WO2014053912A1 - Procédé de traitement de réservoirs de carbonate - Google Patents

Procédé de traitement de réservoirs de carbonate Download PDF

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Publication number
WO2014053912A1
WO2014053912A1 PCT/IB2013/002620 IB2013002620W WO2014053912A1 WO 2014053912 A1 WO2014053912 A1 WO 2014053912A1 IB 2013002620 W IB2013002620 W IB 2013002620W WO 2014053912 A1 WO2014053912 A1 WO 2014053912A1
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WIPO (PCT)
Prior art keywords
steam
hydrocarbon deposit
acid
wet
water
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PCT/IB2013/002620
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English (en)
Inventor
Jian-Yang Yuan
Qi JIANG
Bruce THORNTON
Kent QIN
John D. Watson
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Osum Oil Sands Corp.
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Publication of WO2014053912A1 publication Critical patent/WO2014053912A1/fr

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    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
    • C09K8/592—Compositions used in combination with generated heat, e.g. by steam injection
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/60—Compositions for stimulating production by acting on the underground formation
    • C09K8/62—Compositions for forming crevices or fractures
    • C09K8/72—Eroding chemicals, e.g. acids
    • 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
    • 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 disclosure relates generally to a method for treating hydrocarbon reservoirs and specifically to a method for altering surface wettability of carbonate reservoirs for improved recovery of heavy oil or bitumen.
  • Non-conventional means include drilling wells and pumping crude oil or natural gas to the surface.
  • Non-conventional means include recovering bitumen and heavy oil, for example by surface mining and in- situ means involving mobilization of the heavy hydrocarbons.
  • In-situ techniques include injecting steam, solvents, a combination of steam and solvents, electrical heating methods, in-situ combustion, water flooding and chemical flooding.
  • thermal recovery examples include Steam Assisted Gravity Drain (“SAGD”), Cyclical Steam Stimulation (“CSS”) and steam flooding.
  • SAGD Steam Assisted Gravity Drain
  • CSS Cyclical Steam Stimulation
  • VAPEX An example of recovery using solvents is the VAPEX process. Recovery by mining is practiced by large surface mines where the hydrocarbon deposit is near the surface. All three methods are practiced in the recovery of heavy oil and bitumen in the Western Canadian Sedimentary Basin.
  • quartz sand is typically a water- wet matrix and this allows reasonably high recovery of bitumen, heavy oil and solvents used in VAPEX and solvent-enhanced SAGD operations. In addition to the recovery of bitumen and incremental bitumen due to the use of solvent, high solvent recovery factors are important since the cost of solvents is typically a large component of overall recovery costs.
  • the reservoir matrix of the Carbonates is known to be oil wet and this can significantly reduce the recovery factor of bitumen and solvents from fractures, vugs and other matrix surfaces, especially in tight matrices, in thermal, solvent or combined thermal-solvent processes.
  • configurations of the present disclosure which are directed to a method for treating hydrocarbon reservoirs and specifically to a method for altering surface wettability of carbonate reservoirs for improved recovery of heavy oil or bitumen.
  • the methods disclosed herein are aimed specifically at oil-wet reservoir matrices such as the Grosmont Carbonates but may be applied to other oil-wet or even water- wet hydrocarbon deposits to improve recovery of residual bitumen and solvents when solvents are used, alone or in combination with steam, to mobilize or assist in mobilizing heavy hydrocarbons.
  • the method disclosed herein comprises adding gases, such as for example, carbon dioxide, sulfur dioxide, nitrogen dioxide and the like, when combined with water provided by steam to form carbonic acid, sulfuric acid, nitric acid and the like.
  • gases such as for example, carbon dioxide, sulfur dioxide, nitrogen dioxide and the like
  • These acidic liquids or vapors are combined with water or steam when the latter is injected into an in-situ recovery operation to mobilize heavy hydrocarbons.
  • the acid-producing gas or gases may be injected separately or in combination with injected steam or in combination with injected solvents or in combination with injected steam and solvents. It is noted that solvents are typically injected in the gaseous or vapor state.
  • the acid-producing gas or gases may be injected at any time during the recovery process. While it is preferable to inject one or more acid-producing gases during the terminal phase of recovery operations, the acid-producing gases may be injected continuously during the recovery process or at selected intervals during the recovery process. As can be appreciated, any of the acid-producing gases can be mixed with water or steam above ground and injected separately as acids in liquid or vapor form into the reservoir.
  • An acid-producing gas may also be referred to as an acid precursor.
  • the concentration of injected acid-producing gas as measured by mass fraction or mass percentage can be 0% to 100%. When no acid-producing gases are being injected, the percentage by injected mass is 0%. When only acid-producing gases are being injected, the percentage by injected mass is 100%.
  • the acid-producing gases will typically remain in the gaseous or vapor state at reservoir pressures and temperatures typical of steam and solvent recovery processes. Therefore the acid-producing gases will tend to fill the entire volume of the portion of the reservoir from which at least some hydrocarbon has been recovered.
  • the acid-producing gases condense or dissolve into liquids, they will tend to adhere to the surfaces of the matrix rock. Acidic fluids are known to react with carbonate rocks such as limestone and dolomite which are typical matrix rocks of the Carbonates and this reaction tends to transform the surfaces from oil-wet towards water- wet. This, in turn, reduces the surface affinities to bitumen and solvents trapped in the pore spaces, vugs and microfractures of the matrix rock where residual bitumen and excess solvents tend to adhere.
  • acid-producing gases are available at in-situ operations, especially carbon dioxide which is generated by steam production facilities and sulfur dioxide which is recovered from, for example, an upgrading process carried out on site. It is believed that acidic vapors or acidic liquids condensed from such vapors will take time to change the surface affinities of oil-wet surfaces. Therefore it is preferred to add acid-producing gases to injected steam whenever steam is used. It is believed that the weak acids formed when the acid-producing gases combine with steam or water will fill the various pore spaces, vugs and micro-fractures of the matrix rock and work over time to change the surface affinity from oil-wet to water-wet. As the reservoir cools, the acidic vapors will condense into acidic liquids and retain their effectiveness.
