Schlumberger Technology Corporation

Anatoly Vladimirovich Medvedev

Dean Michael Willberg

Ivan Vitalievich Kosarev

J Ernest Brown

Timothy M Lesko

Oleg Olegovich Medvedev

Alexander Alexandrovich Burukhin

Jonathan Abbott

Alejandro Pena

Konstantin Mikhailovich Lyapunov

Fedor Nikolaevich Litvinets

Alexander Vuacheslavovich Mikhaylov

John Lassek

Andrey Vladimirovich Bogdan

Sergey Makarychev-Mikhailov

Dominic Vincent Perroni

Carlos Abad

Balkrishna Gadiyar

Christopher N Fredd

Mohan K R Panga

Michael J Fuller

Ian C Walton

Raymond J Tibbles

Christopher Daeffler

Adam Ethan Keilers

Matthew Miller

James Ernest Brown

Bipin Jain

Kreso Kurt Butula

Nikita Yurievich Silko

Marina Bulova

Sergey Vladimirovich Semenov

Laure Martin-Al-Khatib

Konstantin Viktorovich Vidma

Petr Kolchanov

Timothy Michael Lesko

Sergey Mikhailovich Makarychev-Mikhaliov

Ivan Sergeyevich Glaznev

Daniel Anatolievitch Kalinin

Ashley Watling

Alexander Igorevich Titkov

Dean M Willberg

Sergey Mikhailovich Makarychev-Mikhailov

Oleg Medvedev

Ian Walton

Methods for shortening the waiting-on-cement (WOC) time during primary and remedial cementing operations are disclosed. A fluid pill is injected into the wellbore that comprises reactants. The reaction is exothermic and heat is conducted into the cement sheath, thereby accelerating hydration and shortening the time necessary for the slurry to set and harden.

Methods for shortening waiting-on-cement time in a subterranean well

Cement slurries are prepared that comprise water, a hydraulic cement and particles of an oil-absorbent material. The particles are present in an amount sufficient to alter a property of a non-aqueous drilling fluid. The cement slurry is placed in a subterranean well, whereupon the slurry contacts residual drilling fluid on casing and formation surfaces. The oil-absorbent material in the cement slurry may reduce the mobility of the drilling fluid, thereby improving zonal isolation.

Cement compositions and methods

The positions of hydraulic fractures may be detected during multistage reservoir stimulation operations. Fracturing fluid is injected into a well at a pressure above the fracturing pressure to produce at least one hydraulic fracture. Then, a marker slug is injected into the well. Next, additional fracturing fluid is injected into the well. When the marker slug enters at least one of the hydraulic fractures, a detectable pressure response is observed, and the position of a hydraulic fracture may be detected from the volume of fracturing fluid injected after injection of the marker slug. The marker slug is a fluid that has a viscosity and/or density that is different from the fracturing fluids injected before and after the marker slug. This technique may be combined with other well operations, such as plugging at least one hydraulic fracture or creating at least one new hydraulic fracture.

Method for detecting a fracture position in a well (variants)

A treatment fluid that comprises a carrier fluid and a degradable material in the form of particles, fibers or both is provided or prepared. The treatment fluid is placed in a borehole such that the treatment fluid contacts a liner, a downhole filter, perforations, natural fractures, induced fractures, or a subterranean formation or combinations thereof. The treatment fluid is allowed to flow into the liner, downhole filter, perforation, natural or induced fracture or subterranean formation such that the degradable material forms at least one plug or filter cake (or both), preventing or reducing further fluid movement between the wellbore and the subterranean formation. The degradable material is then allowed to dissolve after a period of time, causing the plug or filter cake (or both) to weaken, thereby allowing removal of the plug or filter cake (or both) and reestablishing fluid movement between formation and the wellbore.

Methods for treating a subterranean well

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

A fluid slug consolidation is maintained in a fluid system for use in downhole applications. The fluid system has an interfacing fluid of a different character adjacent to the fluid slug. The method is carried out by admixing a particulate material with at least one of the fluid slug and adjacent interfacing fluid in an amount wherein discrete interfacing fluid margins are formed between the slug and the adjacent interfacing fluid under laminar flow conditions. The fluid system is introduced into a well bore of a well formed in a subterranean formation. In certain applications at least a portion of the particulate material is provided with adhesive properties to facilitate aggregation of the particulate material within the at least one of the fluid slug and adjacent interfacing fluid.

Method of fluid slug consolidation within a fluid system in downhole applications

A method of 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 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 filler material can be dissolvable particles, initially acting as a filler material during placement of the proppant in the fracture, and later dissolving to leave the flow channels between the proppant pillars. The well treatment fluid can include extrametrical materials to provide reinforcement and consolidation of the proppant and/or to inhibit settling of the proppant.

A method for producing minerals and, more specifically, for producing hydrocarbons, by hydraulic fracturing of the rock, can be used for the optimization of formation fracturing crack processing conditions. The method includes splitting a main stream of a propping agent suspension in a fluid at a mixer output into at least two flows having different volume delivery rates, and comingling the at least two flows before delivering to the hydraulic fracturing zone.

Method of propping agent delivery to the well

A method of heterogeneous proppant placement in a subterranean fracture is disclosed. The method comprises injecting well treatment fluid including proppant () wherein the proppant comprises from 1 to 100 percent in weight of stiff, low-elasticity and low-deformability elongated particles () and proppant-spacing filler material called 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 in the fracture, 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, additionally or alternatively, to inhibit settling of the proppant in the treatment fluid.

Heterogeneous proppant placement in a fracture with removable channelant fill

A technique includes completing a well, including installing a tubing string that includes a screen in the well and installing a fiber-based material outside of the screen. The technique further includes using the well as an injection well, including communicating a fluid into the tubing string to cause an injection flow to be communicated in a fluid flow path from an interior of the tubing string, through the screen and into a formation.

Gravel and fracture packing using fibers

A proppant pack may be formed in a fracture that extends from a wellbore formed in a subterranean formation and is accomplished through different methods. The methods involve providing multiple spaced apart proppant slugs within a hydraulic fracturing fluid that is introduced into the wellbore at a pressure above the fracturing pressure of the formation.

Methods for providing proppant slugs in fracturing treatments

A method of heterogeneous proppant placement in a subterranean fracture is disclosed. The method comprises injecting a first treatment fluid comprising a gas and substantially free of macroscopic particles through a wellbore to initiate a fracture in a subterranean formation; injecting a second treatment fluid comprising proppant and channelant through the wellbore into the fracture; placing the proppant in the fracture in a plurality of proppant clusters forming pillars spaced apart by the channelant; and removing the channelant to form open channels around the pillars for fluid flow from the subterranean formation through the fracture toward the wellbore.

Growing community of inventors

Moscow, Russia

Anatoly Vladimirovich Medvedev