Schlumberger Technology Corporation

Services Petroliers Schlumberger

Schlumberger Holdings Limited

Michael Hayes Kenison

Robert Bucher

Richard Morrison

Sarmad Adnan

L Michael McKee

Hubertus V Thomeer

John Mervyn Cook

Zheng Rong Xu

Harold Steven Bissonnette

Bart V Thomeer

Robert Greenaway

Jordi Juan Segura Dominguez

John George Allen Charlesworth

Michael Ramsey

Joachim Sihler

Gokturk Tunc

Frank F Espinosa

Douglas Pipchuk

Randolph J Sheffield

Zhanke Liu

Michael G Gay

Robert Van Kuijk

Adam Ian Bowler

Joseph K Flowers

Larry J Leising

Michael L Smith

Kevin J Forbes

Jeffrey Conner McCabe

William D Eatwell

Robin Mallalieu

Vong Vongphakdy

Charles Kearney

David P Smith

Mahmuda Afroz

Santiago Hassig Fonseca

Gregory Campbell

Jose Vidal Noya

Bonnie Powell

Carlos Foinquinos Bocco

Zefer Erkol

A drilling system includes an internal assembly comprising a chassis, a flow diverter, or both, and a strain gauge coupled to the chassis, the flow diverter, or both, in which the strain gauge is configured to output a signal associated with a strain deformation of the internal assembly. The drilling system also includes a drill collar coupled to the internal assembly, in which the internal assembly extends along the drill collar, and the drill collar encloses the internal assembly of the internal assembly such that a strain deformation of the drill collar causes the strain deformation of the internal assembly.

Indirect detection of bending of a collar

A system for use in carrying out downhole coiled tubing applications with two-way telemetry over a single fiber optic thread. The system includes uphole and downhole assemblies each having unique couplers. Specifically, the couplers may be configured to secure the single fiber optic thread at one end thereof while having dedicated fiber optic channels at another side thereof for interfacing a fiber optic transmitter and receiver. Thus, fiber optic data may travel from a surface assembly over the thread for detection at the downhole assembly simultaneous with fiber optic data travelling from the downhole assembly to the surface assembly over the same thread.

Fiber optic coiled tubing telemetry assembly

A technique facilitates prediction of run life. Data relating to a pipe defect is provided to a data processing system for comparison to stored data regarding defects. Additionally, data regarding fatigue life accumulation is stored on the data processing system as it relates to fatigue life of the pipe based on the number of cycles to failure of the pipe without the presence of the defect. The number of cycles experienced by the pipe at the time the defect occurs in the pipe also is determined and provided to the data processing system. The system and methodology further comprise using the data regarding the defect type, the fatigue life accumulation data for the pipe, and the number of cycles experienced by the pipe at the time of the defect to estimate a remaining number of cycles until failure of the pipe.

Fatigue life assessment

Systems and methods regarding a reel, downhole tool, control system, and rotary joint. The reel is disposed at a wellsite surface and containing coiled tubing. A first optical conductor is carried with the coiled tubing. The downhole tool is connected to the coiled tubing for conveyance within the wellbore via the coiled tubing. The control system is disposed at the wellsite surface. The rotary joint is disposed in association with the reel and transmits optical communications between the control system and at least one of the downhole tool and the coiled tubing disposed within the wellbore, via at least the first optical conductor and a second optical conductor extending at least partially between the rotary joint and the control system.

Optical rotary joint in coiled tubing applications

A technique facilitates the anchoring and use of a downhole tool. The technique may be utilized with operations in which fluid is pumped or otherwise flowed through a tubular to the downhole tool. The operations are performed after the downhole tool has been fixed relative to the wellbore and while the tubular remains connected to the downhole tool. In some operations, the downhole tool is manipulated from the surface via the tubular to control placement of the fluid flowing down through the tubular.

