WO2011029173A1 - Système et procédé pour la récupération assistée de pétrole à partir de procédés de drainage gravitaire par combustion par le haut - Google Patents

Système et procédé pour la récupération assistée de pétrole à partir de procédés de drainage gravitaire par combustion par le haut Download PDF

Info

Publication number
WO2011029173A1
WO2011029173A1 PCT/CA2010/001158 CA2010001158W WO2011029173A1 WO 2011029173 A1 WO2011029173 A1 WO 2011029173A1 CA 2010001158 W CA2010001158 W CA 2010001158W WO 2011029173 A1 WO2011029173 A1 WO 2011029173A1
Authority
WO
WIPO (PCT)
Prior art keywords
reservoir
wells
injection
steam
pressure
Prior art date
Application number
PCT/CA2010/001158
Other languages
English (en)
Inventor
Robert Bruce Bailey
Original Assignee
Excelsior Energy Limited
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 Excelsior Energy Limited filed Critical Excelsior Energy Limited
Publication of WO2011029173A1 publication Critical patent/WO2011029173A1/fr

Links

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
    • E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
    • E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
    • E21B43/2406—Steam assisted gravity drainage [SAGD]
    • E21B43/2408—SAGD in combination with other methods
    • 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

  • COGD combustion overhead gravity drainage
  • the PIHC by developing horizontal and vertical transmissive zones, predisposes a viscous oil reservoir to develop a conformable combustion chamber. Good conformance of the combustion chamber enhances the recovery factor and improves well operations in the field for in-situ combustion applications.
  • In-situ overhead combustion methods are generally known as enhanced recovery techniques for the recovery of hydrocarbons from subterranean high viscosity/low mobility reservoirs. Such reservoirs are known to exist in the tar sand formations of Alberta, Canada and in Venezuela, with lesser deposits existing in the United States. In-situ overhead combustion methods are referred to in the literature as combustion overhead or split stream horizontal processes.
  • In-situ overhead combustion techniques typically utilize an array of vertical air injection wells and vertical gas vent wells positioned high in the reservoir with a horizontal oil production well or drain located lower in the reservoir (See Kisman, K.E. & Lau, E.C., March 1994, A new combustion process utilizing horizontal wells and gravity drainage, The Journal of Canadian Petroleum Technology, volume 33, no. 3, p. 39-45; Canadian Patent No. 2,096,034; and U.S. Patent No. 5,211 ,230).
  • the hydrocarbons in the reservoir are ignited and an oxygen containing gas is supplied via the injection wells to sustain combustion in the reservoir such that the combustion front burns downwards towards the horizontal drain.
  • Overhead combustion techniques typically address the problem of combustion front override that may occur with other in-situ combustion techniques by injecting oxygen containing gas high in the reservoir to support combustion and evacuating melted bitumen and condensed steam from a position low in the reservoir, thereby segregating the gas from the bitumen and water. Since the combustion chamber occupies the top portion of the reservoir and moves downward toward the horizontal drain, the combustion gases can be readily directed toward vent wells located high in the reservoir on the flank of the reservoir segment as the melted bitumen and condensed steam flow downwards under the effect of gravity. The interface between injected air and melted bitumen is maintained by the difference in density between the two substances and by gravity. In normal COGD operations, gases do not typically reach the horizontal drain in large quantities and liquids do not typically flow to the vent wells.
  • reaction kinetics are typically managed by controlling the volume of air injected into the reservoir via the injection wells and controlling the volume of air and combustion gas vented from the reservoir via the producing wells.
  • the evacuation of air and melted bitumen is segregated in overhead combustion processes, it is usually easier to manage the reaction kinetics of an overhead combustion process as the flux of injected gas can be maintained by adjusting the pressure of the reservoir at the injection wells and vent wells without impacting the drainage of melted oil and condensed water at the horizontal drain.
  • conformance of the combustion chamber can be optimized by adjusting pressure at the injection wells and vent wells.
  • the symmetry and/or shape of the combustion chamber is an important factor in improving the overall efficiency of the process. More specifically, in overhead combustion processes, it is desirable to have good conformance of the combustion chamber in order to maximize the displacement of melted bitumen and minimize cycling of injected gases. If cycling of injected gases can be minimized, residence time in the reservoir for combustion gases can be increased. More specifically, residence time in the hot reservoir can provide for complete combustion of flammable gas by-products that would otherwise be produced to the surface as contaminants. Typical flammable gas by-products of in-situ combustion include methane, carbon monoxide and hydrogen sulphide. In addition, it is desirable to minimize the cycling of injected gas due to the impact of gas cycling on the operating costs.
