Abstract: An anti-fouling system for offshore drilling structures which injects metallic ions into seawater pumping systems. An ion generator may be positioned at various positions including the strainer basket of one or more of the seawater pumps or at various positions in the system. As well, ion generators may be skid mounted and/or otherwise centrally located and connected by controllable valves to various treated water injection points, whereby the flow rates are determined and ion concentrations are maintained at desired levels throughout the system, regardless of different pumping rates.

Abstract: A system for producing oil and/or gas from an underground formation comprising a first array of wells dispersed above the formation; a second array of wells dispersed above the formation; wherein the first array of wells comprises a mechanism to inject a miscible enhanced oil recovery formulation into the formation while the second array of wells comprises a mechanism to produce oil and/or gas from the formation for a first time period; a means to convert at least a portion of the miscible enhanced oil recovery formulation within the formation into another compound during a second time period; and a means to recover at least a portion of the another compound during a third time period.

Abstract: A method for recovering natural gas from a group of subterranean zones containing natural gas, including injecting an amount of a displacing gas into a first subterranean zone, producing a first produced gas from the first subterranean zone, collecting an amount of the first produced gas wherein the quality of the collected first produced gas is higher than or equal to a threshold production quality for the first produced gas, injecting an amount of the first produced gas into a second subterranean zone wherein the quality of the injected first produced gas is higher than or equal to a threshold injection quality for the first produced gas, producing a second produced gas from the second subterranean zone, and collecting an amount of the second produced gas wherein the quality of the collected second produced gas is higher than or equal to a threshold production quality for the second produced gas.

Abstract: The invention relates to an oxycombustion method with capture of the CO2 produced. Mixer M supplies chamber CC with a mixture of oxygen from unit O and of recycled fumes from storage drum SG. Chamber CC is supplied with oxidizer from mixer M and with fuel flowing in through line 8. All of the combustion fumes are sent to water condensation unit CT, then fed into storage drum SG. Part of the fumes containing all the CO2 produced by combustion is compressed to about 60 bars, then cooled and partly liquefied to about 15° C. in liquefaction unit L1, and stored in drum SM. According to the invention, the partly liquefied CO2 is compressed by means of a multiphase pump in order to be discharged through line 16 and stored in an underground reservoir.

Abstract: The present invention relates to an enhanced oil recovery process that is integrated with a synthesis gas generation process, such as gasification or methane reforming, involving combined capture and recycle of carbon dioxide from both processes.

Abstract: A system for producing oil and/or gas from an underground formation comprising a first array of wells dispersed above the formation; a second array of wells dispersed above the formation; wherein the first array of wells comprises a mechanism to inject a miscible enhanced oil recovery formulation into the formation while the second array of wells comprises a mechanism to produce oil and/or gas from the formation for a first time period; and wherein the second array of wells comprises a mechanism to inject a remediation agent into the formation while the first array of wells comprises a mechanism to produce the miscible enhanced oil recovery formulation from the formation for a second time period.

Abstract: A technique enhances hydrocarbon fluid production. The technique utilizes a well with a plurality of lateral wellbores positioned to facilitate removal of well fluid from a hydrocarbon reservoir. A separator is disposed in the well to receive well fluid that flows from a lateral production leg. Operation of the separator separates well fluid into an oil component and a water component to enable production of the oil component. The water component is injected into the reservoir in a manner that drives well fluid trapped in the reservoir into the lateral production leg.

Abstract: An oil recovery process utilizes one or more membranes to remove silica and/or oil from produced water. In one method, the process includes separating oil from produced water and precipitating silica. The produced water having the precipitated silica is directed to a membrane, such as a ceramic membrane, which removes the precipitated silica from the produced water. In some cases, residual oil is present and is also removed by the membrane.

