WO2015000065A1 - Démarrage accéléré de sagd assisté par solvant - Google Patents

Démarrage accéléré de sagd assisté par solvant Download PDF

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Publication number
WO2015000065A1
WO2015000065A1 PCT/CA2014/000546 CA2014000546W WO2015000065A1 WO 2015000065 A1 WO2015000065 A1 WO 2015000065A1 CA 2014000546 W CA2014000546 W CA 2014000546W WO 2015000065 A1 WO2015000065 A1 WO 2015000065A1
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WO
WIPO (PCT)
Prior art keywords
steam
solvent
well
injection
solvent mixture
Prior art date
Application number
PCT/CA2014/000546
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English (en)
Inventor
Mohammed Taha AL-MURAYRI
Thomas Harding
Brij Bhooshan Maini
Javad OSKOUEI
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Nexen Energy Ulc
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 Nexen Energy Ulc filed Critical Nexen Energy Ulc
Priority to CA2917260A priority Critical patent/CA2917260A1/fr
Priority to CN201480046969.0A priority patent/CN105473811A/zh
Priority to CA2952864A priority patent/CA2952864C/fr
Priority to PCT/CA2014/000884 priority patent/WO2016004501A1/fr
Publication of WO2015000065A1 publication Critical patent/WO2015000065A1/fr

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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
    • E21B43/2406—Steam assisted gravity drainage [SAGD]
    • 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

