EP0075515B1 - Procédé et installation de récupération du pétrole par combustion in situ - Google Patents

Procédé et installation de récupération du pétrole par combustion in situ Download PDF

Info

Publication number
EP0075515B1
EP0075515B1 EP82401680A EP82401680A EP0075515B1 EP 0075515 B1 EP0075515 B1 EP 0075515B1 EP 82401680 A EP82401680 A EP 82401680A EP 82401680 A EP82401680 A EP 82401680A EP 0075515 B1 EP0075515 B1 EP 0075515B1
Authority
EP
European Patent Office
Prior art keywords
oxygen
conduit
injection
flame
combustion
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
Application number
EP82401680A
Other languages
German (de)
English (en)
French (fr)
Other versions
EP0075515A1 (fr
Inventor
Guy Savard
Robert Gum Hong Lee
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.)
Air Liquide Canada Inc
Original Assignee
Air Liquide Canada Inc
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
Application filed by Air Liquide Canada Inc filed Critical Air Liquide Canada Inc
Priority to AT82401680T priority Critical patent/ATE16624T1/de
Publication of EP0075515A1 publication Critical patent/EP0075515A1/fr
Application granted granted Critical
Publication of EP0075515B1 publication Critical patent/EP0075515B1/fr
Expired legal-status Critical Current

Links

Images

Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/30—Specific pattern of wells, e.g. optimising the spacing of wells
    • 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
    • E21B41/00—Equipment or details not covered by groups E21B15/00 - E21B40/00
    • E21B41/0078—Nozzles used in boreholes
    • 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
    • E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
    • E21B43/243—Combustion in situ