  • the procedures involved in applying the above acid-producing gas treatments preferably require ongoing knowledge of the effectiveness of the treatment.
  • the procedures therefore preferably require that changes in the condition of the surface wettability be monitored as the process is applied. This may be carried out by monitoring the recovered fluids (gases, water and hydrocarbons) for changes in pH which would indicate that acidic gases were being consumed and therefore changing surface wettability.
  • cased-hole diagnostic systems can be used to determine, for example, changes in formation resistivity and relative amounts of hydrocarbon/water. It is also possible to retrieve matrix rock and fluid samples from time to time from inside a cased observation well. This recovered matrix material allows direct observation of any changes in surface wettability conditions.
  • the acid-producing gases may be injected along with the steam or steam/solvent gases for mobilizing the bitumen or heavy oil. It is also possible to add compressed flue gases to the injected steam or to add carbon dioxide gas recovered from other surface plant processes when available.
  • a method comprising contacting at least one of an acid and acid precursor with a mobilizing agent in a hydrocarbon deposit, whereby a surface wettability of the hydrocarbon deposit before said contacting is altered towards water- wet after said contacting.
  • a method is disclosed to alter surface wettability of a hydrocarbon deposit towards water- wet, comprising 1) providing a first stream
  • a system to alter surface wettability of a hydrocarbon deposit towards water- wet, comprising 1) a first input to receive a first stream comprising a mobilizing agent to mobilize hydrocarbons in a hydrocarbon deposit, 2) a second input to receive a second stream comprising an acid and acid precursor, 3) an injector to inject the first and second streams into the hydrocarbon deposit at a respective first rate and a second rate and 4) at least one sensor to sense at least one of fluids recovered from the hydrocarbon deposit and geological properties of the hydrocarbon deposit to adjust or maintain the first and second rates wherein the surface wettability of the hydrocarbon deposit is altered towards water- wet.
  • a non-transitory computer readable medium having stored thereon computer executable instructions, the computer executable instructions causing a processor of a device to execute a method of altering surface wettability of a hydrocarbon deposit towards water- wet, comprising 1) instructions to provide a first stream comprising a mobilizing agent to mobilize hydrocarbons in a hydrocarbon deposit, 2) instructions to provide a second stream comprising an acid and acid precursor, 3) instructions to inject the first and second streams into the hydrocarbon deposit at a respective first rate and a second rate and 4) instructions to sense at least one of fluids recovered from the hydrocarbon deposit and geological properties of the hydrocarbon deposit to adjust or maintain the first and second rates wherein the surface wettability of the hydrocarbon deposit is altered towards water- wet.
  • each of the expressions "at least one of A, B and C", “at least one of A, B, or C", “one or more of A, B, and C", "one or more of A, B, or C" and "A, B, and/or C" means A alone, B alone, C alone, A and B together, A and C together, B and C together, or A, B and C together.
  • An acid is a chemical substance having the ability to react with bases and certain metals (like calcium) to form salts.
  • acids There are three common definitions for acids: the Arrhenius definition, the Bronsted-Lowry definition, and the Lewis definition.
  • the Arrhenius definition defines acids as substances which increase the concentration of hydrogen ions (H+), or more accurately, hydronium ions (H30+), when dissolved in water.
  • the Bronsted-Lowry definition is an expansion: an acid is a substance which can act as a proton donor. By this definition, any compound which can easily be deprotonated can be considered an acid. Examples include alcohols and amines which contain O-H or N-H fragments.
  • a Lewis acid is a substance that can accept a pair of electrons to form a covalent bond. Examples of Lewis acids include all metal cations, and electron-deficient molecules such as boron trifluoride and aluminium trichloride.
  • Acid-producing gases as used herein are gases such as carbon dioxide, sulfur dioxide, nitrogen dioxide and the like when combined with water provided by steam to form carbonic acid, sulfuric acid, nitric acid and the like. Any acid-producing gas may also be referred to as an acid precursor.
  • An acid precursor or acid-producing gas refers to any type of gas or gaseous mixture which forms an acidic compound when mixed with water.
  • the most common types of acid gases are hydrogen sulfide (H 2 S), sulfur oxides (SOx) (which can form sulfuric acid when mixed with water), nitric oxides ( ⁇ ) (which can form nitric acid when mixed with water), and carbon monoxide (CO) and/or carbon dioxide (C0 2 ) (which can form carbonic acid when mixed with water).
  • Non-volatile media includes, for example, NVRAM, or magnetic or optical disks.
  • Volatile media includes dynamic memory, such as main memory.
  • Computer-readable media include, for example, a floppy disk, a flexible disk, hard disk, magnetic tape, or any other magnetic medium, magneto-optical medium, a CD-ROM, any other optical medium, punch cards, paper tape, any other physical medium with patterns of holes, a RAM, a PROM, and EPROM, a FLASH-EPROM, a solid state medium like a memory card, any other memory chip or cartridge, a carrier wave as described hereinafter, or any other medium from which a computer can read.
  • a digital file attachment to e-mail or other self-contained information archive or set of archives is considered a distribution medium equivalent to a tangible storage medium.
  • the computer-readable media is configured as a database
  • the database may be any type of database, such as relational, hierarchical, object-oriented, and/or the like. Accordingly, the disclosure is considered to include a tangible storage medium or distribution medium and prior art-recognized equivalents and successor media, in which the software implementations of the present disclosure are stored.
  • a carbon sequestration facility is a facility in which carbon dioxide can be controlled and sequestered in a repository such as for example a mature or depleted oil and gas reservoir, an unmineable coal seam, a deep saline formation, a basalt formation, a shale formation, or an excavated tunnel or cavern.
  • a repository such as for example a mature or depleted oil and gas reservoir, an unmineable coal seam, a deep saline formation, a basalt formation, a shale formation, or an excavated tunnel or cavern.
  • CSOR means cumulative steam-oil ratio
  • Dilbit is short for diluted bitumen.
  • dilbit is about 65% bitumen diluted with about 35% naphtha.
  • the naphtha is added to make a fluid that can be transported by pipeline by reducing the viscosity of the bitumen/naphtha mixture.
