Halliburton Energy Services, Inc.

Michel Joseph LeBlanc

John Laureto Maida, Jr

Andreas Ellmauthaler

Neal Gregory Skinner

Christopher Michael Jones

Yenny Natali Martinez

Mikko K Jaaskelainen

Daniel Joshua Stark

Mark Elliott Willis

Xinwei Lan

Glenn Andrew Wilson

Anthony Herman Van Zuilekom

John L Maida

Etienne M Samson

James Martin Price

Xiang Wu

David Andrew Barfoot

Ira Jeffrey Bush

Wolfgang Hartmut Nitsche

Luis Emilio San Martin

Li Gao

Mark Anton Proett

Bin Dai

Darren George Gascooke

Eric James Davis

Satyan Gopal Bhongale

Sudhir Kumar Gupta

Jason Edward Therrien

Mehdi Alipour Kallehbasti

Gireesh K Bhat

Ramon Hernandez Marti

Kenneth Glenn Dixson

Jose R Sierra

Arabinda Misra

William N Gibler

Dale E Jamison

Michael Thomas Pelletier

David L Perkins

Jay Paul Deville

William Walter Shumway

William Cecil Pearl, Jr

Simon Shaw

Sean Gregory Thomas

Larry A Jeffers

Ian Bradford Mitchell

Megan Renee Pearl

Henry Clifford Bland

Richard L Lopushansky

John R Dennis

Jian Li

Peter Ojo Olapade

Marcus Ray Hudson

Marcelo Civarolo

Pramod Chamarthy

Frederick J Gillham

Christopher Wayne Berry

A test tool attached to test string comprising a fluid conduit is deployed to a test position within a wellbore. The deployment includes hydraulically isolating a portion of the wellbore proximate the test tool to form an isolation zone containing the test position. A fluid inflow test is performed within the isolation zone and an initial formation property and a fluid property are determined based on the fluid inflow test. A fluid injection test is performed within the isolation zone including applying an injection fluid through the test string into the isolation zone, wherein the flow rate or pressure of the injection fluid application is determined based, at least in part, on the at least one of the formation property and fluid property.

Drill stem testing

An active fiber stretcher assembly can be used for data acquisition systems. A time-break signal can be detected that coincides with a seismic event emitted from a seismic controller. A predetermined waveform can be generated in response to detecting the time-break signal. The predetermined waveform may be encoded onto a fiber optic cable using a fiber stretcher. A data acquisition system connected to the fiber optic cable may detect the predetermined waveform on the fiber optic cable and initiate acquisition operations including: receiving, during the seismic event, light signals returning from a portion of the fiber optic cable in a subterranean environment; determining one or more characteristics of the subterranean environment from the light signals; and storing the one or more characteristics.

Triggering distributed acoustic sensing downhole using an active fiber stretcher assembly

A wellbore system includes a logging unit having a retrievable logging cable coupled to a downhole tool within a wellbore and a depth correlation unit in the downhole tool that provides current depth data for the wellbore through the retrievable logging cable for recording of a current depth by the logging unit. The wellbore system also includes a distributed acoustic sensing unit that includes a seismic processing unit and a seismic profiling unit connected to a separate optical cable of the retrievable logging cable having distributed acoustic sensing channels, wherein an assignment of the distributed acoustic sensing channels along the separate optical cable is determined by an offset distance between the current depth of a formation reference region within the wellbore and a previous reference depth of the formation reference region within the wellbore. A distributed acoustic sensing method is also included.

Retrievable fiber optic vertical seismic profiling data acquisition system with integrated logging tool for geophone-equivalent depth accuracy

A cable comprises a protective jacket and a plurality of conductor bundles symmetrically arranged within the protective jacket. The cable comprises optical fibers arranged within the protective jacket relative to the plurality of conductor bundles such that an orthogonal mode electrical field symmetry for the plurality of conductor bundles is retained.

Hybrid electro-optic wireline cable

Embodiments of a device, system and method are disclosed herein. In one embodiment, a device comprises a sample cell configured to interact a fluid sample with an ion selective substrate to modify an optical characteristic of the ion selective substrate according to an ion concentration of the fluid sample, wherein the sample cell is also configured to optically interact an illumination light with the ion selective substrate to generate a sample light; an optical element configured to interact with the sample light to provide a modified light that has a property of the fluid sample; and a detector that receives the modified light and provides an electrical signal proportional to the property of the fluid sample indicated by the modified light; and wherein the ion selective substrate comprises a membrane, the membrane configured to change an optical property in a selected wavelength range, according to the property of the fluid sample.

