Abstract: Methods for increasing the recovery of hydrocarbons from a subterranean reservoir. A method may include the steps of injecting a first fluid into a first horizontal well in the reservoir by a first device; producing hydrocarbons from a second horizontal well disposed below the first well; injecting a second fluid into a third well laterally offset from each of the first and second wells while continuing to produce hydrocarbons from the second well; and selectively ceasing injection into the first well when the second well is in fluid communication with the third well. The first and second fluid may comprise steam, carbon dioxide, oxygen, or combinations thereof. Injection into the first well selectively may be ceased when pressure in the first well is increased to a first injection pressure.

Abstract: A device for the in-situ extraction of a hydrocarbon-containing substance, while reducing the viscosity thereof, from an underground deposit, has at least one injection pipeline extending in the deposit and at least one production pipeline leading out of the deposit, which together form a so-called well pair. The injection and production pipelines each have a starting region extending above ground in some areas, and an active region connecting to the starting region inside the deposit. With the method, during a heating phase hot steam is applied to the injection and production pipelines, while during a production phase hot steam is applied only to the injection pipeline. Furthermore, the active region of the injection pipeline is additionally configured as an induction heater regarding the surrounding area in the deposit. In the associated device, for example, the well pair formed by the injection pipeline and production pipeline can be configured as electrodes.

Abstract: A method for recovering oil from a reservoir comprises performing a first CHOPS process in one or more first wells, performing a second CHOPS process in one or more second wells that are laterally offset from the first wells, and injecting gas and/or steam into the one or more second wells after the CHOPS processes are at least partially completed. A plurality of channels that extend from the one or more first and second wells may be created as a result of the CHOPS processes. The gas and/or steam may be injected into the channels of the one or more second wells via a downhole steam generator that is located in the one or more second wells. The gas and/or steam may form a gas and/or steam front that drives reservoir products into the channels of the one or more first wells. The reservoir products may be recovered to the surface through the one or more first wells.

Abstract: A method is provided for applying a thermal process to a lower zone underlying an overlying hydrocarbon zone with thermal energy from the thermal process mobilizing oil in the overlying zone. The lower zone itself could be a hydrocarbon zone undergoing thermal EOR. Further, one can economically apply a thermal EOR process to an oil formation of low mobility and having an underlying zone such as a basal water zone. Introduction gas and steam, the gas having a higher density than the steam, into the underlying zone displaces the basal water and creates an insulating layer of gas between the steam and the basal water maximizing heat transfer upwardly and mobilizing viscous oil greatly reducing the heat loss to the basal water, economically enhancing production from thin oil bearing zones with underlying basal water which are not otherwise economic by other known EOR processes.

Abstract: The present invention is directed to an in situ reservoir recovery process that uses a horizontal well located near the top of a reservoir and an inclined production well to extract bitumen or heavy oil from a reservoir. In a first stage, the top well is used for cold production of reservoir fluids to the surface, in which, reservoir fluids are pumped to the surface in the absence of stimulation by steam or other thermal and/or solvent injection. A lower production well is drilled into the formation below the top well. The top well is converted to an injection well or, if no cold production then a top well is drilled as an injector well. A portion of the bottom well is inclined so that one end of the incline is closer to the injector well than the other end of the incline. In the process, steam circulation creates a heated zone at the point of the two wells that are closest together in the reservoir.

Abstract: A borehole system having a permeability controlled flow profile including a tubular string; one or more permeability control devices disposed in the string; and the plurality of permeability control devices being selected to produce particular pressure drops for fluid entering or exiting various discrete locations along the string and method.

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 utilizing microwaves to heat H2O within a subterranean region wherein the heated H2O contacts heavy oil in the subterranean region to lower the viscosity of the heavy oil and improve production of the heavy oil.

Abstract: A process for utilizing microwaves to heat solvent within a subterranean region wherein the heated solvent, vapor, contacts heavy oil in the subterranean region to lower the viscosity of the heavy oil and improve production of the heavy oil.

Abstract: A process for utilizing microwaves to heat H2O within a subterranean region wherein the heated H2O contacts heavy oil in the subterranean region to lower the viscosity of the heavy oil and improve production of the heavy oil.

Abstract: A process for utilizing microwaves to heat H2O within a subterranean region wherein the heated H2O contacts heavy oil in the subterranean region to lower the viscosity of the heavy oil and improve production of the heavy oil.