Definitions

  • the invention relates to the recovery of petroleum by in situ combustion from deposits located in underground sedimentary formations.
  • Process regulation is essential and complex. To monitor the advance of the combustion front and to predict operational problems, basic data must be obtained and analyzed, in particular the air speed and its pressure, the injection rate of the water, gas evacuation speed in different wells, casing pressures on production wells, gas analysis, oil and water production rate, temperature measurements. Among the other data, which we need more rarely, but on a regular basis, we must mention the density and viscosity of the oil leaving each well, the determination of chlorine in water, the pH of water, the pressure drop of the injectors.
  • the first group of data makes it possible to make calculations on the movement of the forehead, the efficiency of combustion and the use of oxygen.
  • the second set of data makes it possible to make corrections to the calculated data and to prepare for the arrival of the thermal front in a production well.
  • Patent FR-A-1 473 669 discloses a process for recovering petroleum by in situ combustion with the possibility of optionally resorting to the combustion of petroleum from the deposit by an activated combustion gas, such as composed of carbon dioxide, water vapor and enriched with large quantities of oxygen.
  • the invention proposed by this application relates to a process for recovering petroleum by combustion, in situ from a sedimentary formation constituting an oil deposit according to which a gas supporting combustion is introduced such as air or air and water or a gas enriched in oxygen or pure oxygen, by at least one injection well extending from the surface and crossing overburden up to the interior of the deposit, in an injection zone so as to burn part of the oil by creating a flame front, which is advanced to a certain point, and to cause the flow, through a treatment zone, of fluids whose petroleum, to a number of production wells through which fluids are extracted.
  • a gas supporting combustion such as air or air and water or a gas enriched in oxygen or pure oxygen
  • the method according to this proposed invention is characterized in that, when the gas supporting combustion is oxygen, it is introduced by a separate conduit separate from the injection well, this conduit leaving the surface, passing through the dead - land and arriving separately in the deposit near the injection well.
  • the installation for applying this method is characterized in that it also comprises at least one oxygen conduit distinct and separate from the injection well, starting from the surface, passing through the overburden and arriving in the area of treatment at a point located at a distance from the injection well much less than the distance between an injection well and a production well, said conduit being equipped with means for introducing oxygen into the formation.
  • in situ combustion is regulated by the strategic placement of one or more fluid conduits, starting from the surface and crossing the overburden to reach the treatment zone, at a point located at a certain distance from the injection well, the regulating fluid being introduced into the deposit via said conduit, independently of the fluid injected into the injection well.
  • the control fluid introduced is oxygen, serving as auxiliary combustion gas and replacing the injection of a gas supporting combustion such as air in the well. injection.
  • the fluid conduit is located near the injection well, but it is separated by a short distance, so as to allow the establishment, on the surface, of a separate regulation equipment.
  • oxygen and water can be introduced alternately, the oxygen being sent through the fluid conduit and the water through the injection well.
  • a regulating fluid conduit is placed in this zone, and oxygen is introduced to accelerate the flame front and improve the scanning.
  • a regulation duct in this area and introduce appropriate fluids to slow down the flame front and improve the sweep .
  • the invention is preferably used with a conventional in situ combustion model, preferably a multi-well mesh type well layout arrangement, in which air and water are introduced into a well. injection, which leaves the surface and crosses overburden to reach the oil field,. in an injection zone, under conditions leading to the combustion of part of the oil and the flow of part of the oil through a treatment zone to at least one production well, disposed at a certain distance from the injection well.
  • an oxygen introduction conduit is placed strategically, extending from the surface and crossing the overburden to the oil deposit, in the treatment zone.
  • the oxygen conduit is placed near the injection well, but at a sufficient distance so that the equipment for regulating oxygen at the surface is distinct from the equipment. relatively complex regulator at the head of the injection well.
  • the separate oxygen conduit may be approximately 3 to 4.6 m from the injection well.
  • air and water in a representative treatment cycle, are introduced alternately into the injection well to advance the flame front to a certain point.
  • the air injection is then stopped, then the injection well is used to introduce essentially only water.
  • the air is replaced by oxygen, which is introduced into the deposit by the oxygen pipe to continue the advance of the flame front.
  • the invention also relates to a method of recovering petroleum from an underground sedimentary formation by the wet combustion process, method according to which there is an injection well, equipped to introduce air, or l water, or both, under conditions ensuring the combustion of part of the oil by air, and a certain number of production wells, arranged at a certain distance from the injection well, towards which one is s' drain the oil through a processing area.
  • a separate oxygen conduit starts from the surface, passes through the overburden and arrives in the formation treatment area, at a point located at a relatively short distance from the injection well.
  • the injection well is fitted with conventional, relatively complex air and water control equipment. The fact that the oxygen pipe is separated considerably simplifies the surface control system for both the air injection well and the oxygen pipe.
  • FIG. 1 shows a layout arrangement of “three-mesh” wells, comprising three injection wells A, A 1 and A 2 .
  • a series of production wells B are placed, for example, symmetrically with respect to the injection well A, at a certain distance from the latter. Air is injected through the injection well A into the underground formation in an injection area, to allow combustion of the oil.
  • the production wells B located in the production areas are equipped with pumping means so that, when combustion begins in the vicinity of injection well A, the fluids, which include combustion products, water, steam and petroleum, are drawn from the injection zone in the vicinity of well A, through a treatment zone, to reach a production zone at well B.
