Abstract: This disclosure presents methods and systems for positioning a magnetic fluid conditioner in a well. One or more magnetic fluid conditioners are attached to a coupling mandrel operable to engage with the tubing of a well, either with an existing completion component or directly with the tubing. The coupling mandrel includes a locking mechanism, such as keys or dogs, for setting the mandrel to the profile nipple. The coupling mandrel further includes a packing stack or an expandable element that seals with the completion component or the tubing. The seal directs oil through the mandrel and thus, through the magnetic fluid conditioners. In some embodiments, multiple magnetic fluid conditioners are attached in tandem for more effective conditioning operations. The magnetic fluid conditioners can condition the oil to inhibit the formation of paraffin therein.

Abstract: The present disclosure relates generally to equipment utilized and operations performed in conjunction with a subterranean well and, more particularly, to an improved liner hanger system. A downhole expandable liner hanger positionable in a subterranean wellbore may comprise an expansion element. The expansion element may comprise a tubular body. The expansion element may comprise one or more annular seals bonded to the tubular body. The expansion element may comprise a first spike extending from the tubular body. The expansion element may comprise a second spike extending from the tubular body. The downhole expandable liner hanger may further comprise a first slip ring, wherein the first slip ring is disposed around the tubular body of the expansion element between the first spike and the second spike, wherein the first slip ring is configured to expand radially as the expansion element expands.

Abstract: A tubular delivery arm that travels vertically along a rail on the front of a drilling mast in generally parallel orientation to the travel of a top drive. The tubular delivery arm has a dolly vertically translatably connected to a mast of the drilling rig. An arm is rotatably and pivotally connected to the dolly at its upper end. A tubular clasp is pivotally connected to the arm at its lower end.

Abstract: A method of determining a risk of corrosion and scale formation of tubing in a wellbore includes receiving, from a plurality of first sensors positioned at a downhole location of a wellbore, first production stream information and receiving, from a plurality of second sensors positioned at an uphole location, second production stream information. The method also includes performing a material balance to determine a first value representing a difference between a first production steam flow rate at the downhole location and a second production stream flow rate at the uphole location. The method also includes determining a second value representing a critical metal ion concentration of the production stream and, based on a result of comparing the first value with a threshold and based on the second value, determining a third value representing a risk of corrosion and scale formation at the tubing disposed within the wellbore.

Abstract: A system for positioning an inner tubular within an outer tubular. The outer tubular is inserted in a wellbore and has a first central axis. The inner tubular defines an inner passage of the outer tubular and is inserted in a wellbore. The inner tubular has a second central axis that is offset from and parallel to the first central axis. A flange is attached at an uphole end of the outer tubular and encircles an outer circumference of the inner tubular. The flange has a third central axis that is in-line with the second central axis. A wellhead housing is positioned at an uphole end of the flange and encircles the outer circumference of the inner tubular. A casing hanger is positioned within the wellhead housing and has an interference with the wellhead housing. The casing hanger is frictionally attached to the inner tubular.

Abstract: A variable flow resistance system for use with a subterranean well includes a first flow path to receive a fluid, a flow rate sensor to measure a flow rate of the fluid received into the first flow path, and an actuator to control an inflow rate of the fluid received into the first flow path based upon the measured flow rate of the fluid.

Abstract: Systems and methods for wellbore drilling may use one or more cutting elements including a cutting face with one or more channels capable of steering chip cuttings into an intended direction off of the cutting face of the cutting element for drilling operations. A method may comprise rotating a drill bit to extend a wellbore into a subterranean formation, flowing a drilling fluid through the drill bit, and directing a plurality of formation cuttings away from one or more cutting elements of the drill bit by moving the cuttings along one or more channels on at least a portion of a cutting face of the one or more cutting elements.

Abstract: Systems and methods for unsticking a tubular string in a subterranean well that is a stuck pipe include securing a circulation sub to an uphole end of the tubular string outside of the subterranean well. The buoyancy of the tubular string is increased by delivering a replacement fluid through the circulation sub and into a bore of the tubular string. The replacement fluid displaces an operating fluid located within the bore of the tubular string. A density of the replacement fluid is less than a density of the operating fluid. Conventional operations for unsticking the tubular string can be performed. The replacement fluid in the bore of the tubular string can be replaced with the operating fluid, and the replacement fluid can be delivered back out of the subterranean well.

Abstract: An anchor including a tubular body having a longitudinal axis, a number of wedges defined in the tubular body, the wedges having edges defined by surfaces at least one of the edges at a point along that edge having a first angle and at the same or another point along that edge having a second angle.

Abstract: A submersible pumping system for use in producing wellbore fluids from a wellbore within a subterranean formation includes a motor and a pump driven by the motor to produce the wellbore fluids. The pumping system further includes a self-supporting power cable connected to the pump. The self-supporting power cable includes a plurality of conductors and a plurality of strength members. A method of deploying and retrieving a submersible pumping system in a wellbore includes the steps of connecting a wireline to the submersible pumping system, connecting a self-supporting power cable to the submersible pumping system, lowering the submersible pumping system into the wellbore while the weight of the submersible pumping system is borne by the wireline.

