Abstract: A method and apparatus are provided for determining movement of a fluid into or out of a subsurface wellbore, to thereby enable accurate allocation of fluids being produced by or injected into each of several zones of the wellbore. A temperature change is effected in the fluid in a semi-continuous or pulsed manner at one or more locations in the wellbore. A temperature of the fluid is measured at one or more sensing locations downstream of the location of the temperature change. A time of flight model is used to determine, for a plurality of points of interest, a fluid flow direction, bulk flow rate and/or a cumulative flow rate contribution.

Abstract: A cryogenic distillation tower for separating a feed stream. The tower includes a distillation section. A controlled freeze zone section is situated above the distillation section and forms a solid from the feed stream. The controlled freeze zone section includes a spray assembly in an upper section and a melt tray assembly in a lower section. The melt tray assembly includes at least one vapor stream riser that directs the vapor from the distillation section into liquid retained by the melt tray assembly, and one or more draw-off openings positioned to permit a portion of the liquid to exit the controlled freeze zone section. The portion of the liquid indirectly exchanges heat with a heating fluid. One or more return inlets return the portion of the liquid to the melt tray assembly after it has been heated in the heat exchanger.

Abstract: A method of separating a feed stream in a distillation tower. Vapor is permitted to rise upwardly from a distillation section of the distillation tower. A feed stream is introduced into a controlled freeze zone section of the distillation tower, the controlled freeze zone section being situated above the distillation section. The feed stream is released above a level of a liquid retained by a melt tray assembly in the controlled freeze zone section. Vapor from the distillation section is directed into the liquid retained by the melt tray assembly. A solid is formed from the feed stream in the controlled freeze zone section.

Abstract: A method and apparatus are provided for determining movement of a fluid into or out of a subsurface wellbore, to thereby enable accurate allocation of fluids being produced by or injected into each of several zones of the wellbore. A temperature change is effected in the fluid at a first location in the wellbore. A temperature of the fluid is measured at one or more sensing locations downstream of the location of the temperature change. A simulated heat flow profile is generated from a wellbore model. The simulated heat flow profile is compared to the measured temperature of the fluid at the one or more sensing locations. An inversion model is used to determine, for a plurality of points of interest, a fluid flow direction and/or a cumulative flow rate contribution.

Abstract: A method for regasification of liquefied natural gas (LNG) and an LNG regasification terminal employing said method. An LNG carrier is filled with LNG at an LNG hub and transports the LNG to a receiving terminal. The LNG is offloaded to LNG storage at the receiving terminal. The LNG storage has less storage capacity than the storage capacity of the carrier. The LNG is regasified at a regasification rate at the receiving terminal. The carrier is maintained at the receiving terminal until the carrier is empty, and then returns to the LNG hub to be filled with more LNG. The process is then repeated. The storage capacity of the LNG storage is sufficient to supply LNG for regasifying the LNG at the regasification rate until the carrier returns with additional LNG from the LNG hub. The carrier is the sole source of LNG for the receiving terminal.

Abstract: A method and apparatus are provided for determining movement of a fluid into or out of a subsurface wellbore, to thereby enable accurate allocation of fluids being produced by or injected into each of several zones of the wellbore. A temperature change is effected in the fluid in a semi-continuous or pulsed manner at one or more locations in the wellbore. A temperature of the fluid is measured at one or more sensing locations downstream of the location of the temperature change. A time of flight model is used to determine, for a plurality of points of interest, a fluid flow direction, bulk flow rate and/or a cumulative flow rate contribution.

Abstract: A cryogenic distillation tower for separating a feed stream. The tower includes a distillation section. A controlled freeze zone section is situated above the distillation section and forms a solid from the feed stream. The controlled freeze zone section includes a spray assembly in an upper section and a melt tray assembly in a lower section. The melt tray assembly includes at least one vapor stream riser that directs the vapor from the distillation section into liquid retained by the melt tray assembly, and one or more draw-off openings positioned to permit a portion of the liquid to exit the controlled freeze zone section. The portion of the liquid indirectly exchanges heat with a heating fluid. One or more return inlets return the portion of the liquid to the melt tray assembly after it has been heated in the heat exchanger.

Abstract: A method and apparatus are provided for determining movement of a fluid into or out of a subsurface wellbore, to thereby enable accurate allocation of fluids being produced by or injected into each of several zones of the wellbore. A temperature change is effected in the fluid at a first location in the wellbore. A temperature of the fluid is measured at one or more sensing locations downstream of the location of the temperature change. A simulated heat flow profile is generated from a wellbore model. The simulated heat flow profile is compared to the measured temperature of the fluid at the one or more sensing locations. An inversion model is used to determine, for a plurality of points of interest, a fluid flow direction and/or a cumulative flow rate contribution.

Abstract: Systems and methods for separating CO2 and H2S from a natural gas stream are provided herein. The system includes a first loop of co-current contacting systems configured to remove H2S and CO2 from a natural gas stream and a second loop of co-current contacting systems configured to remove the H2S from the CO2.

