Halliburton Energy Services, Inc.

Denise Nicole Benoit

Antonio Recio, Iii

Enrique Antonio Reyes

Kristina Henkel Holan

Zheng Lu

Chandra Sekhar Palla-Venkata

Kurt Hoeman

I Wayan Rakananda Saputra

Gladys Rocio Montenegro-Galindo

Philip D Nguyen

Dale E Jamison

Aaron Michael Beuterbaugh

Nathan Carl Schultheiss

Jody Marie Burks

Brian Alan Evans

Humberto Almeida Oliveira

Ronald Glen Dusterhoft

Daniel Joshua Stark

Tatyana V Khamatnurova

Jason Maxey

Ajish Potty

Antonio Recio

Francisco Xavier Ruiz

Venkata Satya Srikalyan Bhamidipati

Larry Steven Eoff

Jimmie Dean Weaver, Jr

Thomas Donovan Welton

William Walter Shumway

James William Ogle

Jim D Weaver

Andrew David Vos

Ali Alwattari

Travis Hope Larsen

Prashant Dinkar Chopade

David Michael Loveless

Mallikarjuna Shroff Rama

Ronald Oliver Bosch

Jun Su An

Paul Ashcraft

Mateusz Michal Dyngosz

Nicole Mast

Scott Anthony Klasner

Sumit Shivshankar Konale

Yuming Yang

Evan Samples

Nicole Mast-Hale

Daniel Bryant Eddings

Nicole Colleen Mast Hale

Kristina M Henkel

Iii Recio Antonio

Analyzing solid components in the return line of a borehole can be accomplished by implementing a bar or disc in the return line. As solid components pass by, they will generate an acoustic wave on impact. In another aspect, solid components can be directed to a shaker system where the solid components will impact a soundboard. The acoustic waves can be captured, such as by a microphone or transducer. The acoustic waves can be processed and transformed into acoustic data. A machine learning system can use previously trained models to determine the solid component parameters using the acoustic data. The parameters can include the size, shape, composition, density, softness, wettability, and other parameters of the solid components. These parameters can then be used as inputs to users or other borehole systems, such as a well site controller to improve drilling operations or to identify the need to implement corrective actions.

Analyzing drill cuttings using acoustic analysis

Friction reducers can be included in a liquid concentrate for use in treatment fluids in oil and gas operations. The liquid concentrate can be a slurry and include oil or a brine as the continuous phase and the friction reducer in dry form as the dispersed phase. The liquid concentrate can be an invert emulsion and include oil as the continuous phase and water and friction reducer dissolved in the water as the dispersed phase. A suspending agent can be included in the liquid concentrate to distribute and suspend the friction reducer throughout the continuous phase. The suspending agent can form micelles that form a mesh-like network to distribute and suspend the friction reducer. A portion of the liquid concentrate can be added to a base fluid at the wellsite to form the treatment fluid. The treatment fluid can be a fracturing fluid.

Friction reducer slurries with suspending agent

A water-based carrier-fluid system comprising a brine formed from water saturated with at least one saturation salt, a viscoelastic surfactant, and one or more salt crystals. The water-based carrier-fluid system is formed by adding the viscoelastic surfactant to the brine to produce a first mixture prior to the one or more salt crystals being added to the mixture. The salt in the salt crystals has a Ksp value equal to or greater than the saturation salt.

Treatment fluid stabilized to prevent polymer reaction

Well treatment fluids comprise well treatment additives comprising an ionic liquid. Method of treating a subterranean formation may comprise contacting the subterranean formation with the well treatment additive, wherein the well treatment additive comprises an ionic liquid comprising a cation and an anion having the following formula: [RRRRN][X], wherein R, R, R, Rare individually selected from the group consisting of an alkyl group, a hydroxyalkyl group, and a combination thereof provided that at least one of R, R, R, Ris the hydroxyalkyl group, and wherein the anion Xcomprises at least one anion selected from the group consisting of F, Cl, Br, I, HPO, HPO, PO, HSO, CHOSO, CHSO, SO, CHSO, CHSO, CHOSO, CHOSO, and combinations thereof.

Ionic liquid chain transfer agent as well treatment additive

A variety of methods and compositions are disclosed, including, in one embodiment, A friction reducer comprising: a continuous phase comprising a base oil and a secondary oil, wherein the secondary oil is different than the base oil; a discontinuous phase dispersed in the continuation phase, wherein the discontinuous phase comprises water and a water-soluble polymer, and an emulsifying surfactant.

