Schlumberger Technology Corporation

Schlumberger Canada Limited

Services Petroliers Schlumberger

Schlumberger Holdings Limited

Rex Burgos

Douglas Pipchuk

Rod W Shampine

Xiaowei Weng

Victor Matthew Bolze

Iain Michael Cooper

Patrick Schneider

John Styre

Wassim Kharrat

Jahir A Pabon

Shunfeng Zheng

Francois M Auzerais

Hubertus V Thomeer

Zheng Rong Xu

John David Rowatt

Tullio Moscato

Robert Van Kuijk

Larry J Leising

Nathan Wicks

Robin Mallalieu

Philippe Tardy

Moussa Kane

Fernando Baez Manzanera

Philippe M J Tardy

Doug Pipchuk

Jahir Pabon

Philippe M Tardy

Victor M Bolze

A valve assembly for reversibly governing fluid flow through coiled tubing equipment. Valves of the assembly may be directed by a telemetric line running from an oilfield surface. In this manner, valve adjustment and/or reversibility need not require removal of the assembly from the well in order to attain manual accessibility. Similarly, operation of the valves is not reliant on any particular flow rate or other application limiting means. As such, multiple fluid treatments at a variety of different downhole locations may take place with a reduced number of trips into the well and without compromise to flow rate parameters of the treatments.

Surface controlled reversible coiled tubing valve assembly

A method for determining a flow distribution in a formation having a wellbore formed therein comprises the steps of positioning a bottomhole assembly in a wellbore, the assembly including an injection port for dispensing a fluid, a first sensor disposed upwell from the injection port, and a second sensor disposed downwell from the injection port, wherein each of the sensors generates a feedback signal representing a flow rate of the fluid in a portion of the wellbore, determining an approximate depth of a portion of the bottomhole assembly in the wellbore, generating a data model based upon an instruction set, the data model representing flow characteristics of the fluid in the wellbore, wherein the data model is derived from the feedback signal and the approximate depth of the injection port, and analyzing the data model based upon an instruction set to extrapolate a characteristic of the formation.

Methods for interpretation of downhole flow measurement during wellbore treatments

A technique provides an actuation system employed to actuate a tool, such as a downhole tool. The tool is actuated by an actuator element, e.g. a ball, which is selectively releasable from a remote location for interaction with the tool. A carrier is used to hold the actuator element at the remote location until its desired release for interaction with the tool. The carrier may comprise an electro-mechanical actuator mechanism positioned to control release of the actuator element upon receipt of an appropriate control signal.

Automated remote actuation system

Apparatus, systems, and methods operable to perform production logging of a lateral wellbore of a multi-lateral well. For example, a downhole tool is conveyed into a main wellbore of a multi-lateral well via coiled tubing. A component of the downhole tool is used to locate a lateral wellbore extending from the main wellbore, and then the downhole tool is conveyed into the lateral wellbore via the coiled tubing. Production logging data is then obtained with the downhole tool in the lateral wellbore.

Production logging multi-lateral wells

A technique facilitates performance of a perforating operation in a wellbore. The technique comprises positioning a perforating gun assembly downhole in a wellbore via coiled tubing. The perforating gun assembly has a plurality of individually controllable perforating gun sections which may be selectively fired at different well zones. An optical fiber is deployed along the coiled tubing to deliver control signals to the perforating gun assembly. The control signals enable sequential firing of the individually controllable perforating gun sections at the desired locations, e.g. well zones, along the wellbore.

System and method for performing a perforation operation

Apparatus and a method for delivering a rod in a cylinder including propagating a rod in a cylinder along the interior of the cylinder, and introducing a motion in an orientation orthogonal to a length of the rod, wherein the motion comprises multiple motion sources along the length of the rod, and wherein the multiple motion sources comprise a control system that controls at least one of the motion sources. An apparatus and method for delivering a rod in a cylinder including a cylinder comprising a deviated portion, a rod comprising a length within the cylinder, multiple motion sources positioned along the length of the rod, and a control system in communication with at least one of the motion sources, wherein the control system controls the location of frictional contact between the rod and cylinder over time.

Method and apparatus of distributed systems for extending reach in oilfield applications

A method for determining characteristics of a tubing deployed in a wellbore includes positioning a first sensor within the wellbore, wherein the first sensor generates a first feedback signal representing a downhole parameter measured by the first sensor, positioning a second sensor adjacent a surface of the formation in which the wellbore is formed, wherein the second sensor generates a second feedback signal representing a surface parameter measured by the second sensor, generating a simulated model representing a simulated surface weight indicator of the tubing, wherein the simulated model is derived from at least the first feedback signal, generating a data model representing a measured weight indicator of the tubing, wherein the data model is derived from the second feedback signal, comparing the data model to the simulated model, and adjusting a parameter of the simulated model to substantially match the simulated model to the data model.

Method for determining characteristics of tubing deployed in a wellbore

A method for determining flow distribution in a formation having a wellbore formed therein includes the steps of positioning a sensor within the wellbore, wherein the sensor generates a feedback signal representing at least one of a temperature and a pressure measured by the sensor, injecting a fluid into the wellbore and into at least a portion of the formation adjacent the sensor, shutting-in the wellbore for a pre-determined shut-in period, generating a simulated model representing at least one of simulated temperature characteristics and simulated pressure characteristics of the formation during the shut-in period, generating a data model representing at least one of actual temperature characteristics and actual pressure characteristics of the formation during the shut-in period, wherein the data model is derived from the feedback signal, comparing the data model to the simulated model, and adjusting parameters of the simulated model to substantially match the data model.

Method for interpretation of distributed temperature sensors during wellbore treatment

Methods, systems, and apparatus that are suitable for use in production of hydrocarbons from subterranean heavy oil deposits employ a subterranean cavity in communication with a borehole. The cavity is preferably formed along a U-tube borehole by coiled tubing reaming operations and/or radial drilling and explosive blasting.

Methods, systems, and apparatus for production of hydrocarbons from a subterranean formation

Methods, systems and apparatus for production of hydrocarbons from a subterranean formation

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Richmond, TX, United States of America

Rex Burgos