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 reel assembly having three reels disposed side-by-side on a shaft pays out coiled tubing to an injector. A conveyor is used to support and guide the coiled tubing during travel from the reels to the injector. The conveyor is selectively rotatable such that the conveyor may be directed to the reel which actively pays out the coiled tubing. In another embodiment, two reels are slidably disposed side-by-side on a shaft. A conveyor is used to support and guide the coiled tubing during travel from the reels to the injector. In this embodiment, the conveyor is directed to a specific location on the shaft and the reels are slid into the specific location for coiled tubing payout.

Abstract: A drilling head with a cone rock bit, each cone having a stationary part and a rotary part which rotates about an axis of rotation. Also included is a dynamic sealing device between the stationary part and the rotary part. The sealing device is borne by the rotary party and has a first sealing lip and a second sealing lip, each of which forms a surface of revolution about the axis of rotation. Further, the first and second lips bear respectively against a first bearing face and a second bearing face secured to the stationary part. The first lip is oriented in such a way that it presses against the first bearing face under the action of the pressure, and the second lip is oriented in such a way that it moves away from the second bearing face under the action of the pressure of the lubricating product, so as to allow this product to fill a cavity and compensate for the pressure in the cavity.

Abstract: A marine riser, particularly but not exclusively for use in connecting a subsea well installation to a dynamically positioned servicing vessel, comprises at least one section formed from rigid pipe and at least one section formed from flexible pipe. Preferably, the upper and lower sections (10, 12) are formed from fixed lengths of flexible pipe and the central section is formed from a plurality of lengths of rigid pipe which may be assembled to make up any required length. The riser may be deployed from a moonpool of the vessel and serves to accommodate movements of the vessel on the surface. This allows the use of a dynamically positioned service vessel rather than a conventional drilling rig.

Abstract: In accordance with the present invention, a downhole separation tool is provided which utilizes a downhole separation chamber with a series of fluid regulators responsive to a formation fluid and constituent components for separate desirable formation yields from the less desirable yields prior to lifting the fluids to the surface. The separation chamber has an input for the formation fluid, a production output, and a disposal output, in a tree arrangement according to the density order of the fluids in the separation chamber. The input flow regulator is coupled to the separation chamber input, the production regulator is coupled to the production output, and the disposal regulator is coupled to the disposal output. Each of the regulators are responsive to a fluid density of the formation fluid, first constituent and remainder constituent, accordingly, to regulate the flow of the respective fluid.

Abstract: There is provided a multilateral well and electric transmission system comprising a branch well tubular in a branch wellbore which is connected in an electrically conductive manner to a primary well tubular in a primary wellbore such that the primary and branch well tubulars form a link for transmission of electrical power and/or signals between the primary and branch wellbores. Low voltage electrical power can be transmitted from the surface to a battery in the branch wellbore to trickle-charge the battery and signals from battery-actuated measuring and control equipment in the branch wellbore can be transmitted back to surface via the walls of the electrically interconnected primary and branch well tubulars.

Abstract: A subterranean well tool is run through a well bore tubular and includes a well plug having an expandable elastomer member. An articulating anti-extrusion support system is provided for the well plug to resist extrusion of the elastomer. The system includes upper and lower platforms which are shiftable outwardly by a control mandrel. The platforms support extrusion resistors in the form of a series of crushable plates over which companion flexible cups are disposed and provide blade elements which may be flexibly positioned for inter-alignment around wing portions of the crushable plates for resistance of elastomeric extrusion. An elastomer member may include a series of spirable elastomeric sealing rings which, upon application of compressive load through the mandrel, expand in a helixical configuration through truncation initiation.

Abstract: A tool for isolating segments of a wellbore. The tool includes a packing cup housed in a protective sheath during the insertion of the device into the wellbore. The packing cup is radially outward biased. The protective sheath is removable. Upon removal of protective sheath the packing cup expands and creates a seal with the wellbore. Pressurized fluid pumped through the tool increases pressure within the segment and tightens the packing cup seal. Packing cup also acts like a piston, imparting a force to a packing element predisposed to buckle in a radially outward direction. Packing element makes a second seal with the wall of the wellbore. A hydraulically actuated button slip assembly anchors the tool in place. The tool can contain significant pressure to facilitate well stimulation and completion by fracture or acidization. The tool can also be used to facilitate measuring production from an isolated segment of the well.

Abstract: A system and process for reducing the flowing bottom-hole pressure in a natural gas well has a first discrete fluid flow path extending from the surface well head through a valve to an inlet of a separator, the valve being actuable between a closed condition and an open condition, and a second discrete gas flow path extending from an outlet of the separator to an inlet of a compressor, the compressor maintaining a near or below zero PSIG pressure at the separator inlet. When the valve is in the closed condition, positive pressure builds on the well head side of the valve and, when the valve is in the open condition, the near or below zero PSIG pressure of the separator is applied to the well head.

Abstract: The present Invention relates to hydrocarbon well stimulation, and more particularly to methods and compositions to remove (or more generally to transfer) fluid introduced into the subsurface. For instance, preferred methods involve creating then exploiting a capillary pressure gradient at the fracture face to induce fluid flow from the fracture into the formation thereby increasing effective fracture length, and then improving fracture conductivity.

