Schlumberger Technology Corporation

Westerngeco L.l.p.

Schlumberger Technology Corportion

Schlumberger Canada Limited

Prad Research and Development Nv

Sofitech N.v.

Mathew Samuel

Trevor L. Hughes

Gary J. Tustin

Jesse C. Lee

Diankui Fu

Richard Hutchins

Philip Fletcher

Michael Parris

Gary John Tustin

Timothy Gareth John Jones

Trevor Lloyd Hughes

Philip F Sullivan

Bruno Drochon

Gregory Kubala

Robert Seth Hartshorne

Valerie Lafitte

Yenny Christanti

Timothy G J Jones

Jian Zhou

Shiyi Wang

Yiyan Chen

Marie Noelle Dessinges

Carlos Abad

Erik B Nelson

Lijun Lin

Timothy Gareth Jones

Paul R Howard

Ahmed Hammami

Slaheddine Kefi

Steven Antony Gahlings

Shawn David Taylor

Matthew Miller

Stephen N Davies

Alexander Martin Wilson

Khooi Tan

Christelle Vatry

Timothy Gareth J Jones

Jesse Ching-Wang Lee

Julian J Pop

Kai Hsu

Syed Afaq Ali

Li Jiang

Christopher Del Campo

Nathan Scott Lawrence

Jesse Lee

Bruno Lecerf

Peter S Hegeman

Balkrishna Gadiyar

Richard Donald Hutchins

John W Still

Anthony R H Goodwin

Michael D Parris

Ricardo Vasques

Mohan K R Panga

Christopher Alan Sawdon

Mathew M Samuel

Keith Ingram Dismuke

Andrew Meredith

Kevin W England

Anthony Robert Holmes Goodwin

Raymond V Nold, Iii

Raymond J Tibbles

Bernhard Lungwitz

Ashley C Kishino

Robert Hughes Jones

Alexander Nadeev

Samuel Danican

Don Williamson

John Allan Nighswander

Hemant K Ladva

Andrey Vladimirovich Fedorov

Keith James Massie

Kay Robinson

Clive E Hall

Vadim Kamilievich Khlestkin

Ernest Brown

Michaela Nagl

Olesya Levanyuk

Thomas Cochet

Anders Nesheim

Silke Olthoff

Tatiana Zolnikova

Tim Jones

Juan-Carlos Gonzalez

Maria Violante De Paz Banez

Hemant Kuman Jethalal Ladva

James Francis Westwood

Golchi Salamat

Miller Matthew

Bruno Druchon

Sarah Pelham

Clive Hall

Raymond Tibbles

Jesse C Lee

An aqueous fluid, possibly a wellbore fracturing fluid, comprises an aqueous solution or dispersion of a first polymer, which may be polysaccharide, as a thickener and a cross linking agent to enhance the viscosity of the fluid by crosslinking the first polymer, wherein the crosslinking agent is a second polymer comprising at least one polymer chain with phenyl boronate groups distributed along the polymer chain and the phenyl boronic acid groups have nitrogen attached to the phenyl group at a position which is meta relative to the boronate group.

Thickening of fluids

Pumpable process-fluid compositions and methods for establishing hydraulic isolation in cemented subterranean wells comprise more than 1 wt % polyacrylamide and a non-metallic crosslinker. Upon entering voids and cracks in or adjacent to a cement sheath, and contacting the set-cement surfaces, the compositions react and form a seal that prevents further leakage.

Methods for servicing subterranean wells

A marine seismic streamer comprising a solid, hydrophobic core member that is encased in a hydrophobic streamer skin/casing. The hydrophobic streamer skin may be extruded onto and/or heat welded to the hydrophobic core member. The hydrophobic streamer skin/casing may comprise a thermoplastic polyurethane that includes fluorine and/or silicon moieties, silicon, polydimethylsiloxane or the like. The hydrophobic streamer skin/casing may reduce the drag of the streamer and may provide anti-biofouling properties to the streamer. A hydrophobic paint, coating or polymer may in some instances be disposed on top of the hydrophobic streamer skin/casing.

Solid marine seismic streamers

An electrochemical sensor measuring concentration of an analyte in a test fluid at 50&#xb0; C. or above by voltammetry uses electrodes in contact with an electrolyte containing the analyte and a redox-active species electrochemically convertible between reduced and oxidised forms. At least one form of the redox active species is present within surfactant micelles. The surfactant micelles enhance thermal stability of the redox active species and may also solubilise a species with poor water solubility, such as t-butylferrocene. A downhole tool incorporating such a sensor comprises a barrier, permeable to the analyte, to separate the electrolyte from subterranean reservoir fluid, so that the sensor directly measures analyte which has passed through the barrier and thereby indirectly measures analyte in the test fluid.

Electrochemical sensor system

This invention relates to compositions and methods for treating subterranean formations, in particular, oilfield stimulation compositions and methods using water-in-water polymer emulsions to uniformly dissolve a rheologically active polymer, such as a thickener or friction reducer, in the treatment fluid. The emulsions have a low viscosity and are easily pumped for mixing into a treatment fluid, where upon dilution with an aqueous medium, the polymer is easily hydrated without forming fish-eyes. The partitioning agent in the water-in-water emulsion does not generally affect the rheology of the treatment fluid. The invention also relates to further processing of the emulsion by wet grinding, high shear mixing and/or heating to enhance the hydration rate in the preparation of the well treatment fluid.

