Shell Oil Comapny

Combustion Tec

Other

Air Products and Chemicals, Inc.

American Air Liquide, Inc.

Baker Hughes Oilfield Operations LLC

L'air Liquide, Societe Anonyme Pour L'etude Et L'exploitation Des

General Electric Company

Air Liquide America, L.p.

Marathon Oil Canada Corporation

Shell Canada Energy Cheveron Canada Limited

L'air Liquide Societe Anonyme Pour L'etude Et L'exploitation Des Procedes Georges Claude

L'air Liquide, Societe Anonyme a Directoire Et Conseil De Surveillance Pour L'etude Et L'exploitation Des Procedes Georges Claude

Baker Hughes Holdings LLC

Ge Inspection Technologies, Gmbh

Mahendra L Joshi

Olivier Charon

Harley A Borders

Scott Lee Wellington

Jingyu Cui

Ovidiu Marin

Aleksandar Georgi Slavejkov

Stanley Nemec Milam

Lee Broadway

Frederik Arnold Buhrman

Patrick J Mohr

Brian Paul Reeves

Jacques Dugue

James K Nabors

Alexey Tyshko

Robert Klenner

Remi Pierre Tsiava

Julian Robert Kift

Xuele Qi

Jeffrey Potts

Alireza Shahkarami

Dewey Lavonne Parkey, Jr

Donald J Fournier

Raymond Patrick Murphy

Arnaud Fossen

Erik Edwin Engwall

John William Johnston

Zbigniew Zurecki

Xianming Jimmy Li

Thomas McClain Scott

Shyam Sivaramakrishnan

Stewart Blake Brazil

Eric Streicher

Yi Liao

Glen Murrell

Kevin Ray Heier

Guoxiang Liu

Pejman Kazempoor

Cherish M Hoffman

Whip C Thompson

Jean-Francois Simon

Hayley Stephenson

Walter Farman Farmayan

Haifeng Jiang

Benjamin J Jurcik, Jr

Jose Armando Salazar-Guillen

Virginia Howe

Willem P C Duyvesteyn

Naresh Sundaram Iyer

Mark Daniel D'Agostini

Jeremy Daniel Van Dam

Michael Reynolds

Chengbao Wang

Steven Hector Azzaro

Gary Williams

William Robert Licht

Michael Franklin Hughes

Stephen P DiMartino, Sr

John Frank Foss

Pierre Bodelin

Nurali Virani

Jin Cao

Thierry Legiret

Kevin Alan Lievre

Nasr Eldine Alkadi

John Foss

Nathan A Etter

Dustin Michael Sharber

Olivier Delabroy

Robert Krumm

Victor Jose Acacio

Reda El-Mahbes

Matthew Landon George

Michael Edward Habel

Jack L Nitzman

Grant Hartman

Marvin E Tester

Michael Salerno

Scott-Lee Wellington

Frederik Arnold Buehrman

Rogier Maarten Kamerbeek

Lily Nuryaningsih

Abud Saeed Jamaluddin

Patrice Rich

Qi Xuele

Curtis Johnson

Mohamed Ouf

Glenn Richard Murrell

Jeannine M Harris

Bernard Labegore

Fran&ccedil;ois Lacas

Jianmin Zhang

Valeria Di Filippo

Bilal Zoghbi

Ammar Abdilghanie Mohammed

Ghazal Izadi

Roman E Grosman

Paul O'Connor

Dominic J Zelnik

Catherine James

A distributed monitoring and analytics system is configured to automatically monitor conditions in a remote oil field. The distributed monitoring and analytics system generally includes one or more mobile monitoring units that each includes a vehicle, a sensor package within the vehicle that is configured to produce one or more sensor outputs as the mobile monitoring unit traverses the remote oil field, and an onboard computer configured to process the output from the sensor package. The sensor package can include any number of sensors, including a camera that outputs a video signal for computer vision analysis and a gas detector that outputs a gas detection signal based on the detection of fugitive gas emissions within the remote oil field.

