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: Flare gas is recovered by varying a number of ejector legs that depends on a flare gas flowrate. The ejector legs include ejectors piped in parallel, each ejector has a flare gas inlet and a motive fluid inlet. Flare gas and motive fluid is provided to ejectors by selectively opening or closing valves. The number of ejector legs online is varied to accommodate the amount of flare gas. The controller is also programmed to direct signals to actuators attached to the valves to open or close the valves, or to change the capacity of the ejector legs so they can handle changing flowrates of the flare gas. Included is a flare gas storage system with vessels made with flexible material, when flare gas is evacuated from the vessels, pressure in the vessels is maintained by compressing the vessels with an external force.

Abstract: A flare gas recovery system includes an ejector that receives flare gas from a suction line extending from a flare gas header, and further receives a motive fluid that draws the flare gas into the ejector to be mixed with the motive fluid and discharge a recovered gas into a discharge gas line. A solid oxide fuel cell system receives the recovered gas and includes a fuel cell power module that uses the recovered gas to generate electrical power, an anode exhaust, and a cathode exhaust, a combustor that receives and combusts at least a portion of the anode and cathode exhausts and thereby generates waste heat, and a process gas heat exchanger that receives and converts the waste heat into electrical power.

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: A crude oil demulsification system includes a vessel. A cyclonic separator is disposed outside the vessel. The cyclonic separator is configured to receive and separate phases of a multi-phase fluid stream into a gaseous stream and a liquid stream that includes a first liquid phase and a second liquid phase by inducing cyclonic flow. A heat exchanger is fluidically connected to the cyclonic separator. The heat exchanger is disposed outside the vessel, and is configured to receive the liquid stream and to heat the liquid stream by exchanging heat with a heating medium flowed through the heat exchanger. An electrostatic coalescer is fluidically connected to the heat exchanger and is disposed inside the vessel. The electrostatic coalescer is configured to receive the liquid stream heated by the heat exchanger and to demulsify the liquid stream by causing coalescence of liquid droplets of one of the first or second liquid phases.

Abstract: A crude oil demulsification system includes a vessel. A cyclonic separator is disposed outside the vessel. The cyclonic separator is configured to receive and separate phases of a multi-phase fluid stream into a gaseous stream and a liquid stream that includes a first liquid phase and a second liquid phase by inducing cyclonic flow. A heat exchanger is fluidically connected to the cyclonic separator. The heat exchanger is disposed outside the vessel, and is configured to receive the liquid stream and to heat the liquid stream by exchanging heat with a heating medium flowed through the heat exchanger. An electrostatic coalescer is fluidically connected to the heat exchanger and is disposed inside the vessel. The electrostatic coalescer is configured to receive the liquid stream heated by the heat exchanger and to demulsify the liquid stream by causing coalescence of liquid droplets of one of the first or second liquid phases.

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: A fluid sampling device including an inlet configured to receive a portion of a non-homogeneous fluid flowing through a conduit, a first double block bleed valve coupled to the inlet, a first flexible hose coupled to the first double block bleed valve by a first quick acting and leakage free coupling, a collection drum coupled to the first flexible hose by a first control valve, and a container coupled to the connection drum by a manual valve, wherein the device is configured to collect a fluid sample in the container. The device also includes a pressure controller to control pressure within the collection drum, and a level indicator to indicate a level of fluid in the collection drum.

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: Flare gas is recovered by varying a number of ejector legs that depends on a flare gas flowrate. The ejector legs include ejectors piped in parallel, each ejector has a flare gas inlet and a motive fluid inlet. Flare gas and motive fluid is provided to ejectors by selectively opening or closing valves. The number of ejector legs online is varied to accommodate the amount of flare gas. The controller is also programmed to direct signals to actuators attached to the valves to open or close the valves, or to change the capacity of the ejector legs so they can handle changing flowrates of the flare gas. Included is a flare gas storage system with vessels made with flexible material, when flare gas is evacuated from the vessels, pressure in the vessels is maintained by compressing the vessels with an external force.

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: A system includes a device disposed within a storage tank. The device includes a cyclonic separator and an electrostatic coalescer. The cyclonic separator is configured to receive and separate phases of a multi-phase fluid stream. The cyclonic separator is configured to induce cyclonic flow of the multi-phase fluid stream to separate the multi-phase fluid stream into a gas stream and a liquid stream. The liquid stream includes a first liquid phase and a second liquid phase. The cyclonic separator is configured to discharge at least a portion of the gas stream and at least a portion of the liquid stream. The electrostatic coalescer is downstream of and fluidically connected to the second outlet of the cyclonic separator. The electrostatic coalescer is configured to demulsify the liquid stream by causing coalescence of liquid droplets of one of the first or second liquid phases.

Abstract: A system includes a device disposed within a storage tank. The device includes a cyclonic separator and an electrostatic coalescer. The cyclonic separator is configured to receive and separate phases of a multi-phase fluid stream. The cyclonic separator is configured to induce cyclonic flow of the multi-phase fluid stream to separate the multi-phase fluid stream into a gas stream and a liquid stream. The liquid stream includes a first liquid phase and a second liquid phase. The cyclonic separator is configured to discharge at least a portion of the gas stream and at least a portion of the liquid stream. The electrostatic coalescer is downstream of and fluidically connected to the second outlet of the cyclonic separator. The electrostatic coalescer is configured to demulsify the liquid stream by causing coalescence of liquid droplets of one of the first or second liquid phases.

Abstract: A system includes a device disposed within a storage tank. The device includes a cyclonic separator and an electrostatic coalescer. The cyclonic separator is configured to receive and separate phases of a multi-phase fluid stream. The cyclonic separator is configured to induce cyclonic flow of the multi-phase fluid stream to separate the multi-phase fluid stream into a gas stream and a liquid stream. The liquid stream includes a first liquid phase and a second liquid phase. The cyclonic separator is configured to discharge at least a portion of the gas stream and at least a portion of the liquid stream. The electrostatic coalescer is downstream of and fluidically connected to the second outlet of the cyclonic separator. The electrostatic coalescer is configured to demulsify the liquid stream by causing coalescence of liquid droplets of one of the first or second liquid phases.

Abstract: A system includes a device disposed within a storage tank. The device includes a cyclonic separator and an electrostatic coalescer. The cyclonic separator is configured to receive and separate phases of a multi-phase fluid stream. The cyclonic separator is configured to induce cyclonic flow of the multi-phase fluid stream to separate the multi-phase fluid stream into a gas stream and a liquid stream. The liquid stream includes a first liquid phase and a second liquid phase. The cyclonic separator is configured to discharge at least a portion of the gas stream and at least a portion of the liquid stream. The electrostatic coalescer is downstream of and fluidically connected to the second outlet of the cyclonic separator. The electrostatic coalescer is configured to demulsify the liquid stream by causing coalescence of liquid droplets of one of the first or second liquid phases.