Abstract: Methods and apparatus relate to in situ combustion. Configurations of injection and production wells facilitate the in situ combustion. A first production well disposed in a first oil bearing reservoir is spaced from a second production well disposed in a second oil bearing reservoir separated from the first oil bearing reservoir by a stratum having lower permeability than the first and second oil bearing reservoirs. The stratum isolates one of the first and second production wells from one of the first and second oil bearing reservoirs. In situ combustion through the first oil bearing reservoir generates heat that irradiates into the second oil bearing reservoir to enable producing hydrocarbon with the second production well.

Abstract: A modified method for in situ recovery of hydrocarbon from an underground hydrocarbon-containing formation. An “L” shaped production well, having a vertical section, and a lower horizontal leg positioned low in the formation, is provided. The horizontal leg connects to the vertical section at a heel portion, and has a toe portion at an opposite end thereof. Oxidizing gas is injected into the formation in or proximate the vertical section. A combustion front sweeps outwardly from the vertical section and laterally within the formation above the horizontal leg, from the heel to the toe, causing hydrocarbons in the formation above the horizontal leg to drain downwardly into the horizontal leg, which are then delivered to surface via production tubing. A non-oxidizing gas is injected into at least the heel portion and preferably additional portions of the horizontal leg via injection tubing contained within the vertical section of the production well.

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 hydrocarbon production apparatus comprises an injection well, perforated casing, hydrocarbon viscosity reducing fluid injection tubing, a first wellbore restrictor, and a production well. The injection well is bored above the production well within a hydrocarbon reservoir below a ground surface. The injection well comprises a heel end and a toe end. The perforated casing is positioned along a length of the injection well. The hydrocarbon viscosity reducing fluid injection tubing is disposed within the injection well and has a hydrocarbon viscosity reducing fluid injection end. The first wellbore restrictor is transversely disposed within the perforated casing to control hydrocarbon viscosity reducing fluid flow along the injection well, the first wellbore restrictor being spaced closer to the toe end of the injection well than the hydrocarbon viscosity reducing fluid injection end of the hydrocarbon viscosity reducing fluid injection tubing is to the toe end.

Abstract: A system for production of petroleum from an earth formation is provided. The system includes: at least one injection borehole for injecting a thermal source into the formation; at least one production borehole for recovering material including the petroleum from the formation; and at least one drainage borehole intersecting a portion of the at least one production borehole. Methods of recovering petroleum from an earth formation and creating a petroleum production system are also provided.

Abstract: An oil shale formation may be treated using an in situ thermal process. Heat may be applied to the formation to raise a temperature of a portion of the formation to a pyrolysis temperature. Heat input into the formation may be controlled to raise the temperature of portion at a selected rate during pyrolysis of hydrocarbons within the formation. A mixture of hydrocarbons, H2, and/or other formation fluids may be produced from the formation. The mixture may be separated into condensable hydrocarbons and non-condensable hydrocarbons. The condensable hydrocarbons removed from the formation may be a high quality oil that has a relatively low olefin content and a relatively high API gravity.

Abstract: A system and a method for recovering hydrocarbons from a reservoir containing hydrocarbons, by in-situ combustion. The system includes a primary liquid production wellbore having a substantially horizontal primary production length extending through the reservoir, a vent well in fluid communication with the reservoir at a venting position which is relatively higher in the reservoir than the primary production length, an injector apparatus in fluid communication with the reservoir along an injection line in the reservoir which is relatively higher in the reservoir than the primary production length and relatively lower in the reservoir than the venting position, and an injection gas source connected with the injector apparatus.

Abstract: A system for gasification of carbonaceous deposits below the ground surface comprising: an injection well assembly comprising one end positioned at the ground surface and the opposite end of the injection well assembly located within the carbonaceous deposit; a production well assembly comprising one end positioned at the ground surface and the opposite end of the production well assembly located within the carbonaceous deposit; a non-vertical reaction shaft assembly located within the carbonaceous deposit a distance below ground surface, the non-vertical reaction shaft having a length and comprising an injection end in communication with the end of the injection well assembly located within the carbonaceous deposit and a production end in communication with the end of the production well assembly located within the carbonaceous deposit; and a mobile electric device configured to move within the non-vertical reaction shaft assembly.

