Abstract: A downhole perforation tool includes an upper sub-assembly configured to couple to a downhole conveyance within a wellbore that is formed from a terranean surface toward a subterranean formation; and a plurality of perforation sub-assemblies. Each perforation sub-assembly includes one or more perforation guns, and one or more ports configured to fluidly couple the wellbore with a bore that extends from the one or more ports to the upper sub-assembly. The downhole perforation tool further includes a main wellbore seal positioned between the upper sub-assembly and the plurality of perforation sub-assemblies and actuatable to anchor the downhole perforation tool to a casing in the wellbore. The downhole perforation tool further includes at least one secondary wellbore seal positioned between adjacent perforation sub-assemblies of the plurality of perforation sub-assemblies.

Abstract: An ultrasonic flow check system for wellbores includes an ultrasonic transceiver installed within an inner surface of a bell nipple attached to a well head of a wellbore at a surface. The bell nipple receives wellbore fluid from a flow line attached to a side surface of the bell nipple. An alarm is installed on a rotary table installed above the bell nipple such that the bell nipple is between the rotary table and the well head. A ultrasonic signal is caused to be transmitted, by the ultrasonic transceiver, into the bell nipple. The ultrasonic signal is reflected by the wellbore fluid within the bell nipple resulting in an ultrasonic response signal. The ultrasonic response signal is caused to be received by the ultrasonic transceiver. Based on the ultrasonic response signal, it is determined whether the fluid level within the bell nipple is static or mobile.

Abstract: An assembly and a method for maintaining and inspecting a wellbore are described. The assembly includes a body. Multiple magnetic wheel sub-assemblies are adjustably coupled to the body. The magnetic wheel sub-assemblies position the body within the wellbore and reposition relative to the body in response to a wellbore narrowing or a wellbore widening. The assembly includes a tool connection coupled to the body. The tool connection couples a well tool to the body. The assembly includes a control sub-assembly to control the magnetic wheel sub-assemblies and operate the well tool within the wellbore. The assembly includes a power sub-assembly to supply power to the control sub-assembly and the well tool. The assembly includes a backup retrieval mechanism coupled to the body. The backup retrieval mechanism couples to a retrieval tool.

Abstract: A first interval inflow control device and a second interval inflow control device are positioned on a production tubing string proximate to a first subterranean interval and a second subterranean interval, respectively. The inflow control devices each include a central bore, a sand screen surrounding an inner tube, a plurality of ports connect the annular space between an inner surface of the sand screen and an outer surface of the inner tube, and a sliding sleeve configured to translate between an open position and closed position. A first shifting tool is configured to engage with and axially translate the sliding sleeve of the first interval inflow control device and a second shifting tool is configured to engage with and axially translate the sliding sleeve of the second interval inflow control device. The second shifting tool has an outer diameter less than the bore of the first interval inflow control device.

Abstract: A system may include a control system disposed on a well surface, a casing disposed in a wellbore, a first electrical wiring coupled to the control system and the casing within a first section of the wellbore, and a second electrical wiring coupled to various flow control devices in a second section of the wellbore. The first section of the wellbore may be disposed at a first predetermined direction that is different than a second predetermined direction of the second section of the wellbore. The system may further include an electrical connector coupled to the first electrical wiring and the second electrical wiring. The electrical connector may include a mechanical receiver that couples with the first electrical wiring, and a stinger assembly coupled with the second electrical wiring and that connects to the mechanical receiver.

Abstract: A system includes an upper section, having a first lateral end. The upper section has upper production tubing configured to be a conduit for production fluids, an upper electrical cable configured to transmit electricity, and a sub-surface safety valve fixed to the upper production tubing. The system further includes a lower section having a second lateral end, lower production tubing configured to be a conduit for the production fluids, a lower electrical cable configured to transmit electricity, an electric submersible pump assembly, and an anchor configured to hold the lower section within the casing string. A stinger assembly is fixed to the first lateral end of the upper section, and a stinger receptacle is fixed to the second lateral end of the lower section. The stinger receptacle is configured to receive the stinger assembly and create an electrical connection between the upper section and the lower section.