Abstract: A process for utilizing microwaves to heat H2O and sulfur hexafluoride within a subterranean region wherein the heated H2O and sulfur hexafluoride contacts heavy oil in the subterranean region to lower the viscosity of the heavy oil and improve production of the heavy oil.

Abstract: A cyclic steam soak (CSS) stimulation method for producing heated hydrocarbons from a viscous hydrocarbon-containing formation comprises the steps of: a) drilling a well (1) having a substantially horizontal or inclined lower section (3) into the viscous hydrocarbon-containing formation (4) substantially along the trajectory of the minimum compressive horizontal stress Sh; b) cutting at selected intervals along the length of the lower well section (3) substantially disk-shaped cavities (5A-5D) into the viscous hydrocarbon-containing formation (4) by a rotating hydraulic jet cutting device (6); c) completing the well (1); d) injecting steam into the well (1) and disk-shaped cavities (5A-5D) at such an elevated pressure that the hydraulic pressure in at least one disk-shaped cavity 5A is above the formation fracturing pressure, thereby fracturing the formation (4) and permitting the steam to invade the formation surrounding the fracture and to heat hydrocarbons in the steam invaded zone; e) interrupting steam i

Abstract: A method for extracting bitumen and/or extra-heavy oil from an underground deposit is provided. The energy for producing the steam and for the electric heating is generated in situ, for which purpose part of the extracted bitumen and/or extra-heavy oil is burned in an industrial turbine with a downstream generator coupled to the turbine. The industrial turbine may be a gas turbine or a steam turbine. In particular the industrial turbine with downstream generator is assigned a waste heat recovery steam generator which serves for generating the steam and accordingly takes the form of a boiler. Through intermediate storage of the bitumen and/or ultra-heavy oil produced it is possible to implement a self-contained closed circuit which operates autonomously, independently of any external energy supply, using approx. 20% of the extracted bitumen and/or extra-heavy oil for the purposes of extraction.

Abstract: Systems and methods for creating high-pressure mixtures of steam and one or more noncondensable gas species, which may be injected into deep, high-pressured oil reservoirs to supply heat and aid oil recovery. These systems and methods may include generating these mixtures, also referred to as a combined stream, controlling the total pressure of the combined stream, controlling the partial pressure of steam within the combined stream, supplying the combined stream to a subterranean formation that includes hydrocarbons, such as viscous oil, reducing the viscosity of the oil, and/or producing oil from the subterranean formation. In some embodiments, the total pressure of the combined stream may approach or even exceed the critical pressure of water while still retaining significant amounts of latent heat for delivery. In some embodiments, the partial pressure of steam may be less than the critical pressure of water.

Abstract: Methods and systems relate to recovering petroleum products from an underground reservoir. Injection of steam along with carbon dioxide into the reservoir facilitates the recovering, which is further influenced by operating pressure for the injection. Absorption of the carbon dioxide by the products and heat transfer from the steam to the products act to reduce viscosity of the products in order to aid flowing of the products.

Abstract: A process for utilizing microwaves to heat H2O within a subterranean region wherein the heated H2O contacts heavy oil in the subterranean region to lower the viscosity of the heavy oil and improve production of the heavy oil.

Abstract: A method of servicing a wellbore, comprising providing a fluid diode in fluid communication with the wellbore, and transferring a fluid through the fluid diode. A fluid flow control tool, comprising a tubular diode sleeve comprising a diode aperture, a tubular inner ported sleeve received concentrically within the diode sleeve, the inner ported sleeve comprising an inner port in fluid communication with the diode aperture, and a tubular outer ported sleeved within which the diode sleeve is received concentrically, the outer ported sleeve comprising an outer port in fluid communication with the diode aperture, wherein a shape of the diode aperture, a location of the inner port relative to the diode aperture, and a location of the outer port relative to the diode aperture provide a fluid flow resistance to fluid transferred to the inner port from the outer port and a different fluid flow resistance to fluid transferred to the outer port from the inner port.

Abstract: A method of producing oil which begins by drilling, casing and inserting a tubing string in a wellbore. The method then perforates both an upper portion and a lower portion of the casing to establish communication between the wellbore with a upper horizontal fracture and a lower horizontal fracture. A retrievable packer or a seal assembly is inserted horizontally between the tubing string and the casing and vertically between the upper horizontal fracture and the lower horizontal fracture for heat isolation. Steam is then injected into the wellbore both into the upper horizontal fracture and the lower horizontal fracture.

