Saudi Arabian Oil Company

Schlumberger Middle East, S.a.

Khalid Mohammed M Alruwaili

Mohamed Nabil Noui-Mehidi

Murtadha J AlTammar

Gallyam Aidagulov

Devon Chikonga Gwaba

Abbad Mustapha

Younane N Abousleiman

Hassan Sakar Alqahtani

Katherine Leigh Hull

Yanhui Han

Vera Solovyeva

Misfer J Almarri

Khaqan Khan

Mirajuddin Riazuddin Khan

Saad AlMutairi

Ghassan Salem AlShehry

Murtadha J Altammar

Justin Tate Abel

A well tool for generating a notch in an open-hole wellbore, includes a tool body having a housing defining at least one slot and an interior volume. The tool body includes a cutting device disposed in the interior volume, configured to form a notch in a formation. The cutting device includes a shaft disposed in the interior volume of the housing having a first portion with a first exterior threads that extend around the first portion in a first direction, and a second portion having second exterior threads that extend around the second portion in a second direction opposite the first direction. The cutting device includes multiple blades configured to extend radially outward toward the formation through the slot or inward away from the formation and having a first blade extending from the first portion of the shaft and a second blade extending from a second portion of the shaft.

Wellbore notching assembly

A method of treating kerogen is provided. The method includes: generating a fracture network in a subterranean formation including kerogen by injecting a treatment fluid through a wellbore into the subterranean formation, the treatment fluid including water, an oxidant, and nanoparticles, the treatment fluid oxidizing a portion of the kerogen in the subterranean formation while generating the fracture network; and injecting carbon dioxide (CO) through the wellbore into the subterranean formation, the CO2 penetrating the subterranean formation through the facture network.

Hydraulic treatment of subterranean formations using oxidant, nanoparticles, and carbon dioxide

A hydraulic fracturing operation is performed in a wellbore formed in a subterranean zone. A wellhead is installed at an entrance to the wellbore. Liquid COis flowed through a pipeline located at a surface and fluidically coupled to the wellhead. The liquid COis flowed into the wellbore through the wellhead to perform the hydraulic fracturing. The hydraulic fracturing operation including flowing of the liquid COthrough the pipeline to the wellhead is stopped. A portion of the liquid COis withdrawn from within the pipeline into a liquid COstorage container, which is a portable system designed to capture and store liquid COand that is fluidically coupled to the pipeline at the surface.

Portable system to capture and store liquid carbon dioxide

A system for carbon dioxide (CO) capture at a wellhead using a mixed matrix membranes (MMM). The MMM includes a polymer matrix and covalent triazine framework (CTF) fillers. The captured COstream may be reutilized through sequestration and utilization approaches. The bulk stream may be split into multiple streams for various applications. Some COmay be converted chemically into fuels, reaction intermediates, and productivity enhancement tools such as methanol, syngas, CO-foam, used in fracking fluids, and stimulant acids. The rest may be stored through direct injection into porous formations or reactive rocks such as basalt.

Wellhead carbon capture, utilization, and storage using mixed matrix membranes

A well tool for generating a shaped perforation in a cased wellbore includes a tool body. The told body has at least one wall, a fluid channel, a first perforation device, and a second perforation device. The at least one wall defines an opening and an interior volume. The fluid channel extends from the opening of the at least one wall into the interior volume. The first perforation device is configured to form a perforation tunnel in the cased wellbore disposed in a formation. The second perforation device is coupled to the first perforation device and to the fluid channel. The second perforation device is configured to form the shaped perforation in the formation by flowing fluid received through the fluid channel to the formation through the perforation tunnel.

Wellbore shaped perforation assembly

To monitor hydraulic fracturing operations, an acoustic insulation tool acoustically insulates a wellhead installed at a surface of a wellbore. Multiple acoustic sensors attached to the wellhead sense acoustic signals generated responsive to operation of hydraulic fracturing components. The components perform hydraulic fracturing operations within the wellbore. The acoustic insulation tool acoustically insulates the wellhead from acoustic signals generated by sources other than the hydraulic fracturing components. The multiple acoustic sensors transmit the sensed acoustic signals to a computer system. Using the received acoustic signals, the computer system monitors the hydraulic fracturing operations performed within the wellbore.

