US3700035A - Method for controllable in-situ combustion - Google Patents

Method for controllable in-situ combustion Download PDF

Info

Publication number
US3700035A
US3700035A US3700035DA US3700035A US 3700035 A US3700035 A US 3700035A US 3700035D A US3700035D A US 3700035DA US 3700035 A US3700035 A US 3700035A
Authority
US
Grant status
Grant
Patent type
Prior art keywords
combustion
steam
water
annular space
oxygen
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
Application number
Inventor
Hans Lange
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
RWE-DEA AG fur Mineraloel und Chemie
Original Assignee
RWE-DEA AG fur Mineraloel und Chemie
Priority date (The priority date 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 date listed.)
Filing date
Publication date
Grant date

Links

Images

Classifications

    • EFIXED CONSTRUCTIONS
    • E21EARTH DRILLING; MINING
    • E21BEARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B36/00Heating, cooling, insulating arrangements for boreholes or wells, e.g. for use in permafrost zones
    • EFIXED CONSTRUCTIONS
    • E21EARTH DRILLING; MINING
    • E21BEARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B36/00Heating, cooling, insulating arrangements for boreholes or wells, e.g. for use in permafrost zones
    • E21B36/001Cooling arrangements
    • EFIXED CONSTRUCTIONS
    • E21EARTH DRILLING; MINING
    • E21BEARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/16Enhanced recovery methods for obtaining hydrocarbons
    • E21B43/24Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
    • E21B43/243Combustion in situ

Abstract

A method and device for controllable in-situ combustion in subterranean hydrocarbon bearing formations containing bitumens with simultaneous production and recovery of energy sources supplying the mechanical and thermal energy required for the insitu combustion and operation of the facilities involved.

Description

United States Patent Lange 1 1 Oct. 24, 1972 [54] METHOD FOR CONTROLLABLE IN- 2,823,752 2/ 1958 Walter ..166/272 SITU COMBUSTION 2,839,141 6/1958 Walter ..166/261 3,150,716 9/1964 Strelzofi et a1. 166/272 [72] Hans Luge Germany 3,344,856 10/1967 Lange ..166/261 x [73] Assignee: Deutsche Texaco Aktiengesellschaft 3,360,044 12/1967 Lange 166/272 [22] Filed: June 4 1970 3,548,938 12/1970 Parker ..166/272 X [21] Appl. No.: 43,547 Primary Examiner-Stephen J. Novosad AttorneyTh0mas l-l. Whaley and Carl G. Reis [52] [LS- Cl. ..166/261, 166/272, 166/57 57 ABSTRACT [51] Int. Cl. .1521!) 43/24 581 Field of Search ..166/303, 261, 272, 57, 302 A method and devlce for bustion in subterranean hydrocarbon bearing forma- [56] References Cited tions containing bitumens with simultaneous production and recovery of energy sources supplying the UNITED STATES PATENTS mechanical and thermal energy required for the in-situ combustion and operation of the facilities involved. 2,695,163 11/1954 Pearce et a1. ..166/261 X 2,734,578 2/1956 Walter ..166/57 X 6 Claims, 4 Drawing figures PATENTEDUBT 24 I972 SHEET 1 OF 4 PATENTEDMII I912 3.700.035

' sum 2 or 4 FIG. 2

METHOD FOR CONTROLLABLE IN-SITU COMBUSTION FIELD OF THE INVENTION trolled by using highly concentrated oxygen with residual nitrogen and a partial and/or temporary supply of superheated high-pressure steam, with simultaneous production of energy suitable for operating the necessary above ground facilities and auxiliary equipment.

DESCRIPTION OF THE PRIOR ART In-situ combustion in subterranean hydrocarbon bearing formations use low hydrogen petroleum residues as fuel for the combustion front, and the heat developed from their combustion produces additional combustional causes such as carbon monoxide and hydrogen which together with the dissolved hydrocarbon gases and the combustion product, such as carbon dioxide, escape from the production wells in gaseous form. The heat from the combustion and the heat contained in the steam formed in the burn-out matrix behind the combustion front flows before the combustion front heating the hydrocarbon bearing reservoir and reducing the viscosity of the hydrocarbon therein and displacing the hydrocarbon toward the production wells.

The combustible gas mixtures and the carbon dioxide escaped enter into pressure-resistant fireboxes or pressure-resistant furnaces of a special steam boiler, are burnt with evolution of heat by means of highly concentrated oxygen with residual nitrogen or of air used in heavy excess, and produce forms of energy, such as steam or hot combustion gases under pressure, that may supply energies to the facilities installed above ground and may also partly be introduced into the deposit through injection boreholes.

