Schlumberger Technology Corporation

3m Innovative Properties Company

Schlumberger Canada Limited

Services Petroliers Schlumberger

Schlumberger Holdings Limited

Prad Research and Development Limited

Dean Michael Willberg

Ivan Vitalievich Kosarev

Anatoly Vladimirovich Medvedev

J Ernest Brown

Timothy M Lesko

Christopher N Fredd

Dmitriy Ivanovich Potapenko

Marina Nikolaevna Bulova

Roberto Suarez-Rivera

Alexander Alexandrovich Burukhin

Maxim Andreevich Chertov

James Ernest Brown

Jonathan Abbott

Sidney J Green

Alejandro Pena

Oleg Olegovich Medvedev

Matthew Miller

Philip F Sullivan

Garud Bindiganavale Sridhar

Douglas Pipchuk

Alhad Phatak

Fedor Nikolaevich Litvinets

Konstantin Mikhailovich Lyapunov

Andrey Vladimirovich Bogdan

Alexander Vuacheslavovich Mikhaylov

Marina Bulova

Carlos Abad

Curtis L Boney

Andrew Emil Pomerantz

Michael D Crandall

James G Carlson

Yong K Wu

Marc J Thiercelin

Jerald J Hinkel

Ignatius A Kadoma

Sergey Makarychev-Mikhailov

Matthew J Miller

John Lassek

Valerie Gisele Helene Lafitte

Philippe Enkababian

Ann M W Hoefer

Alexey Vostrukhov

Dzanis Menshikau

Thorarinn Kristjansson

Ashley Bernard Johnson

Trevor Lloyd Hughes

Bruno Lecerf

Simon James

John W Still

Iain Michael Cooper

James D Carlson

Evgeny Borisovich Barmatov

Jill F Geddes

Chad Kraemer

Timothy L Pope

Jean Desroches

Markus Pagels

Zinaida Usova

Don Conkle

Anatoly Medvedev

Pavel Evgenievich Spesivtsev

Vadim Kamilievich Khlestkin

Bruce Alexander Mackay

Leland Ramsey

Ryan Donald Williams

Timothy Michael Lesko

Trevor McLeod

John J Valenza, Ii

Denis Olegovich Menshikov

Nicholas Drenzek

Sergey Mikhailovich Makarychev-mikhailov

Sindey J Green

Kseniya Evgenievna Eliseeva

Theodore Lafferty

Sergey Mikhailovich Makarychev-Mikhaliov

Katharine Moncada

Kseniya Nosova

Sergey Sokolov

Dina Andreevna Goloshchapova

Flora Marques

Hendrik Grotheer

Pavel Spesivtsev

Philip Sullivan

Trevor Mcleod

Ashley Johnson

Theodore B Lafferty

Composite cement compositions and pumpable slurries for cementing well or at least one zone of the wells are provided and comprise cementitious material that forms calcium silicate hydrates upon exposure to water, inert filler material, nano-sized calcium carbonate particles, and water, wherein the cementitious material has a mean particle size of at least about 0.5 micron and no more than about 20 microns, the inert filler material has particle sizes of at least about 25 microns and no more than about 2 millimeters (mm), and the compositions and slurries have densities of at least about 9.5 pounds per gallon (ppg) and no more than about 12.5 ppg and solid volume fractions of at least about 50%. Methods of cementing the wells or the at least one zone of the wells are also provided and comprise pumping the compositions and slurries into the well and allowing the compositions and slurries to set or cure to form or produce lightweight composite cements having compressive strengths of greater than 400 pounds per square inch.

Lightweight composite cement compositions and methods of cementing wells with said compositions

Composite cement compositions and slurries for treating a well following a water-based wellbore operation are provided and comprise cement comprising at least one of cement particles and cementitious material, water, and water swellable particulates that are embedded in the cement, derived from an elastomeric material, and present at a concentration of at least about 2% by weight of the cement but no more than about 30% by weight of the cement. Methods for treating a well drilled with a water-based drilling mud are provided and comprise pumping the composite cement compositions and slurries into the well and treating the well by allowing the composite cement compositions and slurries to set or cure after being pumped into the well.

Composite cement compositions and methods of cementing and/or treating wells drilled with water-based drilling fluids

Systems and methods presented herein relate to processing produced oilfield brine by deconstructing it into two useful components: (1) desalinated water and (2) a suspension of solid-state salt (e.g., crystallized salt) slurried in a salt-saturated brine, which may be formulated and injected into hydrocarbon-producing formations above hydraulic fracturing pressure to intentionally create regions of localized high stress within the respective formations. In addition, systems and methods presented herein relate to processing oilfield brine received from hydrocarbon-producing wells by: (1) coupling high-pressure desalination technologies with saltwater disposal (SWD) operations, (2) active management of SWD water composition at the rock face through dual stream (e.g., split-stream) injection, and/or (3) coupled SWD injection, flow assurance, and stimulation to minimize SWD formation damage and injection pressures.

Systems and methods for processing produced oilfield brine

Methods for initiating chemical reactions in a wellbore include delivering one or more reactive components via a carrier fluid to the wellbore. The one or more reactive components delivered to the wellbore are configured to enable one or more chemical reactions to occur. The one or more chemical reactions are carried out until a threshold volume of the one or more reactive components is delivered to the wellbore.