Abstract: Methods relate to a steam-gas-solvent (SGS) process for recovery of heavy crude oil and bitumen. The methods include injecting a steam-gas-solvent mixture to mobilize hydrocarbons in a formation and producing from the formation the hydrocarbons that are mobilized. The steam-gas-solvent mixture includes steam, a gas non-condensable under reservoir operating conditions and a solvent condensable under reservoir operating conditions.

Abstract: Methods and apparatus relate to systems and methods of recovering oil from a formation. In operation, a steam chamber develops as a result of steam injection into the formation and the recovery of fluids including the oil through a production well. An auxiliary well spaced in a lateral direction from the production well helps ensure development of the steam chamber as desired. The auxiliary well may enable heating of the formation through establishing an electric potential between the auxiliary well and the production well or by resistive heating of material forming the auxiliary well. Further, the auxiliary well may provide a flow path for solvent or gas injection to facilitate the recovery through the production well.

Abstract: A method for oil recovery whereby an exothermic water reactant (EWR) encapsulated in a water soluble coating is placed in water and pumped into one or more oil wells in contact with an oil bearing formation. After the water carries the EWR to the bottom of the injection well, the water soluble coating dissolves and the EWR reacts with the water to produce heat, an alkali solution, and hydrogen. The heat from the EWR reaction generates steam, which is forced into the oil bearing formation where it condenses and transfers heat to the oil, elevating its temperature and decreasing the viscosity of the oil. The aqueous alkali solution mixes with the oil in the oil bearing formation and forms a surfactant that reduces the interfacial tension between the oil and water. The hydrogen may be used to react with the oil at these elevated temperatures to form lighter molecules, thus upgrading to a certain extent the oil in situ.

Abstract: A method for the in situ extraction of bitumen or very heavy oil from oil sand deposits close to the surface, where thermal energy is introduced into the deposit to reduce the viscosity of the bitumen or very heavy oil is provided. Condensed water is used that is introduced into the deposit via an injection pipe and is horizontally conducted inside the pipe within the deposit such that the water can evaporate in situ and the heat can be applied to the deposit. An apparatus including an injection pipe, an extraction pipe, a converter and electrical conductors are also provided.

Abstract: Amines or ammonia and amines may be used to enhance recovery of heavy hydrocarbons. The amines or ammonia and amines alone or with water, steam or an oil solvent are combined with the heavy hydrocarbons to promote the transport of the heavy hydrocarbons. The amines or ammonia and amines may be injected downhole or admixed with heavy hydrocarbon containing ore on the surface, optionally with water or steam. Ammonia may be used alone with high quality steam.

Abstract: A method for producing hydrocarbons from a region having adjacent strata divided by an impermeable or partially permeable barrier and, wherein at least one of the strata contains hydrocarbons, comprises of sufficiently heating one of the stratum to allow heat to be conducted to the hydrocarbon containing stratum and producing hydrocarbons therefrom. In one aspect, both strata contain hydrocarbons, such as bitumen, and heat is generated by a steam assisted gravity drainage process to the adjacent stratum. Heat may also be generated by in-situ combustion of hydrocarbons to preheat an adjacent stratum, or by electrical heating. Once pre-conditioned to a higher in-situ temperature, hydrocarbon production may be facilitated by diluting the target pre-heated hydrocarbon bearing stratum with solvent injection.

Abstract: A method for recovering heavy oil in a stratum with an injection well, a production well and a steam generator. The method begins by injecting steam from the steam generator into a horizontal portion of the injection well followed by soaking the stratum with the steam from the injection well for a predetermined period of time; and producing heavy oil from the stratum with the production well.

Abstract: A method and system for producing steam for extraction of heavy bitumen including the steps of mixing carbon or hydrocarbon fuel. The fuel is crude oil, vacuum residue, asphaltin, petcoke or coal. The oxidation gas includes oxygen, oxygen enriched air or air-combustion of the mixture under high pressure and high temperature. The fuel is mixed with low quality contaminated water containing organics and inorganics. The liquid phase transferred to a gas phase includes steam and carbon dioxide, wherein solids are separated from the gas phase. The gas phase is mixed with saturated water to scrub the remaining solids and produce saturated steam. The solid rich water is recycled back for combustion. The saturated steam super-heated dry steam and gas mixture is send to an enhanced oil recovery facility for injection into an underground reservoir.