Definitions

  • This relates generally to methods and systems for enhancing hydrocarbon recovery through solvent addition in SAGD operations.
  • SAGD Steam-Assisted Gravity Drainage
  • This invention relates generally to methods and systems for injecting solvent during the early phase (e.g. during the "start-up phase") of a SAGD or SAGD-related operation.
  • the injection and production wells are heated by steam circulation to reduce the viscosity of the oil (vvliich is generally in the form of bitumen) in the inter-well zone and to establish fluid cornmunication between the injection and the production wells.
  • vvliich is generally in the form of bitumen
  • the bitumen may be sufficiently mobilized to allow it to flow and subsequent stages of the SAGD operation, such as ramp-up, can begin.
  • the injection of steam and solvent together during the start-up phase of a SAGD operation accelerates the establishment of fluid communication between the injection and production wells in viscous hydrocarbon-containing formation of limited fluid mobility. The earliest possible establishment of inter-well communication in turn allows for better overall performance of a SAGD operation.
  • a method for recovering hydrocarbons from a reservoir such as a low mobility reservoir.
  • the reservoir is intersected by one or more horizontal wells, referred to as injection wells and production wells that are spaced apart vertically.
  • a steam-solvent mixture may be injected into the injection well when there is no substantial inter- well fluid communication between the injection well and the production well placed vertically below it.
  • the steam-solvent mixture is circulated for a time sufficient for the bitumen in the inter-well region to be mobilized. Mobilized hydrocarbons can then be recovered from the production well.
  • circulation may be discontinued for a period of time, before further injection of either steam alone or a mixture of steam-solvent is resumed.
  • a steam-solvent mixture may be injected into both the injection well and the production well during start-up.
  • a method of recovering hydrocarbons from a subterranean formation comprising injecting a first steam-solvent mixture into an injection well during the start-up phase of a SAGD operation for a time sufficient to establish inter-well communication, discontinuing injection of the first steam-solvent mixture, injecting a second steam-solvent mixture into the injection well, wherein the solvent in the first steam-solvent mixture has a greater proportion of heavy hydrocarbons or is a heavier solvent compared to the solvent in the second steam-solvent mixture, and recovering hydrocarbons from the production well.
  • the first steam-solvent mixture will be injected during the start-up phase of the SAGD operation, and the second steam-solvent mixture will be injected sometime after at least some inter-well conutnimication between the injection well and the production well has been established. It will be appreciated that the steam-solvent mixtures may also be injected mto the production well during the start-up phase. It will also be appreciated that there may be additional steam-solvents mixtures injected either during start-up or later during the SAGD operation, either intermittently with steam alone or consecutively with each other and that the various steam-solvent mixtures may have different compositions, as dictated by the SAGD operation or the phase of the SAGD operation.
  • a method for establishmg mter-well communication in a viscous hydrocarbon-containing formation comprising injecting a first steam- solvent mixture into an injection well while simultaneously injecting a second steam- solvent mixture into a production well, the solvent in the second steam-solvent mixture comprising a higher proportion of light hydrocarbons or a lighter solvent compared to the solvent in the first steam-solvent mixture,
  • FIG. 1 illustrates a conventional steam assisted gravity drainage system
  • FIG. 2 shows a graph of cumulative oil production versus cumulative injected steam when various concentrations of cracked naphtha are injected into a model system according to one embodiment.
  • FIG. 3 shows a graph of oil drainage rate versus time when various concentrations of cracked naphtha are injected into a model system according to one embodiment.
  • FIG. 4 shows a graph of cumulative oil production versus cumulative injected steam when, various concentrations of gas condensate are injected into a model system according to one embodiment.
  • FIG. 5 shows a graph of oil drainage rate versus time when various concentrations of gas condensate are injected into a model system according to one embodiment, DETAILED DESCRIPTION
  • Heavy oil includes oils which are classified by the American Petroleum Institute (API), as heavy oils, extra heavy oils, or bitumens.
  • “Heavy oil” includes asphaltic, dense (low API gravity), and viscous oil that is chemically characterized by its content of asphaltenes. Although variously defined, the limits for heavy oils have been set at API gravity of 22° or lower and a viscosity of more than 100 cP. Once the viscosity of heavy oils is decreased for example by using steam-based processes, their mobility increases. Once the hydrocarbons are mobilized, they can be recovered using substantially gravity- controlled processes.
  • Bitumen is a naturally occuning heavy oil material. Generally, bitumen is the hydrocarbon component found in oil sands.
  • Bitumen can vary in composition depending upon the degree of loss of more volatile components. It can vaiy from a very viscous, tarlike, semi-solid material to solid forms.
  • the hydrocarbon types found in bitumen can include aliphatics, aromatics, resins, and asphaltenes, Bitumen is mined and recovered from oil sands deposits in, for example, the Athabasca area of Alberta and in countries such as Venezuela.
  • Cyclic recover ⁇ ' process or “cyclic process” refers to the steam and/or steam/solvent mixture and/or steam/solvent/gas mixture being injected into a reservoir on a periodic or intermittent basis. For example, injections may be altered depending on the extent or recovery. It is also noted that for any SAGD process, there may be multiple mechanisms, in addition to gravity drainage, that contribute to recovery, and that the inventions described herein are not intended to be limited to recovery processes that are based entirely on gravity drainage.