Polymer delivery in well treatment applications

A process of making observations of a subterranean reservoir penetrated by a wellbore uses distinguishable sets of tracer particles and comprises steps of: The tracer substances are sufficiently distinguishable from each other to enable a tracer substance detected in the produced fluid to identify the set of tracer particles from which it has come and hence identify the location from which it has come. The process may be used in conjunction with hydraulic fracturing, placing sets of particles at different locations within a fracture and/or in different fractures extending from a single wellbore.

Use of encapsulated tracers

An embodiment of the disclosed invention includes a method for attenuating noise during acquisition of marine seismic date. The method includes placing a seismic streamer in a body of water. The seismic streamer includes a streamer body having a length and a channel, a seismic sensor disposed within the channel, and a gel disposed within the channel. The gel has a complex viscosity of at least 50 Pascals and includes a concentration of a polymer between the range of about 5% and about 25% by weight. The method also includes placing a source in the body of water. The seismic streamer and the source are towed through the body of water and the source is fired while being towed through the body of water. Data is collected from the seismic streamer as it is towed through the body of water.

Seismic acquisition using solid streamers

A reservoir sampling apparatus comprising at least one probe adapted to provide a fluid flow path between a formation and the inner of the apparatus with a heating projector adapted to project heat into the formation surrounding the probe and a controller to maintain the temperature in the formation below a threshold value.

Downhole sampling

The recovery of oil from a reservoir is assisted by injecting a diluent into the reservoir formation to reduce the viscosity of the crude oil. This diluent is a mixture of a material which is an asphaltene precipitant, especially supercritical carbon dioxide, and a more polar material which comprises at least one aliphatic compound which includes at least one of a cycloaliphatic ring, an olefinic unsaturation, an ester or ether group. The inclusion of such an aliphatic compound which is more polar than the asphaltene precipitant reduces asphaltene precipitation and can enhance the efficiency of oil recovery when the precipitant is by supercritical carbon dioxide.

Solvent assisted oil recovery

The present invention provides aqueous viscoelastic compositions comprising a cleavable anionic surfactant which is a sulphonate and possibly also an electrolyte. The cleavable surfactants useful in the present invention comprise a chemical bond, which is capable of being broken under appropriate conditions, to produce oil soluble and water soluble products typically having no interfacial properties and surface activity compared with the original surfactant molecule. Further, the rheological properties of the aqueous viscoelastic composition are usually altered upon cleavage of the cleavable surfactant generally resulting in the elimination of the viscosifying, viscoelastic and surfactant properties of the composition. Aqueous viscoelastic compositions in accordance with the present invention are suitable for use in oil-field applications, particularly for hydraulic fracturing of subterranean formations. Thus, the present invention also relates to a wellbore service fluid and a method of fracturing a subterranean formation.

Viscoelastic compositions

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

The magnitude of asphaltic precipitation when injecting a viscosity reducing diluent into a reservoir formation, notably to assist oil recovery therefrom, is forecast by (i) determining a relationship between asphaltic precipitation and a solubility parameter for the diluted oil, and then (ii) utilizing that relationship to forecast the magnitude of asphaltic precipitation when injecting a predetermined viscosity reducing diluent into the formation. Making this forecast may be followed by injecting a viscosity reducing diluent into the formation to assist oil recovery. The diluent may in particular be supercritical carbon dioxide or other asphaltene precipitant mixed with a more polar material in proportions designed by forecasting asphaltic precipitation by candidate materials in possible proportions.

Forecasting asphaltic precipitation

In an arrangement for monitoring of flow within a hydrocarbon well or reservoir by means of one or more tracers which are placed at subterranean locations such that they may be present in flow produced from the well, the analysis of the flow produced from the well is carried out using an electrochemical method, preferably voltammetry, to detect tracer chosen to undergo a detectable electrochemical reaction. The tracer may be provided as nanoparticles in the well fluid.

Detection of tracers used in hydrocarbon wells

Methods and apparatus that change the mobility of formation fluids using thermal and non-thermal stimulation including, an example apparatus to simultaneously provide thermal and non-thermal stimulation to change a mobility of a fluid in a subsurface formation includes one or more containers to hold one or more reactants. Additionally, the example apparatus includes a reactor to initiate a chemical reaction with at least one of the reactants. Further, the example apparatus includes an injector to inject a product of the chemical reaction into a formation. The product of the chemical reaction includes heat and a gaseous diluent to change a mobility of a fluid in a subsurface formation.

Methods and apparatus to change the mobility of formation fluids using thermal and non-thermal stimulation

A thickened aqueous composition is delivered to a subterranean location accessible via a wellbore by steps of i. providing a biphasic aqueous mixture comprising two aqueous solutions which, at surface temperature and pressure, are able to co-exist as separate aqueous phases in contact with each other, ii. pumping said biphasic aqueous system down the wellbore to the subterranean location, and iii. converting the biphasic mixture below ground so that its phases combine into a single aqueous phase which is more viscous than the biphasic mixture. The two phases of the aqueous biphasic mixture contain dissolved solutes which segregate between the two phases such that at least one first solute is present at a greater concentration in the first aqueous phase than in the second aqueous phase while at least one second solute is present at a greater concentration in the second aqueous phase than in the first aqueous phase. The solute in the first phase may be a thickening polymer or other thickening material such as viscoelastic surfactant. The solute in the second phase may be a different polymer, surfactant or salt. Conversion to a single phase may be carried out in various ways including dilution, change in pH, change in salinity, increase in temperature and adsorption of one solute onto formation rock.

Provision of viscous compositions below ground

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Sawston, United Kingdom

Gary John Tustin