Schlumberger Technology Corporation

Intelliserv, Inc.

Intelliserv International Holding, Ltd

John Campbell

Frederic Latrille

Kent D. Harms

Ashers Partouche

Thomas W. Palmer

Kai Hsu

Simon Edmundson

Julian J Pop

Adriaan Gisolf

Kent David Harms

Ryan Sangjun Lee

Thomas Pfeiffer

Yong Chang

Hadrien Dumont

Magdy Samir Osman

Youxiang Zuo

Pierre-Yves Corre

Sylvain Bedouet

Albert Hoefel

Tudor Ioan Palaghita

Adriaan Gerard Gisolf

Morten Kristensen

Arun Sharma

Oliver Clinton Mullins

Reza Taherian

Kang Wang

Steven G Villareal

Cosan Ayan

Stephen Parks

Nathan Mathew Landsiedel

Harold Steven Bissonnette

Shyam B Mehta

Shu Pan

Beatriz E Barbosa

Thomas W Palmer

Edgar Jose Montiel

Abhishek Agarwal

Vladislav Achourov

Thomas W Palmer, Ii

Shardul Sarhad

Steven Villareal

Gbenga Onadeko

James Mather

Henri-Pierre Valero

Pratik Halani

George Christopher Tevis

Catrina De Matos

Gregory Au

Scott C Cook

Daniel Schulz

John Campbell, Jr

Tudor Loan Palaghita

Francois Xavier Dubost

Agob Seradorian

Bryan Zimdars

Bertrand Claude Emile Theuveny

Francois-Xavier Dubost

Iakov Shumakov

Samuel P Subbarao

Kent D Harms

Jr Campbell John

A device may expand a first packer against a borehole wall. A device may expand a second packer against the borehole wall. A device may expand a third packer against the borehole wall. A device may expand a fourth packer against the borehole wall. A device may pressurize an interior zone longitudinally between the second packer and the third packer to a first pressure relative to a hydrostatic borehole pressure that is greater than a second pressure of at least one exterior zone, wherein a first exterior zone is longitudinally between the first packer and the second packer and a second exterior zone is longitudinally between the third packer and fourth packer.

Systems and methods for surface supervision of a downhole tool

Processes for injection of fluids into a wellbore via drill pipe. In some embodiments, the process can include positioning a downhole apparatus on a drill pipe. The process can also include placing the downhole apparatus at a desired station depth within a wellbore. The process can also include attaching a cable to the downhole apparatus from an up-hole environment. The process can also include setting at least one packer to seal a space between at least a portion of the downhole apparatus and an inner surface of the wellbore. The process can also include introducing a fluid to the downhole apparatus through the drill pipe and using a pump to inject at least a portion of the fluid into a geological stratum.

Processes for injection of fluids into a wellbore via drill pipe

Systems and methods presented herein include an assembly of tools that can be arranged in a wellbore in such a way that allows a combination of formation testing (e.g., with a modular formation dynamics testing tool, a wireline formation testing tool, and so forth) and drill stem testing (DST). The assembly of tools enables performance of both types of activities potentially in a single run in the hole, and facilitate full control of the reservoir and formation fluids or, in case of injection, of injected fluids inside the tubing or drill pipe. In addition, the assembly of tools allows for multiple set points to perform zonal evaluations with the formation testing tools, and facilitate performance of full scale flow tests with the DST string.

Zero flaring zonal formation testing with drill stem testing capabilities

Processes for injection of fluids into a wellbore

This disclosure relates to a separating a fluid having multiple phases during formation testing. For example, certain embodiments of the present disclosure relate to receiving contaminated formation fluid on a first flow line and separating a contamination (e.g., mud filtrate) from the formation fluid by diverting the relatively heavier and/or denser fluid (e.g., the mud filtrate) downward through a second flow line and diverting the relatively lighter and/or less dense fluid upward through a third flow line. In some embodiments, the third flow line is generally oriented upwards at a height that may facilitate the separation of the heavier fluid from the relatively lighter fluid based on gravity and/or pumps.

System and method for fluid separation

A method of formation fluid sampling that includes setting a dual packer tool in a wellbore. The dual packer tool is used to isolate an interval between an upper packer and a lower packer. The method also includes drawing fluid from the interval with a lower inlet, until an oil fraction increases over a base line reading, and drawing oil from by pumping at a low rate with an upper inlet.

