Abstract: Embodiments comprise a method of removing material at a well, involving progressively jetting heat along a helical path to heat a target material for removal. Embodiments of the method comprise material removal from a downhole well element, involving running in a downhole assembly with a downhole heating device comprising a fuel towards a target location. For example, such embodiments provide an alternative method for the removal of wellbore tubulars, using a rapid oxidation process to significantly alter the physical state of the tubular well element and reduce it to an oxide deviate, thereby facilitating an area where a more conventional barrier can be installed in the wellbore.

Abstract: Hydrocarbon wells that include interrogation devices positioned within a fracture and methods of monitoring at least one property of a fracture. The hydrocarbon wells include a wellbore that extends within a subsurface region and a fracture that extends from the wellbore. The hydrocarbon wells also include a plurality of interrogation devices entrained within a carrier fluid and positioned within the fracture and a downhole communication device positioned within the wellbore and proximal the fracture. The methods include flowing the interrogation devices into the fracture and conveying the excitation signal into the fracture. The methods also include receiving the excitation signal with the interrogation devices and generating a plurality of corresponding resultant signals with the interrogation devices.

Abstract: Methods and apparatus for installing a deflector in a primary wellbore and confirming lateral wellbore access. The hydraulic retrieving tool is coupled to the interior of the deflector and introduced into the primary wellbore. The hydraulic retrieving tool comprises a bullnose, a plurality of retractable deflective pads, and a retractable dog. The deflector comprises a deflection surface. The hydraulic retrieving tool is decoupled from the interior of the deflector at a depth in the primary wellbore by retracting the dog and the plurality of deflective pads. The hydraulic retrieving tool is removed from the interior of the deflector. The dog and the plurality of deflective pads on the hydraulic retrieving tool are expanded when the hydraulic retrieving tool is removed from the interior of the deflector. The hydraulic retrieving tool drifts at least a portion of the deflection surface to determine if there is lateral wellbore access.

Abstract: A method for drilling a borehole includes selecting a lower pressure limit and an upper pressure limit for a drilling fluid at a drilling location in the borehole. In addition, the method includes activating a pump to circulate the drilling fluid down a drill string and up an annulus disposed about the drill string. Further, the method includes operating the pump to maintain the drilling fluid at the drilling location at a pressure between the upper and the lower pressure limits. Still further, the method includes deactivating the pump to stop circulating the drilling fluid up the annulus. The method also includes sealing the drilling fluid in the annulus at a selected time after deactivating the pump and maintaining the pressure of the drilling fluid at the drilling location between the lower and the upper pressure limits.

Abstract: The present invention relates to a downhole plug and abandonment system comprising a well tubular structure having an inside and a wall and being arranged in a borehole, a first plug arranged in the well tubular structure for sealing off a lower part of the well tubular structure, a second plug arranged in the well tubular structure at a distance and above the first plug isolating a confined space having a space pressure between the first plug and the second plug, wherein an abandonment device is arranged in the confined space, the abandonment device comprising: a unit configured to increase the space pressure, a sensor configured to measure a temperature and/or a pressure in the confined space, and a device communication module configured to receive an input from the sensor and to communicate signals from the abandonment device. Furthermore, the present invention relates to a downhole plug and abandonment method.

Abstract: A system includes a string disposed in a wellbore, a first valve coupled to the string, the first valve including a sleeve having an engagement profile with a first coded sequence, a second valve coupled to the string, the second valve including a sleeve having an engagement profile with a second coded sequence that differs from the first coded sequence of the first valve, and a first dart flow transportable through the string, the first dart including a collet finger having a first coded sequence configured to restrict the collet finger from matingly engaging the engagement profile of the first valve while permitting the collet finger to engage the engagement profile of the second valve, wherein the first dart actuates the sleeve of the second valve between first and second positions in response to the collet finger of the first dart matingly engaging the engagement profile of the second valve.