Abstract: A method of transporting a mixed phase fluid in a conduit. A hydrate and/or wax film is permitted to deposit on an inner wall of the conduit in a conversion zone, the conversion zone being less than a length of the conduit. A quantity of heat is applied to the conduit in the conversion zone until the hydrate and/or wax deposited on the inner wall in the conversion zone separates therefrom, thereby inhibiting the continual formation of hydrates and/or wax on the inner wall. The separated hydrates and/or wax are flowed in the mixed phase fluid.

Abstract: The present disclosure provides a subwater heat exchanger that includes a duct, first coils, a first impeller and a second impeller. The duct is configured to receive a first fluid. The first coils are inside of the duct and are configured to receive a second fluid that is heated or cooled by the first fluid. The first impeller is inside of the duct that is configured to initiate flow of the first fluid around the first coils. The second impeller is inside of the duct and is substantially in line with the first impeller along a duct lateral axis of the duct.

Abstract: The present disclosure provides a method for separating a feed stream in a distillation tower which includes separating a feed stream in a stripper section into an enriched contaminant bottom liquid stream and a freezing zone vapor stream; contacting the freezing zone vapor stream in the controlled freeze zone section with a freezing zone liquid stream at a temperature and pressure at which a solid and a hydrocarbon-enriched vapor stream form; directly applying heat to a controlled freeze zone wall of the controlled freeze zone section with a heating mechanism coupled to at least one of a controlled freeze zone internal surface of the controlled freeze zone wall and a controlled freeze zone external surface of the controlled freeze zone wall; and at least one of destabilizing and preventing adhesion of the solid to the controlled freeze zone wall with the heating mechanism.

Abstract: Systems and methods for separating CO2 and H2S from a natural gas stream are provided herein. The system includes a first loop of co-current contacting systems configured to remove H2S and CO2 from a natural gas stream and a second loop of co-current contacting systems configured to remove the H2S from the CO2.

Abstract: A system for removing acid gases from a raw gas stream the system includes a cryogenic distillation tower. The tower receives and separates the raw gas stream into an overhead methane stream and a bottom liquefied acid gas stream. Refrigeration equipment downstream of the cryogenic distillation tower cools the overhead methane stream and returns a portion of the overhead methane stream to the cryogenic distillation tower as liquid reflux. The system also may include a first molecular sieve bed upstream of the distillation tower and a second molecular sieve bed downstream of the distillation tower. The first molecular sieve bed adsorbs water while the second molecular sieve bed adsorbs additional acid gases from the cooled overhead methane stream.

Abstract: A selective hydrogenation process that is particularly effective in selectively hydrogenating alkynl compounds, such as acetylene or methyl acetylene, over alkenyl compounds, such as ethylene, is described. The process utilizes a slurry conversion unit for heat efficiency purposes during the conversion of acetylene into ethylene.

Abstract: The present disclosure provides a subwater heat exchanger that includes a duct, first coils, a first impeller and a second impeller. The duct is configured to receive a first fluid. The first coils are inside of the duct and are configured to receive a second fluid that is heated or cooled by the first fluid. The first impeller is inside of the duct that is configured to initiate flow of the first fluid around the first coils. The second impeller is inside of the duct and is substantially in line with the first impeller along a duct lateral axis of the duct.

Abstract: A method and system for long-term flow assurance is provided. Data is periodically acquired from multiple transportation systems each having a transportation structure such as a pipeline, and a transported material such as hydrocarbons or oil and gas. The data is stored in a central location. A global predictive flow model is maintained based on the data acquired from the multiple transportation systems. A data set of a transportation system of the multiple transportation systems is analyzed via the global predictive flow model to determine a flow assurance issue of the transportation system.

Abstract: A system and methods for increasing a combustibility of a low BTU natural gas are provided herein. The method includes increasing the adiabatic flame temperature of the low BTU natural gas using heavy hydrocarbons, wherein the heavy hydrocarbons include compounds with a carbon number of at least two. The method also includes burning the low BTU natural gas in a gas turbine.

Abstract: The present disclosure provides a method for separating a feed stream in a distillation tower which includes separating a feed stream in a stripper section into an enriched contaminant bottom liquid stream and a freezing zone vapor stream; contacting the freezing zone vapor stream in the controlled freeze zone section with a freezing zone liquid stream at a temperature and pressure at which a solid and a hydrocarbon-enriched vapor stream form; directly applying heat to a controlled freeze zone wall of the controlled freeze zone section with a heating mechanism coupled to at least one of a controlled freeze zone internal surface of the controlled freeze zone wall and a controlled freeze zone external surface of the controlled freeze zone wall; and at least one of destabilizing and preventing adhesion of the solid to the controlled freeze zone wall with the heating mechanism.

Abstract: Systems and methods for separating CO2 and H2S from a natural gas stream are provided herein. The system includes a first loop of co-current contacting systems configured to remove H2S and CO2 from a natural gas stream and a second loop of co-current contacting systems configured to remove the H2S from the CO2.