Abstract: Methods produce heavy oil with steam assisted gravity drainage. Such methods alternate a traditional steam injection with an injection of a steam-plus-non-condensable gas (such as CO2 or CO2-plus-diluent) mixture. The CO2/diluent mixture is soluble in bitumen, leading to a reduction in viscosity of the heavy oil. Additionally, the steam-only injection reduces the accumulation of vapor NCG along the edge of the steam chamber, leading to improved thermal efficiency.

Abstract: Methods and systems for recovering heavy oil, such as bitumen, by steam assisted gravity drainage (SAGD) from subterranean formations having a water and/or gas containing layer overlying a heavy oil containing layer. A fluid blocking agent is injected into the water and/or gas containing layer above at least one pair of horizontal wells. The blocking agent undergoes a change of density, viscosity or solidity when elevated to a temperature between an initial ambient reservoir temperature and 175 degrees by heat from steam used in the SAGD process, thereby creating a seal within the reservoir above the at least one pair of horizontal wells limiting or preventing movements of fluid through the seal.

Abstract: A method is provided for production of heavy oil from a reservoir containing heavy oil, the method including the steps of: providing a plurality of wells into the formation; injecting into the plurality of wells a mixture comprising steam and a solvent; ceasing injection of the mixture; producing a mixture of heavy oil, solvent and condensed steam from the plurality of wells after injection of steam has ceased: and after production of the mixture of heavy oil, solvent and condensate from at least one of the plurality of wells has declined to a predetermined rate, injecting into the at least one well a stream consisting essentially of steam while at least one other well continues to operate as a producing well.

Abstract: A system for recovering hydrocarbons from a subterranean formation with steam-assisted gravity drainage (SAGD) includes a steam injection well. The steam injection well includes a first portion extending from the surface through an unconsolidated layer of the formation to a consolidated layer of the formation, a second portion extending horizontally through the consolidated layer, and a plurality of third portions extending from the second portion. Each third portion extends upward from the second portion into the unconsolidated layer of the formation and a hydrocarbon reservoir in the unconsolidated layer of the formation. In addition, the system includes a production well. The production well includes a first portion extending from the surface through the unconsolidated and a second portion extending horizontally through the unconsolidated layer. The second portion of the production well is vertically positioned above the second portion of the steam injection well.

Abstract: Multi-stage methods for the enhanced recovery of high viscosity oil deposits from low temperature, shallow subterranean formations. The methods may include the steps of heating potentially extractable hydrocarbons, such as high viscosity oil, by injecting a sufficient amount of a heating fluid having a temperature and viscosity sufficiently high to minimize channeling and to permit penetration into regions of the reservoir containing the potentially extractable hydrocarbons. Thereafter, there is injected an extraction fluid that forms a mobile emulsion with the oil, without need for a co-solvent. The extraction fluid may include either a surfactant-polymer formulation or an alkaline-surfactant-polymer formulation. This is followed by injecting a polymer drive medium into the reservoir to displace and drive hydrocarbons and fluids comprising oil to a production well. An aqueous driving medium is then injected into the reservoir to also drive hydrocarbons and fluids comprising oil to a production well.

Abstract: A device for obtaining carbonic substances, particularly bitumen, from oil sands is provided. The device has at least one steam generator, an injection pipeline and a production pipeline. Steam can be introduced into the oil sand via the injection pipeline, and the carbonic substance can be removed from the oil sand via the production pipeline. At least one steam turbine is arranged between the steam generator and the injection pipeline. A method for obtaining carbonic substances, particularly bitumen, from oil sands is also provided.

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 method of recovering heat from hot produced fluids at SAGD facilities is described that utilizes wellpad steam generation such as Direct Steam Generators (DSG). Heated fluids produced by SAGD are used to preheat the water that is used to make steam for SAGD. Feedwater is conveniently preheated at the wellpads by the produced fluids, emulsions, and/or gases before feeding to the DSGs.

Abstract: A system and method for cracking, hydrogenating and extracting oil from underground deposits includes a gasifier, an injection well and a production well. The gasifier creates high pressure, high temperature syngas. The pressurized syngas flows through an injection well into a deposit of oil under the ground to crack and hydrogenate the oil to produce upgraded oil with a reduced density and viscosity. The production well of the system receives the reduced density and viscosity oil, transports it above the ground where it may be further separated into a portion that may be sold and a portion that can be gasified in the gasifier.