  • the dilbit can be transported by pipeline to a refinery.
  • the naphtha diluent can be taken out as a straight run naphtha/gasoline and reused as diluent. Or it is processed to products in the refinery.
  • the dilbit has a lot of light hydrocarbons from the diluent and a lot of heavy hydrocarbons from the bitumen. So it is a challenge to process directly in a normal refinery. Dilbit can only be a small part of a normal refinery's total crude slate.
  • condensate can also be used as diluent.
  • a diluent as used herein is a light hydrocarbon that both dilutes and partially dissolves in heavy hydrocarbons.
  • a solvent liquid or vapor is used to reduce viscosity of the heavy oil.
  • An injected solvent vapor expands and dilutes the heavy oil by contact.
  • the diluted heavy oil is then produced via horizontal or vertical producer wells. Diluent and solvent are often used interchangeably in the production of heavy oil and bitumen..
  • Finite-difference methods are numerical methods for approximating the solutions to differential equations using finite difference equations to approximate derivatives.
  • An explicit finite difference code involves calculating the appropriate variables (pressure, density, energy, velocity and the like), then calculating a stable time-step, then advancing the calculation time by that time-step. This process is repeated until the time-limit of the calculation is reached. The calculation is regulated by ensuring that mass, momentum and energy are substantially conserved after each time step. These type of calculations are commonly carried out on a high-performance computer.
  • Imbibition is the process of absorbing a wetting phase into a porous rock. It is possible for the same rock to imbibe both water and oil, with water imbibing at low in-situ water saturation, displacing excess oil from the surface of the rock grains, and oil imbibing at low in-situ oil saturation, displacing excess water. The wettability of the rock is determined by which phase imbibes more.
  • a mobilized hydrocarbon is a hydrocarbon that has been made flowable by some means. For example, some heavy oils and bitumen may be mobilized by heating them or mixing them with a solvent to reduce their viscosities and allow them to flow under the prevailing drive pressure. Most liquid hydrocarbons may be mobilized by increasing the drive pressure on them, for example by water or gas floods, so that they can overcome interfacial and/or surface tensions and begin to flow.
  • a mobilizing agent as used herein is at least one of steam and a solvent.
  • Natural gas refers to a hydrocarbon gas including low molecular weight hydrocarbons, primarily methane.
  • the low molecular weight hydrocarbons commonly include, in addition to methane, ethane, propane, and butane.
  • An observation well may be a vertical well, an inclined well or a horizontal well installed for the purpose of gathering data on a reservoir formation as it is being operated.
  • An observation well is not used for production but can be used to inject tracer materials or retrieve reservoir matrix and fluid samples.
  • An observation well may also be called a monitor well.
  • pH is a measure of the acidity or basicity of an aqueous solution. Solutions with a pH less than 7 are said to be acidic and solutions with a pH greater than 7 are basic or alkaline. Pure water has a pH very close to 7.
  • Pipeline quality natural gas is specified for example by the American Gas
  • Primary production or recovery is the first stage of hydrocarbon production, in which natural reservoir energy, such as gas-drive, water-drive or gravity drainage, displaces hydrocarbons from the reservoir, into the wellbore and up to surface.
  • Production using an artificial lift system, such as a rod pump, an electrical submersible pump or a gas- lift installation is considered primary recovery.
  • Secondary production or recovery methods frequently involve an artificial-lift system and/or reservoir injection for pressure maintenance.
  • the purpose of secondary recovery is to maintain reservoir pressure and to displace hydrocarbons toward the wellbore.
  • Tertiary production or recovery is the third stage of hydrocarbon production during which sophisticated techniques that alter the original properties of the oil are used.
  • Enhanced Oil Recovery can begin after a secondary recovery process or at any time during the productive life of an oil reservoir. Its purpose is not only to restore formation pressure, but also to improve oil displacement or fluid flow in the reservoir.
  • the three major types of enhanced oil recovery operations are chemical flooding, miscible displacement and thermal recovery.
  • a producer is any producer of natural gas, oil, heavy oil, bitumen, peat or coal from a hydrocarbon reservoir.
  • Reforming means fossil fuel reforming which is a method of producing useful products, such as hydrogen or ethylene from fossil fuels.
  • Fossil fuel reforming is done through a fossil fuel processor or reformer.
  • the most common fossil fuel processor is a steam reformer. This conversion is possible as hydrocarbons contain much hydrogen.
  • the most commonly used fossil fuels for reforming today are methanol and natural gas, yet it is possible to reform other fuels such as propane, gasoline, autogas, diesel fuel, methanol and ethanol. During the conversion, the leftover carbon dioxide is typically released into the atmosphere.
  • reforming is the dominant method for producing hydrogen. The produced carbon monoxide can combine with more steam to produce further hydrogen via the water gas shift reaction.
  • Synbit is a blend of bitumen and synthetic crude.
  • Synthetic crude is a crude oil product produced, for example, by the upgrading and refining of bitumen or heavy oil. Typically, synbit is about 50% bitumen diluted with about 50% synthetic crude.
  • Syngas (from synthesis gas) is the name given to a gas mixture that contains varying amounts of carbon monoxide and hydrogen.
  • Examples of production methods include steam reforming of natural gas or liquid hydrocarbons to produce hydrogen, the gasification of coal and in some types of waste-to-energy gasification facilities. The name comes from their use as intermediates in creating synthetic natural gas and for producing ammonia or methanol.
  • Syngas is also used as an intermediate in producing synthetic petroleum for use as a fuel or lubricant via Fischer-Tropsch synthesis and previously the Mobil methanol to gasoline process.
  • Syngas consists primarily of hydrogen, carbon monoxide, and very often some carbon dioxide, and has less than half the energy density of natural gas. Syngas is combustible and often used as a fuel source or as an intermediate for the production of other chemicals.
  • Upgrading means removing carbon atoms from a hydrocarbon fuel, replacing the removed carbon atoms with hydrogen atoms to produce an upgraded fuel and then combining the carbon atoms with oxygen atoms to form carbon dioxide.
