Abstract: The present invention provides a system and method to mineralize CO2 into peridotite rocks in a controlled and efficient manner removing carbon permanently from the atmosphere. Carbon dioxide sequestration into peridotite rocks happens naturally by means of natural weathering. However, this process is so slow and might take thousands of years to transform considerable amount of CO2 into carbonate rocks. The present invention, however, shortens the time of mineralization considerably in a controlled and quantifiable manner. This is typically done by injecting CO2 into peridotite rock formation and creating an efficient reaction pathways and conditions for the mineralization reaction to happen and therefore store CO2 by conversion into magnesite (MgCO3) and calcite (CaCO3).

Abstract: Nuclear energy integrated hydrocarbon operation systems include a well site having a subsurface hydrocarbon well configured to produce a produced water output. The system further includes a deployable nuclear reactor system configured to produce a heat output. The system may further include a deployable desalination unit configured to produce a desalinated water output using the produced water output of the subsurface hydrocarbon well and the heat output of the deployable nuclear reactor. The system may further include a deployable off-gas processing system configured to produce an industrial chemical using the off-gas output of the subsurface hydrocarbon well and the heat output of the deployable nuclear reactor.

Abstract: Enhanced hydrocarbon recovery methods may include use of carbonated aqueous fluids. Methods for enhanced hydrocarbon recovery may include: introducing a carbonated aqueous fluid into a subterranean reservoir, the carbonated aqueous fluid including carbon dioxide; introducing a first salt solution and a second salt solution into the subterranean reservoir after introducing the carbonated aqueous fluid; contacting the first salt solution with the second salt solution in the subterranean reservoir under conditions where the first salt and the second salt undergo an exothermic reaction; and heating the carbonated aqueous fluid with heat produced via the exothermic reaction; wherein at least a portion of the carbon dioxide is released from the carbonated aqueous fluid upon heating and migrates from a lower portion to an upper portion of the subterranean reservoir, and a decarbonated saline solution is generated from the carbonated aqueous fluid from which the carbon dioxide is released.

Abstract: The present disclosure discloses a thermal plasma treatment method for sulfur hexafluoride (SF6) degradation. In the thermal plasma treatment method for SF6 degradation, Ar is input into a thermal plasma generator as a carrier gas; annular electrodes are electrically connected to a direct current power supply to generate an arc plasma region in the presence of the carrier gas Ar; to-be-reacted SF6 and to-be-reacted H2 in a predetermined ratio are input into the arc plasma region to generate hydrogen radicals as well as fluorine radicals, and the hydrogen radicals and the fluorine radicals are bonded with each other to generate HF to inhibit the self-recovery reaction of SF6; and final products include HF and elemental S.

Abstract: A method for producing heavy oil, the method including testing a plurality of samples either from a reservoir play or simulating a reservoir play in a temperature and pressure controlled gravity drainage experiment. Test injection fluids are injected into the samples at a reservoir temperature and pressure and Cumulative Oil Production (COP) or Recovery Factor (RF) or similar feature measured over time. An injection profile is obtained by selecting n injection fluids based on a best COP or RF at a given time Tn, wherein n is a number of fluid injection stages and switching to an n+1 injection fluid when a rate of change (ROC) in the COP or RF drops at least 25%-75%, but preferably 40-60% or 50%. The injection profile is then implemented in the reservoir to produce heavy oil. Optimized injection profiles for certain reservoirs are also provided.

Abstract: A heavy oil thermal recovery method based on a multi-composition thermal fluid in a supercritical state, comprising: injecting a mixing of steam and vacuum gas oil containing Fe(III) aromatic sulfonate dissolved therein into an subterranean formation to preheat the subterranean formation, and extracting light crude oil from the subterranean formation when a temperature of the subterranean formation reaches a required temperature for combustion of heavy oil; injecting the steam and a combustion-supporting gas into the subterranean formation to enable the heavy oil to be ignited and a temperature of the subterranean formation to be reached 600° C.; and injecting a multi-composition thermal fluid formed by mixing a hydrogen donor with water into the subterranean formation to enable the multi-composition thermal fluid to be heated to the supercritical state under heat provided by the combustion of the heavy oil, and extracting crude oil modified by the heavy oil through the multi-composition thermal fluid.

