Abstract: A method includes coupling a strain gauge to a tubular member, and positioning the tubular member in the wellbore such that the tubular member is placed under bending stress by a curvature or deviation in the wellbore. The method also includes measuring bend on the tubular member with the strain gauge in at least one plane and determining one or more of the magnitude or orientation of the curvature of the wellbore based on an output of the strain gauge.

Abstract: A diverter assembly may include a diverter body assembly. The diverter body assembly may also include a diverter body, the diverter body fluidly coupled to the annulus of a wellbore via a casing or riser, and the diverter body including one or more diverter outlet ports fluidly coupled to the annulus of the wellbore. The diverter body assembly may also include an upper packer assembly. The upper packer assembly may include a packer sleeve, the packer sleeve mechanically coupled to the diverter body. The packer sleeve may include one or more breach lock slots. The upper packer assembly may also include an upper packer body having one or more packer breach lock tabs engaged with the breach lock slots of the packer sleeve. The diverter assembly may also include a diverter support housing, the diverter support housing coupled to the diverter body assembly.

Abstract: A downhole tool having a mechanically adjustable bend angle from the surface and method for actuation of the tool. The tool includes a knuckled joint between upper and lower housing assemblies and tapered setting ring upon which the lower housing assembly bears. As the setting ring is rotated with respect to the upper housing assembly, the lower assembly is tilted. A spline sub for connection to a drill string is included, which, upon a certain weigh on bit, axially moves within the tool housing to engage the tapered setting ring and force shoes radially outward to engage the formation and hold the tool stationary. The drill string is then rotated to rotate the setting ring, and thereby alter the tool bend angle. Toggles hold the setting ring fixed to the upper housing to maintain a given bend angle during drilling operations.

Abstract: A method that includes deploying an acoustic caliper tool in a borehole, the tool having several axially-spaced acoustic transceivers; obtaining acoustic signal reflection measurements for the transceivers; estimating a distance-to-boundary value for the transceivers based on reflection measurements; calculating a tool inclination angle based on the distance-to-boundary values; and deriving a correction value based on the angle. A system that includes an acoustic caliper tool having several axially-spaced acoustic transceivers to obtain reflection measurements; at least one processor; and at least one memory in communication with the processor, the memory storing instructions that cause the processor to: receive the acoustic signal reflection measurements; estimate a distance-to-boundary value for the transceivers based on the reflection measurements; calculate a tool inclination angle based on the distance-to-boundary values; and derive a correction value based on the angle.

Abstract: The present invention relates to a downhole annular barrier to be expanded in an annulus between a well tubular structure and a wall of a borehole or another well tubular structure downhole in order to provide zone isolation between a first zone having a first pressure and a second zone having a second pressure of the borehole, the annular barrier comprising a tubular part adapted to be mounted as part of the well tubular structure, the tubular part having an outer face and an inside, an expandable metal sleeve surrounding the tubular part and having an inner sleeve face facing the tubular part and an outer sleeve face facing the wall of the borehole, each end of the expandable metal sleeve being connected with the tubular part, and an annular space between the inner sleeve face of the expandable metal sleeve and the tubular part, a first opening in fluid communication with the inside, a second opening in fluid communication with the annular space, a bore having a bore extension and comprising a first bore pa

Abstract: A bottom hole assembly supports a diverter for landing in an existing multilateral junction. Once landed set down weight allows the BHA to progress through the diverter opening into a main bore, for example. A protective sleeve for the seal assembly lands on a shoulder above the targeted seal bore. Further advancing of the BHA moves the seal assembly out of the protective sleeve that has landed on the shoulder by the polished bore. Once the seals are in position in the bore a treatment can be accomplished. On picking up the seal assembly retracts into the protective sleeve and the BHA engages the diverter to bring the BHA and the diverter out of the borehole at the same time.

Abstract: An adjustable tubular string nose uses axially relatively movable wedge segments to form a variable diameter ring shape using technology described in U.S. Pat. No. 7,128,146 in another context. The nose has a seat around a passage therethrough. After insertion of the nose into a first bore, typically a main bore, the nose is retracted out of the main bore and pressure against a seated bore in the nose expands the nose radially to a degree where re-entry into the main bore is precluded but entry into a lateral bore is still possible. The string advances onto a lateral no-go. This signals surface personnel to pick up and raise pressure to blow the seated ball through the seat to again open the passage in the nose. A seal stack behind the nose in advanced into a lateral seal bore and the treatment can then commence.

Abstract: Devices, systems, and processes are provided for retorting and extracting hydrocarbons from oil shale. A heat transfer fluid includes at least one liquefied petroleum gas (LPG) component such as, for example, propane or butane. The heat transfer fluid moves through a heat delivery loop to retort oil shale, thereby facilitating the production of recoverable hydrocarbons. While the heat transfer fluid moves through the heat delivery loop, cracking of a portion of the heat transfer fluid may produce various hydrocarbon materials that may be provided to a product stream.

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.

Abstract: A wet connection system has pressure compensation operative when running in and thermal effects compensation active in the duration between running in and supporting a bottom hole assembly and hooking up a production string having a mating upper part of the wet connect to the lower part of the wet connect already in the hole. The thermal compensation system is then defeated by locking a floating piston so that applied pressure in a given control line will be used to operate an associated tool connected to that control line. Multiple control lines each similarly compensated are envisioned. The pressure compensation system comes out of the hole with the running tool for the bottom hole assembly.

