Abstract: The disclosure is directed to systems, compositions and methods for tagging, identifying and authenticating bulk liquids. Specifically, the disclosure relates to methods, compositions and systems for selectively and specifically identifying bulk liquids as authentic using, as a tagging compound, photoluminescent carbon nanostructures (PCN's) suspended in a continuous phase that is thermodynamically incompatible with non-polar bulk liquid and/or substantially low concentration of PCNs; and incorporating the suspension into the liquid, wherein the suspension is incorporated at a concentration of continuous phase that is at least one of being below the solubility limit of the suspension's continuous phase in the bulk liquid and a concentration that cannot be observed unaided to the naked eye.

Abstract: An apparatus comprises perforating guns, bypass, and isolator mechanism. The first gun fires upon receipt of a first pressure signal delivered from a first axial side of the first gun. The second perforating gun is mounted on a second axial side of the first perforating gun, and fires upon receipt of a second pressure signal delivered from the first axial side of the first perforating gun. The bypass extends from the first axial side of the first gun to the second gun for communicating the second pressure signal to the second gun. The isolator mechanism is configurable between a first configuration in which the bypass is isolated from receiving a pressure signal to the second perforating gun, and a second configuration in which the bypass is permitted to receive a pressure signal. The isolator mechanism is reconfigurable from the first to the second configuration after the first gun has fired.

Abstract: Disclosed is a method of characterizing a subsurface volume. The method comprises: extracting a geobody from seismic data arranged within a discretized volume comprising a plurality of cells, the geobody comprising a subset of the plurality of cells, each cell of the subset having one or more properties indicative of a particular fluid phase. The extraction of the geobody comprises: determining a propagation probability value for each cell indicative of the probability that a front will propagate through the cell; beginning from a source within the discretized volume, using the propagation probability value to calculate a traveltime for each cell, the travel time describing the time the front takes to travel from the source point to the cell; and using the traveltimes to extract the geobody from the seismic data.

Abstract: A method of hydraulic fracturing is provided which uses metal silicides to generate significant pressure inside a wellbore. The method comprises injecting a fracturing fluid and an aqueous or reacting fluid into the wellbore to react with the fracturing fluid. The fracturing fluid comprises metal silicide, which may be uncoated or coated, and hydrocarbon fluid. The aqueous fluid comprises water. The reacting fluid comprises water or a solvent. A method of removing buildup in pipelines such as subsea pipelines which uses metal silicides to generate heat and pressure inside the pipeline is also provided. The method comprises injecting an organic slug and an aqueous slug. The organic slug comprises metal silicide and hydrocarbon fluid. The aqueous slug comprises water. Alternatively, there is also provided a method for purifying flowback water produced from a hydraulic fracturing process comprising adding metal silicide to the flowback water produced from a hydraulic fracturing process.

Abstract: Systems and methods for enhancing production of viscous hydrocarbons from a subterranean formation. The methods may include heating a hydrocarbon solvent mixture to generate a vapor stream, injecting the vapor stream into the subterranean formation to generate reduced-viscosity hydrocarbons, and producing the reduced-viscosity hydrocarbons from the subterranean formation. The methods also may include selecting a composition of the hydrocarbon solvent mixture by determining a threshold maximum pressure of the subterranean formation, determining a stream temperature at which the vapor stream is to be injected into the subterranean formation, and selecting the composition of the hydrocarbon solvent mixture based upon the stream temperature and the threshold maximum pressure. The systems may include a hydrocarbon production system that may be configured to perform the methods and/or that may include an injection well, an injectant supply assembly, and a production well.

Abstract: Processes for recovering hydrocarbons from subterranean formations are disclosed. The hydrocarbon can be contacted with water or steam and one or more additives, and subsequently recovered. The hydrocarbon can be selected from heavy or light crude oil, bitumen, an oil sand ore, a tar sand ore, and combinations thereof. The additive can be, for example, a fluorinated hydrocarbon. Compositions or mixtures including hydrocarbons, water or steam, and additives are also disclosed.

Abstract: A system and process are provided for recovering oil from an oil-bearing formation. An oil recovery formulation that is first contact miscible with a liquid petroleum composition that is comprised of at least 15 mol % dimethyl sulfide is introduced together with steam or hot water into a subterranean oil-bearing formation comprising heavy oil, extra heavy oil, or bitumen, and oil is produced from the formation.

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: Systems and methods are provided for lifting hydrocarbons from reservoirs. A method includes injecting a heat carrier fluid comprising steam, hot water, or both into a first well and injecting an organic compound into a second well. The organic compound is selected to vaporize to a gas from the heat provided by the heat carrier fluid, forcing produced fluids to the surface. The produced fluids are collected at the surface.