  • Vugs are small to medium-sized cavities inside rock that may be formed through a variety of processes. Most commonly cracks and fissures opened by tectonic activity (folding and faulting) are partially filled by quartz, calcite, and other secondary minerals. Open spaces within ancient collapse breccias are another important source of vugs. Vugs may also result when mineral crystals or fossils inside a rock matrix are later removed through erosion or dissolution processes, leaving behind irregular voids. The inner surfaces of such vugs are often coated with a crystal druse. Fine crystals are often found in vugs where the open space allows the free development of external crystal form.
  • vug is not applied to veins and fissures that have become completely filled, but may be applied to any small cavities within such veins.
  • Geodes are a common vug formed rock, although that term is usually reserved for more rounded crystal-lined cavities in sedimentary rocks and ancient lavas.
  • the water-gas shift reaction is a chemical reaction in which carbon monoxide reacts with water to form carbon dioxide and hydrogen.
  • the water-gas shift reaction is often used in conjunction with steam reforming of methane or other hydrocarbons.
  • the water-gas shift reaction is slightly exothermic. The process is often used in two stages, stage one a high temperature shift at 350°C and stage two, a low temperature shift at 190 to 210°C.
  • Well logging is the practice of making a detailed record (a well log) of the geologic formations penetrated by a borehole.
  • the log may be based either on visual inspection of samples brought to the surface (geological logs) or on physical measurements made by instruments lowered into the hole (geophysical logs).
  • Well logging can be done during any phase of a well's history; drilling, completing, producing and abandoning.
  • the oil and gas industry uses wireline logging to obtain a continuous record of a formation's rock properties. These can then be used to infer further properties, such as hydrocarbon saturation and formation pressure, and to make further drilling and production decisions.
  • Wireline logging is performed by lowering a 'logging tool' on the end of a wireline into an oil well (or borehole) and recording petrophysical properties using a variety of sensors.
  • Logging tools developed over the years measure the electrical, acoustic, radioactive, electromagnetic, nuclear magnetic resonance, and other properties of the rocks and their contained fluids.
  • the data itself is recorded either at surface (real-time mode), or in the hole (memory mode) to an electronic data format and then either a printed record or electronic presentation called a "well log" is provided.
  • Well logging operations can either be performed during the drilling process (Logging While Drilling), to provide real-time information about the formations being penetrated by the borehole, or once the well has reached Total Depth and the whole depth of the borehole can be logged.
  • wireline logs There are many types of wireline logs and they can be categorized either by their function or by the technology that they use. Open hole logs are run before the oil or gas well is lined with pipe or cased. Cased hole logs are run after the well is lined with casing or production pipe.
  • Wettability is the preference of a solid to contact one liquid or gas, known as the wetting phase, rather than another.
  • the wetting phase will tend to spread on the solid surface and a porous solid will tend to imbibe the wetting phase, in both cases displacing the non- wetting phase.
  • Rocks can be water- wet, oil-wet or intermediate-wet.
  • the intermediate state between water-wet and oil-wet can be caused by a mixed- wet system, in which some surfaces or grains are water- wet and others are oil-wet, or a neutral-wet system, in which the surfaces are not strongly wet by either water or oil. Both water and oil will wet most hydrocarbon reservoirs in preference to gas. Wettability affects relative permeability, electrical properties, nuclear magnetic resonance relaxation times and saturation profiles in the reservoir.
  • the wetting state impacts waterflooding and aquifer encroachment into a reservoir.
  • a surface is water-wet then the adhesive attraction of the water for the surface is greater than the cohesive attraction of the water molecules for one another.
  • water-wet is also known as hydrophilic or water-loving or oleophobic or oil- hating.
  • oil-wet is also known as oleophilic or oil-loving or hydrophobic or water-hating. Wettability can be quantified by the contact angle that the liquid makes with the contacting surface where the contact angle is measured through the water.
  • Wettability can also be quantified by the "work of cohesion" which is twice the surface tension and the "work of adhesion".
  • CSS means Cyclic Steam Stimulation.
  • steam is injected into the reservoir at rates of the order of 1000 B/d for a period of weeks; the well is then allowed to flow back and is later pumped.
  • the production of oil is rapid and the process is efficient, at least in the early cycles. If the steam pressure is high enough to fracture the reservoir and thus allow injection, it can also be used to produce the very viscous oil of the oil sands at an economic rate.
  • the main drawback of the cyclic steam stimulation process is that it often allows only about 15% to 25% of the oil to be recovered before the oil-to-steam ratio becomes prohibitively low.
  • ESEIEH means Enhanced Solvent Extraction Incorporating Electromagnetic Heating
  • HAGD is an acronym for Heat Assisted Gravity Drainaige.
  • one recovery method being implemented in pilot projects involves the use of resistance heaters and heating elements to raise the temperature of the oil shales so that oil is produced. These methods are being considered for application to both oil sand and carbonate deposits in Alberta. These methods are designed to heat heavy oil and bitumen deposits to mobilize these hydrocarbons for production.
  • Heating of oil sands by electrodes often referred to as a form of HAGD.
  • Direct heating of oil sands by electrically-powered heating elements is another form of HAGD.
  • LASER Liquid Addition to Steam for Enhancing Recovery
  • LASER-CSS means Liquid Addition to Steam for Enhancing Recovery of Cyclic Steam Stimulation
  • N-Solv thermal solvent process
  • SAGD Steam Assisted Gravity Drainaige.
  • SAGD wells or well pairs are drilled from the earth's surface down to the bottom of the oil sand deposit and then horizontally along the bottom of the deposit and then used to inject steam and collect mobilized bitumen.
  • SA-SAGD means Solvent Assisted SAGD
  • SC-SAGD means Solvent-Cyclic SAGD
  • SAP means Solvent Assisted Process
  • SA VES means Solvent Assisted Vapour Extraction with Steam
  • SAVEX Steam and Vapour Extraction process
  • SGS Steam Gas Solvent
  • VAPEX means Vapour Extraction process and is a process which uses a diluent as the fluid injected into the hydrocarbon formation as a mobilizing fluid
  • a reference to solvent herein is intended to include diluent and a reference to diluent herein is intended to include solvent.