Downhole tool anchoring system

A technique facilitates mechanical and electrical connection between components. The components may be coupled mechanically by a threaded engagement and electrically by first and second electrical couplers. The first and second electrical couplers may each have a plurality of electrical contacts oriented for linear engagement. The electrical contacts of the second electrical coupler are mounted on a first portion of the second electrical coupler which is rotatably received by a second portion to enable linear engagement of the electrical contacts while rotating the components relative to each other to form the mechanical connection.

Electrical connection apparatus and method

A technique facilitates an improved operation of a tool, such as a downhole tool. The tool is operated in a manner which provides a dynamic or cyclical loading. The dynamic or cyclical loading of the tool is sampled by a suitable sensing system at a frequency greater than the frequency of the dynamic or cyclical loading to collect detailed data on the dynamic or cyclical loading. The data is used to adjust the tool in a manner which improves operation of the tool. One technique for adjusting the tool is changing the dynamic or cyclical loading of the tool by adjusting the frequency of the dynamic or cyclical loading.

Intervention operations with high rate telemetry

A technique facilitates measuring loads while compensating for the effects of differential pressure. The technique utilizes a load cell comprising a chassis and a sensing element mounted on the chassis. A housing encloses the sensing element in a chamber formed between the chassis and the housing. The housing is connected to the chassis in a manner to transfer loading, e.g. compressive, tensile, and/or torque loading. A pressure compensating piston is positioned within an interior of the chassis and the housing. A plurality of seal points is located in a manner which isolates the sensing element from the effects of differential pressures between the interior and an exterior of the load cell.

Pressure balanced flow through load measurement

The present disclosure relates to a coiled tubing unit. The coiled tubing unit may include coiled tubing with a cable disposed within the coiled tubing. Further, the coiled tubing unit may include a spool about which at least a portion of the coiled tubing is wound, an injector header configured to move the coiled tubing, and a cable slack monitoring feature. The cable slack monitoring feature may be configured to detect an accumulation of cable slack in a portion of the coiled tubing.

Cable monitoring in coiled tubing

A technique for determining conditions downhole in a well, particularly load conditions acting on a well tool, e.g. a bottom hole assembly. The loads acting on a bottom hole assembly or other well tool during a well related operation are measured. Load data is collected and may be transmitted uphole in real time for evaluation at a surface control unit. Based on the load data and other possible data related to the downhole operation, corrective actions can be taken to improve the operation.

System and method for obtaining load measurements in a wellbore

A coiled tubing connection system is used in a well. A connector having an engagement end is used to couple a wellbore device to the end of a coiled tubing. The connector is spoolable, and the engagement end comprises engagement features that facilitate formation of a connection that is dependable and less susceptible to separation.

System and method for forming a coiled tubing connection

The present invention provides methods and apparatus for obtaining downhole well pressure during wellbore operations. One method comprises providing a well intervention tool comprising a straddle sealing assembly having upper and lower annulus sealing elements and a fluid injection port positioned therebetween, the well intervention tool comprising a fluid injection bore having positioned therein a pressure measurement tool; placing the tool in straddle position about a wellbore region to be intervened, with the pressure measurement tool fluidly connected to a wellbore region below the lower annulus sealing element; and performing the wellbore intervention operation while communicating fluid from below the lower annulus sealing element to the pressure measurement tool, thus obtaining a pressure measurement below the lower annulus sealing element during the wellbore intervention operation. This abstract will not be used to interpret or limit the scope or meaning of the claims.

Apparatus and methods for obtaining measurements below bottom sealing elements of a straddle tool

A technique provides an orientation system combined with downhole equipment used in a well. An orientation device is mounted in the downhole equipment, e.g. a bottom hole assembly, for actuation during angular displacement of the downhole equipment. A sensor is mounted to cooperate with the orientation device in detecting the angular displacement.

System and method for measuring an orientation of a downhole tool

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Richmond, TX, United States of America

Michael Hayes Kenison