WO2012166251A1 - Intégration de processus de récupération d'huile visqueuse - Google Patents

Intégration de processus de récupération d'huile visqueuse Download PDF

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Publication number
WO2012166251A1
WO2012166251A1 PCT/US2012/033325 US2012033325W WO2012166251A1 WO 2012166251 A1 WO2012166251 A1 WO 2012166251A1 US 2012033325 W US2012033325 W US 2012033325W WO 2012166251 A1 WO2012166251 A1 WO 2012166251A1
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WIPO (PCT)
Prior art keywords
sdrp
solvent
vorp
situ
extraction
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Ceased
Application number
PCT/US2012/033325
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English (en)
Inventor
Ivan J. Kosik
Mori Y. Kwan
Olusola B. Adeyinka
James A. Dunn
Brian C. Speirs
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ExxonMobil Upstream Research Co
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ExxonMobil Upstream Research Co
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Priority to US14/113,798 priority Critical patent/US20140069641A1/en
Publication of WO2012166251A1 publication Critical patent/WO2012166251A1/fr
Anticipated expiration legal-status Critical
Ceased legal-status Critical Current

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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
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G1/00—Production of liquid hydrocarbon mixtures from oil-shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal
    • C10G1/04—Production of liquid hydrocarbon mixtures from oil-shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by extraction
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G1/00—Production of liquid hydrocarbon mixtures from oil-shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal
    • C10G1/04—Production of liquid hydrocarbon mixtures from oil-shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by extraction
    • C10G1/047—Hot water or cold water extraction processes
    • 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
    • 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
    • E21B43/241—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection combined with solution mining of non-hydrocarbon minerals, e.g. solvent pyrolysis of oil shale
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
    • C10G2300/20—Characteristics of the feedstock or the products
    • C10G2300/30—Physical properties of feedstocks or products
    • C10G2300/302—Viscosity
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
    • C10G2300/40—Characteristics of the process deviating from typical ways of processing
    • C10G2300/44—Solvents

