Halliburton Energy Services, Inc.

Geosensor Corporation

Weatherford/lamb, Inc.

Input/output, Inc.

Landmark Graphics Corporation

Sercel Inc.

Weatherford Technology Holdings, LLC

Welldynamics, B.v.

John L Maida

Etienne M Samson

Daniel Joshua Stark

David Andrew Barfoot

Mikko K Jaaskelainen

John Luscombe

Neal Gregory Skinner

John Paul Bir Singh

Satyan Gopal Bhongale

Krishna Babu Yerubandi

Glenn Andrew Wilson

Andreas Ellmauthaler

Hua Xia

Alan D Kersey

David L Perkins

Li Gao

Michel Joseph LeBlanc

Sean Gregory Thomas

Louis W Erath

David E Sharp

Gary J Craig

William Cecil Pearl, Jr

Christopher Lee Stokely

Malcolm Paul Varnham

Ira Jeffrey Bush

Wolfgang Hartmut Nitsche

Yenny Natali Martinez

Alexis Wachtel, Ii

Kris M Ravi

William John Hunter

Xinwei Lan

William Markus

Todd J Green

Casey Giron

Lee E Siems

Dale E Jamison

Paul David Ringgenberg

Krishna M Ravi

Gary P Funkhouser

Peter James Boul

Ilker R Capoglu

Sandeep D Kulkarni

Brian Vandellyn Park

Yao Ge

Lizheng Zhang

Megan Renee Pearl

Tasneem Mandviwala

Jason Edward Therrien

Yinghui Lu

Rory Dennis Daussin

David O Johnson

Glenn Robert McColpin

Han-Sun Choi

Allen Curtis Cekorich

Welton Danniel Souza

Chafaa Badis

Nitika Kalia

Greyson Orval Knapp

Sebastian Kroczka

David P Sharp

Erhard Lothar Edgar Kluth

Alexis Garcia

Sam Bull

Andreas Ellamauthaler

Reinis Kanders

Kashyap Choksey

Tom O'Brien

Grevson Knapp

Patrick John Jonke

Ed Kluth

Lawrence Griffin

Norm Warpinski

Etienne Samson

Paul Rodney

Kris Ravi

Aspects of the subject technology relate to systems and methods for determining positions of fluids during a cementing process in real-time. Systems and methods are provided for receiving one or more sensing parameters from a distributed acoustic sensing fiber optic line positioned in a wellbore during a cementing process, determining types of fluid proximate to the wellbore based on the one or more sensing parameters received from the distributed acoustic sensing fiber optic line, determining pressure gradients of the types of fluid based on the one or more sensing parameters received from the distributed acoustic sensing fiber optic line, and compiling flow profiles for the types of fluid proximate to the wellbore based on at least one of the determining of the types of fluid and the determining of the pressure gradients of the types of fluid.

Downhole pressure sensing for fluid identification

Systems and methods of the disclosed embodiments include a rheometer having a housing with a fluid inlet and a fluid outlet, a cylinder with a cavity located to receive fluid that passes into the fluid inlet, a motor configured to rotate the cylinder, a torsion bob within the cavity, and a controller located remotely from the rheometer. The controller includes a pressure regulator configured to pressurize fluid to power the motor, a rotation sensor configured to receive an optical rotation signal indicating a rotation speed of the cylinder, and a torque sensor configured to receive an optical signal indicating a torque on the torsion bob. The controller may be configured to receive a rotation speed signal from the rotation sensor, a torque signal from the torque sensor, and to calculate a shear stress for the fluid based on the rotation speed signal and the torque signal.

Optical fluidic methods for a rheometer

A system includes a controlled acoustic source. The system also includes distributed acoustic sensors along a conduit. The distributed acoustic sensors obtain acoustic signal measurements as a function of position along the conduit in response to at least one acoustic signal provided by the controlled acoustic source. The system also includes a processing unit that generates an acoustic activity plot or report based on the acoustic signal measurements. The acoustic activity plot or report is used to identify at least one acoustic impedance boundary anomaly as a function of position along the conduit.

Methods and systems employing a controlled acoustic source and distributed acoustic sensors to identify acoustic impedance boundary anomalies along a conduit

A telemetry system is disclosed for use in a wellbore extending from the surface. The telemetry system includes fiber optic cable locatable in the wellbore, the fiber optic cable including at least one optical fiber. The telemetry system also includes a telemetry device operable to transmit an optical telemetry signal over the fiber optic cable. An optical detector operably connected to the optical fiber and includes a single-photon detector operable to receive the optical telemetry signal transmitted over the optical fiber.