Abstract: A process for recovery oil includes recovering an oil/water mixture from an oil well. Thereafter, the method includes separating oil from the oil/water mixture to produce an oil product and produced water having dissolved silica therein. The produced water is directed to an evaporator and produces steam and a concentrated brine. The method or process entails mixing a precipitant or crystallizing reagent with the produced water or the concentrated brine and causing the silica to precipitate from the produced water or the concentrated brine. Steam produced by the evaporator is condensed to form a distillate which is directed to steam generator. At the steam generator the distillate is heated to produce steam which is injected into an injection well, giving rise to the formation of the oil/water mixture.

Abstract: An economic method for in situ maturing and production of oil shale or other deep-lying, impermeable resources containing immobile hydrocarbons. Vertical fractures are created using horizontal or vertical wells. The same or other wells are used to inject pressurized fluids heated to less than approximately 370° C., and to return the cooled fluid for reheating and recycling. The heat transferred to the oil shale gradually matures the kerogen to oil and gas as the temperature in the shale is brought up, and also promotes permeability within the shale in the form of small fractures sufficient to allow the shale to flow into the well fractures where the product is collected commingled with the heating fluid and separated out before the heating fluid is recycled.

Abstract: A method and apparatus of separating, in a production well, water from a water- and hydrocarbon-containing production flow emanating from at least one surrounding production formation; and also of injecting, in the production well, a resulting water-containing liquid into at least one surrounding disposal formation, whilst a resulting hydrocarbon-containing liquid is produced out of the production well. The water-containing liquid is separated from the production flow by using at least one water separation device being exposed to a pressure difference (P1-P2) that sucks water from the production flow and through the water separation device. Said water-containing liquid is thus provided. The water separation device may, for example, comprise at least one hydrophilic and water-permeable material. The pressure difference (P1-P2) may be provided through suitable adjustment of a gas pressure (P3) in a first gas column at a downstream side of the water separation device.

Abstract: A process for treating produced water to generate high pressure steam. Produced water from heavy oil recovery operations is treated by first removing oil and grease. Pretreated produced water is then fed to an evaporator. Up to 95% or more of the pretreated produced water stream is evaporated to produce (1) a distillate having a trace amount of residual solutes therein, and (2) evaporator blowdown containing substantially all solutes from the produced water feed. The distillate may be directly used, or polished to remove the trace residual solutes before being fed to a steam generator. Steam generation in a packaged boiler, such as a water tube boiler having a steam drum and a mud drum with water cooled combustion chamber walls, produces 100% quality high pressure steam for down-hole use.

Abstract: A system and series of methods, which utilize Geopressured-Geothermal (GPGT) energy for the enhanced recovery of formation crude oil. The system is designed to interface with a conversion system which concentrates the GPGT brine while recovering H2O distillate and gas, e.g., as taught by Nitschke in U.S. Pat. Re. 36,282. The system promotes enhanced oil recovery (EOR) from an oil formation via steamflood and optional gas injection, powered by the GPGT gas and using the recovered H2O distillate for source water. The system optionally reuses the bulk of the injected EOR fluids via thermal regeneration and volume replenishing, alleviating disposal costs and environmental stresses. The system manages the concentrated GPGT brine byproduct by optionally producing solid salt for sale, flowing to an appropriate end-user, or disposing in a suitable subterranean formation.

Abstract: Methods of generating subsurface heat for treating a hydrocarbon containing formation are described herein. The methods include providing a stream that includes water to a plurality of wellbores. Fuel and oxidant is provided to one or more flameless distributed combustors positioned in at least one of the wellbores. The fuel and oxidant is mixed to form a fuel/oxidant mixture. At least a portion of the mixture is flamelessly combusted in at least one of the flameless distributed combustors to generate heat. The fuel includes at least 0.1% hydrogen sulfide by volume.

