Saudi Arabian Oil Company

Akzo Nobel Chemicals International B.v.

Jin Huang

Wengang Li

Feng Liang

Rajendra Arunkumar Kalgaonkar

Ayman Mohammed Almohsin

Vikrant Bhavanishankar Wagle

Abdullah Saleh Hussain Al-Yami

Mohammed Abdullah Bataweel

Hans Olof Lagnemo

Mohammed Abudullah Bataweel

Bader Ghazi Al-Harbi

Ahmed M Gomaa

Prasad Baburao Karadkar

Per Anders Restorp

Ghaithan A Al-Muntasheri

Weishu Zhao

Noor Othman Bagader

Andreas Ake Sundblom

Khalid R Noaimi

In accordance with one or more embodiments of the present disclosure, a low-density treatment fluid includes a base water-control system and at least one light-weight filler material. The base water-control system may include an inorganic material system comprising an aqueous colloidal silica and a water-soluble chemical activator for gelling the colloidal silica, or the base water-control system may include an organic material system comprising of polymeric material. The low-density treatment fluid may have a density of from 0.1 g/cmto 0.75 g/cm. Also described are methods of recovering a target fluid from a subterranean cavity using such a low-density treatment fluid.

Low-density treatment fluid and methods for treating thief zones located above pay zones

This disclosure relates to acidizing retarder compositions and methods of reducing the rate of carbonate dissolution in carbonate acidizing treatments of carbonate formations using the acidizing retarder compositions. The methods may include dissolving one or more retarder compounds in a solution comprising a strong acid to form acidizing retarder compositions, and introducing the acidizing retarder compositions to carbonate formations. The acidizing retarder compositions may include one or more retarder compounds and a strong acid. At least one of the one or more retarder compounds may be a poloxamer. A concentration of the strong acid in the acidizing retarder composition may be 5 weight percent or greater.

Acidizing retarder compositions and methods of reducing a rate of carbonate dissolution using the same

According to embodiments disclosed herein, a gel fluid composite may include a nanosilica gel and a plurality of quantum dot tracers. The nanosilica gel may be configured to seal one or more downhole fractures in a wellbore. The plurality of quantum dot tracers may be dispersed in the nanosilica gel. The plurality of quantum dot tracers may each include a semiconductor particle core housed in a silica shell.

Gel fluid composites comprising nanosilica and quantum dots for sealing water production in a wellbore

A silicon oxide Janus nanosheets relatively permeability modifier (RPM) for carbonate and sandstone formations. The silicon oxide Janus nanosheets RPM may be used to treat a water and hydrocarbon producing carbonate or sandstone formation to reduce water permeability in the formation and increase the production of hydrocarbons. The silicon oxide Janus nanosheets RPM for carbonate formations includes a first side having negatively charged functional groups and a second side having alkyl groups. The silicon oxide Janus nanosheets RPM for sandstone formations includes a first side having positively charged functional groups and a second side having alkyl groups. The negatively charged functional groups may include a negatively charged oxygen group groups and hydroxyl groups. The positively charged functional groups may include amino groups and an amine. Methods of reducing water permeability using the silicon oxide Janus nanosheets RPM and methods of manufacturing the silicon oxide Janus nanosheets RPM are also provided.

Silicon dioxide Janus nanosheets relative permeability modifier (RPM) for reducing subterranean formation water permeability in carbonate and sandstone formations

A chemical gel system having a polymer and a silicon oxide Janus nanosheets crosslinker for treating thief zones in carbonate formations. The polymer and silicon oxide Janus nanosheets crosslinker may form a crosslinked polymer gel to reduce or prevent water production via thief zones during hydrocarbon production. The silicon oxide Janus nanosheets crosslinker includes a first side having negatively charged functional groups and a second side having amines. The negatively charged functional groups may include negatively charged oxygen groups and hydroxyl groups. Methods of reducing water production in a thief zone using the silicon oxide Janus nanosheets crosslinker and methods of manufacturing the silicon oxide Janus nanosheets crosslinker are also provided.

Methods and compositions for treating thief zones in carbonate formations using crosslinked polymeric systems with silicon dioxide janus nanosheets crosslinker

A chemical gel system having a polymer and a graphene oxide Janus nanosheets crosslinker for treating thief zones in carbonate formations. The polymer and graphene oxide Janus nanosheets crosslinker may form a crosslinked polymer gel to reduce or prevent water production via thief zones during hydrocarbon production. The graphene oxide Janus nanosheets crosslinker includes a first side having negatively charged functional groups and a second side having amines. The negatively charged functional groups may include carboxyl groups, negatively charged oxygen groups, and hydroxyl groups. Methods of reducing water production in a thief zone using the graphene oxide Janus nanosheets crosslinker and methods of manufacturing the graphene oxide Janus nanosheets crosslinker are also provided.