Systems and methods of initiating energetic reactions for reservoir stimulation

A system and method using a subterranean biological reactor can include a pre-reactor storage unit configured to receive a feedstock including a slurry of biologically derived material and at least one pump configured to pump the effluent from the pre-reactor storage unit. The system may include at least one wellbore containing a subterranean biological reactor configured to receive the effluent from the pre-reactor storage unit. At least a portion of the subterranean biological reactor may be configured to perform anaerobic digestion upon the effluent to generate a biogas.

System and method for using subterranean biological reactors

A method of receiving a plurality of oilfield brine feedstocks from one or more producing wells producing hydrocarbons from a subterranean formation is provided. The method includes detecting, using one or more sensors, one or more properties of the plurality of oilfield brine feedstocks, selecting two or more oilfield brine feedstocks from the plurality based at least in part on the one or more properties of the plurality of oilfield brine feedstocks, blending the two or more oilfield brine feedstocks into a blended oilfield brine prior to desalinating and crystallizing a portion of the blended oilfield brine, desalinating and crystallizing the portion of the blended oilfield brine to produce desalinated water and a salt slurry suspension, selecting one or more candidate wells for reinjection of the salt slurry suspension into the one or more candidate wells, and reinjecting the salt slurry suspension into the one or more candidate wells.

A system and method is provided that determines at least one bottomhole condition during flowback operations in a well that traverses a hydraulically fractured reservoir. The system and method measure fluid properties of fluids produced at a surface-location of the well during the flowback operations. A transient fluid flow simulator determines composition and properties of fluids in the well between the surface-location of the well and at least one bottomhole-location of the well based on the measured fluid properties. At least one bottomhole condition in the well is determined based on the composition and properties of fluids in the well between the surface-location and at least one bottomhole-location of the well.

System and method for determining bottomhole conditions during flowback operations of a shale reservoir

Methods of delivering reactive components to a geological formation disclosed herein include generating a plurality of microholes along a wellbore, the plurality of microholes comprising one or more openings, and the plurality of microholes are configured to connect the wellbore to the geological formation. Methods further include delivering the one or more reactive components to the plurality of microholes via a carrier fluid, wherein the one or more reactive components are configured to enable one or more chemical reactions to occur, and wherein the carrier fluid is configured to expand, and controlling a flow rate of the one or more reactive components based on whether a volume of the one or more reactive components delivered to the plurality of microholes is greater than a threshold volume.

A method for treating a subterranean formation penetrated by a wellbore, comprising: providing a treatment slurry comprising a carrying fluid, a solid particulate and an agglomerant; injecting the treatment slurry into a fracture to form a substantially uniformly distributed mixture of the solid particulate and the agglomerant; and transforming the substantially uniform mixture into areas that are rich in solid particulate and areas that are substantially free of solid particulate, wherein the solid particulate and the agglomerant have substantially dissimilar velocities in the fracture and wherein said transforming results from said substantially dissimilar velocities is provided.

Compositions and methods for increasing fracture conductivity

A method for characterizing properties of a sample that employs a test apparatus including an isolated sample cell and pressure sensor where the isolated sample cell is loaded with the sample and gaseous test fluid to perform a number of different tests to derive properties of the sample. The tests can be performed over different parameters, such as different applied pressures of the test fluid to derive parameters related to apparent gas permeability of the sample as a function of applied pressure, different gaseous test fluids to characterize dependence of permeability of the sample on mean free molecular path or pressure, with both adsorptive and non-adsorptive test gases to characterize at least one property related to adsorptive interaction between the adsorptive test gas and the sample, and with samples of varying saturation levels to derive a measure of at least one property of the subsamples at corresponding saturation levels.

Apparatus and methodology for measuring properties of microporous material at multiple scales

A method and system is provided that analyzes flow characteristics of return fluid that flows to a surface-located facility during well operations (such as plug mill-out or cleanout/workover operations) in order to characterize local formation properties of the formation. The method and system can be used to characterize a hydraulically-fractured hydrocarbon-bearing formation that is traversed by a well having a number of intervals that are hydraulically isolated from one another by corresponding plugs.

Method and system for establishing well performance during plug mill-out or cleanout/workover operations

Methods of stimulating subterranean formations are given in which thermite is placed downhole and then ignited. The thermite may be ignited with a downhole tool, the fracture may be mapped, and the thermite-affected region of the formation may be reconnected to the surface after the thermite reaction through the original or a second wellbore.

Hydraulic fracturing with exothermic reaction

A method of heterogeneous proppant placement in a subterranean fracture is disclosed. The method comprises injecting well treatment fluid including proppant () and proppant-spacing filler material () 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 material (), and removing the filler material () to form open channels () around the pillars (). The filler material can be dissolvable particles, initially acting as a consolidator during placement of the proppant in the fracture, and later dissolving to leave flow channels between the proppant pillars. The well treatment fluid can include extrametrical materials to provide reinforcement and consolidation of the proppant and, additionally or alternatively, to inhibit settling of the proppant in the treatment fluid.

Heterogeneous proppant placement in a fracture with removable extrametrical material fill

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Tucson, AZ, United States of America

Dean Michael Willberg