Abstract: Diluted wet combustion forms a hot process fluid or VASTgas including carbon dioxide (CO2) and fluid water which is delivered to geologic formations and/or to surface mined materials to reduce the viscosity and/or increase hydrocarbon extraction. High water and/or CO2 content is achieved by reducing non-aqueous diluent and/or adding or recycling CO2. Power recovered from expanding the VASTgas may be used to pressurize the VASTgas for delivery by partial expansion through a Direct VAST cycle, and/or by diverting compressed oxidant through a parallel thermogenerator in a Diverted VAST cycle. Pressurized VASTgas may be injected into a well within the hydrocarbon formation or with mined material into a heavy hydrocarbon separator vessel to heat, mobilize, solubilize and/or extract heavy hydrocarbons. Light hydrocarbons may be mixed in with the hot process fluid to enhance hydrocarbon mobilization and recovery. Microwaves may further heat the VASTgas and/or hydrocarbon.

Abstract: Installation for enhanced oil recovery comprising in succession: a polymer storage hopper, a grinding device and a pressurized injection pump. The grinding device has a chamber for grinding and draining the dispersed polymer comprising a rotor and a stator, and on all or part of the periphery of the chamber, a ring fed by a secondary water circuit. The ring communicates with the chamber for spraying of pressurised water on the blades of the stator. A method implementing the installation is also provided.

Abstract: An embodiment is an apparatus for generating a driver gas, for recovering fluid from the Earth's subsurface. The apparatus includes a fuel reformer, adapted to react a fuel with water to produce carbon dioxide gas and hydrogen gas; a compressor, adapted to compress a portion of the carbon dioxide gas and a portion of the hydrogen gas; a gas injection unit, adapted to inject the portion of the carbon dioxide gas and the portion of the hydrogen gas compressed by the compressor, into a subsurface reservoir; a gas capture unit, adapted to capture a portion of the carbon dioxide gas and the hydrogen gas, that emerges from the subsurface reservoir; and a control module capable of using subsurface data to regulate operation of the gas injection unit. The apparatus may also include a power generator adapted to utilize a portion of the hydrogen gas to generate power, hence producing electricity without greenhouse gas emissions.

Abstract: There is disclosed a system comprising a well drilled into an underground formation comprising hydrocarbons; a production facility at a topside of the well; a water production facility connected to the production facility; wherein the water production facility produces water by removing some multivalent ions, then removing some monovalent ions, and then adding back some multivalent ions, and then injects the water into the well.

Abstract: Systems and methods for producing a well using a gas are disclosed herein. A compressed lift gas can be provided to a well to obtain a production stream. The production stream can be separated to obtain the product and a recycle gas stream. The recycle gas stream can be immediately recompressed for use as lift gas, or separated to form a lift gas stream, and a power stream containing natural gasses from the well. The lift gas stream is recycled for use as lift gas, while the power stream can be transported and/or collected for sale, recycled for use as lift gas, or consumed as power for the compressor, based on measurements obtained throughout the system, coupled with practical and economic variables. By supplementing or replacing generated lift gas and/or an external power source with natural gas from the well, the present systems and methods can become self-contained after start-up.

Abstract: A gas generator is provided with a combustion chamber into which oxygen and a hydrogen containing fuel are directed for combustion therein. The gas generator also includes water inlets and an outlet for a steam and CO2 mixture generated within the gas generator. The steam and CO2 mixture can be used for various different processes, with some such processes resulting in recirculation of water from the processor back to the water inlets of the gas generator. In one process a hydrocarbon containing subterranean space is accessed by a well and the steam and CO2 mixture is directed into the well to enhance removability of hydrocarbons within the subterranean space. Fluids are then removed from the subterranean space include hydrocarbons and water, with a portion of the hydrocarbons then removed in a separator/recovery step. The resulting hydrocarbon removal system can operate with no polluting emissions and with no water requirements.

Abstract: A flow control system includes a pump positioned in a well to remove liquid from the well. A check valve is positioned in the well and includes an open position and a closed position. The check valve in the open position allows gas from a producing formation of the well to flow past the check valve, while the check valve in the closed position substantially reduces gas flow at the pump from the producing formation. A compressed gas source is in fluid communication with the well to provide compressed gas to move the check valve to the closed position.

