Abstract: Master valve and cable hanger system for deploying and making electrical connection to an electric submersible pump. A landing for the cable hanger (50) is in the through bore below the valve closure element. The landing has a seal area and a bore transverse to the through bore penetrating into the seal area for allowing electric connection to the pump. The cable hanger has a seal section having longitudinally spaced apart seals engageable with an interior of the seal area, electrical contacts disposed between the seals, and a lockdown profile. Flow ports are arranged to bypass seal area and seal section. A blanking plug (58) is disposed in the transverse bore to seal the seal area prior to insertion of the cable hanger.

Abstract: The present invention relates to the optimization of the processes relating to the activities performed by Onshore Production Rigs simplified with the placing of loads on wheels. The use of the equipment on a single board, called a Compact Peripheral Unit (UCP), considerably reduces the quantity of loads moved in the rig dismounting, transport and mounting (DTM) process. As a result, in addition to optimizing the layout on leases, the DTM costs and time are reduced, together with the risk of accidents.

Abstract: A method and apparatus that provides a quick connection for a hydraulic fracturing plug to a drill string mandrel. In an embodiment, the hydraulic fracturing plug includes one or more pins for connecting to one or more corresponding connection points on the drill string mandrel. The connection points may include a first section and a second section, where the second section may include an end point for receiving a pin on the hydraulic fracturing plug. The connection between the hydraulic fracturing plug and the drill string mandrel may also include a master pin.

Abstract: Systems and methods are disclosed that can include operating a first rig component at a first location, capturing waste energy from the first rig component at the first location, and redirecting the waste energy to another rig component, another location, or a combination thereof. A method of operating a drilling rig can include operations of determining a power usage profile for a rig based on a digital rig plan; predicting waste energy to be generated during execution of the digital rig plan; and modifying the power usage profile for the rig and the digital rig plan based on the predicted waste energy.

Abstract: A method of sealing a subsurface bore comprises: locating a volume of thermite in the bore; locating a volume of alloy in the bore with the thermite; initiating reaction of the thermite to heat the alloy; and bringing the alloy to above the melting point of the alloy whereby the alloy flows and occludes the bore. The thermite may retain its initial form during or following reaction or may partially fluidise. The thermite may react to provide a platform that at least partially occludes the bore. The alloy may flow over a surface of the thermite.

Abstract: A method includes deploying an optical fiber attached to a distributed acoustic sensing (DAS) interrogator in a wellbore, pre-setting gauge length of the DAS interrogator based on an expected measurement signal, interrogating the optical fiber using the DAS interrogator, receiving reflected DAS signals along a length of the optical fiber using the pre-set gauge length, performing an analysis to estimate a location and a magnitude of a strain source associated with the reflected DAS signals, and dynamically adjusting the gauge length for at least a portion of the optical fiber within a pre-defined limit of the DAS interrogator as a function of the estimated location and magnitude of the strain source to enhance sensitivity and to optimize signal-to-noise ratio.

Abstract: There is disclosed an apparatus (115) for detecting and/or measuring a downhole feature (195), such as a fluid/fluid interface, in a well (105). The apparatus (115) comprises a first fluid and/or liquid permeable tube (120). The first tube (120) is porous or (micro)perforated. The apparatus (115) comprises a second fluid and/or liquid impermeable tube (130). The first and second tubes (110, 130) are hollow, and therefore, provide first and second waveguides, respectively.

Abstract: A method and a system for a confined compressive strength (CCS) and an unconfined compressive strength (UCS) for one or more bedding layers. The method may include identifying a depth interval during a drilling operation as a distance between a first depth and a second depth, measuring one or more drill bit responses within the depth interval using a sensor package disposed on the drill bit, identifying one or more torsional bit vibrations, and identifying one or more bedding layers of the formation within the depth interval from the one or more torsional bit vibrations. The method may further include identifying the (CCS) and the (UCS) for each of the one or more bedding layers and identifying a bit wear of the drill bit within each of the one or more bedding layers using the one or more drill bit responses and the one or more torsional bit vibrations.

Abstract: A monitoring system includes a first transducer component configured to couple to a running tool that is configured to place an insert into a housing and a second transducer component configured to couple to the housing. One of the first transducer component or the second transducer component is configured to emit acoustic waves, and the other one of the first transducer component or the second transducer component is configured to output sensor signals indicative of a received portion of the acoustic waves. The monitoring system also includes one or more processors configured to determine that the insert is in a landed position in the housing based on the sensor signals.

Abstract: A drilling rig system and a method for generating electricity with a magnetic drill pipe. The drilling rig has a rig floor, a derrick extending upwards from the rig floor, and a drive mechanism. A stator is fixed in position relative to the rig floor. At least one section of magnetic drill pipe extends through the stator. The drive mechanism is coupled and rotates the magnetic drill pipe. An electrical storage device is electrically coupled to the stator.

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 system including a stabbing guide with a plurality of guide elements, an engaging element, and a linkage assembly that couples the plurality of guide elements to the engaging element, where rotation of the engaging element relative to the plurality of guide elements drives the linkage assembly and, via the linkage assembly, moves the guide elements radially relative to a center axis of the stabbing guide.

Abstract: A hanger system including an expandable liner, an expandable first slip subsystem disposed about the liner, an expandable second slip subsystem disposed about the liner, a seal disposed about the liner and between the first slip subsystem and the second slip subsystem, and an expandable lock ring disposed about the liner and against one of the first slip subsystem or the second slip subsystem. A method for lining a borehole including running a liner system into a borehole, landing the liner system in a liner hanger, expanding the first slip subsystem simultaneously with a portion of the liner, expanding the second slip subsystem simultaneously with another portion of the liner, and sealing the liner to the liner hanger between the first slip subsystem and the second slip subsystem with the seal. A borehole system including a borehole in a subsurface formation, a casing in the borehole, and a liner system.

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.