drain from ports located along the bottom. The desired quantity of oil then was injected into these same ports. Carbon dioxide was next injected through the ports and flushed through the oil in order to simulate a gas saturation resulting from solution gas drive, and the pressure was brought to approximately 7 inches Hg absolute. The oil then was allowed to drain to the bottom of the reservoir with the final oil level being in the vicinity of the well bore. At this point the oilaich zone contained both a connate water saturation and residual gas saturation, and the model was ready for the next experiment.
  • the process was carried out in the experimental runs by injecting water into the bottom third of the well while oil was produced from the top third.
  • the production rate was controlled with a throttling valve, and the water injection rate was adjusted as closely as possible to the same value with a constant rate pump.
  • injection and production rates had been established, they were continued until the water-oil ratio and the waterfront height stabilized.
  • the model was reprepared for each run as described above, and equilibrium production conditions were established at a dilferent injection rate.
  • FIGS. 1 and 2 a reservoir 10 penetrated by a well 11 provided with well pipe 12 extending to the earths surface and perforated as at 13.
  • a tubing 14 extends through well pipe 1'2, and the annulus there between is packed off by means of a packer 15 adjacent the lower end of the well.
  • a conduit 16 provided with a valve 17 is connected to a wellhead 18 and fluidly communicates with the annulus.
  • Another conduit 19 provided with a valve 20 is connected to wellhead 18 and fluidly communicates with tubing 14.
  • a pump 21 is connected to conduit [19, and in turn fluidly communicates with a source of water supply. As evidenced in FIG. 1, as water is injected into the bottom portion of the well through tubing 14, a bubble of water forms around the injection perforations.
  • the bubble of water expands upwardly until it reaches an equilibrium vertical position. At very low rates, the bubble does not reach the top portion of the well, which is the production interval, and consequently only oil is produced.
  • the injection rate is increased, the bubble of water reaches the production interval, and water begins to be produced. Additional increases in the injection rate increases the water oil ratio.
  • the oil production rate increases with increasing injection rate at first. However, it eventually reaches a maximum value and decreases thereafter. In FIG. 2, the oil has been displaced upwardly by the water, and as the water is continuously injected, the oil is produced through perforations 13 and the annulus.
  • a method for recovery of cellar oil from an inclined reservoir having no natural water drive and which is penetrated by a well pipe perforated with upper and lower perforations along a portion of its length at a location in said'reservoir adjacent the upper level of said a cellar oil, said well pipe containing a tubing and means for closing oli the annulus between said tubing and said well pipe between the upper and lower perforations in said well pipe comprising the steps of producing fluid from said reservoir through said upper well pipe perforations and said annulus while simultaneously injecting water into said reservoir through said tubing and lower well pipe perforations to maintain oil adjacent said upper perforations, the rates of water injection and fluid production being substantially equal.

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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)
  • Earth Drilling (AREA)

