Abstract: A setting tool for actuating a downhole component includes an inner tubular configured to be connected in fluid communication with a borehole string, a housing configured to define a first fluid chamber and a second fluid chamber isolated from the first fluid chamber and in fluid communication with the inner tubular, and a setting piston in pressure communication with the second fluid chamber. The setting tool includes a metering module coupled to the housing and disposed at an end of the first fluid chamber, the metering module including a fluid path forming a restriction therein, and an outlet connected to the fluid path. The outlet is configured to be opened to permit fluid to flow out of the first chamber at a controlled rate to generate a differential pressure between the first and second chambers that causes the setting piston to apply a gradually increasing force on the component.

Abstract: Methods and systems for performing cleaning operations in boreholes penetrating earth formations are described. The methods include obtaining parameter information related to one or more angles of inclination, comparing the obtained parameter information to one or more criteria associated with each respective obtained parameter, generating a cuttings bed model based on the obtained parameter information, obtaining additional parameter information related to the one or more angles of inclination, updating the cuttings bed model in a pseudo-transient manner, determining that a hole cleaning operation is necessary, and at least one of (i) generating an indication that a hole cleaning operation is to be performed and (ii) automatically performing a hole cleaning operation.

Abstract: An electrical submersible pump has a stack of diffusers within the housing, each of the diffusers having a conical upper shoulder and a conical lower shoulder. The lower shoulder of each of the diffusers is in abutment with the upper shoulder of an adjacent one of the diffusers. The upper and lower shoulders of each of the diffusers slope downward and outward relative to the axis. Impeller hubs have conical upper and lower ends. At least some of the upper ends of the hubs abut and transfer up thrust to the lower end of an adjacent one of the hubs. At least some of the lower ends of the hubs abut and transfer down thrust to the upper end of an adjacent one of the hubs.

Abstract: A copolymer useful as a water clarifier for a water phase of a production fluid is selected from those with a first monomer and a second monomer, and in one non-limiting embodiment having the general formula: wherein y is 10 to 50,000; z is 1 to 10,000 and n is 1 to 250. The copolymer may optionally include a third monomer. In an optional embodiment of the process, the fluid has a hydrocarbon phase, and the process further involves simultaneously drying the hydrocarbon phase of the fluid along with clarifying the water phase.

Abstract: Systems and methods to evaluate a formation by analyzing drill cuttings involve a multi-frequency dielectric coaxial probe to obtain a reflected voltage from a medium under test based on a reference voltage over a frequency range. The medium under test includes the drill cuttings. The system includes a processor to compute an effective permittivity of the drill cuttings over the frequency range based on a reflection coefficient, which is a ratio of the reflected voltage to the reference voltage over the frequency range, and to determine one or more parameters from the effective permittivity. The one or more parameters are used to make decisions about subsequent drilling in the formation.

Abstract: A method of estimating downhole fluid properties includes deploying a borehole string in a borehole in a resource bearing formation, simulating a downhole fluid property distribution along a length of the borehole string using a mathematical hydraulics model, the fluid property distribution related to downhole fluid pressure, measuring a downhole fluid property related to downhole fluid pressure at a selected location along the length of the borehole string to generate a measured fluid property value, and comparing the measured fluid property value to a simulated downhole fluid property at the selected location. The method also includes calculating a correction value based on a difference between the measured fluid property value and the simulated fluid property value at the selected location, correcting an entirety of the fluid property distribution along the length based on the correction value, and controlling a downhole operation based on the corrected fluid property distribution.

Abstract: An embodiment of a downhole device includes an elongated body configured to be deployed in a borehole in an earth formation, the borehole including a borehole fluid. The device also includes a propulsion system attached to the body and configured to move the device through the borehole. The propulsion system includes one or more rotor blades configured to generate thrust using the borehole fluid. At least part of the one or more rotor blades is disposed external to the elongated body.

Abstract: A method of cementing a wellbore comprises injecting into the wellbore a cement slurry comprising an aqueous carrier, a swellable nanoclay, and a solid delayed releasing divalent inorganic salt comprising calcined magnesium oxide, calcined calcium oxide, calcium magnesium polyphosphate, a borate, a nitride, a silicate, an agent having a cation of Ba2+, Sr2+, Fe2+, Ni2+, or a combination comprising at least one of the foregoing; and allowing the cement slurry to set.

Abstract: Fouling components within a fluid may be prevented from accumulating when an additive contacts the fluid, e.g. by coating the wellbore with the additive prior to the production of the fluid or adding the additive directly to the fluid, etc.. The additive may include, but is not limited to, a block copolymer having at least two components. The first component may be a charged monomer, and the second component may be a long chain fatty alcohol acrylate monomer. In one alternative embodiment, the fluid may be an oil-based fluid produced through a wellbore or an oil-based wellbore fluid, and the fouling components may be or include, but are not limited to, wax, paraffins, asphaltene, resins, and combinations thereof.

Abstract: A collapsible packer for use in a well includes a deployment assembly, a retraction assembly and a sealing assembly extending between the deployment assembly and the retraction assembly. The deployment assembly may include a spring and a degradable stop configured to offset the force applied by the spring. The degradable stop can be manufactured from a material that dissolves when contacted by fluid in the well. The retraction assembly may by hydraulically or spring energized.

Abstract: A downhole communication repeater adapted for use on a wired drill pipe that extends from a surface to a bottom hole assembly that includes downhole communication equipment, and the surface has surface communication equipment located thereon. The repeater includes memory adapted: to store segments of logging-while-tripping data received from said downhole communication equipment and a microprocessor adapted to receive said logging-while-tripping data; to store said logging-while-tripping data in said memory while said repeater is deployed along a drill string in a well; and to re-transmit segments of said logging-while-tripping data while said repeater is cut off from downhole communications during a tripping operation.

