Methods are provided herein for an end-of-life recovery of mobilized hydrocarbons from a stranded hydrocarbon pay zone within a subterranean reservoir by way of a recovery well. In some embodiments, the stranded pay zone is located between mobilized hydrocarbon zones of thermal recovery operations. In some embodiments, the stranded pay zone is an upper stranded pay zone located above a mobilized hydrocarbon zone of a thermal recovery operation. In some embodiments, the stranded pay zone is a lower stranded pay zone located below a mobilized hydrocarbon zone of a thermal recovery operation. The methods herein involve commencing end-of-life recovery at an end-of-life stage after a production threshold is achieved for thermal recovery operations.

Methods are provided herein for an end-of-life recovery of mobilized hydrocarbons from a stranded hydrocarbon pay zone within a subterranean reservoir by way of a recovery well. In some embodiments, the stranded pay zone is located between mobilized hydrocarbon zones of thermal recovery operations. In some embodiments, the stranded pay zone is an upper stranded pay zone located above a mobilized hydrocarbon zone of a thermal recovery operation. In some embodiments, the stranded pay zone is a lower stranded pay zone located below a mobilized hydrocarbon zone of a thermal recovery operation. The methods herein involve commencing end-of-life recovery at an end-of-life stage after a production threshold is achieved for thermal recovery operations.

A method is provided for producing hydrocarbons from a subterranean reservoir. A mixture of steam and H.sub.2S-sorbent particles (e.g., nanoparticles) is injected into the subterranean reservoir. This may be performed during the steam phase of a steam injection operation, such as steam assisted gravity drainage (SAGD), steam flooding, or cyclic steam stimulation, which is performed on the reservoir. The injected steam reduces the viscosity of the hydrocarbons in the subterranean formation. The injected H.sub.2S-sorbent particles attach to the subterranean reservoir and adsorb H.sub.2S therein. The hydrocarbons are produced to the surface, without producing the H.sub.2S-sorbent particles with adsorbed H.sub.2S that remain attached to the subterranean reservoir.

A method is provided for producing hydrocarbons from a subterranean reservoir. A mixture of steam and H.sub.2S-sorbent particles (e.g., nanoparticles) is injected into the subterranean reservoir. This may be performed during the steam phase of a steam injection operation, such as steam assisted gravity drainage (SAGD), steam flooding, or cyclic steam stimulation, which is performed on the reservoir. The injected steam reduces the viscosity of the hydrocarbons in the subterranean formation. The injected H.sub.2S-sorbent particles attach to the subterranean reservoir and adsorb H.sub.2S therein. The hydrocarbons are produced to the surface, without producing the H.sub.2S-sorbent particles with adsorbed H.sub.2S that remain attached to the subterranean reservoir.

An embodiment of a fluid control device includes a housing, a fluid channel defined within the housing, the fluid channel having a first surface and a second surface opposing the first surface and having an inlet, and a flow control body disposed in the fluid channel, the flow control body tapering toward the inlet. The body, in use, causing fluid flowing through the channel to diverge into at least a first path between the first surface and a first side of the body, and a second path defined by at least by the second side of the body. A geometry of the first path and the second path selected is based on a subcool of the fluid at a pressure of the fluid entering the fluid channel, and the geometry is selected to induce cavitation of the fluid to choke fluid flow through the fluid channel.

A method for reducing water production from a hydrocarbon bearing subterranean formation includes identifying a high permeability zone in the formation and injecting a dense CO.sub.2 composition from a production well into the high permeability zone. The dense CO.sub.2 composition includes dense CO.sub.2 and a thickener soluble in the dense CO.sub.2. The thickener includes a copolymer that is the polymerized reaction product of monomers that include at least one alkenyl ether or dialkenyl ether monomer, at least one acrylate or methacrylate monomer, at least one structural monomer, and at least one allyl ester monomer. After injecting the dense CO.sub.2 composition into the high permeability zone, the method includes withdrawing hydrocarbons from the hydrocarbon bearing subterranean formation through the production well. The dense CO.sub.2 composition blocks pores in the high permeability zone to reduce or prevent flow of water from the high permeability zone into the production well.

A method for reducing water production from a hydrocarbon bearing subterranean formation includes identifying a high permeability zone in the formation and injecting a dense CO.sub.2 composition from a production well into the high permeability zone. The dense CO.sub.2 composition includes dense CO.sub.2 and a thickener soluble in the dense CO.sub.2. The thickener includes a copolymer that is the polymerized reaction product of monomers that include at least one alkenyl ether or dialkenyl ether monomer, at least one acrylate or methacrylate monomer, at least one structural monomer, and at least one allyl ester monomer. After injecting the dense CO.sub.2 composition into the high permeability zone, the method includes withdrawing hydrocarbons from the hydrocarbon bearing subterranean formation through the production well. The dense CO.sub.2 composition blocks pores in the high permeability zone to reduce or prevent flow of water from the high permeability zone into the production well.

Recovering heavy oil from a subterraneous formation penetrated by at least one injection well and one production well, by injecting into the injection well a mixture of steam and an alkyl alkoxylated carboxylate salt, increasing the apparent viscosity of the steam while at the same time lowering the steam mobility, and recovering oil from the subterranean formation.

Recovering heavy oil from a subterraneous formation penetrated by at least one injection well and one production well, by injecting into the injection well a mixture of steam and an alkyl alkoxylated carboxylate salt, increasing the apparent viscosity of the steam while at the same time lowering the steam mobility, and recovering oil from the subterranean formation.

A superconducting down-hole heating device with a superconducting cable, a cryostat around the superconducting cable, and a heat source coupled to the superconducting cable. The device is configured to use within a well-casing, and to produce heat outside of the cryostat and not inside of the cryostat.