  • a flame front is produced in the treatment zone between the injection zone and the production zone.
  • a cycle is carried out according to which air is introduced for two days, then water for one day, and this cycle is repeated continuously for several months or several years.
  • the injection well A is located in the center of the mesh and the production wells B are at the corners of the hexagon, at a distance of approximately 122 m.
  • the oil formation can be several tens to several hundred meters from the surface, for example 610 m.
  • the thickness of the formation can range from a minimum of 0.3 m to more than 30 m. For example, most of the oil found in the Lloydminister area occurs in formations about 6 m thick. Exploitation can continue for several months before recovery begins in the production wells of oil from on-site combustion.
  • an oxygen conduit C starts from the surface, crosses overburden and arrives in the oil deposit, in the treatment zone, at a relatively short distance from the injection well A.
  • the oxygen duct C can be 4.6 m from the injection well.
  • the oxygen duct be located at a certain distance from the injection well so as to allow independent realization l 'exploitation of both. In all cases, a fluid must constantly flow through the oxygen pipe and through the injection well. According to the invention, once the flame front has advanced in the treatment zone, to the desired point, the injection of air and water is stopped in the injection well A and the introduction of oxygen in the oxygen line, alternating with the injection of water into the injection well.
  • the production well pumps are turned on and a certain amount of oil is extracted before in situ combustion.
  • the flame can then be lit, for example by lowering a gas burner into the injection well, by sending air or natural gas to promote combustion.
  • the burner can either remain in place or be recovered, depending on the circumstances.
  • Figure 2 is a theoretical view of what happens during in situ wet combustion.
  • This figure is a vertical section through an underground sedimentary formation containing petroleum, also known as an oil deposit, which has undergone wet combustion.
  • the formation consists of an injection zone surrounding the injection well A, intended to introduce air to maintain the combustion of petroleum in the deposit and water to modify the heat transfer according to the method of wet combustion, and a production area surrounding the production well B, intended to extract the fluids pushed forward by the flame front. Between these two zones is a treatment zone, and the different materials making up this zone, at a particular stage of operation, are indicated by legends in the figure.
  • a gas injection tube C is placed strategically in the treatment zone to introduce oxygen intended to promote combustion or to regulate the advance of the flame front, as will be described. in detail below.
  • an oxygen conduit so that it penetrates into the burned region, then introduce oxygen to promote combustion, oxygen which will replace the air injected into well A.
  • a representative method could include two days of oxygen injection and one day of water injection, during the entire treatment period, which can last up to several years.
  • the injection well A is approximately 125 m (a) from the production well B.
  • the thickness of the sedimentary formation is between 0.3 and 30 m, and it can be at a depth of about 610 m, being covered by overburden in which there may be separate additional sedimentary oil formations by rock.
  • Oxygen line C should be placed approximately 3.0 to 4.6 m from the injection well.
  • FIG. 4 represents an installation according to the invention, in vertical section, in an underground formation.
  • the reference A designates an air-water injection well.
  • the well consists of a borehole, lined with a steel casing 15, which starts from the surface, descends through the overburden and arrives in the underground sedimentary formation in which the oil deposit is found.
  • the borehole, outside the casing 15, is suitably filled with standard filling materials which form an envelope 17 internally lining the borehole.
  • the casing 17 is lined with perforations 19 to allow the fluids to exit the borehole.
  • the casing 15 is lined with a casing shoe 21.
  • a lined tube 23 starts from a wellhead 25, located on the surface, to arrive at a “recoverable packer 26, the lower end of which is centered in the envelope 17.
  • An air and water pipe 27 starts from an injection unit, and can send air head or pressurized water to the wellhead 25.
  • Gate valves 29 and 31 are provided, as well as check valves 33 and full-flow valves 35 and 36 for regulating the flow of air or water to the tube 23.
  • the apparatuses placed above from well A are frequently called "Christmas tree".
  • an oxygen conduit C is placed, formed by a borehole housing a steel casing 37 and a concrete casing 36 filling the space between the borehole and the casing.
  • An oxygen tube 41 which extends beyond the casing 37 and passes through a recoverable "packer” 43 to come out from below, extends into the borehole.
  • the oxygen tube starts from the surface, crosses the overburden and enters the underground sedimentary formation, in the treatment zone located between the injection well A and the production wells.
  • oxygen 45 starts from a pressurized oxygen source, passes through a full-flow valve 47 and arrives at the oxygen tube 41. Since only oxygen is introduced into the conduit C, the tube 41 does not need to be made of an expensive stainless steel such as that which is necessary for the injection well A where the presence of water causes corrosion. In addition, only relatively simple oxygen control equipment is required.
  • the lower end of the oxygen tube has a safety injector D, which is described in detail below.
  • Figure 5 is an enlarged partial vertical section of the bottom of the oxygen conduit.
  • the end of the tube 41 carries an external thread intended to receive a cylindrical connector member 51 over its entire length.
  • the member 51 has an internal bore, which has a cylindrical part 53, enlarged and tapped, meshing with the end of the pipe 41.
  • the bore narrows into a frustoconical part 54 to arrive at a groove 55, which defines the inlet of a throttled central cylindrical passage 57.
  • the lower end of the element 51 has an annular recess 58, which receives the end of a pipe 59 made of nickel alloy.
  • the pipe 59 and the connector member 51 are welded to each other at 61.
  • a tip element 63 is mounted at the lower end of the pipe 59.
  • the element 63 has a cylindrical body over its entire length, with an upper annular recess 60 receiving the end of the pipe 59.
  • the element 63 and the pipe 59 are welded to each other at 65.
  • the body of the element 63 has a central passage, which has an upper frustoconical part 67 narrowing to a short cylindrical groove 69, then widening in part frustoconical 71 ending in a shorter and wider frustoconical part 73.
  • Parts 51 and 63 are made of a non-fissurable nickel alloy.
  • the dimensions of the oxygen pipe depend to a large extent on the force required to pull the packer.
