Schlumberger Technology Corporation

Konstantin Mikhailovich Lyapunov

J Ernest Brown

Anatoly Vladimirovich Medvedev

Oleg Olegovich Medvedev

Alexander Vuacheslavovich Mikhaylov

Dean Michael Willberg

Timothy M Lesko

Alejandro Pena

Ivan Vitalievich Kosarev

Alexander Alexandrovich Burukhin

Fedor Nikolaevich Litvinets

Jonathan Abbott

Andrey Vladimirovich Bogdan

Sergey Makarychev-Mikhailov

Christopher N Fredd

Evgeny Borisovich Barmatov

John Lassek

Kreso Kurt Butula

Sergey Dmitrievich Parkhonyuk

Danil Sergeyevich Pantsurkin

Alexander Victorovich Golovin

Ivan Vladimirovich Velikanov

Denis Viktorovich Bannikov

Sergey Mikhailovich Makarychev-Mikhaliov

Mixing equipment for hydraulic fracturing operations undergoes wear with continued use. Monitoring the performance of the mixing equipment and predicting failure may be performed by measuring discharge pressures or hydrodynamic acoustic noise. Computer modeling and machine learning may be employed to help operators decide whether to take equipment out of service for maintenance or to allow the equipment to continue operating.

Monitoring the performance of hydraulic pumping equipment

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 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 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

Particulate material used for proppant flowback control from the fracture, where the material is a polymer which increases its hardness under downhole conditions.

Particulate material for proppant flowback control

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Novosibirsk, Russia

Konstantin Mikhailovich Lyapunov