The generation of combustion heat in the underground deposit and the additional production above ground of different forms of energy that are partly and temporarily supplied to the deposit from above ground create a more comprehensive effect upon the content of the deposit. The addition of high-pressure steam in quickly variable amounts leads to an even spreading of the combustion front, facilitates the start of the process in each injection borehole, and increases the yield from the deposit. The use of carbon dioxide recovered in minor quantities from the condensation plant improves safety in the injection boreholes and also has a favorable influence upon the yield. It is advantageous, therefore, to combine all conditioning agents above ground so that they can be produced, applied, and controlled with the operation of the surface plants. The activated combustion gas can easily be varied in its composition and adjusted to operating conditions at any given time. In the starting phase, it may temporarily consist almost exclusively of steam with little oxygen; in the actual burning phase, it may contain plenty of oxygen with small quantities of residual nitrogen and carbon dioxide. The formation of steam may be either reduced by throttling down the supply of fuel gas, or it may be increased to provide mechanical energy for covering other energy requirements in the production field.

It is, therefore, an object of the invention to-use various process elements in the deposit and in the surface installations for making available all necessary operating agents at short notice and in a controllable manner. There are several possibilities of variation, thus allowing of several application techniques. Moreover, the plant and equipment involved can be readily transported owing to their light weight and small dimensions, thus facilitating adjustment to the conditions in oilfields being opened out.

SUMMARY This invention relates to methods and devices for controlling in-situ combustion using highly concentrated oxygen with residual nitrogen and a partial and/or temporary supply of superheated steam together with simultaneous production of energy for the operation of the necessary above ground facilities.

BRIEF DESCRIPTION OF THE DRAWINGS FIG. 1 is a diagramatic cross section of the firebox.

FIG. 2 is a diagrammatic cross section of high-pressure steam boiler.

FIG. 3 is a general illustration of the overall layout.

FIG. 4 is a diagramatic cross section showing a double-walled boiler.

DESCRIPTION OF THE PREFERRED EMBODIMENT When using high pressures of injection into the borehole, such as for steam coming from a closed system of tubes, it is envisaged that the pressure of the feed water tlowing'in the annular space of the doublewalled firebox or steam boiler should be smaller or slightly higher than that prevailing in the combustion chamber, and only after leaving the annular space should the feed water be pumped up to the pressure required for injection into the borehole.

The invention achieves these objects mainly by producing hot high-pressure steam in the combustion chamber injecting water into a pressure flame from an open system of tubes, and by additionally producing high-pressure steam in a closed system of tubes. The two types of steam may be used both for injection into the deposit and for supplying surface installations. Moreover, a mixture of separated dry carbon dioxide and residual nitrogen may be introduced at combustion chamber pressure, or at increased pressure after passing through a compressor, into the deposit via special pipes in the injection boreholes.

Technically, these requirements are met by using means know per se, such as a firebox or a steam boiler provided with a high-pressure combustion chamber. Particularly suitable is a firebox or steam boiler surrounded by a double wall forming an annular space through which a cooling medium, such as the feed water for the firebox or steam boiler, is passed, the surface area of the interior wall being enlarged at the side I of the flowing feed water so that the interior and exterior walls will always have the same temperature and thus the same expansion, enabling them to take up high pressure from within the combustion chamber.

According to the invention, when using highly concentrated oxygen at very high pressures up to and above 200 atmospheres, only a small volume of combustion gases will be present in the combustion chamber. Alternatively, at medium pressures ranging from 3 to atmospheres, air will be used in heavy excess, and part of the air from the compressor for the combustion turbine before the steam boiler will be branched off for the oxygen plant. In both cases, however, flue gas is taken from the combustion chamber and steam is taken from the high-pressure steam section for two different purposes, the flue gas and the steam each simultaneously doing two different jobs above ground and in the deposit. The temperature of a flame is known to increase as the pressure in the combustion chamber and the oxygen content of the combustion air increase. The shorter the period of time during which a given quantity of oxygen is converted to combustion gas, and the smaller the combustion chamber volume in which this conversion takes place, the higher the flame temperature will be. The pressure .flame used in the method of the invention meets all conditions that will increase the flame temperature at a high rate of combustion. Thus, it is a flame maintained in a small-volume combustion chamber. Its characteristic feature is an extremely high flame temperature with an extraordinarily strong radiation of heat, which cannot be cooled down sufficiently by a system of water and steam tubes even with normal circulation of the combustion gases. Almost invariably, film evaporation will occur in the water tubes, which will further deteriorate the cooling of the flame and will allow the temperatures to rise to an undesirable degree. To that case, the flow of feed water through the annular space between the two walls will scarcely lower the temperatures in these walls sufficiently to maintain adequate mechanical resistance values for the material of the walls.

