Schlumberger Technology Corporation

Zilift Holdings, Limited

Magnomatics Limited

Jamie Cochran

Richard McCann

Zafer Erkol

Calum Crawford

Ivor MacIver

Kenneth John Sears

Jeff Birchall

Maria Yunda

Kellen Wolf

Kenneth Smith

Andrew Henderson

Michael J Rushby

A well pump system includes a fluid pump having an inlet and a discharge. The inlet and discharge are separated longitudinally by an inflatable annular seal. An inflation line extends between the discharge and an inflation inlet of the inflatable annular seal. A pressure relief is operable to direct flow from the discharge to the inflation line. The pressure relief is operable to open the discharge to flow to surface in the well when a predetermined fluid pressure is reached. The system includes means for opening the inflation line to release pressure in the inflatable annular seal when a selected tension is applied to the well pump system.

Inflatable packer system for submersible well pump

An electrical submersible pump (ESP) system, comprises a motor rotationally coupled to a pump. The system has at least one of (i) a rotation stop operable to stop transfer of rotation of the pump to the motor when the ESP is switched off and (ii) a flow control valve operable to stop flow through the pump in both flow directions when the ESP is switched off.

Safety systems for electric submersible pumps

A splice connector for a spoolable tube includes a center portion having an outer diameter equal to an outer diameter of the tube. A longitudinal extension extends in each longitudinal direction outwardly from the center portion. The longitudinal extensions have a plurality of spaced apart segments having an outer diameter equal to an inner diameter of the tube and a plurality of longitudinally spaced apart crimp grooves disposed between the spaced apart segments. An inner diameter of the splice connector is selected such that when the splice connector is assembled to the tube on each longitudinal extension, the splice connector is bendable to a radius of curvature of a winch reel used to deploy the tube into a wellbore.

Spoolable splice connector and method for tubing encapsulated cable

An electrical submersible pump system include an electric submersible pump coupled to a lower end of a production conduit extending into a wellbore, the production conduit in fluid communication with a discharge of the electric submersible pump and with a well conduit extending to the surface. A bypass conduit is nested inside the production conduit and is in fluid communication with the discharge. The check valve is opened when flow is established in the annular space and is otherwise closed. The bypass conduit extends for a selected distance above the discharge. The bypass conduit has a plurality of selected diameter apertures through a wall of the bypass conduit to enable flow into the annular space.

Apparatus and method for improving an electric submersible pump system

A method for deploying a pump in a wellbore includes coupling the pump to an end of a coiled tubing having upper and lower coiled tubing portions interconnected by a releasable tubing connector, and inserting the pump into the wellbore by extending the coiled tubing therein until the releasable tubing connector is disposed in a suspending arrangement proximate a surface of the wellbore. The method includes uncoupling the upper coiled tubing portion from the releasable connector, wherein the releasable connector, lower coiled tubing portion and pump are retained suspended in the wellbore from the suspending arrangement.

Method and apparatus for deploying wellbore pump on coiled tubing

An electrical submersible pump system includes an electric motor operably coupled to a fluid pump which includes first and second fluid ports. The first and second ports are selectively operable as a fluid intake and a fluid discharge of the fluid pump with reversal of a direction of rotation of the fluid pump. Valves in the system are controllable to selectively direct fluid discharge of the fluid pump to an inflation volume of the inflatable packer and toward the surface in a wellbore tubing. The valves are further controllable to vent pressure in the inflation volume to deflate the packer.

Apparatus and method for deploying an electrically operated pump in a wellbore

Apparatus and methods of treating a subterranean formation including introducing a coiled tubing string into a wellbore to a wellbore zone, wherein the string comprises a packer on a bottom hole assembly; introducing an acid fracture treatment through the string; introducing bridging fluid comprising particulates through the string; circulating a portion of fluid in the wellbore; introducing a final portion of fluid with a higher concentration of particulates to further form and consolidate bridge-packer, wherein the concentration of particulates in the final portion of fluid is higher than the introducing the bridging fluid comprising the particulates; squeezing the bridging fluid to isolate a perforation into the zone; moving the string to next zone; and repeating introducing and moving.

Method of isolating a wellbore with solid acid for fracturing

A wellbore rotating instrument system includes a source of rotational energy for transmission thereof to within a wellbore. At least one magnetic gear assembly is coupled at its input to an output of the source. A rotating load is coupled at its input to a rotational output of the magnetic gear assembly. The at least one magnetic gear assembly comprises a housing, a stator disposed in the housing proximate an inner wall thereof, a second shaft rotatably supported on bearings disposed at longitudinally spaced apart locations inside the housing and a first shaft rotatably supported inside the output shaft. The stator comprises a plurality of magnets disposed in generally circular laminations. The second shaft comprises a non-magnetic, electrically non-conductive body and a plurality of pole pieces disposed circumferentially therearound. The first shaft comprises magnets disposed around its exterior circumference and shaped to fit rotatably within the second shaft.

Magnetic gear for use with wellbore instruments

A fiber optic coiled tubing assembly of multiple segments and coupling mechanism therefor. The assembly may be assembled from multiple coiled tubing segments which are pre-loaded with fiber optic line. Thus, the coupling mechanism may be employed for physical coupling of the coiled tubing segments as well as communicative coupling of the lines of the separate segments to one another. As such, pumping of a single fiber optic line through the coiled tubing assembly following coupling of the segments may be avoided. This may be of particular benefit for offshore operations where the joining of multiple coiled tubing segments is likely due to crane load capacity limitations and where such pumping may consume vast amounts of time.

Segmented fiber optic coiled tubing assembly

Apparatus and methods of treating a subterranean formation including introducing a coiled tubing string into a wellbore to a lowest wellbore zone, wherein the string comprises a single packer on a bottom hole assembly; setting a packer at the lowest zone; introducing an acid fracture treatment through the string at a single zone; introducing bridging fluid comprising polyacid particulates through the string; reducing fluid injecting to unset the packer; circulating a portion of fluid in the wellbore while moving the string in the wellbore; introducing a final portion of fluid with a higher concentration of polyacid particulates to further bridge packer formation and consolidation wherein the concentration of particulates in the final portion of fluid is higher than when introducing bridging fluid comprising polyacid particulates through the string; squeezing the bridging fluid to isolate a perforation into the zone; moving the string to next zone; and repeating introducing and moving.

A method of lifting at least a portion of an attachment system to and from a predetermined location comprises providing an attachment system comprising a support member, a socket member, and a locking member, the support member located at the predetermined location and defining an indentation formed therein, the socket member defining a cavity formed therein, placing the socket member in the indentation, placing the locking member in the cavity, locking the locking member in the socket member, and lifting the locked socket member and locking member from the support member and to the predetermined location.

Growing community of inventors

Inverurie, United Kingdom

Jamie Cochran