Abstract: A running string for a subsea completion comprises an upper section (70) which may be a coiled tubing (CT) injector unit as shown, or a wireline lubricator (FIG. 8). A lower section (60) provides wireline/CT access to production/annulus bores of a tubing hanger (not shown) attached to tubing hanger running tool (62). A flow package (64) in the lower section (60), together with BOP pipe rams (86) and annular seal (88), directs production and annulus fluid flows/pressures to the BOP choke/kill lines (78/76). The upper and lower sections allow installation and pressure/circulation testing of, and wireline/CT access to, a subsea completion, without the use of a high pressure riser.

Abstract: A completion system comprises a christmas tree (10) mounted on a wellhead housing (11), a tubing hanger (12) landed in the tree or wellhead housing, the wellhead housing (11) being mounted on a casing string (100) and a tubing string (14) being suspended from the tubing hanger within the casing string; wherein, in use, the annulus defined between the tubing (14) and the casing (100) serves as a production bore. A second tubing string (98) is expanded into sealing engagement with the casing string (100) over at least a portion of their lengths. The annulus normally used to provide well service functions is thus eliminated. Well servicing is instead provided via the tubing string (14), which may be coiled tubing.

Abstract: A horizontal Christmas tree is adapted for ESP/HSP or downhole sensor deployment by a coiled tubing hanger 38 received in the tubing hanger 12. Coiled tubing 40 suspends downhole equipment such as ESP 60, and carries power/signal lines. These lines are connected to an external line 58 via a transition connector 46 in a tubing access plug 44 provided in an internal tree cap 32. A debris cap 50 is provided with a further connector 52. Self orientating wet mate connectors 48, 54, 56 are provided between the connectors 46, 52 and external line 58. The coiled tubing hanger and/or tubing hanger may be provided with flow by flutes or holes (78, 80 FIGS. 4 and 5) sealable by a separate adapter plug (88, FIG. 5) above the coiled tubing hanger. Flow test procedures are also disclosed.

Abstract: A completion system comprises a christmas tree (10) mounted on a wellhead housing (11), a tubing hanger (12) landed in the tree or wellhead housing, the wellhead housing (11) being mounted on a casing string (100) and a tubing string (14) being suspended from the tubing hanger within the casing string; wherein, in use, the annulus defined between the tubing (14) and the casing (100) serves as a production bore. A second tubing string (98) is expanded into sealing engagement with the casing string (100) over at least a portion of their lengths. The annulus normally used to provide well service functions is thus eliminated. Well servicing is instead provided via the tubing string (14), which may be coiled tubing.

Abstract: A running string for a subsea completion comprises an upper section (70) which may be a coiled tubing (CT) injector unit as shown, or a wireline lubricator (FIG. 8). A lower section (60) provides wireline/CT access to production/annulus bores of a tubing hanger (not shown) attached to tubing hanger running tool (62). A flow package (64) in the lower section (60), together with BOP pipe rams (86) and annular seal (88), directs production and annulus fluid flows/pressures to the BOP choke/kill lines (78/76). The upper and lower sections allow installation and pressure/circulation testing of, and wireline/CT access to, a subsea completion, without the use of a high pressure riser.

Abstract: A preferably fiber optic line passes into a well interior through a pressure barrier such as a tree or wellhead housing, via a modified horizontal penetrator assembly. The penetrator assembly comprises double poppet valve assemblies arranged to open upon engagement of the penetrator with an interior well component such as a tubing hanger. Retraction of the penetrator closes the poppet valves, sealing the pressure barrier, severing the line and allowing the tubing hanger to be pulled. A replacement line is readily installed through the open poppet valve assemblies.

Abstract: A horizontal Christmas tree is adapted for ESP/HSP or downhole sensor deployment by a coiled tubing hanger 38 received in the tubing hanger 12. Coiled tubing 40 suspends downhole equipment such as ESP 60, and carries power/signal lines. These lines are connected to an external line 58 via a transition connector 46 in a tubing access plug 44 provided in an internal tree cap 32. A debris cap 50 is provided with a further connector 52. Self orientating wet mate connectors 48, 54, 56 are provided between the connectors 46, 52 and external line 58. The coiled tubing hanger and/or tubing hanger may be provided with flow by flutes or holes (78, 80 FIGS. 4 and 5) sealable by a separate adapter plug (88, FIG. 5) above the coiled tubing hanger. Flow test procedures are also disclosed.

Abstract: A gate valve hydraulic actuator having a stem extension accessible from outside the actuator body to provide override operation of the gate valve, for example in the event of hydraulic failure. The stem extension is lockable to a spring compression hub in a valve open position and a valve closed position by locking dogs selectively engageable in recesses. The locking dogs are operated by a cam spindle coaxially received in the stem extension.

Abstract: A preferably fiber optic line passes into a well interior through a pressure barrier such as a tree or wellhead housing, via a modified horizontal penetrator assembly. The penetrator assembly comprises double poppet valve assemblies arranged to open upon engagement of the penetrator with an interior well component such as a tubing hanger. Retraction of the penetrator closes the poppet valves, sealing the pressure barrier, severing the line and allowing the tubing hanger to be pulled. A replacement line is readily installed through the open poppet valve assemblies.