Abstract: A wellbore depth instrument (WDI) for measuring wellbore depths along a wellbore, acting as an odometer. In one embodiment, the WDI may be mounted onto a downhole tool-string deployed by a pipe, coil, e-line, or slickline. Further, the WDI may comprise two independently suspended wheels of fixed diameter with respective internal electronic packages that each may record in memory rotations of their respective wheels and frequencies of those rotations along the wellbore. Such recordings may allow for accurate determination and characterization of tool-string dynamics (e.g., tool-string speed, direction, stick slip, creep and hold-ups) as well as absolute and relative tool-string position along a wellbore (i.e., wellbore depth).

Abstract: A method may include determining a stuck pipe event in a well operation for a well. The method may further include obtaining well data regarding the well operation and stuck pipe data regarding the stuck pipe event. The method may further include determining, using the well data and the stuck pipe data, a diagnostic action for the stuck pipe event. The method may further include transmitting a command to a stuck pipe adapter to perform the diagnostic action. The stuck pipe adapter may be a substitute adapter for a drill string or a work string in the well. The method may further include obtaining diagnostic data regarding the stuck pipe event in response to the stuck pipe adapter performing the diagnostic action. The method may further include determining a predicted location in the well of the stuck pipe event based on the diagnostic data and a machine-learning algorithm.

Abstract: A water separation system includes a production control valve fluidly connected to a production tubing and positioned at an uphole end of the production tubing at a well head of a well site, a production fluid pathway between the production control valve and a water separator, an injection control valve fluidly connected to an injection tubing and positioned at an uphole end of the injection tubing at the well head, and an injection fluid pathway between the injection control valve and the water separator. The water separator is positioned at the well site and is fluidly connected to the production fluid pathway and the injection fluid pathway. The water separator separates water from the production fluid and directs the separated water to the injection fluid pathway. An output fluid pathway fluidly connects to the water separator to direct the production fluid out of the water separator.

Abstract: A technique enables easy quantitative evaluation for drilling operations. A civil engineering work data processing device includes a positioning data receiving unit, a three-dimensional model estimating unit, and a drilled depth calculator. The positioning data receiving unit receives positioning data obtained by performing positioning using laser light, on a drilling rod. The three-dimensional model estimating unit estimates a three-dimensional model of the drilling rod, on the basis of the positioning data. The drilled depth calculator calculates a depth of a hole generated in a civil engineering work target by the drilling rod, on the basis of the estimated three-dimensional model.

Abstract: A system having an instrumented cutter of a drill bit including an on-cutter sensor for monitoring drilling performance metrics while performing drilling operations based on offset well data and a computing device is disclosed. The computing device executes a model development system configured to use the drilling performance metrics, surface drilling parameters, and characteristics of the instrumented cutter to train a machine learning (ML) model. The trained ML model is used to optimize drilling parameters and predict drill bit performance in a current well.

Abstract: A system for automatic in-situ gas lifting of fluid in a multilateral well may include a plurality of downhole sensors arranged to periodically capture pressure data associated with the multilateral well is disclosed. The system may include a processor operatively connected to the downhole sensors and configured to dynamically determine a pressure gradient value associated with the multilateral well based on the periodically captured pressure data. The system may include a first inflow control valve (ICV) operatively connected to the processor and placed within a first lateral to automatically control a flow of a gas from a downhole natural gas source into the multilateral well based on the dynamically determined pressure gradient, and to cause a lift of the fluid received from a second lateral within the well when the ICV is open.

Abstract: An automated drilling-fluid additive system and method for on-site real-time analysis and additive treatment of drilling fluid to be injected into a well. The drilling fluid includes returned drilling fluid intended to be re-used, which has a variety of viscosity and other qualities resulting from its various preceding use. The target drilling fluid will have a variety of viscosity and other qualities depending upon and changing with various phases of drilling operations and various conditions encountered. The drilling fluid is analyzed in real time as it flows into the automated drilling-fluid additive system, and various additives are added to and thoroughly blended with the drilling fluid as needed to achieve the desired result. The blended drilling fluid is discharged from the automated drilling-fluid additive system in the proper condition for injection into a well.