Abstract: A well stimulation and or treatment fluid that includes water, other additives, and a biocide consisting of 3,5-dimethyl-1,3,5-thiadiazinane-2-thione in an amount effective to inhibit bacterial growth and minimize antagonistic reactions between the biocide and other additives. Also disclosed are well injection compositions, stimulations, squeezing, waterflood, packing, cement compositions, and methods for cementing.

Abstract: Methods and systems relate to recovering hydrocarbons from within formations in which hydrocarbon bearing reservoirs are separated from one another by a fluid flow obstructing natural stratum. Relative to the reservoirs, the stratum inhibits or blocks vertical fluid flow within the formation. Drilled bores arranged to intersect the stratum provide an array of fluid flow paths through the stratum. Fluid communication established by the drilled bores enables production utilizing a producer borehole deviated from vertical and processes that rely on techniques such as gravity drainage through the fluid flow paths and/or injection through the fluid flow paths.

Abstract: The invention concerns a method and an apparatus (10) for treatment of water (26) to be injected into a subsea injection well, the apparatus (10) being disposed in water overlying the well, preferably on a water bed (12). The invention is characterized in that the apparatus (10) contains at least one receptacle (38, 40, 46, 48, 50) provided with at least one water-soluble solid-state chemical (42, 52, 54, 56) for treatment of the injection water (26). The water (26) is brought into contact with the at least one chemical (42, 52, 54, 56), causing it to gradually dissolve and mix with the water (26), after which treated water (26?) is led into an injection stream to the injection well.

Abstract: A method of recovering hydrocarbons from a porous subterranean hydrocarbon-bearing formation by: (a) reducing the salinity of a saline source water by reverse osmosis using a membrane having a first surface and a second surface by (i) feeding the saline source water to the first surface of the membrane, and (ii) removing treated water of reduced salinity from the second surface of the membrane; and (b) injecting the treated water into the formation; wherein the membrane is selectively permeable to water over dissolved solids such that when (i) the saline source water has a total dissolved solids content of at least 17,500 ppm, and (ii) the applied pressure across the membrane is greater than the osmotic pressure across the membrane and lies within the range 45 to 90 bar (4.5 to 9.0 M Pa), the total dissolved solids content of the treated water is in the range 500 to 5000 ppm.

Abstract: A method for removing silica from evaporator concentrate to facilitate disposal of the concentrate. An alkaline earth compound is mixed with the concentrate in a crystallizer. Silica in the concentrate reacts with the alkaline earth compound and precipitates from the concentrate as alkaline silicate complexes. The concentrate having the alkaline earth silicate complexes is directed to a separator where the alkaline earth silicate complexes are separated from the concentrate, producing an aqueous solution and slurry. The slurry is directed to a filter where solids are separated from a filtrate. Both the aqueous solution and the filtrate can be disposed of by deep well injection.

Abstract: A process for conditioning of wastewater treatment brines for deep well injection during recovery of heavy hydrocarbon oils in situ. High pressure steam is used to mobilize oil, which is recovered in a mixture of oil and produced water. The produced water is pre-treated by removing residual oil. The remaining water is acidified and steam stripped to remove non-hydroxide alkalinity and non-condensable gases, and is then fed to a crystallizing evaporator, where it is evaporated from a circulating brine slurry to produce (1) a distillate stream having a trace amount of residual solutes, and (2) evaporator blowdown stream containing, as dissolved or suspended solids, substantially all of the solutes from the produced water feed. The distillate stream is used as boiler feedwater, either directly or after polishing. The evaporator blowdown is conditioned to remove substantially all suspended solids and to produce a clear brine solution for deep well injection.

Abstract: A method for increasing oil recovery from an oil reservoir in which method surplus gas streams from a plant for synthesis of higher hydrocarbons from natural gas is injected into the reservoir, is described. The surplus streams from the plant is the tailgas from the synthesis and optionally nitrogen from an air separation unit which delivers oxygen or oxygen enriched air to the plant for synthesis of higher hydrocarbons.