Definitions

  • the present disclosure relates generally to viscous oil recovery processes, for example processes for recovering bitumen from oil sands.
  • Oil sands are deposits comprising bitumen, clay, sand, and connate water, and make up a significant portion of North America's naturally-occurring petroleum reserves.
  • bitumen may be extracted from mined oil sands, or recovered using an in situ process.
  • VORP viscous oil recovery process
  • bitumen may be extracted from mined oil sands, or recovered using an in situ process.
  • VORP viscous oil recovery process
  • Commercial in situ VORPs typically exploit at least one of temperature, pressure, and solvent to reduce the viscosity or otherwise enhance the flow of bitumen within the formation.
  • Non-limiting examples of in situ VORPs include CSS (Cyclic Steam Stimulation), SAGD (Steam Assisted Gravity Drainage), SA-SAGD (Solvent Assisted-Steam Assisted Gravity Drainage), VAPEX (Vapor Extraction), LASER (Liquid Addition to Steam for Enhancing Recovery), SAVEX (Combined Steam and Vapor Extraction Process), CSD (Constant Steam Drainage), steam drive, solvent flood, FIRE (Fluidized In situ Reservoir Extraction), and water flooding.
  • An example of CSS is described in U.S. Patent No. 4,280,559 (Best).
  • An example of SAGD is described in U.S. Patent No. 4,344,485 (Butler).
  • An example of SA-SAGD is described in Canadian Patent No.
  • VAPEX 1 ,246,993 (Vogel).
  • VAPEX An example of VAPEX is described in U.S. Patent No. 5,899,274 (Frauenfeld).
  • LASER An example of LASER is described in U.S. Patent No. 6,708,759 (Leaute et al.).
  • SAVEX An example of SAVEX is described in U.S. Patent No. 6,662,872 (Gutek).
  • An example of steam drive is described in U.S. Patent No. 3,705,625 (Whitten).
  • An example of solvent flood is described in U.S. Patent No. 4,510,997 (Fitch).
  • FIRE An example of FIRE is described in U.S. Patent Publication No. 2010/0218954 (Yale et al.).
  • a "VORP” may alternatively comprise the extraction of bitumen from mined oil sand (also referred to herein as a “mining” operation or process).
  • mining also referred to herein as a "mining” operation or process.
  • Oil sand extraction processes are used to liberate and separate bitumen from mined oil sand so that the bitumen can be further processed, for instance to produce synthetic crude oil.
  • Numerous oil sand extraction processes have been developed and commercialized, many of which involve the use of water as a processing medium (referred to as aqueous-based extraction). Other processes are solvent-based processes.
  • One aqueous-based extraction process is the Clark hot water extraction process (the "Clark Process").
  • This process typically requires that mined oil sand be conditioned for extraction by being crushed to a desired lump size and then combined with hot water (e.g. about 95 °C) and perhaps other agents to form a conditioned slurry of water and crushed oil sand.
  • hot water e.g. about 95 °C
  • an amount of sodium hydroxide (caustic) is added to the slurry to adjust the slurry pH upwards, which enhances the liberation and separation of bitumen from the oil sand.
  • Other aqueous-based extraction processes may use other temperatures and may include other conditioning agents, which are added to the oil sand slurry, or may not use a conditioning agent.
  • a bitumen froth stream comprises bitumen, fine particulate solids (also referred to as mineral matter), and water.
  • bitumen fine particulate solids
  • water water.
  • naphtha froth treatment (NFT) processes processes use naphtha to dilute bitumen froth before separating the product bitumen, for instance by centrifugation. These processes are called naphtha froth treatment (NFT) processes.
  • NFT naphtha froth treatment
  • Other processes use a paraffinic solvent, and are called paraffinic froth treatment (PFT) processes, to produce pipelineable bitumen with low levels of solids and water.
  • a paraffinic solvent for example, a mixture of iso-pentane and n- pentane
  • a paraffinic solvent for example, a mixture of iso-pentane and n- pentane
  • a portion of the asphaltenes in the bitumen is also rejected by design in the PFT process and this rejection is used to achieve reduced solids and water levels.
  • the diluted tailings comprising water, solids and some hydrocarbon
  • Recovery of solvent from the diluted bitumen component is currently required before the bitumen may be delivered to a refining facility for further processing.
  • An example of a PFT process is described in Canadian Patent No.
  • Cyclic solvent-dominated recovery processes are a subset of SDRPs.
  • a CSDRP is typically, but not necessarily, a generally non-thermal recovery method that uses a solvent to mobilize viscous oil by cycles of injection and production.
  • Solvent-dominated means that the injectant comprises greater than 50% by mass of solvent or that greater than 50% of the produced oil's viscosity reduction is obtained by chemical solvation rather than by thermal means.
  • One possible laboratory method for roughly comparing the relative contribution of heat and dilution to the viscosity reduction obtained in a proposed oil recovery process is to compare the viscosity obtained by diluting an oil sample with a solvent to the viscosity reduction obtained by heating the sample.
  • a viscosity-reducing solvent is injected through a well into a subterranean viscous-oil reservoir, causing the pressure to increase.
  • the pressure is lowered and reduced-viscosity oil is produced to the surface through the same well through which the solvent was injected. Multiple cycles of injection and production are used.
  • CSDRPs may be particularly attractive for thinner or lower-oil-saturation reservoirs.
  • thermal methods utilizing heat to reduce viscous oil viscosity may be inefficient due to excessive heat loss to the overburden and/or underburden and/or reservoir with low oil content.
  • the family of processes within the Lim et al. references describe embodiments of a particular SDRP that is also a cyclic solvent-dominated recovery process (CSDRP). These processes relate to the recovery of heavy oil and bitumen from subterranean reservoirs using cyclic injection of a solvent in the liquid state which vaporizes upon production.
  • CSPTM processes The family of processes within the Lim et al. references may be referred to as CSPTM processes.
  • one CSPTM process embodiment is described as a single well method for cyclic solvent stimulation, the single well preferably having a horizontal wellbore portion and a perforated liner section.
  • a vertical wellbore (1 ) driven through overburden (2) into reservoir (3) is connected to a horizontal wellbore portion (4).
  • the horizontal wellbore portion (4) comprises a perforated liner section (5) and an inner bore (6).
  • the horizontal wellbore portion comprises a downhole pump (7).
