Abstract: A method and system for servicing a well. Servicing a well often includes running a service string into a production string, which may include a rod string. A service portion is provided in the production string during completion. The service portion is located at or uphole of a large rod string feature. The service portion has a greater inside diameter than production tubing and other standard production string components. The service portion provides sufficient clearance for the service string alongside the large feature. The large feature may be, for example, a PCP stator, a centralizer, or a rod collar. The large feature may be pulled uphole into the service portion prior to running in the service string, allowing servicing downhole of the large feature without pulling the entire rod string. The service portion may also mitigate rod wear in deviated or other portions of the well.

Abstract: A subsurface tool adapted to extend within a wellbore that includes an outer sleeve defining a first passageway; an inner sleeve disposed within the first passageway to form an annulus between the outer sleeve and inner sleeve; and a first annular diaphragm extending between the outer sleeve and the inner sleeve to fluidically isolate a first portion of the annulus from and a second portion of the annulus; wherein when the tool is in a first configuration, the first annular diaphragm is integrally formed with the inner sleeve and outer sleeve to form a single-component tool.

Abstract: A downhole assembly comprises a disintegrable article comprising a metal, a metal alloy, a metal composite, or a combination comprising at least one of the foregoing; the disintegrable article being corrodible in a downhole fluid; a current source configured to supply electrons to the disintegrable article and to delay or reduce the corrosion of the disintegrable article in the downhole fluid; and a controller configured to control the supply of electrons to the disintegrable article.

Abstract: Various embodiments include apparatus and methods to provide an estimation of casing wear. One method determines values of casing and drill string variables and constants. These constants and variables are used to dynamically generate an estimate of casing wear, based on a stress theory. The drilling operation can be halted when the estimate of casing wear reaches a predetermined value.

Abstract: A radiation detection assembly that includes an ionization chamber having a cathode and an anode. The ionization chamber detects radiation that passes into the ionization chamber. The assembly includes an exterior enclosure defining a hollow internal volume within which the ionization chamber is enclosed. The exterior enclosure includes at least two layers. At least one of the layers provides an electromagnetic shield to the hollow internal volume and the ionization chamber enclosed therein.

Abstract: The subject matter of this specification is directed to a method that includes providing an outer tubular member having a bore with an inner surface, applying a lubricant layer to at least a portion of the inner surface of the outer tubular member, and positioning the outer tubular member in at least a portion of the wellbore. During the drilling process, mechanical wear between the outer and inner members can be measured by an indicator to determine if the measured indicator exceeds a predetermined threshold level.

Abstract: A method of laying a pipeline comprising a plurality of tubular components is disclosed. The method includes depositing a weld material onto a surface of a first tubular component of the plurality of tubular components and machining a profile into the weld material. The profile includes a support shoulder into the weld material. The method further includes suspending the first tubular component in a vertical or near vertical position and supporting the first tubular component by the support shoulder. A further tubular component of the plurality of tubular components is connected to a free end of the first tubular component. The support shoulder is formed at a point spaced from the free end of the first tubular component thereby facilitating connection of the first tubular component to the second tubular component.

Abstract: Embodiments may take the form of a tool string sub. The tool string sub may include a longitudinally extending tubular housing having an outside surface and an inside surface. A stepped circumferential portion of the inside surface of the housing bisects the interior surface of the housing. A degradation part is connected adjacent to the stepped portion of the housing and is supported by the housing and at least one moveable support part protruding inward and beyond the inner surface of the housing. The support part has a first position where the degradation part is at first stress and a second position where the degradation part is at a second stress greater than the first stress. At least one end of the tool string sub is adapted to connect with a tool string.

Abstract: A method of forming a downhole tool comprises contacting at least one downhole structure comprising at least one metal material with a molten electrolyte comprising anhydrous sodium tetraborate. Electrical current is applied to at least a portion of the at least one downhole structure to form at least one borided downhole structure comprising at least one metal boride material. Other methods of forming a downhole tool, and a downhole tool are also described.

Abstract: A technique facilitates the use of polymer materials in a downhole environment via utilization of a coating that can be applied to the polymer material. The methodology enables formation of a coating that sufficiently bonds with an underlying base structure of polymer material to withstand the harsh environment encountered in a downhole application. Additionally, the coating may utilize reactive chemistries to further protect the polymer material against the ingress of deleterious fluids while located in the downhole environment. Well tubulars formed of coated polymer are also described.