To eliminate these disadvantages, water is injected into the flames so that a radiation-absorbing envelope of steam is formed around the flames which will effect an inertialess reduction of the flame temperature by evaporation of the water and will considerably diminish the effect of heat radiation on the walls of the combustion chamber. Heat distribution is further improved by providing in the combustion chamber and near the double wall of said combustion chamber a tubemounted wall having circular openings to permit circulation of the cooled-down steam.

In such steam boilers or fireboxes having pressure-resistant features, it is also possible to withdraw from the combustion chamber, from a condensation plant, or from a closed system of tubes such combustion products as carbon dioxide with residual nitrogen and steam in the desired temperature range, or cold dry carbon dioxide with residual nitrogen, as diagrammatically shown in the attached drawings.

The simplest case is illustrated in FIG. 1, when the oxygen with a small amount of residual nitrogen is available at such a high pressure that it can be forced into the deposit at against the pressure of the deposit, using an additional pressure of 50 to 75 atmospheres, a very small part stream of oxygen stream is introduced at its full pressure into a double-walled pressure-resistant firebox to be burnt with hydrocarbons to form carbon dioxide with residual nitrogen and steam. Since the combustion of hydrocarbons with highly concentrated oxygen leads to very high temperatures endangering the steel construction material of the firebox, water is injected at 15 and 16 through injection tubes 6 and 11 directly into the flame in combustion chamber 18. The injection water evaporates immediately thus reducing the temperature in the combustion chamber. To be able to resist the high pressures encountered, the firebox is surrounded with a double wall 1 and 2, enclosing an annular space 3. For cooling the two walls, the slightly preheated injection water is introduced into annular space 3 at 13. At 14, the water can be separated into two part streams and passed to the injection tubes via the inlet openings 15 and 16. Inlet 15 provides an upper injection water supply with injection openings 6 and inlet 16 provides a lower injection water supply with openings 1 1. The upper injection openings 6 form the steam envelope for protecting the combustion chamber, and with the lower injection openings 11 the outlet temperature of the combustion gases and vapors is adjusted to the necessary temperature for entry into the injection borehole 28. The tubesupporting wall 4 has openings fitted with steam injectors at 17 and further injectors 12 in the annular space 5 permitting circulation via outlet 10 of part streams from combustion chamber 18 to provide balanced temperature conditions.

Oxygen 8 and hydrocarbon 9 enter into the burner (not indicated) at 7 and leave the combustion chamber as combustion products together with steam from the injection water at 19, any entrained solids being kept back by small refractory bodies 31, which may consist of sintered iron or small ceramic bodies having large pores, to prevent obstructions in the deposit. Through sluices 29 and 30 the bodies 31 can be replaced without interrupting operations. A completely unchanged stream from outlet 19 is introduced into the interior corrosion-resistant tube 24 of the injection bore. After cooling, a smaller part stream of dry carbon dioxide with residual nitrogen passes into the annular space 27 of borehole 28 and temporarily, alternating with the oxygen, into the annular space 25 of the ascending tube 26. Similarly, the hydrocarbon 23, alternating with the combustion products and steam 21 and 22, passes into the interior tube 24.

FIG. 2 shows an additionally installed closed system of tubes 32 which is used as a high-pressure steam boiler. Since the interior wall 2 of the double wall is very closely covered with tubes, only small amounts of radiation and conduction heat can reach this wall, so that a special tube-supporting wall is not required. The water for the high-pressure steam boiler entering at 13 and the injection water pass through annular space 3 for cooling the double walls and enter the two systems of tubes at 33 and 35 at a controlled rate.

Combustion of the oxygen and hydrocarbons with cooling of the flame as well as the entry of the combustion products formed into the bore are effected in the same way as shown in FIG. 1. However, the amount of fuel and oxygen must be increased to such an extent, that the steam leaving at 39 can be used for operating steam turbine 36 and power generator 37, the waste steam being condensed in condenser 38. Opening 34 is used for introducing water for temperature regulation.

In FIG. 3 compressed air in the pressure range of 3 to 15 atmospheres is used as oxidation agent for combustion chamber 18, while highly concentrated oxygen with residual nitrogen is produced in an oxygen plant 57 on the oilfield and brought to the required pressure by means of high-pressure compressor 59 so that it can be introduced into the deposit in sufficient quantity through injection borehole 28.

The overall layout shown in FIG. 3 provides for a complete coordination of the methods of operating the in-situ combustion in the deposit with the supply of installations above ground. It will be desirable, however, to supplement the equipment shown in FIG. 3 by a firebox as shown in FIG. 1, so that in the event of breakdowns or when starting the in-situ combustion no major pause or delay can occur during which the fire in the deposit might be extinguished.

