Saudi Arabian Oil Company

King Fahd University of Petroleum and Minerals

Rajendra Arunkumar Kalgaonkar

Vikrant Bhavanishankar Wagle

Abdullah Saleh Al-Yami

Nisar Ullah

Mohammed Abudullah Bataweel

Muhammad Mansha

Zainab Alsaihati

Eyad Alali

Abdullah Saleh Hussain Al-Yami

Qasim Sahu

Nour Baqader

Ayman Mohammed Almohsin

Jin Huang

Mohammed Abdullah Bataweel

Ahmed M Gomaa

Khalid Alnoaimi

Muhammed Mansha

Ming Han

Sara Alkhalaf

Vera Solovyeva

Mustafa Alkhowaildi

Mohamed Ahmed Nasr El Din Mahmoud

Mohammed I Alabdrabalnabi

Abdullah AlYami

Ghaithan A Al-Muntasheri

Khalid R Alnoaimi

Maxim Orlov

Ziyuan Qi

Ameerah M Bokhari

Noor Othman Bagader

Khalid R Noaimi

Iaroslav Rybkin

Noor O Baqader

Ferromagnetic proppant including 3D cross particle core and a ferromagnetic material. Methods of increasing the permeability of a subterranean zone, and methods of enhancing heavy oil recovery.

Material and method for flow diversion in proppant fracturing

A method includes providing a well extending underground from a surface, using radial drilling to drill a primary tunnel extending in an outwardly direction from the well at a first axial location along the well, installing a chemical storage assembly in the primary tunnel, and ejecting chemicals from the chemical storage assembly into the well.

Method for downhole chemical storage for well mitigation and reservoir treatments

Compositions and methods for providing water shut off within a water producing zone of a wellbore. The composition includes alkaline nanosilica particles and hydrolysable ester-based 3D engineered non-convex particles. The method includes dissolving the hydrolysable ester-based 3D engineered non-convex particles to release an acid, which reacts with the alkaline nanosilica particles to form a solid.

Nanosilica-based compositions and related methods for providing water shut off to subterranean formations

A system and a method for determining hydrocarbon production from multiple subterranean formations. Different nanotag tracers are sequentially injected into subterranean production zones fluidly coupled to a wellbore extending from a surface of the Earth through the subterranean production zones. The respective nanotag tracers are injected into a respective subterranean production zone. The different nanotag tracers and production fluids contained within the subterranean production zones are produced through the wellbore to the surface. A turbidity of the production fluids containing the different nanotag tracers is determined at the surface. A quantity of each of the one or more different nanotag tracers from each of the subterranean production zones in the production fluids is determined. Based on the turbidity of the production fluids and the quantity of the different nanotag tracers, a total oil production rate from the subterranean production zones is determined.

Determining hydrocarbon production from multiple subterranean formations

Fracturing subterranean formation to produce hydrocarbons requires fracturing fluids. These fluids contain proppant particles. A system and method for making and using ultralight weight proppant particles includes a composite of a precipitated polymer matrix and a plant-based material, wherein the precipitated polymer matrix includes a thermoplastic, and wherein the plant-based material includes microparticles.

Ultra-lightweight proppants

A method of reducing water production in a wellbore may include introducing an alkaline nanosilica dispersion to the wellbore such that it contacts a water producing zone of the wellbore, introducing a sodium bicarbonate activator to the wellbore such that it contacts the alkaline nanosilica dispersion in the water producing zone, and forming a gelled solid from the water shutoff material in the water producing zone, thereby reducing water production in the wellbore.

Methods to use water shutoff material composition comprising alkaline nanosilica dispersion and sodium bicarbonate in downhole conditions

A hydraulic fracturing fluid and methods for using the hydraulic fracturing fluid fracturing a formation are provided. An exemplary hydraulic fracturing fluid includes a polymer additive, a breaker, a non-ionic surfactant. The hydraulic fracturing fluid also includes an amphoteric surfactant, or a cationic surfactant, or both, and a base fluid.

Low surface tension surfactant system for enhancing flow-back performance

A method, wellbore, and pill for treating a region of a subterranean formation adjacent a wellbore zone of the wellbore, including injecting a gellable treatment composition (e.g., as the pill) through the wellbore zone into the region of the subterranean formation adjacent the wellbore zone, allowing the gellable treatment composition to form nanoparticles in-situ in the region and gel in the region via heat provided by the region to prevent or reduce flow of an unwanted fluid from the region into the wellbore zone. The gellable treatment composition may include a zwitterionic gemini surfactant (ZGS).

