Halliburton Energy Services, Inc.

Other

John Dean Stabenau

William Owen Alexander Ruhle

Geoffrey Wedell Gullickson

Michael John Caple

Richard David Grisinger

Jon Preston Doucette

William Owen Ruhle

Methods and systems for delivering well stimulation materials to a wellbore using a high-pressure delivery manifold are provided. In some embodiments, the methods of the present disclosure include: providing a pressurizable delivery manifold at a well site, wherein the pressurizable delivery manifold is continuously equalized with a piping system; providing a pressurized treatment fluid to the pressurizable delivery manifold; releasing one or more well stimulation materials into the pressurized treatment fluid to create a payload delivery treatment fluid; and injecting the payload delivery treatment fluid into at least a portion of a subterranean formation.

High-pressure manifold for well stimulation material delivery

A flow constraint material consists essentially of degradable particles, where at least 50% by volume of the degradable particles have an average particle size of about 1 millimeters (mm) to about 6 mm.

Methods for fracturing a subterranean formation by using flow constraint material

Flow constraint material and slurry compositions

A treatment additive for hydraulic fracturing made of heated silica to create amorphous silicate with a Mohs hardness between 4.5 and 6 and a particles distribution with maximum diameter between 5 and 2600 microns that has been heated and shaped into amorphous shapes with large surface area to weight ratio and ultra-low settling velocity used to prop microfractures distal from well bore, especially in low viscosity and high temperature wells. The microparticle size and shape allow the treatment to effectively hold microfractures open, stimulate backpressure, and prevent leakoff; which has the added benefit of improving primary fracture development; refrac and frac protect productivity; and reduces the likelihood of interference between offset wells. An additional benefit is that the treatment doesn't contain crystalline silica.

Use of micro-particle amorphous silicate in well stimulation

Method of using micro-particle amorphous silicate in well stimulation

A method of fracturing a subterranean formation to produce fluid from a reservoir through a wellbore includes flowing a treating fluid into the wellbore to create fractures in the formation, selectively flowing a flow constraint material (FCM) into the wellbore simultaneously with the treating fluid, pausing the flow of the FCM while maintaining the flow of the treating fluid, monitoring a parameter of the formation to determine whether the parameter is within a range, resuming the flow of the FCM when the parameter of the formation is out of the range, ceasing the flow of the FCM when the parameter of the formation is in the range, where a system strain increase is about 0.0003 or less when the parameter of the formation is in range, and where the flow of the flow constraint material partially constrains the treating fluid from entering at least one of the fractures.

Fracturing a subterranean formation

Systems and methods for fracturing an interval of a subterranean formation to produce fluid from a reservoir through a wellbore. A treating fluid flows into the wellbore to create fractures in the formation. A flow constraint material is selectively flowed into the wellbore simultaneously with the treating fluid. A parameter of the formation is monitored to determine whether a formation system strain is within a range. When the formation system strain is out of the range, the flow of the flow constraint material is adjusted. The flow constraint material partially constrains the treating fluid from entering a fracture so as to at least partially redistribute the treating fluid to an another fracture or fractures.

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Littleton, CO, United States of America

John Dean Stabenau