Abstract: A method for generating a heated product stream downhole is provided wherein a fuel rich mixture is reacted downhole by contact with a catalyst to produce a partially reacted product stream, the fuel rich mixture comprising fuel and oxygen. The partially reacted product stream is brought into contact with an oxidant thereby igniting combustion upon contact producing a combustion product stream. The combustion product stream may be cooled by injecting a diluent flow such as water or CO2. The cooled combustion product stream may be into an oil bearing strata in order to reduce the energy requirements for the production of heavy oil.

Abstract: Methods for treating a tar sands formation are described herein. Methods may include heating at least a section of a hydrocarbon layer in the formation from a plurality of heaters located in the formation. The heat may be controlled so that at least a majority of the section reaches an average temperature of between 200° C. and 240° C., which results in visbreaking of at least some hydrocarbons in the section. At least some visbroken hydrocarbon fluids may be produced from the formation.

Abstract: Recovery of viscous hydrocarbon by hot fluid injection from subterranean formations is assisted by using a specially designed and under-reamed vertical well to form a central production cavity; combined with a plurality of specially perforated horizontal wells drilled from the surface down to the producing formation, and then drilled laterally to intersect and be operatively connected to the central production well cavity. These continuous horizontal uniwells™ behave as single wells with two wellheads, each with multiple injection-production perforation pairs, between which the controlled flow of hot oil via a specialized annular communication zone. The production process is controlled by modulating the hot oil flow where the wellbore fluids act as a hydraulic “P-trap” seal limiting steam bypass. The hot displaced oil is allowed to drain from the lateral horizontal wells in to the central collection cavity.

Abstract: A system for treating a subsurface hydrocarbon containing formation includes one or more shafts. A first substantially horizontal or inclined tunnel extends from one or more of the shafts. A second substantially horizontal or inclined tunnel extends from one or more of the shafts. Two or more heat source wellbores extend from the first tunnel to the second tunnel. The heat source wellbores are configured to allow heated fluid to flow through the wellbores from the first tunnel to the second tunnel.

Abstract: A novel method is provided for in situ combustion and recovery of oil from underground reservoirs including injecting air into the reservoir at a region near the reservoir floor, withdrawing combustion products from a region near the reservoir ceiling, and collecting oil from a horizontal production well near the reservoir floor.

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: A system for treating a tar sands formation is disclosed. A plurality of heaters are located in the formation. The heaters include at least partially horizontal heating sections at least partially in a hydrocarbon layer of the formation. The heating sections are at least partially arranged in a pattern in the hydrocarbon layer. The heaters are configured to provide heat to the hydrocarbon layer. The provided heat creates a plurality of drainage paths for mobilized fluids. At least two of the drainage paths converge. A production well is located to collect and produce mobilized fluids from at least one of the converged drainage paths in the hydrocarbon layer.

Abstract: A system for heating a hydrocarbon containing formation is described. A conduit may be located in an opening in the formation. The conduit includes ferromagnetic material. An electrical conductor is positioned inside the conduit, and is electrically coupled to the conduit at or near an end portion of the conduit so that the electrical conductor and the conduit are electrically coupled in series. Electrical current flows in the electrical conductor in a substantially opposite direction to electrical current flow in the conduit during application of electrical current to the system. The flow of electrons is substantially confined to the inside of the conduit by the electromagnetic field generated from electrical current flow in the electrical conductor so that the outside surface of the conduit is at or near substantially zero potential at 25° C. The conduit may generate heat and heat the formation during application of electrical current.

Abstract: The invention provides hydrocarbon recovery processes that may be utilized in heavy oil reservoirs. Horizontal hydrocarbon production wells may be provided below horizontal oxidizing gas injection wells, with distant combustion gas production wells offset from the injection well by a distance that is greater than the hydrocarbon production well offset distance. Oxidizing gases injected into the reservoir through the injection well support in situ combustion, to mobilize hydrocarbons. The process may be adapted for use in a reservoir that has undergone depletion of petroleum in a precedential petroleum recovery process, such as a steam-assisted-gravity-drainage process, leaving a residual oil deposit in the reservoir as well as mobile zone chambers. Processes of the invention may be modulated so that a portion of the residual oil supports in situ combustion, while a larger portion of the residual oil is produced, by channelling combustion gases along the pre-existing mobile zones with the reservoir.

