Search Images Maps Play YouTube News Gmail Drive More »
Sign in
Screen reader users: click this link for accessible mode. Accessible mode has the same essential features but works better with your reader.


  1. Advanced Patent Search
Publication numberUS3780805 A
Publication typeGrant
Publication dateDec 25, 1973
Filing dateSep 7, 1971
Priority dateSep 7, 1971
Publication numberUS 3780805 A, US 3780805A, US-A-3780805, US3780805 A, US3780805A
InventorsGreen W
Original AssigneeGreen W
Export CitationBiBTeX, EndNote, RefMan
External Links: USPTO, USPTO Assignment, Espacenet
Viscous oil recovery system
US 3780805 A
A system to provide means for recovering crude oils known to exist in production formations which cannot be produced economically by systems now in operation and known to the industry. This type of oil will not flow into the wells drilled to produce it because it is too viscous, and has no mobility.
Previous page
Next page
Description  (OCR text may contain errors)

FU /91E United States Patent 1191 Green Dec. 25, 1973 [54] VISCOUS' OIL RECOVERY SYSTEM 2,875,836 3/1959 Stiff, Jr. et a1. 166/266 16 [76] Inventor: William G. Green, 10614 X Hempslead Houston, 2,885,002 5/1959 Jenks 166/245 77002 3,120,870 2/1964 Santourian 166/245 Filed: Sept. 9 3,228,467 1/1966 Schlmger et a1. 166/266 PP 178,237 Primary ExaminerStephen J. Novosad Attorney-Ranseler O. Wyatt [52] US. Cl 166/266, 166/271, 166/273 [51] Int. Cl E2lb 43/22, E2lb 43/27 [57] ABSTRACT [58] Field of Search 166/268, 266, 267, A f d 166/265 271, 273, 274 245 system to pr ov1 e mea ns or recevenngeru e 01 s known to ex1st 1n productlon formations which cannot [561 CM Zififiiiiifififfii1111131321.?58;" J? $313111 UNITED STATES PATENTS not flow into the wells drilled to produce it because it 2,309,075 1/1943 HI" 166/266 is too viscous and has no mobility 2,423,156 7/1947 Reid 166/266 X 8 Claims, 5 Drawing Figures 2,617,484 11/1952 Swearingen ..166/266X VISCOUS OIL RECOVERY SYSTEM Two known means exist to increase the mobility and reduce the viscosity of this oil. They are heat and solvents. The heat requirement is so great as to be of questionable economy. Solvent, although the most effective means known, is similarly too expensive in the quantities required.

This invention entails a group of practical component systems, by which the heavy oil in the formation is thinned by solvents, extracted from the extracted crude oil, and recovered by an on the spot refinery known as the Fuel and Solvent Generator, and the rate and efficiency of production is increased by the use of a continuous acidizing system, which, on the spot, converts saline water into Cl, and HCL; and the effectiveness of acidizing is increased by removing the calcium and magnesium carbonates (limestone) from the acid saltwater, thus increasing the solubility of those constituents in the acid water and lowering the cost of the fuel required for electric generation, air compression and other auxilliary services and the cost of lifting, or pumping, for bringing the crude oil to the surface and, where necessary, to institute the first mobility by electric heating of the formation by a few degrees Fahrenheit, wherein the electricity is generated from fuel refined from the produced crude oil, utilizing the reject heat from the engine driving the generator and replacing the crude oil depleted by the refining process by injecting CO and H under the proper conditions of catalyst, temperature and pressure, to form a hydrocarbon of the ethanal type, and producing hydrogen from electrolysis of water, using the same economical electricity, and separating from the exhaust gases of the engine a supply of CO, to provide a free source of this fuel, and means to inject the remaining CO of the exhaust into the water-acid solution being injected for the purpose of diluting the oil and increasing its mobility to accomplish the lowest lifting or producing cost yet achieved.