  • Intermittent injection refers to a process wherein either steam alone, solvent alone, or a steam-solvent mixture can be injected and then, injection can be stopped for a period of time before being resumed and that when injection is resumed, either steam alone, solvent alone, or a steam-solvent mixture can be injected.
  • This invention relates to the timing of solvent addition during a SAGD operation, and it is contemplated that solvent addition will occur during the start-up phase of a SAGD operation.
  • variations wherein steam is first injected, wherein solvent is injected alone, wherein solvent is injected as a steam-solvent mixture (e.g. co-injection), and wherein solvent may also be injected at a later stage of a SAGD operation are all included within the scope of this invention, provided that solvent addition occurs at least during the start-up phase of the SAGD operation.
  • Start-up phase of a SAGD operation refers to the start or initiation of a SAGD operation.
  • substantial inter-well communication has been not been established.
  • the hydrocarbons in the reservoir are not yet mobile.
  • steam chamber growth is initiated, but there is little or no substantial steam chamber formed er se.
  • start-up phase of a SAGD operation may also be referred to as the circulation phase.
  • start-up phase and circulation phase are intended to have the same meaning and this disclosure is intended to any process for which solvent is added early in the SAGD operation, before inter-well communication has been established and at least before the time that production of hydrocarbons has occurred.
  • volume of solvent or "vol%" solvent refers to the volume of solvent per total steam plus solvent volume on a cold liquid equivalent basis.
  • SCIS solvent co-injection with steam
  • Viscos hydrocarbon-containing formation means a subterranean formation containing oils of high viscosity and which are largely incapable of being recovered without the use of heat or dilution.
  • An example of a viscous hydrocarbon-containing formation is an oil sands reservoir with bitumen.
  • the start-up phase of a SAGD operation is performed to establish thermal and hydraulic communication between SAGD injection and production wells.
  • the reservoir contains cold bitumen of high viscosity and limited mobility so that there is no fluid communication between the injection and production wells.
  • the start-up phase may include circulating steam through one or both the injection and production wells, thereby establishing inter-well communication.
  • the time required to establish fluid communication is reservoir and well-pair dependent, but relates to factors such as injector-to-producer well separation along the horizontal well length, injected steam temperatures and reservoir pressures at which circulation is maintained. Typical steam circulation time is around 120 days, but may be shorter or longer.
  • the ramp-up phase of a SAGD operation generally refers to a period of time after communication has been established between the SAGD injection and production wells.
  • the steam chamber has already been established, and grows vertically up to the top of the bitumen zone, Mobilized oil and water are removed from the production well. The entire length of the well pair eventually becomes heated and oil production rates peak.
  • Conventional or normal SAGD operation refers to the phase after the ramp-up phase. During this phase, the steam chamber has essentially reached almost maximum vertical height and continues to extend laterally. The oil production rates are steady or possibly start to decline.
  • Blow-down operations refers to a phase wherein steam injection is terminated and often, a non-condensable gas m injected into the steam chamber to maintain pressure. Oil production rates decline over time and eventually the operation becomes uneconomic. Thereafter, the SAGD well pairs may be abandoned.
  • the present invention relates to methods and systems for enhancing the recovery of hydrocarbons such as heavy oil through solvent injection during the initial or so-called start-up phase of SAGD and SAGD-related operations,
  • solvent injection with steam during the start-up phase of a SAGD operation increases oil recovery and reduces cumulative steam-to-oil ratio (SO ) relative to a SAGD operation in which there has been no solvent addition during the start-up phase of SAGD.
  • SO cumulative steam-to-oil ratio
  • the time required to switch between the startup phase of a SAGD operation to the ramp-up phase of a SAGD-mode of operation is diminished when solvent is added during the start-up phase of a SAGD operation.
  • the more rapid and/or enhanced mobilization of bitumen is due to the combined effects of conduction and dilution by solvent on viscosity of the bitumen in the inter-well zone, and all of these effects are particularly pronounced when solvent is injected as early as possible in the SAGD operation.
  • the use of solvent with steam during the start-up phase of SAGD allows for more uniform fluid development along the length of the wells, This occurs because of greater dilution of bitumen by solvent along the well segments heated to lower temperatures.
  • the timing of solvent injection is important in determining how to optimize the overall efficacy of a SAGD operation, hi many prior art studies, the timing of solvent injection is not injected during the start-up phase of the SAGD operation and/or the solvent is only injected sometime after at least some inter-well communication has been established. Also, in many prior art studies, solvent is added late as after peak oil production rates have been observed. This invention differs from these prior studies in that solvent co-injection with steam is initiated during the start-up phase of SAGD.
  • this invention provides a basis for understanding how the effects of solvent early in a SAGD operation can affect later stages of a SAGD operation, and what operational changes may need to be performed to help optimize the overall SAGD operation, Solvent-steam injection during the start-up phase of a SAGD operation can lead to enhanced solvent recover ⁇ ', lower SORs, and lower production time for hydrocarbon recovery. Moreover, the matching of timing of solvent addition, solvent composition and solvent concentration with the stage of SAGD operation can help improve the overall SAGD operation.
  • heavier or more dense solvents can be added early in a SAGD operation to assist in establishing inter-well commimication.
