Halliburton Energy Services, Inc.

Glenn Andrew Wilson

Burkay Donderici

Ahmed Elsayed Fouda

Andreas Ellmauthaler

Jin Ma

Rencheng Song

Wei-Bin Ewe

Luis Emilio San Martin

Etienne M Samson

John Laureto Maida, Jr

John L Maida

Xiang Wu

Li Pan

Tasneem Mandviwala

Paul Andrew Cooper

Christopher Michael Jones

Paul F Rodney

Hsu-Hsiang Wu

Krishna M Ravi

Anthony Herman Van Zuilekom

Darren George Gascooke

Michel Joseph LeBlanc

YiJing Fan

Ira Jeffrey Bush

Wei Li

Mikko K Jaaskelainen

Mark Windsor Roberson

Jing Jin

Scott Goodwin

Mark Elliott Willis

Arthur Cheng

Henry Clifford Bland

Sigurd Moe

Iftikhar Ahmed

Yan-Wah Michael Chia

Seth Cormier

Philip D Nguyen

Craig Wayne Roddy

Li Gao

Chung Lung Chang

Daniel Joshua Stark

Vimal Vinod Shah

Ruijia Wang

Junsheng Hou

Akram Ahmadi Kalateh Ahmad

Wei Hsuan Huang

Kwang Il Suh

Yan Wah Michael Chia

Matthew Hui Chong

Brian Patrick McGuigan

James Dupree

Charles Bartee

Michel LeBLANC

Golchehreh Salamat

Yijing Fan

Alexander Stewart

Paul Ching Ling Chang

Jr Maida John L

Michel Joseph Leblanc

Tasneem A Mandviwala

Paul Cooper

Scott Urquhart

Paul Ching Chang

A well system, and a related method, are included herein. The well system, in one aspect, includes a wellbore extending through first and second subterranean hydrocarbon producing zones, as well as a feedthrough packer located in the wellbore, the feedthrough packer configured to help separate a first inflow of hydrocarbons from the first subterranean hydrocarbon producing zone through a first inflow control valve into production tubing from a second inflow of hydrocarbons from the second subterranean hydrocarbon producing zone through a second inflow control valve into the production tubing. The well system, in accordance with this aspect, may further include a fiber optic cable installed across the feedthrough packer, the fiber optic cable configured to collect inflow data from the first subterranean hydrocarbon producing zone or the second subterranean hydrocarbon producing zone.

Fiber optic enabled intelligent completion

A well system and a related method are discussed. The well system, in one aspect, includes a wellbore extending through a subterranean hydrocarbon producing zone, as well as production tubing located in the wellbore, the production tubing including a first inflow control valve configured to regulate a first inflow of hydrocarbons from the subterranean hydrocarbon producing zone into the production tubing. The well system, in accordance with this aspect, further includes a flange coupled to the production tubing and having a fitting positioned proximate a downhole end thereof, and a fiber optic cable installed within the wellbore, an end connector of the fiber optic cable coupled end to end with the fitting of the flange to fix the fiber optic cable relative to the first inflow control valve.

Fiber optic enabled intelligent completion employing an end connector

A fiber optic sensing (FOS) system and method. The system may include one or more interrogator units and a proximal wavelength division multiplexer (WDM) and a distal WDM optically connectable to the one or more interrogator units, an upgoing transmission fiber, a down-going transmission fiber, and one or more downhole sensing fibers. The method may include transmitting one or more light pulses from an interrogator unit, multiplexing the one or more light pulses from the interrogator unit with a proximal WDM into an upgoing transmission fiber and a down-going transmission fiber, and receiving the one or more light pulses with a distal WDM. The method may further include multiplexing the one or more light pulses from the upgoing transmission fiber and the down-going transmission fiber into one or more downhole sensing fibers and receiving backscatter light from at least one of the one or more downhole sensing fibers.

Multi-fiber sensing topology for subsea wells

A distributed acoustic system (DAS) may comprise an interrogator and an umbilical line attached at one end to the interrogator, a downhole fiber attached to the umbilical line at the end opposite the interrogator. The interrogator may further include a proximal circulator, a distal circulator connected to the proximal circulator by a first fiber optic cable, and a second fiber optic cable connecting the proximal circulator and the distal circulator.

Topside distributed acoustic sensing interrogation of subsea wells with a single optical waveguide

A fiber optic sensing (FOS) system may include a Brillouin Optical Time Domain Analyzer (BOTDA) unit, a first fiber optical cable optically connected to the BOTDA interrogator unit at a first end, and an optical feedthrough system (OFS) optically connected the first fiber optical cable at a second end of the first fiber optical cable. The FOS system may further comprise a fiber optic cable forming a loop within a wellbore that is optically connected to the first fiber optical cable at the OFS and a second fiber optical cable optically connected to the loop at the OFS and wherein the second fiber optical cable is optically connected to the BOTDA interrogator unit.

A method includes positioning a downhole tool in a borehole formed in a subsurface formation, wherein the downhole tool comprises a plurality of calipers arranged around a circumference of the downhole tool. The method includes detecting, using the plurality of calipers, a plurality of standoff measurements at different rotation angles and determining a plurality of apparent diameters of the borehole for the different rotation angles of the downhole tool based on the plurality of standoff measurements and at least one of a radius and a diameter of the downhole tool. The method includes determining a probability function based on the plurality of apparent diameters and determining a shape of the borehole based on the probability function.