Two separate plants are installed for the energy production, accordingly the steam boiler with its pressure-resistant furnace is equipped for using compressed air, part of which serves for the production of oxygen. The second source of energy is based on steam; the steam has a pressure sufiicient for injection into the borehole and is also used continuously or temporarily for driving a turbogenerator 36 whose energy output is used for operating installations above ground.

The inter-connected plant elements, air compressor 49 and combustion turbine 50, are combined with a steam boiler forming the combustion chamber. 85 i 20 percent of the air is passed into annular space 44 between walls 2 and 43, where it is preheated. Then the air is passed through annular space 44 to point 7 and is mixed with the hydrocarbons 9 at the outlets to the burner (not indicated). The mixture is burnt in combustion chamber 18 using a heavy excess of air.

From line 47, a part quantity of 30 i percent of the compressed air is branched off to oxygen plant 57, supplementing the quantity of air from air compressor 56. Thus, there are two separate sources of air for the oxygen plant, each of which can provide about 50 percent of the total air required.

The combustion gases formed in combustion chamber 18, being products of the combustion of the hydrocarbons with compressed air, have a high temperature. In passing through pipe 15 with openings 6 they are precooled to such an extent that no film evaporation can occur in pipes 32. The injection waterintroduced through outlet 40 to pipe system 41 leading to the injection opening 42 is controlled so that the water entering the evaporator 45 at 46 is evaporated and drawn off through pipe 39 in the desired temperature both for the injection borehole 21 and for steam turbine 36 which may, for example, drive the power generator 37. The volume of steam formed by the injection water replaces the air from air compressor 49 branched off for oxygen plant 57, thus resulting in a total gas volume or additional steam volume for combustion turbine 50 driving power generator 51.

The waste steam from steam turbine 36 is partially condensed in heat exchanger 11 (point 38, combined with condenser III), and the residual steam in condenser III, point 38. The condensate is passed via pump 2 into heat exchanger I, point 52, which receives its heat from the waste gases of the combustion turbine 50. In heat exchanger I, point 52, combined with condenser the feed water from feed water treatment plant 55 introduced via pump 3 and the condensation water from point 38 introduced via pump 2 are heated,

the water for the closed system of tubes 32 entering pipes 32 at 34 as a part stream. The steam from the in- 5 jection water from combustion turbine 50 having an inlet temperature of about 450C. is cooled in heat exchanger I, point 52, condensed in condenser I, and mixed via pump 4 with part of the feed water 55 in con-. denser II, point 53. The heat from heat exchanger II and condenser III is further used at point 38 for heating the wet petroleum recovered from the deposit, thus separating oil and water. The separated separated water can be used in other boreholes for flooding purposes. Parts of the condensate obtained at 38 can be introduced without heating into annular space 3 between walls 1 and 2 at point 13 via pump 1.

The combustion gases from chamber 18 and steam generated by injecting water into the flame will enter the heat exchanger I (position 52) via line 48 and combustion turbine 50. The temperature of the gaseous mixture decreases from 950 to 450C. while passing combustion turbine 50. Loss water from apparatus 55 for dehardening the feeding water also will enter the heat exchanger 52. The inside temperature of chamber 18 will be controlled furthermore by injecting feeding water at 34.

Inside the condenser II (position 53) especially near its upper warm and gaseous products, like nitrogen, oxygen, and carbon dioxide will escape from the condensate. A mixture from carbon dioxide and remaining nitrogen will be delivered at the bottom of condenser 53 and supplied to the injection borehole 28.

Owing to the cold water the carbon dioxide and residual nitrogen are also obtained cold containing very little steam, it may be considered in the borehole as dry carbon dioxide which is not corrosive even if it must be pressurized. With the same degree of cooling the oxygen may also become non-corrosive after compres- Air from air compressors 49 and 56 is used for producing oxygen in plant 57, almost all of the nitrogen escaping at 58. In compressor 59 the oxygen is sufficiently pressurized for passing into the deposit via the injection borehole. Also in the case of combustion chamber 18 using compressed air as oxidation agent for the hydrocarbons from the deposit, the injection borehole 28 is supplied with the necessary agents as shown in FIG. 1.

The double-walled combustion chambers with its walls 1 and 2 also receives part of the feed waterfor for reducing the temperature direct from condenser Ill, point 38, at a pressure below that of combustion chamber 18. The feed water enters the annular space 3 at 13, leaves it at 60, is brought to the pressure of the closed system of tubes 32 by means of pump 61, and passes into the closed system of tubes at 62.

