Abstract: Systems and methods for crude oil separations including degassing, dewatering, desalting, and stabilization. One method includes separating crude oil into a crude oil off-gas and a partially degassed crude oil output; compressing the crude oil off-gas; applying the compressed crude oil off-gas for indirect heating through reboilers of the partially degassed crude oil output; and directly mixing with the crude oil a compressed atmospheric pressure gas. In some embodiments, multiple reboilers are used. In some embodiments, heat exchangers are used. Aftercoolers are used after the compressor to cool the gas; knockout drums are used after the coolers to separate liquids.

Abstract: Systems and methods for crude oil separations including degassing, dewatering, desalting, and stabilization. One method includes separating crude oil into a crude oil off-gas and a partially degassed crude oil output; compressing the crude oil off-gas; applying the compressed crude oil off-gas for indirect heating through reboilers of the partially degassed crude oil output; and directly mixing with the crude oil a compressed atmospheric pressure gas. In some embodiments, multiple reboilers are used. In some embodiments, heat exchangers are used. Aftercoolers are used after the compressor to cool the gas; knockout drums are used after the coolers to separate liquids.

Abstract: Systems and methods for crude oil separations including degassing, dewatering, desalting, and stabilization. One method includes separating crude oil into a crude oil off-gas and a partially degassed crude oil output; compressing the crude oil off-gas; applying the compressed crude oil off-gas for indirect heating through reboilers of the partially degassed crude oil output; and directly mixing with the crude oil a compressed atmospheric pressure gas. In some embodiments, multiple reboilers are used. In some embodiments, heat exchangers are used. Aftercoolers are used after the compressor to cool the gas; knockout drums are used after the coolers to separate liquids.

Abstract: Systems and methods for crude oil separations including degassing, dewatering, desalting, and stabilization. One method includes separating crude oil into a crude oil off-gas and a partially degassed crude oil output; compressing the crude oil off-gas; applying the compressed crude oil off-gas for indirect heating through reboilers of the partially degassed crude oil output; and directly mixing with the crude oil a compressed atmospheric pressure gas. In some embodiments, multiple reboilers are used. In some embodiments, heat exchangers are used. Aftercoolers are used after the compressor to cool the gas; knockout drums are used after the coolers to separate liquids.

Abstract: Systems and methods for crude oil separations including degassing, dewatering, desalting, and stabilization. One method includes separating crude oil into a crude oil off-gas and a partially degassed crude oil output; compressing the crude oil off-gas; applying the compressed crude oil off-gas for indirect heating through reboilers of the partially degassed crude oil output; and directly mixing with the crude oil a compressed atmospheric pressure gas. In some embodiments, multiple reboilers are used. In some embodiments, heat exchangers are used. Aftercoolers are used after the compressor to cool the gas; knockout drums are used after the coolers to separate liquids.

Abstract: Additive is introduced into a tubular that carries produced fluid from a wellhead; the additive addition prophylactically guards against damage to the tubular, such as from corrosion or oxidation. Gas from the wellhead is utilized as a pressure source for driving the additive into the tubular. The rate of additive injection is varied based on characteristics of the tubular or fluid in the tubular. Characteristics of the fluid in the tubular include iron content, residual additive, moisture content, and flowrate; characteristics of the tubular include its corrosion rate of the tubular. The characteristics are measured real time, measured historically, or predicted from a model.

Abstract: Systems and methods for treating a rag layer in a gas oil separation plant. The method includes withdrawing the rag layer from a vessel proximate an oil water interface, conveying the rag layer to a separation device, and recycling separated oil from the separation device back to the gas oil separation plant process.

Abstract: While operating a compressor system equipped with compression train(s), condensate is collected from within stages of the compression train(s), and directed to a blowdown system. Gas from a later stage of the compression train is routed to the blowdown system and used to drive the condensate to a condensate destination at a pressure that avoids flashing of the condensate until it reaches the condensate destination. Inside the blowdown system the condensate is stored in a tank and directed to parallel piped vessels. Operation of the vessels includes (1) receiving the condensate, (2) pressurization with gas from a later stage of compression, (3) flowing the pressurized condensate from the vessel to the condensation destination, (4) depressurizing the vessel, and (5) repeating steps (1)-(4). A flow of condensate from the blowdown system is continuous by staggering the phases of operation between the two vessels.

Abstract: Systems and methods for crude oil separations including degassing, dewatering, desalting, and stabilization. One method includes separating crude oil into a crude oil off-gas and a partially degassed crude oil output; compressing the crude oil off-gas; applying the compressed crude oil off-gas for indirect heating through reboilers of the partially degassed crude oil output; and directly mixing with the crude oil a compressed atmospheric pressure gas. In some embodiments, multiple reboilers are used. In some embodiments, heat exchangers are used. Aftercoolers are used after the compressor to cool the gas; knockout drums are used after the coolers to separate liquids.

Abstract: Additive is introduced into a tubular that carries produced fluid from a wellhead; the additive addition prophylactically guards against damage to the tubular, such as from corrosion or oxidation. Gas from the wellhead is utilized as a pressure source for driving the additive into the tubular. The rate of additive injection is varied based on characteristics of the tubular or fluid in the tubular. Characteristics of the fluid in the tubular include iron content, residual additive, moisture content, and flowrate; characteristics of the tubular include its corrosion rate of the tubular. The characteristics are measured real time, measured historically, or predicted from a model.