Description

2 Sheets-Sheet '1' M. H. GASKELL ETAL RECOVERY OF CELLAR OIL Sept. 24, 1963 Filed Sept. 9, 1960 INVENTORS.
MERWIN H. GASKELL,
DONALD C. LINDLEY, FREDERICK M. PERK|NS,JR.,
-' ATTORNEY.
Sept. 24, 1963 M. H. GASKELL 'ETAL RECOVERY OF CELLAR on.
Filed sept. s, 1960 2 Sheets-Sheet 2 PROTOTYPE WATER-OIL RATIO AND OIL PRODUCTION RATE VS. WATER INJECTION RATE 4 a LO: 7 2 a: ILI 4- I; 0.6 3 0.2 I00 zoo 300 400 500 600 WATER INJECTION RATE, BBLSJDAY INVENTORS.
MERWIN H. GASKELL, DONALD C. LINDLEY,
ATTORNEY.
United States Patent 1 3,104,702 RECOVERY OF CELLAR OIL Merwiu H. Gaskell, Donald C. Lindley, and Frederick M. Perkins, .lr., Houston, Tex., assignors, by mesne assignments, to Jersey Production Research Company,
Tulsa, Okla, a corporation of Delaware Filed Sept. 9, 1960, Ser. No. 54,902 2 Claims. (Cl. 166--9) This invention concerns recovery of oil located below the structurally lowest well in reservoirs in which a natural water drive is not present.
Small, steeply inclined reservoirs without natural water drives are often found associated with salt domes or other highly faulted structures. Frequently, only one well may be economically justified in these reservoirs and oil is produced from them by an expanding gas-cap drive or by a dissolved gas drive. Although a large fraction of the oil up-structure from the well may be recovered during primary depletion, because of gravity effects, only a small fraction of the down-dip oil can be produced. The down-dip oil is defined as cellar oil in contradistinction to attic oil which is the oil above the structurally highest well in reservoirs where a natural water drive is present.
The method of the invention, the primary object of which is to provide an improved method for recovery of cellar oil, comprises the simultaneous injection of water and production of fluid from a single well in which the lower portion of the productive formation or interval of the well is completed for water injection and the upper portion thereof is completed for production. The fluid production rate is maintained equal to the water injection rate to prevent the 'oil level from falling below the well or rising into the gas cap.
The above noted object and other objects of the invention will be apparent from a more detailed description of the invention when taken in conjunction with the drawings wherein:
FIG. 1 is a cross-sectional view of the earths subsurface showing a well penetrating an inclined reservoir and illustrating the mechanics of operation when water is initially injected;
FIG. 2 is \a view similar to that shown in FIG. 1 illustrating the mechanics of operation during simultaneous oil production and water injection; and
FIG. 3 is a graph showing plots of oil production rate and water-oil ratio vs. water injection rate.
A series of experiments were conducted with a sand packed lucite model scaled to represent a 30 acre, single well reservoir representative of typical conditions for cellar oil recovery operations to determine if practical water injection and oil production rates could be achieved in certain reservoirs.
The prototype reservoir and the fluids were selected to have the dimensions and physical properties shown 1n the following Table I.
Table 1 Property Prototype Model Length 1,140 feet 36 inches. Thickness 30 feet 0.95 inch. Length/thickne 38 38. Areal extent 29.8 acres 9 sq. ft. Dip angle 30 degrees 30 degrees. Porosity 30 percent 37.9 percent. Permeability 500 md 190 darcies Oil viscosity. 4.07 cp. Water viscosity P Oil-to-water viscosity ratio 0.960. Density difierence 0-4407 Interfacial ten inn 4.26 dyne/cm. COnnate water 25 percent 9.5 percent. Residual oil. 15 percent 15 percent. Pore volume 2,083,000 bbl 7650 cc. Injection rate l 720 g (bbl/day) g (cc./sec.). Timem. t/241 months t seconds.
Patented Sept. 24, 1963 The model properties alsogshown in Table I were chosen to satisfy the prototype scaling requirements shown in Table I. The clear 'lucite model, formed as a rectangular parallelepiped 36 inches long, 36 inches wide, and 0.95 inch thick, was supported at a dip of 30 degree to the horizontal by a wooden frame. With the model in this position, the well was drilled vertically through the geometric center of the sand. The model well bore was scaled to represent a 9-inch well bore and was perforated along the top and bottom third of its length; the middle third was not perforated. The sand packed in the model was a round-grained quartz (Ottawa), 20 to 30' mesh sand. The 'oil phase was a white mineral oil with a density of 0.812 gin/cc.
' The aqueous phase was a solution of sodium nitrate, glycerol, xylene 'sulfonate spent-caustic product, and
polyethylene glycol 300. The sodium nitrate was added to give a density of 1.253 gm./cc., glycerol was added to give a viscosity of 4.24 cp., and xylene sulfonate spentcaustic product and polyethylene glycol 5300 were added to lower the interfiacial tension to 4.26 dyne/om.
At the end of each run, the sand nearest the bottom of the model had a high water saturation and a low oil saturation. Above this was a small region of sand with a high oil saturation and a low water saturation. The very top portion of the sand was predominantly saturated with gas, with low saturations of oil and water. The model was under vacuum, as it had to be maintained at subatmospheric pressure at all times to prevent its being deformed.
The model was prepared for the each succeeding experiment without changing its 30-degree angle of dip by first allowing all the mobile liquid to drain from ports located along the bottom. The desired quantity of oil then was injected into these same ports. Carbon dioxide was next injected through the ports and flushed through the oil in order to simulate a gas saturation resulting from solution gas drive, and the pressure was brought to approximately 7 inches Hg absolute. The oil then was allowed to drain to the bottom of the reservoir with the final oil level being in the vicinity of the well bore. At this point the oilaich zone contained both a connate water saturation and residual gas saturation, and the model was ready for the next experiment.
The process was carried out in the experimental runs by injecting water into the bottom third of the well while oil was produced from the top third. The production rate was controlled with a throttling valve, and the water injection rate was adjusted as closely as possible to the same value with a constant rate pump. When equal injection and production rates had been established, they were continued until the water-oil ratio and the waterfront height stabilized. The model was reprepared for each run as described above, and equilibrium production conditions were established at a dilferent injection rate.
In FIGS. 1 and 2 is shown a reservoir 10 penetrated by a well 11 provided with well pipe 12 extending to the earths surface and perforated as at 13. A tubing 14 extends through well pipe 1'2, and the annulus there between is packed off by means of a packer 15 adjacent the lower end of the well. A conduit 16 provided with a valve 17 is connected to a wellhead 18 and fluidly communicates with the annulus. Another conduit 19 provided with a valve 20 is connected to wellhead 18 and fluidly communicates with tubing 14. A pump 21 is connected to conduit [19, and in turn fluidly communicates with a source of water supply. As evidenced in FIG. 1, as water is injected into the bottom portion of the well through tubing 14, a bubble of water forms around the injection perforations. As the injection of water continues, the bubble of water expands upwardly until it reaches an equilibrium vertical position. At very low rates, the bubble does not reach the top portion of the well, which is the production interval, and consequently only oil is produced. As the injection rate is increased, the bubble of water reaches the production interval, and water begins to be produced. Additional increases in the injection rate increases the water oil ratio. The oil production rate increases with increasing injection rate at first. However, it eventually reaches a maximum value and decreases thereafter. In FIG. 2, the oil has been displaced upwardly by the water, and as the water is continuously injected, the oil is produced through perforations 13 and the annulus.
The data from the experiments performed are presented in FIG. 3, wherein both the water oil ratio and the oil production rate are shown as a function of injection rate. For the prototype investigated, the first water was produced at a water injection rate of about 125 bbL/day, and the maximum oil production rate, 275 bbL/day, occurred at an injection rate of 550 bbl./day.
These results show that practical injection and production rates can be achieved in certain reservoirs by the simultaneous injection production technique. Also shown is that there is a critical water injection rate at which water is first produced and an injection rate which results in a maxim-um oil production rate.
Having fully described the objects, method and operation of our invention, we claim:
-1. A method for recovery of cellar oil from an inclined reservoir having no natural water drive and which is penetrated by a well pipe perforated with upper and lower perforations along a portion of its length at a location in said'reservoir adjacent the upper level of said a cellar oil, said well pipe containing a tubing and means for closing oli the annulus between said tubing and said well pipe between the upper and lower perforations in said well pipe comprising the steps of producing fluid from said reservoir through said upper well pipe perforations and said annulus while simultaneously injecting water into said reservoir through said tubing and lower well pipe perforations to maintain oil adjacent said upper perforations, the rates of water injection and fluid production being substantially equal.
2. -A method as described in claim 1 in which said fluid consists of both oil and water and said water injection and fluid production rates are selected so as to achieve a maximum oil production rate.
References Cited in the file of this patent OTHER REFERENCES McGhee: Left-Over Oil Rescued on Gulf Coast,
The Oil and Gas Journal, vol. 57, No. 17, pages 62 to 64.