Abstract: A process for improved safety and productivity when undertaking oil recovery from an underground reservoir by the toe-to-heel in situ combustion process employing a horizontal production well. Water, steam, and/or a non-oxidizing gas, which in the preferred embodiment substantially comprises carbon dioxide which acts as a gaseous solvent, is injected into the reservoir for improving recovery in an in situ combustion recovery process, via either an injection well, a horizontal well, or both.

Abstract: A process for improved safety and productivity when undertaking oil recovery from an underground reservoir by the toe-to-heel in situ combustion process employing a horizontal production well. Water, steam, and/or a non-oxidizing gas, which in the preferred embodiment substantially comprises carbon dioxide which acts as a gaseous solvent, is injected into the reservoir for improving recovery in an in situ combustion recovery process, via either an injection well, a horizontal well, or both.

Abstract: An automatic control system that protects downhole equipment and surface equipment from high temperatures resulting from the breakthrough of injection vapor. The system operates to derive an estimate of the temperature of production fluid at a location upstream from the downhole equipment. An alarm signal is generated in the event that this temperature exceeds a threshold temperature characteristic of injection vapor breakthrough. Electric power to the downhole equipment is automatically shut off in response to receiving the alarm signal. A bypass valve selectively directs production fluid to a bypass path. The system operates to derive an estimate of the temperature of the production fluid at a location upstream from the surface equipment. An alarm signal is generated when this temperature exceeds a threshold temperature characteristic of injection vapor breakthrough. The bypass valve is automatically controlled to direct production fluid to the bypass path in response to receiving the alarm signal.

Abstract: A system and method for extracting hydrocarbon products from oil shale using nuclear energy sources for energy to fracture the oil shale formations and provide sufficient heat and pressure to produce liquid and gaseous hydrocarbon products. Embodiments of the present invention also disclose steps for extracting the hydrocarbon products from the oil shale formations.

Abstract: A method and apparatus for production of material from a subsurface earth formation being intersected by a wellbore that is lined with a well casing. After preparing the well casing by forming injection and production openings or removing a section of the casing to define a borehole interval, a plurality of lateral injection and production passages are formed that extend into the subsurface earth formation from the casing openings or borehole interval. Packers within the well casing define an injection compartment that is in communication with the lateral injection passages and a production compartment that is isolated from the injection compartment. Steam or other injection fluid is injected into the formation via an injection conduit extending from the surface to the injection compartment. Formation fluid migrating through the formation to the production passages is produced via a production conduit extending from the surface to the production compartment.

Abstract: A method and apparatus for recovering viscous hydrocarbons from a subsurface reservoir holding the same using an essentially horizontal well bore having a production inlet and containing steam injection tubing that carries a plurality of jet nozzles oriented to emit steam along said injection tubing towards said production inlet.

Abstract: A process for improved safety and productivity when undertaking oil recovery from an underground reservoir by the toe-to-heel in situ combustion process employing a horizontal production well. Water, steam, and/or a non-oxidizing gas, which in the preferred embodiment substantially comprises carbon dioxide which acts as a gaseous solvent, is injected into the reservoir for improving recovery in an in situ combustion recovery process, via either an injection well, a horizontal well, or both.

Abstract: Systems and methods are provided for treating a wellbore using a loop system to heat oil in a subterranean formation contacted by the wellbore. The loop system comprises a loop that conveys a fluid (e.g., steam) down the wellbore via a injection conduit and returns fluid (e.g., condensate) from the wellbore via a return conduit. A portion of the fluid in the loop system may be injected into the subterranean formation using one or more valves disposed in the loop system. Alternatively, only heat and not fluid may be transferred from the loop system into the subterranean formation. The fluid returned from the wellbore may be re-heated and re-conveyed by the loop system into the wellbore. Heating the oil residing in the subterranean formation reduces the viscosity of the oil so that it may be recovered more easily.