  • a method of preparing a viscous oil bearing reservoir for in-situ overhead combustion by developing transmissive pathways in the reservoir prior to igniting the reservoir wherein the reservoir well network comprises one or more injection wells and one or more vent wells located in the top portion of the reservoir and a horizontal drain located in the bottom portion of the reservoir, wherein the method comprises the steps of:
  • the invention further includes the steps of circulating steam into the horizontal drain to increase oil mobility in the region of the reservoir around the horizontal drain; and injecting steam into the one or more injection wells while shutting in the one or more vent wells and evacuating fluids from said horizontal drain until a vertical transmissive zone is established between the one or more injection wells and the horizontal drain.
  • the steam is injected at a rate that yields a circulating pressure in the reservoir below fracture pressure or, depending on reservoir conditions, the steam is injected at a rate that yields a circulating pressure in the reservoir exceeding fracture pressure.
  • the conformance of the transmissive zones is adjusted by control of injection and drawdown pressures during each step.
  • the lateral transmissive zones enable the combustion chamber to expand laterally through the lateral transmissive zones.
  • the progression of the lateral transmissive zones is indirectly monitored from temperature data obtained from one or more observation wells in contact with the reservoir and/or from pressure communication data derived from pressure readings between the one or more injection wells and the one or more vent wells.
  • steam is circulated between a heel tubing string and a toe tubing string in the horizontal drain to effect heating of the reservoir.
  • progression of the vertical transmissive zone is monitored from pressure communication data derived from pressure readings between the one or more injection wells and the horizontal well.
  • Figure 1 is a perspective schematic view of a typical overhead in-situ combustion well network as described in the prior art
  • Figure 2 is a cross-sectional view of a well network representing a portion of the well network shown in Figure 1 ;
  • Figure 3 is a section view of a well network having horizontal and vertical transmissive paths after a pre-ignition heat cycle has been completed in accordance with the invention
  • Figure 4 is a section view of a well network undergoing a pre-ignition heat cycle in accordance with a first phase of the invention
  • Figure 5 is a section view of a well network undergoing a pre-ignition heat cycle in accordance with a second phase of the invention
  • Figure 6 is a section view of a well network undergoing a pre-ignition heat cycle in accordance with a third phase of the invention.
  • Figure 7 is a section view of a well network undergoing a pre-ignition heat cycle in accordance with a fourth phase of the invention.
  • Figure 8 is a completion design of a vent well and injection well
  • Figures 9A and 9B are representative simulation model outputs showing produced volumes for oil, gas and water during combustion operations for a process using a pre-ignition heat cycle in accordance with one embodiment of the invention ( Figure 9A) as compared to an overhead combustion process as described in the prior art ( Figure 9B); and,
  • Figure 10 is a simulation model output showing cumulative produced volumes of bitumen and oil recovery factors expressed as percent using a pre-ignition heat cycle in accordance with one embodiment of the invention and compared to an overhead combustion process as described in the prior art.
  • PIHC pre-ignition heat cycle
  • Figure 1 shows a well network pattern typically used in gravity-stable overhead in-situ combustion processes as described in the prior art.
  • the overburden has not been shown for ease of reference.
  • the reservoir 1 generally has dimensions of approximately 150 m width, 500 m length and 28 m thickness.
  • the well network includes approximately four vertical injection wells 2, six vertical vent wells 3, a horizontal drain 4 and approximately four vertical observation wells 5. It is understood that the techniques described herein can be applied to overhead combustion systems having different dimensions and well networks as understood by one skilled in the art.
  • Figure 2 shows a section view of the well network from Figure 1.
  • the injection well 2 and vent wells 3 are drilled and completed in the top section of the reservoir 1.
