Halliburton Energy Services, Inc.

Hallibunon Energy Services, Inc.

Venkata Satya Srikalyan Bhamidipati

Ajish Potty

Denise Nicole Benoit

Philip D Nguyen

Jimmie Dean Weaver, Jr

Jim D Weaver

Zheng Lu

Kristina Henkel Holan

Chandra Sekhar Palla-Venkata

Kurt Hoeman

Syed Muhammad Farrukh Hamza

Humberto Almeida Oliveira

Yuming Yang

Surface modification agents may be included in emulsified acidic treatment fluids to leave surfaces in carbonate formations water wet after acidizing operations. A method of acidizing a subterranean formation, comprising: providing a treatment fluid in the form of an invert emulsion, wherein the treatment fluid comprises: a hydrocarbon phase comprising an oil-soluble liquid and an emulsifier; and an aqueous acidic phase comprising water, an acid, and a surface modification agent; and introducing the treatment fluid into a wellbore.

Emulsified acidic treatment fluid with surface modification agents

Methods of ranking formation stabilizer performance are described. The methods include obtaining drill cuttings from a subterranean formation, grinding and sieving the drill cuttings to a particle size larger than 200 mesh, adding a formation stabilizer solution to the ground and sieved drill cuttings to form a mixture, agitating the mixture, and measuring turbidity of the agitated mixture.

Methods of ranking formation stabilizer performance

Method of selecting an optimum formation stabilization treatment for subterranean formations is described. The methods include obtaining formation material, adding a test fluid to the formation material to form a first mixture, adding the test fluid to the formation material to form a second mixture, agitating the first and second mixtures, measuring capillary suction time of the first mixture, and measuring turbidity of the second mixture.

Formation stabilization workflow

Evaluating surfactants for use in downhole applications, especially surfactants with similar surface tension or interfacial tension values and wetting properties, may be achieved with a sensitive column test using a non-uniform particulate media therein. An exemplary method may include providing a column containing two types of particles that differ by at least one of: a mean particle diameter, a sphericity, and a chemical composition. Surfactant samples may be individually tested by passing the sample through the column followed by a displacement fluid, typically an oleaginous. The displacement rate and volume of the surfactant sample may be used to assess the surfactant's suitability for downhole applications.

Surfactant selection for downhole treatments

A method of fracturing a subterranean formation comprising: introducing a fracturing fluid into the subterranean formation to create or enhance one or more fractures in the subterranean formation; introducing a cement composition into the one or more fractures, wherein the cement composition comprises: (A) cement; (B) water; and (C) an additive; and allowing the cement composition to set, wherein the additive creates a plurality of pores within the set cement.

Porous cement composition for propping fractures open

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Kingwood, TX, United States of America

Venkata Satya Srikalyan Bhamidipati