Abstract: Surfactants for use in formulations and processes suitable for hydrocarbon recovery. These formulations, include formulations suitable for fracking, enhancing oil and or gas recovery, and the recovery and or production of bio-based oils.

Abstract: A method of enhancing heat transfer and energy efficiency in a geothermal reservoir includes injecting a carbonated fluid to the reservoir, injecting a first salt solution and a second salt solution into the reservoir, and increasing the temperature of the reservoir by reacting the first salt solution with the second salt solution to provide heat. The carbonated fluid injection decreases a temperature of the reservoir. The second salt solution is reactive with the first salt solution under the conditions in the reservoir after the injecting. A system of enhancing heat transfer and energy efficiency in a geothermal reservoir includes an injection system in fluid communication with an injection well. The injection system is configured to alternate the injection of the carbonated fluid and the first salt solution and second salt solution.

Abstract: Surfactants for use in formulations and processes suitable for hydrocarbon recovery. These formulations, include formulations suitable for fracking, enhancing oil and or gas recovery, and the recovery and or production of bio-based oils.

Abstract: Systems and methods relating to determination of oil saturation, kerogen content, and/or water saturation within kerogen-containing subsurface formations such as unconventional formations (e.g., tight formations such as shales) are provided herein. These methods advantageously rely on a simplified measurement process, reducing the direct measurements of a subsurface formation relied upon in determining oil saturation, kerogen content, and/or water saturation. In particular, methods according to some embodiments include determining or otherwise obtaining values of TOC; bulk density; porosity; and densities of kerogen, oil, and water corresponding to a subsurface formation of interest or a zone thereof. Methods of various embodiments further include, based at least in part upon the obtained values, determining one or more of kerogen content, oil saturation So, and water saturation Sw of the subsurface formation of interest, and/or a corresponding zone thereof.

Abstract: A system and method for a treatment of a subterranean formation. The treatment may include pumping a water shut-off material into a wellbore and to a target zone in the subterranean formation. The treatment may also include pumping a silicate to the target zone behind the water shut-off material, thereby forming a layer of silicate between the water shut-off material and the wellbore. An energy source may be directed to the layer of silicate until the layer of silicate solidifies to yield a solid barrier between the water shut-off material and the wellbore.

Abstract: A method for retrieving heavy oil from a reservoir by injection of solvent, hot water, and polymer solution. This method includes the steps of providing an injection well traversing into reservoir containing heavy oil. Sequential injections of solvent, a hot water and polymer solution are performed via the injection well traversing into reservoir containing the heavy oil. The solvent, hot water, and polymer solution intermingle with the heavy oil within the reservoir to form a heavy oil mixture that is retrieved from a production well. The sequential solvent and hot water injection may also be repeated to reduce the viscosity of the heavy oil until an estimated viscosity of the heavy oil in the reservoir is below a threshold viscosity before injecting polymer solution into the reservoir.

Abstract: A system for improving a steam oil ratio (SOR) includes a direct steam generator (DSG) boiler fluidly coupled with a downhole portion of a steam system via at least a DSG outlet, wherein the DSG boiler is configured to schedule super-heat delivered to the downhole portion to optimize the SOR associated with the system.

Abstract: Surfactants for use in formulations and processes suitable for hydrocarbon recovery. These formulations, include formulations suitable for fracking, enhancing oil and or gas recovery, and the recovery and or production of bio-based oils.

Abstract: A method, a system, tools for use by the system, and an interpretation method for injecting and detecting tracers and conducting flow characterizing of a petroleum well are disclosed. The method describes monitoring of travel time and slip velocity between two/three different phases (oil/water and possibly gas) in the well. The travel time and slip velocity are determined using an injection too for injection of an over pressurized injection of the partitioning tracers each of which would follow certain phase. The tracers are detected by an optical detection probe in the pipe. The slip velocity is obtained from the difference of travel time of two tracers which partition to two different phases.

Abstract: An apparatus for generating acoustic waves within a medium to stimulate oil recovery within an oil reservoir. The apparatus is operable with a single moving part—a central rotor, and the rotor further includes a “conduit” through which the supply fluid passes.

