Schlumberger Technology Corporation

Services Petroliers Schlumberger

Schlumberger Holdings Limited

Garud Bindiganavale Sridhar

Joseph P Varkey

Byong Jun Kim

Wayne Fulin

Alhad Phatak

Rajesh Luharuka

Jonathan Wun Shiung Chong

Avinash Ramesh

Dean Michael Willberg

William Troy Huey

Dmitriy Ivanovich Potapenko

Douglas Pipchuk

Andrea Sbordone

James Ernest Brown

Noor F Sait

Noor Sait

Hau Nguyen-Phuc Pham

Matthew Edward Billingham

Gregoire Omont

Rod W Shampine

Philippe Gambier

Jean-Louis Pessin

Bruno Lecerf

Jesse Lee

Anthony Louis Collins

Joe Hubenschmidt

Rashmi Bhavsar

Christopher Todd Shen

Kim A Hodgson

Adam Ethan Keilers

Jijo Oommen Joseph

Zinaida Usova

Herbe Gomez Conzatti Y Martinez

Matthew Billingham

Lewis Callaway

Nikki Morrison

Anna Dunaeva

Du'Bois Joseph Ferguson

John Robin Starr

Ivan Alaniz

Laurent Yves Claude Coquilleau

Mike Wedge

Liang Du

Aparna Raman

Dan Fu

Terry Riddle

Seth Silverman

Amit Bhatia

Christopher Joseph Decker

Methods for initiating chemical reactions in a wellbore include delivering one or more reactive components via a carrier fluid to the wellbore. The one or more reactive components delivered to the wellbore are configured to enable one or more chemical reactions to occur. The one or more chemical reactions are carried out until a threshold volume of the one or more reactive components is delivered to the wellbore.

Systems and methods of initiating energetic reactions for reservoir stimulation

A mixing unit comprising a frame, a rheology control portion, and a high-volume solids blending portion. The rheology control portion comprises means for receiving a first material from a first transfer mechanism, a dispersing/mixing system connected with the frame, and a first metering system to meter the first material from the first material receiving means to the dispersing/mixing system. The dispersing/mixing system disperses/mixes the metered first material with a fluid to form a first fluid mixture. The high-volume solids blending portion comprises means for receiving a second material from a second transfer mechanism, a solids blending system connected with the frame, and a second metering system to meter the second material from the second material receiving means to the solids blending system. The solids blending system blends the metered second material with the first fluid mixture to form a second fluid mixture.

Integrated process delivery at wellsite

A system includes a hydraulic fracturing system including a tank having a slurry and an injector line, where the injector line is disposed between a high-pressure pump and a treatment line to fluidly couple to a wellhead. The system includes a plurality of valves disposed adjacent to the injector line and a control system communicatively coupled to the plurality of valves. The control system fluidly isolates the injector line using the plurality of valves, fills the injector line with an amount of the slurry using a first valve of the plurality of valves, and injects the slurry into the treatment line using a second valve of the plurality of valves.

Systems and methods for injecting fluids into high pressure injector line

Methods of delivering reactive components to a geological formation disclosed herein include generating a plurality of microholes along a wellbore, the plurality of microholes comprising one or more openings, and the plurality of microholes are configured to connect the wellbore to the geological formation. Methods further include delivering the one or more reactive components to the plurality of microholes via a carrier fluid, wherein the one or more reactive components are configured to enable one or more chemical reactions to occur, and wherein the carrier fluid is configured to expand, and controlling a flow rate of the one or more reactive components based on whether a volume of the one or more reactive components delivered to the plurality of microholes is greater than a threshold volume.

Apparatus and methods for energizing well operations fluids, including a fluid energizing device directly or operatively connected between first and second conduits. The fluid energizing device includes a chamber. A first fluid enters the chamber from the first conduit, and a second fluid enters the chamber from the second conduit and energizes the first fluid within the chamber. A third conduit conducts the energized first fluid from the chamber to a wellhead.

Fluid energizing device

Methods and apparatus for monitoring and controlling wellsite emissions. A mobile emissions monitoring device is operated in airspace above a wellsite to generate and transmit a monitor signal related to emissions in the airspace. The emissions may be associated with wellsite equipment at the wellsite. A processing system in receipt of the monitor signal operates to cause a change in an operational parameter of the wellsite equipment based on information conveyed by the monitor signal.

