Baker Hughes Corporation

Bj Services Company

Baker Hughes, a Ge Compnay, LLC

Baker Hughes Holdings LLC

Baker Huges Incorporated

Harold Dean Brannon

Allan Ray Rickards

Christopher John Stephenson

D V Satyanarayana Gupta

Scott Gregory Nelson

William Dale Wood

Brian Benedict Beall

Charles Elmer Bell

Brian N Ward

Harold Gene Hudson

Jimie Devon Lemons

Thomas Ray Starks, Ii

Roger R Myers

Randall Edgeman

Doug Walser

Mark Malone

Naima Bestaoui-Spurr

Mark Alan Vorderbruggen

Philip James Rae

Robert M Tjon-Joe-Pin

Richard S Wheeler

Russell L Maharidge

Chandler C Newhall

Jeffrey Carl Dawson

Dan Thomas Mueller

Paul S Carman

Phillip Kaufman

Marshall G Ault

Brent W Naizer

Gino A DiLullo

Tom N Royce

Angel F Gonzalez

Curtis David Huff

John Gottschling

Brian B Beall

James Philip Rae

Allan Roy Rickards

Phillip B Kaufman

Thomas Jason Pisklak

Qi Qu

Leiming Li

Jia Zhou

Hong Sun

Charles David Armstrong

John Gordon Misselbrook

Juan Carlos Flores

Blake C Burnette

Joel Lynn Boles

Timothy W Sampson

William Russell Wood

Sandra L Berry

Joseph Earl Thompson, Sr

Windal Scott Bray

Gino F Di Lullo Arias

Ronnie D Hughes

Robert L Dillenbeck

Jason McCann

Dv Satyanarayana Gupta

Ahmed M Gomaa

Michael Brendt Wilson

Stephen N Zuklic

Stephen Jan Szymczak

William D Holcomb

Alyssa Michelle Volk

Leonard John Kalfayan

Ted B Reed

Alexander Raphael Crabtree

Rajani Satti

Stephen Jan Szymzak

George Tso-Chih Woo

Michael R Farris

David Ross

Khaled Gasmi

Windell Scott Bray

Donald L Purvis

James N Gilliat

Satyanarayana Dv Gupta

D V Gupta

Satyanarayana D Gupta

Anna Jensen

Thomas Ray Starks

Alexander Pirogov

Benjamin Tatum

Chandler Newhall

Curtis D Huff

John C Gottschling

Scott G Nelson

Timothy Sampson

Stephen Zuklic

Juan C Flores

Juan Flores

James Gilliat

Brian Ward

Satyanarayana DV Gupta

DV Saytanarayana Gupta

Ii Thomas Ray Starks

The flow of well treatment fluids may be diverted from a high permeability zone to a low permeability zone within a fracture network within a subterranean formation by use of a mixture comprising a dissolvable diverter and a proppant. At least a portion of the high permeability zone is propped open with the proppant of the mixture and at least a portion of the high permeability zone is blocked with the diverter. A fluid is then pumped into the subterranean formation and into a lower permeability zone of the formation farther from the wellbore. The diverter in the high permeability zones may then be dissolved at in-situ reservoir conditions and hydrocarbons produced from the high permeability propped zones of the fracture network. The mixture has particular applicability in the enhancement of production or hydrocarbons from high permeability zones in a fracture network located near the wellbore.

Method of using diverter and proppant mixture

A method of enhancing carbonate precipitation in a downhole environment comprises introducing into the downhole environment a treatment composition comprising: a carbonate producing agent comprising a microbe, an enzyme, or a combination comprising at least one of the foregoing, and a substrate comprising N-oxyurea, semicarbazide, N,N-dioxyurea, or a combination comprising at least one of the foregoing. An organic feedstock and a geobacter can also be used to treating a wellbore or a subterranean formation. Encapsulated carbonate producing agent such as encapsulated bacterial spores are used to form self-healing cemented structure in a downhole environment.

Biologically mediated precipitation of carbonates for use in oilfield applications

The complexity of a fracture network may be enhanced during a hydraulic fracturing operation by monitoring operational parameters of the fracturing job and altering stress conditions in the well in response to the monitoring of the operational parameters. The operational parameters monitored may include the injection rate of the pumped fluid, the density of the pumped fluid or the bottomhole pressure of the well after the fluid is pumped. The method provides an increase to the stimulated reservoir volume (SRV).

Methods of improving hydraulic fracture network

Fluids produced from a fractured subterranean formation may be monitored by pumping into the well a fracturing fluid which contains a tracer. The method may be used to monitor produced hydrocarbons as well as produced water. The tracer may also be used in a sand control, frac pack or acid fracturing operation. The tracer is a component of a composite where it may be immobilized within a matrix (such as an emulsion) or porous particulate, onto a support or compressed with a binder into a solid particulate. The tracer may be slowly released from the composite.