Abstract: A technique utilizes spatially resolved temperature measurements to infer the temperature of a subsea infrastructure. According to an embodiment, temperature data, e.g. a temperature map, is determined for the subsea infrastructure and comprises performing remote temperature measurements of water surrounding the subsea infrastructure. Additionally, a metrological scan of the subsea structure may be obtained. Furthermore, a simulation or simulations may be run for an assumed temperature profile along a surface of the subsea infrastructure. The data obtained from the remote temperature measurements, the metrological scan, and the simulation is processed to determine a temperature profile of the subsea infrastructure. This temperature profile can then be used to facilitate a variety of subsea infrastructure management decisions.

Abstract: Thermal energy is extracted from geological formations using a heat harvester. In some embodiments, the heat harvester is a once-through, closed loop, underground heat harvester created by directionally drilling through hot rock. The extracted thermal energy can be converted or transformed to other forms of energy.

Abstract: A liquid filtration apparatus includes a series of upright filter plates forming a filter plate pack. Filtering spaces are formed in the filter plate pack. The liquid filtration apparatus includes at least one filtering space and a filter chamber that is at least partly limited laterally by a filter media. The at least one filtering space has an elongated bottom discharge opening at a level below the filter chamber. The elongated bottom discharge opening is provided with a first openable and closable hatch arrangement and with a second openable and closable hatch arrangement extending across the elongated bottom discharge opening.

Abstract: Methods and systems related to SAGD injection and/or production wells that utilize flow distribution control devices. Additionally, methods and systems using limited vertical spacing separating the wells are described. These methods and systems improve steam assisted gravity drainage (SAGD) oil production, reduce SAGD start-up time and costs, and improve overall SAGD performance.

Abstract: Hydrocarbons in a subterranean reservoir are recovered using Expanding Solvent-Steam Assisted Gravity Drainage (ES-SAGD), including recovering hydrocarbons while reducing the solvent retention in the reservoir. Reducing solvent retention improves process economics.

Abstract: A system and method for steam assisted gravity drainage of hydrocarbons having increased solvent recovery to improve the economics of steam-only injection processes, such as steam assisted gravity drainage, while reducing environmental impact. Embodiments aid the condensation of solvent either by shutting-in or reducing the steam injection or by injecting a secondary lighter and cheaper solvent post solvent-steam co-injection, after which, normal steam injection at optimized operating conditions is restarted and continued until blow down while primary solvent recovery is continued, thus significantly accelerating and maximizing the recovery of solvent injected without affecting the long term cumulative bitumen production.

Abstract: A method starts wells with electrical downhole heating and injects solvent(s) or NGL mixes as a preconditioning for a steam injection process. The downhole electrical heating and solvent injection recovers oil and reduces the reservoir pressure. Once oil has been recovered for a period of time and the operating pressure and temperature has been reduced, steam or steam and solvent(s) may be injected to produce high oil recoveries at faster production rates than downhole heating or downhole heating and solvent(s) injection alone. The method reduces heat losses due to steam injection at lower pressure and temperature and therefore, improves efficiency and lowers operating costs. Operating at lower pressure and temperature also reduces the risk of melting the permafrost and consequent well failure issues.

Abstract: A proposed methodology to startup wells with electrical downhole heating as a preconditioning method for a steam injection process. The downhole electrical heating recovers oil which results in a reduction in the reservoir pressure. Once oil has been recovered for a period of time and the operating pressure and temperature has been reduced, SAGD well pairs are provided between the downhole heater wells, and SAGD or a SAGD-like method used to produce oil. The method reduces heat losses due to steam injection at lower pressure and temperature and therefore, improves efficiency and lowers operating costs. Operating at lower pressure and temperature will also reduce the risk of melting the permafrost and consequent well failure issues. When oil production drops below an economical level, remaining oil can be collected at the DHH wells using the SAGD wellpair for gas or solvent or steam sweeps, or combinations thereof.

Abstract: An inflow control device includes a flow device having an inlet; an outlet; a flow path fluidically connecting the inlet to the outlet; and a feature configured to reduce a mass flow rate of liquids to the outlet, the liquids having a subcool less than a predetermined subcool for a selected drawdown pressure, lower than a mass flow rate of liquids having a subcool greater than the predetermined subcool at the selected drawdown pressure.