Abstract: In one embodiment, a system can include a centralized storage module, for example a database, that stores data relating to petroleum, natural gas and other related products taken from several different sources and entities. The entity storing and maintaining this data can be an entity independent from the operators, producers and/or other working interests. This system can use automated techniques to reconcile distributions to all entities associated with a well due to the removal of a mineral, for example, petroleum, natural gas and/or other related products, from that well, on a periodic basis. These automated techniques include, for example, reconciling all agreements associated with the well, reconciling the amount of mineral removed at the well, reconciling the spot market price associated with the well at the time of removal, automating approval by the removing entity, automating payment and the like.

Abstract: A method for increasing oil recovery from an oil reservoir in which method surplus gas streams from a plant for synthesis of higher hydrocarbons from natural gas is injected into the reservoir, is described. The surplus streams from the plant is the tailgas from the synthesis and optionally nitrogen from an air separation unit which delivers oxygen or oxygen enriched air to the plant for synthesis of higher hydrocarbons.

Abstract: An oil extraction system is provided. The oil extraction system includes a sucker rod pump (10) provided for a production well (2) so as to pump up crude oil; a signal detecting section (12) for detecting a pump-off signal sent from the sucker rod pump (10); and an injection pump (20) provided for an injection well (3) so as to pressure-inject fluid which is used for secondary extraction or tertiary extraction. The pressure injection pump (20) is operated based on the pump-off signal detected by the signal detecting section (12).

Abstract: The present disclosure relates to a system and method of providing water management and utilization during the process of dewatering and retorting of oil shale. More specifically, the process described relates to co-producing potable and non-potable water, for various uses, during the extraction of petroleum from shale oil deposits. Generally, the process allows the production of multiple streams of waters or varying salinity and pressures at least one of which is of high enough pressure for reinsertion into geological formations or reservoirs, and another which may supply a potable water source. In one embodiment, the high pressure required for reinserting the non-potable water into geological formation or reservoirs may be utilized for producing the potable water supply. In another embodiment, the non-potable water supply may also be used for entraining and sequestering undesired emissions, such as CO2.

Abstract: A system and method is disclosed for treating a mixture of hydrocarbon and carbon dioxide gas produced from a hydrocarbon reservoir. The system includes a gas power turbine adapted to burn the produced gas mixture of hydrocarbon and carbon dioxide gas with oxygen as an oxidizing agent and a capture system to collect the exhaust gas from the power turbine. An inlet compressor receives exhaust gas from the capture system and compresses the exhaust gas for injection of the exhaust gas into a hydrocarbon reservoir and for recycle to the power turbine. The system may further include a membrane system that preferentially removes carbon dioxide and hydrogen sulfide from the produced gas stream before said stream is used as fuel gas in the power turbine. The carbon dioxide and hydrogen sulfide removed by the membrane system is combined with the exhaust gas, and the combined gas is injected into a hydrocarbon reservoir.

Abstract: Apparatus, methods, and systems for extracting oil or natural gas from a well using a portable coal reformer. In one example, the method may include reforming coal by reaction with water to generate driver gas (comprising carbon dioxide and hydrogen gas), and injecting the driver gas into the well. The driver gas reduces the viscosity and pressurizes the oil to help extract the oil from the oil well. The coal reforming operation may include combusting coal or other combustible material with ambient oxygen to release energy, and heating coal and water with the energy released to a temperature above that required for the coal reforming reaction to proceed, thereby reforming coal and water into driver gas. The driver gas may be purified by filtering out particles and sulfur before injecting into the well. A portion of the hydrogen gas may be separated from the driver gas and used to generate electrical power.

Abstract: A system including a mechanism for recovering oil and/or gas from an underground formation, the oil and/or gas comprising one or more sulfur compounds; a mechanism for converting at least a portion of the sulfur compounds from the recovered oil and/or gas into a carbon disulfide formulation; and a mechanism for releasing at least a portion of the carbon disulfide formulation into a formation.