Abstract: A wellhead system includes a first position casing hanger and a second position casing hanger, arranged within a wellbore. The second position casing hanger is positioned axially higher and stacked on the first position casing hanger, and a weight of the second position casing hanger is supported, at least in part but less than entirely, by the first position casing hanger and, at least in part but less than entirely, by an actuated load shoulder transferring the force into a high pressure housing. The actuated load shoulder includes a load ring having a hanger side profile and a housing side profile, the load ring is adapted to engage a hanger profile formed in the second position casing hanger and a housing profile formed in the high pressure housing upon activation via the first position casing hanger.

Abstract: An adaptable anchor including a frame; an arm articulated to the frame; a pad connected to the arm at a distance from the articulation with the frame; a wedge movably mounted to the frame and in wedging contact with the arm; a biasing member disposed to selectively apply a biasing energy between the frame and the wedge; and a degradable retainer preventing application of the biasing energy until degraded. An embodiment of a borehole system including a borehole in a subsurface formation; a tubular member disposed in the borehole; and an adaptable anchor as in any prior embodiment in operable contact with the tubular member. An embodiment of a method for anchoring a tool in a borehole including running the adaptable anchor as in any prior embodiment; degrading the degradable retainer; urging the wedge into contact with the arm with the biasing member; and displacing the pad.

Abstract: Systems and methods to cover sensitive areas of downhole tools including a downhole tool having an outer surface including a first position and a second position on the outer surface of the downhole tool, the outer surface having a sensitive area, a downhole sensitive element positioned along the outer surface of the downhole tool at the sensitive area, a movable cover operatively connected to the downhole tool and movable relative to the sensitive area, a control unit configured to generate an activation signal, and an activation mechanism operable in response to the activation signal, the activation mechanism configured to move the movable cover relative to the sensitive area from the first position to the second position, wherein the movement of the movable cover from the first position to the second position one of increases or decreases a portion of the sensitive area covered by the movable cover.

Abstract: A perforation blocking sleeve is provided for use in well restimulation, the perforation blocking sleeve having a first anchoring device and one or more expandable members secured to an outer surface of the perforation blocking sleeve. The first anchoring device may be used to secure the perforation blocking sleeve over a perforation cluster within a perforated well casing. The perforation blocking sleeve defines a flow channel and may be remotely and individually uncoupled from a running tool. The perforation blocking sleeve flow channel is sized such that the running tool and a running tool driver are retractable through the flow channel of the perforation blocking sleeve. In one or more embodiments, the perforation blocking sleeve contains an organic polymeric material which expands on contact with a production fluid or an exogenous fluid introduced into the well.

Abstract: Fluids produced from a fractured subterranean formation may be monitored by pumping into the well a fracturing fluid which contains a tracer. The method may be used to monitor produced hydrocarbons as well as produced water. The tracer may also be used in a sand control, frac pack or acid fracturing operation. The tracer is a component of a composite where it may be immobilized within a matrix (such as an emulsion) or porous particulate, onto a support or compressed with a binder into a solid particulate. The tracer may be slowly released from the composite.

Abstract: A resource exploration and recovery system includes a first system, a second system including a tubular string having an inner surface, a connector system provided at the inner surface, a screen component, and a cable extending between the connector system and the control system. The connector system includes at least one connector component and at least one frangible link component. A tractor is deployable into the tubular string. The tractor includes a cable reel having an amount of cable deployable in the tubular string. The tractor is connected to a control system and is operable to configure at least one component in the tubular string including at least one of the connector component, the frangible link component and the screen component.

Abstract: The flow of a fluid may be diverted from a high permeability zone to a low permeability portion of a subterranean formation by use of particulates comprising dicarboxylic acid, ester or an anhydride of the formula: or an anhydride thereof, wherein R1 is —COO—(R5O)y—R4 or —H; R2 and R3 are selected from the group consisting of —H and —COO—(R5O)y—R4, provided both R2 and R3 are —COO—(R5O)y—R4 when R1 is —H and further provided only one of R2 or R3 is —COO—(R5O)y—R4 when R1 is —COO—(R5O)y—R4, R4 is —H or a C1-C6 alkyl group, R5 is a C1-C6 alkylene group, and each y is 0 to 5. The dicarboxylic acid, ester or anhydride may further be admixed with an aliphatic polyester having the general formula of repeating units: where n is an integer between 75 and 10,000 and R is selected from the group consisting of hydrogen, alkyl, aryl, alkylaryl, acetyl, heteroatoms, and mixtures; thereof.

Abstract: A tool for use in a wellbore includes a first tubular having an outer surface and an inner surface defining a first conduit. The inner surface includes a dog engagement zone. A second tubular includes an outer surface portion and an inner surface portion defining a second conduit. The second tubular extends into the first conduit and including a dog opening having a dog support. A dog is arranged in the dog opening. The dog includes an outer surface contour that engages with the dog engagement zone and an inner surface including a recess that engages with the one or more dog supports. The dog is moveably retained between the first tubular and the second tubular.

Abstract: A well treatment fluid containing borated galactomannan may be used to isolate a pre-determined productive zone in an oil or gas well. The fluid is pumped into the well in a substantially non-hydrated form and forms a temporary seal. The fluid may be used as a chemical packer in place of a mechanical packer. After the pre-determined productive zone is isolated, a well intervention operation may be performed within the isolated pre-determined zone.