Halliburton Energy Services, Inc.

Enrique Antonio Reyes

Aaron Michael Beuterbaugh

Alyssa Lynn Smith

Antonio Recio, Iii

Alyssa Lynn Lablanc

Ronald Glen Dusterhoft

Denise Nicole Benoit

Kristina Henkel Holan

Jimmie Dean Weaver, Jr

Natalie Lynn Pascarella

Neil Alan Stegent

Hongyu Luo

Antonio Recio

Doug W Walser

Christopher Lynn Smith

Benjamin Edward LaBlanc

Benjamin Edward Lablanc

Philip D Nguyen

Thomas Donovan Welton

Dipti Singh

Richard Dale Rickman

Travis Hope Larsen

Narongsak Tonmukayakul

Ronald Oliver Bosch

Matt E Blauch

Tiffany Anne Pinder

Pinmanee Boontheung

Wirdansyah Lubis

Nicole Mast

Norman R Warpinski

Aaron M Beuterbaugh

Michael Linley Fripp

B Raghava Reddy

Jay Paul Deville

William Walter Shumway

Zachary William Walton

Loan K Vo

David Eugene McMechan

Baireddy R Reddy

Michael Wayne Sanders

Jeremy A Holtsclaw

Matthew Eric Blauch

Rajender Salla

Vladimir Nikolayevich Martysevich

Ubong Akpan Inyang

Tatyana V Khamatnurova

Prashant Dinkar Chopade

Sairam Eluru

Mallikarjuna Shroff Rama

Gagan Saini

Christopher R Parton

Chetan Prakash

Jun Su An

Lalit Pandurang Salgaonkar

Norman Raymond Warpinski

Qi Liang

Lucas Kurtis Fontenelle

Walter T Stephens

Kurt Hoeman

Brian Atkins

Eli Allen Schnoor

Jessica Lynn Heeter

Cesar Edmundo Meza

Vijaya Kumar Patnana

Tyler Austen Anderson

Monica Rajendra Dandawate

Drew Henry Gaugler

Julio Estuardo Vasquez Estrada

Victor Daniel Escobar

Andrew Bailey Slocum

Sumit Shivshankar Konale

Dandan Hu

Marisol Mendez

Alyssa L LaBlanc

Sarai Santos

James Rosthorn

Renata Vieira Pires

Corine L McMechan

Antonio Iii Recio

David Mcmechan

Luo Hongyu

Breaker fluids for removing polyolefin agglomerations from wellbore equipment and subterranean formations. An example breaker fluid includes an acid, at least one oxidizer, a corrosion inhibitor, a surfactant, an asphaltene remover, a sludging inhibitor, and an aqueous base fluid. The breaker fluid is introduced to wellbore equipment and subterranean formations and breaks down polyolefin agglomerations present therein.

Breaker fluids for removal of polyolefin residue

A method may include: introducing a treatment fluid into a production fluid disposed in a surface well system, the treatment fluid comprising: a base fluid; and a supramolecular host guest product comprising: a treatment fluid additive comprising a surfactant; and a supramolecular host molecule, wherein the supramolecular host molecule is not covalently bonded to the treatment fluid additive; introducing the production fluid containing the treatment fluid into a production facility separator; and separating, in the production facility separator, at least a portion of the production fluid to form a water stream.

Supramolecular host guest product concentrators for production fluids

A method for acidizing a subterranean formation may include: preparing a water-in-oil emulsion comprising a non-polar phase, a polar phase, an emulsifier an acid, and a drag reducing agent; pumping the water-in-oil emulsion into a wellbore penetrating a subterranean formation above a fracture gradient of the subterranean formation to create or extend at least one fracture in the subterranean formation.

Drag reducing agent for emulsified acids

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

A variety of methods, systems, and compositions are disclosed, including, in one example, a method that includes: introducing a treatment fluid into a wellbore extending into a subterranean formation, wherein the treatment fluid comprises: water; an acid; a corrosion inhibitor; and a friction reducer having a vinyl phosphonic acid moiety, an acrylic acid moiety, a vinyl sulfonate moiety, a diallyl moiety, or an acrylamide moiety; and flowing at least a portion of the treatment fluid into the subterranean formation, wherein the pressure required to achieve a given flow rate of the treatment fluid into the subterranean formation is reduced by at least 1% as compared to the pressure required to achieve the given flow rate of the treatment fluid in the subterranean formation without the friction reducer.

Friction reduction of acidic treatment fluids

The present disclosure relates to subterranean formation operations and, more particularly, to embedded treatment fluid additives for use in subterranean formation operations. The embedded treatment additives may comprise an aqueous-soluble downhole reactive material embedded in a crosslinked polymeric solution to delay the reactivity of the aqueous-soluble downhole reactive material, thereby forming the embedded treatment additive, wherein the aqueous-soluble downhole reactive material is a solid.

Embedded treatment fluid additives for use in subterranean formation operations

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 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

Well treatment operation comprises introducing nanosized particulates into a formation. The nanosized particulates are synthesized by combining PMIDA, a calcium source, a pH adjusting agent, and an aqueous medium. This combination results in a degradable (i.e., dissolvable) solid that can be used in heterogeneous formations like shale type rock reservoirs, as well as sedimentary rock formations like clastic, siliclastic, sandstone, limestone, calcite, dolomite, and chalk formations, and formations where there is large fluid leak-off due to stimulation treatments. The disclosed particulates may also be used for acidizing treatments in mature fields and deep water formations commonly characterized by high permeability matrices. The solubility of the particulates advantageously allows the material to act as a temporary agent having a lifespan that is a function of temperature, water flux, and pH, making it adaptable to various reservoir conditions with minimal to no risk of adverse effects on the reservoir.

Nanosized particulates for downhole applications

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

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.

Removal of a mineral phase from a surface associated with a wellbore

A method and system for pressurizing and stimulating a formation with a parent well therethrough, the method including storing and de-liquefying liquefied natural gas (LNG) at an on-site location near the parent well, injecting a first stream of de-liquefied LNG into the parent well to pressurize the formation, and injecting a second stream of de-liquefied LNG into the parent well at a fracturing pressure sufficient to fracture the pressurized formation.

Liquefied natural gas (LNG) re-fracturing

The rapid reaction of hydrofluoric acid with siliceous materials can make it difficult to increase the permeability of subterranean formations containing siliceous minerals. Methods for stimulating a subterranean formation can comprise: providing a latent hydrofluoric acid composition comprising a degradable matrix, and a hydrofluoric acid precursor dispersed in the degradable matrix; introducing a first treatment fluid containing the latent hydrofluoric acid composition in a non-dissolved form into a wellbore penetrating a subterranean formation comprising a siliceous material; differentially depositing the latent hydrofluoric acid composition upon a portion of the siliceous material in one or more locations; degrading at least a portion of the degradable matrix, thereby exposing at least a portion of the hydrofluoric acid precursor; converting the exposed hydrofluoric acid precursor into hydrofluoric acid; and reacting the hydrofluoric acid with the siliceous material where the latent hydrofluoric acid composition was deposited.

Methods, treatment fluids and systems for differential acidizing of a siliceous material

Growing community of inventors

Tomball, TX, United States of America

Enrique Antonio Reyes