Abstract: An embodiment is a portable, modular apparatus, having one or more modules, for recovering oil from an oil well and generating electric power, and including a chassis to support a fuel reformer, a gas separator, a power generator, and/or a compressor. The fuel reformer module is adapted to react a fuel source with water to generate driver gas including a mixture of carbon dioxide gas and hydrogen gas. The gas separator module is operatively coupled to the reformer module and is adapted to separate at least a portion of the hydrogen gas from the rest of the driver gas. The power generator module is operatively coupled to the gas separator module and is adapted to generate electric power using a portion of the separated hydrogen gas. The compressor module is operatively coupled to the reformer module and is adapted to compress a portion of the driver gas, and to eject the driver gas at high pressure into the oil well for enhanced oil recovery.

Abstract: A wellbore servicing apparatus comprising an inflow control assembly having an inflow flowbore and a stimulation assembly having a stimulation flowbore is disclosed. A method of servicing a wellbore comprising placing a stimulation assembly in the wellbore and placing at least one inflow control assembly in the wellbore, the at least one inflow control assembly comprising a selectively adjustable inflow sleeve, is also disclosed. A method of servicing a wellbore comprising opening a plurality of jetting nozzles in a production string located in a wellbore adjacent a formation, jetting a treatment fluid through the nozzles and perforating and/or fracturing the formation, at least partially closing the plurality of jetting nozzles, opening a plurality of inflow ports to allow fluid to flow from the formation into the production string, and filtering the fluid prior to the fluid entering the inflow ports is disclosed.

Abstract: Oil-contaminated clay dispersions in final tailings pond water from a bitumen extraction operation are used in downhole catalytic steam production for an in situ process such as SAGD to produce bitumen. The final tailings pond water is thus disposed of in an environmentally acceptable manner and a suitable source of water is made available for steam generation and subterranean injection.

Abstract: Systems, methods, and heaters for treating a subsurface formation are described herein. At least one method for providing acidic gas to a subsurface formation is described herein. The method may include providing heat from one or more heaters to a portion of a subsurface formation; producing fluids that include one or more acidic gases from the formation using a heat treatment process. At least a portion of one of the acidic gases may be introduced into the formation, or into another formation, through one or more wellbores at a pressure below a lithostatic pressure of the formation in which the acidic gas is introduced.

Abstract: A method and device for separating particles from injection water, the injection water being used for the stimulation of a petroleum reservoir. The water is drawn from a water reservoir, cleaned and typically treated by means of additives before being led into the petroleum reservoir. The injection water is first led into a closed space (14), in which the flow rate is sufficiently low for undesired particles to precipitate from the injection water.

Abstract: An oil recovery process utilizes one or more membranes to remove silica and/or oil from produced water. In one method, the process includes separating oil from produced water and precipitating silica. The produced water having the precipitated silica is directed to a membrane, such as a ceramic membrane, which removes the precipitated silica from the produced water. In some cases, residual oil is present and is also removed by the membrane.

Abstract: A method of recovering hydrocarbons from a porous subterranean hydrocarbon-bearing formation comprising the steps of: a) feeding to at least on reverse osmosis unit of a desalination assembly a high salinity water feed stream having a total dissolved solids content (total salinity) of at least 10,000 ppm; b) driving a portion of the high salinity water feed stream across a membrane in the reverse osmosis unit of the desalination assembly at a pressure above the osmotic pressure of the high salinity water feed stream while excluding at least a portion of the dissolved solids from crossing said membrane to produce a treated low salinity water product stream having a total salinity of less than 5,000 ppm and a concentrated waste brine stream wherein the hydrostatic head exerted by the high salinity water feed stream on the feed side of the membrane provides at least a major component of the pressure required to overcome the osmotic pressure; c) injecting the low salinity water product stream into the hydrocarbon

Abstract: An oil recovery process utilizes one or more membranes to remove silica and/or oil from produced water. In one method, the process includes separating oil from produced water and precipitating silica. The produced water having the precipitated silica is directed to a membrane, such as a ceramic membrane, which removes the precipitated silica from the produced water. In some cases, residual oil is present and is also removed by the membrane.

