Saudi Arabian Oil Company

Ziyad Kaidar

Damian Pablo San Roman Alerigi

Muhammad Majid Almajid

Abdulkareem AlSofi

Adrian Cesar Cavazos Sepulveda

Amer Alanazi

Zuhair AlYousef

Abdulkareem Mohamad AlSofi

Mustafa Redha Satrawi

Thamer Zahrani

Muhammad B Otaibi

Abdulaziz AlKhateeb

Methods and associated systems for reducing permeability of fractures in deep underground formations are provided. Thermal responsive fluid is used that transitions to a gel upon exposure to heat generated by one or more subsequently added exothermic reactants. Exothermic reaction is utilized to control the temperature at the targeted stratum to and affect the gelation time and gel propagation in the porous medium.

Thermal responsive fluid injection method

Systems and methods include a computer-implemented method for analyzing rock samples. Rock and oil electromagnetic baselines are determined for rock samples in at least a section of an electromagnetic spectrum ranging from ultraviolet to long terahertz radiation. An aging process is conducted on each rock sample, initially starting with the rock and oil electromagnetic baselines. The aging process is repeated using spectrometry on the rock sample and measured wettabilities of the rock sample until changes in spectra are less than a predetermined threshold. Aging information including the spectra and wettabilities are stored in a machine learning database. Spectra are obtained from an unknown rock sample. The spectra are mapped to clusters in the machine learning database. Wettability ranges are determined for the unknown rock sample based on a mapping of the spectra of the unknown rock sample to clusters in the machine learning database.

Contactless measurement of rock wettability by photonic techniques

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 method includes determining a critical micelle concentration (C) of a sample with an unknown concentration (C) of a surfactant based on an assumed surfactant concentration (C) of the sample, providing a benchmark solution with a known concentration of the surfactant, determining an actual critical micelle concentration (C) of the surfactant from the benchmark solution, and calculating the unknown concentration (C) of the surfactant in the sample from the following equation: C=C/(C/C).

CMC-based method for surfactant concentration determination

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Dhahran, Saudi Arabia

Ziyad Kaidar