Abstract: A process for the recovery of hydrocarbons from a hydrocarbon bearing formation having an extraction chamber where the extraction chamber has an extraction surface. The process has the steps of heating a solvent, such as propane, and then placing the solvent into the extraction chamber at a temperature and a pressure sufficient for the solvent to be in a vapor state in the chamber and to condense on the extraction surface. The next step is to produce a liquid blend of solvent and heavy oil and then to separate the solvent from said heavy oil. Then the solvent is purified, before being re-injected into the formation again. The purification step removes less condensable fractions from the solvent to ensure a purity that is high enough to support continued heat transfer at extraction conditions. The pressure and temperature are set to levels to cause less condensable fractions to drain away with the liquid bitumen and solvent blend that is produced, thus mitigating heat transfer poisoning.

Abstract: The recovery of hydrocarbons from hydrocarbon bearing rock, sands or other geological materials (collectively “rock”) uses a recovery fluid. In certain embodiments, the recovery fluid includes miscible compounds or an azeotrope-forming mixture (including an azeotrope), used alone or with other compositions. Two or more compounds in the recovery fluid yield a mixture with different and/or improved characteristics over those of one or more of the component compounds in both liquid and vapor states.

Abstract: A variety of methods for thermal recovery of natural gas and bitumen from a formation containing the latter. In general, the methods incorporate a series of existing, but previously uncombined technologies. A modified flue gas from the steam generators conventionally used in a SAGD recovery operation is injected into the formation to enhance recovery with the produced fluids, natural gas, bitumen, inter alia are further processed. The injection of the flue gas conveniently is disposed of and further acts to repressurize the formation which otherwise becomes depressurized when depleted of natural gas. Accordingly, environmental and economic advantages are realized with the methodology.

Abstract: Oil is recovered from a borehole using a pump having limited high temperature breakdown resistance. The pump is located in a borehole having a cooling zone, in which the temperature of the well fluid is reduced to, or below, the temperature at which the temperature breakdown resistance of the pump is commercially acceptable. In one embodiment, the pump is a positive displacement pump which is mechanically driven from the well head location, such as through a rotating rod. The cooling zone is provided by positioning and controlling the pump to maintain a sufficiently low pressure at the pump intake to cause a portion of the liquid well fluid to vaporize prior to entry of the liquid into the pump, creating bubbles which pass upwardly in the wellbore in a zone passing the pump. The evolution of the vapor cools the well fluid to the acceptable temperature.

Abstract: The present invention is directed to a method of increasing hydrocarbon production in an existing well in a hydrocarbon reservoir. The method includes the steps of forming a substantially horizontal transverse fractured wellbore that intersects the existing well and injecting a fluid remote from the existing well so as to form a fluid front that sweeps the hydrocarbons into the horizontal transverse fractured wellbore. Successive fractures can be sealed to control propagation of the fluid front and delay infiltration of the fluid into the production.

Abstract: A method for recovering hydrocarbon trapped in a hydrate formation, comprising the steps of (a) contacting the hydrate formation with an aqueous solution comprising from 10% to 75% by weight of a salt such as potassium formate or acetate salt to liberate hydrocarbon from the hydrate formation and producing a mixture of hydrocarbon and water vapour; (b) transporting the hydrocarbon/water vapour mixture and the aqueous solution to a separator, whereby the said aqueous solution absorbs water vapour from the mixture during the transportation step, to form a more dilute aqueous solution of the alkali metal salt, thereby inhibiting formation of hydrocarbon hydrates; (c) separating hydrocarbon from said dilute aqueous solution; (d) regenerating the aqueous solution of step (a) by heating said dilute aqueous solution to remove absorbed water vapour; and (f) recycling the regenerated aqueous solution to step (a).

Abstract: Steam assisted gravity drainage (“SAGD”) is practised in a first section of a reservoir containing heavy oil. When steam/oil ratio rises sufficiently, steam injection into the first section is curtailed or terminated. Non-condensible gas is then injected into the section to pressurize it and production of residual oil and steam condensate is continued. Concurrently with pressurization, SAGD is practised in an adjacent reservoir section. As a result, some of the residual oil in the first section is recovered and steam loss from the second section to the first section is ameliorated.

Abstract: An in situ process for treating an oil containing formation is provided. The process may include providing heat from one or more heaters to at least a portion of the formation. The heat may be allowed to transfer from the one or more heaters to a part of the formation such that heat from the one or more heat sources pyrolyzes at least some hydrocarbons within the part. Hydrocarbons may be produced from the formation.