Determination of borehole shape using standoff measurements

A distributed acoustic system (DAS) may include an interrogator that includes two or more lasers, a pulser module disposed after and connected to each of the two or more lasers, a wavelength division multiplexer (WDM), wherein each of the pulser modules are connected to the WDM as inputs, and a downhole fiber attached to the WDM as an output and wherein the downhole fiber includes at least one sensing fiber. A method for increasing a sampling frequency may include identifying a length of a downhole fiber connected to an interrogator, generating and launching a light pulse from each of the two or more lasers the pulser module, and delaying an output from the pulser module into the downhole fiber by seconds, where k is a pulse repetition interval of the pulser module and N is equal to the two or more lasers.

Topside interrogation using multiple lasers for distributed acoustic sensing of subsea wells

A method of monitoring a marine animal in a marine environment, implemented by an interrogator unit and a sensing attached to the interrogator, the method comprises deploying the sensing cable within a water column, interrogating, using the interrogator unit, the sensing cable, receiving acoustic data comprising acoustic signals generated by the marine animal, and processing, by a processor coupled to the interrogator unit, the acoustic data to detect a presence of the marine animal.

Marine animal monitoring during seismic surveying using distributed acoustic sensing

A distributed acoustic system (DAS) method and system. The system may comprise an interrogator and an umbilical line comprising a first fiber optic cable and a second fiber optic cable attached at one end to the interrogator. The DAS may further include a downhole fiber attached to the umbilical line at the end opposite the interrogator and a light source disposed in the interrogator that is configured to emit a plurality of coherent light frequencies into the umbilical line and the downhole fiber. The method may include generating interferometric signals of the plurality of frequencies of backscattered light that have been received by the photo detector assembly and processing the interferometric signals with an information handling system.

Topside interrogation for distributed acoustic sensing of subsea wells

Methods and systems for performing injection treatments in subterranean formations stimulated by the ignition of propellants are provided. In some embodiments, the methods comprise: igniting a propellant in one or more secondary boreholes in a subterranean formation to at least partially rupture at least a region of the subterranean formation near the secondary boreholes; introducing a fracturing fluid into a first production well bore in the subterranean formation in or near the ruptured region of the subterranean formation at or above a pressure sufficient to create or enhance at least a primary fracture in the subterranean formation that extends into at least a portion of the ruptured region of the subterranean formation; and introducing a displacement fluid into one or more of the secondary boreholes or an injection well bore in the subterranean formation that comprises one or more fractures penetrating the ruptured region of the subterranean formation.

Fluid injection treatments in subterranean formations stimulated using propellants

A method including, without removing a BHA from a wellbore of a well extending into a formation, extending, into an interior flow bore of the BHA, a first component of a wet latch assembly to provide an extended first component of the wet latch assembly, conveying downhole via a wireline cable, from a surface through an interior flow bore provided by a drill string, a second component of the wet latch assembly, and coupling the second component of the wet latch assembly with the extended first component of the wet latch assembly such that an electrical connection is established between the first component and the second component and between the BHA and the surface via the wireline cable, and testing the formation with a formation tester of the BHA, while providing power and/or data telemetry for the formation tester via the wet latch assembly and the wireline cable.

LWD formation tester with retractable latch for wireline

A data seismic sensing system and method for obtaining seismic refraction data and tomography data. The system may comprise a subsurface sensor array, wherein the subsurface sensor array is a fiber optic cable disposed near a wellbore, a seismic source, wherein the seismic source is a truck-mounted seismic vibrator comprising a base plate, and a surface sensor array, wherein the surface sensor array is coupled to the seismic source. The method may comprise disposing a surface sensor array on a surface, disposing a subsurface sensor array into a wellbore, activating a seismic source, wherein the seismic source is configured to create a seismic wave, recording a reflected seismic wave with the surface sensor array and the subsurface sensor array, and creating a seismic refraction data and a seismic tomography data from the reflected seismic wave.

Simultaneous seismic refraction and tomography

Deconvolution-based processing of ultrasonic waveforms enables robust calculation of two-way travel time for an ultrasonic caliper, particularly in the presence of multiple, proximal reflectors (e.g., mud cake, formation, casing, cement, etc.).

Ultrasonic waveform processing using deconvolution in downhole environments

A system for processing DAS VSP surveys in real-time is provided. The system includes a DAS data collection system coupled to at least one optical fiber at least partially positioned within a wellbore and configured to repeatedly activate a seismic source of energy. The system further includes an information processing system connected to the DAS data collection system. A seismic dataset is received from the DAS data collection system. The seismic dataset includes a plurality of seismic data records. Two or more of the plurality of seismic data records are combined into a stack. A quality metric indicative of a desired signal-to-noise ratio or incoherence of the stack is determined for each processed seismic dataset collected from a repeated source. Instructions are sent to the DAS data collection system to stop activating the seismic source, in response to determining that the quality metric has reached a predefined threshold.

Real-time processing and control of DAS VSP surveys

Growing community of inventors

Houston, TX, United States of America

Glenn Andrew Wilson