  • solvent or viscosified solvent is driven down and diverted through the perforated liner section (5) where it percolates into reservoir (3) and penetrates reservoir material to yield a reservoir penetration zone (8). Oil dissolved in the solvent or viscosified solvent flows into the well and is pumped by downhole pump through an inner bore (6) through a motor at the wellhead (9) to a production tank (10) where oil and solvent are separated and the solvent is recycled.
  • the present disclosure relates generally to the integration of at least two different viscous oil recovery processes (VORPs), at least one of which is a solvent-dominated recovery process (SDRP). Integration of the SDRP and the VORP may be achieved through at least one of: solvent, heat, a production stream, and a viscous oil reservoir.
  • VORPs viscous oil recovery processes
  • SDRP solvent-dominated recovery process
  • a method of operating at least two different viscous oil recovery processes comprising: operating a solvent dominated recovery process (SDRP); operating a viscous oil recovery process (VORP); and integrating the SDRP and the VORP through at least one of: solvent, heat, a production stream, and a viscous oil reservoir.
  • SDRP solvent dominated recovery process
  • VORP viscous oil recovery process
  • Other aspects and features of the present disclosure will become apparent to those ordinarily skilled in the art upon review of the following description of specific embodiments of the invention in conjunction with the accompanying figures.
  • FIG. 1 is a schematic of a CSP process in accordance Canadian Patent No. 2,349,234 (Lim et al.).
  • Figure 2 is a flow chart outlining the integration of a SDRP with a VORP, according to a disclosed embodiment.
  • viscous oil means a hydrocarbon, or mixture of hydrocarbons, that occurs naturally and that has a viscosity of at least 10 cP (centipoise) at initial reservoir conditions. Viscous oil includes oils generally defined as “heavy oil” or “bitumen”. Bitumen is classified as an extra heavy oil, with an API gravity of about 10° or less, referring to its gravity as measured in degrees on the American Petroleum Institute (API) Scale. Heavy oil has an API gravity in the range of about 22.3° to about 10°. The terms viscous oil, heavy oil, and bitumen are used interchangeably herein since they may be extracted using similar processes.
  • in situ is a Latin phrase for "in the place” and, in the context of hydrocarbon recovery, refers generally to a subsurface hydrocarbon-bearing reservoir.
  • in situ temperature means the temperature within the reservoir.
  • an in situ oil recovery technique is one that recovers oil from a reservoir within the earth.
  • formation refers to a subterranean porous media.
  • the terms “reservoir” and “formation” may be used interchangeably.
  • CSDRP is one type of in situ VORP. Another description of a CSDRP is provided in Canadian Patent Application No. 2,688,392, filed December 9, 2009 (Lebel et al.).
  • solvent-based extraction of mined oil sand is one type of VORP.
  • An example of solvent-based extraction is provided in Canadian Patent Application No. 2,724,806 filed December 10, 2010 (Adeyinka et al.).
  • SDRP solvent-dominated recovery process
  • SDRP and the VORP may be achieved through at least one of: solvent, heat, a production stream, and a viscous oil reservoir.
  • the expression "two different viscous oil recovery processes”, means that the processes are different but may fall within the same category; for instance VAPEX and CSDRP are different processes, but fall within the SDRP category. While the integration may be more beneficial, in certain instances, when the two different processes are close to one another, proximity is not essential.
  • Certain underground viscous oil deposits for instance certain Alberta oil sands, involve naturally occurring thick high oil saturation zones adjacent to lower oil saturation formations.
  • the high oil saturation zones have historically been exploited first using thermal- solvent based in situ recovery methods. Thick high quality and deep deposits, too deep to be mined, are quite often surrounded by thinner and lower quality oil bearing zones. While viscous oil from the thick zones can be economically recovered by using thermal-solvent in situ recovery methods, the same processes would provide uneconomic yields in the thin lower quality zones due to excessive heat loss.
  • non-thermal SDRPs can be employed effectively in many of those poorer quality reservoirs. In the future, SDRP projects may be developed next to existing thermal in situ operations when the poorer quality deposits are accessed.
  • Some operations also produce or consume hydrocarbon solvents, which are purchased at a significant cost. Due to impurity or irregular timing, excess hydrocarbon solvent produced by the recovery operations could be used elsewhere, for instance as boiler fuel. Although this approach does not generate high utilization value for the solvent, it may be preferable to building solvent recovery units and associated storage facilities.
  • Resources targeted by SDRPs include bitumen deposits where thermal recovery operations are not feasible or preferred due to low bitumen saturation or thin resource thickness. It is expected that these relatively marginal resources may often be adjacent to thermal operations exploiting thicker, higher bitumen saturation resources, or adjacent to mining operations exploiting shallow resources. The relatively marginal resources may also be located deeper or shallower than the resource being exploited by the thermal process.
  • a SDRP is integrated with another VORP at the same or a nearby location, while accessing different subsurface resources.
  • One SDRP may also be practiced nearby another SDRP; and to cite but one example, a CSDRP may be integrated with VAPEX.
  • FIG. 2 is a flow chart outlining the integration of a SDRP with a VORP, according to a disclosed embodiment.
  • an SDRP is operated (202)
  • a VORP is operated (204)
  • the two are integrated (206) through at least one of: solvent, heat, a production stream, and a viscous oil reservoir.
  • a SDRP is integrated with a mining operation.
  • a SDRP is integrated with an in situ VORP.
  • a SDRP and in situ VORP are operated on a common reservoir.
  • First category SDRP integrated with a mining operation
  • solvent is shared between a mining process and a SDRP.
  • the mining process uses a solvent (for instance a light hydrocarbon such as propane to hexane to partially or fully de-asphalt bitumen, or naphtha for upgrading).
  • a SDRP injects solvent and recovers solvent and viscous oil.
  • These two processes can share a common solvent source and/or method of transportation, for instance a pipeline network.
  • the processes can also share solvent storage. In this way, facilities are reduced.
  • the solvent recovery unit of a mining process may produce a product stream that does not meet quality specification for the next stage of processing and is recycled through the facility during period of plant upsets.