Abstract: A downhole device with compressive layer at the surface thereof. Such devices may be particularly well suited for survivability in the face of potentially long term exposure to a downhole environment. Techniques for forming protective compressive layers at the surfaces of such devices may include positioning devices within a chamber for bombardment by high frequency particles. As a manner of enhancing the compressive layer thickness and effectiveness, low temperature conditions may be applied to the device during the high frequency treatment.

Abstract: Provided are coated oil and gas well production devices and methods of making and using such coated devices. In one form, the coated device includes one or more cylindrical bodies, hardbanding on at least a portion of the exposed outer surface, exposed inner surface, or a combination of both exposed outer or inner surface of the one or more cylindrical bodies, and a coating on at least a portion of the inner surface, the outer surface, or a combination thereof of the one or more cylindrical bodies. The coating includes one or more ultra-low friction layers, and one or more buttering layers interposed between the hardbanding and the ultra-low friction coating. The coated oil and gas well production devices may provide for reduced friction, wear, erosion, corrosion, and deposits for well construction, completion and production of oil and gas.

Abstract: Provided are coated sleeved oil and gas well production devices and methods of making and using such coated sleeved devices. In one form, the coated sleeved oil and gas well production device includes one or more cylindrical bodies, one or more sleeves proximal to the outer diameter or inner diameter of the one or more cylindrical bodies, hardbanding on at least a portion of the exposed outer surface, exposed inner surface, or a combination of both exposed outer or inner surface of the one or more sleeves, and a coating on at least a portion of the inner sleeve surface, the outer sleeve surface, or a combination thereof of the one or more sleeves. The coating includes one or more ultra-low friction layers, and one or more buttering layers interposed between the hardbanding and the ultra-low friction coating. The coated sleeved oil and gas well production devices may provide for reduced friction, wear, erosion, corrosion, and deposits for well construction, completion and production of oil and gas.

Abstract: Provided are drill stem assemblies with ultra-low friction coatings for subterraneous drilling operations. In one form, the coated drill stem assemblies for subterraneous rotary drilling operations include a body assembly with an exposed outer surface including a drill string coupled to a bottom hole assembly, a coiled tubing coupled to a bottom hole assembly, or a casing string coupled to a bottom hole assembly and an ultra-low friction coating on at least a portion of the exposed outer surface of the body assembly, hardbanding on at least a portion of the exposed outer surface of the body assembly, an ultra-low friction coating on at least a portion of the hardbanding, wherein the ultra-low friction coating comprises one or more ultra-low friction layers, and one or more buttering layers interposed between the hardbanding and the ultra-low friction coating.

Abstract: A downhole device with compressive layer at the surface thereof. Such devices may be particularly well suited for survivability in the face of potentially long term exposure to a downhole environment. Techniques for forming protective compressive layers at the surfaces of such devices may include positioning devices within a chamber for bombardment by high frequency particles. As a manner of enhancing the compressive layer thickness and effectiveness, low temperature conditions may be applied to the device during the high frequency treatment.

Abstract: An apparatus and related methods for removing hazardous trace elements from hydrocarbon reservoir effluent is implemented by placing an adsorbing volume of material designed to adsorb the hazardous trace elements into the vicinity of a producing formation face at a downhole location; and letting the reservoir effluent flow through the volume of adsorbing material.

Abstract: Provided are coated sleeved oil and gas well production devices and methods of making and using such coated sleeved devices. In one form, the coated sleeved oil and gas well production device includes an oil and gas well production device including one or more bodies and one or more sleeves proximal to the outer or inner surface of the one or more bodies, and a coating on at least a portion of the inner sleeve surface, outer sleeve surface, or a combination thereof, wherein the coating is chosen from an amorphous alloy, a heat-treated electroless or electro plated based nickel-phosphorous composite with a phosphorous content greater than 12 wt %, graphite, MoS2, WS2, a fullerene based composite, a boride based cermet, a quasicrystalline material, a diamond based material, diamond-like-carbon (DLC), boron nitride, and combinations thereof.

Abstract: Liquid loading, corrosion and scaling in an oilfield tubular, such as a production tubing in a natural gas production well, is inhibited by treating the inner surface of the oilfield tubular (4,24) with a hydrophobic or other coating or lining which inhibits creation of a liquid film and promotes liquid droplet flow alongside said inner surface.