Abstract: Hydrocarbons are recovered from a subterranean reservoir by drilling an injection well bore having an outlet in the reservoir and drilling a production well bore spaced apart from the injection well bore and having an inlet in the reservoir. A permeable zone having a first patterned web of channels radiating outwardly from the outlet of the injection well and connecting to a second patterned web of channels radiating outwardly from the inlet of the production well is formed in the reservoir. Heated fluid is passed from the outlet into the permeable zone to mobilize hydrocarbons in the subterranean reservoir so that the mobilized hydrocarbons flow toward the inlet. The permeable zone fans out from the wells to cover an extended area of the reservoir to enhance hydrocarbon recovery by heating hydrocarbons from an expanded area of a reservoir and gravity draining the hydrocarbons.

Abstract: In an embodiment, a method for heating a hydrocarbon containing formation may include providing heat from one or more heaters to an opening in the formation. A first end of the opening may contact the earth's surface at a first location and a second end of the opening may contact the earth's surface at a second location. The heat may be allowed to transfer from the opening to at least a part of the formation. The transferred heat may pyrolyze at least some hydrocarbons in the formation. In certain embodiments, providing the heat to the opening may include providing heat, heated materials, and/or oxidation products from at least one heater to the opening.

Abstract: In an embodiment, a method of treating a kerogen and liquid hydrocarbon containing formation in situ may include providing heat from one or more heat sources to at least a portion of the formation. Heat may be allowed to transfer from the one or more heat sources to a part of the formation. In some embodiments, at least a portion of liquid hydrocarbons in the part may be mobilized. At least a portion of kerogen in the part may be pyrolyzed. In certain embodiments, a pressure within at least a part of the formation may be controlled. The pressure may be controlled to be at least about 2.0 bars absolute. A mixture may be produced from the formation.

Abstract: A method for treating a relatively permeable formation containing heavy hydrocarbons in situ may include providing heat from one or more heat sources to a portion of the formation. The heat may be allowed to transfer from the heat sources to a selected section of the formation. The transferred heat may reduce the viscosity of at least some hydrocarbons within the selected section. A gas may be provided to the selected section of the formation. The gas may produce a flow of hydrocarbons within the selected section. A mixture of hydrocarbons may be produced from the selected section.

Abstract: A method for treating a relatively permeable formation containing heavy hydrocarbons in situ may include providing heat from one or more heat sources to a portion of the formation. The heat may be allowed to transfer from the heat sources to a selected section of the formation. The transferred heat may pyrolyze at least some hydrocarbons within the selected section. A temperature proximate a selected portion of a heater well may be selectively limited to inhibit coke formation at or near the selected portion. A mixture of at least some hydrocarbons may be produced through the selected portion of the heater well.

Abstract: A process for producing hydrocarbons through a heater wellbore positioned in a hydrocarbon containing formation. The in situ treatment process may include providing heat from one or more heaters to at least a portion of the formation. The heat may be allowed, in some embodiments, to transfer from one or more heaters to a selected section of the formation. Heat that is allowed to transfer to the selected section may pyrolyze at least some of the hydrocarbons within the selected section. The process may include, in some embodiments, selectively limiting a temperature proximate a selected portion of a heater wellbore to inhibit coke formation at or near the selected portion. In some embodiments fluids may be produced at certain locations of a heater wellbore such that coke formation is inhibited.

Abstract: A process for the recovery of hydrocarbons from a hydrocarbon bearing formation having an extraction chamber where the extraction chamber has an extraction surface. The process has the steps of heating a solvent, such as propane, and then placing the solvent into the extraction chamber at a temperature and a pressure sufficient for the solvent to be in a vapor state in the chamber and to condense on the extraction surface. The next step is to produce a liquid blend of solvent and heavy oil and then to separate the solvent from said heavy oil. Then the solvent is purified, before being re-injected into the formation again. The purification step removes less condensable fractions from the solvent to ensure a purity that is high enough to support continued heat transfer at extraction conditions. The pressure and temperature are set to levels to cause less condensable fractions to drain away with the liquid bitumen and solvent blend that is produced, thus mitigating heat transfer poisoning.