  • the smallest diameter would be approximately 51 mm, the largest of 254 mm, 178 mm corresponding to a practical intermediate diameter. This diameter must be sufficient to allow the introduction of cement.
  • a tube with a diameter of 51 mm is sufficient.
  • the maximum diameter corresponds to a pipe which can be part of the well itself and still be cemented.
  • the pressure is generally the same as that of air, and is between 28 and 70 kg / cm 2 .
  • An empirical calculation method calculates the pressure, which will be about half a pound for 30 cm deep. The specific pressure depends on both the depth and the porosity of the formation.
  • the boreholes can have any diameter.
  • a plunger is provided to expel the cement.
  • a unit on the surface supplies oxygen at low pressure at a rate of at least 18 tonnes per day, and compresses it to a pressure of 28 to 70 kg / cm 2.
  • the oxygen pipe must be equipped with to allow rapid replacement of oxygen with other fluids.
  • At least part of the passage, through which the oxygen-containing gas is introduced, must be throttled so as to have a diameter such that the speed of the gas is greater than the maximum speed of the flame likely to to occur.
  • This injector has throttled grooves, arranged in series, followed by an outlet opening of increasing diameter intended to allow the expansion of the gas. in order to reduce its speed and minimize the sanding effect inside the casing.
  • the safety injector as shown can be used not only for oxygen, but also for oxygen mixed with another fluid having desirable properties for the in situ combustion of a hydrocarbon deposit, for example CO 2 , N 2 air, H 2 0, etc ...
  • the tube downstream of the packer must resist cracking in contact with oxygen, heat, corrosion and erosion. Besides this, the tube must have maximum security. In an oil formation, for example, there may be disturbances and fuel seepage inside and around the injection tube. '
  • a hydrocarbon can burn in the presence of air giving a flame having a certain speed. If the same hydrocarbon burns with oxygen, its flame propagation rate may be much higher.
  • the methane-air mixture gives a maximum flame propagation speed of 0.46 m / s, while the methane-oxygen flame has a maximum propagation speed of 4.57 m / s.
  • the hydrogen-air mixture has a maximum flame propagation speed of 3 m / s, while the hydrogen-oxygen flame has a maximum flame propagation speed of 14 m / s.
  • the flame propagation speed H 2 -0 2 is approximately 19.81 m / s under a pressure of 21 kg / cm 2 , approximately 28.35 m / s under a pressure of 63 kg / cm 2 , and 30.48 m / s under a pressure of 105 kg / cm 2.
  • a nozzle can be installed at the outlet of the tube, to accelerate the oxidizing gas to a speed greater than the maximum speed of propagation of the flame, to avoid a flashback in the tube.
  • one or more other nozzles can be placed upstream of the outlet nozzle, to resist any backfire.
  • the flow rate of the oxidizing gas through the tube (which has sufficient mechanical strength) is high enough for the speed of the gas to be greater than the maximum speed of propagation of the flame likely to be at the level of the well. injection, it is not necessary to use nozzles accelerating the oxidizing gas.
  • nozzles can be in the form of a straight bore, or they can be of a venturi type, such as that shown in FIG. 5, intended to avoid cracks in contact with oxygen which would reduce the resistance mechanical, and to prevent any backfire in the tube.
  • it is relatively resistant to corrosion.
  • a tube with a diameter of 50.8 mm, nomenclature 80 is used (that is to say a tube having an external diameter of 60.31 mm and an internal diameter of 49.21 mm, the spacing of its walls being 5.5 mm), for its mechanical strength, because it has a free length of 550 m.
  • a venturi nozzle is placed at the bottom, at the injector outlet. As additional security, another nozzle is placed upstream.
  • the injector is designed, for example, for an oxygen flow rate of 84,950 m 3 / day under a pressure of 31.5 kg / cm 2 at ambient temperature.
  • the groove of the venturi nozzle has a diameter of about 11.4 mm, which allows the oxidizing gas to '' have a speed of 30.5 m / s, a speed which is higher than any flame propagation speed that can be encountered at the bottom of an injection well or an oxygen pipe.
  • the outlet orifice (s) of the injector may be in the form of one or more holes. Each hole must be dimensioned so as to give the oxidizing gas injected a speed greater than the maximum flame propagation speed that can be encountered.
  • the downhole injector can only be used for oxidizing gas or a mixture of gases, or it can be used alternately with water injection, intermittently.
  • it can be used for the oxidizing gas and the mixture of gases with the other injected fluids (for example H 2 0 and / or air), injected into the formation by another injection well.
  • the other injected fluids for example H 2 0 and / or air
  • water, air or other fluids need not be free of hydrocarbons (e.g. petroleum).
  • all the fluids intended for the injection well must be injected into the formation using only this single injector, all the fluids must be free of petroleum, in particular when the oxidizing gas is oxygen.
  • the invention is characterized by the introduction, defined in a strategic manner, of oxygen instead of air as a gas promoting combustion; by oxygen is meant here an oxygen having a volume concentration of 90% (under normal conditions), or more, and preferably a concentration of at least 99.5%.
  • the theoretical scanning efficiency which can be obtained with oxygen is about 45 to 50%, which is considerably lower than when using air. Indeed, there is less nitrogen ballast and a higher partial pressure of C0 2 in the oxygen combined with the coke. There is more C0 2 in the oil, which decreases its viscosity, increases the production rate and decreases the entrainment of nitrogen in the production well. It is difficult to dissolve the emulsion that forms at the production well when using air as the combustion promoting gas. When using oxygen, the emulsion formed is easier to dissolve.
  • the product leaving the production well, when using air contains petroleum and sand, water, gas, C0 2 and nitrogen, a little methane, a little hydrogen and a little sulfur.
  • the tube must simply have sufficient mechanical strength to withstand the forces applied during its installation, and its outlet orifice must be suitably shaped so as to withstand the temperatures to which it may be exposed.
  • the tube When, for example, the duct is installed in front of the flame front, the tube can be protected by a jacket of water or thick cement. There must always be a flow of fluid through the tube, in the same way as in the injection well, to avoid any backflow in the conduit.
  • the extreme flexibility of using a pipe of this type for injecting oxygen is clear from the description above.
  • conduits can go up to levels below which water is injected into the injection well in the case of wet combustion.
  • oxygen can be introduced near the bottom of the oil deposit or at intermediate points.