Abstract: A method of hydrocarbon resource recovery from a subterranean formation may include forming a plurality of spaced apart injector/producer well pairs in the subterranean formation. Each injector/producer well pair may include a laterally extending producer well and a laterally extending injector well spaced thereabove. The method may include forming an intermediate well adjacent a given injector/producer well pair, and operating a positioning actuator to position a radio frequency (RF) sensor coupled to the positioning actuator to at least one predetermined location within the intermediate well. The method may further include operating the RF sensor at the at least one predetermined location within the intermediate well to selectively sense at least one corresponding portion of the subterranean formation adjacent the given injector/producer well pair. The method may also include recovering hydrocarbon resources from the plurality of injector/producer well pairs including the given injector/producer well pair.

Abstract: Heavy oil recovery from oil sand reservoirs is enhanced through the creation of subsurface high permeability pathways distributed throughout the oil sand reservoirs. The high permeability pathways may be boreholes that extend through the oil sand reservoir. A portion of the high permeability pathway may be packed with high permeability particulate to provide structural support and allow for high permeability throughout the boreholes. After establishing the high permeability pathways throughout the oil sand reservoir, solvent may be introduced into the oil sand reservoir. The solvent has the beneficial effect of lowering the viscosity of the heavy oil, which aids in the extraction of the heavy oil. Thermal recovery processes and other enhancements may be combined with these methods to aid in reducing the viscosity of the heavy oil. Advantages of these methods include, accelerated hydrocarbon recovery, higher production efficiencies, lower costs, and lower extraction times.

Abstract: An in situ combustion process entailing the simultaneous production of liquids and combustion gases that combines fluid drive, gravity phase segregation and gravity drainage to produce hydrocarbons from a subterranean oil-bearing formation, comprising initially injecting gas, steam or a fluid through a horizontal well placed high in the formation, and initially producing hydrocarbons through a lower, parallel horizontal well. Thereafter, in accordance with the method, production from the lower well is ceased, and a gas, liquid, or steam injected into such lower well, and an adjacent parallel well likewise low in the reservoir is used to produce the oil. Significant portions of a reservoir may thereby be exploited by continually drilling lower adjacent horizontal wells in a direction along the reservoir and converting penultimate lower production wells into injection wells and thereby driving hydrocarbons to an adjacent parallel production well for recovery to surface.

Abstract: A method for hydrocarbon resource recovery in a subterranean formation including a laterally extending injector well having a tubular conductor therein, and a laterally extending producer well adjacent the injector well, may include drilling outwardly from a distal end of the injector well beyond a distal end of the tubular conductor to define an extended injector well portion. The method may further include advancing a radio frequency (RF) conductor through the tubular conductor so as to extend beyond the distal end of the tubular conductor and into the extended injector well portion. The method may further include supplying RF energy into adjacent portions of the subterranean formation from the RF conductor, and recovering hydrocarbon resources utilizing the producer well.

Abstract: A method of producing heavy oil by first injecting water and sulfur hexafluoride molecules into a region. The method then introduces electromagnetic waves such as microwaves and/or radio frequencies into the region at a frequency sufficient to excite the water and the sulfur hexafluoride molecules and increase the temperature of at least a portion of the water and sulfur hexafluoride molecules within the region to produce heated water and sulfur hexafluoride molecules. At least a portion of the heavy oil is heated in the region by contact with the heated water and sulfur hexafluoride molecules to produce heated heavy oil. The heated heavy oil is then produced.

Abstract: A method of recovering oil from an oil well and producing steam for injection into an injection well is provided. After recovering an oil-water mixture from the oil well, oil is separated from the mixture to produce an oil product and produced water. In one process, the produced water is directed to an indirect fired steam generator which is powered by an independent boiler or steam generator. As water moves through the indirect fired steam generator, the same is heated to produce a steam-water mixture. The steam-water mixture is directed to the steam separator which separates the steam-water mixture into steam and water. The separated water is directed from the steam separator back to and through the indirect fired steam generator. This separated water is continued to be recycled through the indirect fired steam generator. Steam separated by the steam separator is directed into the injection well.

