Abstract: A system and a method for isolating pressure in a wellbore are described. The system includes a body, a first packer, a second packer, and a control assembly. The body couples to a wellhead and casing. The first packer is disposed within the body and fluidically seals the wellbore providing a first sealing boundary. The second packer is disposed within the body above the first packer to fluidically seal the first packer from the atmosphere providing a second sealing boundary. The first packer and the second packer are spatially arranged within the body to define a packer cavity. The control assembly senses a wellbore pressure on a bottom surface of the first packer, senses a packer cavity pressure, and compares the wellbore pressure to the packer cavity pressure to determine that the wellbore is fluidically sealed from the packer cavity.

Abstract: An inflatable multifunctional downhole tool includes a body having an outer shell and a threaded connection at an axial end of the body, at least one pressurized container disposed inside the outer shell, the pressurized container containing compressed gas, a plurality of floatation chambers fluidly connected through connection lines to the at least one pressurized container, a dissolvable plug positioned along each of the connection lines between the floatation chambers and the at least one pressurized container, and a tool sub threadably connected to the threaded connection of the body.

Abstract: A drilling assembly includes a drill string configured to be disposed within a wellbore. The drilling assembly also includes a sub fluidically coupled to the drill string. The sub includes a mandrel fixed to the drill string and defines an external helically undulated surface and a bore configured to flow drilling fluid received from the drill string. The sub includes a sleeve rotationally coupled to and disposed outside the mandrel. The sleeve has an internal helically undulated surface corresponding with the external helically undulated surface of the mandrel to form, with the mandrel, a progressive cavity. The progressive cavity receives fluid from the bore of the mandrel to rotate the sleeve as the drilling fluid flows along the cavity. The sub also includes a valve configured to regulate a flow of the drilling fluid along the bore to direct fluid toward or away from the progressive cavity.

Abstract: An inflatable multifunctional downhole tool includes a body having an outer shell and a threaded connection at an axial end of the body, at least one pressurized container disposed inside the outer shell, the pressurized container containing compressed gas, a plurality of floatation chambers fluidly connected through connection lines to the at least one pressurized container, a dissolvable plug positioned along each of the connection lines between the floatation chambers and the at least one pressurized container, and a tool sub threadably connected to the threaded connection of the body.

Abstract: An apparatus is positioned within a wellbore in a subterranean formation. The apparatus includes a housing, a guide shaft, a follower, multiple underreamer blades, and a hydraulic chamber. The housing defines a track including multiple catch points. The guide shaft is disposed within the housing. The follower protrudes radially outward form the guide shaft and is received by the track. The follower and the track are cooperatively configured to restrict movement of the guide shaft relative to the housing. A rate of flow to the guide shaft is adjusted to adjust a relative position of the guide shaft with respect to the housing until the follower is located at one of the catch points. A pressure within the hydraulic chamber is adjusted to adjust a level of radially outward protrusion of the underreamer blades. The underreamer blades are rotated to cut into the subterranean formation.

Abstract: A downhole autonomous cutting tool and methods are described. The downhole autonomous cutting tool including: a body comprising a hydraulic motor, the body having a generally cylindrical configuration such that the body limits a downhole flow of fluids past the autonomous cutting tool between the autonomous cutting tool and the pipe when the tool is deployed in the pipe; a locking unit attached to the body, the locking unit actuable to engage inner surfaces of the pipe in the wellbore; a sensor module operable to detect interactions between the pipe and walls of the wellbore; an actuation unit attached to the body and rotatable by the hydraulic motor, the actuation unit operable to move a plurality of cutting elements between a running position and a cutting position; and a control unit in electronic communication with the sensor module, the locking unit, and the actuation unit.

Abstract: An incinerator system includes an evaporator tank having a fluid inlet, a steam vent, and an evaporation cavity and a heating assembly having a plurality of heating rods mounted on a rod spacing mechanism and disposed in the evaporation cavity of the evaporator tank. The rod spacing mechanism is configured to move the plurality of heating rods within the evaporation cavity. The incinerator system also includes a sensor system having a plurality of sensors positioned to perform one or more sensor measurements in the evaporation cavity and a programmable logic controller communicatively coupled to the sensor system and the heating assembly. The programmable logic controller is configured to instruct the rod spacing mechanism to move at least one of the plurality of heating rods based on the one or more sensor measurements.

Abstract: A system and a method for isolating pressure in a wellbore are described. The system includes a body, a first packer, a second packer, and a control assembly. The body couples to a wellhead and casing. The first packer is disposed within the body and fluidically seals the wellbore providing a first sealing boundary. The second packer is disposed within the body above the first packer to fluidically seal the first packer from the atmosphere providing a second sealing boundary. The first packer and the second packer are spatially arranged within the body to define a packer cavity. The control assembly senses a wellbore pressure on a bottom surface of the first packer, senses a packer cavity pressure, and compares the wellbore pressure to the packer cavity pressure to determine that the wellbore is fluidically sealed from the packer cavity.

Abstract: Systems and methods include a computer-implemented method for automating product inspection processes. A product is scanned using multiple scans obtained from different angles. A 3D numerical model of the product is generated. The 3D numerical model is compared to 3D product specification models, each numerically defining specifications for a given product in new condition. The 3D numerical model is matched to a matched 3D product specification model. A product type of the product is determined. A report is generated based on comparisons of the 3D numerical model and the matched 3D product specification model. For a new product, the report includes an indication of whether the new product matches design specifications for new products of the product type. For a used product, the report includes an indication of a used condition of the used product relative to a new condition of new products of the product type.