  • the production stream from a SDRP using a light hydrocarbon solvent may produce a light liquid phase at the early stage of production.
  • This light stream is nearly de-asphalted with pentane-insoluble components removed and has a higher value than bitumen. This quality improvement value is lost if the product is mixed and sold with heavier components such as whole bitumen.
  • a mining process may produce partially or fully de-asphalted bitumen, in this embodiment, the light stream from the SDRP is combined and sold with the mining up-graded stream to take better advantage of its increased product value.
  • the mid- to late-stage production from a SDRP may produce a heavy phase that comprises a higher proportion of pentane-insoluble components than whole bitumen.
  • This heavy stream provides a higher asphalt yield than bitumen and asphalt value peaks during high demand periods.
  • This heavy stream can be combined with the bottom fraction from the de-asphalting facility in the operation to be processed or transported to a nearby facility to maximize asphalt production during peak demand season.
  • the heavy phase can be blended with other streams to be sold as bitumen, sometimes further diluted with a diluent such as a gas condensate.
  • the tailings stream from a froth separation unit in a mining operation may be about 90 °C.
  • the waste heat from the tailings stream may be used in one of more of the following ways:
  • the waste heat may be captured using heat exchangers.
  • 1-D Other Product Sharing Synergy
  • the miscibility of light hydrocarbon solvents with viscous oils can be altered by blending the solvent with higher molecular weight hydrocarbon liquids.
  • De-asphalted or upgraded bitumen from a mining operation can be added to source solvent to be injected into SDRP wells to improve miscibility and increase bitumen recovery.
  • Mining processing byproduct gases such as C0 2 , CH 4 and S0 2 can be added to SDRP solvent and injected to target wells to enhance bitumen and solvent recovery.
  • Mining processing byproduct gas can be used as a gas lift gas for SDRP wells.
  • Blending SDRP and mining bitumen streams can reduce demand for diluent for pipelining when de-asphalted bitumen is blended with heavy components of bitumen as a result of in situ separation of bitumen in SDRP.
  • Second category SDRP integrated with an in situ VORP
  • a common solvent source and transportation system for instance a pipeline network
  • in situ VORP and SDRP needs for instance a common solvent source and transportation system (for instance a pipeline network) is used to meet in situ VORP and SDRP needs.
  • CDRP cyclic SDRP
  • integrating with an in situ VORP operation provides more wells for injecting solvent and more wells as storage for recycling solvent, thus providing more flexibility for scheduling wells for injection and production, especially during the startup phases of both processes.
  • Blending early SDRP production, i.e. the light phase, with an in situ VORP bitumen stream reduces the demand for diluent for pipelining.
  • waste heat from VORP facilities for instance CSS facilities
  • VORP facilities for instance CSS facilities
  • boiler exhaust for instance at 200 °C to 300 °C
  • hot flow-back production stream for instance at 220 °C
  • waste heat from glycol systems for instance 80 °C
  • (b) circulate down a SDRP well via a carrier fluid (for instance glycol, for instance in a slim tube) to heat (for instance to 55 °C) and reduce the viscosity of the production stream from a SDRP to increase production rate;
  • a carrier fluid for instance glycol, for instance in a slim tube
  • An in situ VORP may produce greenhouse gases.
  • greenhouse gases are removed and injected with solvent into SDRP wells.
  • greenhouse gases may be sequestered and SDRP viscous oil and solvent recoveries may be improved.
  • Integrating VORP and SDRP operations may lower the greenhouse gas intensity of the combined operations since SDRP may have a lower greenhouse gas intensity (for instance 10% of the greenhouse gas intensity as compared to a thermal in situ VORP).
  • a single casing gas compression system can be used for both processes when their respective facilities are in close proximity (for instance up to 5 km) to each other.
  • Non-recyclable combustible gases from an SDRP operation can be used to fuel VORP boilers.
  • Non-condensable gases from an in situ VORP operation can be used to pressurize annulus gas or as lift gas in SDRP wells.
  • Various SDRPs can be implemented as a follow-up process to another in situ VORP which may leave a sufficient residual hydrocarbon base to justify the follow-up SDRP.
  • the remnant heat in the VORP reservoirs (for instance up to 120 °C) may provide energy needed to generate vapour solvent for some of the SDRP follow-up operations.
  • VORP displacement methods such as SAGD, SA-SAGD, or steam- flood
  • Some SDRPs such as CSDRPs
  • CSDRPs can be implemented first in viscous oil reservoirs until fluid communication is established between wells and then these wells may be converted to in situ VORP displacement operations.
  • Some in situ VORPs especially the ones that are gravity-stabilized, may have high oil recovery efficiency (for instance greater than 60% of original oil in place).
  • Various in situ VORPs can be implemented as a follow- up process to a SDRP which may leave a sufficient residual hydrocarbon base remaining to justify the implementation of the follow-up operation.
  • the remnant solvent in the SDRP reservoirs (for instance up to 10 volume percent of injected value) may provide the required mobility in the reservoir fluid to effectively carry out the in situ VORP operation without excessive bypassing of the viscous oil related to drive fluid fingering.
  • the at least two processes may be operated simultaneously, consecutively, with overlap, or as a hybrid process, and on the same or separate reservoirs.
  • the CSDRP comprises: (a) injecting a volume of fluid comprising greater than 50 mass % of a solvent, wherein the solvent is a viscosity-reducing solvent, into an injection well completed in the reservoir; (b) halting injection into the injection well and subsequently producing at least a fraction of the injected fluid and the in situ viscous oil from the reservoir through a production well; (c) halting production through the production well; and (d) subsequently repeating the cycle of steps (a) to (c); wherein, in at least one subsequent cycle, an in situ volume of fluid injected in step (a) is equal to a net in situ volume of fluids produced from the production well in an immediately preceding cycle plus an additional in situ volume of the fluid. Immediately after halting injection into the injection well, at least 25 mass % of the injected solvent may be in a liquid state in the reservoir.