Abstract: A system and method for extracting hydrocarbon products from oil sands using nuclear energy sources for power to decrease the viscosity of bitumen in oil sands deposits and provide sufficient heat and pressure to produce liquid and gaseous hydrocarbon products. Steps for extracting the hydrocarbon products form the oil sands deposits are disclosed.

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 system for oscillating compressible working fluid in a wellbore defined in a subterranean formation includes a fluid supply and a fluid oscillator device. The fluid supply communicates compressible working fluid into a conduit disposed within the wellbore. The fluid oscillator device is configured to reside in the wellbore. The fluid oscillator device includes an interior surface that defines an interior volume of the fluid oscillator device, an inlet into the interior volume, and an outlet from the interior volume. The interior surface is static during operation to receive the compressible working fluid into the interior volume through the inlet and to vary over time a flow rate of the compressible working fluid from the interior volume through the outlet.

Abstract: A pre-ignition heat cycle (PIHC) using cyclic steam injection and steam flood techniques is described that improves the recovery of viscous hydrocarbons from a subterranean reservoir using an overhead in-situ combustion technique such as combustion overhead gravity drainage (COGD). The PIHC, by developing horizontal and vertical transmissive zones, predisposes a viscous oil reservoir to develop a conformable combustion chamber. Good conformance of the combustion chamber enhances recovery factor and improves well operations in the field for in-situ combustion applications.

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: The invention provides methods for natural gas and oil recovery, which include the use of air injection and in situ combustion in natural gas reservoirs to facilitate production of natural gas and heavy oil in gas over bitumen formations.

Abstract: A method to extract bitumen or very heavy oil in situ from oil sand seams close to the Earth's surface is provided. Energy is introduced via at least two pipes at a given, repeatable distance from the seam, a predefined geometry is maintained in relation to the well pair. The associated apparatus includes at least one additional pipe which is alternatively designed as an electrode or also for feeding vapor and is placed above the injection pipe.

Abstract: The invention includes a method for determining a steam injection schedule for a set of subsurface formation subsurface regions of an oil field, the method including the steps of determining a thermal maturity for each subsurface region of the set; calculating a latent heat target for each subsurface region according to the determined thermal maturity therefore; calculating a steam injection target for each subsurface region according to the calculated latent heat target therefore; determining the availability of steam for injection to the subsurface regions; and calculating a steam injection schedule for each subsurface region according to the determined steam availability and calculated steam injection targets for all subsurface regions of the set.

Abstract: A once-through steam generator including one or more steam-generating circuits extending between inlet and outlet ends thereof and including one or more pipes, the steam-generating circuit having a heating segment at least partially defining a heating portion of the once-through steam generator, and one or more heat sources for generating heat to which the heating segment is subjected. The steam-generating circuit is adapted to receive feedwater at the inlet end, the feedwater being subjected to the heat from the heat source to convert the feedwater into steam and water. The pipe has a bore therein at least partially defined by an inner surface, and at least a portion of the inner surface has ribs at least partially defining a helical flow passage. The helical flow passage guides the water therealong for imparting a swirling motion thereto, to control concentrations of the impurities in the water.

Abstract: A system comprising a well drilled into an underground formation comprising hydrocarbons; a water supply; a steam production facility, the steam production facility comprising a filter to remove at least 80% of a quantity of divalent cations in the water supply; an exchange resin to remove at least 80% of a quantity of divalent cations in a filtered water stream that has already passed through the filter; a steam injection facility connected to the well and the steam production facility, adapted to inject the steam into the well.

Abstract: A plant for generation of steam for oil sand recovery from carbonaceous fuel with capture of CO2 from the exhaust gas, comprising heat coils (105, 105?, 105?) arranged in a combustion chamber (101) to cool the combustion gases in the combustion chamber to produce steam and superheated steam in the heat coils, steam withdrawal lines (133, 136, 145) for withdrawing steam from the heat coils, an exhaust gas line (106) for withdrawal of exhaust gas from the combustion chamber (101), where the combustion chamber operates at a pressure of 5 to 15 bara, and one or more heat exchanger(s) (107, 108) are provided for cooling of the combustion gas in line (106), a contact device (113) where the cooled combustion gas is brought in countercurrent flow with a lean CO2 absorbent to give a rich absorbent and a CO2 depleted flue gas, withdrawal lines (114, 115) for withdrawal of rich absorbent and CO2 depleted flue gas, respectively, from the contact device, the line (115) for withdrawal of CO2 depleted flue gas being connect

Abstract: Methods and systems for treating a hydrocarbon containing formation described herein include providing heat to a first portion of the formation from a plurality of heaters in the first portion, producing produced through one or more production wells in a second portion of the formation, reducing or turning off heat provided to the first portion after a selected time, providing an oxidizing fluid through one or more of the heater wells in the first portion, providing heat to the first portion and the second portion through oxidation of at least some hydrocarbons in the first portion, and producing fluids through at least one of the production wells in the second portion. The produced fluids may include at least some oxidized hydrocarbons produced in the first portion.