  • a reference to heavy hydrocarbons herein is intended to include low API hydrocarbons such as bitumen (API less than -10°) and heavy crude oils (API from -10° to -20°).
  • a reference to oil is understood to include heavy hydrocarbons as well as higher API hydrocarbons such as medium crude oils (API from -20° to -35°) and light crude oils (API higher than -35°).
  • a reference to bitumen is also taken to mean a reference to heavy hydrocarbons.
  • Figure 1 is a schematic of a typical horizontal well pair used in SAGD, VAPEX and various forms of combined steam and solvent processes.
  • Figure 2 illustrates the types of cased-hole logging technologies available for monitoring reservoir parameters associated with surface wettability.
  • Figure 3 is a schematic showing the principal elements of a prior-art bitumen recovery operation using natural gas for power.
  • Figure 4 is schematic of a prior-art thermal recovery power plant using natural gas for power and for capturing C02. (Taken from US Patent Application No. 12/498,895 entitled “Carbon Removal from an Integrated Thermal Recovery Process”).
  • Figure 5 is schematic of a bitumen recovery surface plant wherein flue gases and C02 are available for injection into the reservoir.
  • Figure 6 is an example of a time-line for a cyclical steaming process wherein an acid or acid precursor is injected from time to time during one or more injection intervals.
  • Figure 7 is a schematic of a control and feedback system for applying an acid treatment to a hydrocarbon reservoir.
  • FIG. 1 is a schematic of a typical horizontal well pair used in SAGD, VAPEX and various forms of combined steam and solvent processes. This Figure was taken from US 2011/0120709 published May 26, 2011 entitled “Steam-Gas-Solvent (SGS) Process for Recovery of Heavy Crude Oil and Bitumen”.
  • SGS Steam-Gas-Solvent
  • This configuration of injector wells 30 and recovery wells 35 and variants of them is well-known and is prior art. It is possible to use the injector wells to inject either steam or a steam/solvent mix into the formation. Further, a steam/acid vapor or steam/solvent and acid vapor mix may also be injected into the formation. It is also possible to use separate injector wells to inject acid-producing gas or other forms of acids into the formation.
  • Any acid-producing gas treatment should also act to maintain pressure drive as the steam condenses in the vicinity of the steam chamber front.
  • some acid-gas vapor can condense at the steam chamber front and this will add heat to the steam front.
  • C0 2 dissolves in water forming carbonic acid, which is a weak acid, because C0 2 molecule ionization in water is incomplete.
  • Oxidation of S02 usually in the presence of a catalyst such as N02, forms H2S04.
  • the sequential oxidation of sulfur dioxide followed by its hydration is used in the production of sulfuric acid.
  • Nitrogen dioxide is the chemical compound with the formula NO 2 . It is one of several nitrogen oxides. NO 2 is an intermediate in the synthesis of nitric acid.
  • acids or acid precursors can also be injected to alter surface wettability.
  • acids or acid precursors can also be injected to alter surface wettability.
  • These include, for example, volatile organic acids, such as acetic acid.
  • the mixture brought up by the recovery wells includes water, mobilized bitumen, solvent and various gases such as methane and carbon dioxide. If acid-producing gases are also injected into the formation along with steam and solvent (e.g. the upper well in Figure 1), then some of these gases may be included in the recovered gases.
  • the recovered gases are removed from the recovered mixture before and/or during water/hydrocarbon separation and these gases can be analyzed by known means. If there is a deficit between recovered S0 2 , for example, with the amount injected, then it is known that some SO 2 may have been converted on the exposed surfaces of the reservoir. Water is usually separated out next, as described in Figure 3. This recovered water can be analyzed using known methods to determine its pH which can be compared to the pH of the injected steam or a sample of condensed steam. If the pH of the recovered water is higher (more alkaline) than the injected water in the form of steam, then this is another indicator that the injected acid-producing gases have altered the surface wettability from primarily oil-wet to water- wet or at least to intermediate-wet.
  • diagnostics may be installed in fixed locations (as opposed to moving them such as in a wireline operation) or the diagnostics can be operated as a cased-hole wireline (that is, moved back and forth along the well by a wireline).
  • One or more of these diagnostics may be used to determine changes over time of reservoir parameters that relate to changing amounts of water, hydrocarbon and gas.
  • An observation well may be a vertical well, an inclined well or a horizontal well.
  • the casing of a cased-hole may be made of any number of materials such as, for example, steel, thermal plastic or ceramic.
  • a short section of casing may be made from a suitable thermal plastic, fiberglass or ceramic from which dielectric diagnostics may be operated.
  • Figure 2 illustrates the types of cased-hole logging technologies available for monitoring reservoir parameters associated with surface wettability. These include known cased-hole well logging diagnostics that can measure formation resistivity, dielectric response, formation fluid flow velocity, porosity and relative amounts of salt water, fresh water, hydrocarbons and reservoir gases and the like. It is also common to run cased-hole temperature and noise logs to detect the flow of fluids and differentiate between liquid and gaseous flows. Radioactive tracers can be injected from a cased-hole and detected from within the casing, a technique that can also determine local reservoir fluid flow
  • Reservoir matrix materials and fluid flow samples can also be retrieved with currently available cased-hole tools.
  • This observation well information alone or in combination with analysis of recovered fluids, can be used to determine if the acid-producing gas treatment is having the desired effect of changing surface wettability from oil-wet towards water-wet. This information can then be used to alter the injection schedule, injection composition and injection amounts of acid-producing gases to optimize the process of effect of changing surface wettability from oil-wet towards water- wet.
  • Detailed reservoir response can be calculated using computer codes such as ID, 2D and 3D explicit finite difference codes. These codes are capable of calculating transient response of large volumes of reservoir utilizing hundreds of thousands or millions of computational "zones". These codes will calculate time histories and spatial contour maps and the like for any selected parameter such as, for example, temperature, pressure, density, stress component, energy, velocity, mass flux, phase change and the like.
  • such calculations are organized to match known material and boundary conditions such as, for example, locations of and materials comprising geologic layers in the reservoir, known in-situ pressures (before recovery operations begin), known or estimated features such as porosity distribution, permeability distribution, large fractures and the like.