Abstract: Systems and methods for enhanced delivery of thermal energy to vertical wellbores are disclosed. In one embodiment, a method comprises heating a heat transfer fluid; continuously circulating the heat transfer fluid into a vertical wellbore to a downhole heat exchanger; advancing hot feedwater into the vertical wellbore to the downhole heat exchanger, wherein the downhole heat exchanger is configured to transfer heat from the heat transfer fluid to the hot feedwater to generate high-quality steam; transmitting the steam from the downhole heat exchanger into a subterranean formation, whereby thermal energy from the steam causes a reduction in viscosity of hydrocarbons in the subterranean formation; injecting an acid scale wash to counter scale buildup from the hot feedwater on the downhole heat exchanger; and returning the heat transfer fluid from the downhole heat exchanger to the surface thermal fluid heater for reheating and recirculation into the vertical wellbore.

Abstract: A completion for steam injection and production includes a production tubing connected to the stinger, a downhole steam generator (DSG) having a discharge connected to the production tubing through an inverted Y-tool, a fuel supply tubing extending between the DSG and a surface fuel supply and an air supply tubing extending between the DSG and a surface fuel supply. The completion can have an artificial lift device incorporated in the production tubing.

Abstract: A completion system includes a first borehole structure having a first section formed proximate to a volume of methane hydrate located at a subsurface location. A second borehole structure has a second section formed proximate to the volume of methane hydrate, the first section positioned deeper than the second section with respect to gravity. A first string is positioned in the first borehole structure and arranged to convey a heat-bearing fluid through the first string into contact with a volume of methane hydrate in order to liberate methane from the methane hydrate. A second string is positioned in the second borehole structure and arranged to produce the methane.

Abstract: A method is described for accelerating start-up for SAGD-type operation by providing radio frequency heating devices inside the lateral wells that can re-heat the injected steam after losing heat energy during the initial injection. The method also extends the lateral wells such that the drilling of vertical wells can be reduced to save capital expenses.

Abstract: A hydrocarbon resource recovery system is provided for a subterranean formation having an injector wellbore and a producer wellbore therein. The hydrocarbon resource recovery system includes a tubular producer positioned in the producer wellbore and a tubular injector positioned in the injector wellbore. A steam source is coupled to a proximal end of the tubular injector, and a radio frequency (RF) energy source is coupled to the proximal end of tubular injector. The tubular injector has spaced apart steam injector slots sized to allow steam to pass into the subterranean formation, while containing RF energy within the tubular injector to heat the steam.

Abstract: A continuous process for upgrading a heavy hydrocarbon includes the steps of: obtaining a heavy hydrocarbon; heating the heavy hydrocarbon; contacting the heavy hydrocarbon with a solvent at upgrading conditions so as to produce a first product comprising a mixture of upgraded hydrocarbon and solvent and a second product comprising asphaltene waste and water; continuously feeding the first product and the second product to a first separator; heating the first product; and continuously feeding the first product to a second separator to separate the upgraded hydrocarbon from the solvent. A system is also provided.

Abstract: A method of establishing fluid communication between a well pair in an oil-sand reservoir, where dilatable oil sands in the reservoir form a barrier to fluid communication between the well pair. Steam or water is circulated within at least one well to a region of the oil sands adjacent to the well. The steam or water pressure is increased to a dilation pressure sufficient to dilate the oil sands in the region. While circulating steam or water within the well at a substantially steady state, the steam or water pressure is maintained at a level sufficient to enlarge the dilated region, until detection of a signal indicative of fluid communication between the well pair. The rates and pressures of steam or water injection and production may be monitored and adjusted to vary a bottom-hole pressure in the well.

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: An oil recovery process entails recovering an oil-water mixture from an oil bearing formation and separating the oil-water mixture to produce an oil product and produced water. The produced water includes suspended and dissolved solids and is subjected to treatment which removes suspended and dissolved solids therefrom. The treated water is then directed to a forced circulation steam generator that includes a furnace having a burner, water cooled walls and an evaporator unit. The treated water is pumped through the water cooled walls and the evaporator unit. The water passing through the water cooled walls and evaporator unit are heated to produce approximately 10% to approximately 30% quality steam in both the water cooled walls and the evaporator unit. The steam is collected and separated from a water-steam mixture to produce high quality steam, on the order of 95% or greater quality steam.

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: Casing valves for selective well stimulation and control. A well system includes at least one valve interconnected in a casing string operable via at least one line external to the casing string to selectively control fluid flow between an exterior and interior of the casing string, and the casing string, valve and line being cemented in a wellbore. A method of selectively stimulating a subterranean formation includes: positioning a casing string in a wellbore, the casing string including spaced apart valves operable via a line to selectively control fluid flow between an interior and exterior of the casing string; and for each of multiple intervals of the formation in sequence, stimulating the interval by opening a corresponding one of the valves, closing the remainder of the valves, and flowing a stimulation fluid from the casing string into the interval.

