Saudi Arabian Oil Company

Bandar S Al-Malki

Zainab Alsaihati

Najeeb Al-Abdulrahman

Magbel Alharbi

Chinthaka Pasan Gooneratne

Bodong Li

Timothy Eric Moellendick

Guodong Zhan

Ismail Adebiyi

Ahmed Abdulaziz Al-Mousa

Omar M Alhamid

Mohammed Ahmed Alkhowaildi

Asim Alkhuwayr

Hassan K Al-Aswad

Yousef H Dahnem

Oscar David Bautista Sayago

Ghassan A Essa

Mohammed Al-Atigue

Asim Al-Khuwayr

Mohammed T Al-Mojbel

Abdullah Essa Alnoaimi

Mohammed Y Al-Daif

Ali M Assiri

A downhole tool includes a tool body including an uphole joint and a downhole joint configured to couple within a wellbore tubing string that extends in a wellbore. One or more flow directing paths are formed on an outer surface of the tool body and configured to rotate a portion of the tool body in response to a fluid flow within the wellbore tubing string. One or more ports are disposed around a circumference of the tool body; and a piston is configured to adjust between an open position such that the one or more ports are open to enable injection of a lost circulation material circulated through the tool body and into the wellbore and a closed position such that the one or more ports are closed to block injection of the lost circulation material into the wellbore from the tool body.

Lost circulation material tool

A system and method for evaluating a wellbore involves drawing fluid from a surrounding formation into an isolated portion of the wellbore, collecting the fluid in the isolated portion, and directing the sampled fluid to surge tanks on surface through a string of coiled tubing. The system and method includes measuring fluid properties, such as density and viscosity; and observing fluid flow characteristics, such as the fluid pressure, the fluid flowrate, and changes in the fluid flowrate. Based on the measured fluid properties and observed characteristics a determination is made if the wellbore is a candidate for a drill stem test.

Wellbore sampling and testing system

A method of freeing a stuck pipe in a wellbore includes positioning a pipe freeing tool within an annulus of the stuck pipe, the pipe freeing tool including a body and two or more arms coupled to and extending from the body, and activating the two or more arms of the pipe freeing tool to extend outwards from the body to apply a force to the stuck pipe. Another method of freeing a stuck pipe in a wellbore includes determining a stuck point along a drillstring comprising the stuck pipe, and activating a pipe freeing tool coupled to the stuck pipe to apply a force to the stuck pipe, wherein the force moves the stuck pipe away from a surface of the wellbore and towards a center of the wellbore, and the pipe freeing tool includes a plurality of expandable disc elements.

Freeing a stuck pipe from a wellbore

Techniques for removing a tubular from a wellbore include running a downhole tool on a downhole conveyance into a wellbore formed from a terranean surface into a subterranean formation; activating a piston sub-assembly to repeatedly move pistons to contact a portion of a casing installed in the wellbore to at least de-bond a cement layer installed between the portion of the casing and the subterranean formation from the portion of the casing; activating a cutting sub-assembly to move a cutting blade to cut through the portion of the casing adjacent the de-bonded portion of the cement layer; activating a hanger sub-assembly to move a set of slips into contacting engagement with the cut portion of the casing; and running the downhole tool on the downhole conveyance out of the wellbore with the cut portion of the casing engaged with the set of slips.

Removing a tubular from a wellbore

A downhole tool assembly includes a housing, the housing defining one or more formation jetting ports structurally configured to pass fluid outward from the downhole tool assembly, a downhole motor positioned at least partially within the housing, a centrifugal pump coupled to the downhole motor, the centrifugal pump including a shaft coupled to the downhole motor, and one or more blades extending outward from the shaft, and a filtration element in communication with the centrifugal pump, where the filtration element is structurally configured to separate particulate matter from fluid passing through the filtration element.

Downhole cleaning tools and methods for operating the same

A system for collecting subsurface formation data in a petroleum exploration environment includes a drilling tool and a subsurface formation data hub. A drilling tool may include drill pipe, a geophone, a drilling hammer, and a drill bit. The subsurface formation data hub may comprise a seismic data processor and a user interface. The seismic data processor may be operable to drive the drilling hammer at a frequency and an energy, synchronize the geophone to sense seismic vibration at a frequency, and determine subsurface formation properties. The user interface may be operable to display subsurface formation data. A method of collecting subsurface formation data in a petroleum exploration environment may include defining a drilling hammer frequency and energy, synchronizing a geophone to sense seismic vibration at a frequency, generating an impact in the petroleum exploration environment, receiving a returning seismic vibration at the geophone, and collecting subsurface formation data.

Seismic-while-drilling systems and methodology for collecting subsurface formation data

A method of freeing a stuck pipe includes positioning a pipe freeing tool within the wellbore at a location proximate the stuck pipe, the pipe freeing tool including a downhole conveyance; and an arm coupled to the downhole conveyance, and activating the arm of the pipe freeing tool to apply a force to an external surface of the stuck pipe, wherein the force moves the stuck pipe away from a surface of the wellbore and towards a center of the wellbore. Another method of freeing a stuck pipe from a wellbore includes positioning a pipe freeing tool within the wellbore at a location proximate the stuck pipe, the pipe freeing tool including a jack device and a set of wheels coupled to the jack device, and activating the jack device of the pipe freeing tool to apply a force to an external surface of the stuck pipe.

Tools and methods are described to measure dimensions of wellbores. Downhole caliper tools include: a downhole collar; an uphole collar; and a caliper sensor assembly disposed between the downhole collar and the uphole collar. The caliper sensor assembly include: an annular sensor module defining a plurality of radially extending tracks; and a caliper including: a plurality of linear slide arms, each linear slide arm at least partially disposed in the annular sensor module in one of the plurality of radially extending tracks and radially moveable relative to the annular sensor module, each linear slide arm extending from a first end within the annular sensor module to a second end outside the annular sensor module, and a cover extending from the downhole collar to the uphole collar. The annular sensor module can measure the radial position of the plurality of linear slide arms relative to the annular sensor module.

Measuring wellbore cross-sections using downhole caliper tools

Tools and methods are described to measure dimensions of wellbores. Downhole caliper tools include a downhole collar and an uphole collar having a running position and a sensing position. The uphole collar is farther from the downhole collar in the running position than in the sensing position. A caliper sensor assembly includes: a sensor module defining tracks extending parallel to an axis of the caliper tool, the sensor module positioned towards an uphole end of the caliper tool relative to the uphole collar; and a caliper disposed between the downhole collar and the uphole collar including: a flexible mesh extending from the downhole collar to the uphole collar. Movement of the uphole collar from the running position to the sensing position axially compresses and radially expands the flexible mesh. The annular sensor module can measure dimensions of the flexible mesh relative to the axis of the caliper tool.

A non-metallic tubular defines a central flow passage. Actuable rollers are actuable between an extended position and a retracted position. The actuable rollers are pivotally attached to the non-metallic tubular. The actuable rollers centralize the non-metallic tubular when in the extended position. The actuable rollers extend between the non-metallic tubular to an inner surface of the wellbore when in the extended position. A connector is attached to an uphole end of the non-metallic tubular. The connector is configured to attach to a downhole end of a work string.

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Dammam, Saudi Arabia

Bandar S Al-Malki