Methods and compositions for treating thief zones in carbonate formations using crosslinked polymeric systems with graphene oxide Janus nanosheets crosslinker

A graphene oxide Janus nanosheets relative permeability modifier (RPM) for carbonate formations. The graphene oxide Janus nanosheets RPM may be used to treat a water and hydrocarbon producing carbonate formation to reduce water permeability in the formation and increase the production of hydrocarbons. The graphene oxide Janus nanosheet RPM includes a first side having negatively charged functional groups and a second side having alkyl groups. The alkyl groups may include C8 to C30 alkyls. The negatively charged functional groups may include carboxyl groups, epoxy groups, and hydroxyl groups. Methods of reducing water permeability of a carbonate formation using the graphene oxide Janus nanosheets RPM and methods of manufacturing the graphene oxide Janus nanosheets RPM are also provided.

Graphene oxide janus nanosheets relative permeability modifier (RPM) for reducing subterranean formation water permeability in carbonate formations

A polymer gel composition for treating an aqueous zone of a subterranean formation may include a base polymer, a cross-linking agent, and an adsorption system. The adsorption system may include one or more silane compounds or a combination of silane compounds and silicates. The adsorption system may improve bonding of the polymer gel composition to the pore surfaces of the rock in the aqueous zone. A method of treating an aqueous zone of a subterranean formation may include injecting the polymer gel composition into the aqueous zone of the formation and allowing the polymer gel composition to cure to form a cross-linked polymer gel matrix that provides a barrier that reduces or prevents the flow of aqueous materials from the aqueous zone to the wellbore.

Polymer gel compositions for treating aqueous zones in subterranean formations and methods of treating the aqueous zones

A composition useful for subterranean water or gas shut off applications includes organosilane-modified colloidal silica and an accelerator. The accelerator includes one or more organic or inorganic salts. A method of using a composition, including an organosilane-modified colloidal silica and an accelerator, includes forming a fluid system that is flowed to a formation in a subterranean zone, such as through a wellbore, where the composition forms a gel to plug the formation and shut off water flow into the wellbore.

Composition and method for water and gas shut-off in subterranean formations

A nanoparticle-resin coated frac sand composition is provided. The nanoparticle-resin coated frac sand composition includes a silica sand, an epoxy resin, methanol, a hardener, and nanoparticles. The nanoparticles may be silica nanoparticles, alumina nanoparticles, zinc oxide (ZnO) nanoparticles, or titanium oxide (TiO) nanoparticles. The methanol is used as a diluent for the epoxy resin. The nanoparticle-resin coated frac sand composition may be used as a proppant in a hydraulic fracturing operation, such by injecting a hydraulic fracturing fluid having the composition into a subterranean formation. Methods of manufacturing the composition and hydraulic fracturing of a subterranean formation are also provided.

Nanoparticle-enhanced resin coated frac sand composition

Nanoparticle-enhanced resin coated Frac sand composition

A subterranean formation sealant includes a mixture of an aqueous colloidal dispersion including silica nanoparticles and a C6-C12 fatty acid. Heating the sealant above 70&#xb0; C. initiates gelation of the sealant. Sealing an opening in a water or gas producing zone in a subterranean formation includes providing a sealant including a mixture of a colloidal dispersion including silica nanoparticles and a C6-C12 fatty acid to the water or gas producing zone, initiating gelation of the sealant in situ, and solidifying the sealant in the water or gas producing zone to yield a set gel, thereby sealing the opening in the water or gas producing zone.

Plugging and sealing subterranean formations

Fracturing a reservoir includes providing a pad fluid to the reservoir via a wellbore in a well to create fractures in the reservoir, providing a fracturing fluid to the fractures via the wellbore, providing a nanosilica carrier fluid to the fractures via the wellbore, activating the nanosilica particles with an activator to yield a nanosilica gel, and shutting in the wellbore at a wellbore pressure, thereby allowing the nanosilica gel to form proppant pillars in the fractures. The nanosilica carrier fluid includes nanosilica particles, and providing the nanosilica carrier fluid to the fractures comprises pulsing quantities of the nanosilica carrier fluid into a continuous flow of the fracturing fluid or alternately pulsing quantities of the nanosilica carrier fluid and the fracturing fluid. An elapsed time between pulsing the quantities of the nanosilica carrier fluid is between 2 seconds and 10 minutes.

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Dhahran, Saudi Arabia

Jin Huang