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: A steam-assisted gravity drainage method includes a two stage solvent injection scheme, wherein steam plus solvent injection is followed by steam plus heavier-solvent injection. The two solvent injections improve recoveries of both the heavy oil and the injected solvent while limiting steam requirements, thus improving the economics of the method.

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 method of preparing and using a subterranean formation stabilization agent. The stabilization agent includes a guanidyl copolymer and may be admixed with a fracturing fluid and optionally brine. The stabilization agent is effective in preventing and/or reducing, for example, clay swelling and fines migration from a subterranean formation contacted with the stabilization agent.

Abstract: Methods for improving the quality of hydrocarbon fluids produced by in situ pyrolysis or mobilization of organic-rich rock, such as oil shale, coal, or heavy oil. The methods involve reducing the content of olefins, which can lead to precipitation and sludge formation in pipelines and during storage of produced oils. The olefin content is reduced by arranging wells and controlling well pressures such that hydrocarbon fluids generated in situ are caused to pass through and contact pyrolyzed zones in which coke has been left. This contacting chemically hydrogenates a portion of the olefins in the pyrolysis oil by reducing the hydrogen content of the coke.

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

Abstract: The present invention relates generally to in situ hydrate control during hydrocarbon production when applying a recovery method utilizing cyclic injection of light hydrocarbon solvents. Hydrate formation is limited by creating an energy reserve within a hydrocarbon reservoir adjacent to the wellbore. A heated solvent is injected during an injection phase of a cyclic solvent dominated recovery process to form a heated region adjacent to the wellbore at the end of an injection cycle. The energy reserve is used to act against the evaporative cooling effect caused by subsequent production and associated depressurization to maintain reservoir conditions outside of hydrate formation conditions. In situ conditions are estimated and injected energy amounts are controlled.

Abstract: Methods and apparatus relate to recovering petroleum products from underground reservoirs. The recovering of the petroleum products relies on introduction of heat and solvent into the reservoirs. Supplying water and then solvent for hydrocarbons in direct contact with combustion of fuel and oxidant generates a stream suitable for injection into the reservoir in order to achieve such thermal and solvent based recovery.

Abstract: Embodiments include methods for recovering petroleum products from a formation containing heavy crude oil. In one embodiment, a method includes positioning a steam generator within the petroleum-bearing formation, flowing a fuel source and an oxidizing agent into the steam generator, generating and releasing steam from the steam generator to heat the heavy crude oil, flowing a catalytic material containing a nanocatalyst into the petroleum-bearing formation, and exposing the catalytic material to the heavy crude oil. The method further provides forming lighter oil products from the heavy crude oil within the petroleum-bearing formation and extracting the lighter oil products from the petroleum-bearing formation. In some examples, the fuel source contains methane, syngas, or hydrogen gas, and the oxidizing agent contains oxygen gas, air, or oxygen enriched air. The nanocatalyst may contain cobalt, iron, nickel, molybdenum, chromium, tungsten, titanium, alloys thereof, or combinations thereof.

Abstract: A system and method for cracking, hydrogenating and extracting oil from underground deposits is presented. A method includes injecting syngas into the oil deposit for processing the oil to produce upgraded oil with a reduced density and viscosity. A natural catalytic bed of the oil deposit is utilized to aid a rate of processing the oil into upgraded oil. The upgraded oil with reduced density and viscosity is extracted from the underground oil deposit by transporting the upgraded oil aboveground.

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: A process of increasing recovery rate of hydrocarbon from a reservoir of bituminous sands is disclosed. The process comprises softening bitumen in a region in the reservoir to generate a fluid comprising a hydrocarbon, to allow the fluid to drain by gravity from the region into a production well below the region for recovery of the hydrocarbon; and providing vapour of a compound to the region, and allowing the compound to disperse and condense in the region. The compound is represented by wherein (i) m is 1, and A is —NH2 or —N(H)CH2CH2OH; or (ii) m is 1 or greater than 1, and A is —OR1, R1 being an alkyl group. A mixture comprising steam and vapour of the compound for injection into the reservoir and a system for recovery of hydrocarbon from the reservoir are also disclosed.

Abstract: Embodiments include methods for recovering petroleum products from a formation containing heavy crude oil. In one embodiment, a method includes positioning a steam generator within the petroleum-bearing formation, flowing a fuel source and an oxidizing agent into the steam generator, generating and releasing steam from the steam generator to heat the heavy crude oil, flowing a catalytic material containing a nanocatalyst into the petroleum-bearing formation, and exposing the catalytic material to the heavy crude oil. The method further provides forming lighter oil products from the heavy crude oil within the petroleum-bearing formation and extracting the lighter oil products from the petroleum-bearing formation. In some examples, the fuel source contains methane, syngas, or hydrogen gas, and the oxidizing agent contains oxygen gas, air, or oxygen enriched air. The nanocatalyst may contain cobalt, iron, nickel, molybdenum, chromium, tungsten, titanium, alloys thereof, or combinations thereof.