Landscapes

  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Mining & Mineral Resources (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Fluid Mechanics (AREA)
  • Environmental & Geological Engineering (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Physics & Mathematics (AREA)
  • Fats And Perfumes (AREA)
  • Lubricants (AREA)
  • Air Supply (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
  • Processing Of Solid Wastes (AREA)
  • Removal Of Floating Material (AREA)
  • Gasification And Melting Of Waste (AREA)
EP82401680A 1981-09-18 1982-09-16 Procédé et installation de récupération du pétrole par combustion in situ Expired EP0075515B1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
AT82401680T ATE16624T1 (de) 1981-09-18 1982-09-16 Verfahren und vorrichtung zur oelgewinnung durch verbrennung an ort und stelle.

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
CA000386166A CA1206411A (en) 1981-09-18 1981-09-18 Oil recovery by in situ combustion
CA386166 1981-09-18

Publications (2)

Publication Number Publication Date
EP0075515A1 EP0075515A1 (fr) 1983-03-30
EP0075515B1 true EP0075515B1 (fr) 1985-11-21

Family

ID=4120987

Family Applications (1)

Application Number Title Priority Date Filing Date
EP82401680A Expired EP0075515B1 (fr) 1981-09-18 1982-09-16 Procédé et installation de récupération du pétrole par combustion in situ

Country Status (9)

Country Link
US (1) US4557329A (no)
EP (1) EP0075515B1 (no)
AT (1) ATE16624T1 (no)
BR (1) BR8205528A (no)
CA (1) CA1206411A (no)
DE (1) DE3267617D1 (no)
EG (1) EG16308A (no)
NO (1) NO162091C (no)
OA (1) OA07214A (no)

Families Citing this family (12)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4691773A (en) * 1984-10-04 1987-09-08 Ward Douglas & Co. Inc. Insitu wet combustion process for recovery of heavy oils
CA1289868C (en) * 1987-01-13 1991-10-01 Robert Lee Oil recovery
US6296453B1 (en) * 1999-08-23 2001-10-02 James Layman Production booster in a flow line choke
US6708763B2 (en) * 2002-03-13 2004-03-23 Weatherford/Lamb, Inc. Method and apparatus for injecting steam into a geological formation
CN1993534B (zh) * 2004-06-07 2011-10-12 阿克恩科技有限公司 油田改进的就地燃烧工艺
US7817757B2 (en) * 2006-05-30 2010-10-19 Fujitsu Limited System and method for independently adjusting multiple offset compensations applied to a signal
US8127842B2 (en) * 2008-08-12 2012-03-06 Linde Aktiengesellschaft Bitumen production method
US8256537B2 (en) * 2009-02-16 2012-09-04 John Adam Blasting lateral holes from existing well bores
CA2709241C (en) * 2009-07-17 2015-11-10 Conocophillips Company In situ combustion with multiple staged producers
CA2713703C (en) * 2009-09-24 2013-06-25 Conocophillips Company A fishbone well configuration for in situ combustion
CN112196505A (zh) * 2020-09-04 2021-01-08 中国石油工程建设有限公司 一种油藏原位转化制氢系统及其制氢工艺
CN115075790A (zh) * 2021-03-15 2022-09-20 中国石油天然气股份有限公司 火驱油层燃烧状态的判断方法