Abstract: A wellhead adaptor tool, a system, and a method for installing a shooting nipple on a rotating control device of a wellhead. The wellhead adaptor tool has a body, a first flange, and a second flange. The body has a void. The first flange is coupled to a first portion of the body. The first flange has multiple voids to couple the body to a shooting nipple by multiple fasteners. The second flange is coupled to a second portion of the body. The second flange couples the body to a rotating control device of a wellhead coupled to a wellbore. A clamp is coupled to the second flange to couple the second flange to the rotating control device.

Abstract: A well tool for milling a tubular includes a well tubing disposed in a wellbore and including a circulation fluid pathway through an interior of the well tubing, a first milling tool coupled to the well tubing at a first longitudinal end of the well tubing, a second milling tool coupled to the well tubing at a location longitudinally uphole from the first milling tool, and a third milling tool coupled to the well tubing at a location longitudinally uphole from the second milling tool. Each of the milling tools include a mill bit and a circulation sub fluidly connected to the circulation fluid pathway. The first milling tool mills a first portion of the tubular, the second milling tool mills a second portion of the tubular, and the third milling tool mills a third portion of the tubular.

Abstract: A well system includes a tubular string comprising a plurality of tubular segments and positioned in a wellbore drilled into a subterranean zone, and a landing sub connected to a bottom end of one of the plurality of tubular segments. The landing sub includes a landing sub central bore and a landing sub locking profile on an inner surface of the landing sub central bore. The well system also includes a valve assembly configured to be pumped down the tubular string by fluid flowing in a downhole direction through the tubular string and to land within the landing sub central bore. The valve assembly includes a main body with a valve central bore and a flapper configured to pivot between an open position and a closed position. In the closed positon the flapper seals against a flapper seat and blocks fluid from flowing in an uphole direction through the valve central bore.

Abstract: A system includes production tubing, a telescoping joint, a pump sub, a lock ring, and a crossover. The production tubing provides a hydraulic connection from a surface location to a well. The telescoping joint has a housing and a by-pass hanger having a head. An opening of the housing is larger than the by-pass hanger and smaller than the head and the head is moveably located within the housing. The lock ring is disposed around the by-pass hanger directly beneath the opening of the housing. The lock ring absorbs a compressive force and prevents the by-pass hanger from moving in an upwards direction. The crossover component is hydraulically connected to the production tubing and provides the hydraulic connection to the telescoping joint and the pump sub. The pump sub is located parallel to the telescoping joint, and the pump sub is connected to an electric submersible pump string.

Abstract: A bell nipple includes a downhole end configured to sealingly couple to an uphole-end of a blow-out preventer. An uphole end of the bell nipple includes a first set of threads along an inner surface of the bell nipple. A thread saver is configured to be received by the uphole end. The thread saver is configured to protect the first set of threads from impact. An extension sub is configured to be received by the uphole end. The extension sub includes a downhole end with a second set of threads configured to engage with the first set of threads. An uphole end of the extension sub includes a third set of threads configured receive a well tool.

Abstract: A bell nipple assembly includes a tubular main body and a catcher assembly positioned above the tubular main body that includes an upper opening with a diameter greater than an inner diameter of the tubular main body and one or more inwardly sloping inner surfaces configured to catch fluids falling from the rig floor or from an exterior surface of the drill string and to direct the fluids to the tubular main body. The bell nipple assembly also includes one or more magnets configured to direct a magnetic field toward an interior of the catcher assembly and to attract a metallic object falling within the interior of the catcher assembly towards the inwardly sloping inner surfaces.

Abstract: A first interval inflow control device and a second interval inflow control device are positioned on a production tubing string proximate to a first subterranean interval and a second subterranean interval, respectively. The inflow control devices each include a central bore, a sand screen surrounding an inner tube, a plurality of ports connect the annular space between an inner surface of the sand screen and an outer surface of the inner tube, and a sliding sleeve configured to translate between an open position and closed position. A first shifting tool is configured to engage with and axially translate the sliding sleeve of the first interval inflow control device and a second shifting tool is configured to engage with and axially translate the sliding sleeve of the second interval inflow control device. The second shifting tool has an outer diameter less than the bore of the first interval inflow control device.

