Cameron International Corporation

Schlumberger Technology Corporation

Onesubsea IP UK Limited

Cameron Technologies Limited

Edmund Peter McHugh

Declan Elliott

Finbarr Williams Evans

Neil Cannon

David C Hoyle

Jerry Allen Martino

Conor James Gray

Michael David Mullin

Andrew Grace

Jonathan D Marshall

Kevin Peter Minnock

David Francis Anthony Quin

Ghulam A Barkatally

Scott A Miller

James Eden White

Donald Roy Augenstein

Matthew Mihalcin

Michael McKeon

Abinesh Gnanavelu

Martin O'Donnell

David Quin

Gregory Greene

Tobias Voelkel

Scott Steven Dahlgren

J Daniel Belnap

David C Wahlquist

Gustavo M Gonzalez

Lynn L Belnap

Frederic Pauchet

Phillip M Theriot

Cheng Peng

Chris Kocurek

Burkhard Sommer

Jesse Morin

Stephen A Chambers

Pierre Petit

Scott Dahlgren

Ivan Tapia

Martin Fleet

Padraic Edward McDonnell

Raymond Nicholas Smyth

Michael Hanes

Padraic Edward Mcdonnell

Finbarr William Evans

A system for generating electrical power may include a flowline having an inlet that receives reservoir fluid at a first pressure, an outlet that outputs the reservoir fluid at a second pressure, a first flow path between the inlet and the outlet, and a second flow path between the inlet and the outlet, in parallel with the first flow path. The difference between the first pressure and the second pressure may include a pressure differential, and the system may include a valve that adjusts the pressure differential. Additionally, the system may include a turbine disposed along the second flow path that generates mechanical energy from a flow of the reservoir fluid induced by the pressure differential, and the mechanical energy may be converted to electrical energy.

Method and system for power generation

An apparatus includes a sensor for sensing pressure, temperature, or another physical parameter at a wellhead assembly or other oilfield component. In one embodiment, an apparatus includes a wellhead body and a branch assembly coupled to the wellhead body such that a bore of the branch assembly is in fluid communication with an interior of the wellhead body through an access passage of the wellhead body. The branch assembly includes a penetration extending outwardly from the bore to an exterior surface of the branch assembly that is radially outward of the bore, and a sensor is installed in the penetration of the branch assembly. Additional systems, devices, and methods are also disclosed.

Wellhead assembly monitoring sensor and method

A needle for a choke valve assembly includes a base portion formed from a first non-superhard material and a tip portion formed from a superhard material. The needle also includes a brazed connection coupling the tip portion to the base portion. The brazed connection includes an insert formed from a second non-superhard material, in which the second non-superhard material is harder than the first non-superhard material and softer than the superhard material. In addition, the brazed connection includes a shim disposed between the insert and the base portion, a first layer of brazing material disposed between the base portion and the shim, and a second layer of brazing material disposed between the shim and the insert.

Needle for a choke valve assembly

A generator unit of a system for generating electrical power includes a generator coupled to a turbine. A flowline coupled to the generator unit conveys a fluid to an inlet of the turbine. A second flowline couples an outlet of the turbine and a tree of a well at a wellsite. The second flowline conveys the fluid from the outlet to the tree.

Systems and methods for electrical power generation

Embodiments of the present disclosure relate to a choke valve that includes a choke body, a choke trim disposed in the choke body, where the choke trim is configured to adjust a cross-sectional area of a flow path in the choke body to adjust a fluid flow through the choke valve, a needle of the choke trim disposed in the flow path of the fluid flow, where the needle includes a first portion having a superhard material, a seat of the choke trim, where the needle is configured to move along an axis extending through an opening of the seat to adjust the fluid flow through the choke valve.

Needle tip and seat for a choke valve

A seat assembly for a choke valve assembly includes a housing having an internal passage, in which the housing is formed from a non-superhard material. The seat assembly also includes a seat disposed within the internal passage of the housing. The seat is configured to engage a needle of the choke valve assembly while the choke valve assembly is in a closed state, and the seat is formed from a first superhard material. In addition, the seat assembly includes an annular insert disposed within the internal passage of the housing downstream from the seat. The annular insert is formed from a second superhard material, and a maximum cross-sectional area of the seat along a longitudinal axis of the seat assembly is greater than a maximum cross-sectional area of the annular insert along the longitudinal axis.

Choke valve assembly

An annulus pressure release system includes a gas metering valve assembly having a fluid pathway. The gas metering valve assembly includes a pressure sensor configured to be fluidly coupled to an annulus and to output a sensor signal indicative of a fluid pressure within the annulus. The gas metering valve assembly also includes an electronically actuated adjustable control valve disposed along the fluid pathway and a electronically actuated two-position valve disposed along the fluid pathway. Furthermore, the gas metering valve assembly includes a flow controller. The flow controller, in response to determining the fluid pressure exceeds a threshold pressure, is configured to output a first control signal to the electronically actuated two-position valve indicative of instructions to open the electronically actuated two-position valve, and to output a second control signal to the electronically actuated adjustable control valve indicative of instructions to adjust a flow of fluid through the fluid pathway.

Annulus pressure release system

A system includes a plug assembly having a housing configured to be positioned within a first passageway formed in a wellhead component. A channel is formed in the housing, and the channel is configured to enable fluid to flow from a bore of the wellhead component into the channel. A sensor is supported by the housing and is configured to measure a condition of the fluid within the channel. An annular seal is configured to extend between an outer surface of the housing and an inner surface of a second passageway formed in a flange that circumferentially surrounds at least part of the plug assembly while the flange is coupled to the wellhead component.

Plug assembly system for monitoring condition of fluid within wellhead

Plug assembly for positioning within a passageway of a wellhead component

Plug assembly for a mineral extraction system

A technique facilitates monitoring fluid phases of a multiphase flow during, for example, well fluid production operations. According to an embodiment, data may be obtained from devices, such as chokes and pressure sensors. This data is then processed to identify phases of the multiphase well fluid flow. The use of data from such well related devices effectively establishes a virtual multiphase flowmeter. However, the output from the virtual multiphase flowmeter may be calibrated periodically by taking measurements from an actual multiphase flowmeter. In some embodiments, the data from a plurality of flow meters having differing physical operating principles may be correlated in a manner to obtain additional parameters related to the multiphase well fluid flow.

Virtual multiphase flowmeter system

A system includes a flow-through component fluidly coupled to a wellhead and including an annular passage disposed about a central flow-through bore. The annular passage is transverse to the central flow-through bore. The central flow-through bore is downstream of the annular passage. The system also includes a first 90-degree elbow fluidly coupled to the flow-through component, a multi-phase flow meter disposed downstream of, and fluidly coupled to the first 90-degree elbow, a second 90-degree elbow disposed downstream of, and fluidly coupled to, the multi-phase flow meter, a monitor fluidly coupled to the second 90-degree elbow, and a choke disposed downstream of, and fluidly coupled to, the second 90-degree elbow, wherein, the central flow-through bore is downstream of the choke.

Flow control module

Growing community of inventors

Longford, Ireland

Edmund Peter McHugh