Saudi Arabian Oil Company

Abdulkareem AlSofi

Jinxun Wang

Ming Han

Amar Jaber M Alshehri

Amar J Alshehri

Hassan W Al Hashim

Shaohua Chen

Subhash Chandrabose Ayirala

Ali Abdallah Al-Yousef

Jun Gao

Adrian Cesar Cavazos Sepulveda

Ahmed Gmira

Amer Alanazi

Mohanad M Fahmi

Ziyad Kaidar

Yara Alzahid

Abdulaziz AlKhateeb

A sand prevention system includes a housing having a conduit and a plurality of sand crushers coupled to the housing that prevent sand particles disposed within a fluid of a well having a diameter greater than a specified diameter from passing through the conduit of the housing of the sand prevention system. Each sand crusher includes a casing and a plurality of crushing elements encased within the casing that reduce the diameter of the sand particles. The sand prevention system further includes a sensor module, fixed within the housing, that includes a plurality of sensors that detect a presence of sand particles within the fluid and a transmitter that notifies a surface location of the well of the presence of the sand particles within the fluid.

Sand prevention system

A viscosity reducer composition may include one or more polycyclic compounds, one or more polymers covalently attached to one or more polyaromatic compounds, one or more rheology modifiers, one or more surfactants, and an aqueous solution.

Viscosity reducer compositions, methods for producing, and methods of using

A removable apparatus having a core holder body and a core sample assembly fitted inside the core holder body is disclosed. The core sample assembly includes a core sample and a sleeve fitted around the core sample. A first flanged stopper and a second flanged stopper are positioned at opposite axial ends of the core holder body. A flow path is formed through the first and second flanged stoppers and interfaces at opposite end surfaces of the core sample. Also provided are an assembly and a system comprising the removable apparatus for use in oilfield applications. Further, a method of testing a property of a fluid using the removable apparatus is provided.

On-line core holder design for polymer quality testing device

A method and a system to determine a gelation time of a substance in a container is disclosed. The system includes a container, a bubble generator arranged at a first end of the container, and a bubble sensor arranged at the second end of the container. The container holds a substance having a surface adjacent the second end. The bubble generator is configured to generate a bubble at the first end. The bubble sensor is configured to sense the bubble at the surface of the substance. The method includes releasing a gas into a first end of the container such that the gas bubbles rise from the first end of the container to a second end of the container, sensing the released bubbles, determining an absence of a bubble released by the bubble generator at the bubble sensor, and determining a gelation time based on a number of detected bubbles.

Gaseous bubble system and method to measure gelation time

Formation treatment fluid compositions and methods are provided that include an aqueous base fluid, where the aqueous base fluid comprises one or more salts; and sago. The profile modification fluid may include sago in an amount in the range from 50,000 ppm to 100,000 ppm. Formation treatment fluid compositions may also include an aqueous base fluid, where the aqueous base fluid comprises one or more salts, and sago, where the formation treatment fluid may include sago in an amount in the range from 10,000 ppm to 50,000 ppm. Methods for using the formation treatment fluid may include introducing into a targeted stratum of a subterranean formation a treatment fluid. The subterranean treatment fluid may include an aqueous base fluid, where the aqueous base fluid includes one or more salts, sago, and the treatment fluid may include sago in an amount in the range from 10,000 ppm to 100,000 ppm.

Sago-based formulations for gel applications including conformance control and water shutoffs

A solution for injection to a formation containing hydrocarbons includes an ionic liquid and a brine having a salinity of at least 60,000 ppm total dissolved solids (TDS). The ionic liquid is configured to lower an interfacial tension between the solution and the hydrocarbons in the formation.

Reuse of hypersaline brine with ionic liquids

A method includes saturating a core sample with a hydrocarbon fluid to provide a hydrocarbon-saturated core, placing the core into a first aqueous fluid, applying an external force at increasing magnitude to the hydrocarbon-saturated core to displace a volume of the hydrocarbon fluid in the hydrocarbon-saturated core with the first aqueous fluid at each pressure magnitude, measuring a volume of displaced hydrocarbon fluid at each pressure magnitude, obtaining a first capillary pressure curve, re-saturating the core sample, placing the hydrocarbon-saturated core into a second aqueous fluid having a wettability altering agent, applying an external force at increasing magnitude to displace a volume of the hydrocarbon fluid in the core with the second aqueous fluid at each pressure magnitude, measuring a volume of displaced hydrocarbon fluid at each pressure magnitude, obtaining a second capillary pressure curve, and calculating a contact angle of the second aqueous fluid.

Centrifuge method for evaluating contact angle and wettability alteration

This disclosure relates to water-soluble viscosity reducer complexes for use in reducing the viscosity of heavy oil in oil recovery operations. The viscosity reducer complexes contain a hydrophilic component of polyaromatic-hydrocarbon-based polymers and a hydrophilic component of cyclodextrin-based polymers.

Polyaromatic hydrocarbon-based host-guest complex for heavy crude oil viscosity reduction

A method of forming a model of a porous structure includes three dimensionally printing a mold of the porous structure using a polycaprolactone mold material, filling the mold with a polymer mixture, and heating the filled mold at a temperature above a melting temperature of the mold material to cure the polymer mixture, where the cured polymer mixture forms the model of the porous structure.

Fabrication method of transparent 3D polydimethylsiloxane devices with polycaprolactone molds

A contact angle measurement system includes a housing that can hold a volume of a first fluid having a first density, an adjustable rock sample holder positioned within the housing, a fluid dropper attached to the housing, an image capturing a device, and a computer system. The holder can support a rock sample. An orientation of the holder relative to the housing is adjustable such that an outer surface of the rock sample is at a non-zero angle relative to a lower wall of the housing. When the orientation of the holder relative to the housing is such that the outer surface of the rock sample is at the non-zero angle relative to the lower wall, the fluid droplet traverses the outer surface of the rock sample. The image capturing device can capture images of the fluid droplet as the fluid droplet traverses the outer surface of the rock sample.

Dynamic contact angle measurement

Techniques for analyzing a sample include preparing a sample; circulating a gel solution through the sample to saturate the sample; scanning the saturated sample with a nuclear magnetic resonance (NMR) system to determine two or more NMR values of the saturated sample; determining a permeability of the saturated sample based, at least in part, on the two or more NMR values of the saturated sample; aging the saturated sample; scanning the aged sample with the NMR system to determine two or more NMR values of the aged sample; determining a permeability of the aged sample based, at least in part, on the two or more NMR values of the aged sample; comparing the determined permeability of the saturated sample against the determined permeability of the aged sample; and based on the compared permeabilities, determining a gel solution syneresis rate.

Determining permeability variation

A polymer is flowed through a slim tube including porous media until steady state is achieved. A temperature of the porous media with the polymer is adjusted to emulate a reservoir temperature. A slug of a gel solution is flowed through the porous media in the slim tube. The gel solution includes the polymer and a crosslinker. The gel solution is configured to at least partially solidify at the temperature. Multiple pressure drops across the porous media in the slim tube are measured at corresponding locations along a length of the slim tube while the slug flows through the porous media in the slim tube. The slug at least partially solidifies within the slim tube, causing an increase in pressure. A location of gelation of the slug of gel solution within the slim tube is determined based on the increase in pressure.

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Dhahran, Saudi Arabia

Abdulkareem AlSofi