Abstract: A flexible hose assembly for horizontal well drilling is provided. The flexible hose assembly has a number of spaced thruster couplings along its length to impart drilling force to a nozzle blaster at an end of the flexible hose. The thruster couplings have rearwardly oriented holes which impart a forward drilling force upon the exit of high pressure water through the holes. A method of horizontal well drilling using the above-described flexible hose is also provided. The method is particularly useful for shallow wells, such as 50-2000 feet.

Abstract: A directional boring device is provided for attachment to a carrier having a power source for providing a first power supply to the boring device for moving the device and a second power supply for operating the device. The boring device includes an attachment frame, and a selectively attachable first coupler for coupling the attachment frame to the first power supply to permit movement of the device. A drill tool assembly is provided that includes a drill head, a drill stem attachable to the drill head, a drill bit attachable to the drill stem and a drill assembly power transmission. The drill assembly power transmission imparts rotational and axial movement to the drill tool assembly whereby the drill assembly transmission is capable of moving the drill head and drill stem in a path generally parallel to the plane on which the carrier rests.

Abstract: Methods and apparatus are provided which permit well testing operations to be performed downhole in a subterranean well. In various described methods, fluids flowed from a formation during a test may be disposed of downhole by injecting the fluids into the formation from which they were produced, or by injecting the fluids into another formation. In several of the embodiments of the invention, apparatus utilized in the methods permit convenient retrieval of samples of the formation fluids and provide enhanced data acquisition for monitoring of the test and for evaluation of the formation fluids.

Abstract: This invention provides apparatus and methods for controlling the particle size of the solid mass present in the circulating drilling fluid returning from an underwater wellhead during the drilling of a subsea wellbore. The system may include a separator at the sea floor adjacent the wellhead, which separates solids above a predetermined size from the wellstream. The wellstream then enters one or more underwater pumps, which pump the wellstream to the surface. A crusher, as a separate unit, integrated in the separator or in the pump, receives the separated solids and reduces them to relatively small-sized particles. The small particles are then pumped or moved to the surface by the pumps utilized for pumping the wellstream to the surface or by a separate underwater pump. Alternatively, the separated solids are collected from the separator into a container, which container is then transported to the surface by a suitable method.

Abstract: A means and method for improving the injection of coiled tubing into and from a well by providing a secondary injection device for supplementing the thrust forces of the primary injector means. Use of the secondary injection device coacting in tandem with the coiled tubing injector permits developing significantly higher axial forces in the tubing than can be provided by the primary injector alone. The selectably operable thrust enhancement device of this invention provides a short, repeatable stroke in either direction. The thrust enhancement device operates by selectably gripping the tubing with a reciprocably moveable means in a first position, shifting the moveable means to a second position thereby moving the tubing, gripping the tubing with a static means at its new position, releasing the tubing from the moveable means, and returning the moveable means to its first position. When the thrust enhancement device is not needed for the injection operation, its gripping means are disengaged from the tubing.

Abstract: A communication tool (100) for communicating hydraulic fluid through a tubing retrievable safety valve (50) is disclosed. The tool (100) has a first section (102) and a second section (132) that are initially coupled together. A set of axial locating keys (112) is operably attached to the first section (102) and is engagably positionable within a profile (62). A radial cutting device (148) is radially extendable through a window (152) of the second section (132). A circumferential locating key (140) is operably attached to the second section (132) and is engagably positionable within a pocket (66) of the safety valve (50) when the first and second sections (102, 132) are decoupled, thereby circumferentially aligning the radial cutting device (148) with the non annular hydraulic chamber (60).

Abstract: Methods and apparatus for forming metal or metal alloy casings in well bores are provided. A method of the invention comprises the steps of providing and pumping a fluid suspension of a particulate metal or metal alloy into a pipe string within a well bore having a casing forming tool connected thereto. The casing forming tool includes an internal passageway sealingly communicated with the pipe string and with a plurality of radial openings in the tool positioned around the periphery thereof. An internal heater for heating the fluid suspension and melting the particulate metal or metal alloy and an internal rotating impeller for imparting centrifugal force to the fluid suspension are provided in the casing forming tool. Centrifugal force is imparted to the fluid suspension by the rotating impeller whereby the melted particulate metal or metal alloy forms a casing which solidifies on the walls of the well bore.

Abstract: A method and apparatus for recomputing an optimum path between a present location of a drill bit and a direction or horizontal target uses linear approximations of circular arc paths. The technique does not attempt to return to a preplanned drilling profile when there actual drilling results deviate from the preplanned profile. By recomputing an optimum path, the borehole to the target has a reduced tortuosity.

Abstract: The present invention presents an improved method and apparatus for liquid entrainment by a two-phase flow system. The present invention provides an apparatus that recovers liquids by entrainment without experiencing deadhead conditions, choking or dry recovery due to fluctuations in the elevation of the liquid level. The apparatus provides self-regulated two-phase recovery of gas and liquid by construction design, thus eliminating the need for manual adjustments or electronically controlled devices. The enhanced venturi effects of the present invention enhance liquid lift while maintaining the gas recovery point above the liquid at all times to eliminate deadhead conditions.

Abstract: A running tool for a wellhead has an outer sleeve, a piston, an inner sleeve, each with respective hydraulic chambers, and a pair of collets for engaging a tubing hanger in a wellhead. Pressure is applied to the various chambers to actuate the collets and engage and/or release the tubing hanger. This process is gradual so that the tubing hanger is landed softly in a production bore of a tree or wellhead. The piston is forced downward to actuate a lower sleeve and move locking dogs into a bore profile to secure the tubing hanger. This process is reversed to release the collets and detach the running tool from the tubing hanger. The running tool is then brought back to the surface without the tubing hanger, which remains landed in the bore.