In combustion chamber 18, the tube-supporting wall 4 is provided within pipe wall 43 so that in annular space S with injectors l2 and 17, a circulating effect can be achieved at 10 by means of the injection water introduced at 16 to create balanced temperature conditions.

This special double-walled steam boiler thus supplies the injection borehole 28 and turbines 36 and 50 so that a coherent system has been provided and a maximum of conditioning agents is available for controlling the inesitu combustion.

FIG. 4 is a diagrammatic drawing of a double-walled steam boiler having a multi-stage burner and pressureresistant upper and lowercover plates. This design is suitable for higher pressures even at temperatures of 300C.

For transport from one oilfield to the other, the exterior wall can be removed so that the remaining low weight of the interior wall with its installations permits its transport as a unit. The lower rings 66 are suitably parted and fitted to the walls 1 and 2.

Thus, the exterior wall 1 and the interior wall 2 have inner and outer rings 66 at the top and bottom. The upper ring 82 has openings only for bolts 63.

The upper and lower cover plates 68 are welded to the inner rings 66 and 70.

By means of screw joints 63 and 64 the upper counter-ring 82 is pressed on the soft iron rings 65 and rings 66 to form a tight seal.

Additional seals are provided by rings 67 and 71.

The flange openings 69 are screwed to the upper and lower cover plate rims 68. The burner with its inner opening 74 and its outer opening 72 is welded or screwed to the upper flange opening.

The combustible gases enter at 9 and the oxidation agent at 44. The oxidation agent passes from 47 into the annular space 44 formed by walls 2 and 43. It passes between walls 72 and 73 and is mixed at ring burners 75 and 78 or, respectively, 79 and 81, at the conical outlet 80.

The burner having several ring burners 75 and 78 is able to produce a very long downward flame through the vertical openings 79 and 81. The feed water is introduced into annular space 3 at 13 and leaves it at 60.

The bottom of the boiler casing corresponds in design to the top part. The top and bottom of the boiler casing are practically symmetrical.

We claim:

1. A method for producing hydrocarbons by controllable in-situ combustion from deposits containing bitumens, said deposits traversed by an injection well and a production well, whereby the mechanical energy and heat required for in-situ combustion and for operation of the above-ground facilities and auxiliary equipment are simultaneously produced, which comprises:

a. introducing via said injection well compressed air produced by known methods in a compressor coupled with a combustion turbine for the partial production of the oxygen required for in-situ combustion with little carbon dioxide and residual 10 jection well contains two concentric tubings, comprising producing a combustion gas in a double-walled pressure resistant firebox of a steam boiler by combustion of hydrocarbons with said oxygen containing little carbon dioxide and a small amount of residual nitrogen, increasing the volume of said combustion gas by injecting water through said open system of tubes under controlled temperature conditions, introducing a major quantity of said combustion gas into the inner tubing of said injection well, cooling the smaller part of said combustion gas to condense the steam and to form a dry mixture of carbon dioxide and residual nitrogen, introducing said dry mixture into the annular space between the borehole of said well and the second larger concentric tubing, and temporarily, introducing oxygen via the annular space between the two said tubings.

3. The method of claim 1 wherein said combustion gas required for the in-situ combustion has an average composition of 94 X 5% O 25 X 4% N and 50 X 2% C0 4. A method according to claim 1 wherein said water in step (b) is controllably injected into the burner flames of the combustion chamber through the water injection nozzles subdivided into groups, said flames consisting of fuel and compressed oxygen or air with increasing oxygen content, forming a cooling and radiation heat absorbing body of steam around the flame thus shaping and cooling the flame.

5. A method of claim 1 wherein said water injection nozzles with and without fitted injectors are used to provide circulation of the steam and combustion gases between the combustion chamber and the annular space formed by the interior wall of the double wall and a tube-supporting wall limiting the combustion chamber.

6. A method of claim 1 wherein said water injection nozzles with and without fitted injectors are used to provide circulation of the steam and combustion gases between the combustion chamber and an annular space formed by the interior wall of a guide wall suitable for guiding the combustion gas and arranged between the double wall and the tube-supporting wall.

32 3 UNITED STATES PATENT OFFICE CERTIFICATE OF CORRECTION Patent No. 3,700,035 Dated October 97 Inventor (s) Hans Lange It is certified that error appears in the above-identified patent and that said Letters Patent are hereby corrected as shown below:

[101. 6, line 12 Delete "separated" at end of line.

line 51 "chambers" should be --cha.mber-- line 52 Delete "for" at end of line.

Col. 7, line 2 "inesitu" should be --in situ-- Col. 8, line 28 In three instances, change "X" to i Signed and sealed this 13th day of March 1973.

