Schlumberger Technology Corporation

Services Petroliers Schlumberger

Alejandro Camacho Cardenas

Vishwanathan Parmeshwar

Manat Singh

Dudi Abdullah Rendusara

David Milton Eslinger

Arthur Ignatius Watson

David C Hoyle

Andrew Meredith

Spyro J Kotsonis

Michael Raymond Netecke

Leo Steenson

David Robert Evan Snoswell

Edwin Sutrisno

Peter Benjamin Johnson

Spyridon Joseph Kotsonis

Apparatus and methods for measuring backlash of a drive train of an equipment unit. The drive train may comprise an input member operatively connected with an actuator and an output member operatively connected with a work portion of the equipment unit. An example apparatus may include a sensor operable to facilitate operational measurements indicative of an operational parameter associated with the drive train, and a processing device operable to cause the actuator to move the input member until the output member moves, record the operational measurements while the actuator moves the input member, and determine a backlash of the drive train by determining a difference between the operational measurements when the input member starts to move and the operational measurements when the output member starts to move.

Measuring backlash of a drive train

A system for monitoring and optimizing fuel consumption by a genset at an oil rig is described. Gensets require large amounts of fuel to initiate and to maintain in a standby, idling position. The system accesses data in a drill plan to determine the present and future power requirements and initiates gensets if needed; otherwise gensets can be shut down. Excess power can be stored in a power storage unit such as a capacitor, battery, or a liquid air energy storage unit.

Rig power management system

A system and method for controlling a pump in a drilling system, of which the method includes determining a plurality of baseline behaviors for one or more valves of the pump, determining a plurality of in-use behaviors for the one or more valves of the pump. Each of the plurality of in-use behaviors are determined based on one or more measurements from one or more sensors. The method also includes comparing the in-use behaviors and the baseline behaviors, and forecasting, based on the comparison of the in-use behaviors and the baseline behaviors, a remaining useful life of the at least one of the one or more valves.

Mud pump valve leak detection and forecasting

Apparatus and method for reducing pressure pulsations within drilling mud being pumped downhole by a plurality of pumps to thereby improve quality of mud-pulse telemetry. The apparatus may include a position sensor disposed in association with each pump and operable to generate a position signal indicative of operational timing of a corresponding one of the pumps, a surface telemetry device fluidly connected with the drilling mud and operable to output a telemetry quality signal indicative of the quality of mud-pulse telemetry, and a controller communicatively connected with the pumps, the position sensors, and the surface telemetry device. The controller may be operable to receive the position signal and the telemetry quality signal, and cause the pumps to change relative operational timing of the pumps based on the position signal and the telemetry quality signal to improve the quality of mud-pulse telemetry.

Active drilling mud pressure pulsation dampening

A drilling rig system may include a drilling rig including a plurality of surface rig equipment thereon and a plurality of orientation sensors disposed on the plurality of surface rig equipment. The plurality of orientation sensors may be configured to provide relational positioning of the plurality of surface rig equipment on the drilling rig.

Orientation measurements for rig equipment

Methods and systems for performing weigh measurement of a downhole tool string and validating accuracy of corresponding sensors. A method may include commencing operation of a processing device to control operations at an oil and gas wellsite. The processing device may then output a movement control command to a lifting device to cause a downhole tool string to move in accordance to the movement control command, receive an acceleration measurement of the downhole tool string, and determine a weight measurement of the downhole tool string based on the movement control command and the acceleration measurement.

Downhole tool string weight measurement and sensor validation

Systems and methods for monitoring health of systems and components of an oil rig are disclosed. Monitoring usage parameters allows for a probabilistic way to determine when rig equipment will fail. A failure probability curve based on past performance of the equipment can be used. Multiple usage metrics allow for increased accuracy and certainty of a time of failure for the equipment. Using a sufficiently high number of usage metrics allows the failure probability range to be very narrow and therefore the certainty of the prediction is high.

Adaptive probabilistic health management for rig equipment

A system can include a housing that defines an interior space; a shaft disposed at least in part in the interior space of the housing where the shaft includes a longitudinal axis, a curved surface and an end surface; a submersible electric motor operatively coupled to the shaft where the submersible electric motor includes a cable connector; two proximity sensors where each of the proximity sensors includes a sensor aperture disposed in the interior space of the housing; and circuitry operatively coupled to the proximity sensors that determines position values of the shaft with respect to time based at least in part on output of the proximity sensors.

Shaft proximity sensors

An electric submersible pump system can include a shaft; at least one impeller operatively coupled to the shaft; and a bearing assembly that rotatably supports the shaft, where at least one component of the electric submersible pump includes a volumetric composite material that includes polycrystalline diamond material and at least one metallic material.

Unitary thick diamond composite downhole tool components

Systems and methods for calculating a standardized Health Index for a plurality of different components are shown and described. There is a vast number of different components used on an oil rig and each one may have a different definition of new, worn, damaged, or depleted. The system includes a measurement component that takes a measurement of the different components, and a health modeling component which calculates the standardized Health Index. Monitoring the Health Indices provides a rig operator information from which decisions on equipment use can be made.

Rig systems self diagnostics

A system including a rig site with at least one pollution control system located on the rig site. The pollution control system is configured to modify an output of light, noise, or vibrations from the rig site to an environment surrounding the rig site. Additionally, the pollution control system may include at least one active noise cancellation device, at least one active vibration cancellation device, and/or at least one active light control system to modify the light, noise, or vibrations.

System and method for noise, vibration, and light pollution management on rig systems

An electric submersible pump (ESP) can include a shaft; an electric motor configured to rotatably drive the shaft; a housing; a stack of diffusers disposed in the housing; impellers disposed in the housing and operatively coupled to the shaft; and a proximity sensor operatively coupled to the housing.

Proximity sensor system for electric submersible pumps

A system for raising a mast includes a primary cylinder and an actuator. The primary cylinder has a first end coupled to the mast and a second end coupled to a lifting base. The primary cylinder actuates from a retracted position to an extended position to at least partially raise the mast. The actuator actuates from a retracted position to an extended position to at least partially raise the mast, thereby moving the first end of the primary cylinder or the second end of the primary cylinder toward a pivot point between the mast and the lifting base.

Growing community of inventors

Houston, TX, United States of America

Alejandro Camacho Cardenas