BACKGROUND OF THE INVENTION The U. S. Bureau of Mines has placed the total number of barrels of crude petroleum discovered since the first well was drilled by Drake, in 1859, at approximately 315 b i llion b a r r els. Of this total, some 250 billion barrels are classified as unrecoverable reserves. These reserves of unrecoverable oil are about three times the total oil produced to date. The oil is classified as unrecoverable because it is so thick, or viscous, that it will not flow into the wells drilled, and will not be driven through the formations by cold water, or air. Steam has been widely used, but is quite expensive. Many cases are recorded where the cost of steam exceeded the value of the recovered petroleum. There are also a number of cases where solvents have been used, with great success, but not economically. In one case, the cost of the solvent and operation amounted to $6.00 per produced barrel, and the posted price for the oil was $3.00 per barrel.

For normal producible oil, the efficiency of the recovery is 25-30 percent of the in situ petroleum. One system has succeeded in producing all of the oil in a core sample of the formation, that is to say, one hundred percent of the hydrocarbons was recovered by washing out the porous formation with a solvent. The solvent used was a slug of methyl alcohol 4 percent and Pe ent fiwmwxl lw o A thqqsh yme! 9 fective system found,'the high cost of the solvent precludes its commercial application.

A considerable amount of work has been done in electrical heating of the formations, but this has been quite costly, since the electricity must be produced with purchased fuel, in these viscous petroleum areas, or be purchased outright from power companies.

Well services, usually purchased from well service companies, have developed to the point that the services frequently aggregate more than the cost of the bore-hole and equipment installed therein.

The major oil companies find their profits continually reduced, and run up against the inability to get a higher price for the crude oil, particularly in view of the lower cost petroleum available from Venezuela, Iran, Bahrein and other places having a surplus of crude petroleum. But they have improved their refining technics by utilizing all possible byproducts, and by actually increasing the volume of petroleum by means of hydrogenation, thus increasing their cash flow from total sales. The non-refiner, or independent oil producer, however, who has no sales outlets, must sell to the refiners at posted prices. Sometimes it is a moot question as to whether such producer makes profits or loses money.

The objective of industry has been for many years to analyze the requirements for producing oil, and to try to devise economical means for reducing the cost, and improve the recovery and increase the rate.

Many people do not appreciate the fact that if a given operation produces 100 parts in a day, for a total cost of $100.00, that if 200 parts were to be produced in the same day, for the same cost of facilities and manpower, the cost per unit would have dropped from $1.00 each to 50 each. Utilizing this principle, if the oil can be produced twice as fast, with the same equipment, etc., then it will be produced at approximately one half the original amount. in one oil field near San Antonio, Texas, in the 30 years since it was first brought in, a total of 175,000 bbls of oil were produced from a total calculated 16,000,000 bbls in situ. At this rate, no one has made any money, and the properties have changed hands a' number of times. If they could have been produced at twice the rate, everyone would have made a little profit.

Viscosity is defined as the internal friction of a fluid in motion. It is measured by timing the fall of a steel ball down a tube of given length, or of observing the time for a given amount of fluid to flow through an orifice, or a funnel. A poise is the unir=to dyne sec/cm. Centipoise is the term usually used for oil. Examples:

Many of the viscous petroleums have 600 centipoises, but at F. some have a certain gel strength, which increases the apparent viscosity. Tar has this gel strength or rigidity. One APl 15 crude oil had the following viscosities, vs temperature:

80 F viscosity 2 75 Centipoises 150 Centipoises 12 Centipolses Thus it may be seen that warming the oil 5 F will make a substantial change in the viscosity, and consequently in the mobility. From the definition of the poise, increasing the force, or pressure, will increase the flow rate, too. Thus, if pressure is cheaper to arrive at than temperature, this would be the way to go.

Looking at the examples above, if a quantity of alcohol could be mixed with either castor oil or glycerin, a small amount of the alcohol would produce a substantial reduction of viscosity of the heavier substance. Thus, if the solvent can be obtained economically, it may readily replace heat, and, if the solvent may be recovered and used again, or be recycled, the economies are further advanced.

SUMMARY OF THE INVENTION The method of producing viscous oil employing a system of operation including: extracting engine operating fuel from the production fluid by means of a fuel and solvent generator, similar to that described in U.S. Pat. No. 3,447,51 l to Franklin Beard and W.G. Green, and the improvements thereon, to be the subject matter of other applications for patent. This device is a small refinery, in which crude oil is passed through the heat exchanger and is heated by all the rejected heat from the engine exhaust and cooling systems, to a temperature that will provide l0l5 percent of the oil as a fuel gas to operate the engine, and as a condensate with solvent properties. The design of the generator is such that the condensate is cooled to a stable, condensed, state.

