A carbon-based gas extraction and storage system is described that includes a coal bed methane (CBM) energy production facility. A first well includes a first pump configured operate in an extraction mode in which methane from the CBM chamber is pumped from a CBM chamber, and convertible to an insertion mode in which CO2 is pumped into the CBM chamber. The second well extracts CBM from the CBM chamber. A controller controls the first pump to operate in the extraction mode and controllably switch to the insertion mode in which CO2 emissions from CBM processed by the CBM energy production facility are injected in the CBM chamber. Thus, first pump injects the CO2 emissions into the CBM chamber to assist in extraction of CBM and to permanently store the CO2 in the CBM chamber.

Provided are methods of recovering oil from a reservoir using carbon dioxide foam flooding in which a carbon dioxide foam of increased strength is used.

Methods of Enhanced Oil Recovery (EOR) from an oil reservoir by CO.sub.2 flooding are disclosed. One method comprises producing a well stream from the reservoir; separating the well stream into a liquid phase and a gas phase with a first gas/liquid separator, wherein the gas phase comprises both CO.sub.2 gas and hydrocarbon gas; cooling the gas phase with a first cooler; compressing the gas phase using a first compressor into a compressed stream; mixing the compressed stream with an external source of CO.sub.2 to form an injection stream; and injecting the injection stream into the reservoir. Systems for EOR from an oil reservoir by CO.sub.2 flooding are also disclosed.

A method comprises introducing a sequestration fluid through one or more injection wells into an underground reservoir containing at least one native fluid. Each injection well includes one or more injection well reservoir openings through which the sequestration fluid flows from the injection well into the underground reservoir. The method further comprises simultaneously or substantially simultaneously withdrawing a portion of the at least one native fluid through one or more withdrawal wells. Each injection well includes one or more withdrawal well reservoir openings through which the portion of the at least one native fluid flows from the underground reservoir into the withdrawal well. The one or more withdrawal well reservoir openings are proximate to the one or more injection well reservoir openings.

Methods of enhancing productivity of a subterranean wellbore may include introducing a carbonated mixture comprising water and carbonate anions to a target zone of the subterranean wellbore; introducing basaltic particles to the target zone of the subterranean wellbore; contacting the basaltic particles with the carbonated mixture; dissolving at least a part of the basaltic particles with the carbonated mixture to release divalent cations including calcium cations, magnesium cations and ferrous cations; reacting, in the target zone of the subterranean wellbore, the divalent cations with the carbonate anions in the carbonated mixture to produce carbonate minerals; providing stimulus to the basaltic particles and the carbonated mixture to promote the dissolving and the reacting; depositing at least a part of the carbonate minerals to fractures of the target zone; and monitoring the reacting of the divalent cations with the carbonated anions and depositing.

A method for the regulation of an installation for the geological sequestration of carbon dioxide includes a structure; a CO.sub.2 storage compartment, received in said structure; a device for injecting CO.sub.2 into a geological reservoir; an energy production device; and an energy storage device. The energy production device supplies a power that varies over time, between low, intermediate, and high states. When the power supplied is in the low state, the injection device is powered by the energy storage device; and when said power supplied is in the high state, the injection device is powered by the power generation device, to ensure a continuous injection of CO.sub.2 into the geological reservoir.

A first well, configured to act as a production well or an injection well, is formed. The first well includes a first horizontal portion. A second well, configured to act as a production well or an injection well, is formed. The second well includes a second horizontal portion substantially parallel to the first horizontal portion. The first horizontal portion and the second horizontal portion are at different depths. A fluid is injected into a geologic formation through the first well for a first duration of time. Hydrocarbons are produced from the geologic formation through the second well for the first duration of time. A fluid is injected into a geologic formation through the second well for a second duration of time. Hydrocarbons are produced from the geologic formation through the first well for the second duration of time.

The present invention provides compositions and methods for enhancing oil recovery from low permeability subterranean formation using three mechanisms: repressurization; reduction of interfacial tension; and increased permeability. The subject compositions comprise a chelating agent, a biosurfactant, a carbonate or bicarbonate salt, water, and a pH adjusting substance, which when applied to an oil-bearing formation according to the methods of the subject invention, allow for controlled release of carbon dioxide within the formation without complicated machinery or gas-producing microorganisms.

A method for enhanced oil recovery may comprise inputting into a computer system data related to properties of a hydrocarbon reservoir and depletion of the hydrocarbon reservoir; calculating, with the computer system, a current oil saturation and a current gas saturation of the hydrocarbon reservoir based on the data; determining, with the computer system, that the current reservoir pressure is less than a bubble point pressure based on the data; calculating, with the computer system, a time to repressure the hydrocarbon reservoir by waterflooding based on the data; comparing, with the computer system, the data related to properties of the hydrocarbon reservoir to oil recovery screening criteria; selecting a flooding technique from a plurality of flooding techniques, with the computer system, based on satisfying the oil recovery screening criteria with the data related to properties of the hydrocarbon reservoir.

A method for recovering hydrocarbons from a hydrocarbon bearing formation includes introducing a first solution having a first salt into the hydrocarbon bearing formation. A second solution is also introduced into the hydrocarbon bearing formation, wherein the second solution has a second salt and a foaming agent. The first salt and the second salt produces a nitrogen gas, and the nitrogen gas and the foaming agent produces a foam formed in-situ within the formation. The foam forms a foam barrier, and carbon dioxide is introduced into the formation to form a gas cap, wherein the carbon dioxide gas cap has a gas front that is separated from the hydrocarbons by the foam barrier.