Treatment of subterranean formations

In a method for diverter fracturing, a water-based fracturing fluid including non-convex particles is introduced into a hydraulic fracture of a wellbore at a first location. Each non-convex particle is formed to interlock with another non-convex particle. A diverter plug is formed in the hydraulic fracture when multiple non-convex particles interlock. Flow of another water-based fracturing fluid is diverted to a second location due to the diverter plug, forming another hydraulic fracture at the second location.

Materials and method for diverter fracturing

A method of controlling a permeability zone in a reservoir includes introducing a diverter agent comprising a morpholinium based zwitterionic surfactant including a sulfonate terminal moiety, an ammonium-based zwitterionic surfactant, and an activator in a wellbore. Once introduced, the diverter agent contacts a high permeability zone in the reservoir. The diverter agent heats and gels to form a gelled diverter agent in the high permeability zone, subsequently forming a zone of decreased permeability.

Viscoelastic surfactants for acid diversion in downhole operations

A diverter agent includes a morpholinium based zwitterionic surfactant having a sulfonate terminal moiety; and an ammonium based zwitterionic surfactant.

Methods and materials for wellbore fluid diversion using visco-elastic surfactants

A composition for a fracturing fluid may include a chelating agent, a polymeric gelling agent, and a base fluid. The base fluid in the fracturing fluid composition may be a produced fluid having a hardness content of at least 7,000 ppm. Method for treating a hydrocarbon-bearing formation may include introducing a fracturing fluid in the hydrocarbon-bearing formation. The fracturing fluid contains a chelating agent, a polymeric gelling agent, and a base fluid. The base fluid may be a produced fluid that has a hardness content of at least 7,000 ppm. The fracturing fluid may have a viscosity of at least 200 cp at 150° F., 100 1/s shear rate, and 300 psia when tested using model 5550 HPHT rheometer. After contacting the hydrocarbon-bearing formation, the viscosity of the fracturing fluid may drop near a range of 1 cP to 5 cP.

Fracturing fluid based on oilfield produced fluid

A downhole system includes a packer sealing an annular space around a downhole tubing and an insulating packer fluid positioned within the annular space and adjacent to the packer. The insulating packer fluid includes a sodium bicarbonate activator and an acidic nanosilica dispersion having silica nanoparticles and a stabilizer, wherein the pH of the acidic nanosilica dispersion ranges from 2 to 5, and the silica nanoparticles form at least 20 percent by weight of the acidic nanosilica dispersion.

Packer fluid with nanosilica dispersion and sodium bicarbonate for thermal insulation

A fracturing fluid may include a first surfactant and a second surfactant. The first surfactant may have a structure represented by formula (I): wherein m is an integer ranging from 2 to 3, and n, o, and k are each, independently, integers ranging from 2 to 10. The second surfactant having a structure represented by Formula (II): wherein Ris a C-Chydrocarbon group or a C-Csubstituted hydrocarbon group, Ris a C-Chydrocarbon group, and p and q are each, independently, an integer ranging from 1 to 4. Methods of treating a hydrocarbon-bearing formation include injecting the fracturing fluid in the hydrocarbon-bearing formation, the fracturing fluid being configured to transport a proppant in fractures of the hydrocarbon-bearing formation.

Fracturing fluids based on viscoelastic surfactants

A wellbore fluid including a first surfactant, a second surfactant, an activator and an aqueous base fluid is provided. The first surfactant has a structure represented by Formula (I): where Y, Y, Y, Yare each, independently, a sulfonate, a carboxylate, an ester or a hydroxyl group, m is an integer ranging from 2 to 3, and n, o, and k are each, independently, integers ranging from 2 to 10. The second surfactant has a structure represented by Formula (III): where Ris a C-Chydrocarbon group or a C-Csubstituted hydrocarbon group, Ris a C-Chydrocarbon group, and p and q are each, independently, an integer ranging from 1 to 4. A method of using the wellbore fluid for treating a hydrocarbon-containing formation is also provided.

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Abqaiq, Saudi Arabia

Rajendra Arunkumar Kalgaonkar