Abstract: A downhole displacement impact method and an impact drilling tool are provided, which relates to the field of drilling tools. The downhole displacement impact drilling tool includes a flow passing sleeve, a first main shaft, an impact-bearing seat, and a second main shaft that are all formed by annular structures and are connected in sequence from top to bottom. A vibration sleeve, a vibration starting seat, and an impact head are connected in sequence from top to bottom on the impact-bearing seat. The vibration sleeve is connected and fixed to the impact head through a connecting sleeve. The vibration starting seat synchronously rotates with the impact-bearing seat through a spline connection therebetween. The vibration starting seat generates an up-down periodic displacement along an axial direction of the vibration starting seat during rotating.

Abstract: A downhole assembly includes a disintegrable article, which contains a polymer matrix comprising a polymer having an oxygen content of about 2 wt % to about 30 wt %; an energetic material configured to generate heat upon activation to facilitate a chemical decomposition of the polymer; and at least one of a reinforcing fiber or a filler. The disintegrable article is disintegrated by disposing the downhole assembly in a downhole environment; performing a downhole operation; exposing the polymer in the polymer matrix to the generated heat to chemically decompose the polymer producing a decomposed product containing a small molecule in a supercritical state; and disintegrating the disintegrable article with the small molecule in the supercritical state.

Abstract: A horseshoe lateral is drilled having two substantially parallel lateral sections connected with a horseshoe section. The horseshoe section may be obtained by steering a drill bit within a first plane over an in-plane angle of about 180°, and then continuing drilling along a straight path. A second lateral well system may drilled from a second borehole section, to create an additional lateral section interdigitally arranged between the previous two substantially parallel lateral sections.

Abstract: Cutting elements include a carbonate diamond-bonded body that is sintered under HPHT conditions in the presence of a carbonate material, where the body includes a matrix phase of intercrystalline bonded diamond with interstitial regions including the carbonate material, where the diamond-bonded body is sintered without a substrate. A matrix casting is formed and mechanically coupled to the body after the body is sintered, and a portion of the body surface is exposed along a surface of the matrix casting. The exposed body surface is thereafter intentionally treated to induce a compressive residual surface stress that is greater than a remaining portion of the body. The compressive residual surface stress is less than about 500 MPa, and from about 100 to 500 MPa, and a remaining region the body may have a residual stress of less than about 300 MPa, and less than about 100 MPa.

Abstract: A downhole tool comprising magnesium is placed in a well bore in a subterranean formation for performance of a downhole operation. After performance of the downhole operation, rather than mechanically retrieving or removing the tool, at least a portion of the magnesium in the downhole tool is dissolved by contacting the downhole tool with an aqueous ammonium chloride solution.

Abstract: A wellbore completion apparatus includes an engager having an engageable surface configured for becoming engaged to a surface of the wellbore is disclosed. The apparatus is configurable in an engagement-ready state and an engagement state. Actuation of the apparatus such that it transitions from the engagement-ready state to the engagement state is with effect that the engageable surface becomes engaged to the wellbore surface. In the engagement-ready state, the engager can include a first free end and a second free end, and the transitioning to the engagement steady is effected in response to relative displacement between the first and second free ends. In the engagement state, the engager can be configured in a loop configuration.

Abstract: A reactive torque automatic balancing device for a screw drilling tool includes an upper joint (1); a core cylinder (9) having an inner chamber in communication with the screw drilling tool (305) located downstream, so that drilling fluid from the inner chamber of the upper joint (1) flows to the screw drilling tool (305) through the inner chamber of the core cylinder (9) to allow the screw drilling tool to perform drilling; a lower joint (16) fixedly arranged at a lower end of the core cylinder (9); and an automatic balancing assembly, which is arranged between an outer wall of the core cylinder (9) and an inner wall of the upper joint (1), and driven by hydraulic pressure generated by a part of the drilling fluid flowing through the inner chamber of the upper joint (1).