Abstract: The present disclosure relates to the technical field of rock mechanics, and in particular to a method for accurately measuring a reopening pressure of hydraulic fracturing induced fracture in a deep borehole. The method includes: pumping a fluid into a sealed inner space of a drilling pipe for energy storage; and opening a valve at a lower end of the drilling pipe such that energy is released from the fluid in the inner space of the drilling pipe under the action of pressure to inject the fluid into a test interval. In the method according to the present disclosure, a fluid is pumped into an inner space of a drilling pipe so that the inner space of the drilling pipe is used as a high-pressure fluid pump to inject the fluid in the inner space of the drilling pipe to the test interval until the closed fracture is reopened.

Abstract: An apparatus housing for a cutting system for radially projecting a flow of heated gas to cut from an internal surface through an external surface of a conduit. The cutting system adapted to be positioned within the conduit comprising an igniter, an extension housing, and an apparatus housing. The apparatus housing has a movable sleeve section and a nozzle assembly. The nozzle assembly comprises a conical head with through holes for evenly dispersing the flow of heated gas. A retainer abuts a diverter. The diverter imposes a 90-degree bend in the direction of the flow of the heated gas to cause the flow of heated gas to move the sleeve section away from the apparatus housing to expose a circumferential diverter gap through which the flow of heated gas projects radially to perform the cutting function. A spindle provides structure for the nozzle assembly and maintains the position of the nozzle assembly in the apparatus housing.

Abstract: Disclosed are a measurement-while-drilling method and device for obtaining a coal seam gas parameter applicable to measurement of a coal seam gas/coal seam methane parameter while drilling and evaluation of gas drainage performance. The invention performs a measurement-while-drilling operation to obtain information about downhole gas and a coal seam, thereby realizing on-site measurement of a coal seam gas parameter while drilling. The measurement-while-drilling device for obtaining a coal seam gas parameter comprises a compartment (17), a pressure sensor (15), a temperature sensor (14), a flow sensor (4), an acoustic emission sensor (16), a monitoring and control module (11), a power module and a communication module. The device is installed between a drill bit (1) and a first drill pipe (20).

Abstract: A downhole tool includes a casing string with a fluid barrier connected therein defining a lower end of a buoyancy chamber. A plug assembly connected in the casing string defines an upper end of the buoyancy chamber. The plug assembly has an outer case with a rupture disc positioned therein configured to block flow and to burst at a predetermined pressure. The rupture disk is removable from a flow path through the outer case upon the flow of fluid therethrough.

Abstract: A poppet valve having an elongated tubular housing and an internal bore. A flange extends within the internal bore supporting an interior tubular member. The interior tubular member itself has a central aperture and an inwardly protruding lip extending into the central aperture. A stem having collet fingers may be partially received in the central aperture of the interior tubular member. The collet fingers have a protrusion which is engagable with the inwardly protruding lip. A biasing element is provided biasing the stem toward a first position. An elastomeric seal may be disposed around the stem. When the stem is in a first position the elastomeric seal forms a fluid tight seal preventing fluid flow through the internal bore, and wherein upon application of a predetermined fluid pressure the stem transitions from the first position to a second position, whereby fluid flow is permitted through the internal bore.

Abstract: A system and method for mounting a Closed-Mouth Power Tong on a Well Servicing Rig in order is disclosed. The power tong can be operated remotely when making up or breaking out connections on oilfield tubing. The system utilizes an assembly that can lift and lower the tong to the appropriate height as required to engage the threads on the tubing. The assembly is connected to the blowout preventer or wellhead with a quick connect system that is adjustable for various angles so that the tong can be utilized in various positions to run tubing into, or out from, the well center unhindered.

Abstract: An apparatus for slip monitor and control includes a body; a plurality of slips; a transmitter for each slip; at least one receiver coupled to the body; and an actuator for each slip configured to move the respective slip vertically relative to the body. A method for slip monitor and control includes obtaining slip positional information for a plurality of slips; determining whether the slip positional information for each of the slips matches criteria; and sending one or more control signals to one or more actuators, each actuator configured to move one of the slips vertically relative to a body. A method for handling a tubular includes actuating a plurality of slips to move vertically relative to a body; engaging the tubular with at least one of the slips; measuring positional data of the plurality of slips; and identifying an offset pipe condition.

