Abstract: System and methods of controlling fluid flow during reservoir stimulation treatments are provided. A flow distribution of treatment fluid injected into formation entry points along a wellbore path is monitored during a current stage of a multistage stimulation treatment. Upon determining that the monitored flow distribution meets a threshold, a remainder of the current stage is partitioned into a plurality of treatment cycles and at least one diversion phase for diverting the fluid to be injected away from one or more formation entry points between consecutive treatment cycles. A portion of the fluid to be injected into the formation entry points is allocated to each of the treatment cycles of the partitioned stage. The treatment cycles are performed for the remainder of the current stage using the treatment fluid allocated to each treatment cycle, wherein the flow distribution is adjusted so as not to meet the threshold.

Abstract: A wiper plug is used in an operation to cement tubing in a borehole. The wiper plug is pumped down the tubing to separate an advancing fluid from a following fluid of the cementing operation, and an internal pressure chamber is maintained in a throughbore of the wiper plug between uphole and downhole barriers. The wiper plug eventually lands in the tubing, and the uphole barrier is removed by applying a first predetermined pressure against the uphole barrier. Removal of the uphole barrier is facilitated by the known and controlled internal pressure of the plug's chamber. The downhole barrier is also removed so that flow is permitted through the throughbore of the wiper plug. To perform a tubing pressure test, the downhole barrier can be removed due to pressure, and the chamber may have a temporary valve to hold applied pressure to a test level. Alternatively, the downhole barrier can hold the applied pressure. The temporary valve and the downhole barrier can then be self-removing in response to a stimulus.

Abstract: A switch sliding sleeve device for oil-gas exploitation and switching method thereof, an oil-gas exploitation tool and a switching method of a wall through hole thereof are disclosed. The disclosure relates to the technical field of oil-gas exploitation, and solves the technical problems in the prior art that the switching operation steps of a wall through hole of an outer cylinder are tedious and complex, and a large amount of manpower and material resources are consumed. The switch sliding sleeve device for oil-gas exploitation and the oil-gas exploitation tool include an outer cylinder, a switch sliding sleeve mechanism and a trigger. When the trigger is put into the outer cylinder and punching triggers the switch sliding sleeve mechanism, the switch sliding sleeve mechanism is capable of being switched from a state of opening the wall through hole to a state of closing the wall through hole until is triggered by the trigger or another trigger again.

Abstract: Systems and methods for delivering an injection fluid into a subterranean well include an injection tool having an injection tool body with an internal cavity. A fluid chamber is located within the internal cavity. A heating chamber includes a pipe segment arranged parallel to the central axis. A one way valve provides a fluid flow path for the injection fluids to travel in a downhole direction through the one way valve, and prevents the flow of fluids through the one way valve in an uphole direction. A fiber optic cable extends to the pipe segment, the fiber optic cable operable to deliver a laser radiation to the pipe segment, heating the pipe segment. The injection tool body provides a fluid flow path from the one way valve to an outside of the injection tool.

Abstract: The present disclosure provides a method for running a drilling rig or a workover rig including a plurality of stands into a wellbore. In step 1, position information of the stands in a finger board area may be recorded with a control system. In step 2, the stands may be placed. In step 3, a position of a traveling block may be adjusted so as to move a power elevator to a second waiting position of a racking platform. In step 4, the stands may be pushed with the pipe racking device. In step 5, the second stand may be moved and stabbed in the first stand with an iron floor man. In step 6, a joint between the first stand and the second stand may be made up. In step 7, the traveling block may be moved downward. In step 8, the traveling block may be moved upward.

