Saudi Arabian Oil Company

Aramco Services Company

Rti International

The City University of New York

King Fahd University of Petroleum and Minerals

King Abdulaziz City for Science and Technology

Cornell Center for Technology, Enterprise and Commercialization

Ghaithan Al-Muntasheri

Feng Liang

Leiming Li

B Raghava Reddy

Katherine Leigh Hull

Martin E Poitzsch

Jason R Cox

Hooisweng Ow

Younane N Abousleiman

David J Jacobi

Ginger Denison Rothrock

Leah Marie Johnson

Mohammed Sayed

Amy J Cairns

George John

Sehmus Ozden

Sarah Dorothy Shepherd

Abdulrahman F Alharbi

Vidyasagar Adiyala

Emmanuel P Giannelis

Ibnelwaleed A Hussein

Abdullah Saad Sultan

Mohammed Ali Ibrahim Sayed

Ahmad Akanbi Adewunmi

Liling Fu

Genggeng Qi

Khalid Saad Elkarsani

Sarah Sheperd

A treatment fluid system for reducing permeability of high permeability zones in a subterranean reservoir formation comprising a fluid composition comprising a nano-crosslinker, the nano-crosslinker comprising a nanomaterial, and a crosslinker, wherein the crosslinker comprises a chemical group selected from the group consisting of carbonyl, sulfhydryl, amine and imine, wherein the nano-crosslinker is produced by a method selected from the group consisting of pre-treating the nanomaterial with the crosslinker such that the crosslinker has been functionalized onto the nanomaterial, embedding the crosslinker on the nanoparticle, grafting the crosslinker onto the nanomaterial, and coating the crosslinker on the nanomaterial, a base polymer, and a base fluid, the base fluid operable to suspend the fluid composition, wherein the base fluid comprises water, wherein the treatment fluid system is operable to reduce permeability of a high permeability zone in the subterranean reservoir formation.

High temperature treatment fluids with nano-crosslinkers

A composition for use as a pressure-tolerant dual-crosslinker gel in a fracturing fluid that comprises polymer, the polymer operable to increase the viscosity of a fluid; boron-containing crosslinker, the boron-containing crosslinker operable to crosslink the polymer; and a transition metal oxide additive, the transition metal oxide additive operable to crosslink the polymer.

Additives to minimize viscosity reduction for guar/borate system under high pressure

A polymer-encapsulated mineral acid solution and a method for forming the polymer-encapsulated mineral acid solution. Introducing a strong mineral acid solution to a monomer solution occurs such that a primary emulsion that is a water-in-oil type emulsion forms. Introducing the primary emulsion to a second aqueous solution forms a secondary emulsion that is a water-in-oil-in-water type double emulsion. The monomer in the secondary emulsion is cured such a polymerized shell forms that encapsulates the strong mineral acid solution and forms the capsule. The strong mineral acid solution has up to 30 wt. % strong mineral acid. A method of stimulating a hydrocarbon-bearing formation using the polymer-encapsulated mineral acid solution includes introducing a capsule suspension into a fissure in the hydrocarbon-bearing formation to be stimulated through a face in a well bore. The capsule is maintained within the fissure until the polymer shell degrades.

Encapsulation and controlled delivery of strong mineral acids

A stabilized emulsified acid composition for deep carbonate formation stimulation is provided. The stabilized acid emulsion composition includes a petroleum operable to provide a barrier between an acid and a reservoir rock, the acid operable to react with the reservoir rock to dissolve the reservoir rock and produce a wormhole, a functional framework operable to stabilize the stabilized acid emulsion, an emulsifier operable to stabilize the stabilized acid emulsion, and a corrosion inhibitor operable to provide protection against corrosion for the metal components of a well. The petroleum can be diesel. The acid can be hydrochloric acid. The functional framework can be selected from the group comprising surface-modified clay-based material, zeolites, hybrid organic-inorganic materials, covalent-organic framework materials, and boron nitride nanotubes, and combinations thereof. The functional framework can be a surface-modified clay material selected from an organoclay. The corrosion inhibitor is a cationic ammonium-based corrosion inhibitor.

Targeting enhanced production through deep carbonate stimulation: stabilized acid emulsions containing insoluble solid materials with desired wetting properties

Provided in this disclosure, in part, are methods, compositions, and systems for degrading organic matter, such as kerogen, in a subterranean formation. Further, these methods, compositions, and systems allow for increased hydraulic fracturing efficiencies in subterranean formations, such as unconventional rock reservoirs. Also provided in this disclosure is a method of treating kerogen in a subterranean formation including placing in the subterranean formation a composition that includes a first oxidizer including a persulfate and a second oxidizer including a bromate.