  • the focus of the SAGD operation is shifted to maximize steam chamber growth and in allowing the solvent to have maximum effect on the surrounding bitumen.
  • the solvent may be changed to lighter or less dense solvents compared to the solvent chosen during the start-up phase of the SAGD operation,
  • Figure 1 shows a conventional SAGD or SCIS operation.
  • the injection of steam 10 into a first horizontal well 20 may result in the mobilization of hydrocarbons 30 mside a formation 40, which is generally a formation consisting of viscous hydrocarbons of limited mobility such as bitumen.
  • the mobilized hydrocarbons may drain to a second horizontal well 50 (also referred to as the production well), and be removed to the surface 60 as a mixed stream 70.
  • the mixed stream 70 may be comprised of hydrocarbons, steam condensate and other materials, such as water, gases, and the like.
  • the mixed stream 70 also includes recovered solvent,
  • the mixed stream 70 from one or more production wells may be combined and sent to a processing facility 80.
  • a processing facility SO various processing operations can occur but generally, the water and hydrocarbons from mixed stream 70 can be separated, and the hydrocarbons 86 sent on for further refining. Water from the separation may be recycled to a steam generation unit within the facility 80, with or without further treatment, and used to generate the steam 10 used for the SAGD operation or SCIS process.
  • solvent may be recovered in the facility 80 and re-used for the SAGD operation or SCIS process. It is useful to use solvent which is produced on-site so as to reduce blending requirements.
  • solvent is added during the start-up phase of a SAGD operation.
  • the solvent is injected as a vapor, along with steam at a time before which there is little or no inter-well communication between the injection and production wells, so that mobilized hydrocarbons fluids cannot be produced.
  • the injection of solvent with steam is expected to reduce the partial pressure of steam slightly, causing a marginal depression in temperature.
  • steam forms a separate liquid phase, and the solvent becomes miscible with bitumen.
  • the condensation of solvent occurs initially by dissolution in the oil phase to achieve local equilibrium.
  • the partial pressure of the solvent becomes higher than its vapour pressure due to condensation of water vapour and/or a reduction in temperature, the solvent condenses and becomes miscible with bitumen.
  • the methods described herein rely on both solvent and thermal benefits to reduce the viscosity of the heavy crude oil or bitumen.
  • the solvent benefits are provided by dilution of bitumen or heavy crude oil through continuous or mtermittent mjection of solvents that are condensable under reservoir operating conditions.
  • first steam-solvent mixture is injected
  • additional steam-solvent mixtures of varying composition or the same composition may be injected into the formation, either continuous with or intermittent with the first steam-solvent mixture, Gas may also be injected.
  • the injection of the first steam-solvent mixture during the startup phase does not limit the solvents that can be used at later stages of the SAGD operation.
  • solvents such as cracked naphtha and gas condensate can be used as the solvent.
  • Figure 2 shows cumulative produced oil when various concentrations of cracked naphtha are injected with steam using a model experimental set-up. Oil production rates peak earlier, and are consistently higher when cracked naphtha is injected along with steam during the start-up phase of the SAGD operation.
  • Figure 4 shows oil production rate when various concentrations of gas condensate are added during the start-up phase of a SAGD operation as modelled in an experimental set-up.
  • Figure 3 shows oil drainage rate versus time when various concentrations of cracked naphtha are injected into a model experimental set-up. Oil drainage rates are higher at earlier times when solvent is co-injected with steam.
  • Figure 5 shows oil drainage rate versus time when various concentrations of gas condensate are injected into a model experimental set-up.
  • solvent recovery is improved, In some cases, solvent recovery can be as high as 72,1% and 99.5% depending on solvent type, concentration and operating strategy. Steam chamber initiation and growth is faster when solvent is added during the start-up phase of SAGD, allowing for more rapid transition to the subsequent phases of the SAGD operation.
  • Co-injecting multi-component solvents with steam early in a SAGD operation provides additional operational flexibility.
  • the volume of solvent in the injected steam can be from about 0, 1 vol% to about 30 vol% of the total volume of the steam-solvent mixture. More particularly, the volume of solvent may be between 5 vol% and 30 vol% of the total volume of the steam-solvent mixture.
  • a variety of solvents can be used in the method and system described herein. The solvent should be chosen based on miscibility in bitumen, availability, cost and thermo-physical properties.
  • the term “heavy solvent” refers to a solvent with a typical boiling range of 177-343 °C and generally includes hydrocarbon liquids in the CIO to C20 range such as kerosene and diesel.
  • Light solvent means a solvent with a typical boiling range of 36-100 °C and generally include hydrocarbon liquids in the C5 to C7 range such as pentane, hexane, cyclohexane and toluene).
  • various combinations of light solvents and heavy solvents could be combined, provided that a light solvent has a higher proportion of light hydrocarbons and a heavy solvent has a Ingher proportion of heavy hydrocarbons.
  • solvents examples include hexane, gasoline, kersosene, naphtha, natural gas condensates, xylene, diesel, benzene, toluene, distallates, C1-C30 hydrocarbons (butane, methane, pentane, etc.) and mixtures thereof, cracked naphtha etc.
  • the solvent may be a single- or multi-component solvent.
  • multi-component solvents are recommended because they provide additional operational flexibility compared to single component solvents, and because from a commercial perspective, they are more readily available and cheaper to obtain compared to single component solvents.
  • Multi-component solvents are better able to account for pressure fluctuations. For example, a multi-component solvent containing hexane and lighter components such as butane can be more effective over a wider range of pressures relative to a single component. Additionally, solvents should be chosen such that asphaltene precipitation is less likely to take place.