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Abstract

La présente invention porte de façon générale sur l'intégration d'au moins deux processus de récupération d'huile visqueuse (VORP), dont au moins l'un est un processus de récupération dominé par un solvant (SDRP). L'intégration du processus de récupération dominé par un solvant et du processus de récupération d'huile visqueuse peut être réalisée par au moins l'un parmi : un solvant, la chaleur, un courant de production et un réservoir d'huile visqueuse.
PCT/US2012/033325 2011-06-02 2012-04-12 Intégration de processus de récupération d'huile visqueuse Ceased WO2012166251A1 (fr)

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US14/113,798 US20140069641A1 (en) 2011-06-02 2012-04-12 Integration of viscous oil recovery processes

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CA2741916A CA2741916C (fr) 2011-06-02 2011-06-02 Integration de processus de recuperaton d'huile visqueuse
CA2,741,916 2011-06-02

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CA2972763C (fr) * 2015-03-04 2019-01-15 Halliburton Energy Services, Inc. Dispositif d'injection et de production actionne par vapeur
CA2912159C (fr) * 2015-11-16 2017-01-03 Chi-Tak Yee Procede employant un gaz, un solvant et la vapeur, et des puits de production horizontaux supplementaires pour ameliorer la recuperation de petrole brut et de bitume
CA2972203C (fr) 2017-06-29 2018-07-17 Exxonmobil Upstream Research Company Solvant de chasse destine aux procedes ameliores de recuperation
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