  • the horizontal drain 4 is located in the bottom section of the reservoir and the observation well 5 is drilled and completed in the bottom section of the reservoir.
  • Reference within this description to the injection well, vent well and observation well are understood to include all injection wells, vent wells and observation wells in the well network.
  • the PIHC prepares the low mobility reservoir for ignition in an in-situ overhead combustion process by developing a lateral hot fluid transmissive path 15 in the top section of the reservoir and a vertical hot fluid transmissive path 17 from the top section of the reservoir to the horizontal drain located in the bottom section of the reservoir as shown in Figure 3.
  • the purpose of the lateral hot fluid transmissive path is to provide communication between the injection wells 2 and vent wells 3.
  • the development of a lateral hot fluid transmissive path facilitates the flow of combustion gases between the injection wells and vent wells such that the combustion gases do not flow preferentially to the horizontal drain 4.
  • This segregation allows for greater conformance for the combustion chamber by drawing the combustion front towards the vent wells 3.
  • Operating conditions for the horizontal drain 4 are also improved by the segregation of combustion gas high in the reservoir. Specifically, good reservoir conformance of the combustion chamber enables the combustion front to mobilize the largest possible quantity of melted bitumen and minimize cycling of injected gas.
  • the purpose of the vertical hot fluid transmissive path is to provide communication between the injection well 2 located high in the reservoir and the horizontal drain 4 located low in the reservoir to facilitate the flow of melted bitumen and condensed steam toward the horizontal drain, by means of gravity, during combustion operations. Absent sufficient mobility between the injection well and the horizontal drain, a clear evacuation path is not available for melted bitumen. If melted bitumen cannot drain away from the combustion chamber, air flux may be insufficient to sustain combustion and development and conformance of the combustion chamber will be poor. Therefore the ready evacuation of melted bitumen by gravity drainage allows for the formation of a conformable combustion chamber such that efficient and effective combustion operations can occur.
  • the amount of steam and time required to develop the hot fluid transmissive zone 15 is variable. Primarily, the amount of steam and time required will depend on reservoir quality and fluid saturation where the presence or absence of mobile water in the reservoir may provide a zone of naturally enhanced or decreased mobility in the top section of the reservoir which may minimize or maximize the amount of steam injection required to effect pressure communication.
  • the development of the lateral hot fluid transmissive zone 15 commences.
  • the steam cycling phase that develops the lateral hot fluid transmissive zone also initiates the development of the vertical hot fluid transmissive zone via conduction and convection processes.
  • a steam circulation process 16 is commenced to increase the mobility of the bitumen around the drain. Specifically, steam is circulated into a toe tubing string within the horizontal drain 4 and returned to surface through the heel tubing string of the horizontal drain so as to heat the formation in the region around the drain. Typically, a circulation period of 1-2 months is needed to warm the region around the horizontal drain 4. Ideally, temperatures are monitored by a thermocouple string within the horizontal well and circulation is continued until a sustained well temperature of 150-200°C is achieved.
  • a steam slug 14 is injected to the injection well 2 while the vent wells 3 are shut-in.
  • a steam slug of approximately 6000 m 3 (cold water equivalent) 100 % quality steam at 4000 kPa is used.
  • Steam injection continues until good pressure communication is established between the injection well and the horizontal drain. Pressure communication is monitored at each well by detecting significant pressure changes and/or responses at respective wells. Injection pressures are generally substantially below fracture pressure during this phase due to the increased mobility within the reservoir from the existence of the horizontal transmissive pathway and the preheating of the region between the injection wells 2 and the horizontal drain 4.
  • a vertical hot fluid transmissive zone 17, as shown in Figure 3 is present linking the injection wells 2 and the horizontal drain 4.
  • the vertical hot fluid transmissive zone has saturations and temperatures that are conducive to the flow of melted bitumen and condensed steam toward the horizontal drain by gravity drainage.
  • thermocouples cemented within the observation wells The thermocouples generally allow for indirect measurement of the growth of the transmissive zones in the reservoir, the temperature in the overburden as well as progression of the combustion front after ignition.