Abstract: Provided are coated oil and gas well production devices and methods of making and using such coated devices. In one form, the coated oil and gas well production device includes an oil and gas well production device including one or more bodies, and a coating on at least a portion of the one or more bodies, wherein the coating is chosen from an amorphous alloy, a heat-treated electroless or electro plated based nickel-phosphorous composite with a phosphorous content greater than 12 wt %, graphite, MoS2, WS2, a fullerene based composite, a boride based cermet, a quasicrystalline material, a diamond based material, diamond-like-carbon (DLC), boron nitride, and combinations thereof. The coated oil and gas well production devices may provide for reduced friction, wear, corrosion, erosion, and deposits for well construction, completion and production of oil and gas.

Abstract: An arrangement intended to be part of a rock drilling machine for percussive drilling. The arrangement includes a casing part with at least one plane end plane. The end plane includes at least a first region and a second region. The first region includes at least a part of the outer contour of the end plane and includes of a material that resists corrosion.

Abstract: Corrosion of metallic tubulars in an oil, gas or geothermal well may be inhibited by introducing into the well a dithiazine of the formula: wherein R is selected from the group consisting of a C1 to C10 saturated or unsaturated hydrocarbyl group or a C1 to C10 ?-hydroxy saturated or unsaturated hydrocarbyl group. The dithiazine may be isolated from a whole spent fluid formed by reaction of hydrogen sulfide and a triazine. Alternately, the whole spent fluid containing the dithiazine may be introduced into the well. In addition, the dithiazine or whole spent fluid may be formulated with at least one component selected from alkyl, alkylaryl or arylamine quaternary salts; mono or polycyclic aromatic amine salts; imidazoline derivative or a quaternary salt thereof; a mono-, di- or trialkyl or alkylaryl phosphate ester; or a monomeric or oligomeric fatty acid.

Abstract: Corrosion of metallic tubulars in an oil, gas or geothermal well may be inhibited by introducing into the well a dithiazine or dithiazine of the formula: wherein R is selected from the group consisting of a C1 to C12 saturated or unsaturated hydrocarbyl group or a C1 to C10 ?-hydroxy saturated or unsaturated hydrocarbyl group; R1 is selected from the group consisting of a C1-C24 straight chain or branched alkyl group or a C1-C24 arylalkyl; R2 is selected from the group consisting of X-R4-X, R4 being a C1-C6 alkyl group; and X is chlorine, bromine or iodine. The dithiazine may he isolated from a whole spent fluid formed by reaction of hydrogen sulfide and a triazine. Alternately, the whole spent fluid containing the dithiazine may be introduced into the well. The dithiazines of formulae (II) and (III) are quaternized derivatives of the dithiazine of formula (I).

Abstract: The present invention relates to an improved method and system for perforating, slotting, and cutting steel and subterranean rock; and also for fracturing a subterranean formation to stimulate the production of desired fluids therefrom. The invention involves a fluid jetting device with a sleeve composed of a hard material. The sleeve includes at least one hole and a fluid flowing through the jetting device is emitted through the hole in the sleeve.

Abstract: A heating system for a subsurface formation includes a conduit located in an opening in the subsurface formation. An insulated conductor is located in the conduit. A material is in the conduit between a portion of the insulated conductor and a portion of the conduit. The material may be a salt. The material is a fluid at operating temperature of the heating system. Heat transfers from the insulated conductor to the fluid, from the fluid to the conduit, and from the conduit to the subsurface formation.

Abstract: Systems, methods, and heaters for treating a subsurface formation are described herein. At least one system for electrically insulating an overburden portion of a heater wellbore is described. The system may include a heater wellbore located in a subsurface formation and an electrically insulating casing located in the overburden portion of the heater wellbore. The casing may include at least one non-ferromagnetic material such that ferromagnetic effects are inhibited in the casing.

Abstract: Protective barriers for small devices, such as sensors, actuators, flow control devices, among others, protect the devices from erosive and/or corrosive fluids, for example, formation fluids under harsh downhole conditions. The protective barriers include protective coatings and fluid diverting structures in the fluid flow which facilitate use of the small devices in high temperature-high pressure applications with erosive and/or corrosive fluids that are often found in downhole environments.

Abstract: A protective sleeve can be inserted through tubing and latched in a manner that resists rotation. At the conclusion of the through tubing operation that involves rotational movement, the sleeve is withdrawn on the string that previously extended through it.

Abstract: A casing shoe for a casing string that includes an annular body. The annular body includes an annular recess that forms an outer portion and an inner portion, the inner portion forming and extending into an inner bore. The annular recess can accept an end of the casing string such that the casing string extends between the inner and outer portions. The annular body includes a homogenous material. The casing shoe is used in a method of guiding a casing string into a wellbore where the casing shoe is attached to an end of the casing string. Attaching the casing string includes inserting the end of the casing string into the annular recess such that the casing string extends between the inner and outer portions. The casing string is then inserted into the wellbore.