Abstract: A cutting element may include a substrate, an upper surface of the substrate including a crest, the crest transitioning into a depressed region, and an ultrahard layer on the upper surface, thereby forming a non-planar interface between the ultrahard layer and the substrate. A top surface of the ultrahard layer includes a cutting crest extending along at least a portion of a diameter of the cutting element, the top surface having a portion extending laterally away from the cutting crest having a lesser height than a peak of the cutting crest.

Abstract: Disclosed are a wellbore inspection system and method for an ultra-deep vertical shaft. The wellbore inspection system includes a wire rope moving system, inspection robots, a visual image acquisition system, a wireless communication module, a central control system, and an image post-processing system of an upper computer. The wire rope moving system includes a surface wire rope guide rail, an underground wire rope guide rail, a surface wire rope moving device, an underground wire rope moving device, and a wire rope. The visual image acquisition system includes explosion-proof cameras. After image information acquired by the explosion-proof cameras is processed by a lower computer, the processed image is transmitted by a wireless image transmission module to the image post-processing system of the upper computer. The central control system is connected to the inspection robots and the wire rope moving system, and the inspection robots are connected to the central control system.

Abstract: An inflatable packer assembly configured to be conveyed within a wellbore. The inflatable packer assembly includes a mandrel having a flowline, a first packer ring slidably connected with the mandrel, a second packer ring fixedly connected with the mandrel, a latching mechanism fluidly connected with the flowline, and an inflatable packer fluidly connected with the flowline. The inflatable packer may be disposed around the mandrel and sealingly connected with the first and second packer rings. The inflatable packer may be operable to expand against a sidewall of the wellbore upon receiving a fluid from the flowline. The latching mechanism may be operable to limit movement of the first packer ring with respect to the mandrel, and permit the movement of the first packer ring with respect to the mandrel upon being actuated by the fluid from the flowline.

Abstract: An apparatus and method for connecting a shaped charge retainer to a shaped charge and connecting that to a charged tube in a perforating gun for use downhole.

Abstract: Method and apparatus for removing a downhole casing from a well on a single trip. A downhole tool assembly is arranged on a work string having a downhole pull tool, a spear tool, motor unit and cutting device. The downhole pull tool is set inside a first casing string and the spear tool, motor unit and cutting device are located inside a second casing string, located through the first casing string. The downhole pull tool and spear tool can be configured to grip the respective casings during cutting of the second casing string. The cut casing section can then be pulled using the downhole pull tool to dislodge the casing section, whereupon via attachment to the spear tool, the cut casing section can be removed from the well. The assembly can be re-set at shallower depths in the event that the cut casing section cannot be dislodged for removal.

Abstract: A firing head assembly for use with a perforating gun is described. The firing head assembly includes a tubular housing, first and second pistons, and a compressible member arranged within a lumen of the tubular housing and positioned between the first and second pistons. According to an aspect, the assembly includes a plurality of upper locking arms and lower locking arms that engage with locking members formed in the tubular housing. The firing head assembly further includes upper and lower shear washers arranged at the second opening of the tubular body, in a sandwich type configuration with respect to the second piston. Pressures within the firing head assembly may be adjusted to activate the firing head assembly to either trigger an explosive reaction or to not trigger the explosive reaction.

Abstract: Discrete wellbore devices, hydrocarbon wells including a downhole communication network and the discrete wellbore devices, and systems and methods including the same are disclosed herein. The discrete wellbore devices include a wellbore tool and a communication device. The wellbore tool is configured to perform a downhole operation within a wellbore conduit that is defined by a wellbore tubular of the hydrocarbon well. The communication device is operatively coupled for movement with the wellbore tool within the wellbore conduit. The communication device is configured to communicate with a downhole communication network that extends along the wellbore tubular via a wireless communication signal. The methods include actively and/or passively detecting a location of the discrete wellbore device within the wellbore conduit. The methods additionally or alternatively include wireless communication between the discrete wellbore device and the downhole communication network.