Abstract: Methods of Enhanced Oil Recovery (EOR) from an oil reservoir by CO2 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 CO2 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 CO2 to form an injection stream; and injecting the injection stream into the reservoir. Systems for EOR from an oil reservoir by CO2 flooding are also disclosed.

Abstract: Methods of Enhanced Oil Recovery (EOR) from an oil reservoir by CO2 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 CO2 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 CO2 to form an injection stream; and injecting the injection stream into the reservoir. Systems for EOR from an oil reservoir by CO2 flooding are also disclosed.

Abstract: Methods of Enhanced Oil Recovery (EOR) from an oil reservoir by CO2 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 CO2 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 CO2 to form an injection stream; and injecting the injection stream into the reservoir. Systems for EOR from an oil reservoir by CO2 flooding are also disclosed.

Abstract: Methods of Enhanced Oil Recovery (EOR) from an oil reservoir by CO2 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 CO2 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 CO2 to form an injection stream; and injecting the injection stream into the reservoir. Systems for EOR from an oil reservoir by CO2 flooding are also disclosed.

Abstract: The present invention relates to a system for desorption of acid gas (1) from an acid gas rich absorption liquid having a steam part (3) and a process part (4). The steam part (3) and the process part (4) are separated to prevent intermixing of fluids in the steam part with fluids in the process part. The system (1) comprises a desorption cylinder (9) which is adapted to rotate about a longitudinal axis of rotation A of the desorption cylinder (9), and a stationary support stand (19) for supporting the desorption cylinder (9), and means for rotating (18) the desorption cylinder. The steam part (3) and the process part (4) are integrated in the desorption cylinder (9) and steam is supplied to the steam part (3) and acid gas rich absorption liquid (2) is supplied to the process part (4).

Abstract: The invention relates to a continuous process for removal of acid gas, such as carbon dioxide (CO2) from a fluid stream, such as natural gas comprising mainly hydrocarbons, by means of a absorbent medium in a rotating absorption zone. Subsequently, the acid gas is desorbed in a rotating desorption zone from the absorbent medium to allow the absorbent medium to be recirculated and the acid gas is removed for storage or drying and processing. This process can be carried out continuously, as the absorption medium is re-used.

Abstract: The present invention relates to a system for desorption of acid gas (1) from an acid gas rich absorption liquid having a steam part (3) and a process part (4). The steam part (3) and the process part (4) are separated to prevent intermixing of fluids in the steam part with fluids in the process part. The system (1) comprises a desorption cylinder (9) which is adapted to rotate about a longitudinal axis of rotation A of the desorption cylinder (9), and a stationary support stand (19) for supporting the desorption cylinder (9), and means for rotating (18) the desorption cylinder. The steam part (3) and the process part (4) are integrated in the desorption cylinder (9) and steam is supplied to the steam part (3) and acid gas rich absorption liquid (2) is supplied to the process part (4).

Abstract: A gas-liquid separator includes a housing which encloses a separation chamber, an inlet port for feeding the multi-phase flow into the separation chamber, a liquid outlet port for discharging the liquid dominated flow from the separation chamber and a gas outlet port provided at a position above both the inlet port and the liquid outlet port for discharging the gas dominated flow from the separation chamber. Both the inlet port and the liquid outlet port are positioned adjacent to an elongated lower bottom wall of the housing and define a flow direction into the and out of the separation chamber approximately aligned along the bottom wall. The separation chamber extends above the bottom wall in between the inlet port and the liquid outlet port. The liquid outlet port is provided with a gas seal to prevent entrainment of free gas from the separation chamber into the liquid outlet port.

Abstract: The invention relates to a continuous process for removal of acid gas, such as carbon dioxide (CO2) from a fluid stream, such as natural gas comprising mainly hydrocarbons, by means of a absorbent medium in a rotating absorption zone. Subsequently, the acid gas is desorbed in a rotating desorption zone from the absorbent medium to allow the absorbent medium to be recirculated and the acid gas is removed for storage or drying and processing. This process can be carried out continuously, as the absorption medium is re-used.

Abstract: A process for absorption and desorption of CO2 from an flue gas comprising feeding the flue gas into a mainly horizontal channel (20, 22, 249 where an absorption fluid is spray in to the channel in the flow direction of the flue gas and collected as CO2 rich absorption fluid at a lower part of the channel and transported into the centre of a rotating desorber wheel (30), where the CO2 is desorbed and the lean absorption fluid is returned to the channel is disclosed. This process can be utilized with absorption fluids with high concentration of conventional amine CO2 absorbents. Disclosed is also the use of an amine absorbent in a concentration of between 61 and 100% by weight for the absorption of CO2 from a gas stream, where the amine is an alkanol amine.

Abstract: A system for desorption of CO2 from an absorption fluid includes a cylinder with an open inner core, a reboiler including a stripper unit arranged between the inner core and the circumference of the cylinder, where the reboiler including the stripper unit is rotatable arranged around an axis through the core, where the system further includes a condenser rotatable arranged in proximity of the cylinder and rotatable around the same axis, where all the parts of the system are symmetrically arranged around the rotational axis through the core, and where all the fluid paths through the rotational parts of the system are arranged to provide symmetry and weight balance when the system is operational. A method for desorbing CO2 is also provided.

Abstract: The gas-liquid separator separates a variable multi-phase flow of gas and liquid in a gas dominated flow and a liquid dominated flow. The separator includes a housing which encloses a separation chamber, an inlet port for feeding the multi-phase flow into the separation chamber, a liquid outlet port for discharging the liquid dominated flow from the separation chamber and a gas outlet port provided at a position above both the inlet port and the liquid outlet port for discharging the gas dominated flow from the separation chamber. Both the inlet port and the liquid outlet port are positioned adjacent to an elongated lower bottom wall of the housing and define a flow direction into the and out of the separation chamber approximately aligned along the bottom wall, wherein the separation chamber extends above the bottom wall in between the inlet port and the liquid outlet port.

Abstract: A device for measuring rates in individual phases of a multiphase flow, such as in flow of hydrocarbon fluid through a pipe line, comprising a venturi having, seen in the flow direction thereof, a first inlet portion with deceasing cross-section, a second intermediate portion with mainly uniform cross-section, and a third outlet portion with increasing cross-section, and being situated within the pipe line. According to the present invention, the venturi is provided with a number of sensors, and the sensors are arranged in mutual distance at different cross-section areas along at least the first of the three portion of the venturi as thereby being able to determine a pressure profile along the venturi as a base for estimating rates for actual rates of the flow.