Abstract: An evaporation based method for generation of high pressure steam from produced water in the heavy oil production industry. De-oiled produced water is processed through a high pH/high pressure evaporator driven by a commercial watertube boiler. The vapor produced by the evaporator is suitable for the steam assisted gravity drainage (SAGD) method being utilized by heavy oil recovery installations, without the use of once through steam generators that require extensive chemical treatment, and without requiring atmospheric distillation, which requires high power consuming compressors. Evaporator blowdown may be further treated in a crystallizing evaporator to provide a zero liquid discharge (ZLD) system and, with most produced waters, at least 98% of the incoming produced water stream can be recovered in the form of high pressure steam.

Abstract: A closed loop system for increasing yield, reducing post process pollution, reducing energy consumed during and after extraction of fuels or contaminants in formations and for sequestering of carbon dioxide C02 from various sources is converted to a critical fluid for use as a flushing and cooling medium. Electrical energy heats a hydrocarbon rich formation resulting in the extraction of hot fluids which are fed to heat exchangers, gas/liquid separator, and steam turbine whereby oil, electric power, carbon dioxide and methane are produced for reuse in the system or for external use. Further, a method for sequestering of carbon dioxide in a formation comprises the steps of injecting CO2 into the reservoir, flushing with cool pressurized CO2 for heat removal, infiltrating with ultra-fine low density suspended catalyst particles of dry sodium hydroxide in CO2, pumping water moistened CO2 into the reservoir to activate the catalysts, binding the CO2 with reacting materials and capping the reservoir.

Abstract: A water reinjection arrangement for a coal bed methane well to minimize water disposal problems at the well surface. Water is withdrawn by a motor driven pump from an upper coal seam through openings in the upper portion of the well casing. A flow reversing head is provided within the well casing and into which the withdrawn water is directed. The water flow direction is reversed by about 180° and is conveyed within the well casing through tubular conduits to a downstream flow collector and into a downflow pipe, to be injected into a lower seam through openings in a lower portion of the well casing wall. A sealing arrangement is provided within the well casing to seal off the upper coal seam from the lower seam.

Abstract: A method for treating an oil shale formation comprising dawsonite includes providing heat from one or more heaters to the formation to heat the formation. Hydrocarbon fluids are produced from the formation. At least some dawsonite in the formation is decomposed with the provided heat. A chelating agent is provided to the formation to dissolve at least some dawsonite decomposition products. The dissolved dawsonite decomposition products are produced from the formation.

Abstract: A process may include providing heat from one or more heaters to at least a portion of a subsurface formation. Heat may transfer from one or more heaters to a part of a formation. In some embodiments, heat from the one or more heat sources may pyrolyze at least some hydrocarbons in a part of a subsurface formation. Hydrocarbons and/or other products may be produced from a subsurface formation. Certain embodiments describe apparatus, methods, and/or processes used in treating a subsurface or hydrocarbon containing formation.

Abstract: An oil recovery process utilizes one or more membranes to remove silica and/or oil from produced water. In one method, the process includes separating oil from produced water and precipitating silica. The produced water having the precipitated silica is directed to a membrane, such as a ceramic membrane, which removes the precipitated silica from the produced water. In some cases, residual oil is present and is also removed by the membrane.

Abstract: A method of recovering hydrocarbons from a porous subterranean hydrocarbon-bearing formation by: (a) reducing the salinity of a saline source water by reverse osmosis using a membrane having a first surface and a second surface by (i) feeding the saline source water to the first surface of the membrane, and (ii) removing treated water of reduced salinity from the second surface of the membrane; and (b) injecting the treated water into the formation; wherein the membrane is selectively permeable to water over dissolved solids such that when (i) the saline source water has a total dissolved solids content of at least 17,500 ppm, and (ii) the applied pressure across the membrane is greater than the osmotic pressure across the membrane and lies within the range 45 to 90 bar (4.5 to 9.0 MPa), the total dissolved solids content of the treated water is in the range 500 to 5000 ppm. Increased oil recovery can be achieved.