Abstract: Thermal recovery methods for recovering viscous hydrocarbons from a subterranean formation. The thermal recovery methods include performing a plurality of injection cycles. Each injection cycle in the plurality of injection cycles includes injecting a heated solvent vapor stream into a heated chamber that extends within the subterranean formation and fluidly contacting the viscous hydrocarbons with the heated solvent vapor stream to generate mobilized viscous hydrocarbons. Each injection cycle also includes injecting a steam stream into the heated chamber. The thermal recovery methods further include producing a chamber liquid and/or mobilized viscous hydrocarbons from the subterranean formation.

Abstract: Enhanced methods for recovering viscous hydrocarbons from a subterranean formation as a follow-up to thermal recovery processes. The methods include injecting a solvent flood vapor stream into a first thermal chamber, which extends within the subterranean formation, via a solvent flood injection well that extends within the first thermal chamber. The injecting includes injecting to generate solvent flood-mobilized viscous hydrocarbons within the subterranean formation. The methods also include, at least partially concurrently with the injecting, producing the solvent flood-mobilized viscous hydrocarbons from a second thermal chamber, which extends within the subterranean formation, via a solvent flood production well that extends within the second thermal chamber.

Abstract: Thermal recovery methods for recovering viscous hydrocarbons from a subterranean formation. The thermal recovery methods include performing a plurality of injection cycles. Each injection cycle in the plurality of injection cycles includes injecting a heated solvent vapor stream into a heated chamber that extends within the subterranean formation and fluidly contacting the viscous hydrocarbons with the heated solvent vapor stream to generate mobilized viscous hydrocarbons. Each injection cycle also includes injecting a steam stream into the heated chamber. The thermal recovery methods further include producing a chamber liquid and/or mobilized viscous hydrocarbons from the subterranean formation.

Abstract: The present disclosure relates to production of a bitumen product from a subterranean reservoir with improved processes for solvent recovery at end of production or near end of production (i.e., “late life”) of heavy oil from a solvent-based heavy oil extraction process. The process include converting at least some of the wells in the subterranean reservoir, and injecting gas phase dilution agent into the reservoir, converting at least a portion of the liquid solvent to a gas phase, and recovering, in the vapor phase, at least a portion of the solvent remaining in the reservoir.

Abstract: Methods and apparatus for recovering heavy oil from subterranean reservoirs. A steam-utilizing heavy oil recovery process may be used to recover the heavy oil while employing a steam-solvent mixture. The solvent may be a tailored hydrocarbon solvent obtained from a precursor mixture of hydrocarbon compounds from which light end hydrocarbon compounds have been removed.

Abstract: Methods and apparatus for recovering heavy oil from subterranean reservoirs. A steam-utilizing heavy oil recovery process may be used to recover the heavy oil while employing a steam-solvent mixture. The solvent may be a tailored hydrocarbon solvent obtained from a precursor mixture of hydrocarbon compounds from which light end hydrocarbon compounds have been removed.

Abstract: Methods and apparatus for recovering heavy oil from subterranean reservoirs. A steam-utilizing heavy oil recovery process may be used to recover the heavy oil while employing a steam-solvent mixture. The solvent may be a tailored hydrocarbon solvent obtained from a precursor mixture of hydrocarbon compounds from which light end hydrocarbon compounds have been removed.

Abstract: Methods and apparatus for recovering heavy oil from subterranean reservoirs. A steam-utilizing heavy oil recovery process may be used to recover the heavy oil while employing a steam-solvent mixture. The solvent may be a tailored hydrocarbon solvent obtained from a precursor mixture of hydrocarbon compounds from which light end hydrocarbon compounds have been removed.

Abstract: Methods and apparatus for recovering heavy oil from subterranean reservoirs. A steam-utilizing heavy oil recovery process may be used to recover the heavy oil while employing a steam-solvent mixture. The solvent may be a tailored hydrocarbon solvent obtained from a precursor mixture of hydrocarbon compounds from which light end hydrocarbon compounds have been removed.

Abstract: Methods and apparatus for recovering heavy oil from subterranean reservoirs. A steam-utilizing heavy oil recovery process may be used to recover the heavy oil while employing a steam-solvent mixture. The solvent may be a tailored hydrocarbon solvent obtained from a precursor mixture of hydrocarbon compounds from which light end hydrocarbon compounds have been removed.

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: 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: A method of operating a cyclic solvent-dominated recovery process (CSDRP) for recovering viscous oil from a subterranean reservoir of the viscous oil. The cyclic solvent process involves using an injection well to inject a viscosity-reducing solvent into a subterranean viscous oil reservoir. Reduced viscosity oil is produced to the surface using the same well used to inject solvent. The process of alternately injecting solvent and producing a solvent/viscous oil blend through the same wellbore continues in a series of cycles until additional cycles are no longer economical. Aspects of the invention relate to the particular volume of solvent injected in each cycle, when to switch from production to injection, the injection pressure to be used, the production pressure to be used, and to middle and late life operation.

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.