Clearwater International LLC

Weatherford Technology Holdings, LLC

Halliburton Energy Services, Inc.

Other

Lubrizol Oilfield Solutions, Inc.

The Lubrizol Corporation

Frank Zamora, Jr

Sarkis R Kakadjian

Tina Garza

Olusegun Matthew Falana

Larry W Gatlin

Barry B Ekstrand

Thomas P Wilson, Jr

Don M Hannegan

Russell M Fitzgerald

Karen Luke

Michael Brian Grayson

David Pavel

Wayne Mueller

Jim Venditto

Erin Fitzgerald

Todd Douglas Cooper

Sarkis Kakadjian Ranka

Timothy P Dunn

Brent Lukocs

B Raghava Reddy

Ashok K Santra

Ronnie Glen Morgan

Ian D Robb

Ronald Van Petegem

Ronney R Koch

Shaun T Mesher

Cesar Pena

Edward C Marshall

Marilyn J Bramblett

Said Boutalbi

Mark R Savery

Raynard Veldman

Joe M Sandy

Ray R Veldman

Joseph E Thompson

Jose L Garza

Mario Hernandez

Laura De Santis Marquez

Jean-Luis Salager

Ron Powell

Giddo Antonio Ocana Gomez

Marshall C Edward

Ali D Allison

Michael DiBiasio

Emilia U Ugwu

Zoraida Vazquez

Gabriel Monreal

Sarkis Ranka Kakadjian

Bairreddy Raghava Reddy

Joseph Thompson

Roy T Perez

Sarkia R Kakadjian

Emilia U Ugwa

Zoraida Vasquez

A method of cementing a tubular string in a wellbore includes: deploying the tubular string into the wellbore; pumping cement slurry into the tubular string; launching a cementing plug after pumping the cement slurry; propelling the cementing plug through the tubular string, thereby pumping the cement slurry through the tubular string and into an annulus formed between the tubular string and the wellbore; and controlling flow of fluid displaced from the wellbore by the cement slurry to control pressure of the annulus.

Managed pressure cementing

Gel compositions include a high molecular weight water-soluble acrylamide polymer, a crosslinking system capable of crosslinking the polymer, a crosslink delay system and an aqueous solvent. The gel compositions are prepared at the surface and injected into a zone of a formation assessable by a wellbore to form a continuous single-phase gel. The gel compositions may be tailored to a specific formation by predetermining gelation rate, gel strength and/or gel stability to form gels having predetermined properties suitable for the zone.

Enhancing delaying in situ gelation of water shutoff systems

Methods for reducing settling rates of proppants in fracturing fluids include injecting sufficient gas into the fluid to form bubbles that reduce proppant settling rates. Compositions including proppants made buoyant with gas bubbles.

Methods using low concentrations of gas bubbles to hinder proppant settling

A drilling fluid, spacer fluid and cementing compositions for use in subterranean wells are disclosed along with methods for making using same, where the compositions include a weighting system having an effective amount of a metal silicon alloy, mixtures of metal silicon alloys, or mixtures of metal silicon alloys and conventional weighting agents, to produce compositions having a desired high density, while retaining other fluid properties such as pumpability, gas tight sealing, low tendency to segregate, and reduced high temperature cement strength retrogression.

Weight materials for use in cement, spacer and drilling fluids

Apparatus and compositions for reducing the viscosity of a gelled fluid is provided. In one embodiment, a viscosity reducing microbe is disposed in a capsule and added to the gelled fluid. The gelled fluid may include a thickening agent adapted to increase its viscosity. Upon release from the capsule, the microbe begins to digest the thickening agent in the gelled fluid and/or releases enzymes that that breakdown the thickening agent.

Apparatus, compositions, and methods of breaking fracturing fluids

Methods and systems are disclosed for well completion and/or production, where an aggregating, agglomerating or conglomerating composition is injected into a producible formation, zone or interval thereof to alter an aggregation or zeta potential of formation surfaces and particulate to increase a maximum sand free production rate.

Method and system using zeta potential altering compositions as aggregating reagents for sand control

Methods are disclosed for improved sand control, fines control, load recovery and well productivity, where the compositions comprise reaction products of an amine and a phosphate-containing compound.

Methods for increase gas production and load recovery

Epoxy-based zonal isolation compositions are capable of being adjusted by varying the epoxy-based compositions for isolating zones in borehole of oil and gas wells under high-temperature, mid-temperature and low-temperature conditions.

Resin sealant for zonal isolation and methods for making and using same

Foamable epoxy-based zonal isolation sealing compositions include epoxy resin and a blowing agent and methods for isolating zones in borehole of oil and gas wells using the compositions, where the foam nature of the cured seals provide sufficient compressibility and resiliency to be used with expandable tubing without substantial loss in sealant integrity and in squeeze operations.

Foam resin sealant for zonal isolation and methods for making and using same

Defoamer compositions are disclosed and methods for making and using same, where the defoamer has universal applicability at low concentrations. The defoamer compositions include between 40 vol. % and about 80 vol. % distilled water (other waters may be used instead), 10 vol. % and about 30 vol. % of silicon anti-foam agent and between about 10 vol. % and about 30 vol. % of active silicon anti-foam agent. The defoamer compositions are used in amount of less than or equal to 200 ppm in all foamed downhole fluid systems.

Defoamer formulation and methods for making and using same

Breaking compositions are disclosed for controlled breaking of borate cross-linked fracturing fluids, and to method for making and using same, where the composition includes an oxidative component and an ester component.

Compositions and method for breaking hydraulic fracturing fluids

Complementary surfactant systems and downhole fluids made using the systems are disclosed along with methods for making and using same, where the surfactant systems include from 0 wt. % to 100 wt. % of a first surfactant subsystem, from 100 wt. % to 0 wt. % of a second surfactant subsystem, and from 0 wt. % to 100 wt. % of a solvent subsystem based on the wt. % of the surfactant subsystems, where the system is tailored to foam the fluid including the analyzed crude and/or condensate.

Complementary surfactant compositions and methods for making and using same

New fluids are disclosed for use in servicing subterranean formations containing oil and gas. In particular, an improved chemical gelling additive for hydrocarbon based fracturing fluids is disclosed having reduce, negligible or no volatile phosphorus at temperatures below about 250&#xb0; C.

Methods for using non-volatile phosphorus hydrocarbon gelling agents

A method for treating solid materials is disclosed, where the treating compositions coats surfaces or portions of surfaces of the solid materials changing an aggregation or agglomeration propensity of the materials. Treating composition and treated solid materials are also disclosed. The methods and treated materials are ideally suited for oil field applications.

Aggregating compositions, modified particulate metal-oxides, modified formation surfaces, and methods for making and using same

Growing community of inventors

San Antonio, TX, United States of America

Frank Zamora, Jr