Schlumberger Technology Corporation

Dowell Schlumberger Incorporated

Dowell, a Division of Schlumberger Technology Corporation

Other

Schlumberger Technology Corporation - Dowell Division

Schlumberger Canada Limited

Sofitech N.v.

Mathew Samuel

Trevor L. Hughes

Gary J. Tustin

Jesse C. Lee

Diankui Fu

Richard Hutchins

Philip Fletcher

Michael Parris

Erik B Nelson

Carlos Abad

Philip F Sullivan

Jesse Lee

Richard Donald Hutchins

J Ernest Brown

Keith Ingram Dismuke

Marie Noelle Dessinges

Roger J Card

Samuel Danican

Vernon G Constien

Yiyan Chen

Gary John Tustin

Lijun Lin

Michael D Parris

Sylvaine Le Roy-Delage

Mathew M Samuel

Golchehreh Salamat

Dominique Guillot

Belgin Baser

Kay E Cawiezel

Roger Keese

Raafat Abbas

Benoit Vidick

Floyd R Sallee

Trevor Munk

Jacques J Orban

Trevor Lloyd Hughes

James E Brooks

Balkrishna Gadiyar

Frank F Chang

Kevin W England

Kenneth H Nimerick

Alejandro Pena

Claude J Vercaemer

Dean M Willberg

Bernhard Lungwitz

Clifford L Aseltine

Sylwia Komocki

Véronique Barlet-Gouedard

Roger Card

Raymond J Jasinski

Palathinkara S Vinod

Brent Busby

Tatiana Pyatina

Juan-Carlos Santamaria

Qi Qu

Ronnie L Thomas

Bruno Goffe

Simon G James

Benedicte Zusatz-Ayache

Ernest Brown

Stanley Bruce McConnell

S Bruce McConnell

Xiaoping Qiu

David B Larson

Jean-Michel Casabonne

L Jack Maberry

William D Norman

Chrystel Cambus

Marc Jouve

Jesse C Lee, Jr

Fr&eacute;d&eacute;ric J Guinot

Jean Pierre Feraud

Golchi Salamat

Juan-Carlos Gonzalez

Muriel Martin-Beurel

Jesse C Lee

Keith Dismuke

Well-cementing compositions for use in high-pressure, high-temperature (HPHT) wells usually contain a complex array of cement additives, including retarders, dispersants and fluid-loss additives. Under these extreme conditions additive degradation, reactions between additives, reactions between additives and the cement, or combinations thereof may occur&#x2014;causing slurry gelation, premature setting or both. Incorporation of organoamine compounds in the cement compositions may help prevent or reduce the severity of slurry gelation, setting-time reduction or both.

Compositions and methods for well completions

A self-adaptive cement system includes cement, water and at least one additive that reacts or/and expands in contact with oil and gas. Several chemical products have been identified including rubber alkylstyrene, polynorbornene, resins such precrosslinked substituted vinyl acrylate copolymers and diatomaceous earth. These additives have the effect of making the cement self-healing in the event of physical failure or damage such as micro-annuli. The self healing property is produced by the contact with subterranean hydrocarbon fluids, the potential repair mechanism is thus activated if and when needed in case of start of loss of zonal isolation. In another embodiment, the expansion is deliberately induced by pumping a hydrocarbon fluid in the vicinity of the set cement.

Self adaptive cement systems

A self-healing cement system includes cement, water and at least one additive that swells in contact with water from reservoir or from formation in the case of a structural failure in the set cement to provide a physical barrier in the zone of failure. Examples of such material include particles of super-absorbent polymer. These additives have the effect of making the cement self-healing in the event of physical failure or damage such as micro-annuli. The self healing property is produced by the contact of the water itself, the potential repair mechanism is thus activated if and when needed in case of start of loss of zonal isolation. Several super-absorbent polymers have been identified such as polyacrylamide, modified crosslinked poly(meth)acrylate and non-soluble acrylic polymers.

A method of heterogeneous proppant placement in a subterranean fracture is disclosed. The method comprises injecting well treatment fluid including proppant and a channelant through a wellbore into the fracture, heterogeneously placing the proppant in the fracture in a plurality of proppant clusters or islands spaced apart by the channelant, and removing the channelant filler material to form open channels around the pillars for fluid flow from the formation through the fracture toward the wellbore. The proppant and channelant can be segregated within the well treatment fluid, or segregated during placement in the fracture. The channelant can be dissolvable particles, initially acting as a filler material during placement of the proppant, and later dissolving to leave the flow channels between the proppant pillars. The well treatment fluid can include fibers to provide reinforcement and consolidation of the proppant and/or to inhibit settling of the proppant in the treatment fluid.