Another step in the system is hydrogenation. Hydrogen is produced from water by electrolysis, and is pumped through the heat exchanger of the fuel and solvent generator, along with CO which is separated from the engine exhaust gases (about 6 percent of such gas may be expected to be CO). The combination of CO and H may be expected to result in a hydrocarbon of the general type: CH CHO (Ethanal) or CH COOH, if extra 0 is supplied. This forms readily at 200A and 200-300 F".

Another stepis the gas lift system. The pressures put upon the oil in the formation by the injection of solvent and CO and air, cause the producing wells to flow their production naturally, when the proper arrangements are made, well pressure is maintained, and no gases are allowed to escape through open holes. Therefore, the lifting costs are borne by the operation of the rest of the systems. However, for the intended production of an oil field now being studied, the cost of preparation of the wells for free flowing would be about $2,500.00 per well, and the anticipated production would make an amortization of $0.087l/bbl.

Another step is the gas recycling system. All of the air and CO put into the oil formation will be recovered. Since it now carries a modicum of dissolved hydrocarbon gases, it becomes a better solvent each time it is recycled, until it is the equal of, or richer than, natural gas. Thus in the interest of pollution control, as well as economics, this gas will be separated from the oil and water produced, and recycled back to the air compres- 100 F viscosity 120 F viscosity sor, for re-injection. As the oil is depleted from the formation, additional air will have to be injected to maintain the pressure. This is shown in the schematic of the plant.

Another step is the continuous acidizing system. The acidizing of lime wells, limed boilers, and limed air conditioning systems, has generally been done by non experts. They have not realized that acid can not dissolve limestone (CaCO to any extent, except when liberally diluted in water. The solubility of CaCO in water is about 7,000 ppm. When the acid solution has dissolved this amount of calcium carbonate, it stops dissolving. When the acid stops working, analysis of the CaCO content comes up to about 7,000 ppm. The addition of more acid does very little, since the dilution of the commercial acid is comparatively small, but the addition of fresh water immediately restarts the dissolving process. I have shown that a small amount of acid, with copious dilution, will dissolve more limestone than a larger amount of acid, with insufficient dilution.

In limestone oil formations the oil is generally trapped in crevases or fractures in the rock. But, under certain conditions, the oil is trapped in vu gs, or cavities, in the rock. Sometimes a significant percentage of the oil is trapped in vugs or cavities, which are not connected, or conductive into the larger cavities. When the production of a limestone oil field falls to an uneconomical level, a common practice is to acidize the formation, by injecting several thousand gallons of dilute acid (usually I-lCl) into the formation, to dissolve some of the limestone and release the trapped oil. This greatly increases the flow of oil, but inevitably a decline sets in, and eventually the field is again uneconomical. Many oil fields, for instance, at Luling, Texas, there is a tremendous oil field, in limestone, and the wells of this field have been acidized dozens of times. There are many commercial operating companies which do nothing except provide this acidizing service. It is expensive and rewarding to the service people. The acid is provided in this system by applicants acid generating apparatus, which produces chlorine by electrolysis of saltwater as described in U.S. Pat. Nos. 3,241,512 and 3,379,633 issued to this applicant. There are many systerns for converting the chlorine to acid, inasmuch as one of the products of electrolysis is hydrogen which is easily collected.

One form of this chlorine generator has been evaluated by the National Sanitation Foundation, Ann Arbor, Michigan, and shown to produce 2 pounds of Cl; per day, from a comparatively small generator cell. l have shown that the output of C1 is linear with the number of square inches of electrode surface, if the critical value of current is maintained. Thus, no special problem exists to make the chlorine generator any desirable dimensions, thus producing the amount of chlorine and/or acid desired.

Since salt water is produced with oil, the brine for the chlorine generator is free; and since electricity is produced at an extremely low price, the acid so produced is less costly than any purchased.