(SEAL) Attest:

EDWARD M.FLETCHER,JR. ROBERT GOTTSCHALK Attesting Officer Commissioner of Patents

Claims (5)

  1. 2. A method according to claim 1, wherein said injection well contains two concentric tubings, comprising producing a combustion gas in a double-walled pressure resistant firebox of a steam boiler by combustion of hydrocarbons with said oxygen containing little carbon dioxide and a small amount of residual nitrogen, increasing the volume of said combustion gas by injecting water through said open system of tubes under controlled temperature conditions, introducing a major quantity of said combustion gas into the inner tubing of said injection well, cooling the smaller part of said combustion gas to condense the steam and to form a dry mixture of carbon dioxide and residual nitrogen, introducing said dry mixture into the annular space between the borehole of said well and the second larger concentric tubing, and temporarily, introducing oxygen via the annular space between the two said tubings.
  2. 3. The method of claim 1 wherein said combustion gas required for the in-situ combustion has an average composition of 94 X 5% O2, 25 X 4% N2, and 50 X 2% CO2.
  3. 4. A method according to claim 1 wherein said water in step (b) is controllably injected into the burner flames of the combustion chamber through the water injection nozzles subdivided into groups, said flames consisting of fuel and compressed oxygen or air with increasing oxygen content, forming a cooling and radiation heat absorbing body of steam around the flame thus shaping and cooling the flame.
  4. 5. A method of claim 1 wherein said water injection nozzles with and without fitted injectors are used to provide circulation of the steam and combustion gases between the combustion chamber and the annular space formed by the interior wall of the double wall and a tube-supporting wall limiting the combustion chamber.
  5. 6. A method of claim 1 wherein said water injection nozzles with and without fitted injectors are used to provide circulation of the steam and combustion gases between the combustion chamber and an annular space formed by the interior wall of a guide wall suitable for guiding the combustion gas and arranged between the double wall and the tube-supporting wall.
US3700035A 1970-06-04 1970-06-04 Method for controllable in-situ combustion Expired - Lifetime US3700035A (en)

Priority Applications (1)

Application Number Priority Date Filing Date Title
US4354770 true 1970-06-04 1970-06-04

Publications (1)

Publication Number Publication Date
US3700035A true US3700035A (en) 1972-10-24

Family

ID=21927715

Family Applications (1)

Application Number Title Priority Date Filing Date
US3700035A Expired - Lifetime US3700035A (en) 1970-06-04 1970-06-04 Method for controllable in-situ combustion

Country Status (1)

Country Link
US (1) US3700035A (en)

Cited By (19)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4159743A (en) * 1977-01-03 1979-07-03 World Energy Systems Process and system for recovering hydrocarbons from underground formations
DE2924580A1 (en) * 1978-07-03 1980-01-24 Gulf Research Development Co Catalytic oxidn. of gas mixts. with low heat value - giving exhaust gas with reduced carbon mon:oxide (NL 7.1.80)
US4186801A (en) * 1978-12-18 1980-02-05 Gulf Research And Development Company In situ combustion process for the recovery of liquid carbonaceous fuels from subterranean formations
US4192381A (en) * 1977-07-13 1980-03-11 Occidental Oil Shale, Inc. In situ retorting with high temperature oxygen supplying gas
US4199024A (en) * 1975-08-07 1980-04-22 World Energy Systems Multistage gas generator
US4224991A (en) * 1978-03-01 1980-09-30 Messerschmitt-Bolkow-Blohm Gmbh Method and apparatus for extracting crude oil from previously tapped deposits
US4273188A (en) * 1980-04-30 1981-06-16 Gulf Research & Development Company In situ combustion process for the recovery of liquid carbonaceous fuels from subterranean formations
US4325432A (en) * 1980-04-07 1982-04-20 Henry John T Method of oil recovery
US4385661A (en) * 1981-01-07 1983-05-31 The United States Of America As Represented By The United States Department Of Energy Downhole steam generator with improved preheating, combustion and protection features
US4456069A (en) * 1982-07-14 1984-06-26 Vigneri Ronald J Process and apparatus for treating hydrocarbon-bearing well formations
US4499946A (en) * 1981-03-10 1985-02-19 Mason & Hanger-Silas Mason Co., Inc. Enhanced oil recovery process and apparatus
WO1999067505A1 (en) * 1998-06-24 1999-12-29 World Energy Systems, Incorporated Recovery of heavy hydrocarbons by in-situ hydrovisbreaking
WO1999067504A1 (en) * 1998-06-24 1999-12-29 World Energy Systems, Incorporated Production of heavy hydrocarbons by in-situ hydrovisbreaking
US20070193748A1 (en) * 2006-02-21 2007-08-23 World Energy Systems, Inc. Method for producing viscous hydrocarbon using steam and carbon dioxide
US20080053065A1 (en) * 2006-08-31 2008-03-06 Hobson Russell B Apparatus for the decomposition of hydrogen peroxide
US20100077943A1 (en) * 2008-09-26 2010-04-01 Air Products And Chemicals, Inc. Combustion system with steam or water injection
US20110127036A1 (en) * 2009-07-17 2011-06-02 Daniel Tilmont Method and apparatus for a downhole gas generator
US8613316B2 (en) 2010-03-08 2013-12-24 World Energy Systems Incorporated Downhole steam generator and method of use
US8684072B2 (en) * 2012-08-03 2014-04-01 Kreis Syngas, Llc Downhole gas generator

