Abstract: A protective tubular is run downhole into a wellbore in a subterranean formation. A non-metallic tubular is disposed within the protective tubular. The non-metallic tubular includes an adapter. The adapter includes a spring-loaded latch, a ball seat, a shear pin, and a ball catcher. While intact, the shear pin holds a position of the non-metallic tubular relative to the protective tubular. A ball is used to shear the shear pin of the adapter, thereby allowing the non-metallic tubular to move relative to the protective tubular. Pressure is applied to the ball to move the non-metallic tubular relative to the protective tubular. The non-metallic tubular is coupled to the protective tubular using the spring-loaded latch of the adapter. Pressure is applied to the ball to shear the ball seat of the adapter. A fluid is flowed into the non-metallic tubular through an opening defined by the adapter.

Abstract: 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.

Abstract: Logging electronics are housed within a tool housing. A first coolant reservoir is housed within the tool housing. A second coolant reservoir is housed within the tool housing. A tubing length defines a coolant passage. The tubing length fluidically connects the first coolant reservoir to the second coolant reservoir. A portion of the tubing length is adjacent to the logging electronics. A flow regulator is within the coolant passage. The flow regulator regulates a coolant flow between the first coolant reservoir and the second coolant reservoir.

Abstract: A protective tubular is run downhole into a wellbore in a subterranean formation. A non-metallic tubular is disposed within the protective tubular. The non-metallic tubular includes an adapter. The adapter includes a spring-loaded latch, a ball seat, a shear pin, and a ball catcher. While intact, the shear pin holds a position of the non-metallic tubular relative to the protective tubular. A ball is used to shear the shear pin of the adapter, thereby allowing the non-metallic tubular to move relative to the protective tubular. Pressure is applied to the ball to move the non-metallic tubular relative to the protective tubular. The non-metallic tubular is coupled to the protective tubular using the spring-loaded latch of the adapter. Pressure is applied to the ball to shear the ball seat of the adapter. A fluid is flowed into the non-metallic tubular through an opening defined by the adapter.

Abstract: 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.

Abstract: A protective tubular is run downhole into a wellbore in a subterranean formation. A non-metallic tubular is disposed within the protective tubular. The non-metallic tubular includes an adapter. The adapter includes a spring-loaded latch, a ball seat, a shear pin, and a ball catcher. While intact, the shear pin holds a position of the non-metallic tubular relative to the protective tubular. A ball is used to shear the shear pin of the adapter, thereby allowing the non-metallic tubular to move relative to the protective tubular. Pressure is applied to the ball to move the non-metallic tubular relative to the protective tubular. The non-metallic tubular is coupled to the protective tubular using the spring-loaded latch of the adapter. Pressure is applied to the ball to shear the ball seat of the adapter. A fluid is flowed into the non-metallic tubular through an opening defined by the adapter.

Abstract: 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.

Abstract: A protective tubular is run downhole into a wellbore in a subterranean formation. A non-metallic tubular is disposed within the protective tubular. The non-metallic tubular includes an adapter. The adapter includes a spring-loaded latch, a ball seat, a shear pin, and a ball catcher. While intact, the shear pin holds a position of the non-metallic tubular relative to the protective tubular. A ball is used to shear the shear pin of the adapter, thereby allowing the non-metallic tubular to move relative to the protective tubular. Pressure is applied to the ball to move the non-metallic tubular relative to the protective tubular. The non-metallic tubular is coupled to the protective tubular using the spring-loaded latch of the adapter. Pressure is applied to the ball to shear the ball seat of the adapter. A fluid is flowed into the non-metallic tubular through an opening defined by the adapter.

Abstract: A downhole fluid sampling system includes a tool body to attach to a tubing string, and multiple probe pads having a curved shape and disposed circumferentially about a section of the tool body in a helical gear pattern about a central longitudinal axis of the tool body. Each probe pad includes probes on an external surface of the respective probe pad, and each probe can contact and engage a wall of a wellbore and receive a flow of formation fluid from the wall of the wellbore. An outer surface of the tool body includes multiple channels disposed circumferentially about the section of the tool body and between the probe pads. The channels direct fluid flow along the tool body.