  • a surface plant In a thermal bitumen recovery operation, a surface plant is built to house the steam generation as well as the recovery fluid separation and treatment facilities. These plants typically use natural gas to power the various operations. As can be appreciated other fuels such as oil and coal, for example, may be used for power generation.
  • fuels such as oil and coal, for example, may be used for power generation.
  • water/hydrocarbon mixtures and fuel and whose outputs are hydrocarbon products, waste water and emissions from burning fuel.
  • captured carbon dioxide may also be an output. Of these outputs, the flue gas emissions from burning fuel are typically released to the atmosphere. If carbon dioxide is captured as a by-product, it may be used for
  • EOR Enhanced Oil Recovery
  • FIG 3 is a schematic showing the principal elements of a prior art bitumen recovery operation using natural gas for power.
  • raw bitumen- water feedstock from a well-pad facility 302 is fed into a bitumen- water separation sequence comprising a Free Water Knock-Out (“FWKO") unit 303.
  • Diluent 306 is added to the raw bitumen-water feedstock to form a pumpable mixture prior to entering the FWKO unit 303.
  • the FWKO unit 303 separates most of the diluent-bitumen mixture ("dilbit").
  • This dilbit mixture is then sent to an oil treatment unit 304 which separates the remaining water from the dilbit.
  • Additional diluent 307 is added to the dilbit product which is then sent to a product storage tank 305, where it remains ready for transport by rail, truck or pipeline 308 to an upgrader.
  • the water from the oil treatment unit 304 is sent to a de-oiling unit 310 for final cleaning of remaining oil residue.
  • the oil residue from the de-oiling unit 310 is returned to the feedstock of the FWKO unit 303.
  • Make-up water 316 from a water well source is added to the de-oiled water and then fed to a series of water treatment apparatuses which purify the water in preparation for making steam.
  • the water treatment apparatuses are often comprised of water softener units 311, walnut filter unit 314 and an ion exchange unit 315.
  • the treated water is fed to steam generators 321 which are used to produce primarily hot, dry steam which is sent to a high-pressure steam separator unit 322.
  • natural gas 323 is used to power the steam generators 321.
  • These steam generators may be large single pass boilers or they may be multi-pass drum steam generators.
  • the combustion products of the fuel burned to power the steam generator 321 is typically released into the atmosphere as flue gases 325.
  • the high pressure steam separator unit 322 compresses the steam from the steam generators 321 and delivers the hot, high-pressure, high-quality steam to the well-pads 302 for injection into the bitumen reservoir 301 where it is used to continue the bitumen mobilization and recovery process. Condensate from the high pressure steam separator unit 322 is handled by a blowdown apparatus 324 and sent to a water disposal well 326.
  • Figure 4 is schematic of a prior art thermal recovery power plant using natural gas for power and for capturing C02. Figure 4 is taken from US Patent Application No.
  • Natural gas fuel 421 is brought into the facility and a substantial fraction of the natural gas is diverted by a gas separator and reformed and water-gas shifted in a carbon extraction plant to eliminate carbon in the form of captured carbon dioxide.
  • the carbon extraction plant delivers clean C0 2 , molecular hydrogen and electrical power.
  • the molecular hydrogen is then mixed by a gas combiner with portion of natural gas not sent to the carbon extraction plant to form a mixed gas fuel which is then used to power steam generators and other apparatuses in the main plant.
  • about 20% to about 60% of the methane by volume of the natural gas is converted into molecular hydrogen.
  • this use of mixed fuel commonly reduces fossil carbon emissions by at least about 20%> and as high as about 60%>.
  • bitumen product is a 19° to 20° API dilbit which is the same as that of the prior art plant described in Figure 3.
  • the raw bitumen- water feedstock from well pads 401 is fed into a bitumen-water separation sequence comprising a Free Water Knock-Out (“FWKO") unit 403.
  • FWKO Free Water Knock-Out
  • bitumen-water feedstock 402 is added to the raw bitumen-water feedstock to form a pumpable mixture prior to entering the FWKO unit 403.
  • the treated hydrocarbon mixture typically, dilbit is sent to a product storage tank 405. Additional diluent 406 is added to the dilbit product so that it can be transported by rail, truck or pipeline 407 to an upgrader.
  • the FWKO unit 403 separates most of the water which is then sent to a de -oiling unit 408 for final cleaning of remaining oil residue.
  • the oil residue from the de -oiling unit 408 is returned to the feedstock of the FWKO unit 403.
  • Make-up water from a water well source 409 for example, is added to the de-oiled water and then fed to a tube evaporator 410 which distills the water in preparation for making steam.
  • Some water is condensed in the tube evaporator 410 and is processed by a blowdown treatment apparatus 415 and then returned to the ground via a water disposal well 416. It is understood that reference to a tube evaporator may mean a rising tube evaporator or a falling tube evaporator since both accomplish the same function in process illustrated.
  • the distilled water from the tube evaporator 410 is fed to the steam drum generators 412 which are used to produce primarily hot dry steam which is sent to a high pressure steam separator unit 413.
  • a mixture of molecular hydrogen and methane (called a mixed gas) are used to power the steam drum generators 412.
  • the primary function of the steam drum generators 412 is to produce high quality steam which is transferred to a high pressure steam separator unit 424.
  • the high pressure steam separator unit 413 compresses the steam from the steam drum generators 412 and delivers the hot, high-pressure, high-quality steam to the underground facility 400 for subsequent use in maintaining temperature and pressure conditions in steam chamber. Water condensate from the high pressure steam separator unit 413 is returned to the tube evaporator 410.
  • the steam is added to the high pressure steam separator 413; the 24 MW of power is used to operate the various units in the carbon extraction plant 414 and the main plant; the C0 2 423 is sold, used for EOR or sequestered; and the recovered hydrogen 426 is mixed with the 26 million standard cubic feet per day of natural gas 421 to produce a high energy gas mix that is used in the burners of the steam drum generators 412.
  • the carbon extraction plant 414 removes a substantial portion of fossil carbon while using slightly less energy to process a barrel of bitumen and produce steam than the prior art plant of Figure 3.