Wellhead acoustic insulation to monitor hydraulic fracturing

Provided is a diagnostic wellbore testing method that includes forming a diagnostic wellbore in a subterranean zone including one or more formations. The wellbore extends through a portion of a formation having a maximum horizontal stress extending in a first direction and a minimum horizontal stress extending in a second direction perpendicular to the first direction. The method also includes forming a pair of notches on a circumference of the wellbore. The pair of notches are formed diametrically opposite each other. The method also includes applying fluidic pressure to the wellbore at the pair of notches in the second direction while avoiding applying fluidic pressure in the first direction. Fractures propagate from the pair of notches responsive to the fluidic pressure. The method also includes measuring a closure pressure of the wellbore, and providing the closure pressure as the maximum horizontal stress of the formation.

Measuring horizontal stress in an underground formation

A pressure testing system for analyzing a rock formation includes a tubular support member sized to pass into a wellbore of the rock formation and an adjustable loading device configured to exert a radial load against the wall of the wellbore. The adjustable loading device includes multiple expandable members distributed around a circumference of the tubular support member and configured to expand to respectively exert multiple radial pressures against the wall of the wellbore that together provide the radial load. The pressure testing system further includes a control module configured to selectively control expansion of each expandable member of the multiple expandable members to vary the radial load exerted by the adjustable loading device as a function of an angle around the circumference of the tubular support member.

Pressure testing systems for subterranean rock formations

Methods for predicting a structural response and failure of a liner for a well can include receiving geometric properties of the liner; receiving structural properties of the liner; receiving material properties of the liner; developing a numerical model of the liner; calibrating one or more parameters of the constitutive model representing the material of the liner, the calibrating including: determining a numerical burst pressure failure; determining a numerical collapse failure pressure; and simulating the structural response and failure of the numerical model subjected to an expected non-uniform pressure loading of the well, where the numerical model is used to predict the structural response and failure of the liner when installed in the well.

Calibration and simulation of a wellbore liner

A method for determining rock properties includes running a downhole tool into a wellbore formed from a terranean surface to a subterranean zone that includes an underground rock formation, the downhole tool including one or more protrusions coupled with at least one expandable member of the downhole tool, the one or more protrusions including memory metal; actuating the downhole tool, at a location in the wellbore adjacent the underground rock formation, to adjust the at least one expandable member to move the one or more protrusions into or near contact with the underground rock formation; activating the one or more protrusions to fracture the underground rock formation through forcible contact between the one or more protrusions and the underground rock formation; determining a wellbore pressure increase at the location in the wellbore based on the fracture; and determining one or more properties of the underground rock formation based at least in part on the determined wellbore pressure increase.

Determining in-situ rock stress

A cylindrical drum with a fluid inlet is configured to be connected to a downhole end of a fluid conduit. The cylindrical drum has an outer surface along which is the fluid inlet. The cylindrical drum has a center and an inner surface. Fluid nozzles fluidically connect to an interior of the cylindrical drum and are positioned around the outer circumference of the cylindrical drum. The fluid nozzles are positioned to direct fluid away from the cylindrical drum. A rotatable collar is positioned in the center of the cylindrical drum. The rotatable collar has an outer surface parallel to the inner surface of the cylindrical drum. Sleeve plates are positioned between the inner surface of the cylindrical drum and the outer surface of the rotatable collar. Each of the sleeve plates defines a hole with a diameter smaller than a diameter of a corresponding dropped ball.

Stimulating U-shape wellbores

A first fracturing fluid is pumped through a first wellbore at a first pressure. The first wellbore includes a first vertical section and horizontal section having a first end, intersecting from the first vertical section, and a distal end. A second fracturing fluid is pumped through a second wellbore at a second pressure simultaneously while the first fracturing fluid is pumped through the first wellbore. The second wellbore includes a second vertical section that intersects with the distal end of the horizontal section. The first pressure and the second pressure result in the first fracturing fluid and the second fracturing fluid intersecting at a fracture point within the horizontal section at a third pressure. The first fracturing fluid and the second fracturing fluid each experience a respective pressure drop traveling through their respective wellbores to the fracture point/. The respective pressure drops result in the third pressure.

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Dhahran, Saudi Arabia

Khalid Mohammed M Alruwaili