Exxonmobil Upstream Research Company

Exxonmobil Technology and Engineering Company

Michael C Romer

Randy C Tolman

Tony W Hord

P Matthew Spiecker

Rami Jabari

Ted Alan Long

Timothy J Hall

Andrey A Troshko

Scott R Buechler

Jason Y Wang

Federico A Tavarez

Billy-Bob K Walker

Christopher C Frazier

Michael C Tschauner

Michael Thomas Hecker

Timothy I Morrow

Dragan Stojkovic

Federico G Gallo

Conal H O'Neill

Rosmer Maria Brito Jurado

Andrew D McFadden

Adam J Johnson

Robert A Frantz, Iii

Salvador G Vela

Anthony J Bermea

Krishnan Kumaran

Mark M Disko

Pavlin B Entchev

William A Symington

Louis-Claude Porel

Peter A Gordon

David A Howell

George R King

Jeff H Moss

Santos D Ortiz

Timothy G Benish

Giovanni A Grasso

Gaston L Gauthier

Michael K Johnson

Stuart G Luyckx

Matthew J Tenny

Joseph Salviz

Wilfried Manfoumbi

Francois Ramon Leon Porel

Jessica I Chidi

Dustin H Rose

Daniel R Flowers

Billy-Bob Walker

Conal H O'neill

Robert A Frantz

Lucas Marrero

Ted A Long

Iii Vela Salvador G

Andrew D Mcfadden

An electric submersible pump (ESP) system is described herein. The ESP system includes a pump and a motor connected to drive the pump. The pump and motor are disposed to pump fluid into production tubing in a wellbore. A connector is in fluid communication with the production tubing and the connector contains a receptacle to receive a plug. A fixed power cable section is connected at a first end to power the motor. The fixed power cable section is fixedly connected at a second end to the receptacle of the connector. Also included in the ESP system is an ESP power cable that extends through the production tubing to an ESP surface unit. The ESP power cable includes a removable plug to engage the receptacle of the connector.

Electric submersible pump (ESP) system and method

A plunger lift system, as well as a method for monitoring plunger parameters within a wellbore using such a plunger lift system, are provided. The plunger lift system includes a lubricator attached to a wellhead at the surface and a plunger dimensioned to travel through the production tubing upon being released from the lubricator. The plunger lift system also includes magnetic sensor systems installed along the production tubing, where each magnetic sensor system includes a magnetic sensor for detecting the passage of the plunger as it travels through the production tubing, as well a communication device for transmitting communication signals between the magnetic sensor systems and a computing system located at the surface, where the computing system includes a processor and a non-transitory, computer-readable storage medium including computer-executable instructions that direct the processor to dynamically determine the plunger position and/or velocity based on the received communication signals.

Plunger lift systems and related methods

A capacitive cable, as well as a method for operating a downhole electro-hydraulic (EH) tool using the capacitive cable, are described herein. The capacitive cable includes at least one standard conductor and at least one capacitive conductor including integrated wire-shaped capacitors. The method includes inserting a tool string including the capacitive cable and an attached downhole EH tool into a wellbore and conducting power from the surface to the downhole EH tool via the standard conductor(s) of the capacitive cable. The method also includes storing electrical energy downhole within the capacitive conductor(s) of the capacitive cable, and activating the downhole EH tool to provide for the rapid release of the electrical energy from the capacitive conductor(s) into the downhole EH tool, initiating an electro-hydraulic event within the wellbore.

Capacitive cable for a downhole electro-hydraulic tool

Systems and a method for resisting a fluctuation in a value of a parameter relating to well equipment using a magnetorheological dampener system are described herein. The method includes continuously determining the value of the parameter relating to the well equipment, determining a fluctuation in the value of the parameter, and comparing the fluctuation in the value of the parameter to a preset limit. The method also includes energizing an electromagnet to increase a viscosity of a magnetorheological fluid (MRF) if the fluctuation exceeds the preset limit.

Magnetorheological dampener system for protecting well equipment

Methods for the in-situ application of coating agent to production tubing within wellbores using plunger lift systems are provided herein. One method includes shutting in the wellbore, pressurizing the production tubing to displace fluids from the production tubing, and dropping a plunger from the surface into the production tubing such that the plunger travels toward the bottom of the production tubing until landing on a bumper spring. The method also includes pumping a predetermined amount of the coating agent from the surface into the production tubing such that the coating agent flows to the bottom of the production tubing and settles on top of the plunger and utilizing the differential pressure between the production tubing and the annulus to return the plunger and the coating agent to the surface, where the coating agent is applied to the inner diameter of the production tubing as it flows toward the surface.

Methods for in-situ application of a coating agent to production tubing using a plunger lift system

The hydrocarbon wells include a radioactive tracer system, a production conduit, a lift gas supply conduit, a lift gas supply system configured to provide a lift gas stream to the lift gas supply conduit, and one or more gas lift valves each being configured to selectively permit lift gas to enter the production conduit and mix with reservoir liquid therein to generate a produced fluid stream. The radioactive tracer system is configured to inject a radioactive tracer into the lift gas stream and to detect the radioactive tracer within the produced fluid stream. The methods include injecting the radioactive tracer into the lift gas stream, flowing the radioactive tracer through an open gas lift valve into the production conduit, mixing the radioactive tracer with the reservoir liquid to generate a tracer-marked liquid band within the produced fluid stream, and detecting radiation from the tracer-marked liquid band.