Abstract: A power plant for combustion of carbonaceous fuels with CO2 capture, comprising a pressurized fluidized bed combustion chamber (2), heat pipes (8, 8?) for cooling of the combustion gas in the combustion, a direct contact cooler (15), a cleaned exhaust pipe (18) for withdrawal of the exhaust gas from the direct contact cooler (15) and introduction of the cooled exhaust gas into a CO2 absorber (19), where a lean exhaust pipe (20) is connected to the top of the absorber (19) for withdrawal of lean exhaust gas from the absorber (20), and a rich absorbent pipe (30) is connected to the bottom of the absorber (19) for withdrawal of rich absorbent and introduction of the rich absorbent into a stripping column (32) for regeneration of the absorbent to give a lean absorbent and a CO2 stream that is further treated to give clean CO2, where a water recirculation pipe (16) is connected to the bottom of the direct contact cooler (15) for withdrawal of used cooling water and connected to the top of the direct contact cooler

Abstract: Methods relate to producing hydrocarbons, such as bitumen in an oil sands reservoir. The methods include utilizing an injector well with multiple horizontal laterals to provide downward fluid drive toward a producer well. Combined influence of gravity and a dispersed area of the fluid drive due to the laterals facilitate a desired full sweep of the reservoir. Fluids utilized for injection include water heated to less than 60 weight percent steam, solvent for the hydrocarbons and emulsifying agent for the hydrocarbons. The methods employing these fluids provide energy efficient recovery of the hydrocarbons.

Abstract: A method for treating a tar sands formation includes providing heat from a first heater located between a steam injection well and a production well in a hydrocarbon containing layer. The first heater, the steam injection well, and the production well are located substantially horizontally in the layer. Heat is provided from a second heater horizontally offset from the first heater. The second heater is located vertically above an injection/production well and substantially horizontally in the layer. Steam is injected into the layer through the steam injection well after a selected amount of heat is provided from the first heater. Hydrocarbons are produced from the layer through the production well. Steam is injected and hydrocarbons are produced alternately through the injection/production well after a selected amount of heat is provided from the second heater.

Abstract: An integrated thermal recovery process using a solvent of a pentane or hexane or both as an additive to, or sole component of, a gravity-dominated process for recovering bitumen or heavy oil from a reservoir. A pentane-hexane specific solvent fraction is extracted at surface from a diluent stream. That pentane-hexane solvent fraction is then injected into the reservoir as part of a gravity-dominated recovery process within the reservoir, and when that solvent fraction is subsequently produced as part of the oil or bitumen blend, it is allowed to remain within the blend to enhance the subsequent blend treating and transportation steps. Meanwhile, the remainder of the diluent from which the solvent stream had been extracted is utilized at surface as a blending stream to serve as an aid in treating of produced fluids and also to serve as a means of rendering the bitumen or heavy oil stream pipelineable.

Abstract: A method of geothermal energy production can include injecting water into a formation, and then automatically decreasing resistance to flow through at least one valve in response to the water changing phase in the formation. A geothermal well system can include a tubular string disposed in a production wellbore, the tubular string including at least one valve, water which flows from an injection wellbore into a formation surrounding the wellbore, and then flows from the formation into the production wellbore as steam, and resistance to flow through the valve decreasing automatically in response to presence of the steam in the production wellbore. Another method of geothermal energy production can include injecting water into a formation from an injection wellbore, the water changing phase in the formation, and then automatically decreasing resistance to fluid flow through at least one valve in response to presence of steam in a production wellbore.

Abstract: Techniques for recovering hydrocarbons, such as heavy hydrocarbons or bitumen, from a cellar region below a horizontal production well can include providing a cellar well section that extends from the horizontal production well into the cellar region. The horizontal production well can be part of a Steam-Assisted Gravity Drainage (SAGD) in situ recovery system, which forms a hydrocarbon depleted region and a hydrocarbon bearing cellar region. The cellar region includes hydrocarbons that have been pre-heated by SAGD operations. One or more cellar well sections are provided from the SAGD production well to extend into the cellar region, in order to form a branched production well. A pressurizing gas can be injected into the hydrocarbon depleted region from a SAGD injection well, in order to provide sufficient pressure to promote production of pre-heated hydrocarbons from the cellar region through the cellar well section.