  • the data obtained from the thermocouples allows the operator to adjust the pressures at the injection and vent wells to control the growth of the transmissive zones.
  • the steam injected into the vent wells, and injection wells during the PIHC process may be injected at such a rate that the injection pressure exceeds hydraulic fracture pressure. This may be necessary to develop the lateral hot fluid transmissive pathways in a timely fashion in certain reservoirs.
  • the completion design includes a casing string 20 set into the top of the reservoir and cemented in place; a cementing diverter tool 21 located in the casing string 20 to facilitate the cementing of the casing string; a tubing string 22 set into a pay section of the reservoir; a coil tubing string 23 set inside the tubing string 22; a thermal packer 24 set in the casing string 20 to isolate the casing annulus 25 (the space between the casing string 20 and the tubing string 22); a perforated joint 26 located below the thermal packer 24; base pipe wire wrap screen 27 for sand control over the liner 28 that comprises the bottom of the casing string 20; and a stab-in plug 29 to isolate the coil tubing string 23 from the tubing string 22.
  • the principal objectives served by the completion design are: a) good communication of the vent well or injection well with the reservoir section; b) sand control for high temperature cycling operations; c) isolation of the casing annulus 25 from hot corrosive fluids; and d) capacity to lift liquids from below the thermal packer 24 using gas injection in the coil tubing string 23.
  • the surface facilities required for the PIHC cycle are consistent with current cyclic steam operations that can provide for multiphase flow to and from injection wells and vent wells.
  • the PIHC process is used to exploit a zone of naturally enhanced mobility such as is observed in the top of the reservoir section in the Athabasca Oil Sands Region and other fluvial estuarine depositional systems.
  • a zone of enhanced mobility high in the reservoir is commonly observed due to:
  • the PIHC process has been numerically simulated to verify the physical principles of the PIHC and to evaluate the improvements relative to the prior art.
  • a three dimensional (3-D) simulation was prepared to model the PIHC and subsequent in-situ combustion exploitation process.
  • a geological model representative of an actual bitumen reservoir section based on full diameter core, well log and seismic data was used as the base earth model for the simulation (the Earth Model).
  • the reservoir section modelled is characteristic of a well developed, bitumen saturated McMurray sand in the Athabasca Oil Sands Region.
  • the Earth Model included the presence of silt and shale partings and inclined heterolithic strata characteristic of fluvio-estuarine depositional systems.
  • CMG STARS Computer Modelling Group, Calgary, Alberta
  • CMG STARS simulation routines handle many aspects of thermal and compositional reservoir modelling including: thermal, k value composition, chemical reactions, geo-mechanics, and combustion reaction kinetics.
  • Figure 9A shows the results of a simulation in accordance with the invention (base case) whereas Figure 9B shows the results of a simulation in accordance with the prior art (alternate case).
  • the base case realization employs the pre-ignition heat cycle as described in the preferred embodiment. Oil rate, gas rate, gas rate oxygen, water rates and well bottom hole pressure for the horizontal drain are recorded for the base case.
  • Figure 9B presents an alternative realization that employs a pre-ignition heat cycle as described in the prior art by Kisman and Lau, AOSTRA, (CA 2096034).
  • the Kisman process is described as cycling steam from the injection wells to the horizontal drain to form an initial hot fluid transmissive chamber prior to ignition of a combustion overhead process. Oil rate, gas rate, gas rate oxygen, water rates and well bottom hole pressure for the horizontal drain are recorded for the alternate model. All other input variables are maintained to provide a meaningful comparison between the base model and the alternate model.
  • Figure 10 shows the results of simulations in which cumulative volumes of bitumen and bitumen recovery factor expressed as percentage are shown for the base model and alternate model.
  • the base model recovers 244,100 m 3 of bitumen in 10 years representing 65% recovery of the petroleum-initially-in-place.
  • the alternate model recovers 146,000 m 3 of bitumen in 10 years representing 39% recovery of the petroleum-initially-in-place.
  • the higher recovery factor observed in the base model is attributed to the enhanced lateral conformance of the combustion chamber developed as a result of the pre-ignition heat cycle, as described in the preferred embodiment.
  • the absence of the lateral fluid transmissive path in the alternate model has retarded the lateral development of the combustion chamber resulting in poorer recovery performance and increased cycling of injected gas.

