Abstract: An example system for conditioning drilling fluid includes a tank to hold drilling fluid and outlet conduits located at least partly within the tank. The outlet conduits have a tree structure that includes a trunk and branches. Each of the branches has one or more nozzles for outputting drilling fluid within the tank. The system also includes one or more inlet conduits for receiving drilling fluid from the tank and one or more pumps that are controllable to suction the drilling fluid from the tank through the one or more inlet conduits and to force the drilling fluid into the tank through the outlet conduits.

Abstract: An example drill bit includes a body that is connectable to a drill string. The body has a base configured to face downhole within a wellbore and a perimeter configured to face a wall of the wellbore. The body includes a first nozzle and a second nozzle. The first nozzle corresponds to a first channel that exits the body through the perimeter and the second nozzle corresponds to a second channel that exits the body through the base. The example drill bit also includes a bit cutter on the base of the body and a valve within the body. The valve is configured to move within the body to block either the first channel or the second channel.

Abstract: A smart skidding system includes a transverse skidding platform comprising a plurality of first skidding rails for skidding the a rig floor of the drilling rig sideways, wherein the plurality of first skidding rails are parallel to each other, a longitudinal skidding platform comprising a plurality of second skidding rails for skidding the rig floor of the drilling rig forward and backward, the plurality of second skidding rails being perpendicular to the plurality of first skidding rails, and a skidder unit configured to skid the rig floor of the drilling rig along the transverse skidding platform or the longitudinal skidding platform, the skidder unit further comprising a gear box assembly having a gear structure configured to engage with the plurality of first skidding rails and the plurality of second skidding rails, and an AC motor configured to drive the skidder unit.

Abstract: A programmable logic controller (PLC) receives first information from a first set of cameras positioned adjacent to a coiled tubing reel configured to deliver a coiled tubing string for insertion into a well. The PLC receives second information from a second different set of cameras positioned on a center of an arc of a primary turn of coiled tubing string. The PLC receives third information from a third different set of cameras positioned above a stripper and below an injector head. The PLC receives fourth information from a fourth different set of cameras embedded in an adapted spool below coiled tubing blow-out preventer equipment. The PLC uses the first, second, third, and fourth information, each including images of the coiled tubing string captured over time, to determine flaws exists in a segment of the coiled tubing string. A notification is provided that includes information identifying the flaws.

Abstract: An example wellbore cementing system includes a casing to line at least part of a wellbore, and a pipe to introduce cement slurry containing capsules into the wellbore. The capsules include an accelerator. The accelerator reacts with the cement slurry to affect a thickening time of the cement slurry. The example system also includes a substructure having shearing pins. The substructure is arranged to receive the cement slurry from the pipe. The substructure is configured rotate to break at least some of the capsules in the cement slurry.

Abstract: A drilling fluid system and associated method for supplying drilling mud to a drilling operation includes a plurality of first sensors associated with a first mud pit, configured to measure a plurality of properties of the drilling mud in the first mud pit, a plurality of second sensors associated with a second mud pit, configured to measure the plurality of properties of the drilling mud in the second mud pit, and a control unit configured to receive measurements from the plurality of first sensors and the plurality of second sensors, determine which of the mud pits comprises drilling mud with a desired plurality of properties, and cause to operate a first valve associated with the first mud pit or a second valve associated with the second mud pit for selecting drilling mud from the first mud pit or the second mud pit based on the determination.

Abstract: An example drill bit is configured to operate within a wellbore of a hydrocarbon-bearing rock formation. The drill bit includes a drill bit body including at least one leg. The drill bit may include at least one roller cone rotatably mounted on the drill bit body. The roller cone includes a plurality of cutting elements for abrading or crushing rock. The drill bit includes at least one bearing mounted between a surface of the drill bit body and the at least one roller cone to facilitate rotation of the at least one roller cone. The drill bit system includes a lubrication system to reduce friction between moving parts of the drill bit. The drill bit system includes at least one wear sensor associated with the drill bit to sense physical wear on the drill bit.