Abstract: A small supercritical once-through steam generator (OTSG) includes a radiant section with a furnace coil, and a convection section downstream of the radiant section that includes a superheater which is fluidically connected to the furnace coil. Optionally, the OTSG is devoid of a steam separator. An economizer can also be included downstream of the superheater. Supercritical steam can be generated using the OTSG, for use, among other things, in enhanced oil recovery applications.

Abstract: A downhole assembly of an artificial lift system includes: an adapter for connection to production tubing; a receptacle shaft; an up-thrust bearing; a centrifugal pump; and a down-thrust bearing. The receptacle shaft has a latch profile for receiving a latch fastener of a drive coupling and a torsional profile for mating with the coupling to longitudinally and torsionally connect thereto. The up-thrust bearing includes: a thrust driver longitudinally and torsionally connected to the receptacle shaft; and a thrust carrier connected to the adapter. The centrifugal pump includes: a diffuser connected to the adapter; a pump shaft torsionally connected to the receptacle shaft; and an impeller connected to the pump shaft. The down-thrust bearing includes: a thrust driver longitudinally and torsionally connected to the pump shaft; and a thrust carrier connected to the adapter.

Abstract: The method include (a) compressing the feed water at a low pressure; (b) filtering the feed water; (c) compressing the filtered water stream at a medium pressure; (d) supplying the filtered water stream, compressed at a medium pressure, in the liquid phase of an instant expansion tank; (e) in the tank, heating the stream of step (d) by mixing with the recycled stream (h); (f) compressing again at a high pressure the liquid fraction in the tank and supplying it to the heat exchanger inlet; (g) heating the liquid fraction in the exchanger while maintaining the liquid fraction in the liquid state; (h) recycling the fraction from the step (g) in the tank; and (i) expanding the stream of the step (h) in the expansion tank, generating by instant expansion the searched steam; and (j) separating the solid particles formed as a second blowdown containing water and the particles.

Abstract: A process for increasing the efficiency of hydrocarbon recovery from an underground formation containing viscous hydrocarbons through the use of both gravity drainage and mobile water drive. The process comprises a pair of vertically-spaced horizontal wells and a laterally offset horizontal well. A heated fluid is injected into the formation via a first well pair, and an adjacent horizontal well creates a pressure sink to draw the heated fluid laterally to assist growth of the formation drainage area for hydrocarbon recovery improvement. Injected fluids recovered from both producers are collected for recycling.

Abstract: The present disclosure describes a single well predominantly gravity-dominated recovery process for producing viscous hydrocarbons from a subterranean oil sands formation. The process operates a single vertical or inclined well within a formation, the wellbore having an injection means and a production means, the injection means being positioned in the wellbore closer to the surface than the production means. The process provides an area of high mobility adjacent the production means. A mobilizing fluid is injected through the injection means into the formation to mobilize the viscous hydrocarbons in the formation while substantially concurrently producing hydrocarbons through the production means. The gravity dominated process may be SAGD and the present process may be a single vertical or inclined well SAGD process.

Abstract: The present disclosure describes a single well predominantly gravity-dominated recovery process for producing viscous hydrocarbons from a subterranean oil sands formation. The process operates a single vertical or inclined well within a formation, the wellbore having an injection means and a production means, the injection means being positioned in the wellbore closer to the surface than the production means. The process provides an area of high mobility adjacent the production means. A mobilizing fluid is injected through the injection means into the formation to mobilize the viscous hydrocarbons in the formation while substantially concurrently producing hydrocarbons through the production means. The gravity dominated process may be SAGD and the present process may be a single vertical or inclined well SAGD process.

Abstract: Methods and systems generate steam for thermal oil recovery, such as a steam assisted gravity drainage (SAGD) operation. Feedwater is first pressurized to a pressure above that desired for steam injection in the SAGD operation before being heated to avoid at least some nucleate boiling. After being throttled, the local boiling regime is beyond the nucleate boiling regime due to the local pressure drop and the enhanced mixing caused by the throttling process. Two-phase liquid may continue through the boiler generating higher quality steam.

Abstract: Method and systems relate to generating steam by transitioning water from supercritical conditions and injecting the steam that results into a formation to facilitate recovery of oil. Pressurizing and heating the water forms a supercritical fluid that may solvate impurities in the water and/or oxidize the impurities. Retaining the impurities in solution and/or oxidation of the impurities limits fouling problems associated with generating the steam from water recycled in thermal processes, such as steam assisted gravity drainage (SAGD), for recovering the oil.