  • Figure 5 is schematic of a bitumen recovery surface plant wherein flue gases and C02 (when produced as a by-product) are available for compression and injection into the reservoir.
  • Bitumen- water feedstock is recovered from hydrocarbon reservoir 501 at well- pads 502.
  • Diluent is added to the bitumen- water and sent to free water knockout apparatus 503 where the bitumen and diluent are separated from the water.
  • bitumen and diluent are sent to a treatment apparatus 504 and then the final plant product is stored in facility 505. From storage the treated bitumen and diluent are shipped out as product 592.
  • the water from free water knockout apparatus 503 is treated in water treatment apparatus 511 before being sent to steam generation facility 525.
  • the output of the steam generation facility 525 is high quality steam which is sent via path 551 and compressed to injection pressure in compressor 541 before being sent to well-pads 502 for injection into reservoir 501.
  • Fuel such as natural gas, for example, is input 591 where it is used to power C0 2 capture plant 53 land steam generator facility 525.
  • the flue gas emissions from burning fuel are output from C0 2 capture plant 53 land combined with the flue gas emissions from burning fuel in steam generation facility 525.
  • These flue gas emissions are then sent via path 552 and compressed to injection pressure in compressor 542 before being sent to well pads 502 for injection into reservoir 501.
  • these flue gases can be vented from time to time to the atmosphere or stored for later compression and injection into the reservoir.
  • Carbon dioxide captured in C0 2 capture plant 531 is also compressed to injection pressure in compressor 543 before being sent via path 553 to well-pads 502 for injection into reservoir 501.
  • this C0 2 can be vented from time to time to the atmosphere before compression or stored for injection into the reservoir or stored for sale as a product for other hydrocarbon recovery operations.
  • the flue gases, C0 2 from the carbon capture plant and/or the acquired acid-producing gases can be injected separately with the steam or steam/solvent mix on a schedule and in an amount as determined by the acid treatment process requirements.
  • the recovered water can be analyzed after the free water knockout process and compared to the water used to make steam in order to determine if the recovered water is consistent with acid-producing gas interaction with the reservoir surfaces. As also described previously, this information and any information obtained from the observation wells can be used to modify the acid-producing gas injection schedule and amounts.
  • Figure 6 is an example of a time-line for a cyclical steaming process wherein an acid or acid precursor is injected from time to time during one or more injection intervals.
  • a CSS, SAGD or steam flooding process there is typically an operational cycle comprising an injection interval 601, a changeover interval 604, a soak interval 602, another changeover interval, a hydrocarbon recovery interval 603 and a final changeover interval.
  • the changeover interval is typically short lasting from several hours to about a day or two.
  • the operation changes from an injection mode to a soak mode or a hydrocarbon recovery mode, or the operation changes from a hydrocarbon recovery mode to an injection mode.
  • each well-pair cycles can be operated separately from other well-pairs or in synchronicity with other well-pairs.
  • Figure 6 is an example of a number of hydrocarbon process cycles that illustrate a short start-up phase, a CSS phase, a SAGD phase and a blow-down phase. Overlaid on these phases is a schedule of acid or acid-precursor injections for the purpose of altering the reservoir surface wettability from oil- wet towards water- wet.
  • an injection of steam can be an injection of steam and solvent.
  • Cycles 1 and 2 represent start-up cycles wherein steam is injected to the reservoir in order to establish fluid communication between an upper injection well and a lower recovery well.
  • the start-up phase typically comprises a number of relatively short injection, soak and recovery intervals.
  • Cycles 3, 4 and 5 represent post start-up cycles wherein some acid or acid-precursors 610 are injected along with the steam in a series of CSS cycles.
  • Cycles 6 through 10 represent a series of SAGD cycles wherein varying amounts of acid or acid-precursors 610 are injected along with the steam.
  • the pressures associated with SAGD cycles are lower than the pressures associated with CSS cycles.
  • Cycles 11 through 14 represent the blow-down phase wherein the steam chamber is fully developed and is characterized by a series of high acid or acid-precursor content. The objective of the blow-down phase is to recover as much residual bitumen and as much remaining solvent as possible.
  • the number of cycles, the duration of the cycle components can be varied as well as the pressure levels associated with each cycle and the relative amounts of steam, solvent, acid or acid-precursors in the injection part of the cycle.
  • systems and methods of this disclosure can be implemented in conjunction with a special purpose computer, a programmed
  • any device(s) or means capable of implementing the methodology illustrated herein can be used to implement the various aspects of this disclosure.
  • Exemplary hardware that can be used for the disclosed embodiments, configurations and aspects includes computers, handheld devices, telephones (e.g., cellular, Internet enabled, digital, analog, hybrids, and others), and other hardware known in the art. Some of these devices include processors (e.g., a single or multiple microprocessors), memory, nonvolatile storage, input devices, and output devices.
  • alternative software e.g., a single or multiple microprocessors
  • implementations including, but not limited to, distributed processing or component/object distributed processing, parallel processing, or virtual machine processing can also be constructed to implement the methods described herein.
  • the disclosed methods may be readily implemented in conjunction with software using object or object-oriented software development environments that provide portable source code that can be used on a variety of computer or workstation platforms.
  • the disclosed system may be implemented partially or fully in hardware using standard logic circuits or VLSI design. Whether software or hardware is used to implement the systems in accordance with this disclosure is dependent on the speed and/or efficiency requirements of the system, the particular function, and the particular software or hardware systems or microprocessor or microcomputer systems being utilized.
  • the disclosed methods may be partially implemented in software that can be stored on a storage medium, executed on programmed general- purpose computer with the cooperation of a controller and memory, a special purpose computer, a microprocessor, or the like.
  • the systems and methods of this disclosure can be implemented as program embedded on personal computer such as an applet, JAVA® or CGI script, as a resource residing on a server or computer workstation, as a routine embedded in a dedicated measurement system, system component, or the like.
  • the system can also be implemented by physically incorporating the system and/or method into a software and/or hardware system.
  • FIG 7 is a schematic of a control and feedback system for applying an acid treatment to a hydrocarbon reservoir.
