Schlumberger Technology Corporation

Other

Schlumberger Canada Limited

Services Petroliers Schlumberger

Sofitech N.v.

Diankui Fu

Frank F Chang

Marieliz Garcia-Lopez De Victoria

Zhijun Xiao

Bruno Lecerf

Wayne W Frenier

Mathew M Samuel

Slaheddine Kefi

Bernhard Lungwitz

Jian Zhou

Roger Card

Fatma Daou

Soo Hui Goh

Olga Alexandrovna Minikh

Alexander F Zazovsky

Gary John Tustin

J Ernest Brown

Christopher Del Campo

Mehmet Parlar

Murtaza Ziauddin

Keith Ingram Dismuke

Michael J Fuller

Raymond J Tibbles

Golchehreh Salamat

Bentley J Palmer

Palathinkara S Vinod

Bipin Jain

Andrey Vladimirovich Fedorov

Mohan Panga

Stephen Nigel Davies

Kong Teng Ling

Jonathan Mark Davison

Olesya Levanyuk

Antje M Wierenga

Vladimir Sergeevich Bugrin

Jese C Lee

Helene Bulte

Yiyan Chen

Trevor Lloyd Hughes

Erik B Nelson

Jesse Lee

Richard Donald Hutchins

John W Still

Michael D Parris

Mohan K R Panga

Alejandro Pena

Gregory Kubala

Matthew J Miller

Alexander Nadeev

Yenny Christanti

Sylvie Daniel

Valerie Lafitte

Stephen Davies

Eric Clum

Dmitry Ivanovich Potapenko

Elena Nikolaevna Tarasova

Anastasia Evgenyevna Shalagina

Bernhard Rudolf Lungwitz

Shiyi Wang

Kreso Kurt Butula

Pia-Angela Francini

Elizabeth W A Morris

Philip Fletcher

Peiwen Xia

Vadim Kamilievich Khlestkin

Elizabeth W Morris

Edgar Volpert

Vadim Kamil'evich Khlestkin

Gustavo Cavazzoli

Daniel Kalinin

Daniel Thomas Melice

Tatiana Zolnikova

Larisa Kochmar

Golchi Salamat

Andrey Federov

Steve Russell

Ann Wattana

Juan Gabriel Blanco

Jesse C Lee

Mark Davison

Mathew Samuel

Aqueous fluids containing hydrophobic particles are effective media for cleaning water-base drilling fluids and drilling fluid solids from the interior surface of a casing string. Hydrophobic fibers may be added to a drilling fluid, a spacer fluid, a sacrificial spacer fluid, a chemical wash, or combinations thereof. The disclosed fluids may be employed during primary cementing operations where it is not possible to use a bottom plug.

Methods and compositions for cleaning interior of a casing string

Treatment fluids containing salts, surfactants, mutual solvents and fibers may be used to remove wellbore filter cakes that have been deposited by drilling fluids. The drilling fluids may be water-base, oil-base, synthetic-base or emulsions. The fibers may be selected from polylactic acid, celluloses, polyesters, polyvinyl alcohols and polyethylene terephthalates. A combination of straight and crimped fibers is present in the treatment fluid.

Compositions and methods for servicing subterranean wells

A method for treating a subterranean formation containing shale includes introducing to the subterranean formation a shale stabilizer, a surfactant, and a triggering agent simultaneously with or prior to introducing an alkali silicate to the subterranean formation, and allowing the alkali silicate and triggering agent to react to form a reaction product. Methods include coating the surface of at least a portion of the shale with the reaction product.

Shale stabilization fluids

Aqueous fluids containing hydrophobic particles are effective media for cleaning water-base drilling fluids and drilling fluid solids from the interior surface of a casing string. Hydrophobic fibers may be added to a drilling fluid, a spacer fluid, a chemical wash, or combinations thereof. The disclosed fluids may be employed during primary cementing operations where it is not possible to use a bottom plug.

Fibers are employed to improve proppant transport in low viscosity treatment fluids. The treatment fluids employ fibers to inhibit proppant settling without an unacceptable bridging tendency. The fibers are preferably crimped staple fibers having 1-10 crimps/cm of fiber length, a crimp angle between 45 and 160 degrees and a mean diameter between 8 and 40 microns.