Abstract: A system and method for producing hydrocarbons in situ from an oil shale, fixed bed hydrocarbon formation disposed below a ground surface and having a naturally occurring, water-flow leached, higher permeability zone next to a lower permeability zone. The system includes at least one injection opening and at least one production opening in the naturally occurring, water-flow leached, higher permeability zone. A heated thermal-energy carrier fluid is injected into the injection opening and circulated horizontally through the higher permeability zone. The carrier fluid pyrolyzes the hydrocarbons in the lower and higher permeability zones in situ by heating the higher permeability zone and the adjacent lower permeability zone along an interface extending substantially between from the injection opening and the production opening and produces at least a portion of the mobilized hydrocarbons by flowing the carrier fluid with the pyrolyzed hydrocarbons through the production opening to the ground surface.

Abstract: A process is disclosed for using heavy petroleum fraction as a drive fluid in the recovery of hydrocarbons from a subterranean formation. The hydrocarbons may be in the form of bitumen or heavy oil. The heavy petroleum fraction may be injected into at least one injection well and hydrocarbons produced out of at least one distinct production well. The heavy petroleum fraction may be co-injected together with steam and/or hot water and/or solvent. The heavy petroleum fraction may be a heavy fraction of a process used to upgrade crude oil, such as a heavy asphaltene fraction produced from solvent deasphalting crude oil produced by this recovery process.

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: The invention relates to a method for producing steam comprising the successive steps of: providing feedwater containing carbonate and/or sulfate ions; adding a crystallizing reagent able to react with carbonate and/or sulfate ions to the feedwater, in order to produce carbonate and/or sulfate crystals; filtering the feedwater with a ceramic membrane to produce a permeate stream; supplying the permeate stream to a boiler; and generating steam in the boiler. The invention also relates to an installation adapted for implementing said method, as well as to a process for extracting hydrocarbons from a subterranean formation using the abovementioned method for producing steam.

Abstract: A method for recovering hydrocarbons from a reservoir includes separating air into a nitrogen-rich gas and an oxygen-rich gas, oxidizing a hydrocarbon fuel with at least part of the oxygen-rich gas to produce steam and a CO2-rich gas, injecting at least part of the steam through an injection well into the reservoir to heat the hydrocarbons, purging the injection well with at least part of the nitrogen-rich gas, and injecting at least part of the CO2-rich gas into the reservoir containing the heated hydrocarbons.

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 method for the integrated production and utilization of synthesis gas for production of mixed alcohols, for hydrocarbon recovery, and for gasoline/diesel refinery, has the following steps: forming a hydrocarbon fuel including coal and/or gas oil; gasifying the hydrocarbon fuel to form synthesis gas that includes hydrogen and carbon monoxide; directing the carbon monoxide and a stoichiometric amount of the hydrogen to an alcohol synthesis unit for the synthesis of mixed alcohols; combusting the remaining hydrogen with oxygen via a downhole gas combustion unit; and adding the water to the combustion to produce high-pressure steam for the recovery of crude oil from the hydrocarbon bearing formation.

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

Abstract: Embodiments include methods for recovering petroleum products from a formation containing heavy crude oil. In one embodiment, a method includes positioning a steam generator within the petroleum-bearing formation, flowing a fuel source and an oxidizing agent into the steam generator, generating and releasing steam from the steam generator to heat the heavy crude oil, flowing a catalytic material containing a nanocatalyst into the petroleum-bearing formation, and exposing the catalytic material to the heavy crude oil. The method further provides forming lighter oil products from the heavy crude oil within the petroleum-bearing formation and extracting the lighter oil products from the petroleum-bearing formation. In some examples, the fuel source contains methane, syngas, or hydrogen gas, and the oxidizing agent contains oxygen gas, air, or oxygen enriched air. The nanocatalyst may contain cobalt, iron, nickel, molybdenum, chromium, tungsten, titanium, alloys thereof, or combinations thereof.

Abstract: A method for producing bitumen or heavy oil from a subterranean reservoir comprising a carbonate mineral solid matrix comprising injection or co-injection of a gas other than carbon dioxide, injection or co-injection of a carbon containing gas containing a relatively low amount of carbon dioxide, injection of steam providing bicarbonate/alkalinity, or increasing the subterranean reservoir pressure, such that the dissolution and re-precipitation of carbonates is suppressed thereby.

Abstract: The invention provides a method of enhancing oil recovery from a subterranean hydrocarbon reservoir, said method comprising injecting into said reservoir through a matrix injection section of a well a microorganism capable of digesting oil, and recovering oil from an oil receiving section of a production well, where said injection section is in said production well or is in an injection well and is above or adjacent said oil receiving section, and wherein microorganism injection is preceded by another oil extraction enhancing procedure.