Landscapes

  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
  • Combined Controls Of Internal Combustion Engines (AREA)

Abstract

La présente invention concerne un cycle de traitement thermique pré-allumage (PIHC) mettant en œuvre des techniques d'injection de vapeur et de drainage par la vapeur cycliques qui améliorent la récupération d'hydrocarbures visqueux à partir d'un réservoir souterrain au moyen d'une technique de combustion in situ par le haut telle qu'un drainage gravitaire par combustion par le haut (COGD). Le cycle de traitement thermique pré-allumage, grâce au développement de zones de transmission horizontale et verticale, prédispose un réservoir de pétrole visqueux au développement d'une chambre de combustion conforme. La bonne conformité de la chambre de combustion améliore le facteur de récupération et améliore des opérations sur puits sur le terrain pour des applications in situ.
PCT/CA2010/001158 2009-09-11 2010-07-21 Système et procédé pour la récupération assistée de pétrole à partir de procédés de drainage gravitaire par combustion par le haut WO2011029173A1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
CA2678347A CA2678347C (fr) 2009-09-11 2009-09-11 Systeme et methode d'extraction amelioree de petrole a partir des procedes d'ecoulement par gravite des produits de tete de distillation
CA2,678,347 2009-09-11

Publications (1)

Publication Number Publication Date
WO2011029173A1 true WO2011029173A1 (fr) 2011-03-17

Family

ID=41697640

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/CA2010/001158 WO2011029173A1 (fr) 2009-09-11 2010-07-21 Système et procédé pour la récupération assistée de pétrole à partir de procédés de drainage gravitaire par combustion par le haut

Country Status (3)

Country Link
US (1) US20110061868A1 (fr)
CA (1) CA2678347C (fr)
WO (1) WO2011029173A1 (fr)

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN107339089A (zh) * 2017-09-13 2017-11-10 北京军秀咨询有限公司 一种火烧油层段塞加蒸汽驱组合式开采原油的方法

Families Citing this family (13)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB201100549D0 (en) * 2011-01-13 2011-03-02 Statoil Canada Ltd Process for the recovery of heavy oil and bitumen in situ combustion
CN104011331B (zh) 2011-10-21 2017-09-01 尼克森能源无限责任公司 伴加氧的蒸汽辅助重力泄油方法
CA2857211C (fr) * 2012-01-10 2018-09-04 Harris Corporation Production de petrole lourd par prechauffage electromagnetique et injection de gaz
CN104919134B (zh) 2012-05-15 2018-11-06 尼克森能源无限责任公司 用于受损沥青储层的sagdox几何结构
US9970275B2 (en) * 2012-10-02 2018-05-15 Conocophillips Company Em and combustion stimulation of heavy oil
US20140251598A1 (en) * 2013-03-08 2014-09-11 Conocophillips Company Radio-frequency enhancement and facilitation of in-situ combustion
CA2851803A1 (fr) 2013-05-13 2014-11-13 Kelly M. Bell Procede et systeme pour traiter les gaz et les liquides produits par les sables bitumineux
CA2852542C (fr) 2013-05-24 2017-08-01 Cenovus Energy Inc. Recuperation d'hydrocarbures facilitee par une combustion in situ
CA2871569C (fr) 2013-11-22 2017-08-15 Cenovus Energy Inc. Recuperation de chaleur perdue a partir d'un reservoir epuise
CN105971577B (zh) * 2016-07-08 2018-09-04 中国石油天然气股份有限公司 提高火驱注入井与生产井连通性的方法及装置
CN110344798B (zh) * 2019-06-20 2021-08-03 中国石油天然气股份有限公司 一种利用水平排气井改善重力火驱调控的重力火驱方法
CN111810103B (zh) * 2020-07-31 2022-10-04 中国石油天然气股份有限公司 一种利用水平井改善厚层稠油油藏火驱效果的调控方法
CN117740888B (zh) * 2023-12-20 2024-08-06 东北石油大学 一种考虑多因素的剩余油定量评价三维非均质仿真体装置

