Abstract: A method and systems are provided for injecting a hydrate slurry into a reservoir. The method includes combining gas and water within a subsea simultaneous water and gas (SWAG) injection system. The method also includes forming a hydrate slurry from the gas and the water, and injecting the hydrate slurry into a reservoir.

Abstract: Methods and systems are provided for producing hydrocarbons from production fluids that have water as an external phase. A method for transporting a hydrocarbon through a pipeline includes injecting water into a production stream at a production center. The production stream includes a hydrocarbon, and the water injection forms a transportation stream that includes a water external phase. The transportation stream is flowed through a transportation line to a surface facility, wherein the transportation line comprises a plurality of static mixers spaced at intervals along the transportation line.

Abstract: Methods and systems are provided for producing hydrocarbons from production fluids that have water as an external phase. A method for transporting a hydrocarbon through a pipeline includes injecting water into a production stream at a production center. The production stream includes a hydrocarbon, and the water injection forms a transportation stream that includes a water external phase. The transportation stream is flowed through a transportation line to a surface facility, wherein the transportation line comprises a plurality of static mixers spaced at intervals along the transportation line.

Abstract: Methods and systems are provided for producing hydrocarbons from production fluids that have water as an external phase. A method for transporting a hydrocarbon through a pipeline includes injecting water into a production stream at a production center. The production stream includes a hydrocarbon, and the water injection forms a transportation stream that includes a water external phase. The transportation stream is flowed through a transportation line to a surface facility, wherein the transportation line comprises a plurality of static mixers spaced at intervals along the transportation line.

Abstract: A method and systems are provided for injecting a hydrate slurry into a reservoir. The method includes combining gas and water within a subsea simultaneous water and gas (SWAG) injection system. The method also includes forming a hydrate slurry from the gas and the water, and injecting the hydrate slurry into a reservoir.

Abstract: Managing hydrates in a subsea includes a host production facility, a production cluster comprising one or more producers, a water injection cluster comprising one or more water injectors, a water injection line, and a single production line for directing production fluid from the one or more producers to the host production facility. The methods comprise placing a pig in the subsea production system, shutting in production from the producers, and injecting a displacement fluid into the subsea production system in order to displace the hydrate inhibitor and any remaining production fluids in the production flowline and to further move the pig through the production flowline. The method may also include further injecting displacement fluid into the subsea production system in order to displace the hydrate inhibitor and pig through the single production line and to the host production facility.

Abstract: A method for managing hydrates in a subsea production system is provided. The production system includes a host production facility, a control umbilical, at least one subsea production well, and a single production line. The method generally comprises producing hydrocarbon fluids from the at least one subsea production well and through the production line, and then shutting in the production line. In addition, the method includes the steps of depressurizing the production line to substantially reduce a solution gas concentration in the produced hydrocarbon fluids, and then repressurizing the production line to urge any remaining gas in the free gas phase within the production line back into solution. The method also includes displacing production fluids within the production line by moving displacement fluids from a service line within the umbilical line and into the production line. The displacement fluids preferably comprise a hydrocarbon-based fluid having a low dosage hydrate inhibitor (LDHI).

Abstract: Methods and systems are provided for producing hydrocarbons from production fluids that have water as an external phase. A method for transporting a hydrocarbon through a pipeline includes injecting water into a production stream at a production center. The production stream includes a hydrocarbon, and the water injection forms a transportation stream that includes a water external phase. The transportation stream is flowed through a transportation line to a surface facility, wherein the transportation line comprises a plurality of static mixers spaced at intervals along the transportation line.

Abstract: Managing hydrates in a subsea includes a host production facility, a production cluster comprising one or more producers, a water injection cluster comprising one or more water injectors, a water injection line, and a single production line for directing production fluid from the one or more producers to the host production facility. The methods comprise placing a pig in the subsea production system, shutting in production from the producers, and injecting a displacement fluid into the subsea production system in order to displace the hydrate inhibitor and any remaining production fluids in the production flowline and to further move the pig through the production flowline. The method may also include further injecting displacement fluid into the subsea production system in order to displace the hydrate inhibitor and pig through the single production line and to the host production facility.

Abstract: A method for managing hydrates in a subsea production system is provided. The production system includes a host production facility, a control umbilical, at least one subsea production well, and a single production line. The method generally comprises producing hydrocarbon fluids from the at least one subsea production well and through the production line, and then shutting in the production line. In addition, the method includes the steps of depressurizing the production line to substantially reduce a solution gas concentration in the produced hydrocarbon fluids, and then repressurizing the production line to urge any remaining gas in the free gas phase within the production line back into solution. The method also includes displacing production fluids within the production line by moving displacement fluids from a service line within the umbilical line and into the production line. The displacement fluids preferably comprise a hydrocarbon-based fluid having a low dosage hydrate inhibitor (LDHI).