Abstract: Systems and methods of integrated gas oil separation are disclosed. Systems include a high pressure production trap (HPPT), a low pressure production trap (LPPT), a low pressure degassing tank (LPDT), a first knockout drum (KOD) fluidly coupled to the LPDT and operable to accept an atmospheric pressure off-gas from the LPDT, an atmospheric pressure compressor fluidly coupled to the first KOD and operable to compress the atmospheric pressure off-gas to introduce the atmospheric pressure off-gas from the LPDT into the LPPT inlet feed stream, a second KOD fluidly coupled to the LPPT and operable to accept a low pressure off-gas from the LPPT, and a low pressure compressor fluidly coupled to the second KOD and operable to compress the low pressure off-gas to introduce the low pressure off-gas from the LPPT into the crude oil inlet feed stream.

Abstract: Systems and methods for treating a rag layer in a gas oil separation plant. The method includes withdrawing the rag layer from a vessel proximate an oil water interface, conveying the rag layer to a separation device, and recycling separated oil from the separation device back to the gas oil separation plant process.

Abstract: Systems and methods for treating a rag layer in a gas oil separation plant. The method includes withdrawing the rag layer from a vessel proximate an oil water interface, conveying the rag layer to a separation device, and recycling separated oil from the separation device back to the gas oil separation plant process.

Abstract: Systems and methods of integrated gas oil separation are disclosed. Systems include a high pressure production trap (HPPT), a low pressure production trap (LPPT), a low pressure degassing tank (LPDT), a first knockout drum (KOD) fluidly coupled to the LPDT and operable to accept an atmospheric pressure off-gas from the LPDT, an atmospheric pressure compressor fluidly coupled to the first KOD and operable to compress the atmospheric pressure off-gas to introduce the atmospheric pressure off-gas from the LPDT into the LPPT inlet feed stream, a second KOD fluidly coupled to the LPPT and operable to accept a low pressure off-gas from the LPPT, and a low pressure compressor fluidly coupled to the second KOD and operable to compress the low pressure off-gas to introduce the low pressure off-gas from the LPPT into the crude oil inlet feed stream.

Abstract: Systems and methods of integrated gas oil separation are disclosed. Systems include a high pressure production trap (HPPT), a low pressure production trap (LPPT), a low pressure degassing tank (LPDT), a first knockout drum (KOD) fluidly coupled to the LPDT and operable to accept an atmospheric pressure off-gas from the LPDT, an atmospheric pressure compressor fluidly coupled to the first KOD and operable to compress the atmospheric pressure off-gas to introduce the atmospheric pressure off-gas from the LPDT into the LPPT inlet feed stream, a second KOD fluidly coupled to the LPPT and operable to accept a low pressure off-gas from the LPPT, and a low pressure compressor fluidly coupled to the second KOD and operable to compress the low pressure off-gas to introduce the low pressure off-gas from the LPPT into the crude oil inlet feed stream.

Abstract: Systems and methods for treating a rag layer in a gas oil separation plant. The method includes withdrawing the rag layer from a vessel proximate an oil water interface, conveying the rag layer to a separation device, and recycling separated oil from the separation device back to the gas oil separation plant process.

Abstract: A system and method for dispensing an injection material to an injection point. The injection material is stored in a tank and disposed to parallel piped vessels. An orifice is disposed in piping connected to discharge ends of the vessels, and has an opening with a designated cross sectional area. A high pressure fluid drives the injection material to the injection point; the pressure of the high pressure fluid is regulated with a pressure control valve. Valves in the inlet and discharge piping connected to the vessels are selectively opened and closed so that injection material flows to and from the vessels. Vessels vent to a recycle/recovery system to reduce vessel pressure enabling refilling with injection material. Valves in the pressurizing and depressurizing lines are selectively opened and closed to depressurize and refill the vessels to have continuous chemical injection to the injection location.

Abstract: Systems and methods of integrated gas oil separation are disclosed. Systems include a high pressure production trap (HPPT), a low pressure production trap (LPPT), a low pressure degassing tank (LPDT), a first knockout drum (KOD) fluidly coupled to the LPDT and operable to accept an atmospheric pressure off-gas from the LPDT, an atmospheric pressure compressor fluidly coupled to the first KOD and operable to compress the atmospheric pressure off-gas to introduce the atmospheric pressure off-gas from the LPDT into the LPPT inlet feed stream, a second KOD fluidly coupled to the LPPT and operable to accept a low pressure off-gas from the LPPT, and a low pressure compressor fluidly coupled to the second KOD and operable to compress the low pressure off-gas to introduce the low pressure off-gas from the LPPT into the crude oil inlet feed stream.

Abstract: Systems and methods of integrated gas oil separation are disclosed. Systems include a high pressure production trap (HPPT), a low pressure production trap (LPPT), a low pressure degassing tank (LPDT), a first knockout drum (KOD) fluidly coupled to the LPDT and operable to accept an atmospheric pressure off-gas from the LPDT, an atmospheric pressure compressor fluidly coupled to the first KOD and operable to compress the atmospheric pressure off-gas to introduce the atmospheric pressure off-gas from the LPDT into the LPPT inlet feed stream, a second KOD fluidly coupled to the LPPT and operable to accept a low pressure off-gas from the LPPT, and a low pressure compressor fluidly coupled to the second KOD and operable to compress the low pressure off-gas to introduce the low pressure off-gas from the LPPT into the crude oil inlet feed stream.

Abstract: A system and method for dispensing an injection material to an injection point. The injection material is stored in a tank and disposed to parallel piped vessels. An orifice is disposed in piping connected to discharge ends of the vessels, and has an opening with a designated cross sectional area. A high pressure fluid drives the injection material to the injection point; the pressure of the high pressure fluid is regulated with a pressure control valve. Valves in the inlet and discharge piping connected to the vessels are selectively opened and closed so that injection material flows to and from the vessels. Vessels vent to a recycle/recovery system to reduce vessel pressure enabling refilling with injection material. Valves in the pressurizing and depressurizing lines are selectively opened and closed to depressurize and refill the vessels to have continuous chemical injection to the injection location.