Abstract: A well fluid processing system has a separator for separating heavier and lighter components of well fluid flowing from a subsea well and directing the lighter components to flow to a surface processing facility. The separator has a cylindrical chamber having a length at least ten times its diameter. A coalescing unit located in the chamber causes water droplets in the well fluid flowing through the tubes to coalesce into larger droplets. A dielectrophoresis unit having undulating sheets spaced close to each other is also located in the chamber. The sheets of the unit are supplied with an electrical potential to force the water droplets into predetermined passage portions to form high water content sections of liquid. Bypass valves allow backflushing of one of the separators while others continue to operate.

Abstract: An inlet device to a separator including a generally tubular outer wall and a generally tubular inner wall. The walls define at least a part of a first annular path between them. An inlet opening provides for the passage of a fluid through the outer wall into the first annular path. At least one communication channel provides for the passage of a fluid from the first annular path into the second annular path. At least one movable closing element provides for at least partial closure of the fluid passage from the first path into the second path. The communication channel(s) is/are arranged to extend along the outside of the inner wall downwards from the first path into the second path, wherein the second path is arranged below the first path.

Abstract: An inline well fluid separator is movable for pigging operations. The separator assembly has a housing with an inlet port and an outlet port. A separation unit is carried within the housing. The separation unit has an operational position in alignment with the ports to cause well fluid to flow through the separation unit. The separation unit will move to a storage position within the housing outside of the flow path to enable a pipeline pig to pass.

Abstract: Subsea wells are drilled and completed with an offshore floating platform in a manner that allows simultaneous work on more than one well. A first well is drilled and casing. Then a tubing hanger is run through a drilling riser and landed in the wellhead housing. Then, with the same floating platform, the drilling riser is disconnected and moved to a second well. While performing operations on the second well, the operator lowers a production tree from the floating platform on a lift line, and connects it to the first wellhead housing. An ROV assisted subsea plug removal tool is used for plug removal and setting operations required through the production tree.

Abstract: A well fluid processing system has a separator for separating heavier and lighter components of well fluid flowing from a subsea well and directing the lighter components to flow to a surface processing facility. The separator has a cylindrical chamber having a length at least ten times its diameter. A coalescing unit located in the chamber causes water droplets in the well fluid flowing through the tubes to coalesce into larger droplets. A dielectrophoresis unit having undulating sheets spaced close to each other is also located in the chamber. The sheets of the unit are supplied with an electrical potential to force the water droplets into predetermined passage portions to form high water content sections of liquid. Bypass valves allow backflushing of one of the separators while others continue to operate.

Abstract: An inline well fluid separator is movable for pigging operations. The separator assembly has a housing with an inlet port and an outlet port. A separation unit is carried within the housing. The separation unit has an operational position in alignment with the ports to cause well fluid to flow through the separation unit. The separation unit will move to a storage position within the housing outside of the flow path to enable a pipeline pig to pass.

Abstract: An inlet device to a separator including a generally tubular outer wall and a generally tubular inner wall. The walls define at least a part of a first annular path between them. An inlet opening provides for the passage of a fluid through the outer wall into the first annular path. At least one communication channel provides for the passage of a fluid from the first annular path into the second annular path. At least one movable closing element provides for at least partial closure of the fluid passage from the first path into the second path. The communication channel(s) is/are arranged to extend along the outside of the inner wall downwards from the first path into the second path, wherein the second path is arranged below the first path.

Abstract: An inline well fluid separator is movable for pigging operations. The separator assembly has a housing with an inlet port and an outlet port. A separation unit is carried within the housing. The separation unit has an operational position in alignment with the ports to cause well fluid to flow through the separation unit. The separation unit will move to a storage position within the housing outside of the flow path to enable a pipeline pig to pass.

Abstract: A subsea well fluid processing system has a separator for separating heavier and lighter components of well fluid flowing from a subsea well and directing the lighter components to flow to a surface processing facility. A choke is located downstream of the separator for limiting the flow rate of well fluid. The separator has a cylindrical chamber having a length at least ten times its diameter. A coalescing unit located in the chamber causes water droplets in the well fluid to coalesce into larger droplets. A dielectrophoresis unit having undulating sheets spaced close to each other is also located in the chamber. The sheets of the unit are supplied with an electrical potential to force the water droplets into predetermined passage portions to form high water content sections of liquid. Bypass valves allow backflushing of one of the separators while others continue to operate.

Abstract: Subsea wells are drilled and completed with an offshore floating platform in a manner that allows simultaneous work on more than one well. A first well is drilled and casing. Then a tubing hanger is run through a drilling riser and landed in the wellhead housing. Then, with the same floating platform, the drilling riser is disconnected and moved to a second well. While performing operations on the second well, the operator lowers a production tree from the floating platform on a lift line, and connects it to the first wellhead housing. An ROV assisted subsea plug removal tool is used for plug removal and setting operations required through the production tree.

Abstract: Subsea wells are drilled and completed with an offshore floating platform in a manner that allows simultaneous work on more than one well. A first well is drilled and cased. Then a tubing hanger is run through a drilling riser and landed in the wellhead housing. Then, with the same floating platform, the drilling riser is disconnected and moved to a second well. While performing operations on the second well, the operator lowers a production tree from the floating platform on a lift line, and connects it to the first wellhead housing. An ROV assisted subsea plug removal tool is used for plug removal and setting operations. Seabed separation is configured upstream of a production choke valve.

Abstract: An inline well fluid separator is movable for pigging operations. The separator assembly has a housing with an inlet port and an outlet port. A separation unit is carried within the housing. The separation unit has an operational position in alignment with the ports to cause well fluid to flow through the separation unit. The separation unit will move to a storage position within the housing outside of the flow path to enable a pipeline pig to pass.

Abstract: Subsea wells are drilled and completed with an offshore floating platform in a manner that allows simultaneous work on more than one well. A first well is drilled and casing. Then a tubing hanger is run through a drilling riser and landed in the wellhead housing. Then, with the same floating platform, the drilling riser is disconnected and moved to a second well. While performing operations on the second well, the operator lowers a production tree from the floating platform on a lift line, and connects it to the first wellhead housing. An ROV assisted subsea plug removal tool is used for plug removal and setting operations required through the production tree. Seabed separation is configured upstream of a production choke valve.

Abstract: A subsea well fluid processing system has a subsea well fluid separator for separating heavier and lighter components of well fluid flowing from a subsea well and directing the lighter components to flow to a surface processing facility. A choke is located downstream of the separator for limiting the flow rate of well fluid from the subsea well. The separator has a cylindrical chamber having a length at least ten times its diameter. A coalescing unit having a plurality of tubes to which an electrical potential is applied is located in the chamber to cause water droplets in the well fluid flowing through the tubes to coalesce into larger droplets. A dielectrophoresis unit having a pair of undulating sheets spaced close to each other is also located in the chamber. The sheets of the dielectrophoresis unit are supplied with an electrical potential to force the water droplets in the well fluid into predetermined passage portions between the sheets to form high water content sections of liquid.