Wellsite emissions monitoring and control

Disclosed herein is a method for viscosity measurement of non-Newtonian fluid for in-line measurement and process control. The process involves mixing additives to a base fluid to form the non-Newtonian fluid. The non-Newtonian fluid is fed to an in-line viscosity measurement device to obtain a rheological measurement. The addition of the additives to the base fluid is then adjusted based on the rheological measurement. A system for accomplishing the same is also disclosed.

Viscometer and methods of use thereof

A method for monitoring wellsite equipment may include producing a digital image and a thermal image of the wellsite equipment; identifying one or more equipment units in the digital image; overlaying the thermal image on the one or more identified equipment units in the digital image to thermally map the one or more identified equipment units; and analyzing temperature conditions of at least a first identified equipment unit.

Visual and thermal image recognition based PHM technique for wellsite

A system and method are disclosed for preparing a treatment fluid and includes charging packets containing an additive encased within a liner to a first container packet storage area of a first container; passing the packets to a packet shredder; breaching the liners of the packets to expose the additive; passing exposed additive to a mixer; passing an aqueous solution to the mixer from a second container; and mixing the exposed additive with the aqueous solution to form the treatment fluid. The first container can also include a first container proppant storage area, and proppant is passed from the first container proppant storage area to the mixer. The treatment fluid can be charged to a well bore penetrating a subterranean formation. The system and method can also include a silo positioned in fluid flow communication with the first container and partitioned into a silo packet storage area and a silo proppant storage area.

System and method for preparing a treatment fluid

A technique facilitates removal of heat. The technique involves moving a process fluid through a buffer tank which is combined with a heat exchange system. The heat exchange system includes a conduit carrying a coolant fluid which removes excess heat from a heat source. The conduit is routed to the buffer tank so that the cooler process fluid moving through the buffer tank is able to remove heat from the coolant fluid before it is routed back to the heat source for continued heat removal. In a well application, for example, a heat source, e.g. an electric motor, may be located on a transport vehicle and cooled by the coolant fluid. The heat transferred to the coolant fluid from the heat source is removed by routing the coolant fluid through the conduit associated with the buffer tank. This enables the cooler process fluid in the buffer tank to be used in lowering the temperature of the coolant fluid.

System and method using buffer tank for heat exchange

Systems and methods for handling wellsite packets for a wellsite are provided. The wellsite packets include soluble packaging with wellsite materials therein. The wellsite has surface equipment and downhole equipment positioned about a wellbore. The handling system includes at least one feeder, at least one mixer, at least one metering device, and a pump. The feeder moves the wellsite packets directly or indirectly into the mixer. The mixer stimulates dissolution of the soluble packaging so as to mix the wellsite materials with a fluid to form a wellsite mixture. The metering device selectively controls the number of wellsite packets moving to the mixer. The pump is operatively coupled to the mixer to pump the wellsite mixture at the wellsite.

Wellsite handling system for packaged wellsite materials and method of using same

A cable component is provided that includes at least one optical fiber; and a two shaped profiles having inner and outer surfaces such that the inner surfaces combine to from an enclosure for the at least one optical fiber, wherein a first of the two shaped profiles has a cross sectional arc that is greater than a cross sectional arc of a second of the two shaped profiles.

Packaging for encasing an optical fiber in a cable

A method of deploying a cable into a wellbore penetrating a subterranean formation that includes providing a cable. The cable includes an insulated conductor; an armor wire layer surrounding the insulated conductor; and a polymeric material disposed in interstitial spaces formed between armor wires forming the armor wire layer, and in interstitial spaces formed between the at least one armor wire layer and the at least one insulated conductor. The method also includes introducing the cable into a wellbore and performing at least one operation in the wellbore utilizing the cable.

Methods of using enhanced wellbore electrical cables

An embodiment of a method of deploying a cable into a wellbore penetrating a subterranean formation comprises providing a cable, wherein the cable comprises at least one insulated conductor, at least one armor wire layer surrounding the insulated conductor, a polymeric material disposed in interstitial spaces formed between armor wires forming the at least one armor wire layer, and interstitial spaces formed between the at least one armor wire layer and insulated conductor, the polymeric material forming a continuously bonded layer which separates and encapsulates the armor wires forming the at least one armor wire layer, and whereby the polymeric material is extended to form a smooth polymeric jacket around the at least one armor wire layer, introducing the cable into a wellbore and performing at least one operation in the wellbore utilizing the cable.

Growing community of inventors

Sugar Land, TX, United States of America

Garud Bindiganavale Sridhar