Abstract: Described herein are compositions for reducing or preventing the degradation of equipment and articles exposed to hydrogen sulfide present in high concentrations in subterranean environments (e.g., oil and gas wells). The compositions are composed of a thermoplastic resin, a thermosetting resin, or a combination thereof, and at least one compound that interacts with hydrogen sulfide from the subterranean environment. In certain aspects, the compositions are coated on the article of interest. In other aspects, the composition is used to manufacture the article and, thus, is integrated throughout the article.

Abstract: A crossover tool that resists the erosive forces of high velocity slurry streams of gravel in downhole fracturing and gravel packing operations employs hardened inserts that protect the inside face of the housing as well as the openings through the crossover housing wall. The inserts have an extending portion that goes through housing openings preferably to the outer surface of the housing. The inserts also have inboard flanged surfaces that preferably abut or overlap to give preferably full inner wall protection to the housing from the flow of abrasive slurry. The inserts can be secured to each other or to the interior of the housing to hold them firmly in place.

Abstract: A technique facilitates the use of polymer materials in a downhole environment via utilization of a coating that can be applied to the polymer material. The methodology enables formation of a coating that sufficiently bonds with an underlying base structure of polymer material to withstand the harsh environment encountered in a downhole application. Additionally, the coating may utilize reactive chemistries to further protect the polymer material against the ingress of deleterious fluids while located in the downhole environment. Well tubulars formed of coated polymer are also described.

Abstract: The present disclosure provides a method, system, apparatus, and related alloy to provide a protective wear coating on a downhole component for a well through a synergistic use of a thermal spraying process in combination with a novel iron-based alloy. The thermal spraying process melts the material to be deposited while a pressurized air stream sprays the molten material onto the downhole component. The coating operation takes place at low temperatures without fusion or thermal deterioration to the base material. The wear resistance is increased while providing a lower coefficient of friction by the wear resistant layer relative to a coefficient of friction of the downhole equipment without the wear resistant layer. In at least one embodiment, the disclosed process using the iron-based alloy can apply a much thicker coating than heretofore has been able to be applied without spalling and without necessitating an intermediate buffer layer.

Abstract: An aperture design minimizes erosion on the surrounding casing and to the aperture itself and is particularly effective in fluid injection wells where large volumes of fluids over a long period of time with entrained solids are expected to be pumped through. The preferred design is an elongated shape with a flaring wider in the downhole direction. The downhole end of the opening features an exit that flares in the downhole direction with multiple slopes with an arc transition. Other options for the opening configuration are envisioned.

Abstract: A device for use with components for a downhole tool—such as a throat, a nozzle, or a diffuser—used for cleaning a wellbore, are disclosed which decreases the erosion of the components. The device may be comprised of a hardened material, such as stack of pure diamond disks brazed to form an insert for a throat. The device may also be comprised of polycrystalline diamond (PCD) washers stacked together and mechanically secured within the component such as a throat. The device may also be comprised of diamond grown on a mandrel into a trumpet shape, which may then be brazed or epoxied into the component. As each of these materials is harder than materials previously utilized, erosion performance is enhanced. A method of improving erosion performance of components utilized to clean a wellbore is also disclosed.

Abstract: Methods of and apparatus for drilling, casing and/or completing a borehole wherein one or more portions of the borehole are drilled into a formation at a single diameter along the entire length or depth of the or each portion of the borehole. An expandable tubular member is then located within the or each portion of the borehole and radially expanded in the or each portion to line and/or case it or them. Optionally, a corrosion resistant member and/or a service string can be located in the borehole. An advantage of certain embodiments is that a single diameter borehole is formed along the entire length or depth thereof.

Abstract: A clad pipe includes an external layer and a coating layer made of Ni base anticorrosion alloy. Both end portion areas of the coating layer are formed by a build-up welded layer (Ni base alloy of composition 1) on the inner surface of the external layer. Other areas are formed by a Ni base alloy layer (Ni base alloy of composition 2) fusion-bonded to the build-up welded layers and the inner surface of the pipe, a solidus-curve temperature of the Ni base alloy layer being 1300° C. or below and lower than a solidus-curve temperature of the Ni base alloy formed by build-up welding by 150° C. or more. Composition 1 and composition 2 are adjusted so that, in the same environment, corrosion resistance of the Ni base alloy of composition 1 is equivalent to or superior to that of the Ni base alloy of composition 2.