Citations (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2695163A (en) * 1950-12-09 1954-11-23 Stanolind Oil & Gas Co Method for gasification of subterranean carbonaceous deposits
US2734578A (en) * 1956-02-14 Walter
US2823752A (en) * 1955-08-30 1958-02-18 Worthington Corp Method and arrangement of apparatus for oil recovery
US2839141A (en) * 1956-01-30 1958-06-17 Worthington Corp Method for oil recovery with "in situ" combustion
US3150716A (en) * 1959-10-01 1964-09-29 Chemical Construction Corp Pressurizing oil fields
US3344856A (en) * 1964-03-26 1967-10-03 Deutsche Erdoel Ag Process for the extraction of liquid and solid bitumens from underground deposits
US3360044A (en) * 1963-03-21 1967-12-26 Deutsche Erdoel Ag Process and apparatus for the recovery of liquid bitumen from underground deposits
US3548938A (en) * 1967-05-29 1970-12-22 Phillips Petroleum Co In situ method of producing oil from oil shale

Patent Citations (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2734578A (en) * 1956-02-14 Walter
US2695163A (en) * 1950-12-09 1954-11-23 Stanolind Oil & Gas Co Method for gasification of subterranean carbonaceous deposits
US2823752A (en) * 1955-08-30 1958-02-18 Worthington Corp Method and arrangement of apparatus for oil recovery
US2839141A (en) * 1956-01-30 1958-06-17 Worthington Corp Method for oil recovery with "in situ" combustion
US3150716A (en) * 1959-10-01 1964-09-29 Chemical Construction Corp Pressurizing oil fields
US3360044A (en) * 1963-03-21 1967-12-26 Deutsche Erdoel Ag Process and apparatus for the recovery of liquid bitumen from underground deposits
US3344856A (en) * 1964-03-26 1967-10-03 Deutsche Erdoel Ag Process for the extraction of liquid and solid bitumens from underground deposits
US3548938A (en) * 1967-05-29 1970-12-22 Phillips Petroleum Co In situ method of producing oil from oil shale