  • the solvent is generally between 0.1 - 30 vol% of the total steam-solvent mixture volume,
  • the amount of solvent used is based on oil viscosity at initial conditions, operating pressure, the formation permeability and the composition of solvent.
  • the solvent is injected in the vapor phase and should remain in the vapor phase for a predetermined time before condensing in the reservoir. Once the steam chamber begins to grow (e.g. when the start-up phase is complete and some inter-well communication has been established), the solvent should remain as a vapor withm the steam chamber as the solvent travels towards the bitumen interface.
  • Solvents are chosen that have suitable themiodynamic characteristics, and the amount of solvent is chosen such that the solvent remains in the vapor phase for the appropriate time and condenses at the desired time and place within the reservoir.
  • the present invention allows for operational flexibility of a SAGD process in terms of the timing of solvent addition, and the concentration and type of solvent in accordance with changing reservoir conditions and operational requirements,
  • a heavier solvent is injected along with steam into the injection well during start-up, while simultaneously injecting a lighter solvent in a steam-solvent mixture into the production well.
  • the heavier solvent would tend to diffuse towards to the production well, while the lighter solvent would tend to diffuse towards the injection well.
  • the two solvents would act concertedly to sweep the inter-well zone between the injection and production well, thus allowing for inter-well communication to be more established more quickly during the start-up phase.
  • cracked naphtha and natural gas condensate
  • cracked naphtha generally refers to naphthas that come from refinery processes such as catalytic or thermal cracking or visbreaking.
  • cracked naphtha compositions There are many different cracked naphtha compositions, and a representative sample composition is presented in the Examples.
  • cracked naphtha is high in olefins
  • natural gas condensate may have a variety of compositions depending on the source, but generally has a specific gravity ranging from 0.5 to 0.8 and is composed of hydrocarbons such as propane, butane, pentane, hexane, etc.
  • Gas condensate generally has veiy low viscosity and is frequently used as a diluent to dilute heavier oils to meet pipeline specifications.
  • Whether a solvent is in the vapour phase depends on temperature and pressure conditions in the reservoir.
  • the pressure and temperature should be suitable such that the solvent has maximum niiscibility in bitumen. In practice, this can be achieved by controlling the operating pressure.
  • the optimal pressure that allows for this during the start-up phase is generally the maximum operating pressure of the injection well,
  • the production well will be at reservoir pressure. This will allow for the maximum pressure differential during the start-up phase.
  • the thermodynamic conditions have to be chosen so as allow for maximum solubility of the solvent in bitumen, regardless of the concentration of solvent.
  • Experiment 2 refers to an experiment set-up where only steam was injected using the SAGD injection well to establish a SAGD baseline that could be compared with subsequent SCIS experiments.
  • Experiment 3 refers to the experiment set-up where 10 vol% cracked naphtha combined with steam was used to enhance SAGD performance.
  • Experiment 4 refers to the experiment set-up where 15 vol% cracked naphtha combined with steam is used to enhance SAGD performance.
  • Experiment 5 refers to the experiment set-up where 5 vol% cracked naphtha combined with steam is used to enhance SAGD performance.
  • the cracked naphtha used in Experiments 2 to 5 had the following composition:
  • co-injecting cracked naphtha at the early stages of the SAGD process can potentially accelerate the start-up phase even when only 5 vol% of cracked naphtha is used.
  • the SAGD wells are normally switched from a circulation mode of operation to a SAGD mode of operation when the viscosity in the inter-well region is between 600-1200 cp, and this can be achieved sooner by co-injecting cracked naphtha with steam due to the synergy of heat and mass transfer processes.
  • the experiments also showed that the injection of cracked naphtha with steam allows more oil to be drained using lower amounts of steam. The best performance was achieved using 10 vol% of cracked naphtha.
  • Figure 3 also shows that the impact of solvent addition is more pronounced in the beginning of the drainage process.
  • the slopes of the cumulative produced oil versus cumulative injected steam were nearly the same after 4000 ml of steam injection. Therefore, solvent injection is most effective when initiated early in the process.
  • Figure 2 shows cumulative oil produced versus cumulative injected steam.
  • co-injecting cracked naphtha can extend the economic window of a SAGD operation, by allowing oil drainage to continue at lower steam oil ratios, particularly in the presence steam thief zones such as top water underneath the reservoir overburden, The energy efficiency of the baseline SAGD and cracked naphtha SCIS cases deteriorated with time.
  • Gas condensate is a multicomponent solvent that is to blend produced bitumen to make it suitable for pipeline transportation.
  • Experiment 6 refers to the experiment set-up where 5 vol% gas condensate combined with steam was used to enhance SAGD performance
  • Experiment 7 refers to the experiment set-up where 10 vol% gas condensate combined with steam was used to enhance SAGD performance
  • Experiment 8 refers to the experiment set-up where 15 vol% gas condensate combined with steam was used to enhance SAGD performance.
  • Water and gas condensate were mixed before passing through the pre-heater and steam generator toward the heel of the SAGD injection well.
  • the steam and gas condensate mixture were co-injected into the reservoir using the SAGD injection well. Steam and solvent injection was increased gradually.
  • Gas condensate concentration in the steam-solvent injection ranged from 5-15 vol% of the liquid stream,
  • the produced fluids from Experiments 6, 7 and S were analyzed extensively to evaluate the impact of injecting different amounts of gas condensate on SAGD performance.