Friction reducers for dissolved solids tolerance

Methods and treatments fluids for treating a wellbore. One example method introduces the treatment fluid into the wellbore. The treatment fluid comprises an aqueous fluid, an aminopolycarboxylic acid, a nanoparticle dispersed, and an organic solvent. The treatment fluid has a pH in a range between about 5 to about 9. The method further includes contacting a rock surface in the subterranean formation; wherein at least a portion of the rock surface is coated with a hydrocarbon. The treatment fluid removes a portion of the hydrocarbon from the rock surface and alters the rock surface to be water-wet.

Nanoparticle wedge effect to induce water wettability

Compositions and methods using subterranean treatment fluids comprising water-soluble polymers are provided. In some embodiments, the methods include: adding an anionic or amphoteric water-soluble polymer to a treatment fluid comprising an aqueous base fluid; adding a dewatering agent to the treatment fluid, wherein the dewatering agent comprises an aqueous phase, a solvent, a co-solvent, and one or more surfactants selected from the group consisting of: ethoxylated alcohol, a polyamine polyether, a resin alkoxylated oligomer, and any combination thereof; and introducing the treatment fluid into a well bore penetrating at least a portion of the subterranean formation.

Compositions and methods using subterranean treatment fluids comprising water-soluble polymers

A variety of methods and compositions are disclosed, including, in one embodiment, A friction reducer comprising: a continuous phase comprising a base oil and a secondary oil, wherein the secondary oil is different than the base oil; a discontinuous phase dispersed in the continuation phase, wherein the discontinuous phase comprises water and a water-soluble polymer; and an emulsifying surfactant.

Systems and methods wherein well-treatment fluids are evaluated for use in a subterranean reservoir. The systems and methods utilize quartz crystals configured to be quartz crystal microbalances (QCM). The QCM has a surface with a reservoir-specific material deposited on the surface. The reservoir-specific material is representative of formation material or proppant. Changes in mass of the reservoir-specific material are measured using the QCM. The changes reflect the interaction of the treatment fluid with the reservoir-specific material and/or hydrocarbons in the reservoir-specific material.

Surfactant selection workflow based on performance at the reservoir surface

A wellbore servicing fluid comprising (a) a cationic formation stabilizer having (i) a molecular weight in a range of from equal to or greater than 0.05 to equal to or less than 2.0 kiloDaltons (kDa), or (ii) cationic charge functional groups of greater than 2 to equal to or less than 5 cationic charges per molecule, or (iii) both (i) and (ii), (b) an anionic friction reducer, and (c) an aqueous fluid.

Cationic formation stabilizers compatible with anionic friction reducing polymers

A method of producing natural resources from a wellbore penetrating a subterranean formation with a Huff and Puff process comprising: (a) placing a recovery enhancing fluid system into the wellbore during an injection (Huff) period of time wherein placing the recovery enhancing fluid system comprises injecting under pressure; (b) ceasing injection of the recovery enhancing fluid system and allowing the composition to soak in the subterranean formation for a soak period of time; (c) producing fluids from the subterranean formation during a production (Puff) period of time; and (d) optionally repeating steps (a) to (c) for a plurality of Huff, soak, and Puff periods of time, respectively.

Enhanced oil recovery harvesting for fractured reservoirs

A well treatment fluid comprising an aqueous base fluid and a wettability modifier, and a method using the well treatment fluid. The wettability modifier includes an alkylamine oxide surfactant, and an organic compound having a phosphonoalkyl moiety. As an example, the well treatment fluid is suitable for treating oil-wet formations.

Rapid reversal of wettability of subterranean formations

A method for strengthening a subterranean formation is disclosed herein. A method of strengthening a subterranean formation includes: introducing a first fluid into the subterranean formation, wherein the first fluid includes polyvalent cations; and introducing a second fluid into the subterranean formation, wherein the second fluid includes a dissolved silicate in an aqueous-base fluid; wherein the dissolved silicate reacts with the polyvalent cations in the subterranean formation to form a reaction product including precipitated silicate in the subterranean formation.

Subterranean drilling and completion in geothermal wells

Provided are methods for selecting a treatment for a subterranean formation in accordance with the disclosure and the illustrated FIGs. An example method comprises obtaining a formation material, measuring a geomechanical property of the formation material, measuring a mineralogy of the formation material, preparing a predictive model for the formation material from the measured geomechanical property and the mineralogy of the formation material; wherein the predictive model analyzes production over time for a plurality of treatments for the formation material, wherein the formation material is treated with each treatment in the plurality of treatments and the geomechanical property and the mineralogy of the formation material are measured before and after an individual treatment, selecting the treatment having the greatest production from the plurality of treatments, and contacting the subterranean formation with the treatment.

Workflow for predictive model to select formation damage treatment

Growing community of inventors

Houston, TX, United States of America

Denise Nicole Benoit