Abstract: An improved external trap apparatus 570 and a method for safely controlling drilling tool string components during oil field drilling operations includes a collar clamp 72 affixed to a drilling tool string lubricator 80 and configured with laterally spaced first and second vertical rails 120, 122 depending therefrom. Lubricator 80 also carries a lubricator clamp assembly 572 which is affixed to Lubricator 80 with inward clamping surfaces defining a non-circular or slightly elliptical central bore 574. Laterally spaced first and second vertical rails 120, 122 are configured to support a reinforced catcher plate assembly 164 carrying a tool-end receiving funnel receptacle 202 and first and second energy absorbing crush cylinders 160, 162. When the drill string 82 is raised or withdrawn from the well 28, the funnel receptacle 202 can be rotated into coaxial alignment to catch the drill string's end or downhole tool, in the event of an inadvertent loss of control of the drill string 82.

Abstract: A cable head line cutter tool comprising an internal mandrel anchored to a line and releasably held in an initial position by a locking mechanism disposed within an outer housing of the cable head cutter tool. When a tensile load is applied to the line sufficient to overcome a mechanical resistance acting upon the locking mechanism, and maintained for a duration sufficient to overcome a hydraulic resistance acting upon the locking mechanism, the internal mandrel may become released from the locking mechanism and allowed to travel within the outer housing free of the locking mechanism. In embodiments, the cable head line cutter tool may comprise one or more such locking mechanisms acting independently or in coordination. If the tensile load applied to the line is sufficient to release the mandrel from each of the one or more locking mechanisms and maintained for sufficient duration, the mandrel may cause a line cutter device disposed within the cable head line cutter tool to cut the line.

Abstract: A power tong locking system includes a gear assembly with an aperture formed to receive a head shaft of a power tong gear shift system. The gear assembly includes discrete positions defined by notches formed between adjacent teeth arranged on a perimeter of the gear assembly. The power tong locking system further includes a lock arm assembly that includes a shift handle that includes an aperture formed to receive the head shaft of the power tong gear shift system adjacent the gear assembly, and a release handle rotatably coupled to the shift handle. The lock arm assembly is movable between a first position in which the release handle is secured in a first position to lock the power tong gear shift system at a first gear setting and a second position to lock the power tong gear shift system at a second gear setting that is different than the first gear setting.

Abstract: Aspects of the disclosure relate to convertible float valve assemblies, and associated components thereof, and methods of using convertible float valve assemblies. A convertible float valve assembly may comprise a sleeve, one or more valves and valve bodies coupled to the sleeve, and a collet coupled to the sleeve. A method may comprise lowering the convertible float valve assembly and a ball downhole, seating the ball on the collet, and releasing the sleeve from the one or more valve bodies.

Abstract: A collapsible bullnose assembly may include a mandrel, a bullnose secured to a distal end of the mandrel, a lower ramp disposed about the mandrel adjacent the bullnose and having a first ramped surface, and an upper ramp slidably disposed around and releasably secured to the mandrel. The upper ramp may have a second ramped surface axially offset from the first ramped surface. The collapsible bullnose assembly may further include a collapsible guide member having opposing ends initially supported on the first and second ramped surfaces and protruding radially outwardly of the bullnose. The collapsible guide member may be actuatable to a radially collapsed orientation in response to axially shifting the upper ramp along the mandrel to a released position away from the lower ramp.

Abstract: An assembly disposed within a subterranean wellbore can include a first dislodging tool coupled to a bottom end of a tubing string, wherein the first dislodging tool, when enabled at a first time, performs a first action to free at least one service tool, disposed below the first dislodging tool in the subterranean wellbore, from being stuck.

Abstract: A window mill is positionable in a wellbore having an annulus. The window mill includes a mill body having an outer surface, a conduit extending axially through the mill body, and a flow port extending from the conduit through the outer surface. A nozzle shuttle including a nozzle is arranged in the conduit. The nozzle shuttle selectively extending over the flow port. A selectively openable port adapter extends between the flow port and the nozzle shuttle. The selectively openable port adapter is responsive to fluid pressure to fluidically expose the conduit to the annulus through the flow port.