Abstract: Systems and methods include a computer-implemented method for automating product inspection processes. A product is scanned using multiple scans obtained from different angles. A 3D numerical model of the product is generated. The 3D numerical model is compared to 3D product specification models, each numerically defining specifications for a given product in new condition. The 3D numerical model is matched to a matched 3D product specification model. A product type of the product is determined. A report is generated based on comparisons of the 3D numerical model and the matched 3D product specification model. For a new product, the report includes an indication of whether the new product matches design specifications for new products of the product type. For a used product, the report includes an indication of a used condition of the used product relative to a new condition of new products of the product type.

Abstract: An apparatus includes a vessel, a vent valve, a helical heating element, and a control system. The vessel includes an inlet, a solids outlet, and a steam outlet. The helical heating element is configured to generate heat, thereby vaporizing water in an aqueous fluid to produce steam. The helical heating element includes multiple coils, and a spacing between adjacent coils is adjustable. The control system includes multiple sensors and a controller. The controller is configured to transmit a spacing adjustment signal to adjust the spacing between adjacent coils of the helical heating element and transmit a heating adjustment signal to adjust an amount of heat produced by the helical heating element.

Abstract: An offshore spill protection system includes a flare boom configured to connect to an offshore drilling rig. The flare boom is configured to flare at least a portion of hydrocarbons flowed from the offshore drilling rig to the flare boom. A liquid hydrocarbon capture system includes a plate configured to be spatially positioned relative to the flare boom. The plate is sized to collect at least unflared hydrocarbons in a liquid state that flow through the flare boom.

Abstract: An apparatus includes a tubular, pressure sensors, expandable pads, a hydraulic chamber, and a computer system. The apparatus can be run in a wellbore. The apparatus is configured to detect whether the tubular is stuck within the wellbore. In response to determining that the tubular is stuck within the wellbore, the apparatus can determine a local of sticking of the tubular in the wellbore and can transmit a signal to the hydraulic chamber to pressurize one or more of the expandable pads, thereby causing the one or more expandable pads to expand and exert a force necessary to free the tubular.

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: An example pipe cutting tool includes a plurality of actuators and a plurality of cutters. Each of the plurality of cutters is connected to at least one separate actuator of the plurality of actuators. The at least one separate actuator is configured to move the cutter between a pre-deployed and deployed position. The deployed position is beyond the pre-deployed position. The plurality of cutters may include a first and second cutter, with the at least one separate actuator connected to the second cutter moving based, at least in part, on one or more cutting conditions. An example method of cutting a pipe includes extending a first cutter to contact the pipe, cutting at least a portion of the pipe using the first cutter, detecting a cutting condition, extending a second cutter based, at least in part, on the cutting condition, and resuming the cutting using the second cutter.

Abstract: A machine-learning ecosystem includes a correlation module for building at least one prediction model based on at least one data input including at least one input parameter and at least one output parameter, the prediction model relating the output parameter to the input parameter. The correlation module performs at least one threshold check on the prediction model to assess the robustness of the prediction model. The ecosystem further includes a decision module communicatively coupled to the correlation module and receiving the prediction model from the correlation module. Based on a verification check at the decision module, a confirmation, a deferral, or a rejection of the prediction model is sent from the decision module to the correlation module.

Abstract: Systems and methods for drilling optimization of a subterranean well include securing a multifunction sub in line with a tubular string. A nozzle provides a fluid flow path from the central bore through a sidewall of the sub body, the nozzle oriented in a direction so that the fluid flow path directs a wellbore fluid from within the central bore in a direction uphole. A valve system can move between a closed position where the fluid flow path of the nozzle is closed, and at least one open position where the wellbore fluid can pass through the fluid flow path. A control system is operable to receive information and provide a signal to move the valve system. The tubular string is moved into a bore of the subterranean well and information is delivered to the control system to regulate the flow of wellbore fluid through the nozzle.

Abstract: A wearable device includes: at least one communications module; at least one programmable logic controller (PLC) communicatively coupled to the at least one communications module; and at least one toxicity module communicatively coupled to the PLC. The toxicity module includes at least one toxicity detector for detecting at least one toxic gas.

Abstract: Systems and methods for performing operations in a subterranean well with a smart tool include securing the smart tool in line with a tubular string of a well clean out system. The smart tool has a packer, primary slips located downhole of the packer, secondary slips located uphole of the packer, and a circulating valve located uphole of the packer, the circulating value providing a fluid flow path between a central bore of the smart tool and the bore of the subterranean well. The tubular string is moved into the bore of the subterranean well and performing a well clean out operation. The smart tool is releasably anchored in the subterranean well, separating a zone of the bore with the packer, and a well testing operation is performed with the smart tool.

Abstract: Methods and systems for isolating a loss circulation zone of a subterranean formation includes lowering a drill string having a tubular member from a surface into a subterranean well and securing a packer assembly to the tubular member, the packer assembly having an inflatable packer unit and a protective sleeve. The protective sleeve is in an extended position and circumscribes the inflatable packer unit and the inflatable packer unit is in a deflated condition. A stabilizer body is secured to the tubular member downhole of the packer assembly. The stabilizer body is shaped to centralize the packer assembly and direct debris traveling uphole in a direction radially outward of the packer assembly. The protective sleeve is moved from the extended position to a retracted position. The inflatable packer unit is inflated to an inflated condition, forming a seal with an inner diameter surface of the subterranean uphole of the loss circulation zone.