Another step is the water treatment. All water treating authorities agree that the reactive power of water increases with its purity. Absolutely pure H O will dissolve a little of almost everything even glass, and thus it is nearly impossible to make and store completely pure H O. Since the brine from the oil wells is saturated with CaCO it is necessary to precipitate the limestone by treating the water. Since the other constituents are relatively unimportant, the carbonates and silicates are precipitated by treating the salt water to above the pH of saturation (pHs). For the purposes this pl-I may be adjusted to a value of l 1, upon which the hardness will drop to about 3 ppm. Decanting the softened water off the precipitate, or removing the precipitate which has settled, permits its use, then, as a dilutent for the acid. Additional quantities may be used for the electrolysis of chlorine and the making of hydrochloric acid. The complete water treatment, using this principle, is the subject of a another application for patent, as is the production of HCl from brine.

The recovered or produced brine will ultimately become saturated with carbonates, due to the action of the acid on the formations, and it will have to be recycled, or resoftened before it may be reused. Under the present laws, all salt water produced must be reinjected 7 into the producing formation, or into a salt water aquifer. Either of these operations is quite expensive, and the use of the produced brine for the above purposes is most economical, since the reinjection would have to be done, in any event.

BRIEF DESCRIPTION OF THE DRAWINGS FIG. l is a diagramatio view of the system.

FIG. 2 is a diagramatic view of the super heater employed.

FIG. 2A is a diagrammatic view of of the water purifier.

FIG. 3 is a diagramatic view of the electrical circuits employed, and

FIG. 4 is a diagramatic view of another form of the invention.

DESCRIPTION OF THE PREFERRED EMBODIMENT The system herein defined is designed to be established in an oil production field, having injection wells and having production wells in a suitable pattern, preferably the injection wells being axial, with the production wells extending around the injection area.

Crude petroleum from wells flows through line 1 to the separator 2 where the gas is separated and flows through line 40 to recycle system 3, where gas is scrubbed and passes through line to the compressor 9, and is reinjected into wells 13 through the line 12. Oil flows from the separator 2 through line 18 into the fuel and solvent generator 6, where reject heat from the engine-generator 7 flows through line 21 into the fuel generator 6 to heat the oil. Waste heat from the coolant system of the engine 7 flows through line 41 into the fuel generator 6 and is returned to the engine through the line 42. The heated oil in the fuel generator 6 vaporizes and some of the gas flows through the line 22 to the carburetor of the engine 7, to supply fuel thereto. To provide pressure for the gas to the engine, particularly for supercharged engines, which require a minimum of psi, a bleed-off from the engine compressor 9 flows through line 45 to pressure regulator 44, thence through a check valve 46 into line 18, and into the fuel generator 6.

Back pressure on the separator 2 is prevented by the check valve 43 in line 18. The exhaust of engine 7 has been shown to pass through line 21 into the fuel generator 6, and thence through line 19 into the CO-CO separator 15. CO has the atomic weight of 28, as opposed to the atomic weight of 44 for CO They are thus separated by gravity in a very large, baffled, tank. Six percent, plus or minus, of the exhaust is CO. This will settle to the top of the CO separator 15. The excess exhaust then discharges through line 11 to the air line 24 into the engine compressor where it is compressed and injected into the wells 13 through line 12.

The residual oil, which is sometimes asphalt, flows from the fuel generator 6 through line 20, into stock tanks or to the asphalt refinery (not shown). The fuel generator 6 is operated at the temperature necessary for production of all the 550 F end products, which will be all the solvent materials from the treated oil. This solvent flows from the fuel generator 6 through line 43 to the pump 54 where it is pressurized for injection into wells 13 through line 37.

The fuel consumed by the engines 7 and 9 is replaced, in whole or in part, by the process of hydrogenation. In this case, hydrogen is obtained by electrolysis of fresh water from water well 28, and line 29, into the water purifier 30. This water contains calcium and magnesium carbonates, which will form scale on the electrodes of the electrolysis cell unless removed. Therefore, it is passed to the purifier 30, through float valve 30 where its pH is increased to 11, which causes precipitation of the carbonates, which settle to the bottom of the tank 30 and are removed through line 33, FIG. 2, by operation of the solenoid valve 38, and is wasted through line 39. This material, however, is not a pollutant. The NaOH used to increase the pH is obtained from the chlorine generator through line 35, into line 32, to tank 30. Some of the same softened water is passed through line 31, into the hydrogen generator. Some also is proportioned into the C1 generator 5 through line 34. Hydrogen from the hydrogen generator 8 passes through the line 27 into the motor-pump 25 where it is mixed with CO from separation tank 15, and expelled through line 26, into line 21, for raising its temperature to 500600 F. The outlet into the fuel generator 6, shown on FIG. 2, has an orifice on the end inside the fuel generator 6 to increase the pressure thereon, while subjected to the heat in line 21, which conditions are necessary to convert the H and CO into a hydrocarbon of the CH COH family. The amount of hydrogen and CO will be proportioned to approximately replace the fuel removed for the engine.

