Schlumberger Technology Corporation

Services Petroliers Schlumberger

Schlumberger Holdings Limited

Prad Research and Development Limited

Kent David Harms

Albert Hoefel

Julian J Pop

Steven G Villareal

Jeremy Murphy

Michael J Stucker

Ashers Partouche

Steven Villareal

Kai Hsu

Dale E Meek

William Ewan Brennan, Iii

Qingyan He

Sylvain Ramshaw

Thomas W Palmer, Ii

Gocha T Chochua

Stephen Parks

Victor Matthew Bolze

Lei Chen

Desheng Zhang

Shayan Darayan

Frederic Latrille

Luis Pamintuan

Karidja Louise-Olivia Djibo

Walter Luckett

Satya Bhan

Francois Bernard

Taylor Johnson

John Campbell, Jr

Robert Kelly

Kong Hauw Sarwa Bakti Tan

Daniel Fernandez

Qing Zhang

William E Brennan Iii

Jeremy T Murphy

A method for calibrating an electromagnetic measurement tool includes deploying a test loop about a first antenna in the electromagnetic measurement tool and electromagnetically coupling the test loop and the first antenna and measuring a first voltage. The test loop is then deploying about a second antenna in the electromagnetic measurement tool and electromagnetic ally coupling the test loop and the second antenna and measuring a second voltage. A ratio of the first voltage to the second voltages is computed that can be used to calibrate the first antenna with respect to the second antenna.

Antenna calibration in an EM logging tool

A shield assembly for logging tool sensors includes a single piece cylindrical shield and first and second cylindrical end clamps deployed about opposing axial ends of the cylindrical shield. The cylindrical shield is deployed about a logging sensor disposed on a logging tool collar. At least one of the first and second end clamps includes one or more keys for engaging a corresponding slot in the shield and a corresponding pocket in an outer surface of the tool collar. Engagement of the key with the corresponding slot and the corresponding pocket is operative to prevent relative rotational and relative axial motion between the cylindrical shield, the first and second end clamps, and the tool collar.

Shield assembly for logging tool sensors

Formation fluid sample container apparatus are described. An example apparatus includes a downhole tool having a body including an opening and a cavity extending into the body from the opening. The sample container includes an elongated container for holding a formation fluid sample and a sheath coupled to an outer surface of the elongated container and at least partially surrounding the elongated container. The sample container is fixed in the cavity and the sheath is to increase the mechanical integrity of the elongated container in a downhole environment.

Formation fluid sample container apparatus

The present discloses valve systems that include valve shift detection systems that can be employed to determine when a valve has shifted. In certain embodiments, the valve shift detection systems include a switch integrated into a valve block that may be closed upon shifting of the spool valve. In certain embodiments, the switch may include a component that completes a circuit upon contacting the valve. The valve shift detection systems also may include a controller designed to detect a voltage or current change produced by completing the circuit.

Valve shift detection systems and methods

A system includes a valve subassembly configured to be disposed along an internal flowline exit of a first internal flowline within a downhole drilling module. The valve subassembly includes an active valve configured to regulate flow of a fluid through the internal flowline exit and a passive valve configured to be passively controlled based on a differential pressure between a first volume of the downhole drilling module and a second volume surrounding the downhole drilling module.

While drilling valve system

Systems, methods, and devices for predicting pump performance in a downhole tool are provided. A pump performance predictor may receive inputs and generate outputs that predict the performance of a pump of a pumpout module of a downhole tool. The pump performance predictor may calculate and output a set of first predictions that include, for example, the minimum alternator voltage of a power module used to power the electronics of the pumpout module, the maximum pump flowrate, the pumpout performance, and the achievable formation mobility. The pump performance predictor may also calculate and output a set of second predictions that may include, for example, a pump volume efficiency, a pressure profile in a flowline, the number of strokes to fill a sampling bottle, and the time to fill the sampling bottle.

Predicting pump performance in downhole tools

Systems, methods, and devices for fault detection and tolerance in a downhole tool string are provided. If a fault is detected in an electrical path between tools of downhole tool string, one or more switches of a fault detection and tolerance circuit may be kept open to isolate the fault in an electrical path between tools of downhole tool string. If a fault is not detected, one or more switches of a fault detection and tolerance circuit may be closed to enable the transmission of signals on the electrical path. In some embodiments of fault detection and tolerance circuits, an additional one or more switches may be kept open to isolate the fault in electronics of the tool.

Fault detection and tolerance in downhole tool string assemblies

A rotary check valve is disclosed having sealing surfaces between two sealing members that engage with a rotating shearing motion. The rotating shearing motion may shear debris between the sealing members and minimize or eliminate blockage of fluid passageways in the sealing members. In a closed position, the upper sealing member and lower sealing member are rotated such that fluid passageways in the upper sealing member and fluid passageways in the lower sealing member are not aligned and blocked by the sealing surfaces. The sealing members of the rotary check valve may be biased to a closed position via a spring.

Rotary check valve

An apparatus for extending the operational flow rate range of a turbine is described herein. Two or more removable sleeves may be used to change the cross-sectional area of a turbine. Each removable sleeve may define or eliminate the stator gap between a stator blade tip and an inner wall of the removable sleeve and a rotor gap between a rotor blade tip and an inner wall of the removable sleeve. A movable sleeve may be disposed in the turbine and may move between a first position and a second position in response to changes in the pressure differential across the turbine. The movable sleeve may define or eliminate a stator gap between a stator blade tip and the inner conical surface of the sleeve or a hub of the turbine and a rotor gap between a rotor blade tip and the inner conical surface of the sleeve.

Apparatus for extending the flow range of turbines

A system includes a valve assembly configured to be disposed within a downhole tool module, a valve of the valve assembly configured to regulate flow of a fluid within the downhole tool module, a pump configured to supply a hydraulic fluid to actuate the valve, and an actuator configured to drive the pump.

Pump actuated valve

A drilling system includes a first section of a drilling tool having a collar configured to hold internal components of the first section. The drilling system also includes a second section of the drilling tool configured to be coupled with the first section in a specific orientation relative to the first section. The second section is interchangeable with at least one different section.

Drilling tool system and method of manufacture

A downhole tool includes a body including an opening and a cavity extending into the body from the opening. A sample container is fixed in the cavity and includes an elongated container for holding a formation fluid sample and a sheath coupled to an outer surface of the elongated container and at least partially surrounding the elongated container.

A downhole modular tool includes a first module, a second module, a third module, and one or more connectors for connecting the first, second, and third modules. Each module includes a drill collar, a drilling fluid passageway, a first fluid passageway, and a second fluid passageway. The one or more connectors connect any one of the first, second, and third modules, to another of the first, second, and third modules to transfer the drilling fluid, the first fluid, and the second fluid between the connected modules.

Modular connector

A method includes drawing formation fluid from a formation into a pressure test chamber of a downhole tool while the downhole tool is positioned at a location within a wellbore. The method also includes, while the downhole remains positioned at the location, measuring pressure of the formation fluid drawn into the pressure test chamber and operating a first pump to route additional formation fluid from the formation through the downhole tool and out into the wellbore. Still further, the method includes operating a second pump to expel the formation fluid from the pressure test chamber and to mix the formation fluid with the additional formation fluid such that the formation fluid expelled from the pressure test chamber is also routed through the downhole tool and out into the wellbore along with the additional formation fluid.

Growing community of inventors

Richmond, TX, United States of America

Kent David Harms