Treatment fluid

Fluids containing surfactants and hydrophobic particles are effective media for cleaning non-aqueous fluids (NAFs) out of a subterranean wellbore. The fibers and surfactants are preferably added to a drilling fluid, a spacer fluid, a chemical wash, a cement slurry or combinations thereof. NAFs, such as an oil-base mud or a water-in-oil emulsion mud, are attracted to the fibers as the treatment fluid circulates in the wellbore.

Adding shapeable particles to drilling fluids may be useful for curing lost circulation. When the shapeable particles are pumped downhole through the drillpipe and the drillbit, they may deform when exposed to shear as they pass through the drillbit nozzles. While circulating back toward the surface they may relax at least partially and assume the shape of cracks or voids they encounter along the formation wall, thereby stopping losses.

Compositons and methods for curing lost circulation

A method of treating a geologic formation including injecting into a wellbore a high viscosity composition which comprises a base fluid wherein the base fluid has an initial viscosity of 100 cP or greater and which exhibits a decrease in viscosity upon exposure to a viscosity reducing agent, and fibers wherein the fibers exhibit flocking upon a decrease in the viscosity of the base fluid, and injecting into the wellbore a viscosity reducing agent wherein the viscosity reducing agent is injected into the wellbore with or separately from the high viscosity composition is provided.

Method to enhance fiber bridging

A method of treating a subterranean formation penetrated by a wellbore comprising injecting electrically conductive or electromagnetic fibers into the subterranean formation during hydraulic fracturing is provided. Suitable metallic materials, organic polymers, and organic polymers coated with or containing conductive or electromagnetic materials are described. The treatment is followed by measurement of resistivity and/or electromagnetic properties, optionally by a crosswell technique.

Method for treating and measuring subterranean formations

Methods for controlling fluid flow through one or more pathways in one or more rock formations penetrated by a borehole in a subterranean well, comprise injecting into or adjacent to the formation a treatment fluid comprising at least one polysaccharide polymer; at least one crosslinker; and fibers, or a mixture of fibers and particles. The fluids are pumped into the well through a tubular body that comprises at least one flow restriction. Shearing of the treatment fluid as it passes through the flow restriction causes the viscosity to decrease, allowing the fibers to form masses that migrate to formation-rock openings such as pores, cracks, fissures and vugs. As a result, the fibrous masses are useful for curing lost circulation, providing fluid-loss control and as diverting agents.

Methods for servicing subterranean wells

The current application discloses compositions and methods for reducing fluid loss during subterranean operations. COactivated swellable elastomers can be used in subterranean operations to reduce fluid loss. In particular, the current application discloses compositions and methods for reducing lost circulation during drilling and drilling related subterranean operations.

Compositions and methods for reducing fluid loss

The current application discloses compositions and methods for treating a subterranean formation. CO2 swellable elastomers can be used in a treatment fluid to at least partially block a high permeability region, therefore improving the performance of an operation such as matrix stimulation, acidizing, and acid fracturing.

Swellable elastomer and its use in acidizing or matrix stimulation

A method for treating a subterranean formation penetrated by a wellbore is provided. The method includes providing a treatment fluid containing a viscoelastic surfactant having at least one degradable linkage, a hydrolysable material, and a pH control material, and injecting the treatment fluid into a subterranean formation. The pH control material may have a pH equal or greater than about 9 and may include a strongly alkaline material and an oxidizing agent.

Method for treating subterranean formation with degradable material

In a method of treating a sandstone-containing formation penetrated by a wellbore, a treatment fluid comprising an aqueous fluid containing a Bronsted acid, a hydrogen fluoride source and an organic acid or salt thereof that is substantially soluble in the aqueous fluid is formed. The treatment fluid contains less than about 2% of fluoride (F) by weight of the fluid and from 2% or less of sodium (Na) by weight of the fluid. The treatment fluid is introduced into the formation through the wellbore as a single-stage without introducing an acid-containing fluid preflush into the formation prior to introducing the treatment fluid.

Method for single-stage treatment of siliceous subterranean formations

Growing community of inventors

Missouri City, TX, United States of America

Diankui Fu