Abstract: A method for managing hydrates in a subsea production system is provided. The system has at least one producing subsea well, a jumper for delivering produced fluids from the subsea well to a manifold, a production line for delivering produced fluids to a production gathering facility, and an umbilical for delivering chemicals to the manifold. The subsea well has been shut in, leaving produced fluids in a substantially uninhibited state. The method generally comprises the steps of pumping a displacement fluid into the chemical injection tubing, pumping the displacement fluid through a chemical injection tubing provided in the umbilical, further pumping the displacement fluid through the manifold and into the production line, and pumping the displacement fluid through the production line so as to displace the produced fluids before hydrate formation may begin. Preferably, a chemical inhibitor is placed in the chemical injection tubing before the displacement fluid is pumped into the chemical injection tubing.

Abstract: A computer system and method of operating the same to optimize the operating conditions of a petroleum production field, in which a plurality of wells are arranged according to drill sites, and connected to one or more central processing facilities, is disclosed. In this disclosed embodiment, gas compression capacity is a significant constraint on the operation of the complex production field, and surface line hydraulic effects of well production are to be considered in the optimization. A genetic algorithm is used to generate, and iteratively evaluate solution vectors, which are combinations of field operating parameters such as incremental gas-oil ratio cutoff and formation gas-oil ratio cutoff values. The evaluation includes the operation of an adaptive network to determine production header pressures, followed by modification of well output estimates to account for changes in the production header pressure.

Abstract: A system for producing a material balance solution for well patterns in a hydrocarbon reservoir is described that automatically optimizes the fluid allocation factors for each well used in determining the solution. The system automatically optimizes estimates for the allocation factors to be used in the material balance solution by randomly generating a first generation of allocation factor strings, each string in the generation assigning allocation factors to each of the wells in the reservoir. A fitness function value is determined for each of the strings by evaluating a fitness function, wherein the fitness function comprises the sum of the differences between computed and measured field pressures for each pattern, and the sum of the differences between target allocation factors and the allocation factors specified within the string for each well. A succeeding generation of allocation factor strings is produced according to a genetic algorithm.

Abstract: A packed bed static mixer, and a piping network including the same, is disclosed. The packed bed static mixer includes a vertical intake portion, within which packing material consisting of small elements, is disposed. The packing elements may be spheres, PALL RING elements, or the like, and are fabricated of a material suitable for the particular application of the static mixer. The size of the packing elements is maintained to be relatively small relative to the mixer, to provide numerous mixing vortices therewithin; the packing elements are randomly packed into the static mixer. Outlets are provided which extend horizontally and radially from the bottom of the static mixer, and are typically of smaller diameter than the intake portion. Because the mixing action depends upon the size of the vortices at the interstitial voids among the packing elements, the disclosed static mixer design may be readily scaled to various diameters.

Abstract: A system for producing a material balance solution for well patterns in a hydrocarbon reservoir is described that automatically optimizes the fluid allocation factors for each well used in determining the solution. The system automatically optimizes estimates for the allocation factors to be used in the material balance solution by randomly generating a first generation of allocation factor strings, each string in the generation assigning allocation factors to each of the wells in the reservoir. A fitness function value is determined for each of the strings by evaluating a fitness function, wherein the fitness function comprises the sum of the differences between computed and measured field pressures for each pattern, and the sum of the differences between target allocation factors and the allocation factors specified within the string for each well. A succeeding generation of allocation factor strings is produced according to a genetic algorithm.

Abstract: Natural gas is reinjected into an earth formation for storage and/or stimulating the recovery of hydrocarbon liquids by mixing the gas with water at a pressure sufficient to maintain bubble flow of gas dispersed in a water flowstream in a range of volumetric gas fraction up to about twenty percent of total flow. A water and gas distribution system includes static flow mixers for maintaining uniform distribution of gas bubbles in the water flow stream through the distribution conduits. The mixers may comprise multi-stage bladed mixing elements of the same or opposite pitch and extending across the intersection of branch conduits with the main conduit of the distribution system. The water and gas may be mixed in an injection well having a tubing string extending within the well and having a distal end below the point of injection into an earth formation so that a uniform gas and water mixture enters the formation through the well perforations.