Method of using controlled release tracers

The flow of a stimulation fluid may be diverted from a high permeability zone to a low permeability portion of a subterranean formation by use of an acid soluble or acid degradable solid particulate and a composite of an acid or an acid generating compound adsorbed onto a water-insoluble adsorbent. Conductive flow of hydrocarbons from an occluded fracture may be resumed by release of the acid from the adsorbent or the acid generating compound.

Use of an acid soluble or degradable solid particulate and an acid liberating or acid generating composite in the stimulation of a subterranean formation

A system and method for stimulating hydrocarbon production from a wellbore that perforates the formation around the wellbore in strategic locations so that fractures can be formed in the formation having specific orientations. The system includes deep penetration perforators that extend past a portion of the formation adjacent the wellbore having locally high internal stresses (a stress cage); and big hole perforators that form perforations with a larger entrance diameter. The perforators form perforations in the formation that are axially consolidated along the wellbore. After perforating, the wellbore is hydraulically fractured with high pressure fluid, which creates fractures in a formation surrounding the wellbore that extend radially outward from the perforations. Creating perforations that are axially consolidated reduces the chances of forming competing fractures in the formation during fracturing.

System and method for perforating a wellbore

A process of managing inventory and delivery logistics of one or more chemical additives used at a well treatment site. The process includes placing one or more bulk containers at the well treatment site to maintain inventory capacity for one or more chemical additives on-site for a well treatment procedure. Monitoring chemical additive inventory within the one or more bulk containers. Making a determination, based on monitored chemical additive inventory, whether additional additive is needed in the one or more bulk containers; generating, based on the determination, initiation of an order for delivery of additional additive. delivering the additional additive in a delivery bulk container to the well treatment site. Also included is an automated additive inventory and delivery logistics control system.

Automated additive inventory and delivery logistics control system and method thereof

A method of distributing proppant in a spatial arrangement throughout a created or enlarged fracture by pumping into a subterranean formation penetrated by a well multiple stages of fracturing fluid wherein a fluid laden with proppant is pumped into the well and a fluid substantially free of proppant is then pumped into the well; the fluid of the fluid laden with proppant and the fluid substantially free of proppant being the same. Vertically extending pillars are created within the formation. Fluid produced from the hydrocarbon-bearing reservoir is then flowed at least partially through channels between the vertically extending pillars.

Method for optimizing conductivity in a hydraulic fracturing operation

A method of hydraulically fracturing a subterranean formation penetrated by a wellbore comprises: providing a diverting fluid comprising a carrier fluid, a first superabsorbent polymer and a second superabsorbent polymer, the second superabsorbent polymer having a shape, or a composition, or a combination thereof different from that of the first superabsorbent polymer; injecting the diverting fluid into the subterranean formation; and injecting a fracturing fluid into the formation after injecting the diverting fluid. A viscosity modifying agent can be present in the diverting fluid. Superabsorbent polymers can also be used to develop a temporary filter cake at the formation face to reduce or eliminate the fluid leakoff out of the wellbore.

Use of superabsorbent polymers for pressure control and diversion applications

A method of obtaining information about at least one variable existing at a target location in an underground well bore and/or surrounding subterranean formation includes delivering a plurality of signal generating devices to the target location(s), emitting at least one detectable signal from the target location and receiving at least one such signal. Information about the variable(s) is derived from at least some of the received signals.

Apparatus and methods for providing information about one or more subterranean variables

A method of fracturing a subterranean formation penetrated by a well comprises: combining an aqueous carrier with a superabsorbent polymer and a borated galactomannan to form a hydraulic fracturing composition; and pumping the hydraulic fracturing composition into the well.

Using borated galactomannan to enhance swelling of superabsorbents for fracturing applications

The production of hydrocarbons from a hydrocarbon bearing formation is enhanced by introduction into the formation a non-aqueous fluid containing a liquefied natural gas.

Method of fracturing with liquefied natural gas

The flow of well treatment fluids may be diverted from a high permeability zone to a low permeability zone within a fracture network within a subterranean formation by use of a divert system comprising dissolvable diverter particulates and proppant. At least a portion of the high permeability zone is propped open with the proppant of the divert system and at least a portion of the high permeability zone is blocked with the diverter particulates. A fluid is then pumped into the subterranean formation and into a lower permeability zone of the formation farther from the wellbore. The diverter particulates in the high permeability zones may then be dissolved at in-situ reservoir conditions and hydrocarbons produced from the high permeability propped zones of the fracture network. The divert system has particular applicability in the enhancement of production or hydrocarbons from high permeability zones in a fracture network located far field from the wellbore.

Method of enhancing fracture complexity using far-field divert systems

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Magnolia, TX, United States of America

Harold Dean Brannon