Intelligent mobile oilfield analytics platform

Systems and methods involve capturing gaseous and liquid byproducts from the recovery of hydrocarbons and then using those captured byproducts for commercially and environmentally advantageous purposes. A method for recovering hydrocarbons from a well includes the steps of placing the well in a first mode of operation in which gases from the well are stored under pressure in a gas storage unit on the surface, and placing the well in a second mode of operation in which gases are transferred from the gas storage unit into an underground gas storage formation through the well. Methods for managing produced water include the steps of storing the produced water in an underground water storage reservoir, heating the produced water with geothermal energy, and transferring the heated water to an energy recovery system to generate electricity from the heated produced water.

Low emissions well pad with integrated enhanced oil recovery

A method is provided for controlling the operation of an offset well located near an active well that is undergoing a hydraulic fracturing operation that may produce a fracture driven interference (FDI) event to the offset well. The method includes providing an FDI intervention system that includes a computer-implemented predictive model for determining a risk of the FDI event occurring during the hydraulic fracturing operation, calculating a risk-weighted FDI event cost of the FDI event impacting production from the offset well, and calculating a defensive intervention implementation cost to apply a defensive intervention on the offset well to mitigate harm from an FDI event. The method includes calculating a cost comparison based on a comparison of the defensive intervention implementation cost and the risk-weighted FDI event cost. The method concludes with automatically controlling the operation of the offset well with the FDI intervention system based on the cost comparison.

Automatic well control based on detection of fracture driven interference

Systems, methods, and a computer readable medium are provided for monitoring and detecting a gas emission. Sensor data including gas concentration and wind data associated with a gas emission from an emission source is received from Near-Field and Far-Field sensors configured within a gas production and distribution environment. The sensor data can be provided as inputs to a Near-Field dispersion model to determine an emission rate associated with the gas emission and one or more source locations associated with the gas emission. The emission rate can be included in emission data and provided for output. Related apparatus, systems, techniques, and articles are also described.

Gas emission monitoring and detection

A method for determining a location and trajectory for a new wellbore relative to an adjacent wellbore includes: receiving controllable variable data and uncontrollable variable data related to fracturing a formation by a stimulation operation in a first wellbore penetrating the formation; receiving pressure communication event or pressure non-communication event identification data related to identification of a pressure communication event or pressure non-communication event in a second wellbore penetrating the formation in response to the fracturing; extracting features from the controllable and uncontrollable variable data to provide extracted features; detecting a pressure communication event using the extracted features and the pressure communication event or pressure non-communication event identification data using an analytic technique; identifying one or more quantified causes of the detected pressure communication event using an artificial intelligence technique; and determining the location and trajectory of the new wellbore using the one or more quantified causes.

Process for infill well development in a subsurface reservoir

A system for the resilience of an electric submersible pumping system to a transient power interruption includes a power backup connected to the variable speed drive of the pumping system. A method for controlling the electric submersible pump during the transient power interruption includes connecting a variable speed drive to a power source, charging one or more rechargeable batteries within the power backup, and connecting the power backup to the variable speed drive. The method continues with the steps of operating the motor with the variable speed drive, detecting a disruption in AC power from the power source to the variable speed drive, and applying power from the power backup to the variable speed drive to operate the motor during the transient interruption in electrical power.

System and method for managing transient power disruptions on ESP motor drives

A system and method of generating electricity. A work string extends into a wellbore. A heat pump unit at a surface location circulates a working fluid through the work string to absorb heat from a formation surrounding the wellbore. A turbine generates a rotation from the working fluid that has absorbed the heat. A generator generates electricity from the rotation of the turbine. The electricity is transmitted to the surface location via an electrical cable.

Downhole geothermal power generation and storage

Systems and methods for communicating between surface equipment and a downhole tool installed in a well. First and second toroidal transformers are positioned around an inner one of a pair of coaxial structural members of a well completion (e.g., a pump rod and tubular, or a tubular and a well casing) which are electrically coupled to form an electrical circuit. A transmitter generates a data signal which is applied to the first toroidal transformer, causing a corresponding electrical current to be induced in the circuit, which then induces the data signal on the second toroidal transformer. A receiver coupled to the second toroidal transformer receives the data signal induced on the second toroidal transformer. The transmitter and receiver may be components of transceivers that may communicate bidirectionally. Additional toroidal coils and transceiver may be provided to communicate with equipment at additional locations in the well.