Abstract: A programmable logic controller (PLC) receives first information from a first set of cameras positioned adjacent to a coiled tubing reel configured to deliver a coiled tubing string for insertion into a well. The PLC receives second information from a second different set of cameras positioned on a center of an arc of a primary turn of coiled tubing string. The PLC receives third information from a third different set of cameras positioned above a stripper and below an injector head. The PLC receives fourth information from a fourth different set of cameras embedded in an adapted spool below coiled tubing blow-out preventer equipment. The PLC uses the first, second, third, and fourth information, each including images of the coiled tubing string captured over time, to determine flaws exists in a segment of the coiled tubing string. A notification is provided that includes information identifying the flaws.

Abstract: An example drilling system includes a rotary steerable system (RSS) having an inner shaft configured to rotate during drilling performed by the drilling system. One or more sensors are associated with the inner shaft to obtain one or more readings based on the drilling performed by the RSS. One or more processing devices may receive data based on the sensor readings and process that data in order to generate an output based on the sensor readings. The data may relate to stresses on the inner shaft and the data may be used for purposes including, but not limited to, controlling operation of the RSS in real-time, determining current condition of the RSS, and estimating a potential life expectancy of the RSS.

Abstract: An example tool for testing a wellbore includes a body having a longitudinal dimension configured for insertion into a casing of the wellbore, and a packer disposed along the body. The packer is controllable to expand against an inner diameter of the casing to enable testing the wellbore. The example tool also includes a scraper assembly disposed along the body for arrangement downhole of the packer when the body is inserted into the casing.

Abstract: Systems and methods for predicting an efficient hole cleaning in vertical, deviated, and horizontal holes by developing a hole cleaning model that combines hole cleaning and drilling rate to optimize performance. Specifically by ensuring optimum mud rheology values that have an influence on drilling mud from the aspects of ECD, cuttings transport, shear thinning, and thixotropic, and developing an effective hole cleaning model by utilizing carrying capacity index (CCI) and cutting concentration in annulus (CCA).

Abstract: Systems and methods for performing operations in a subterranean well with a smart tool include securing the smart tool in line with a tubular string of a well clean out system. The smart tool has a packer, primary slips located downhole of the packer, secondary slips located uphole of the packer, and a circulating valve located uphole of the packer, the circulating value providing a fluid flow path between a central bore of the smart tool and the bore of the subterranean well. The tubular string is moved into the bore of the subterranean well and performing a well clean out operation. The smart tool is releasably anchored in the subterranean well, separating a zone of the bore with the packer, and a well testing operation is performed with the smart tool.

Abstract: Systems and methods for drilling optimization of a subterranean well include securing a multifunction sub in line with a tubular string. A nozzle provides a fluid flow path from the central bore through a sidewall of the sub body, the nozzle oriented in a direction so that the fluid flow path directs a wellbore fluid from within the central bore in a direction uphole. A valve system can move between a closed position where the fluid flow path of the nozzle is closed, and at least one open position where the wellbore fluid can pass through the fluid flow path. A control system is operable to receive information and provide a signal to move the valve system. The tubular string is moved into a bore of the subterranean well and information is delivered to the control system to regulate the flow of wellbore fluid through the nozzle.

Abstract: Methods and systems for isolating a loss circulation zone of a subterranean formation includes lowering a drill string having a tubular member from a surface into a subterranean well and securing a packer assembly to the tubular member, the packer assembly having an inflatable packer unit and a protective sleeve. The protective sleeve is in an extended position and circumscribes the inflatable packer unit and the inflatable packer unit is in a deflated condition. A stabilizer body is secured to the tubular member downhole of the packer assembly. The stabilizer body is shaped to centralize the packer assembly and direct debris traveling uphole in a direction radially outward of the packer assembly. The protective sleeve is moved from the extended position to a retracted position. The inflatable packer unit is inflated to an inflated condition, forming a seal with an inner diameter surface of the subterranean uphole of the loss circulation zone.