Claims (1)

1. A METHOD FOR RECOVERY OF CELLAR OIL FROM AN INCLINED RESERVOIR HAVING NO NATURAL WATER DRIVE AND WHICH IS PENETRATED BY A WELL PIPE PERFORATED WITH UPPER AND LOWER PERFORATIONS ALONG A PORTION OF ITS LENGTH AT A LOCATION IN SAID RESERVOIR ADJACENT THE UPPER LEVEL OF SAID CELLAR OIL, SAID WELL PIPE CONTAINING A TUBING AND MEANS FOR CLOSING OFF THE ANNULUS BETWEEN SAID TUBING AND SAID WELL PIPE BETWEEN THE UPPER AND LOWER PERFORATIONS IN SAID WELL PIPE COMPRISING THE STEPS OF PRODUCING FLUID FROM SAID RESERVOIR THROUGH SAID UPPER WELL PIPE PERFORATIONS AND SAID ANNULUS WHILE SIMULTANEOUSLY INJECTING WATER INTO SAID RESERVOIR THROUGH SAID TUBING AND LOWER WELL PIPE PERFORATIONS TO MAINTAIN OIL ADJACENT SAID UPPER PERFORATIONS, THE RATES OF WATER INJECTION AND FLUID PRODUCTION BEING SUBSTANTIALLY EQUAL.
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Cited By (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3219114A (en) * 1965-01-13 1965-11-23 Sun Oil Co Secondary recovery of oil from subterranean oil-bearing strata
US3363684A (en) * 1964-06-26 1968-01-16 Buck J. Miller Method of recovery by increased density fluid
US4540052A (en) * 1982-03-30 1985-09-10 Phillips Petroleum Company Generation of microorganism control composition and use thereof

Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US1885807A (en) * 1924-08-28 1932-11-01 Henry L Doherty Production of oil from oil sands in the earth
US1899497A (en) * 1925-05-22 1933-02-28 Henry L Doherty Method of developing oil fields
US2258614A (en) * 1938-02-28 1941-10-14 Sulifvan Machinery Company Method of treating and producing oil-water wells
US2281801A (en) * 1938-12-20 1942-05-05 Joseph H Reynolds Method of and means for pumping wells
US2842204A (en) * 1955-08-29 1958-07-08 Core Lab Inc Method of increasing oil recovery

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US1885807A (en) * 1924-08-28 1932-11-01 Henry L Doherty Production of oil from oil sands in the earth
US1899497A (en) * 1925-05-22 1933-02-28 Henry L Doherty Method of developing oil fields
US2258614A (en) * 1938-02-28 1941-10-14 Sulifvan Machinery Company Method of treating and producing oil-water wells
US2281801A (en) * 1938-12-20 1942-05-05 Joseph H Reynolds Method of and means for pumping wells
US2842204A (en) * 1955-08-29 1958-07-08 Core Lab Inc Method of increasing oil recovery

Cited By (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3363684A (en) * 1964-06-26 1968-01-16 Buck J. Miller Method of recovery by increased density fluid
US3219114A (en) * 1965-01-13 1965-11-23 Sun Oil Co Secondary recovery of oil from subterranean oil-bearing strata
US4540052A (en) * 1982-03-30 1985-09-10 Phillips Petroleum Company Generation of microorganism control composition and use thereof

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