Family Cites Families (17)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CA739768A (en) * 1966-08-02 Pan American Petroleum Corporation Underground combustion method
US3007520A (en) * 1957-10-28 1961-11-07 Phillips Petroleum Co In situ combustion technique
US2999539A (en) * 1957-11-07 1961-09-12 Phillips Petroleum Co In situ combustion process
US2994375A (en) * 1957-12-23 1961-08-01 Phillips Petroleum Co Recovery of hydrocarbons by in situ combustion
US2994376A (en) * 1957-12-27 1961-08-01 Phillips Petroleum Co In situ combustion process
US2994377A (en) * 1958-03-24 1961-08-01 Phillips Petroleum Co In situ combustion in carbonaceous strata
US3150715A (en) * 1959-09-30 1964-09-29 Shell Oil Co Oil recovery by in situ combustion with water injection
US3208519A (en) * 1961-07-17 1965-09-28 Exxon Production Research Co Combined in situ combustion-water injection oil recovery process
US3171479A (en) * 1962-04-30 1965-03-02 Pan American Petroleum Corp Method of forward in situ combustion utilizing air-water injection mixtures
US3272261A (en) * 1963-12-13 1966-09-13 Gulf Research Development Co Process for recovery of oil
FR1473669A (fr) * 1966-03-31 1967-03-17 Deutsche Erdoel Ag Procédé pour l'épuisement intégral des gisements de pétrole
US3438437A (en) * 1966-07-11 1969-04-15 Carl Edward Christofferson Convector type heat exchanger
US3441083A (en) * 1967-11-09 1969-04-29 Tenneco Oil Co Method of recovering hydrocarbon fluids from a subterranean formation
CA1034485A (en) * 1976-02-02 1978-07-11 Bradford C. White Tar sands gasification
DE2615874B2 (de) * 1976-04-10 1978-10-19 Deutsche Texaco Ag, 2000 Hamburg Anwendung eines Verfahrens zum Gewinnen von Erdöl und Bitumen aus unterirdischen Lagerstätten mittels einer Verbrennungfront bei Lagerstätten beliebigen Gehalts an intermediären Kohlenwasserstoffen im Rohöl bzw. Bitumen
US4099567A (en) * 1977-05-27 1978-07-11 In Situ Technology, Inc. Generating medium BTU gas from coal in situ
US4418751A (en) * 1982-03-31 1983-12-06 Atlantic Richfield Company In-situ combustion process

Also Published As

Publication number Publication date
NO823162L (no) 1983-03-21
NO162091B (no) 1989-07-24
ATE16624T1 (de) 1985-12-15
OA07214A (fr) 1984-08-31
DE3267617D1 (en) 1986-01-02
EG16308A (en) 1991-06-30
US4557329A (en) 1985-12-10
NO162091C (no) 1989-11-01
CA1206411A (en) 1986-06-24
EP0075515A1 (fr) 1983-03-30
BR8205528A (pt) 1983-08-30