Abstract: A swellable packer comprises an elastomeric element and a mandrel extending through the elastomeric element. The elastomeric element is formed of an elastomer which undergoes swelling following contact with certain types of well fluids. The elastomeric element is sealed with respect to the mandrel and may be located along an undercut region of the mandrel. Additionally, the mandrel has an interior passage extending longitudinally through the mandrel and offset with respect to an external geometry of the mandrel. Accordingly, the mandrel is effectively constructed with relatively thicker and thinner wall sections. The thicker wall section or sections accommodates at least one bypass conduit which extends longitudinally through the mandrel.

Abstract: An artificial lift system has a surface pump operated by a prime mover powered by a variable speed drive. A jet pump disposed downhole in tubing receives pressurized power fluid from the surface pump, mixes the power and production fluid and delivers the product uphole. A controller disposed at surface adjusts the artificial lift system relative to a set value based on a measured discharged pressure or a measured flowrate and trends a change in the other of the measured flowrate or the measured discharged pressure over time. The controller can also trend an operating condition (intake pressure vs. production rate) to determine changes relative to cavitation conditions. Based on the trended changes, the controller initiates an operation in the artificial lift system, such as adjusting the discharge pressure, initiating an alarm condition, etc.

Abstract: Drill hole sequence planning equipment (14) includes a position determining module (18) for determining an initial location of a mobile drill rig (12). A selection module (24) selects a destination location for the drill rig (12). A corridor establishment module (26) establishes a corridor between the initial location of the drill rig (12) and its destination location, the corridor having a selected width. A processing unit (28) is responsive to the modules (18, 24 and 26) for selecting a hole location of each hole within the corridor to be drilled by the drill rig (12) sequentially as it moves from its initial location to its destination location.

Abstract: A resettable pressure activated device, comprises an inner wall, a return spring, a resilient element and an axially movable piston arranged around the inner wall. The piston comprises a radially extending piston area in fluid communication with a central bore within the inner wall such that the piston moves in an activation direction when a bore pressure within the central bore exceeds the pressure around the device by a predetermined release pressure.

Abstract: A method, system, and apparatus for restraining a firing pin using a bushing for use in a downhole switch that is armed using the explosive energy of a previously detonated shaped charge.

Abstract: A power management system may monitor data relating to respective loads on a plurality of power sources. The plurality of power sources may be associated with a drilling rig engaged in a drilling process. The power management system may determine a stage of the drilling process based on the respective loads on the plurality of power sources. The power management system may determine, based on the stage of the drilling process that is determined, respective load shares for the plurality of power sources. The power management system may manage load sharing among the plurality of power sources according to the respective load shares that are determined.

Abstract: A method for determining a rotational frequency of a positive displacement motor positioned in a downhole portion of a drill string, the method including: providing at least one measurement device for measuring a property of a part of the drill string; providing a processor for processing a signal output by the at least one measurement device; operating the positive displacement motor whilst the part of the drill string is in a non-driven state; receiving the signal at the processor; determining, using the processor, a frequency spectrum of the signal; and determining the rotational frequency of the positive displacement motor by: identifying a peak in the frequency spectrum in a pre-determined frequency range associated with an expected rotational frequency of the positive displacement motor; and/or identifying a peak in the frequency spectrum having a pre-determined peak width associated with an expected rotational frequency of the positive displacement motor.

Abstract: A method including determining a concentration of one or more components of a fluid during a wellbore servicing operation of a wellbore, and providing a trigger signal to actuate mechanical operation of a tool based on the determining of the concentration of the one or more components. The determining of the concentration of the one or more components includes contacting a sample of the fluid with a microelectromechanical system (MEMS) device to provide a sample response indicative of the concentration of the one or more components.

Abstract: An electrical submersible pump (“ESP”) has a seal member that carries a packer. A retainer initially retains the packer in a fixed axial position with the seal member as the ESP is lowered into a well conduit. The retainer is releasable after the packer has been set in the conduit in response to a thermal growth axial force on the seal member, enabling relative axial movement between the seal member and the packer. The seal member has annular seal rings that extend over an axial length on the tubular member that is greater than an axial length of the bore of the packer.

Abstract: A platform apparatus positionable close to a surface element to allow an operator to access production tubing being withdrawn from the surface element. The platform apparatus can be positioned in close proximity to a surface element of a well to permit an operator access to production tubing and cable secured to the production tubing. The cable can be separated from the production tubing and directed beneath a primary oil rig platform. The production tubing can be scanned with an electronic scanning device after the cable has been separated from the production tubing as the production tubing is being removed from the well. The platform apparatus can be positioned in close proximity to a surface element of a well being serviced by a pole unit to permit an operator access to production tubing. The production tubing can be scanned with an electronic scanning device as the production tubing is being removed from the well.