Abstract: A smart skidding system includes a transverse skidding platform comprising a plurality of first skidding rails for skidding the a rig floor of the drilling rig sideways, wherein the plurality of first skidding rails are parallel to each other, a longitudinal skidding platform comprising a plurality of second skidding rails for skidding the rig floor of the drilling rig forward and backward, the plurality of second skidding rails being perpendicular to the plurality of first skidding rails, and a skidder unit configured to skid the rig floor of the drilling rig along the transverse skidding platform or the longitudinal skidding platform, the skidder unit further comprising a gear box assembly having a gear structure configured to engage with the plurality of first skidding rails and the plurality of second skidding rails, and an AC motor configured to drive the skidder unit.

Abstract: An example method includes connecting a casing liner device to a polished bore receptacle (PBR) of a liner hanger outside of a wellbore. The PBR includes a first connection mechanism. The casing liner device includes second connection mechanism that connects to the first connection mechanism. The casing liner device connected to the PBR is run into the wellbore in tandem.

Abstract: A downhole tool for use within a wellbore extending into an underground formation includes a wellbore wall disengaging assembly having a tubular string defining a longitudinal axis, and a plurality of longitudinal blades forming a retractable sleeve around the tubular string, the retractable sleeve having a substantially contiguous inner profile in a closed position, and wherein the retractable sleeve is actuated based on an internal pressure in the tubular string proximate to the downhole tool. A method of disengaging a downhole tool from a wall of a wellbore extending into an underground formation includes lowering a wellbore wall disengaging assembly, the assembly comprising a tubular string defining a longitudinal axis, and a plurality of longitudinal blades forming a retractable sleeve around the tubular string, the retractable sleeve having a substantially contiguous inner profile in a closed position, and actuating the retractable sleeve.

Abstract: A drilling fluid system and associated method for supplying drilling mud to a drilling operation includes a plurality of first sensors associated with a first mud pit, configured to measure a plurality of properties of the drilling mud in the first mud pit, a plurality of second sensors associated with a second mud pit, configured to measure the plurality of properties of the drilling mud in the second mud pit, and a control unit configured to receive measurements from the plurality of first sensors and the plurality of second sensors, determine which of the mud pits comprises drilling mud with a desired plurality of properties, and cause to operate a first valve associated with the first mud pit or a second valve associated with the second mud pit for selecting drilling mud from the first mud pit or the second mud pit based on the determination.

Abstract: A method for maintaining pressure in a wellbore drilled from a drilling platform floating on a body of water includes pumping fluid at a determined flow rate into a drill string disposed in a wellbore and measuring fluid pressure within a fluid discharge line of fluid returning from the wellbore. The fluid discharge line has a variable length corresponding to an elevation of the floating platform above the bottom of the body of water. The wellbore pressure is determined at a selected depth in the wellbore or at a selected position along a drilling riser or variable length portion of the fluid discharge line using known parameters/methods. The determined wellbore pressure is adjusted for changes in length of the fluid discharge line corresponding to changes in the elevation of the floating platform relative to the bottom of the body of water.

Abstract: A system and method include pumping drilling fluid through a drill string extended into a wellbore extending below the bottom of a body of water, out the bottom of the drill string and into the wellbore annulus. Fluid is discharged from the annulus into a riser and a discharge conduit. The riser is disposed above the top of the wellbore and extends to the water surface. The discharge conduit couples to the riser and includes a controllable fluid choke. A fluid return line is coupled to an outlet of the choke and extends to the water surface. Gas under pressure is pumped into the return line at a selected depth below the water surface. The controllable fluid choke may be operated to maintain a selected drilling fluid level in the riser, the selected fluid level being a selected distance below the water surface.