Abstract: A process includes (a) injecting a steam composition into a subterranean location containing heavy hydrocarbons, preferably bitumen, wherein the steam composition comprises (i) steam and (ii) a hydroxyalkyl ammonium carboxylate and (b) recovering the heavy hydrocarbon from the subterranean location to above the ground. The process is preferably a cyclic steam stimulation (CSS) process, a steam assisted gravity drainage (SAGD), or a combination thereof.

Abstract: A method of drilling a first well and a second well into the reservoir includes forming a conduit between the first well and the second well. The conduit is filled with a conduit material. Finally, a low viscosity fluid is injected into the conduit to establish fluid communication between the first well and the second well.

Abstract: The present disclosure relates to a particularly effective well configuration that can be used for steam-drive based oil recovery methods. Fishbone multilateral wells are combined with steam drive, effectively allowing drive processes to be used where previously the reservoir lacked sufficient injectivity to allow steam drive or cyclic steam based methods.

Abstract: The present disclosure relates to a particularly effective well configuration that can be used for steam-drive based oil recovery methods. Fishbone multilateral wells are combined with steam drive, effectively allowing drive processes to be used where previously the reservoir lacked sufficient injectivity to allow steam drive or cyclic steam based methods.

Abstract: According to examples, steam breakthrough detection and prevention for a steam assisted gravity drainage (SAGD) well may include accessing real-time data associated with the SAGD well. Parameter values associated with an operation of the SAGD well may be determined based on the real-time data associated with the SAGD well. A potential of occurrence of steam breakthrough may be determined based on an analysis of selected parameter values from the parameter values associated with the operation of the SAGD well. A procedure to prevent the occurrence of the steam breakthrough may be determined based on an application of hypothetical parameter values associated with the operation of the SAGD well to an engineering analysis model associated with the SAGD well. Further, the operation of the SAGD well may be controlled based on the procedure to prevent the occurrence of the steam breakthrough.

Abstract: A Steam-Assisted Gravity Drainage (SAGD) method for recovering hydrocarbons from a reservoir can include generating steam and CO2 from feedwater, fuel and oxygen; transferring a steam-CO2 mixture comprising at least a portion of the steam and at least a portion of the CO2, to a proximate SAGD injection well; injecting the steam-CO2 mixture into the SAGD injection well; obtaining produced fluids from a SAGD production well underlying the SAGD injection well; transferring the produced fluids for separation proximate to the SAGD production well; separating the produced fluids into a produced gas and a produced emulsion; transferring the produced emulsion for separation proximate to the SAGD production well; separating the produced emulsion to obtain a produced hydrocarbon-containing component and produced water; supplying at least a portion of the produced water as at least part of the feedwater; and supplying the produced hydrocarbon-containing component to a central processing facility.

Abstract: Separating hydrocarbon from compositions including hydrocarbon and solids such as oil sands, oil sands by products, asphalt compositions, etc. includes treating such compositions with a mixture including a water soluble salt, polymer flocculent and organic diluent. The hydrocarbon separated can be in high yields and with a low solid fines content.

Abstract: Salt is removed from crude oil by exposing the salt bearing crude to successive stages of water injection and steam injection where the water injection includes high shear and the stream injection does not include high shear applied to the steam bubbles. The steam is seen to transfer salt from the crude via a different transfer mechanism and therefore doesn't require the high shear mixing of conventional water injection systems.

Abstract: Salt is removed from crude oil by exposing the salt bearing crude to successive stages of water injection and steam injection where the water injection includes high shear and the stream injection does not include high shear applied to the steam bubbles. The steam is seen to transfer salt from the crude via a different transfer mechanism and therefore doesn't require the high shear mixing of conventional water injection systems.

Abstract: A method for stimulating heavy oil recovery from CHOPS wells at or nearing the end of productive life but not experiencing water-out, wherein produced water is heated to below boiling point and injected back downhole to reduce heavy oil viscosity in the near-wellbore region and surrounding the wormhole network, enabling existing reservoir pressure to drive the reduced-viscosity heavy oil toward the well for production to surface. The injection-soak-production cycle can be repeated as desired so long as adequate reservoir pressure exists.