The chlorine generator 6 disassociates the C1 and Na ions in a water solution, by electrolysis. If a membrane is placed between the two electrodes (not shown), the output of chlorine is very much greater than without separation, since recombination starts at a fairly low concentration. With a membrane separator, the products C1 and H may be drawn off the positive electrode side of the cell, and NaOH and 0 from the negative electrode side. Passage of the H and C1 through a seeded bubble or glass bead tower will cause a partial combination and formation of HCI. The gases may be drawn through the bubble tower by a vacuum as from flow of water through a venturi. The HCl may be drawn off the lower part of the tower.

Water flows from line 3l 34 into the chlorine generator, and salt is added. If saltwater is available, the saltwater must be purified as in previous softening of hard well water hereinbefore defined to prevent scaling of the electrodes, or water may be added from the separator 2, through line 50 into the positive side of the generator cell. By osmosis the negative side is kept full. Electricity (direct current) of about volts, and 0.5 amperes per in of plate or electrode surface, is passed through the brine solution in the cell. Hydrochloric acid is passed through line 14 to the injection pump, after being diluted with water, or saltwater, as through lines 31, 34-47 to line 14 to pump 54, and thence to the wells through the lines 37-12.

Recycled gases from 3, through line 10 to the compressor 9, augmented by the residual CO from the exhaust line 24 from the CO separator 15, and into line 11 to the compressor 9, are injected into the wells 13 through the line 12. If there is an insufficiency of these gases, enough air to satisfy the compressor is inducted through a suitable air inlet. Thus pressure is maintained, either with recycled gas, or with solvent and hydrocarbon synthetically produced, or with air, or with a combination thereof.

Thus, diluted hydrochloric acid, solvent, and rich, recycled gases, are simultaneously injected into the injection well of a pattern of wells, and this pressure, so created, drives the petroleum toward production wells. During the drive, some of the heavy oil is diluted and made to speed through the formation to be produced; some of the limestone is dissolved by the acid and water, and the oil trapped in the sealed vugs is released for production and the gases enriched by a trip through the oil formation, are recycled back into the formation to provide a drive pressure and to mix with and dilute further, the heavy oil with which it comingles, to further thin it out, reduce its viscosity, and speed it toward the production wells. The produced oil is stripped of the solvent injected into the wells, and in addition, whatever additional solvent is in the heavy oil, is also stripped off by the fuel generator, and the hydrogen generator and the COCO separator remove some of the CO and add it to H to form, under the required circumstances, a modicum of newly formed hydrocarbon, which is added to the solvent stripped from the produced fluid, and reinjected into the wells. This all adds up to more and faster production, and an ever increasing amount of solvent, until finally the whole formation will be swept clean with the solvent, and then the solvent will be produced by air pressure and, if necessary, by water flood.

A modified form of the invention is shown in FIG. 4 wherein a vacuum pump 59 is mounted in the gas line 66 leading from the top of the fuel generator 65, between said fuel generator and the surge tank 57. The surge tank 57 is mounted between the vacuum pump 59 and the carburetor line 67. Two check valves are provided, one, 58, at the outlet of the vacuum pump 57, on the carburetor side, and one, 61, in the carburetor line 67.

A float valve 60 is inserted before the gas take off line 66, at the top of the fuel generator, to prevent liquid from flowing into the surge chamber 57 and carburetor. Since the fluid level in the fuel generator is designed to be several feet below the top, and the outlet of the fuel is above the fluid level, the vacuum would have to exceed 5 pounds for oil to reach up to the outlet pipe. As the fluid level reaches this predetermined point, the float 60 will close the valve, preventing the fluid level from moving above that point.

The objective of the vacuum on the oil charge in the fuel generator is to permit the vaporizing of the fuel at a lower temperature, in order to conserve the heat rejected from the engine, and used to heat the charge.