Kerogen and organic matter degrading additive for hydraulic fracturing fluids

A fracturing fluid system for increasing hydrocarbon production in a subterranean reservoir formation comprising a fluid composition and a base fluid, the fluid composition comprising a nano-crosslinker, and a base polymer; and the base fluid operable to suspend the fluid composition, the base fluid comprising water; wherein the fluid composition and the base fluid are combined to produce the fracturing fluid system, wherein the fracturing fluid system is operable to stimulate the subterranean reservoir formation. In certain embodiments, the nano-crosslinker is an amine-containing nano-crosslinker and the base polymer is an acrylamide-based polymer. In certain embodiments, the fracturing fluid systems comprise proppants for enhancing hydraulic fracturing stimulation in a subterranean hydrocarbon reservoir.

High temperature fracturing fluids with nano-crosslinkers

Gelled hydrocarbon fracturing fluids and their methods of preparation and use are provided. The gelled hydrocarbon fracturing fluid includes a hydrocarbon fluid, a phosphate ester, a crosslinker and a viscosifier. The crosslinker may include iron, aluminum, or combinations thereof and the viscosifier may include clay, graphite, carbon nanotubes, metallic oxide nanoparticles, and combinations thereof. The method of preparation includes combining a hydrocarbon fluid, phosphate ester, and crosslinker to form a baseline fluid. A viscosifier is added to the baseline fluid to form a gelled hydrocarbon fracturing fluid. The method of use includes treating a subterranean formation by contacting a subterranean formation with a gelled hydrocarbon fracturing fluid and generating at least one fracture in the subterranean formation.

Enhancements of gelled hydrocarbon systems

A fracturing fluid including a base fluid including salt water, a polymer, a crosslinker, and a nanomaterial. The crosslinker may include a Zr crosslinker, a Ti crosslinker, an Al crosslinker, a borate crosslinker, or a combination thereof. The nanomaterial may include ZrOnanoparticles, TiOnanoparticles, CeOnanoparticles; Zr nanoparticles, Ti nanoparticles, Ce nanoparticles, metal-organic polyhedra including Zr, Ti, Ce, or a combination thereof; carbon nanotubes, carbon nanorods, nano graphene, nano graphene oxide; or any combination thereof. The viscosity and viscosity lifetime of fracturing fluids with both crosslinkers and nanomaterials are greater than the sum of the effects of crosslinkers and nanomaterials taken separately. Moreover, this synergistic effect offers significant, practical advantages, including the ability to use salt water rather than fresh water for fracturing fluids, the ability to reduce polymer loading to achieve a desired viscosity, and the ability to achieve better formation cleanup after the fracturing treatment.

Hydraulic fracturing fluid

A fracturing fluid including a mixture of an aqueous copolymer composition including a copolymer, the copolymer having 2-acrylamido-2-methylpropanesulfonic acid, acrylamide, and acrylic acid monomer units, or a salt thereof, and a crosslinker. The crosslinker includes a metal, and the weight ratio of the metal to the copolymer is in a range of 0.01 to 0.08. Treating a subterranean formation includes introducing the fracturing fluid into a subterranean formation, and crosslinking the fracturing fluid in the subterranean formation to yield a crosslinked fracturing fluid. The crosslinked fracturing fluid has a viscosity of at least 500 cP for at least 80 minutes when the gel is subjected to a shear rate of 40 sat a temperature in a range of 300&#xb0; F. to 400&#xb0; F.

High temperature crosslinked fracturing fluids

Gas and condensate productivities from a hydrocarbon reservoir can be enhanced using a chemical treatment composition. The chemical treatment composition includes a solvent mixture and a wettability alteration chemical. The solvent mixture includes a solvent that is operable to increase the relative permeability of gas within the hydrocarbon reservoir and the wettability alteration chemical is operable to alter the wettability of surfaces of the hydrocarbon reservoir, in each case enhancing the gas and condensate productivities from the hydrocarbon reservoir. The solvent mixture is selected to provide a chemical treatment composition with a flash point of at least 40&#xb0; C. (104&#xb0; F.).

Flash point adjustment of wettability alteration chemicals in hydrocarbon solvents

Embodiments for a high temperature fracturing fluid comprise an aqueous fluid, carboxyl-containing synthetic polymer, metal oxide nanoparticles having a particle size of 0.1 to 500 nanometers, and a metal crosslinker which crosslinks the carboxyl-containing synthetic polymers to form a crosslinked gel, wherein the metal oxide nanoparticles are dispersed within the crosslinked gel.

High temperature fracturing fluids with nanoparticles

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Houston, TX, United States of America

Ghaithan Al-Muntasheri