Abstract: A method of designing a cement slurry may include: (a) providing cement design requirements for the cement slurry wherein the cement design requirements comprise at least one cement performance property selected from the group consisting of compressive strength, tensile strength, cohesion, friction angle, Young's modulus, Poisson's ratio, and any combination thereof; (b) providing a virtual cement slurry recipe representing at least water and a concentration thereof and one or more cementitious materials and a concentration thereof; (c) inputting at least a well condition and the virtual cement slurry into a cement performance property model; (d) predicting performance properties for the virtual cement slurry recipe using at least the cement performance property model, wherein the performance properties comprise at least one of compressive strength, tensile strength, cohesion, friction angle, Young's modulus, and Poisson's ratio; (e) comparing the predicted performance properties to the cement design requirem

Abstract: Systems and methods for efficiently managing bulk material are provided. The disclosure is directed to a portable support structure used to receive one or more portable containers of bulk material and output bulk material from the containers directly into the blender hopper. The portable support structure may include a frame for receiving and holding the one or more portable bulk material containers in an elevated position proximate the blender hopper, as well as one or more gravity feed outlets for routing the bulk material from the containers directly into the blender hopper. In some embodiments, the portable support structure may be transported to the well site on a trailer, unloaded from the trailer, and positioned proximate the blender unit. In other embodiments, the portable support structure may be a mobile support structure that is integrated into a trailer unit.

Abstract: Various well-perforating systems and methods are disclosed incorporating a self-shunting detonator. The detonator may include an electrically-conductive detonator body. A resistor initiator inside the detonator body includes first and second leads. A grounding element inside the detonator body couples the detonator body to the first lead. An electrically-conductive clip coupled to the second lead includes an arm biased to electrical contact with an external surface of the detonator body to shunt the detonator. The arm is moveable away from the detonator body to un-shunt the detonator, such as automatically in response to insertion into a detonator housing.

Abstract: A gaseous fuel supply for an engine at a wellbore can be regulated using a control system. The control system can include a processing device communicatively coupled to one or more sensors to receive a fuel property measurement from the one or more sensors. The fuel property measurement can correspond to a first fuel source of the engine that can be used as the fuel supply for the engine to power an equipment to perform a wellsite operation. Additionally, the processing device can identify a predefined range of the fuel supply that corresponds to a target performance level of the engine. Based on the fuel property measurement, the processing device can determine that the first fuel source is outside of the predefined range. In response, the processing device can provide a second fuel source as the fuel supply. The second fuel source can enable the engine to operate at the target performance level.

Abstract: A well system and a related method are discussed. The well system, in one aspect, includes a wellbore extending through a subterranean hydrocarbon producing zone, as well as production tubing located in the wellbore, the production tubing including a first inflow control valve configured to regulate a first inflow of hydrocarbons from the subterranean hydrocarbon producing zone into the production tubing. The well system, in accordance with this aspect, further includes a flange coupled to the production tubing and having a fitting positioned proximate a downhole end thereof, and a fiber optic cable installed within the wellbore, an end connector of the fiber optic cable coupled end to end with the fitting of the flange to fix the fiber optic cable relative to the first inflow control valve.

Abstract: A flow control valve is disclosed. The flow control valve includes a body defining a central flow passage and one or more lateral flow openings for fluid communication between the central flow passage and an exterior of the body. The flow control valve also includes a flow trim positioned within the central flow passage and defining at least a first and a second set of flow ports, the first set of flow ports each defined along a radial portion of a longitudinal cross-section of the flow trim, and the second set of flow ports each defined along the radial portion and between a respective pair of the first plurality of flow ports. The flow trim is rotationally movable to align one of the first set of flow ports or the set plurality of flow ports with the one or more lateral flow openings.

Abstract: Systems and methods for performing a gas lift operation using gas to increase production of production fluid through a production tubing in a wellbore. Included is an optical bubble sensor usable to detect bubbles per unit volume of the production fluid in the production tubing. Also included is a pump operable to pump gas into an annulus in the wellbore outside the production tubing, a valve operable to control whether gas from the pump enters the annulus, and a controller comprising a processor. The controller is operable to automatically convert the detected bubbles per unit volume into a gas/liquid saturation index (GLSI) using a transformation function; automatically execute, at designated intervals, a decision function based on the GLSI to either pump or not pump gas into the wellbore; and automatically control the pump and the valve to pump gas into the annulus when indicated by the decision function.

Abstract: Disclosed are systems, apparatuses, methods, and computer readable medium for extracting materials from a well and real-time wear detection and lifecycle prediction for well facilities. A method includes: receiving first measurement data associated with or from a first equipment submersed into a downhole environment during a portion of a current operation for extracting materials from the downhole environment at a pumping system; and estimating a wear rate associated with the first equipment based on an operational assessment of the downhole environment.

Abstract: Described herein are systems, apparatuses, processes (also referred to as methods), and computer-readable media (collectively referred to as “systems and techniques”) for improving an accuracy of determinations made using data sensed in a wellbore. Such systems and techniques may use a combination of sampled data and simulated data to generate updated datasets that may be used to make evaluations about how well a casing is cemented to subterranean formations where a wellbore is located.

Abstract: A drillstring, in a drilling environment, operatively connected to an information handling system, where the information handling system is configured to perform a method for modifying drilling operations that includes obtaining measured drillstring data associated with the drillstring, and calculating a heat generation using the measured drillstring data, where, based on the heat generation, a drilling modification procedure is performed.