Since the heat rejected is a fixed amount, at maximum load, and this heat must heat the charge sent through the fuel generator to the cracking temperature, which would be say 700 F at atmospheric, if a vacuum of 5 pounds is maintained on the fuel generator, the cracking point will then be reduced to perhaps 600 F. This will obviously reduce the heat required by F, times the number of pounds of charge put through the fuel generator per hour, times the latent heat of the oil.

The vacuum pump provides pressure to the surge tank, which, in turn, provides fuel for the carburetor and delivers same to the carburetor under pressure, a necessity where supercharged engines are employed.

In this form the stock tank 64 provides the petroleum to be heated, which passes through line 62 into the fuel generator 65, and a back pressure valve 63, set usualy for about four pounds, will provide relief from over pressure in the tank 65.

What I claim is:

1. In a viscous oil recovery method comprising the steps of forming a pattern for injection wells and pro duction wells, constructing a plant consisting of a fuel generator, a field of stock tanks, and an engine and compressor and a separator and recycling tank, and directing the production flow from the production wells through a separator and collecting gas in the recycling tank that has been separated from the said production, directing the flow of production from the separator to the fuel generator, extracting fuel and solvents from the production in said fuel generator and distributing the fuel from the fuel generator to the engines and distributing the solvents to the injection wells and the residue to the stock tanks for storage and directing exhaust from the fuel generator into a CO separator and recycling the CO separated therefrom into the fuel generator.

2. The method defined in claim 1 wherein water is taken from a well and treated, and the treated water passed through a hydrogen generator and a Cl HClO generator to produce hydrochloric acid, which is injected into the injection wells with the solvents.

3. The method defined in claim 1 wherein saltwater separated from the production fluid is directed into a Cl HClO generator and then into a water treating means, and water from the water treating means is directed into a hydrogen generator, and hydrogen from said hydrogen generator is directed into the solvents which are injected into the injection wells.

4. The method defined in claim 1 wherein the reject heat from the engines exhaust and cooling system is employed to operate the fuel generator.

5. The method described in claim 1 wherein the gaseous fuel for the engine is removed from the fuel generator by a vacuum pump, which, on its exhaust side, compresses the fuel into a surge tank, under sufficient pressure to operate the pressure regulator attached to the engine carburetor to maintain the correct operating pressure for the carburetor.

6. The method described in claim 5 in which the vacuum on the fuel generator charge is maintained at level to cause a substantial reduction of the heat required for the distillation.

7. In a method as described in claim 1 having a modification in which a fluid actuated float valve at the gaseous fuel outlet of the fuel generator closes the outlet port when oil fills the generator chamber to a dangerous level, thus preventing the feeding of solid liquid petroleum therein, and further increase the amount crude oil into the carburetor of the engine. of solvent being injected, thus increasing the flow 8. A method for recovering viscous petroleum comrate of the oil, and

prising the steps of: g. generating chlorine and HCL or hydrochlorous a. Distilling solvent from the produced oil from a proacid, by electrolysis of the salt brine always present duction formation produced by lifting means having engines to actuate same to bring the production to the surface, using the waste heat from said engines for distilling the light ends producing a solin some amount from oil wells along with the petroleum, and injecting the HCl or hydrochlorous acid into the reservoir to dissolve limestone formations, thereby improving the oil conduit therethrough,

vent, and and increasing the total flow by dissolving and b. injecting the said solvent into the production foropening passageways between sealed vugs containmation for the dilution of the viscous oil, causing ing sealed oil, and recovering the water and acid the less viscous oil to flow more rapidly into proresidue along with the oilproduction, and recycling duction wells and to the surface, and such part as is still reactive, for additional effic. injecting air, or other gases, simultaneously into ciency, and