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Abstract

L'invention concerne une méthode et un système d'amélioration de la récupération d'hydrocarbures d'un réservoir. La méthode consiste à injecter un mélange vapeur-solvant pendant la phase de démarrage d'un processus de récupération à assistance gravitationnelle, tel qu'une opération de SAGD. En utilisant la méthode de l'invention, les taux de production de pétrole et de solvant peuvent être augmentés tout en diminuant les besoins de vapeur pour l'opération de SAGD lorsque le mélange solvant-vapeur est injecté avant l'établissement d'une communication substantielle entre puits.
PCT/CA2014/000546 2013-07-05 2014-07-07 Démarrage accéléré de sagd assisté par solvant WO2015000065A1 (fr)

Priority Applications (4)

Application Number Priority Date Filing Date Title
CA2917260A CA2917260A1 (fr) 2013-07-05 2014-07-07 Demarrage accelere de sagd assiste par solvant
CN201480046969.0A CN105473811A (zh) 2013-07-05 2014-07-07 加速的溶剂协助sagd启动
CA2952864A CA2952864C (fr) 2013-07-05 2014-12-12 Adjonction de solvant pour ameliorer l'efficacite de la production d'hydrocarbures
PCT/CA2014/000884 WO2016004501A1 (fr) 2014-07-07 2014-12-12 Adjonction de solvant pour améliorer l'efficacité de la production d'hydrocarbures

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US201361843202P 2013-07-05 2013-07-05
US201361843208P 2013-07-05 2013-07-05
US201361843191P 2013-07-05 2013-07-05
US61/843,208 2013-07-05
US61/843,202 2013-07-05
US61/843,191 2013-07-05

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US11021941B2 (en) 2015-11-22 2021-06-01 XDI Holdings, LLC Method, apparatus, and system for enhanced oil and gas recovery with super focused heat
CA2972203C (fr) 2017-06-29 2018-07-17 Exxonmobil Upstream Research Company Solvant de chasse destine aux procedes ameliores de recuperation
CA2974712C (fr) 2017-07-27 2018-09-25 Imperial Oil Resources Limited Methodes ameliorees de recuperation d'hydrocarbures visqueux d'une formation souterraine comme etape qui suit des procedes de recuperation thermique
CA2978157C (fr) 2017-08-31 2018-10-16 Exxonmobil Upstream Research Company Methodes de recuperation thermique servant a recuperer des hydrocarbures visqueux d'une formation souterraine
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CA2952864A1 (fr) 2016-01-14
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CN105518250A (zh) 2016-04-20
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