Abstract: The method includes: (A) directing a feed water in the liquid phase of an instant expansion tank; (B) in the instant expansion tank, heating the feed water by mixing with the recycled stream from step (E); (C) compressing again at a high pressure the liquid fraction in the instant expansion tank and sending the liquid fraction to the inlet of a heat exchanger or group of heat exchangers connected in series; (D) heating the non-expanded fraction in the heat exchanger(s) while maintaining the non-expanded fraction in the liquid state; (E) recycling the stream from step (D) in the instant expansion tank; (F) in the instant expansion tank, expanding the fraction from step (E) and generating by instant expansion a stream of the searched steam containing the mineral materials of the feed water remaining in solution; and (G) separating the solid particles formed as a blowdown containing water and the particles.

Abstract: A rod positioning tool mounts in series between a tubing string and the stuffing box of a drive head. An outer mandrel of the tool mounts to a first flange at the bottom end for connection to the tubing string below and an inner mandral mounts to a second flange for connection to the stuffing box above. The inner mandrel is slidably received within the outer mandrel with primary seals therebetween to vary the overall length of the tool using one or more actuators between the flanges, while maintaining a sealed connection between the tubing string and the stuffing box. Keys on the outer tubular mandrel are longitudinally slidable in keyways on the inner tubular mandrel to resist relative rotation between the mandrels. A secondary seal provides a sealed connection between the second flange and the top end of the outer mandrel in a fully retracted position of the tool.

Abstract: The present invention relates to a process for treating evaporator concentrate. The process includes generating or producing a vent stream that includes carbon dioxide and mixing the carbon dioxide with the evaporator blowdown to reduce the pH of the evaporator blowdown. In cases where the evaporator blowdown includes a significant concentration of silica, lowering the pH will precipitate silica from the evaporator blowdown.

Abstract: Fracturing methods include introducing a relatively high concentration of a surfactant in an initial portion of one or more fluids used in a fracturing treatment and then cutting or ramping back to a relatively low concentration of the surfactant in the remaining fluid used in the treatment. By using such a method, the volume of surfactant to provide superior treatment can be reduced significantly from the normal recommendations, leading to a high cost savings while still obtaining the desired effect upon cleanup.

Abstract: Various embodiments disclosed relate to acidizing compositions including an ampholyte polymer. Various embodiments provide a method of treating a subterranean formation. The method can include placing in a subterranean formation an ampholyte polymer including an ethylene repeating unit including a —C(O)NH2 group, an ethylene repeating unit including an —S(O)2OR1 group, and an ethylene repeating unit including an —N+R23X? group. At each occurrence, R1 can be independently selected from the group consisting of —H and a counterion. At each occurrence, R2 can be independently substituted or unsubstituted (C1-C20)hydrocarbyl. At each occurrence, X? can be independently a counterion.

Abstract: The invention relates to an apparatus for simultaneously injecting fluids into a plurality of samples of porous media, comprising: a plurality of holders for the samples of porous media, each holder comprising a sleeve and first and second platens, the first platen having an inlet for an injection fluid and the second platen having an outlet for a produced fluid, and the samples of porous media being arranged, in use, in each of the holders such that the first platen and second platen of each holder contact a first and second end of the sample of porous medium respectively, the inlet of each first platen being in fluid communication with an injection line for injecting fluid into the sample of porous medium arranged in the holder, the outlet of each second platen being in fluid communication with a dedicated effluent line for removing fluid produced from the sample of porous medium arranged in the holder, on-line and/or off-line analytical means for analyzing the fluids injected into each of the samples of po

Abstract: Performing a Recovery Design Assessment™ (RDA™) for a petroleum producing field provides a novel indicator and metric that is designed to assess how to improve recovery efficiency of a petroleum producing field. A combination of global benchmark analysis and reservoir management assessment is utilized to identify areas of reservoir management that can be improved to increase recovery efficiency. Global benchmark analysis can include comparing a recovery efficiency for a petroleum reservoir to that of other benchmark petroleum reservoirs to indicate if alterations to recovery design or developments plans or reservoir management optimizations are to be pursued. Management of the petroleum reservoir is assessed to identify recovery obstacles potentially reducing recovery efficiency. Development opportunities for overcoming recover obstacles can be implemented to increase recovery efficiency.

Abstract: Suspensions comprising amphiphilic nanoparticles and at least one carrier fluid. The amphiphilic nanoparticles may be formed from a carbon-containing material and include at least a hydrophilic portion and a hydrophobic portion. The hydrophilic portion comprises at least one hydrophilic functional group and the hydrophobic portion includes at least one hydrophobic functional group. Methods of forming the flooding suspension and methods of removing a hydrocarbon material using the flooding suspensions are disclosed.