Abstract: An oil shale formation may be treated using an in situ thermal process. Heat may be provided to a portion of the formation. Heat may be allowed to transfer from one or more heat sources to a section of the formation. Hydrocarbons, H2, and/or other formation fluids may be produced from the formation through a production well. Conditions at the production well may be controlled to inhibit coking at or near the production well.

Abstract: A hydrocarbon containing formation may be treated using an in situ thermal process. Hydrocarbons, H2, and/or other formation fluids may be produced from the formation. Heat may be applied to a first portion of the formation to mobilize hydrocarbons within the formation. Heat may be applied to a second portion of the formation to raise a temperature of the second portion to a pyrolysis temperature. Vaporized hydrocarbons and pyrolysis fluids may be produced from the formation.

Abstract: LASER-CSS provides a method to improve cyclic steam-based thermal recovery methods for heavy oils and bitumen. A key improvement over prior art consists of mixing liquid hydrocarbons into the injected steam instead of injecting such hydrocarbon as a separate slug in front of a steam stimulation cycle. The objective of the invention is to enhance field applications of Cyclic Steam Stimulation (CSS) by contacting and mobilizing more of the bitumen with the same amount of steam. This is to help increase the recovery efficiency and ultimate recovery normally achieved with conventional CSS-type process operations. The proposed LASER-CSS method utilizes existing CSS wells at some intermediate stage of reservoir depletion. Liquid hydrocarbons are directly mixed and flashed into the injected steam lines, injected into the CSS wellbores and further transported as vapors to contact heavy oil or bitumen surrounding steamed areas between adjacent wells.

Abstract: A hydrocarbon containing formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H2, and/or other formation fluids may be produced from the formation. Heat may be applied to the formation to raise a temperature of a portion of the formation to a pyrolysis temperature. The mixture produced from the formation may have a relatively high hydrogen partial pressure, and a large portion of the pressure within the formation may be attributable to hydrogen partial pressure.

Abstract: The present invention relates to an oil production method for producing oil from an oil-containing reservoir with using horizontal wells, by drilling a gas injection well and a production well to be locate at an appropriate distance between them, depending upon at least a ratio between an averaged vertical permeability and an averaged horizontal permeability in the oil-containing reservoir producing the oil therefrom.

Abstract: A wet electric heating (“WEH”) process involves establishing electrode zones (“e-zones”) around conductors (e.g., wells) for distributing electric current and thereby generating and distributing heat accordingly through a target region in a subterranean formation having hydrocarbons. The inventive WEH process takes into account e-zone geometric shape, spacing and/or spatial orientation to provide a more diffuse distribution of increased temperature values within the target region, compared to conventional electric heating processes, during at least the first 10% of a time interval when an electric potential is applied.

Abstract: The present invention relates to recovery and treatment of underground mineral deposits by multitude of directional and multi-functional wells drilled from the super daisy shaft through which the dynamics and dragging forces of fluid means is developed synergistically with complex rubblization and other techniques, and more particularly where the same wells assist in creation of the pressurized barriers to contain the exploitation field for treatment and recovery of minerals.

Abstract: There is disclosed a method and apparatus for treating produced water from a heavy oil thermal recovery unit to achieve water recovery and recycle levels of greater than 80% and as high as 100% to achieve zero discharge criteria. The method includes the initial steps of capturing the waste heat energy from the high pressure steam separator located downstream of the steam generators. Further, transferring the heat energy into a heated separator and reboiler exchanger to distill oil reservoir produced water and recover distilled water and a concentrated brine or solid product. The heated separator concentrated stream is circulated through the reboiler exchanger to maintain from 1% to about 50% mass vapour in the stream returning to the heated separator and prevent fouling and scaling. The apparatus includes a low pressure waste energy separator, heated separator and vapour compressor in combination with a forced circulation circuit to generate the distilled water.

Abstract: A hydrocarbon containing formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H2, and/or other formation fluids may be produced from the formation. A portion of the mixture may be a condensable component that includes a relatively small amount of olefins and a relatively small amount of tri- and higher order aromatics.

Abstract: A hydrocarbon containing formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H2, and/or other formation fluids may be produced from the formation. Heat may be applied to the formation to raise a temperature of a portion of the formation to a pyrolysis temperature. An unpyrolyzed section may be left between two substantially pyrolyzed sections to inhibit subsidence of the formation.