Abstract: A flow and pressure control valve for injecting a fluid into a well, or for pumping the fluid out of the well, includes an outer housing, a mandrel within the outer housing, and a pressure element attached to the mandrel. The pressure element can be pressurized to move radially inward to constrict a longitudinally extending flow passage in the valve between the mandrel and the outer housing. In addition, the mandrel includes annular orifices, and channel segments along the outside diameter thereof, which form tortuous and circumferential flow paths through the valve. The annular orifices and channel segments are constructed to provide a desired frictional head loss, and to control the pressure and flow rate of the injected fluid to prevent cavitation and cascading. Pressurization of the pressure element can also be controlled to vary the tortuous flow path through the flow passage, or to seal the flow passage.

Abstract: The present invention allows a well to be produced through a screen without the need for a gravel pack. This is accomplished by the placement of an expandable screen that can move radially outwardly when placed at the desired location against the wellbore and be porous enough with sufficient open area to allow production from the formation. The screen is placed in the desired location by using coiled tubing which can be preperforated for a support for the screen. The screen is protected during delivery to the desired location in the wellbore by providing a disposable or removable outer cover which can be disposed of after proper location on the screen in the wellbore.

Abstract: A process for cleaning-up drilling and completion fluid filtercakes using an aqueous wash containing water and cationic salts of polyaminocarboxylic acids at neutral or acidic pH.

Abstract: Removal of Light, non-Aqueous Phase Liquids (LNAPLs) from contaminated soils is expedited by injecting gas into extraction wells. The extraction wells are operated with a vacuum assist which produces a mounding of groundwater around the well. Gas is injected into the groundwater within the extraction well in the form of micro-bubbles. The bubbles rise through the LNAPL and volatilize it. The volatilized LNAPL is drawn to the surface and groundwater is left in the well.

Abstract: An internal junction stabilizer is formed with an outer dimension less than the internal bore of a junction to be strengthened The stabilizer is inserted into the junction, and expanded into tight fit. Multiple stabilizers may be expanded one inside another to form a laminate for reinforcement in high pressure applications. Each layer of metal expanded to the next outermost section provides an additive effective on the mechanical properties of the junction. Expansion can be performed in a number of ways, including mechanical, hydraulic, explosive methods. Use of directional or selective swaging can be used to further effect a fit. Further embodiments of the invention include the use of sealing compounds, elastomers, and plastics to effect a hydraulic seal and fill gaps for strength purposes.

Abstract: An apparatus for assisting the advancement of a work string. In the preferred embodiment, the work string is concentrically disposed within a highly deviated tubular member. The apparatus comprises a cylindrical member having a first half clamp and a second half clamp having an arcuate inner portion, with the first half clamp and second half clamp being connected with a hinge. The apparatus further includes a first housing attached to the first half clamp and a second housing attached to the second half clamp. The apparatus further comprises a first roller inserted into the first housing and a second roller inserted into the second housing. In the preferred embodiment, the first and second rollers are spherical. The apparatus may further comprise a first deflector plate operatively associated with a first side of the first housing and the second housing. The first deflector plate has a first end adjacent the cap member and a second end adjacent the first half body so that an angled end is formed.

Abstract: A retrieval head (14) coupled to a downhole tool that is used for retrieving a drill bit composed of individual drill bit segments (14). The down hole tool is adapted to travel through a drill sting and a drive sub (12) attached to the drill string. The tool also releases segments (14) which are clamped between the drive sub (12) and a bit locking sleeve (16). The retrieval head (10) includes a body (30) having a first length (32) and a contiguous second length (34). The first length (32) is of constant diameter. The second length (34) has a portion (42) of reduced diameter relative to that of the first length (32). The diameter of the first length (32) is dimensioned so that the bit segments (14) can initially collapse radially inwardly wholly onto an outer circumferential surface (38) of the length (32). The reduced diameter portion (42) is dimensioned so that when the bit segments (14) are disposed thereon, the bit segments (14) can pass through the drive sub (12) and bit locking sleeve (16).

Abstract: An apparatus for launching at least one plug into a tubular in a wellbore, in certain aspects, the apparatus having a hollow upper section with at least first and second upper ports one above the other, a landing seat, and a first fluid displaceable member below the second upper port, the hollow lower section adapted to retain a plug and having a first lower port and a landing collar for the fluid displaceable member.

Abstract: The present invention is a connector which connects a first control line in a downhole well tool to a second control line. The connector may include a main body having a longitudinal bore therethrough, a tubular extension threadably secured within a mounting bore in the well tool, and a metal seal ring disposed between a shoulder on the tubular extension of the main body and having an outer conical surface engaged with a conical surface of the mounting bore. The connector may also include a sealing sleeve having a longitudinal bore including a first conical surface adjacent a first end of the sealing sleeve and a second conical surface adjacent a second end of the sealing sleeve; a first ferrule, a second ferrule, and a third ferrule, each being an annular member having an outer conical surface and disposed within the longitudinal bore of the main body.

Abstract: A support table with an upwardly extending tubular neck engages the lower surface of the upper connector of the string to support the string while resting on a floor-level support. The neck is small enough for an elevator to close around the neck and still engage the outer portion of the lower surface of the connector. The support table is split into separable parts for opening to install and remove it from around the string. The base of the support table is large enough to stand on the rig floor level support. Optionally, a liner is provided for an oversize elevator bore to provide an axially short, inwardly extending, lower flange. On the upper end the liner has an outwardly extending flange to engage the usual load bearing surface of the elevator. The liner is split to open with the elevator, with each portion secured to the elevator by at least one fastener.