Citations (9)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3171479A (en) * 1962-04-30 1965-03-02 Pan American Petroleum Corp Method of forward in situ combustion utilizing air-water injection mixtures
US3441083A (en) * 1967-11-09 1969-04-29 Tenneco Oil Co Method of recovering hydrocarbon fluids from a subterranean formation
US4993490A (en) * 1988-10-11 1991-02-19 Exxon Production Research Company Overburn process for recovery of heavy bitumens
US5211230A (en) * 1992-02-21 1993-05-18 Mobil Oil Corporation Method for enhanced oil recovery through a horizontal production well in a subsurface formation by in-situ combustion
CA1323561C (fr) * 1989-07-12 1993-10-26 P. Richard Kry Methode servant a obtenir une conformite areale dans des sables maigres non cimentes
US5456315A (en) * 1993-05-07 1995-10-10 Alberta Oil Sands Technology And Research Horizontal well gravity drainage combustion process for oil recovery
US5860475A (en) * 1994-04-28 1999-01-19 Amoco Corporation Mixed well steam drive drainage process
CA2363909A1 (fr) * 1998-06-24 2003-05-28 World Energy Systems, Incorporated Traitement et recuperation de petrole brut lourd et de bitumes naturels par hydroviscoreduction in situ
US20090188667A1 (en) * 2008-01-30 2009-07-30 Alberta Research Council Inc. System and method for the recovery of hydrocarbons by in-situ combustion

Family Cites Families (9)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CA1085717A (fr) * 1978-05-15 1980-09-16 Karol Sabol Methode de production et d'extraction du gaz a partir d'un depot charbonneux
US4228856A (en) * 1979-02-26 1980-10-21 Reale Lucio V Process for recovering viscous, combustible material
US4422505A (en) * 1982-01-07 1983-12-27 Atlantic Richfield Company Method for gasifying subterranean coal deposits
US4574884A (en) * 1984-09-20 1986-03-11 Atlantic Richfield Company Drainhole and downhole hot fluid generation oil recovery method
US5626191A (en) * 1995-06-23 1997-05-06 Petroleum Recovery Institute Oilfield in-situ combustion process
WO2003036024A2 (fr) * 2001-10-24 2003-05-01 Shell Internationale Research Maatschappij B.V. Procedes et systemes de chauffage in situ d'une formation a base d'hydrocarbures au moyen d'une ouverture en contact avec la surface de la terre au niveau de deux emplacements
RO123558B1 (ro) * 2004-06-07 2013-08-30 Archon Technologies Ltd. Procedeu îmbunătăţit de combustie in situ pe câmpurile petroliere
CA2494391C (fr) * 2005-01-26 2010-06-29 Nexen, Inc. Methodes d'amelioration de la production du petrole brut
CA2631977C (fr) * 2008-05-22 2009-06-16 Gokhan Coskuner Procede thermique in situ de recuperation du petrole de sables bitumineux

Patent Citations (9)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3171479A (en) * 1962-04-30 1965-03-02 Pan American Petroleum Corp Method of forward in situ combustion utilizing air-water injection mixtures
US3441083A (en) * 1967-11-09 1969-04-29 Tenneco Oil Co Method of recovering hydrocarbon fluids from a subterranean formation
US4993490A (en) * 1988-10-11 1991-02-19 Exxon Production Research Company Overburn process for recovery of heavy bitumens
CA1323561C (fr) * 1989-07-12 1993-10-26 P. Richard Kry Methode servant a obtenir une conformite areale dans des sables maigres non cimentes
US5211230A (en) * 1992-02-21 1993-05-18 Mobil Oil Corporation Method for enhanced oil recovery through a horizontal production well in a subsurface formation by in-situ combustion
US5456315A (en) * 1993-05-07 1995-10-10 Alberta Oil Sands Technology And Research Horizontal well gravity drainage combustion process for oil recovery
US5860475A (en) * 1994-04-28 1999-01-19 Amoco Corporation Mixed well steam drive drainage process
CA2363909A1 (fr) * 1998-06-24 2003-05-28 World Energy Systems, Incorporated Traitement et recuperation de petrole brut lourd et de bitumes naturels par hydroviscoreduction in situ
US20090188667A1 (en) * 2008-01-30 2009-07-30 Alberta Research Council Inc. System and method for the recovery of hydrocarbons by in-situ combustion