Abstract: 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.

Abstract: A downhole fluid sampling system includes a tool body to attach to a tubing string, and multiple probe pads having a curved shape and disposed circumferentially about a section of the tool body in a helical gear pattern about a central longitudinal axis of the tool body. Each probe pad includes probes on an external surface of the respective probe pad, and each probe can contact and engage a wall of a wellbore and receive a flow of formation fluid from the wall of the wellbore. An outer surface of the tool body includes multiple channels disposed circumferentially about the section of the tool body and between the probe pads. The channels direct fluid flow along the tool body.

Abstract: An example method includes deploying an example system in a vicinity of the lost circulation zone. The example system includes a stop lost-circulation balloon (SLCB) tool. An example SLCB tool includes an inflatable balloon and a tubing string including a fluid conduit. The string is in fluid connection with the balloon. The method includes deploying, from the SLCB tool, the balloon and forcing slurry into the balloon to cause at least part of the balloon containing the slurry into the fracture. The method includes allowing the slurry to set for a period of time to produce a solid. The method includes drilling through the solid in the balloon in the wellbore, leaving the solid in the fracture.

Abstract: An example method includes deploying an example system in a vicinity of the lost circulation zone. The example system includes a stop lost-circulation balloon (SLCB) tool. An example SLCB tool includes an inflatable balloon and a tubing string including a fluid conduit. The string is in fluid connection with the balloon. The method includes deploying, from the SLCB tool, the balloon and forcing slurry into the balloon to cause at least part of the balloon containing the slurry into the fracture. The method includes allowing the slurry to set for a period of time to produce a solid. The method includes drilling through the solid in the balloon in the wellbore, leaving the solid in the fracture.

Abstract: Logging electronics are housed within a tool housing. A first coolant reservoir is housed within the tool housing. A second coolant reservoir is housed within the tool housing. A tubing length defines a coolant passage. The tubing length fluidically connects the first coolant reservoir to the second coolant reservoir. A portion of the tubing length is adjacent to the logging electronics. A flow regulator is within the coolant passage. The flow regulator regulates a coolant flow between the first coolant reservoir and the second coolant reservoir.

Abstract: A well testing tool mounted on a drill string is positioned within a zone of interest in a wellbore. An RFID tag with a density between 400 and 500 pounds per square foot is dropped through the drill string to activate the well testing tool. An uphole packer positioned at an uphole end of the well testing tool and a downhole packer positioned at a downhole end of the well testing tool are expanded to isolate a portion of the zone of interest between the expanded uphole packer and the expanded downhole packer. A three-way valve positioned between the uphole packer and the downhole packer is adjusted to allow fluid to flow from the isolated portion of the zone of interest into the drill string. One or more sensors within the well testing tool are activated.

Abstract: Testing a fluid in a wellbore with a well testing tool carried on a well testing string includes activating a first selectively controllable longitudinal valve and a second selectively controllable longitudinal valve with a communication module. A first and second packer of the well testing tool engages an inner wall of the wellbore to define a zone of interest between the first packer and the second packer. The communication module further activates a selectively controllable radial valve positioned between the first packer and the second packer to flow fluid between the central bore and the annulus formed between the first packer and the second packer, a fluid sample flows from the annulus between the first packer and the second packer through the testing string to a tophole facility.

Abstract: A well testing tool mounted on a drill string is positioned within a zone of interest in a wellbore. An RFID tag with a density between 400 and 500 pounds per square foot is dropped through the drill string to activate the well testing tool. An uphole packer positioned at an uphole end of the well testing tool and a downhole packer positioned at a downhole end of the well testing tool are expanded to isolate a portion of the zone of interest between the expanded uphole packer and the expanded downhole packer. A three-way valve positioned between the uphole packer and the downhole packer is adjusted to allow fluid to flow from the isolated portion of the zone of interest into the drill string. One or more sensors within the well testing tool are activated.