Abstract: Systems and methods relate to recovering hydrocarbons by injecting into a reservoir outputs from two different types of steam generators along with carbon dioxide, enabling lower fuel consumption for such a hybrid-based approach versus either type of steam generator alone. One steam generator vaporizes water by thermal transfer from combustion with exhaust from the combustion remaining separated from the steam. Since this type of steam generator outputs a limited carbon dioxide concentration with the steam, at least part of the carbon dioxide injected comes from recycling the carbon dioxide separated out of production fluids recovered from the reservoir. Another steam generator produces the steam by direct water contact with combustion products to produce a resulting fluid including the steam and additional carbon dioxide.

Abstract: Hydrocarbon recovery can involve operating flow control devices distributed along a horizontal well based on temperatures of hydrocarbon-containing fluids at a plurality of locations along the horizontal well. The temperatures of hydrocarbon-containing fluids can indicate a presence of a hotter overlying reservoir region and an adjacent colder overlying reservoir region. The operation of the distributed flow control devices can involve reducing flow of hydrocarbon-containing fluid from the hotter overlying reservoir region into the horizontal well, while providing fluid communication and pressure differential between the colder overlying reservoir region and the production well, sufficiently to cause hot fluids surrounding the colder overlying reservoir region to be drawn into and induce heating of the colder overlying reservoir region.

Abstract: Certain aspects of the present invention are directed to a distributed inflow control device that can be disposed in a wellbore through a fluid-producing formation. The distributed inflow control includes a shroud that can be disposed in the fluid-producing formation. The shroud circumferentially covers a section of a tubing string. The shroud includes a profile having multiple flow paths between the fluid-producing formation and an inner volume of the section of the tubing string. Each flow path restricts a fluid flow through the flow path and is independent of each other flow path. The distributed inflow control device also includes a seal over the profile including the flow paths. The seal causes fluid to flow from an inlet to an outlet of each flow path and prevents fluid from entering or exiting each flow path at a point other than the respective inlet or the respective outlet.

Abstract: A well treatment for treating a well includes discrete stop loss elements to seal a fluid loss opening of a well. The discrete stop loss elements include polymer resistive to deformation with an initial stiffness in response to an initial strain rate of the polymer to produce a specified initial pressure signal and deformable with a subsequent, lower stiffness in response to a subsequent, lower strain rate of the polymer to produce a subsequent, different specified pressure signal.

Abstract: Embodiments of the present disclosure include suspensions for use in enhanced oil recovery, and methods of using the suspensions for recovering oil. Suspensions of the present disclosure include a nonionic surfactant that can dissolve in supercritical carbon dioxide, and a metal salt having a concentration of 200 to 1 parts-per-million.

Abstract: Estimates of global total “liquid” hydrocarbon resources are dominated by structures known as oil sands or tar sands which represent approximately two-thirds of the total recoverable resources. This is despite the Canadian Athabasca Oil Sands, which dominate these oil sand based reserves at 1.7 trillion barrels, are calculated at only 10% recovery rate. However, irrespective of whether it is the 3.6 trillion barrels recoverable from the oil sands or the 1.75 trillion barrels from conventional oil reservoirs worldwide, it is evident that significant financial return and extension of the time oil is available to the world arise from increasing the recoverable percentage of such resources. According to embodiments of the invention pressure differentials are exploited to advance production of wells, adjust the evolution of the depletion chambers formed laterally between laterally spaced wells to increase the oil recovery percentage, and provide recovery in deeper reservoirs.

Abstract: A system and a method for recovering oil from an oil-bearing formation wherein the method includes providing a reverse osmosis (RO) unit comprising at least one membrane; feeding a first feed stream having a first salinity content to a first side of the membrane; and feeding a second feed stream having a second salinity content to a second side of the membrane. The method further includes discharging a retentate stream from the first side of the membrane, and discharging a product stream having a controlled salinity content from the second side of the membrane. The method furthermore includes injecting at least a portion of the product stream into the oil-bearing formation, and recovering at least a portion of the oil from the oil-bearing formation.