Abstract: An expandable liner hanger assembly may include a liner hanger body having a radially expandable tubular. The expandable liner hanger assembly may also include a groove formed in a radially outer surface of the liner hanger body that is configured to extend circumferentially about the liner hanger body. Additionally, the expandable liner hanger assembly may include at least one anchor key having a base portion disposed within the groove. Further, an engagement end of the at least one anchor key may extend radially outward from the groove. The engagement end is configured to engage a casing string in response to expansion of the liner hanger body to anchor into the casing string.

Abstract: Disclosed are systems, apparatuses, methods, and computer readable medium for long term trend analysis for equipment for well systems. A method includes: receiving first measurement data associated with or from equipment submersed into a downhole environment during a portion of a current operation for extracting materials from the downhole environment at a pumping system for a well; normalizing the first measurement data; removing portions of normalized data that are associated with scale; combining the normalized data with previous data into complete well data, wherein the previous data is associated with previous runs of the downhole environment; providing the complete well data into a first machine learning model for identifying trends associated with the complete well data; receiving labels associated with operation of a first equipment from the first machine learning model; and displaying information pertaining to trends and events associated with an entirety of the current operation.

Abstract: Systems and methods for performing a wellbore cleanout operation in a production tubing in a wellbore extending through a reservoir. The systems and methods include a sensor usable to detect a wellbore production volume of a production fluid from the production tubing per unit time, a conveyance, and a controller including a processor. The controller is operable to automatically determine a differential flowrate for locations along the production tubing based on a difference between a recorded flowrate and a modeled flowrate at the locations, determine any of the locations where the differential flowrate is equal to or greater than a predetermined threshold, and control deployment of the conveyance into the wellbore to perform the cleanout operation at any of the determined locations where a change in a wellbore cleanout utility function using the modeled flowrate compared to using the recorded flowrate is equal to or greater than an improvement factor.

Abstract: Disclosed are systems, apparatuses, methods, and computer readable medium for a real-time feedback and machine learning system for downhole environments. A method includes: receiving first measurement data from a first equipment submersed into a downhole environment during a run for extracting material from the downhole environment; determining a performance curve based on the first measurement data, the performance curve identifying an extraction rate of the material with respect to efficiency and head capacity; and providing the performance curve to an operator of the run for real-time feedback associated with performance of equipment in the downhole environment.

Abstract: A variety of methods and apparatus are disclosed, including, in one embodiment, an apparatus comprising a downhole tool for use in a borehole, the downhole tool comprising a composite of thermoplastic and fibers, wherein the fibers reinforce the thermoplastic, and wherein fiber placement gives the composite as favoring the hoop strength over the axial strength.

Abstract: Some implementations include a method for controlling a computer system configured to detect scaling and/or plugging of an electric submersible pump (ESP) deployed in a wellbore. The method may include determining, based on a measurement of pressure in the wellbore, a required total dynamic head (RTDH) for the ESP while the ESP is operating in the wellbore. The method also may include determining, based on information from one or more sensors in the ESP, a produced total dynamic head (PTDH) for the ESP while the ESP is operating in the wellbore. The method also may include detecting scaling status or plugging status of the ESP based on the RTDH and the PTDH.

Abstract: A magnetic coupling mechanism in a downhole flow control tool comprising a first chamber within a flow path of wellbore fluids with a first component comprising a Halbach array of magnets. A second chamber isolated from the wellbore environment comprises a second component with a Halbach array of magnets. The first chamber and the second chamber are coupled with a nonmagnetic separation. The second component is translated with the first component by a strong magnetic flux produced by the array of magnets.

Abstract: A blending unit is provided. The blending unit comprises two or more discharge pumps. Each of the two or more discharge pumps has a suction inlet fluidly connected to a common proppant fluid supply via a concentrated proppant inlet line, and a discharge outlet fluidly connected to a blender outlet line. Each of the two or more discharge pumps also has an injection port upstream of the discharge pump and configured to inject substantially proppant-free fluid into the concentrated proppant inlet line, an injection port downstream from the discharge pump and configured to inject substantially proppant-free fluid into the blender outlet line, or both the injection port upstream of the discharge pump and an the injection port downstream from the discharge pump.

Abstract: A downhole electric submersible pump (ESP) assembly. The downhole ESP assembly comprises a permanent magnet motor (PMM) comprising a first drive shaft, a stator, and a rotor disposed within the stator and comprising a core coupled to the first drive shaft, wherein the core retains a first permanent magnet element within a first magnet pocket defined by the core that extends axially parallel to the first drive shaft and retains a second permanent magnet element within a second magnet pocket defined by the core that extends axially parallel to the first drive shaft; a seal section having a second drive shaft coupled to the first drive shaft; and a pump assembly having a third drive shaft coupled to the second drive shaft.

Abstract: Systems and methods of the present disclosure are directed to systems and methods for controlling a wellbore drilling apparatus where the system may include a surface controller and a downhole controller. In certain instances, control of the drilling apparatus may be transferred from the surface controller to the downhole controller. The control of the drilling apparatus may be transferred to the downhole controller as the surface control monitors operation of the drilling operation. The surface controller may also send a command that transfers control of the drilling apparatus from the downhole controller to the surface controller.