Methods of limiting leak off and damage in hydraulic fractures

Methods of treating depression, binge eating disorder, narcolepsy, excessive daytime sleepiness, substance use disorders, and Prader Willi syndrome, disorders characterized at least in part by hypocortisolemia and decreased activity of the hypothalamic-pituitary-adrenal (HPA) axis, and disorders related to disturbances in circadian rhythm, comprising the step of administering an effective amount of a histamine type 3 (H) receptor antagonist, such as betahistine or its pharmaceutically acceptable salts, or its metabolites to an individual.

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Methods of treating depression, binge eating disorder, narcolepsy, excessive daytime sleepiness, substance use disorders, and Prader Willi syndrome, disorders characterized at least in part by hypocortisolemia and decreased activity of the hypothalamic-pituitary-adrenal (HPA) axis, and disorders related to disturbances in circadian rhythm, comprising the step of administering an effective amount of a histamine type 3 (Bb) receptor antagonist, such as betahistine or its pharmaceutically acceptable salts, or its metabolites to an individual.

Methods for treating a formation penetrated by a wellbore which improves fluid loss control during treatment. In some aspects, the treatments include preparing an aqueous fluid including one or more water inert polymers and an optional viscosifier, injecting the aqueous fluid into the wellbore at a pressure equal to or greater than the formation's fracture initiation pressure, and thereafter injecting into the wellbore a proppant laden fluid at a pressure equal to or greater than the formation's fracture initiation pressure. The water inert polymer may be a polymer such as an emulsion polymer or a latex polymer. Some methods of the invention use a fluid which may have a normalized leak off coefficient (C/sqrt(K)) equal to or less than about 0.0022, 0.0014, or 0.0010. A conventional fluid loss additive may or may not be used in conjunction with the treatment fluid and/or the proppant laden fluid. The water inert polymer may or may not substantially enter formation pores. In another aspect, methods for reducing matrix damage to a formation during a treatment operation include preparing an aqueous treatment fluid formed of at least one water inert polymer, and injecting the fluid at a pressure equal or greater than the formation's fracture initiation pressure.

A method of preventing or treating lost circulation during the drilling of a well comprises the addition, at concentration ranging between about 0.5 and 6 pounds per barrel, of water-dispersible fibers having a length between about 10 and 25 mm, for instance glass or polymer fibers, to a pumped aqueous base-fluid including solid particles having an equivalent diameter of less than 300 &#x3bc;m. The base-fluid with the solid particles can be the drilling fluid or a small-volume pill specially pumped for curing lost circulation.

Well treating method to prevent or cure lost-circulation

A sand consolidation system and a method for use of the system is provided. The consolidation system includes an emulsion having an oil phase and an aqueous phase, wherein the emulsion contains a source of insoluble silica particles and a source of calcium hydroxide, wherein the calcium hydroxide particles are present in the oil phase, and the insoluble silica particles are contained in the aqueous phase. Both types of particles must have average particle sizes which will fit into the pores of the formations.

Emulsion system for sand consolidation

A composition and method for improving the fluid efficiency of many oilfield treatments is given. The composition is a solid additive, in a viscosified fluid, in a size range small enough that it enters formation pores; it optionally bridges there to form an internal filter cake, and then decomposes to provide a breaker for the viscosifying system for the fluid. Examples of suitable additives include waxes, polyesters, polycarbonates, polyacetals, polymelamines, polyvinyl chlorides, and polyvinyl acetates. Degradation of the additive may be accelerated or delayed.

Internal breaker for oilfield treatments

An adaptive cementitious composite composition, comprising: a coarse particulate material such as sand or proppant; a series of other particulate or fibrous materials; and a carrier fluid; the sand and other particulate materials being present as a series of coarse, medium and fine particle sizes in ratios selected to provide an optimized packing volume fraction; wherein the sand or proppant is coated with a resin and at least one of the other particulate or fibrous materials is a material that can be modified when placed at a downhole location.

Adaptive cementitious composites for well completions

A treatment fluid that can be used for treating a subterranean formation penetrated by a wellbore is prepared from a primary treatment fluid component and an emulsion component mixed with the primary treatment fluid component. The emulsion component has an oil phase and an aqueous phase. The emulsion component comprising a source of insoluble silica particles and a source of calcium hydroxide, wherein the source of calcium hydroxide is present in the oil phase, and the source of insoluble silica particles are contained in the aqueous phase. The method is carried out by contacting at least a portion of the formation with the treatment fluid.

Control of fines migration in well treatments

In a process to design high temperature cement sluries, the temperature stable phases (anorthite, wairakite) are selected; aluminum modifiers and silica oxides are added to the dry cement so that the elemental composition of the blend corresponds to the phases selected; the control of the particle size distribution and the relative amount of those minerals allow their addition at high concentration while leaving the slurry easily mixable and pumpable; and the kinetics of the targeted phases formation is then controlled by adjusting the crystallinity and the particles sizes of the different solids.

Cement compositions for high temperature applications

Growing community of inventors

Broken Arrow, OK, United States of America

Erik B Nelson