Abstract: The device of the present invention belongs to the field of the steam generators devices. Specifically, the device described herein is based constructively in a rocket-type engine for generates instantaneously a vitiated steam, which is a mix of water steam with combustion gases. The device described herein is a modular device whose each module may be changed in case of break or clogging. The device of this invention provides energy for the operation of different steam equipment, such as turbines, engines, locomotives, among other possible, as well as the combination of them. The device of this invention may also be attached in petroleum wells, making feasible the extraction of petroleum from the mature wells.

Abstract: Processes and systems comprising a five-spot pattern of multiple horizontal wells for increasing the efficiency of heated vapor-assisted hydrocarbon recovery from subterranean viscous hydrocarbon formations.

Abstract: Methods of treating a tar sands formation is described herein. The methods may include providing heat to a first section of a hydrocarbon layer in the formation from a plurality of heaters located in the first section of the formation. Heat is transferred from the heaters so that at least a first section of the formation reaches a selected temperature. At least a portion of residual heat from the first section transfers from the first section to a second section of the formation. At least a portion of hydrocarbons in the second section are mobilized by providing a solvation fluid and/or a pressurizing fluid to the second section of the formation.

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: A method for treating a tar sands formation is disclosed. The method includes providing a drive fluid to a first hydrocarbon containing layer of the formation to mobilize at least some hydrocarbons in the first layer. At least some of the mobilized hydrocarbons are allowed to flow into a second hydrocarbon containing layer of the formation. Heat is provided to the second layer from one or more heaters located in the second layer. At least some hydrocarbons are produced from the second layer of the 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: A system for producing fluids from a subterranean zone comprises a tubing string disposed in a well bore, the tubing string adapted to communicate fluids from the subterranean zone to a ground surface. A downhole fluid lift system is operable to lift fluids towards the ground surface. A downhole fluid heater is disposed in the well bore and is operable to vaporize a liquid in the well bore. A seal between the downhole fluid lift system and the downhole fluid heater is operable to isolate a portion of the well bore containing the downhole fluid lift system from a portion of the well bore containing the downhole fluid heater. A method comprises: disposing a tubing string in a well bore; generating vapor in the well bore; and lifting fluids from the subterranean zone to a ground surface through the tubing string.

Abstract: A method for producing hydrocarbons from a reservoir containing the hydrocarbon comprises a steam assisted gravity drainage (SAGD) incorporating cyclic steam, heavy (e.g. greater than C4) solvent and light (e.g. C2 to C4) solvent injection. The method involves a series of steps wherein the injection of the respective streams is varied. The method provides a significant improvement in hydrocarbon extraction efficiency as compared to a SAGD process alone and mitigates many of the drawbacks associated with typical SAGD operations.

Abstract: This description is directed to a method and system for integrating an in-situ bitumen recovery operation with a bitumen mining operation for improved efficiencies and synergies therebetween. The method comprises obtaining a production fluid from the in-situ bitumen recovery operation, directing the production fluid to the bitumen mining operation, and incorporating the production fluid into the bitumen mining operation. The basic integrated system comprises a production well for recovering production fluid from the in-situ bitumen recovery operation, a bitumen mining and extraction facility, and a transporter for directing the production fluid from the production well to the bitumen mining and extraction facility for incorporation into the mining and extraction operation. The in-situ recovery operation may be a thermal operation, such as steam-assisted gravity drainage (SAGD), cyclic steam stimulation (CSS), or a derivative thereof.

Abstract: Methods for treating a tar sands formation are described herein. Methods for treating a tar sands may include heating a portion of a hydrocarbon layer in the formation from one or more heaters located in the portion. The heat may be controlled to increase the permeability of at least part of the portion to create an injection zone in the portion with an average permeability sufficient to allow injection of a fluid through the injection zone. A drive fluid and/or an oxidizing fluid may be provided into the injection zone. At least some hydrocarbons including mobilized hydrocarbons are produced from the portion.