Abstract: Embodiments include methods for recovering petroleum products from a formation containing heavy crude oil. In one embodiment, a method includes flowing a catalytic material containing the nanocatalyst into the formation containing the heavy crude oil and exposing the heavy crude oil and the catalytic material to a reducing agent (e.g., H2). The method further includes positioning a steam generator within the formation, generating and releasing steam from the steam generator to heat the heavy crude oil containing the catalytic material, forming lighter oil products within the formation, and extracting the lighter oil products from the formation. In another embodiment, a method includes exposing the heavy crude oil and the catalytic material to an oxidizing agent (e.g., O2). The nanocatalyst may contain cobalt, iron, nickel, molybdenum, chromium, tungsten, titanium, oxides thereof, alloys thereof, or combinations thereof.

Abstract: A process is described for in situ recovery of bitumen or heavy oil from a reservoir having a horizontal injection well and a horizontal production well. The process includes a first phase in which steam and a heavy hydrocarbon solvent are injected into the reservoir, a second phase in which the steam and heavy hydrocarbon injections are transitioned to a light hydrocarbon solvent injection, and a third phase in which a light hydrocarbon solvent is injected without further steam or heavy hydrocarbon injection. A displacement gas may be added during any of the phases, and production of hydrocarbons continues throughout all phases. The process employs a high-production start-up phase, followed by lower cost phases which progress a depletion chamber within the reservoir.

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 method of treating a hydrocarbon containing formation is described. The method may include providing a hydrocarbon recovery composition to the hydrocarbon containing formation. Hydrocarbons in the hydrocarbon containing formation may interact with the hydrocarbon recovery composition. The hydrocarbon recovery composition may include an aliphatic anionic surfactant and an aliphatic nonionic additive. In some embodiments, an aliphatic anionic surfactant may be branched. In other embodiments, an aliphatic nonionic additive may be branched.

Abstract: A method of treating a hydrocarbon containing formation is described. The method may include providing a hydrocarbon recovery composition to the hydrocarbon containing formation. Hydrocarbons in the hydrocarbon containing formation may interact with the hydrocarbon recovery composition. The hydrocarbon recovery composition may include an aliphatic anionic surfactant and an aliphatic nonionic additive. In some embodiments, an aliphatic anionic surfactant may be branched. In other embodiments, an aliphatic nonionic additive may be branched.

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: A method and composition are described for improving recovery of oil from an oil reservoir. The method includes adding an effective amount of a fatty acid alkyl ester oil recovery composition to an oil reservoir and recovering oil from the reservoir. The composition may include in predominant proportion a fatty acid alkyl ester as well as effective concentrations of a surfactant, a colloid, and an acid. One exemplary composition includes 96% soy methyl ester, 3% surfactant, and 1% vinegar.

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: Steam is injected into the reservoir, heats the reservoir to mobilize and recover at least a fraction of reservoir hydrocarbons, forming a steam chamber in the reservoir. The steam is continuously injected into the reservoir to mobilize and recover reservoir hydrocarbons therefrom until at least one of (i) an upper surface of the chamber has progressed vertically to a position that is approximately 25 percent to 75 percent the distance from the bottom of the injection well to the top of the reservoir, and (ii) the recovery rate of the hydrocarbons is approximately 25 percent to 75 percent of the peak predicted recovery rate using steam-assisted gravity drainage. A viscosity-reducing hydrocarbon solvent is injected into the reservoir, the solvent being capable of existing in vapor form in the chamber and being just below the solvent's saturation pressure in the chamber, mobilizing and recovering additional hydrocarbons from the reservoir.

Abstract: A process for recovery of hydrocarbons from an underground reservoir penetrated by an injection well and a production well spaced from the injection well, the process comprising:

Abstract: A pair of vertically spaced, parallel, co-extensive, horizontal injection and production wells and a laterally spaced, horizontal offset well are provided in a subterranean reservoir containing heavy oil. Fluid communication is established across the span of formation extending between the pair of wells. Steam-assisted gravity drainage (“SAGD”) is then practised by injecting steam through the injection well and producing heated oil and steam condensate through the production well, which is operated under steam trap control. Cyclic steam stimulation is practised at the offset well. The steam chamber developed at the offset well tends to grow toward the steam chamber of the SAGD pair, thereby accelerating development of communication between the SAGD pair and the offset well. This process is continued until fluid communication is established between the injection well and the offset well.

Abstract: A method for producing hydrocarbons from a subterranean formation comprises injecting steam and an additive into the formation. The additive has at least one nonaqueous fluid, which is selected so that the evaporation temperature of the additive is within about ±150° C. of the steam temperature at the operating pressure. Suitable additives include C1 to C25 hydrocarbons, and combinations thereof. At least a portion of the additive condenses in the formation. The mobility of the hydrocarbons is greater than that obtained using steam alone under substantially similar formation conditions.