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN107339089A (zh) * 2017-09-13 2017-11-10 北京军秀咨询有限公司 一种火烧油层段塞加蒸汽驱组合式开采原油的方法

Also Published As

Publication number Publication date
CA2678347C (fr) 2010-09-21
US20110061868A1 (en) 2011-03-17
CA2678347A1 (fr) 2010-02-17

Similar Documents

Publication Publication Date Title
US20110061868A1 (en) System and Method for Enhanced Oil Recovery from Combustion Overhead Gravity Drainage Processes
US20210277757A1 (en) Pressure assisted oil recovery
CA2046107C (fr) Methode de recuperation d'hydrocarbures dans un puits horizontal decale lateralement et verticalement
CA2651527C (fr) Methode et systeme visant a ameliorer un procede de recuperation utilisant un puits de forage horizontal ou davantage
US7422063B2 (en) Hydrocarbon recovery from subterranean formations
US7621326B2 (en) Petroleum extraction from hydrocarbon formations
CA2761321C (fr) Deplacement selectif de l'eau en communication par pression avec un reservoir d'hydrocarbures
US9534482B2 (en) Thermal mobilization of heavy hydrocarbon deposits
MX2012011315A (es) Proceso mejorado de recuperacion por combustion in situ usando pozo horizontal individual para extraer petroleo y gases de combustion hacia superficie.
Temizel et al. Production optimization through intelligent wells in steam trapping in SAGD operations
Strobl Integration of steam-assisted gravity drainage fundamentals with reservoir characterization to optimize production
Ameli et al. Thermal recovery processes
CA3046523C (fr) Systeme et procede de gestion interpuits de drainage par gravite au moyen de vapeur et schema d`optimisation de pseudo-remplissage
Suranto et al. Smart completion design in cyclic steam stimulation process: an alternative for accelerating heavy oil recovery
Chang et al. Numerical simulation of steam-assisted gravity drainage with vertical slimholes
Ito et al. Numerical simulation study of a well in the jacos hangingstone steam pilot project near fort mcmurray
Canbolat et al. Experimental and numerical investigation of mining assisted heavy oil production for the Bati Raman field, Turkey
Siu et al. Modelling steam-assisted gravity drainage process in the UTF pilot project
Sufi A method of alternating steam and water injection for recovering heavy oils
Wu et al. Feasibility of SAGD as a follow-up process to CSS for a massive deep bitumen reservoir
CA2937710C (fr) Installation verticale a production horizontale pour l'extraction de petrole lourd
CA3004235A1 (fr) Mise en place de la profondeur d'un puits de production
Shayganpour Comparison of CSS and SAGD in Cold Lake
CA2809204A1 (fr) Systeme synchronise de production de petrole brut par combustion in situ
Song Steam Injection Strategies for Bitumen Recovery from an Element of the Grosmont Carbonate Reservoir

Legal Events

Date Code Title Description
121 Ep: the epo has been informed by wipo that ep was designated in this application

Ref document number: 10814830

Country of ref document: EP

Kind code of ref document: A1

NENP Non-entry into the national phase

Ref country code: DE

32PN Ep: public notification in the ep bulletin as address of the adressee cannot be established

Free format text: NOTING OF LOSS OF RIGHTS PURSUANT TO RULE 112(1) EPC (EPO FORM 1205A DATED 02/07/2012)

122 Ep: pct application non-entry in european phase

Ref document number: 10814830

Country of ref document: EP

Kind code of ref document: A1