  • This figure illustrates the important functional units of a thermal recovery plant wherein an acid or acid precursor 705 is injected along with steam from a steam generator 704 to a hydrocarbon reservoir 701.
  • the steam is compressed 706 and sent to reservoir 701 via well-pads 702.
  • the acid or acid precursor is also compressed 707 and sent to reservoir 701 via well-pads 702.
  • the steam and acid or acid precursor are injected at the same or different times and may be combined before injection of injected separately.
  • the flow of material to and from the hydrocarbon reservoir 701 is indicated by solid lines. Recovered fluids are shown flowing from reservoir 701 to treatment facility 703 where the fluids are substantially separated as described in Figures 3, 4 and 5.
  • Figure 7 also shows reservoir diagnostics 712 which include cased-hole diagnostics and the like. Fluid recovery information 711 is typically obtained in treatment facility 703. Reservoir diagnostics 712 and fluid recovery information 711 is communicated to a computer 721 as shown by diagnostic paths 751 and 752. The flow of diagnostic information and diagnostic control commands to and from the hydrocarbon reservoir 701 is indicated by less densely spaced dashed lines.
  • Computer 721 is comprised of a memory module 722, a processor module 723 and a controller 724.
  • the computer 721 controls the steam generation and steam injection processes via control path 762.
  • the computer 721 also controls the acid or acid precursor injection processes via control path 761.
  • the control paths are indicated by densely spaced dashed lines.
  • the controller 724 contains control logic electronics used, among other things, to process sensor data collected from the aforementioned sensors and to provide control inputs for the elements described such as the input streams.
  • the controller utilizes control algorithms comprising at least one of on/off control,
  • present disclosure in various embodiments, includes providing devices and processes in the absence of items not depicted and/or described herein or in various embodiments hereof, including in the absence of such items as may have been used in previous devices or processes, for example for improving performance, achieving ease and ⁇ or reducing cost of implementation.

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Abstract

Cette invention concerne un procédé permettant de traiter des réservoirs d'hydrocarbures pour modifier la mouillabilité superficielle des réservoirs de carbonate et améliorer la récupération du pétrole lourd ou du bitume. Dans un mode de réalisation, l'invention concerne des opérations de récupération impliquant des solvants et/ou de la vapeur pour mobiliser les hydrocarbures lourds, par exemple les matrices imprégnées d'huile de carbonates de Grosmont. Des gaz peuvent être ajoutés, par exemple du dioxyde de carbone, du dioxyde de soufre et/ou du dioxyde d'azote, pour former des liquides ou des vapeurs acides une fois combinés à l'eau ou à la vapeur lorsqu'ils sont injectés pendant les opérations de récupération in situ. Les gaz producteurs d'acide adhèrent aux surfaces des roches matricielles au fur et à mesure de leur condensation/dissolution ; les vapeurs condensées réagissent avec les roches de carbonates, par exemple le calcaire et la dolomite, et modifient les surfaces qui passent de l'état imprégnées d'huile à l'état imprégnées d'eau. L'efficacité du procédé peut être surveillée par analyse des fluides récupérés et/ou par application de diagnostics du puits de fondation des puits d'observation. Les gaz de combustion comprimés ou le dioxyde de carbone récupérés dans d'autres procédés d'installation de surface peuvent être ajoutés au courant injecté.
PCT/IB2013/002620 2012-10-05 2013-10-07 Procédé de traitement de réservoirs de carbonate WO2014053912A1 (fr)

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CN105909220A (zh) * 2016-06-29 2016-08-31 德州华海石油机械股份有限公司 一种集成化调驱注入系统
WO2019013855A1 (fr) 2017-07-10 2019-01-17 Exxonmobil Upstream Research Company Procédés de stimulation de réservoir profond à l'aide de fluides de formation d'acide
CN109505591A (zh) * 2017-09-13 2019-03-22 中国石油化工股份有限公司 确定缝洞型油藏未充填溶洞渗透率界限的方法及系统
CN109763801A (zh) * 2017-11-29 2019-05-17 中国石油天然气股份有限公司 适用于复杂断块油田的橇装模块化聚表二元驱配注装置
WO2021232058A1 (fr) * 2020-05-12 2021-11-18 Saudi Arabian Oil Company Procédés d'injection d'eau à l'aide de manganèse pour la récupération assistée du pétrole dans des formations carbonatées
US11828138B2 (en) 2022-04-05 2023-11-28 Saudi Arabian Oil Company Enhanced carbon capture and storage

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EP2060613A1 (fr) * 2007-11-16 2009-05-20 BJ Services Company Procédé de traitement de formations souterraines par l'hydrolyse in situ d'esters d'acide organique
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CA1248341A (fr) * 1983-12-22 1989-01-10 Howard P. Angstadt Agent de recuperation du petrole
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Publication number Priority date Publication date Assignee Title
CN105909220A (zh) * 2016-06-29 2016-08-31 德州华海石油机械股份有限公司 一种集成化调驱注入系统
WO2019013855A1 (fr) 2017-07-10 2019-01-17 Exxonmobil Upstream Research Company Procédés de stimulation de réservoir profond à l'aide de fluides de formation d'acide
US11131177B2 (en) 2017-07-10 2021-09-28 Exxonmobil Upstream Research Company Methods for deep reservoir stimulation using acid-forming fluids
CN109505591A (zh) * 2017-09-13 2019-03-22 中国石油化工股份有限公司 确定缝洞型油藏未充填溶洞渗透率界限的方法及系统
CN109763801A (zh) * 2017-11-29 2019-05-17 中国石油天然气股份有限公司 适用于复杂断块油田的橇装模块化聚表二元驱配注装置
WO2021232058A1 (fr) * 2020-05-12 2021-11-18 Saudi Arabian Oil Company Procédés d'injection d'eau à l'aide de manganèse pour la récupération assistée du pétrole dans des formations carbonatées
US11384277B2 (en) 2020-05-12 2022-07-12 Saudi Arabian Oil Company Manganese-assisted waterflooding processes for enhanced oil recovery in carbonate formations
US11828138B2 (en) 2022-04-05 2023-11-28 Saudi Arabian Oil Company Enhanced carbon capture and storage

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