Halliburton Energy Services, Inc.

Antonio Recio, Iii

Enrique Antonio Reyes

Denise Nicole Benoit

Kristina Henkel Holan

Larry Steven Eoff

Aaron Michael Beuterbaugh

B Raghava Reddy

Jeremy A Holtsclaw

Travis Hope Larsen

Jason Maxey

Chandra Sekhar Palla-Venkata

Christopher Austin Lewis

Kurt Hoeman

Ronald Glen Dusterhoft

Hong Sun

Tatyana V Khamatnurova

Jun Su An

Gladys Rocio Montenegro-Galindo

I Wayan Rakananda Saputra

Paul Ashcraft

Philip D Nguyen

Rahul Chandrakant Patil

Aaron Gene Russell

Ronald Oliver Bosch

Shoy George Chittattukara

Christopher R Parton

Janette Cortez

Natalie Lynn Pascarella

Ajish Potty

Anindya Ghosh

Walter T Stephens

Shoy Chittattukara George

Golchehreh Salamat

Vishwajit Manajirao Ghatge

Tiffany Anne Pinder

Julio Estuardo Vasquez Estrada

Sarai Santos

Mike Phillips

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

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

Methods and compositions for performing a sealing operation in a wellbore. An example method introduces a sealant composition into the wellbore while the sealant composition is under shear. The sealant composition comprises a thixotropic material, a conformance gel system, and an aqueous base fluid. The sealant composition is placed into a target location, and applied shear is reduced to the sealant composition when in the target location thereby allowing the sealant composition to thicken in the target location. Fluid flow across the target location is reduced by a fluid seal formed by the thickened sealant composition.

Method for wellbore sealing

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

Methods and treatment fluids for removing mixed scale. A treatment fluid is introduced into a wellbore comprising a mixed scale of interspersed calcium carbonate and calcium sulfate. The treatment fluid comprises: phosphonomethyliminodiacetic acid, N,N-bis(phosphonomethyl)glycine, or a combination thereof; and an aqueous base fluid. The treatment fluid has a pH in a range between about 6 to about 8. The method further comprises contacting the mixed scale with the treatment fluid.

Single-fluid mixed scale dissolution

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 method of enhanced oil recovery comprising introducing into one or more injection wells located within a subterranean formation a treatment fluid comprising (i) an aminopolycarboxylic acid comprising a phosphonoalkyl moiety; and ii) a surfactant blend; and removing hydrocarbons from one or more production wells. A method of enhanced oil recovery comprising introducing into one or more injection wells located within a subterranean formation a treatment fluid comprising (i) an aminopolycarboxylic acid comprising a phosphonoalkyl moiety; and ii) a surfactant blend wherein the subterranean formation comprises non-source rock, naturally-fractured rock, low porosity rock, calcite rich reservoir rock or a combination thereof; and removing hydrocarbons from one or more production wells.

Reactive surfactant flooding at neutral pH

Surfactant compositions and methods for hydrocarbon recovery from a subterranean formation are provided. In some embodiments, the methods include: introducing a surfactant composition comprising an aqueous phase, an oil phase, an organic solvent, and one or more surfactants into a wellbore penetrating at least a portion of a subterranean formation; introducing an organic compound comprising a phosphonoalkyl moiety into the wellbore; and at least partially displacing a hydrocarbon from the subterranean formation by contacting a surface in the subterranean formation with the surfactant composition or the organic compound. In some embodiments, the compositions include: an aqueous phase; an oil phase comprising at least one solvent; an organic solvent; one or more surfactants; and at least one organic compound comprising a phosphonoalkyl moiety.

Methods and compositions for hydrocarbon recovery

A method of treating a well, comprising introducing a well treatment fluid into the well. The well treatment fluid includes an aqueous base fluid and a dewatering agent. The dewatering agent includes water, a demulsifying surfactant, and a polyamine polyether.

Polyamine polyethers as nonemulsifier components

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

Various embodiments disclosed relate to surfactant compositions for treatment of subterranean formations and produced oil. In various embodiments, the present invention provides a method of treating a subterranean formation including placing in the subterranean formation a surfactant composition. The surfactant composition includes an alkanolamide surfactant and an alkoxylated alcohol surfactant. The surfactant composition also includes an ionic surfactant, a nonionic surfactant, or a combination thereof.

Surfactant compositions for treatment of subterranean formations and produced oil

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

Various embodiments disclosed relate to demulsifier compositions for treatment of subterranean formations or produced petroleum comprising an emulsion. In various embodiments, the present invention provides a method of treating a subterranean formation. The method includes placing in the subterranean formation a demulsifier composition. The demulsifier composition includes an alkanolamide surfactant that is a (C-C)hydrocarbyl amide having groups Rand Rsubstituted on the amide nitrogen, wherein Rand Rare each independently selected from the group consisting of &#x2014;H, &#x2014;(C-C)hydrocarbyl, and &#x2014;(C-C)hydrocarbylene-OH, wherein at least one of Rand Ris &#x2014;(C-C)hydrocarbylene-OH. The demulsifier composition includes an alkoxylated alcohol surfactant that is a (C-C)hydrocarbyl-OH having a &#x2014;((C-C)alkylene-O)&#x2014;H group on the &#x2014;OH group, wherein n is about 1 to about 100. The demulsifier composition also includes an amine-oxide surfactant. At each occurrence the (C-C)hydrocarbyl and (C-C)hydrocarbylene are substituted or unsubstituted and are independently selected.

Demulsifier compositions for treatment of subterranean formations and produced oil

The compositions for removing a mineral phase from a surface composition for removing a mineral phase of inorganic sulfate scale include a phosphonoalkyl aminopolycarboxylic acid chelating agent; a wettability modifier comprises a dibasic ester and a surfactant, wherein the surfactant comprises one or more of an anionic alkyl sulfonate or an anionic aryl sulfonate; a pH-adjusting agent; a scale converting agent; and water. The methods for removing a mineral phase from a surface include contacting the mineral phase with an aqueous dissolver fluid that is one of the present compositions; and removing the oil wet mineral phase from the surface with the aqueous dissolver fluid. The compositions and methods provide enhanced remediation of mineral phases from surfaces associated with wellbores.

Growing community of inventors

Humble, TX, United States of America

Antonio Recio, Iii