the production formation for maintaining the mateh. improving the production ability of each well in rial balance therein, wherein additional drive presthe field by the combination of injecting solvent sure is generated with further increase in quantity and air into the borehole of each production well and flow rate of the viscous petroleum, and for a period of a few days under sufficient pressure d. recovering the fluids so injected into the formation and for long enough to have filled several hundred as they are produced, recycling the light ends as adcubic feet of the formation adjacent to the boreditional solvent is produced and injected, and hole of the production well with air, utilizing the air e. replacing the losses in material balance of the forto drive the solvent and oil deeper into the resermation thereby improving the gas-oil ratio, thus revoir and under the requisite pressure its solubility placing the solvent and gas temporarily invested in for water vapor becomes quite large, thus the water the dilution process by the injection, under condiin the pore spaces of the sandstone, is evaporated tions proper for hydrogenation, of CO and CO into the air, and when this has been done, the air gases from the engine exhaust with hydrogen prois permitted to escape from the formation into the duced by the electrolysis of water, thus producing borehole of the production well, releasing said air methane gas and methanol liquid, both of which while maintaining sufficient pressure to retain most are solvents, the methane increasing the volume of the water in solution with the air increasing the and pressure of the oil, and the methanol reducing effective conduit for the viscous oil by the ratio of the viscosity of the oil, and increasing its APl gravthe water filled porous zone, to the total pore ity number, and space, which may be 100 percent increase or more, recovering and recycling some portion of the gases effectively increasing the flow rate.

produced along with the oil, to save the dissolved

Patent Citations
Cited PatentFiling datePublication dateApplicantTitle
US2309075 *Mar 9, 1939Jan 19, 1943Continental Oil CoMethod of operating high pressure oil and gas wells
US2423156 *Mar 6, 1939Jul 1, 1947Laurence S ReidMethod of recovering desirable petroleum hydrocarbon fractions at substantially wellhead pressure
US2617484 *Nov 14, 1949Nov 11, 1952Swearingen Judson STreatment of gaseous mixtures
US2875836 *Apr 28, 1954Mar 3, 1959Atlantic Refining CoMethod of water injection into an earth bore
US2880801 *Oct 3, 1956Apr 7, 1959Jersey Prod Res CoMethod of increasing recovery of oil
US2884132 *Sep 9, 1955Apr 28, 1959Phillips Petroleum CoAutomatic filter backwash system
US2885002 *Dec 2, 1954May 5, 1959Jersey Prod Res CoRecovering oil after secondary recovery
US3120870 *Aug 4, 1961Feb 11, 1964Phillips Petroleum CoFluid drive recovery of oil
US3228467 *Apr 30, 1963Jan 11, 1966Texaco IncProcess for recovering hydrocarbons from an underground formation
Referenced by
Citing PatentFiling datePublication dateApplicantTitle
US3913672 *Oct 15, 1973Oct 21, 1975Texaco IncMethod for establishing communication path in viscous petroleum-containing formations including tar sands for oil recovery operations
US4284139 *Feb 28, 1980Aug 18, 1981Conoco, Inc.Process for stimulating and upgrading the oil production from a heavy oil reservoir
US4344486 *Feb 27, 1981Aug 17, 1982Standard Oil Company (Indiana)Method for enhanced oil recovery
US5109928 *Aug 17, 1990May 5, 1992Mccants Malcolm TMethod for production of hydrocarbon diluent from heavy crude oil
US5310478 *Apr 21, 1992May 10, 1994Mccants Malcolm TMethod for production of hydrocarbon diluent from heavy crude oil
US5335728 *Jul 31, 1992Aug 9, 1994Strahan Ronald LMethod and apparatus for disposing of water at gas wells
US7389753 *Sep 14, 2007Jun 24, 2008Dennis LeeSystem and process for improving engine performance
US8028754 *Jun 1, 2010Oct 4, 2011Nitro-Lift Hydrocarbon Recovery Sytems, LLCSystem and method for producing a well using a gas
US20100170674 *Jan 7, 2010Jul 8, 2010Savannah River Nuclear Solutions, LlcInjection well storage of carbon dioxide
WO1983001273A1 *Oct 5, 1982Apr 14, 1983Gerard ChaudotExtraction from oil fields with reinjection of separated materials
WO2009035485A1 *Jun 27, 2008Mar 19, 2009Dennis LeeSystem and process for improving engine performance
U.S. Classification166/266, 166/302, 166/402, 166/271, 166/267
International ClassificationE21B43/40, C09K8/72, E21B43/16, C09K8/60, E21B43/34
Cooperative ClassificationE21B43/16, E21B43/40, C09K8/72, E21B43/164
European ClassificationC09K8/72, E21B43/16E, E21B43/40, E21B43/16