Cited By (31)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4199024A (en) * 1975-08-07 1980-04-22 World Energy Systems Multistage gas generator
US4159743A (en) * 1977-01-03 1979-07-03 World Energy Systems Process and system for recovering hydrocarbons from underground formations
US4192381A (en) * 1977-07-13 1980-03-11 Occidental Oil Shale, Inc. In situ retorting with high temperature oxygen supplying gas
US4224991A (en) * 1978-03-01 1980-09-30 Messerschmitt-Bolkow-Blohm Gmbh Method and apparatus for extracting crude oil from previously tapped deposits
DE2924580A1 (en) * 1978-07-03 1980-01-24 Gulf Research Development Co Catalytic oxidn. of gas mixts. with low heat value - giving exhaust gas with reduced carbon mon:oxide (NL 7.1.80)
US4186801A (en) * 1978-12-18 1980-02-05 Gulf Research And Development Company In situ combustion process for the recovery of liquid carbonaceous fuels from subterranean formations
US4325432A (en) * 1980-04-07 1982-04-20 Henry John T Method of oil recovery
US4273188A (en) * 1980-04-30 1981-06-16 Gulf Research & Development Company In situ combustion process for the recovery of liquid carbonaceous fuels from subterranean formations
US4385661A (en) * 1981-01-07 1983-05-31 The United States Of America As Represented By The United States Department Of Energy Downhole steam generator with improved preheating, combustion and protection features
US4499946A (en) * 1981-03-10 1985-02-19 Mason & Hanger-Silas Mason Co., Inc. Enhanced oil recovery process and apparatus
US4456069A (en) * 1982-07-14 1984-06-26 Vigneri Ronald J Process and apparatus for treating hydrocarbon-bearing well formations
WO1999067505A1 (en) * 1998-06-24 1999-12-29 World Energy Systems, Incorporated Recovery of heavy hydrocarbons by in-situ hydrovisbreaking
WO1999067504A1 (en) * 1998-06-24 1999-12-29 World Energy Systems, Incorporated Production of heavy hydrocarbons by in-situ hydrovisbreaking
US6016867A (en) * 1998-06-24 2000-01-25 World Energy Systems, Incorporated Upgrading and recovery of heavy crude oils and natural bitumens by in situ hydrovisbreaking
US6016868A (en) * 1998-06-24 2000-01-25 World Energy Systems, Incorporated Production of synthetic crude oil from heavy hydrocarbons recovered by in situ hydrovisbreaking
US6328104B1 (en) * 1998-06-24 2001-12-11 World Energy Systems Incorporated Upgrading and recovery of heavy crude oils and natural bitumens by in situ hydrovisbreaking
US20070193748A1 (en) * 2006-02-21 2007-08-23 World Energy Systems, Inc. Method for producing viscous hydrocarbon using steam and carbon dioxide
US8573292B2 (en) 2006-02-21 2013-11-05 World Energy Systems Incorporated Method for producing viscous hydrocarbon using steam and carbon dioxide
US8091625B2 (en) * 2006-02-21 2012-01-10 World Energy Systems Incorporated Method for producing viscous hydrocarbon using steam and carbon dioxide
US8286698B2 (en) 2006-02-21 2012-10-16 World Energy Systems Incorporated Method for producing viscous hydrocarbon using steam and carbon dioxide
US20080053065A1 (en) * 2006-08-31 2008-03-06 Hobson Russell B Apparatus for the decomposition of hydrogen peroxide
US8020614B2 (en) 2006-08-31 2011-09-20 Samuel A. Miller, III Apparatus for the decomposition of hydrogen peroxide
US20100077943A1 (en) * 2008-09-26 2010-04-01 Air Products And Chemicals, Inc. Combustion system with steam or water injection
US8327779B2 (en) 2008-09-26 2012-12-11 Air Products And Chemicals, Inc. Combustion system with steam or water injection
US8387692B2 (en) 2009-07-17 2013-03-05 World Energy Systems Incorporated Method and apparatus for a downhole gas generator
US20110127036A1 (en) * 2009-07-17 2011-06-02 Daniel Tilmont Method and apparatus for a downhole gas generator
US9422797B2 (en) 2009-07-17 2016-08-23 World Energy Systems Incorporated Method of recovering hydrocarbons from a reservoir
US8613316B2 (en) 2010-03-08 2013-12-24 World Energy Systems Incorporated Downhole steam generator and method of use
US9528359B2 (en) 2010-03-08 2016-12-27 World Energy Systems Incorporated Downhole steam generator and method of use
US9617840B2 (en) 2010-03-08 2017-04-11 World Energy Systems Incorporated Downhole steam generator and method of use
US8684072B2 (en) * 2012-08-03 2014-04-01 Kreis Syngas, Llc Downhole gas generator

Similar Documents

Publication Publication Date Title
US3379248A (en) In situ combustion process utilizing waste heat
US3363993A (en) Method and system for using the carbon monoxide content of gases
US2890754A (en) Apparatus for recovering combustible substances from subterraneous deposits in situ
US4014575A (en) System for fuel and products of oil shale retort
US4005752A (en) Method of igniting in situ oil shale retort with fuel rich flue gas
US1422204A (en) Method for working oil shales
US4224991A (en) Method and apparatus for extracting crude oil from previously tapped deposits
US3982592A (en) In situ hydrogenation of hydrocarbons in underground formations
US4372386A (en) Steam injection method and apparatus for recovery of oil
US2970826A (en) Recovery of oil from oil shale
US2780449A (en) Thermal process for in-situ decomposition of oil shale
US3692017A (en) Submerged combustion heat-generator, in particular for the production of very hot water
US1913395A (en) Underground gasification of carbonaceous material-bearing substances
US5055030A (en) Method for the recovery of hydrocarbons
US4336839A (en) Direct firing downhole steam generator
US4641710A (en) Enhanced recovery of subterranean deposits by thermal stimulation
US7048051B2 (en) Recovery of products from oil shale
US4089373A (en) Situ coal combustion heat recovery method
US2890755A (en) Apparatus for recovering combustible substances from subterraneous deposits in situ
US4390062A (en) Downhole steam generator using low pressure fuel and air supply
US20080078552A1 (en) Method of heating hydrocarbons
US4036299A (en) Enriching off gas from oil shale retort
US4301750A (en) Method for pyrolyzing waste materials
US3013609A (en) Method for producing hydrocarbons in an in situ combustion operation
US4057293A (en) Process for in situ conversion of coal or the like into oil and gas