System and method for arrayed telemetry using single-photon detectors

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

Temperature data collected from a distributed temperature sensing system may be used to prepare a temporal thermal profile of the wellbore. The temporal thermal profile may be used to determine a generalized heat transfer coefficient (k) and/or a generalized geothermal profile (T). The temporal thermal profile and the generalized heat transfer coefficient (k) and/or the generalized geothermal profile (T) may be used to estimate thermal properties of a wellbore, such as well as fluid and flow characteristics. A heat of hydration index may also be determined based on the temporal thermal profile.

Thermal analysis of temperature data collected from a distributed temperature sensor system for estimating thermal properties of a wellbore

Locating a loss zone while cementing a well casing in a well bore includes: inserting a fiber-optic cable into the well bore, wherein the fiber optic cable is part of one or more Distributed Fiber-Optic Sensing (DFOS) systems; detecting a loss circulation signature, while cementing the well casing, at a point along the fiber-optic cable by at least one of the one or more DFOS systems; and locating the loss zone within the well bore based on the point along the fiber-optic cable at which the loss circulation signature was detected.

Loss circulation detection during cementing operations

A well system includes a fiber-optic cable positionable downhole along a length of a wellbore. The well system further includes an opto-electrical interface to communicatively couple to the fiber-optic cable to monitor a gas released from a well element within the wellbore. Further, the well system includes a processing device and a memory device that includes instructions executable by the processing device. The instructions cause the processing device to detect hydrogen absorption by the fiber-optic cable within the wellbore and determining a location of deterioration of the well element using the detected hydrogen absorption by the fiber-optic cable.

Continuous assessment of well elements using fiber optics

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

Aspects of the subject technology relate to systems and methods for determining cement barrier quality of a cementing process. Systems and methods are provided for receiving data from a distributed acoustic sensing fiber optic line positioned proximate to cement barrier of a wellbore, determining at least one zonal isolation in the cement barrier based on the data received from the distributed acoustic sensing fiber optic line, and compiling a cement bond log based on the determining of the at least one zonal isolation in the cement barrier.

Using active actuation for downhole fluid identification and cement barrier quality assessment

Activating a reaction of a sealant, such as cement, with a fiber optic cable, the reaction causing hardening of the sealant. The sealant may be used in wellbore cementing operations to cement a casing in a wellbore. The fiber optic cable may be deployed by attaching it to the outside of a casing during insertion into the wellbore. The activation of the sealant can be via thermal or optical initiation in order to causing a hydration reaction or polymerization.

Systems and methods for sealing casing to a wellbore via light activation

A distributed acoustic system may comprise an interrogator which includes a single photon detector, an umbilical line comprising a first fiber optic cable and a second fiber optic cable attached at one end to the interrogator, and a downhole fiber attached to the umbilical line at the end opposite the interrogator. A method for optimizing a sampling frequency may comprise identifying a length of a fiber optic cable connected to an interrogator, identifying one or more regions on the fiber optic cable in which a backscatter is received, and optimizing a sampling frequency of a distributed acoustic system by identifying a minimum time interval that is between an emission of a light pulse such that at no point in time the backscatter arrives back at the interrogator that corresponds to more than one spatial location along a sensing portion of the fiber optic cable.

Single-photon detector-based interrogation for distributed fiber optic sensing of subsea wells

System and methods for detecting a composition in a wellbore during a cementing operation. An electrochemical cell can be disposed towards an end of a wellbore. The electrochemical cell can generate electrical energy in response to a physical presence of a composition at the electrochemical cell. The composition can be pumped from a surface of the wellbore during a cementing operation of the wellbore. Further, a telemetry signal indicating the physical presence of the composition at the electrochemical cell can be generated based on the electrical energy generated by the electrochemical cell. As follows, the telemetry signal can be transmitted to the surface of the wellbore.

Cement as a battery for detection downhole

In some embodiments, a method and apparatus, as well as an article, may operate to determine downhole properties based on detected optical signals. An optical detection apparatus can include an optical detector including a superconducting nanowire single photon detector (SNSPD) for detecting light received at an input section of fiber optic cable. The optical detection apparatus can further include a cryogenic cooler configured to maintain the temperature of a light-sensitive region of the SNSPD within a superconducting temperature range of the SNSPD. Downhole properties are measured based on detected optical signals received at the optical detection apparatus. Additional apparatus, systems, and methods are disclosed.

Cooled single-photon detector apparatus and methods

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Houston, TX, United States of America

John L Maida