Abstract: A centralizer system is provided for use in a marine riser system with an insulated pipe, which may be a titanium stress joint. The centralizer system utilizes one or more centralizers mounted such that insulation material is provided in an annulus between the one or more centralizers and the stress joint. A clamp is utilized to axially affix either one centralizer or multiple centralizers to the stress joint. The clamp is comprised of a plurality of sections with cylindrical interior surfaces which are tightened together using fasteners. The cylindrical interior surfaces avoid damage to the insulation layer which may be elastomeric. The clamp and each centralizer have radially directed projections thereon which interlock the clamp with each centralizer. Because the clamp is axially affixed, the centralizer is then also axially affixed. In one embodiment, the centralizer is axially moveable to a desired axial position prior to being interlocked to the tightened clamp.

Abstract: It has been discovered that carbonate powders and bicarbonate powders are useful to increase the pH and corrosion resistance of high-density brines, such as zinc bromide brines, without significantly reducing their densities. The carbonates and/or bicarbonates should be water-soluble and may be sodium, potassium, magnesium and/or ammonium carbonates and/or bicarbonates and the like. The carbonates and/or bicarbonates are easily added in powder or other finely divided solid form.

Abstract: A downhole cathodic protection cable system includes an attachment shoe electrically connected to a metallic structure at a distance substantially below the earth's surface, and an electrical cable having a first end connected to a connection structure substantially at the earth's surface and a second end electrically connected to the attachment shoe. The first end is connected through the connection structure to provide current to the cable sufficient to prevent substantial corrosion surrounding the attachment shoe.

Abstract: The invention relates to a system and a method for well completion, control and monitoring of processes in a reservoir. A combined prefabricated liner and matrix system (4) with defined properties for fast and simple well and/or reservoir completion, monitoring and control is provided. An embodiment of the combined prefabricated liner and matrix system 4 includes an outer perforated tubular pipe system 6, an inner tubular screen 7, and a matrix 8. A method for control and monitoring of processes in a well or reservoir using the combined liner and matrix system is also described. The combined liner/matrix system may be used in any process equipment, such as reactors, separators and storage tanks. The system may also be used in a gas/oil/water producing or injection well for well completion, control and monitoring.

Abstract: Disclosed herein are tubular goods and tubular good liners which decrease or eliminate friction and mechanical wear and decrease or eliminate chemical corrosion to the walls of the tubular good. The liners may include a diffusion barrier, an adhesive, and a friction and wear resistant layer.

Abstract: A downhole cathodic protection cable system includes an attachment shoe electrically connected to a metallic structure at a distance substantially below the earth's surface, and an electrical cable having a first end connected to a connection structure substantially at the earth's surface and a second end electrically connected to the attachment shoe. The first end is connected through the connection structure to provide current to the cable sufficient to prevent substantial corrosion surrounding the attachment shoe.

Abstract: The present invention relates to a method for inhibiting high temperature corrosion of corrosion prone metal surfaces by organic acid-containing petroleum streams by providing an effective corrosion-inhibiting amount of 4-sulfophthalic acid, typically up to 1000 wppm, to the metal surface.

Abstract: The present invention relates to a method for inhibiting high temperature corrosion of corrosion prone metal surfaces by organic acid-containing petroleum streams by providing an effective corrosion-inhibiting amount of triphenylstibine, typically up to 1000 wppm, to the metal surface.

Abstract: A method of producing fluids from a well bore by polishing the inside diameter surface of a down-hole tubular. The method includes the steps of providing a down-hole tubular having an inside diameter and being made of a carbon steel alloy or a high chromium alloy, preparing an inside diameter surface of the down-hole tubular, subjecting the inside diameter surface to an electropolishing treatment to produce a smooth surface being slick and essentially non-stick, locating the down-hole tubular within the well bore adjacent a fluid-producing formation, and producing the fluids through the inside diameter of the down-hole tubular. The electropolishing treatment can also be applied to the inside diameter surfaces of carbon steel drill pipe.

Abstract: A method of producing fluids from a well bore by polishing the inside diameter surface of a down-hole tubular. The method includes the steps of providing a down-hole tubular having an inside diameter and being made of a carbon steel alloy or a high chromium alloy, preparing an inside diameter surface of the down-hole tubular, subjecting the inside diameter surface to an electropolishing treatment to produce a smooth surface being slick and essentially non-stick, locating the down-hole tubular within the well bore adjacent a fluid-producing formation, and producing the fluids through the inside diameter of the down-hole tubular. The electropolishing treatment can also be applied to the inside diameter surfaces of carbon steel drill pipe.