Abstract: A wellhead adaptor tool, a system, and a method for installing a shooting nipple on a rotating control device of a wellhead. The wellhead adaptor tool has a body, a first flange, and a second flange. The body has a void. The first flange is coupled to a first portion of the body. The first flange has multiple voids to couple the body to a shooting nipple by multiple fasteners. The second flange is coupled to a second portion of the body. The second flange couples the body to a rotating control device of a wellhead coupled to a wellbore. A clamp is coupled to the second flange to couple the second flange to the rotating control device.

Abstract: An ultrasonic flow check system for wellbores includes an ultrasonic transceiver installed within an inner surface of a bell nipple attached to a well head of a wellbore at a surface. The bell nipple receives wellbore fluid from a flow line attached to a side surface of the bell nipple. An alarm is installed on a rotary table installed above the bell nipple such that the bell nipple is between the rotary table and the well head. A ultrasonic signal is caused to be transmitted, by the ultrasonic transceiver, into the bell nipple. The ultrasonic signal is reflected by the wellbore fluid within the bell nipple resulting in an ultrasonic response signal. The ultrasonic response signal is caused to be received by the ultrasonic transceiver. Based on the ultrasonic response signal, it is determined whether the fluid level within the bell nipple is static or mobile.

Abstract: A bell nipple assembly is attached to an upper end of a blowout preventer stack and has a central passageway fluidically connected to a central bore of the blowout preventer stack. The bell nipple assembly includes upper and lower nipple annular preventers. Closure of the nipple annular preventers forms a closed volume within the central passageway between the upper and lower nipple annular preventers. A coolant injection system selectively injects coolant through a coolant conduit positioned within the closed volume.

Abstract: A bell nipple assembly includes a tubular main body and a catcher assembly positioned above the tubular main body that includes an upper opening with a diameter greater than an inner diameter of the tubular main body and one or more inwardly sloping inner surfaces configured to catch fluids falling from the rig floor or from an exterior surface of the drill string and to direct the fluids to the tubular main body. The bell nipple assembly also includes one or more magnets configured to direct a magnetic field toward an interior of the catcher assembly and to attract a metallic object falling within the interior of the catcher assembly towards the inwardly sloping inner surfaces.

Abstract: A wellbore assembly includes a cable and a wellbore tool. The wellbore tool is coupled to the downhole end of the cable. The wellbore tool includes a housing, one or more sensors, a packer, and a controller. The one or more sensors are coupled to the housing or to the cable or both. The sensors detect one or more parameters of the wellbore tool or the cable or both. The controller is coupled to the housing. The controller is electrically coupled to one or more sensors and is operationally coupled to the packer. The controller determines, with the wellbore tool parted from the cable and based on information received from the one or more sensors, an indication of the wellbore tool in free fall. The controller activates, based on the determination, the packer to expand the packer and set the wellbore tool on a wall of the wellbore.

Abstract: A method of cementing a casing in a wellbore includes lowering the casing in the wellbore. The casing includes multiple pipes each of progressively smaller diameters, and a transition point where a first pipe overlaps a second pipe. The method also includes flowing cement into the casing and deploying, by fluidic pressure, a wiper plug assembly in the casing upstream of the cement to push downhole the cement with the wiper plug assembly. The wiper plug assembly includes a hollow wiper plug and a solid wiper plug releasably coupled to the hollow wiper plug. The deploying includes applying fluidic pressure until the hollow wiper plug reaches and is retained at the transition point and the solid wiper plug is released from the hollow wiper plug to flow downhole in the casing to a downhole end of the casing and push the cement out of the casing.

Abstract: A system may include a control system disposed on a well surface, a casing disposed in a wellbore, a first electrical wiring coupled to the control system and the casing within a first section of the wellbore, and a second electrical wiring coupled to various flow control devices in a second section of the wellbore. The first section of the wellbore may be disposed at a first predetermined direction that is different than a second predetermined direction of the second section of the wellbore. The system may further include an electrical connector coupled to the first electrical wiring and the second electrical wiring. The electrical connector may include a mechanical receiver that couples with the first electrical wiring, and a stinger assembly coupled with the second electrical wiring and that connects to the mechanical receiver.