Abstract: The hydrocarbon wells include a radioactive tracer system, a production conduit, a lift gas supply conduit, a lift gas supply system configured to provide a lift gas stream to the lift gas supply conduit, and one or more gas lift valves each being configured to selectively permit lift gas to enter the production conduit and mix with reservoir liquid therein to generate a produced fluid stream. The radioactive tracer system is configured to inject a radioactive tracer into the lift gas stream and to detect the radioactive tracer within the produced fluid stream. The methods include injecting the radioactive tracer into the lift gas stream, flowing the radioactive tracer through an open gas lift valve into the production conduit, mixing the radioactive tracer with the reservoir liquid to generate a tracer-marked liquid band within the produced fluid stream, and detecting radiation from the tracer-marked liquid band.

Abstract: A formation evaluating system including a sonic sensor device attached to a drill string adjacent to a bit includes a sonic source and a first sonic receiver aligned adjacent to the sonic source, and a second sonic receiver aligned with a horizontal offset X. Three kind of two-way trip times are measured: from the sonic source to a) the first receiver after a reflection at the borehole wall, b) the first receiver after propagation in a layer below the borehole wall, an invaded zone, and a reflection at an interface below the borehole wall, and c) the second receiver after oblique propagations in the invaded zone and a reflection at the interface. After determining a sonic speed in the drilling mud and a sonic speed in a matrix of the invaded zone, a porosity and a thickness of the invaded zone are estimated based on a time average equation.

Abstract: In at least one embodiment, a control system may include a processor coupled to the database. The control system may include a memory accessible to the processor and storing instructions executable by the processor for: during slide drilling, detecting an increase to a first differential pressure (?P) that is greater than a first threshold pressure. In at least one embodiment, the control system may responsive to detecting the first ?P, determining a time duration for which the first ?P exceeds the first threshold pressure. In at least one embodiment, the control system may responsive to the first ?P exceeding the first threshold pressure for less than a first threshold time, continuing the slide drilling without modifying a drilling parameter.

Abstract: The present disclosure relates to the technical field of multilateral well drilling, and proposes an integrated whipstock. The integrated whipstock includes a setting body; a whipstock body, provided on the setting body and having a whipstock face; a window mill, located at one side of the whipstock face; and screws, connecting the whipstock body to the window mill, where the whipstock face is provided with slots, and the window mill is provided with protrusions, and the protrusions are configured to be snapped into the slots. With the above technical solution, the present disclosure solves the technical problems in the related art that the integrated whipstock cannot go downhole smoothly and the screws are not easy to be sheared during the setting process.

Abstract: Pump assemblies for subsurface fluid reservoirs include an upper portion connected to a fluid conduit extending to the surface, a lower portion connected to the upper portion and in fluid communication with a fluid reservoir of the wellbore, and a plunger assembly movably located within the upper and lower portion of the pump assembly. As the fluid pressure within the production tubing string, fluidly isolated from the inner tubing string, increases, fluid is forced into the pump assembly moving the plunger assembly upward to draw fluid into the lower portion of the pump and forces fluid out of the upper portion of the pump assembly and into the inner tubing string. As the fluid pressure within the production tubing string decreases, movement of the plunger assembly descends displacing fluid from the lower portion of the pump assembly into the upper portion through a fluid passageway extending through the plunger assembly.

Abstract: System and methods for delivering objects formed of a solid material into a circulation fluid of a subterranean well include a volume transfer container. The volume transfer container has an inlet port, an outlet port, and a charge access opening sized to provide for the filling of the volume transfer container with the objects. A discharge line extends from a pump assembly to the volume transfer container. A transfer line extends from the volume transfer container to the drilling assembly, providing a fluid flow path from the volume transfer container to the drilling assembly that is free of any pump.