Abstract: A debris catcher assembly includes a debris filter assembly having a selectively operable valve. such as a rupture disk, to allow a secondary flow path should the debris filter assembly become clogged with debris.

Abstract: A pressure control assembly can include an outer housing and a rotating control device including a bearing assembly with a rotatable inner barrel, a pressure sensor and one or more magnetic field generators, and at least two seal elements configured to seal between the inner barrel and a tubular positioned in the pressure control assembly. A magnetic field detector secured to the outer housing is configured to receive signals from the magnetic field generators, the signals being indicative of outputs of the pressure sensor. A method can include securing a magnetic field detector to an outer housing, installing the rotating control device in the outer housing, the rotating control device comprising a rotatable inner barrel, a pressure sensor and multiple magnetic field generators, and transmitting signals indicative of outputs of the pressure sensor from the magnetic field generators to the magnetic field detector.

Abstract: A gravel pack system includes a liner assembly and a deployment assembly. The liner assembly includes a sand control screen. The deployment assembly facilitates rotation of the liner assembly and circulation through the liner assembly while running the liner assembly into a wellbore using a work string. The deployment assembly includes a crossover tool that is operated to facilitate gravel packing without manipulation of the work string. The deployment assembly also includes a setting tool for setting a packer and/or a sand barrier at the top of the liner assembly.

Abstract: An explosive assembly for a downhole tool operable to connect and selectively disconnect within a wellbore a first portion of a downhole tool string and a second portion of the downhole tool string. The explosive assembly includes an explosive charge, a detonator switch operable to detonate the explosive charge, and a housing assembly containing the explosive charge and the detonator switch. The explosive assembly may be movable as a single unit and installable within an internal space of the downhole tool. The explosive charge may be operable to sever a support member of the downhole tool when the explosive charge is detonated by the detonator switch to therefore disconnect a first portion of the downhole tool and a second portion of the downhole tool from each other and thus disconnect the first portion of the downhole tool string and the second portion of the downhole tool string from each other.

Abstract: A method of injecting gas into a well can include flowing the gas through a gas flow passage extending through a housing connected to a wellhead installation, the gas thereby flowing through the wellhead installation and into an annulus in the well, and maintaining fluid pressure applied to a piston of a gas injection valve while the gas flows into the annulus. A gas injection system can include a housing having a gas flow passage extending longitudinally through the housing, and being configured to connect to a wellhead installation, and a gas injection valve including a pivotably mounted flapper closure member. The flapper closure member in an open position permits gas flow between the gas flow passage and the wellhead installation, and the flapper closure member in a closed position prevents the gas flow from the wellhead installation through the gas flow passage.

Abstract: A cementing operation cements casing in a borehole. A bottom plug pumped down the casing ahead of cement lands at a float valve. Circulation of the cement is established through the bottom plug to a shoe track downhole from the float valve. A top plug pumped down the casing behind the cement lands on the bottom plug. An internal component of the float valve is released by building-up pressure in the casing behind the internal component up to a release threshold. The internal component can latch at the shoe. At least some of the cement in the shoe track is displaced from the casing's shoe to the borehole by pumping the plugs and the internal component to the shoe. With the cement displaced out of the shoe track, the time required to drill out the assembly can be greatly reduced.

Abstract: A downhole assembly includes a tubular body having a bore and a downhole tool connected to the tubular body. The downhole assembly also includes a sensor assembly having a carrier and a sensor. A sensor adapter is used to couple the sensor assembly to the tubular body. The sensor adapter includes an adapter body disposed in the bore of the tubular body; an adapter shaft for connection with the carrier; and a plurality of channels formed between the adapter shaft and the adapter body.

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 traction tool is operable with fluid flow from coiled tubing for use in a wellbore. The traction tool includes a mandrel, a driver, at least one piston, and a motor. The driver is rotatably disposed on the mandrel and can be movable between retracted and extended conditions when the at least one piston is actuated. The driver in the extended condition is configured to engage inside the wellbore. The piston is adjacent to the driver and is actuated by the fluid flow from the mandrel. The motor is also actuated by the fluid flow from the mandrel. The motor imparts rotation to the piston and the drive, which can be supported by bearings on the tool's mandrel. Tracks on the driver arranged at an angle transverse to a longitudinal axis of the tool allow the rotating driver to spiral inside the wellbore and advance the traction tool.

Abstract: Methods comprising: injecting into a wellbore in a subterranean formation a multi-particle lost circulation material composition comprising a base fluid and a particle blend comprising substantially cylindrical particles and substantially spherical particles and wherein said particle blend comprises: degradable particles of at least three different sizes and wherein a first-sized particles and a second-sized particles are substantially cylindrical and a third-sized particles are substantially spherical.

Abstract: An annulus flow control tool can include an inner mandrel with a longitudinal bypass flow path, a sleeve on the inner mandrel, the sleeve being displaceable on the inner mandrel between bypass open and bypass closed positions, and at least one annular seal carried externally on the sleeve. A method of controlling annulus flow can include connecting an annulus flow control tool in a tubular string, the annulus flow control tool including a bypass flow path and at least one external annular seal, deploying the tubular string into the well, sealingly engaging a well surface with the annular seal, flowing a fluid through the tubular string into the well, thereby causing another fluid in an annulus between the tubular string and the well surface to flow through the bypass flow path, and closing the bypass flow path, the annulus flow control tool thereby blocking flow through the annulus.