Abstract: Grip and guiding device for directional drilling, in order to drill straight or curved holes with a predetermined path. The device includes a drill string (11-21) comprising parts which rotate during drilling, including a drill bit (11) or a water hammer on its front end and a non-rotating packer unit (14) with a packer tubing (28) comprising one or several projecting pressure pads (25,31-32) arranged behind the drill bit (11) or the water hammer. The pressure pad or pads are arranged to be pressed out towards the drill hole wall by means of the pressure from a drill fluid when this exceeds a certain level. The pressure pad (25) or the pressure pads (25A-25C) may be arranged asymmetrically and/or affects the packer tubing (28) asymmetrically, e.g. by having different heights. The pressure pad(s) force guiding ribs on the opposite side into the hole wall in order to prevent rotation of the packer unit (14). The pressure pad or pressure pads can on deactivation be withdrawn for performing linear drilling.

Abstract: An apparatus for reducing paraffin and asphaltene deposits in a pumping oil well including a polish rod having a portion extending outwardly of the earth and having a portion extending into an oil string tubing, a sucker rod string interconnected to the polish rod and extending through the oil string casing into the earth, and an insulating rod interconnected to a lower end of the polish rod and interconnected to an upper end of the sucker rod string. The insulating rod is formed of a material having a thermal conductivity of 0.0167 to 0.06 BTU/(sq. ft.)(hr)(deg.F)(ft). The insulating rod is formed of a body of fiberglass material, an upper connector affixed to the body and formed of a steel material, and a lower connector affixed to the body and formed of a steel material.

Abstract: Expandable tubing (20) has a tubing wall (22) comprising a plurality of deformable tubular structures (24). The structures (24) have permeable walls and containing a filter medium (28) such that fluid may flow through the structures (24) and the filter medium (28) and thus through the tubing wall (22).

Abstract: In one aspect of the invention apparatus and methods are provided for completing a wellbore using expandable sand screen. An apparatus including a section of expandable sand screen, and an expanding member is disposed in the wellbore on a tubular run-in string. Thereafter, the expandable sand screen is expanded in a producing area of the wellbore.

Abstract: A rolling cone bit includes at least one cone cutter having a gage row of cutter elements and a first inner row of near but off-gage cutter elements that are positioned so as to divide the sidewall and bottom hole cutting duty so as to enhance bit durability, maintain borehole diameter and improve ROP. The off-gage distance of the first inner row of cutter elements is defined for various bit sizes to optimize the division of cutting duty. The distance that the first inner row of cutter elements are off-gage may be constant for all the cones on the bit or may be varied among the various cones to balance the durability and wear characteristics on all the cones of the bit.

Abstract: A string of pipe formed by the connection together of multiple joints of shorter pipe segments is stored in the water space adjacent an offshore drilling rig. The pipe string bends from the drilling rig floor in a semicircular arc and enters the water adjacent the drilling rig. A curving guide is used to direct the pipe string movement. A platform extension from the corner of the drilling rig is provided to position a work area above the point at which the pipe enters the water. Multiple guides may be employed for simultaneously running two strings of pipe. The string may be stored in one or more long sections or in a single continuous string. The major portions of the string or long pipe sections may be stored below the surface of the water. Provision is made for pumping fluids through the pipe string, and/or the pipe sections, to the well. The string may be stored in a sleeve.

Abstract: Cement compositions including mixtures of substantially elastic material and cement that may be formulated exhibit reduced bulk volume shrinkage during curing as compared to conventional cement compositions. In one application, such cement compositions may be used for cementing in substantially closed system, such as the interior of a mold used for producing preformed concrete items.

Abstract: The invention is a subsea pump that includes pumping elements, each pumping element including a pressure vessel with a first and a second chamber therein and a separating member disposed between the first and second chambers. The first and second chambers are hydraulically connected to receive and discharge a hydraulic fluid and a drilling fluid, respectively. The separating member moves within the pressure vessel in response to a pressure differential between the first and second chambers. A hydraulic power supply is arranged to pump the hydraulic fluid to the first chamber of each of the pumping elements. A valve assembly is hydraulically coupled to the first chambers of the plurality of pumping elements and to the hydraulic power supply. Volume measurement devices are arranged to measure volumes of each of the first chambers and the second chambers.

Abstract: Reinforced borehole plugs useful in the presplitting and blast removal of earth formations, the improvements provided by the invention comprising inflatable devices intended to support stemming, explosives and the like at suspended locations within a borehole to produce desired blast results. The borehole plugs of the invention comprise inflatable sport balls such as are used on playgrounds as toys and which are reinforced according to the invention to maintain inflation within a borehole, a characteristic which playground balls can only inconsistently provide. The borehole plugs of the invention are preferably inflatable through use of valve structures which permit pumping of an inflating fluid into the plugs once the plugs are respectively suspended at desired locations within boreholes prior to filling the boreholes in whole or in part with stemming and/or explosives and the like.

Abstract: An insert for a rolling cone earth-boring bit has a cylindrical base that interferingly presses into a mating hole formed in a cone of the bit. The insert has a convex end that extends from the base. A polycrystalline diamond cap is bonded to the convex end. The body is formed of at least two layers of carbide material having different mechanical properties, particularly a different modulus of elasticity. The first layer may have a metallic binder with a lesser percentage than the binder of the second layer to reduce the stress at the interface between the first layer and the diamond cap. The layers may have different average carbide grain sizes, with finer average grain sizes adjoining the diamond cap. Further, the layers may have different binders, with cobalt being the binder in the layer adjoining the diamond cap and either nickel or a nickel-cobalt alloy in another layer.