Abstract: An earth-boring tool includes a blade located on a body of the earth-boring tool with a pocket formed in an exposed outer surface of the blade. A formation-engaging structure is affixed within the pocket. The formation-engaging structure includes a distal end, a proximal end and a tapered sidewall therebetween. The distal end of the formation-engaging structure includes a formation-engaging surface. The tapered sidewall engages a tapered inner surface of the pocket. The tapered sidewall of the formation-engaging structure and the tapered inner surface of the pocket are each sized and configured to provide an interference fit between the formation-engaging structure and the pocket of the blade. In additional embodiments, instead of retention by interference fit, the formation-engaging structure is retained to the blade by a threaded fastener threaded within a tapped bore extending through the blade. The threaded fastener is received within a receiving formation of the formation-engaging structure.

Abstract: A rotary impact tool assembled in a drill string transfers torque and axial force between two components. The rotary impact tool includes an anvil and a hammer axially aligned with engaging faces. At a threshold torque, the hammer disengages from the anvil and rotates freely until a biasing element displaces the hammer to reengage the anvil. Kinetic energy stored in the hammer is transferred to the anvil when the faces of the hammer and anvil reengage. This provides an impact to the anvil and any attached component. The tool can accommodate misalignment of the attached components.

Abstract: A downhole control method for use in a wellbore that includes deploying a stand-alone power source and a stand-alone hydraulic reservoir downhole; powering a downhole controller using the stand-alone power source; measuring a downhole fluid parameter; and actuating an inflow control device, using the stand-alone hydraulic reservoir and the downhole controller, based on the measured downhole fluid parameter. In one aspect, the stand-alone power source is selected from the group consisting of a battery and a downhole power generator. In another aspect, the stand-alone hydraulic reservoir, the downhole controller, the stand-alone power source, and the inflow control device comprise a remotely-powered, open-hole completion system.

Abstract: An oilfield assembly including a pump in fluid communication with a string of coiled tubing on a tubing reel through a coiled tubing swivel assembly, includes a fluid inlet segment coupled to a swivel body having a central axis, and a rotatable hollow shaft having a portion that extends axially within the swivel body, wherein the fluid inlet segment, swivel body and hollow rotatable shaft form a conduit for passage of a pumped substance to the tubing reel from the pump. The rotatable shaft includes a first end attachable to the tubing reel, and a distal second end, at least part of which is configured to engage a corresponding indentation in the body, thereby preventing direct contact between the distal end of the shaft and the pumped substance.

Abstract: A method of testing mechanical properties of an earth formation can include disposing a probe in a wellbore, impacting the probe against a wall of the wellbore, and measuring a parameter related to at least one of a displacement, displacement rate, strain, and strain rate, of at least one of the probe and the formation. Another method can include disposing a probe and a known material in a wellbore, and after the disposing, penetrating the known material with the probe. Another method can include disposing a probe in a wellbore, measuring a displacement of the probe into a wall of the wellbore while measuring a load applied to the probe, and applying fluid pressure to the formation via the probe.

Abstract: A production casing string including a plurality of propellant sleeves positioned on an exterior of the production casing string, and each propellant sleeve includes a firing mechanism and a firing sleeve for selectively covering and uncovering the firing mechanism. The casing string also includes an identifiable marker associated with each propellant sleeve and at least one selective bi-directional valve assembly associated with each propellant sleeve.

Abstract: A vertical pumping unit for pumping oil from a well is disclosed including a vertically oriented frame, an electrically powered motor, a flexible beam connected on a first end to pumping machinery lowered into an oil well hole, a counterweight connected to a second end of the flexible beam and suspended by the frame, and a drum-type deceleration roller cone. The roller cone includes an input shaft receiving torque from the motor, internal reduction machinery, and an output drum translating the flexible beam back and forth to activate a pumping action.

Abstract: A plug is engageable with a ball for seating in a tubular having an internal profile. The plug's body has a bore with a seat. Blocks disposed on the body are temporarily held in a retracted condition, but the blocks are biased outward to an expanded condition for engaging inside the tubular. The plug sets in the tubular with the blocks released from the retracted condition to the expanded condition. With the ball dropped downhole, the seat engages the ball so that fluid pressure is sealed from uphole to downhole through the bore. With applied fluid pressure against the seated ball, the plug can move through the tubular until the blocks seat in the internal profile of the tubing, sliding sleeve, or other component. A seal on the plug can then seal inside the tubular while the blocks seat in the profile and applied pressure pushes on the seated ball on the plug's mandrel.

Abstract: An apparatus for activating a wellbore tool may include a first sub, gas transfer sub, and a second sub. The first sub has an igniter that generates a flame output that ignites a power charge. The power charge generates a high pressure gas when ignited by the flame output. The gas transfer sub has a first end receiving a portion of the power charge, a longitudinal bore, and a plurality of flow passages radiating from the longitudinal bore. The flow passages provide fluid communication between the longitudinal bore and the first sub. The second sub includes a shaft having a first end connectable with the gas transfer sub.

Abstract: A natural gas hydrate drilling simulation device, includes a hydrate rock core simulation system, a drilling system, a drilling fluid injection system and a drilling fluid treatment system. The hydrate rock core simulation system includes a hydrate formation simulation wellbore, an artificial rock core, a water bath jacket and low temperature water bath. The drilling system includes a bracket, a high pressure rotary connecting device, a hydraulic device and a drilling device. The drilling fluid injection system includes a mud tank, a drilling fluid flowmeter, mud pumps and an overflow valve. The drilling fluid treatment system includes a high pressure sand remover, a back pressure and overflow control system, a gas-liquid separator, a dyer, a gas flowmeter, a liquid flowmeter and a mud treatment tank. This natural gas hydrate drilling simulation device performs simulation experiments under a variety of downhole working condition environments.