Abstract: Embodiments of the invention relate to methods for increasing the recovery of hydrocarbons from a subterranean reservoir. In one embodiment, a method for recovering hydrocarbons from a subterranean reservoir is provided. The method includes positioning a first device into a first horizontal well, injecting a first fluid into the first horizontal well through the 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 to drive fluids in the reservoir toward the second well 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.

Abstract: Steam-Over-Solvent Injection in Fractured Reservoirs (SOS-FR) is carried out by treating a fractured hydrocarbon bearing formation penetrated by a well with a first phase of injecting a formation compatible aqueous fluid into the fractured hydrocarbon bearing formation through the well, a second phase of injecting a hydrocarbon solvent into the fractured hydrocarbon bearing formation through the well and at least a third phase of repeating the first phase after the second phase.

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. Synergistic results enable 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: A process of dewatering tailings is provided comprising mixing the tailings with a sufficient amount of an additive or a mixture thereof; depositing the resulting mixture into a disposal area; pumping water from the deposit to one or more sumps, and allowing the deposit to reach a sufficient strength; and removing remaining deposit water and rainfall through one or more of a network of ditches, a decant tower, or a plurality of dike drainage structures to yield a non-segregating deposit for reclamation.

Abstract: Thermal recovery of oils is improved by capturing waste heat from a depleted steam chamber using steam plus foam and an optional gas to carry low quality steam deep into the chamber where the waste heat converts water to steam in situ. Thus, overall steam generation needs and thus costs are reduced.

Abstract: An injector insert apparatus is provided. The injector insert apparatus includes a body that has an inner oil passage that is configured and arranged to allow oil to pass there through. The body further has an annular chamber formed around the inner oil passage. The annular chamber has a chamber opening that is configured to be coupled to receive a flow of thermal gas medium. The body also has at least one injector orifice that provides a passage between the annular chamber and the inner oil passage. The at least one injector orifice is configured to inject the thermal gas medium into oil passing through the inner oil passage.

Abstract: Solvent may be injected into a hydrocarbon reservoir at an increasingly elevated vertical level to allow vapor of the solvent to contact and mobilize viscous hydrocarbons in the reservoir, for producing mobilized hydrocarbons. Solvent may be injected into a mobile zone below a viscous hydrocarbon zone, to allow solvent vapor to ascend to mobilize viscous hydrocarbons in the viscous hydrocarbon zone. A vertical or slanted injection well may be used to inject the solvent into the reservoir, and a production well spaced horizontally apart from the injection well may be used to produce fluids from the reservoir. A bottom-up solvent-aided process may comprise injecting water and liquid solvent into the mobile zone, and then injecting heated water and solvent into the mobile zone.

Abstract: An apparatus for combustion steam generation is provided, which includes a combustion chamber having an inlet end and an outlet end; a manifold at the inlet end configured to introduce a fuel and an oxidizer into the combustion chamber; an outer casing defining a coolant chamber between the outer casing and the combustion chamber; and a plurality of converging coolant inlets for conducting coolant from the coolant chamber into the combustion chamber at or near the outlet end of the combustion chamber. The converging coolant inlets are radially disposed around the combustion chamber and preferably configured to produce a converging-diverging nozzle from the coolant conducted into the combustion chamber. The device may be used in systems and methods for enhanced recovery of subterranean hydrocarbons, by deployment into and operation in a wellbore, where the produced steam and combustion gases are injected into a hydrocarbon formation to enhance hydrocarbon recovery.

Abstract: A system comprising a well drilled into an underground formation comprising hydrocarbons; a production facility at a topside of the well; and 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: The system and method for steam production for extraction of heavy bitumen includes a method of mixing fuel and oxidizing gases, combusting the mixture, mixing combustion gas with water containing solids and organics, separating solids, using heat from the separated gas to produce distilled water, recycling the distillation facility brine with the combustion gas and removing solids thereof, generating steam from the distilled water and injecting the steam through an injection well or using it above ground for oil recovery. The system includes a combustion boiler, a direct contact steam generator, a gas-solids separator, and a heat exchanger with a water treatment facility like a distillation facility. The water feed of the present invention can be water separated from produced oil and/or low quality water salvaged from industrial plants, such as refineries and tailings as make-up water.