Systems and methods for wireless communication in a well

Systems and methods for wireless power transmission in a well, wherein first and second structural members of a well completion are electrically connected to form an electrical circuit, with first and second toroidal transformers positioned around the second structural member at different axial locations. A power source coupled to the first toroidal transformer is configured to generate an output voltage which is applied to the first toroidal transformer, inducing a corresponding electrical current in the electrical circuit. This in turn induces a second voltage on the second toroidal transformer, which is provided to a downhole tool. The tool may include conditioning circuitry, which rectifies the received power and charges a battery. The downhole electric tool is then operated using the received power.

Systems and methods for wireless power transmission in a well

A method of treating/cooling a process fluid includes spraying a working fluid into a stream of the process fluid to form a mixed fluid and separating the working fluid from the mixed fluid to form a treated/cooled process fluid and a separated working fluid. The separated working fluid is conditioned to form a recycled working fluid and sprayed into the stream of the process fluid. A variant includes indirectly cooling a process fluid using a cooled working fluid. The spraying may use a working fluid in the form of microdroplets with Sauter Mean Diameter no greater than 100 microns onto a selected fluid.

Advanced process fluid cooling systems and related methods

A collapsible packer for use in a well includes a deployment assembly, a retraction assembly and a sealing assembly extending between the deployment assembly and the retraction assembly. The deployment assembly may include a spring and a degradable stop configured to offset the force applied by the spring. The degradable stop can be manufactured from a material that dissolves when contacted by fluid in the well. The retraction assembly may by hydraulically or spring energized.

Self-cleaning packer system

The current subject matter is related to optimizing resource (e.g., steam) allocation within steam assisted gravity drainage (SAGD) system, and predicting future oil production from production wells of the SAGD system. In some embodiments data characterizing a hypothetical rate of steam injection into injection wells of the SAGD system can be applied within a capacitance resistance model (CRM) to determine an estimated rate of future fluid production, the fluid being a mixture of oil and water. An emulsion viscosity, as well as the estimate rate of future fluid production, can be applied within a Koval fractional flow model to determine an estimate rate of future oil production. In some cases, the hypothetical rate of steam injection can be optimized based on an optimization objective, e.g., a steam-to-oil ratio (SOR).

Rapid steam allocation management and optimization for oil sands

A surface-based separation assembly for use in separating fluid. The surface-based separation assembly includes a gas-liquid separator configured to receive a fluid stream, and configured to separate the fluid stream into a gas stream and a mixed stream of at least two liquids. A liquid-liquid separator is in flow communication with the gas-liquid separator. The liquid-liquid separator is configured to receive the mixed stream from the gas-liquid separator, and is configured to separate the mixed stream into a first liquid stream and a second liquid stream. The assembly further includes a rotatable shaft including a first portion extending through the gas-liquid separator, and a second portion extending through the liquid-liquid separator. The rotatable shaft is configured to induce actuation of the gas-liquid separator and the liquid-liquid separator.

Surface-based separation assembly for use in separating fluid

A well bore robot is configured to travel along an magnetic track element. The magnetic track element includes a plurality of track magnets. The well bore robot includes a robot body and at least one robot magnet. The robot magnet is disposed within the robot body and configured to magnetically and alternatingly engage and disengage with the track magnets. Alternating engagement and disengagement of the robot magnet with the track magnets conveys the well bore robot along the magnetic track element.

Electromagnetic well bore robot conveyance system

A system includes a casing-liner, a first downhole separator, a production pump, and a second downhole separator disposed within a wellbore casing disposed in a wellbore. An annular disposal zone is defined between the casing-liner and the wellbore casing. First downhole separator is configured to receive a production fluid from a production zone and generate a hydrocarbon rich stream and a water stream including a solid medium. Production pump is configured to pump the hydrocarbon rich stream from the first downhole separator to a surface unit. Second downhole separator is configured to receive the water stream including the solid medium from the first downhole separator, separate the solid medium to generate a separated water stream, and dispose the solid medium to the annular disposal zone. The system further includes a tube configured to dispose the separated water stream from the second downhole separator to a water disposal zone in wellbore.

Hydrocarbon production system and an associated method thereof

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Darien, IL, United States of America

Mahendra L Joshi