Abstract: An indexing valve system includes a first tubular having an outer surface portion, an inner surface portion defining a passage portion, and a plurality of indexing components. A second tubular is axially aligned with the first tubular. The second tubular includes an outer surface section, an inner surface section defining a passage section, and a plurality of indexing members that selectively inter-engage with the plurality of indexing components. The inner surface section including a plurality of indexing elements. An insert extends into, and is axially shiftable relative to, the passage portion and the passage section. The insert includes an outer surface supporting an indexer that selectively engages with the plurality of indexing elements to rotate the second tubular relative to the first tubular.

Abstract: An integrated hydraulic fracture design model that utilizes elastic fluids with high proppant suspension and low required power for injection into a hydrocarbon-bearing, subterranean formation. The integrated physics-based approach utilizes a hybrid friction model to compute viscous and elastic behavior to estimate pressure losses at different pumping conditions coupled with a novel geomechanical model capable of modeling proppant transport with elastic fluids in planar hydraulic fractures and natural fractures. An integrated process to optimize hydraulic fracture design evaluates and quantifies the proppant-carrying capacity of elastic fluids and its impact on the proppant transport process, and low water requirements.

Abstract: A downhole well tool assembly can include a perforator and a selectively openable and closable perforation plug discharge port. A method of perforating and treating multiple formation zones of a well in a single trip of a downhole well tool assembly into the well can include positioning the downhole well tool assembly at a zone, closing a perforation plug discharge port of the downhole well tool assembly, perforating the zone, treating the zone, opening the perforation plug discharge port, deploying perforation plugs into the well via the perforation plug discharge port, plugging perforations in the zone with the perforation plugs, positioning the downhole well tool assembly at a subsequent zone, closing the perforation plug discharge port, perforating the subsequent zone, and treating the subsequent zone.

Abstract: The present disclosure relates to a method for pre-warning deformation of a casing pipe according to a change feature of the b-value of the hydraulic fracturing induced microseismicity. Based on number distribution and seismic magnitudes of hydraulic fracturing induced microseismic monitoring events, a b-value of microseismicity in a fracturing stage is calculated according to a Gutenberg-Richter relation describing frequency-seismic magnitude distribution in seismology, and whether fault activation occurs in a fracturing process is identified according to a change feature of the b-value. According to the method, a cumulative effect of fault activation in the hydraulic fracturing process is considered, and symptoms of fault activation in the fracturing process can be accurately identified, so as to pre-warn deformation of the casing pipe.

Abstract: A snubber device for reducing shocks and vibrations in a downhole tool. The snubber includes a main body extending between upper and lower connector ends. The main body is defined by one or more cut-out portions. One or more elastomeric elements are held within the one or more cut-out portions. The cut-out portions provide flexibility to the main body. The elastomeric elements absorb shocks and vibrations and are conveniently replaceable when excessive wear reduces their shock and vibration absorbing capacity.

Abstract: Ball valves, methods to close a ball valve, and methods to form a well barrier are discussed. A ball valve includes a valve housing and a ball that is rotatably movable from an open position to a closed position. The ball valve also includes an actuation mechanism operable to rotate the ball from the open position to the closed position, where a fluid passage of the ball is not aligned with a fluid passage of the valve housing while the ball is in the closed position. The ball valve further includes a sleeve disposed in the valve housing and operable to shift from a first position to a second position to actuate the actuation mechanism.

Abstract: A frac plug with a flapper positioned within a shearable housing. More specifically, embodiments are directed towards an upper portion of the shearable housing that is configured to be separated from an insert responsive to flowing back through the frac plug.

Abstract: An overshot apparatus includes a tubular housing and a grapple disposed within a bore of the tubular housing. The grapple has a central opening to receive a fish and is operable to grip an outer diameter of the fish. A stinger is supported in the bore by an adapter attached to an upper end of the tubular housing. The stinger is positioned to be inserted into the fish received in the central opening of the grapple. A packing element is positioned on an external surface of the stinger to engage an inner diameter of the fish when the stinger is inserted into the fish and the fish is received within the central opening of the grapple. The adapter and stinger have conduits for passage of fluid into the fish.