Method of minimizing immiscible fluid sample contamination

A pressure testing module separable from and configured to be coupled with a tool base that is to be coupled along a downhole tool string to be conveyed within a wellbore extending into a subterranean formation. The pressure testing module includes a chamber and a piston assembly slidably disposed within the chamber, thus dividing the chamber into a first chamber portion and a second chamber portion. The piston assembly is operable to move in response to hydraulic fluid being pumped into the first chamber portion and to draw formation fluid of the wellbore into the second chamber portion in response to the movement of the piston assembly.

Formation pressure testing

An adapter for a wired drill pipe joint includes an annular adapter body having a first end and a second end, an annular recess extending partially into the first end of the adapter body, a communication element disposed at least partially within the annular recess, wherein the second end of the adapter body is configured to releasably couple to an end portion of a first wired drill pipe joint, wherein the annular adapter body includes an arcuate key that is configured to restrict relative rotation of the adapter body with respect to the first wired drill pipe joint, wherein the annular adapter body and the communication element form a shoulder configured for engagement with a corresponding shoulder of a second wired drill pipe joint to form a rotary shouldered threaded connection between the first wired drill pipe joint and the second wired drill pipe joint.

Pipe joint having coupled adapter

A configuration for testing fluid with a single packer includes at least one sample inlet and at least one guard inlet surrounding a periphery of the at least one sample inlet, wherein the at least one sample inlet has at least one side that is parallel to another side of the at least one sample inlet and the at least one sample inlet has at least two rounded ends connecting each of the parallel sides, and the at least one guard inlet has at least one side that is parallel to another side of the at least one guard inlet and the at least one guard inlet has at least two rounded ends connecting each of the parallel side of the guard inlet.

Single packer inlet configurations

A method including positioning a downhole acquisition tool in a wellbore in a geological formation; performing a pretest sequence to gather at least one of pressure or mobility information based on downhole acquisition from a sample line, a guard line, or both while the downhole acquisition tool is within the wellbore. The pretest sequence includes controlling a valve assembly to a first valve configuration that may allow the fluid to flow into the downhole tool via one or more flowlines toward a pretest system. The one or more flowlines include the sample line only, the guard line only, or both the sample line and the guard line; and drawing in the fluid through the one or more flowlines. The method also includes controlling the valve assembly to a second valve configuration. The second valve configuration is different from the first valve configuration and may block the one or more flowlines from drawing in the fluid.

System and methods for pretests for downhole fluids

Techniques for improving implementation of a downhole tool string to be deployed in a borehole formed in a sub-surface formation. In some embodiments, a design device determines a model that describes expected relationship between properties of the downhole tool string, the borehole, the sub-surface formation, and mud cake expected to be formed in the borehole; determines calibration locations along the borehole based on properties of the borehole; determines candidate spacer configurations based on contact force expected to occur at contact points between the downhole tool string and the mud cake when deployed with each of the candidate spacer configuration via the model; and determines a final spacer configuration to be used to attach one or more spacers along the downhole tool string based on expected head tension to move the downhole tool string when deployed in the borehole with each of the candidate spacer configurations via the model.

Downhole toolstring spacer placement systems and methods

A method includes placing a downhole acquisition tool in a wellbore in a geological formation within a hydrocarbon reservoir that contains a reservoir fluid. The method also includes performing downhole fluid analysis using the downhole acquisition tool in the wellbore to determine a measurement associated with the reservoir fluid and using a processor to: estimate a fluid component property by using an equation of state based the measurement and simulate a diffusion process using a diffusive model that takes into account the estimated fluid property. The diffusive model accounts for gravitational diffusion of components in the reservoir fluid. The method also includes using the processor to estimate reservoir fluid geodynamic processes based on the fluid property; compare the estimated reservoir fluid geodynamic processes with the measurement associated with the reservoir fluid; and output reservoir fluid geodynamic processes corresponding to the measurement associated with the reservoir fluid.

Reservoir fluid geodynamics system and method

A method includes operating a downhole acquisition tool including a guard probe and a sample probe in a wellbore that contains a fluid that includes a native reservoir fluid and a contaminant. The method also includes receiving a first portion of fluid into the guard probe and a second portion of fluid into the sample probe, estimating a contamination level of the first or second portions based on a fluid property of the respective first and second portions, determining an initial guard flow rate of the first portion, determining an initial sample flow rate of the second portion, using a processor to adjust a guard flow rate of the second portion over pump time after the contamination level of the first portion is at or below a contamination level threshold, and adjust a sample flow rate of the first portion based on the adjusted guard flow rate and total flowrate.

Systems and methods for controlling flow rate in a focused downhole acquisition tool

Growing community of inventors

Richmond, TX, United States of America

Ashers Partouche