Hydrocarbon wells including tracer systems and methods of tracing a flow path of lift gas within a hydrocarbon well utilizing a radioactive tracer

Downhole tools and methods for detecting a downhole obstruction within a wellbore. The downhole tools include a positioning mechanism, which is configured to facilitate positioning of the downhole tool within a target region of a wellbore of a hydrocarbon well, an acoustic pulse generator, which is configured to generate an acoustic pulse within a wellbore liquid that extends within the wellbore and fluidly contacts the downhole tool, and a sensor assembly, which is configured to detect a reflected acoustic pulse within the wellbore liquid. The methods include positioning a downhole tool within a target region of a wellbore, generating an acoustic pulse, propagating the acoustic pulse within a wellbore liquid, and reflecting the acoustic pulse from a downhole obstruction. The methods also include propagating a reflected acoustic pulse within the wellbore liquid, receiving the reflected acoustic pulse, and characterizing the downhole obstruction based upon the reflected acoustic pulse.

Downhole tools and methods for detecting a downhole obstruction within a wellbore

Hydrocarbon wells and methods of probing a subsurface region of the hydrocarbon wells. The hydrocarbon wells include a wellbore, a downhole sensor storage structure, and a detection structure. The wellbore may extend within a subsurface region and between a surface region and a downhole end region. The downhole sensor storage structure is configured to release a flowable sensor into a wellbore fluid that extends within the wellbore, and the flowable sensor may be configured to collect sensor data indicative of at least one property of the subsurface region. The detection structure may be configured to query the flowable sensor to determine the at least one property of the subsurface region. The methods include releasing a flowable sensor, collecting sensor data with the flowable sensor, and querying the flowable sensor.

Hydrocarbon wells and methods of probing a subsurface region of the hydrocarbon wells

Systems and a method are provided for protecting a gas lift valve (GLV) from erosion. An example system includes a gas lift valve that includes an unloading protection orifice, and wherein the unloading protection orifice unloading protection orifice includes a different open area than a valve seat in the gas lift valve.

Protecting gas lift valves from erosion

Methods of completing a hydrocarbon well. The methods include establishing a first fluid seal with an isolation device, forming a first perforation with a perforation device, and fracturing a first zone of a subsurface region with a pressurizing fluid stream. The methods also include moving the isolation device and the perforation device in an uphole direction within a tubular conduit of a downhole tubular that extends within a wellbore of the hydrocarbon well. Subsequent to the moving, the methods further include repeating the establishing to establish a second fluid seal, repeating the forming to form a second perforation with the perforation device, and repeating the fracturing to fracture a second zone of the subsurface region.

Methods of completing a hydrocarbon well

A self-adjusting gas lift system and corresponding self-adjusting gas lift valve (GLV) are described herein. The self-adjusting gas lift system includes a number of self-adjusting GLVs that fluidically couple an annulus of a well to an interior of a production tubing of the well. Each of the self-adjusting GLVs is configured to open to allow a compressed gas to flow from the annulus to the interior of the production tubing when a pressure differential between an injection pressure of the compressed gas within the annulus and a production pressure of fluids within the production tubing is within an engineered range. Each of the self-adjusting GLVs is also configured to close when the pressure differential is outside the engineered range.

Self-adjusting gas lift system

A self-destructible frac ball is described herein. The self-destructible frac ball is configured to seal a hydraulic flow path through a fluid conduit of a frac plug when engaged on a ball seat of the frac plug. The self-destructible frac ball includes an activation mechanism configured to activate a destructive medium in response to the satisfaction of at least one predetermined condition. The self-destructible frac ball also includes the destructive medium, which is configured to destroy the self-destructible frac ball and a corresponding destructible ball retainer when activated by the activation mechanism. The destruction of the self-destructible frac ball and the corresponding destructible ball retainer reestablishes the hydraulic flow path through the fluid conduit of the frac plug.

Self-destructible frac ball enclosed within a destructible ball retainer

An electric submersible pump (ESP) monitoring system is described herein. The ESP monitoring system includes a base monitoring unit and a discharge monitoring unit that are communicably coupled via a ground path. The discharge monitoring unit is hydraulically coupled to the pump discharge and is configured to measure a discharge parameter relating to the pump discharge and transmit data corresponding to the discharge parameter to the base monitoring unit via the ground path. The base monitoring unit is electrically connected to the motor of the ESP system and is configured to measure a base parameter relating to the motor and/or the pump intake, receive the transmitted data corresponding to the discharge parameter from the discharge monitoring unit, combine the data corresponding to the discharge parameter and the data corresponding to the base parameter, and transmit the combined data to an ESP surface unit via an ESP power cable.

System and method for measuring discharge parameters relating to an electric submersible pump

A method of operating a reciprocating system including a rod pump for pumping liquids from a wellbore. The method includes determining rod position of the rod pump using a wave-based technology detector, the rod pump comprising a rod string carrying a down hole pump and a drive system including a drive motor coupled to the rod string through a transmission unit; communicating rod position to a data acquisition system receiving one or more other measurements of rod pump operation to determine rod pump performance; and adjusting at least one operating parameter to enhance rod pump performance. A method of determining operating parameters and optimizing performance of an oil or gas production rod pump, and a system for determining rod position of an oil or gas production rod pump are also provided.

Rod pump position measurement employing wave-based technologies

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The Woodlands, TX, United States of America

Michael C Romer