Similar Documents

Publication Publication Date Title
EP0075515B1 (fr) Procédé et installation de récupération du pétrole par combustion in situ
CN102348866B (zh) 流体的注入
US8794321B2 (en) Combustion thermal generator and systems and methods for enhanced oil recovery
RU2263774C2 (ru) Способ получения углеводородов из богатой органическими соединениями породы
US4366864A (en) Method for recovery of hydrocarbons from oil-bearing limestone or dolomite
FR2621350A1 (fr) Methode d'exploitation de gisements renfermant de l'hydrogene sulfure
US20100181069A1 (en) Apparatus and method for downhole steam generation and enhanced oil recovery
MXPA06014207A (es) Proceso mejorado de combustion de campo petrolero en el lugar de origen.
NO312481B1 (no) Fremgangsmåter for utvinning av hydrokarboner fra underjordiske formasjoner
RU2060378C1 (ru) Способ разработки нефтяного пласта
RU2602857C2 (ru) Обсадной хвостовик для подземной газификации угля
FR2492452A1 (fr) Procede pour assister la recuperation de petrole dans une formation petrolifere
JP2014502322A (ja) ハイドレートからメタンガスを回収するｉｎＳｉｔｕの方法
RU2444619C1 (ru) Способ извлечения сжиженного или газифицированного углеводорода из подземного углеводородного коллектора (варианты)
CN108026766A (zh) 用于重油采收的移动注入重力泄油
FR2723980A1 (fr) Procede de traitement d'une formation souterraine par agrandissement de fractures
RU2391497C1 (ru) Способ разработки месторождения высоковязкой нефти
US9115579B2 (en) Apparatus and method for downhole steam generation and enhanced oil recovery
FR2497267A1 (fr) Procede d'exploitation miniere d'un gisement de petrole avec injection d'un caloporteur, et produit extrait par ledit procede
CN104594864A (zh) 一种火烧油层开采厚层油藏的方法
CN104632177A (zh) 一种无井式煤炭地下气化系统及工艺
RU2403382C1 (ru) Способ разработки месторождения высоковязкой нефти
EP0229434B1 (fr) Procédé concernant l'amélioration du conditionnement des agents gazéifiants utilisés dans les procédés de gazéification souterraine du charbon
RU2317407C1 (ru) Способ эксплуатации скважины
RU2421609C1 (ru) Способ разработки месторождения высоковязкой нефти

Legal Events

Date Code Title Description
PUAI Public reference made under article 153(3) epc to a published international application that has entered the european phase

Free format text: ORIGINAL CODE: 0009012

17P Request for examination filed

Effective date: 19820920

AK Designated contracting states

Designated state(s): AT BE CH DE FR GB IT LI LU NL SE

ITF It: translation for a ep patent filed

Owner name: BARZANO' E ZANARDO MILANO S.P.A.

GRAA (expected) grant

Free format text: ORIGINAL CODE: 0009210

AK Designated contracting states

Designated state(s): AT BE CH DE FR GB IT LI LU NL SE

REF Corresponds to:

Ref document number: 16624

Country of ref document: AT

Date of ref document: 19851215

Kind code of ref document: T

REF Corresponds to:

Ref document number: 3267617

Country of ref document: DE

Date of ref document: 19860102

PLBE No opposition filed within time limit

Free format text: ORIGINAL CODE: 0009261

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: NO OPPOSITION FILED WITHIN TIME LIMIT

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: LU

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 19860930

26N No opposition filed
PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: BE

Payment date: 19900814

Year of fee payment: 9

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: CH

Payment date: 19900815

Year of fee payment: 9

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: SE

Payment date: 19900816

Year of fee payment: 9

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: LU

Payment date: 19900828

Year of fee payment: 9

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: NL

Payment date: 19900930

Year of fee payment: 9

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: SE

Effective date: 19910917

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: LI

Effective date: 19910930

Ref country code: CH

Effective date: 19910930

Ref country code: BE

Effective date: 19910930

BERE Be: lapsed

Owner name: CANADIAN LIQUID AIR LTD AIR LIQUIDE CANADA LTEE

Effective date: 19910930

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: NL

Effective date: 19920401

NLV4 Nl: lapsed or anulled due to non-payment of the annual fee
REG Reference to a national code

Ref country code: CH

Ref legal event code: PL

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: FR

Payment date: 19920807

Year of fee payment: 11

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: AT

Payment date: 19920811

Year of fee payment: 11

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: GB

Payment date: 19920814

Year of fee payment: 11

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: DE

Payment date: 19920819

Year of fee payment: 11

ITTA It: last paid annual fee
PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: GB

Effective date: 19930916

Ref country code: AT

Effective date: 19930916

GBPC Gb: european patent ceased through non-payment of renewal fee

Effective date: 19930916

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: FR

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 19940531

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: DE

Effective date: 19940601

REG Reference to a national code

Ref country code: FR

Ref legal event code: ST

EUG Se: european patent has lapsed

Ref document number: 82401680.2

Effective date: 19920408