System and methods for downhole property measurement

Systems and methods relate to borehole seismic studies. Traditionally, borehole seismic studies are conducted using geophones. Seismic acquisition can be performed using fiber optic Distributed Acoustic Sensing (DAS). Because DAS measures dynamic relative displacement over a gauge length, which is different from particle velocity, DAS data can be converted into an equivalent geophone output response. Operations include converting DAS data into distributed velocity, and then, converting the velocity output into an equivalent geophone response. Various aspects include separating the data into interleaving subsets, integrating each subset along the spatial coordinates, selecting a window width over which the median of each subset will be calculated and subtracted from the data, performing a spatial average or low-pass filtering over contiguous values, performing a time-domain low-pass filtering, and performing the velocity-to-geophone conversion operation.

Distributed acoustic sensing to geophone seismic data processing

A well system includes a fiber-optic cable that can be positioned downhole along a wellbore. The well system further includes a plurality of opto-electrical interfaces to communicatively couple to the fiber-optic cable to monitor temperature and strain along the fiber-optic cable. Additionally, the well system includes a processing device and a memory device that includes instructions executable by the processing device to cause the processing device to perform operations. The operations include receiving data representing frequency or phase shift measurements from the opto-electrical interfaces using at least two frequency or phase shift measurement techniques. Further, the operations include generating a temperature shift output and a strain change output using an inversion comprising sensitivity ratios and the data representing the frequency or phase shift measurements from the plurality of opto-electrical interfaces.

Temperature and strain measurement using a shared fiber-optic cable within a wellbore

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 positions of cementing plugs during a cementing process. Systems and methods are provided for determining a length of an optical fiber line deployed into a wellbore for a cementing process, measuring signal intensity data as a function of distance from the optical fiber line, the optical fiber line being attached to a lower cementing plug and an upper cementing plug, the upper cementing plug being attached to the optical fiber line by an attenuation assembly, generating signal intensity profiles based on the signal intensity data as a function of a round trip delay of a light signal in the optical fiber line, and determining positions of the lower cementing plug and the upper cementing plug based on the signal intensity profiles of the optical fiber line.

Tracking cementing plug position during cementing operations

A device including an ion-selective membrane arranged within an optical path of the device and coupled to a sample cell to interact with a fluid sample and thereby modify an optical response of the ion-selective membrane according to an ion concentration in the fluid sample, is provided. The device also includes an integrated computational element (ICE) arranged within the optical path, so that the illumination light optically interacts with the ICE and with the ion-selective membrane to provide a modified light that has a property indicative of the ion concentration in the fluid sample. A detector that receives the modified light provides an electrical signal proportional to the property of the modified light. A method and a system for using the above device are also provided.

Adding ion sensitivity to an integrated computational element (ICE)

A system can calculate estimated strain data for a fracture in a geological formation at each of a plurality of selected locations detectable by a strain measurement device. The system can receive real strain data from the strain measurement device for the geological formation. The system can perform an inversion to determine a probable distribution of fluid volume and hydraulic fracture orientation in the geological formation based on the estimated strain data and real strain data. The system can determine adjustments for a fracturing operation based on the inversion.

Determining fluid distribution and hydraulic fracture orientation in a geological formation

A method comprises flowing a mud into a wellbore, wherein the mud has a mud composition and has a weight in a defined range. The method includes introducing a fluid pill into the mud flowing into the wellbore, wherein the fluid pill has an injection fluid with an injection composition that is different from the mud composition. A particulate has been added to the injection fluid to increase the weight of the fluid pill. After flowing the mud into the wellbore such that the fluid pill is positioned in a zone of the wellbore: filtering out the particulate from the injection fluid; injecting, after the filtering, the injection fluid into the zone; measuring a downhole parameter that changes in response to injecting the injection fluid into the zone; and determining a property of the formation of the zone based on the measured downhole parameter.

Reverse drill stem testing

A thermal sensor module, comprising: a housing, wherein the housing comprises a first end and a second end, wherein the housing is hollow and configured to allow a fluid to flow into the housing through the first end and exit through the second end; a heat source, wherein the heat source is disposed at a central axis of the housing and traverses at least partially through the housing; and a temperature sensor, wherein the temperature sensor is positioned in the housing to measure temperature of the fluid flowing in the housing.

Sensor to measure thermal conductivity and heat capacity of reservoir fluids

A densitometer in the present disclosure comprises a measurement module that is calibrated to estimate sample fluid density with high accuracy and minimized sensitivity to temperature of tube and clamp components in the densitometer. The densitometer measures sample fluid density by vibrating the sample fluid and measuring the resonant frequency of the sample fluid, then estimating the sample fluid density based on this resonant frequency. The measurement module is calibrated specific to dissimilar tube and clamp materials. The tube and the clamp of the densitometer have materials are chosen to be cost-effective based on the specifications of the densitometer system and to have coefficients of thermal expansion (CTEs) which reduce temperature dependence of the resonant frequency of the sample fluid inside of the densitometer.

Densitometer with dissimilar tube and clamp materials

Growing community of inventors

Houston, TX, United States of America

Michel Joseph LeBlanc