Abstract: A convertible valve assembly has an upper and lower plunger valve connected to one another so that they reciprocate together. A retainer assembly holds the valves in a bi-directional configuration, allowing fluid flow in both directions through the valves. The retainer assembly then releases the valves to a unidirectional configuration upon application of a downhole hydraulic pressure, so that fluid can flow only one direction through the valve assembly.

Abstract: A method of determining viscosity can include connecting a bypass flow passage in parallel with a main flow passage, connecting a mass flowmeter and a variable flow restrictor in the bypass flow passage, and connecting at least one viscometer to the bypass flow passage. A rheology measurement apparatus can include a bypass flow passage connected in parallel with a main flow passage, a mass flowmeter connected in the bypass flow passage, and a pipe viscometer connected in the bypass flow passage. Another bypass flow passage may be connected in parallel with the main flow passage, with another mass flowmeter connected in the second bypass flow passage.

Abstract: A downhole tool for connecting with a conveyance line. The downhole tool may be or comprise a connector assembly operable to connect to the line. The connector assembly may include a first connector, a second connector, a latching member, and a rotatable member. The first connector and the second connector may be configured to accommodate the line therebetween. The latching member may be latched against the first connector. The rotatable member may be operatively connected with the latching member such that rotation of the rotatable member with respect to the latching member causes relative axial movement between the latching member and the rotatable member thereby forcing the first connector and the second connector toward each other to compress the line therebetween to therefore connect the connector assembly to the line.

Abstract: A sensor assembly can include a gyroscope, an accelerometer, and a housing assembly containing the gyroscope and the accelerometer. An axis of the gyroscope can be collinear with an axis of the accelerometer. A method of inspecting a well pumping unit can include attaching a sensor assembly to the pumping unit, recording acceleration versus time data, and in response to an amplitude of the acceleration versus time data exceeding a predetermined threshold, transforming the data to acceleration versus frequency data. A method of balancing a well pumping unit can include comparing peaks of acceleration versus rotational orientation data to peaks of acceleration due to circular motion, and adjusting a position of a counterweight, thereby reducing a difference between the peaks of acceleration due to circular motion and the peaks of the acceleration versus rotational orientation data for subsequent operation of the pumping unit.

Abstract: A system includes hydraulic power tongs mounted to a rig floor and including a primary tong and one or more controls for operating the primary tong, an electronic limit barrier device including one or more sensors operable to determine a distance between the hydraulic power tongs and an operator on the rig floor, and a hydraulic control valve in communication with the electronic limit barrier device and fluidly coupled to the hydraulic power tongs. The electronic limit barrier device is programmed to compare the distance to a pre-defined cutoff distance, and release hydraulic fluid from the hydraulic power tongs upon determining that the distance is less than or equal to the pre-defined cutoff distance.

Abstract: A tong positioning system includes a positioning device configured to move a tong assembly. The positioning device includes a first actuator, a second actuator, and a control attachment attachable to the positioning device. The control attachment includes a shutoff valve fluidly coupled to a hydraulic supply, a control valve block, and a control device. The control valve block includes a hydraulic input fluidly coupled to the shutoff valve, a hydraulic output fluidly coupled to a hydraulic return, a first valve fluidly coupled to the first actuator, the first valve configured to actuate the first actuator, and a second valve fluidly coupled to the second actuator, the second valve configured to actuate the second actuator. The control device is configured to control the first valve and to control the second valve to actuate the first and second actuators to move the tong assembly.

Abstract: A flow measurement apparatus can include a main flow passage, a bypass flow passage having an inlet and an outlet connected with the main flow passage, a mass flowmeter connected in the bypass flow passage between the inlet and the outlet, and a flow restrictor connected in the bypass flow passage between the inlet and the outlet. A method can include connecting the flow measurement apparatus, so that a fluid flow in the well also flows through the flow measurement apparatus, and determining at least one rheological parameter of a non-Newtonian fluid, based on an output of the flow measurement apparatus.

Abstract: A spider for handling/gripping well components of various sizes can include multiple slip assemblies distributed circumferentially about a central axis, each slip assembly including a slip carrier radially displaceable relative to the central axis, a slip displaceable relative to the slip carrier, and a slip actuator operable to displace the slip relative to the slip carrier, the slip actuator being disposed at least partially internal to the slip carrier. Each slip assembly may include a slip carrier actuator that radially displaces the slip carrier. A table assembly may mount to a well rig with an upper surface of the table assembly being flush with a rig floor of the well rig. Another spider can include a pipe guide assembly with multiple guides and guide actuators. Each guide actuator rotates a respective one of the pipe guides about a respective guide axis that is parallel to the central axis.

Abstract: Methods, tools, and systems for determining CO2 saturation in a porous formation using pulsed neutron logging are described. Embodiments of a pulsed neutron logging tool feature a pulsed neutron generator configured to emit pulsed neutrons into the formation and at least two detectors configured to receive emitted photons. The first detector is located closer to the neutron generator than the second detector. Embodiments of the method involve determining first detector formation capture counts indicative of neutron capture photons originating from the formation and detected at the first detector, determining second detector borehole capture counts indicative of neutron capture photons originating from the borehole and detected at the second detector, using the first detector formation capture counts and the second detector borehole capture counts to estimate the saturation of CO2 in the formation.