Abstract: A mast for lifting and suspending over a wellhead a coiled tubing injector and blow out preventer is pivotally mounted on a rear portion of a truck. The mast has two side-by-side telescoping legs that extend and retract synchronously. When in a retracted position, the blow out preventer and coiled tubing injector are attached to the mast, between the legs, and legs of the mast extended to lift the equipment.

Abstract: An elevator apparatus for manipulating well bore tubing includes a circular body having a top and a central cavity around a body axis. The cavity has a diameter allowing the collar portion of the tubing to pass longitudinally therethrough. A plurality of cavity restricting members above the body, supported on and spaced apart around the top of the body, have proximal and distal portions in respect to the cavity. One or more actuators are operatively associated with the petal plates for moving the proximal portion of each cavity restricting member into the cavity an extent sufficient, in combination with the other cavity restricting members so moved, to prevent passage of the collar portion of the tubing through the cavity, thereby to hold the tubing with the elevator.

Abstract: Drill rod holder (10) for clamping a pair of jaws against a drill rod (40), by a piston-cylinder arrangement (22). A first of the jaws is fixed and a second jaw (36) is movable by the piston-cylinder arrangement. A medium under pressure is introduced into the cylinder to urge the piston (26) and the second jaw attached thereto to release the second jaw from the drill rod. The cylinder (2) is pre-filled with a pressurized gas (46) acting on the piston (26) to urge the second jaw (36) against the drill rod to clamp the drill rod (40) between the jaws when the gas pressure exceeds the medium pressure. The second jaw (36) is arranged to move away from the first jaw (34) when the medium pressure exceeds the gas pressure.

Abstract: The present invention provides a wellhead hydraulic drive unit to operate various styles of downhole pumps, which is installed as an integral part of a wellhead thereby eliminating the need for a stuffing box. The wellhead hydraulic drive unit comprises a hollow hydraulic cylinder having a piston positioned therein, a hydraulic fluid supply attached to the hydraulic cylinder for raising the piston within the hydraulic cylinder, a hollow ram slideably received within the inner wall of the hydraulic cylinder and connected to the piston for reciprocation in response to the piston; and a production tube inserted through the ram for enabling well fluid to be discharged from the well.

Abstract: A snubbing unit for running and retrieving a string of tubing into a well under pressure selectively operates in a stand alone mode and a rig assist mode. The unit has a lower frame for mounting during the stand alone mode on a snubber blowout preventer. Stationary weight supporting slips and snubbing slips are carried by the lower frame during the stand alone mode. The unit has four hydraulic cylinders with weight supporting slips and snubbing slips carried by a traveling base plate on the piston rods. A stationary base plate is mounted between the lower frame and the traveling base plate. A spacer tube is connected to and between the lower frame and the stationary base plate in the stand alone mode. In the rig assist mode, the lower frame along with the stationary weight supporting slips and the spacer tube are removed to enable a rig blowout preventer to connect to the stationary base plate.

Abstract: A reciprocating lubricator includes a lubricator base, a lubricator tube connected at the top to a lubricator head and inserted through a packing in the lubricator base to provide a sealable chamber adapted to accommodate a downhole tool to be inserted into a wellbore against well fluid pressure. The chamber in the lubricator tube is sealed using equipment mounted to the lubricator head. Injectors interconnecting the lubricator base and the lubricator head reciprocate the lubricator tube through the lubricator base. When a downhole tool is inserted into the wellbore, the lubricator head rests against the lubricator base to provide a low, safe and stable position for operation of the equipment mounted to the top of the lubricator head.

Abstract: A method and apparatus for inserting or removing a string of tubulars from a subsea borehole. The apparatus includes a first, lower, gripping mechanism locatable subsea in the vicinity of the subsea borehole. The first gripping mechanism is capable of gripping a portion of the string of tubulars. The apparatus further includes a second, upper, gripping mechanism locatable subsea in the vicinity of the subsea borehole, the second gripping mechanism being capable of-gripping a portion of the sting of tubulars. The first and second gripping mechanisms are moveable with respect to one another. The apparatus further includes a movement mechanism which, when actuated, moves one of the first and second gripping mechanisms with respect to the other of the first and second gripping mechanisms, such that the string of tubulars is inserted into or removed from the subsea borehole.

Abstract: The present disclosure provides an apparatus and method for positioning a section of a well string. The apparatus includes a base plate and a turntable supported by the base plate. The turntable is preferably configured to rotate with respect to the base plate. At least one jack assembly is supported by the turntable and connects to a load collar, which is configured to support the section of the well string. The rotational position of the section of the well string can be adjusted by rotating the turntable. The vertical position of the section of the well string can be adjusted by raising or lowering the jack assembly.

Abstract: After an existing lower rod lock is tightened to keep a pump rod, which extends from a stuck pump rotor, from sliding down into a well, an existing upper rod lock/drive is loosened to allow the rod to slide through the upper rod drive.

Abstract: Apparatus for inserting a tubing hanger into a tubing head spool on a live well includes a landing spool and a landing joint that reciprocates through a top end of the landing spool. The landing joint is connected to the tubing hanger. The landing spool is connected to a top flange of a blowout preventer on the live well. The blowout preventer is then opened and the tubing hanger is injected into the tubing head spool. A lifting spool is also provided to permit the tubing hanger to be injected without the use of a service rig. Safety is improved, costs reduced and production is facilitated because the well does not have to be killed.

Abstract: Canister, sealing method and composition for sealing a borehole. The canister includes a container with slurry inside the container, one or more slurry exits at one end of the container, a pump at the other end of the container, and a piston inside that pushes the slurry though the slurry exit(s), out of the container, and into a borehole. An inflatable packer outside the container provides stabilization in the borehole. A borehole sealing material is made by combining an oxide or hydroxide and a phosphate with water to form a slurry which then sets to form a high strength, minimally porous material which binds well to itself, underground formations, steel and ceramics.

Abstract: A concentric casing jack is disclosed having a casing supporter and actuator that uses hydraulic fluid to vertically raise and lower an inner concentric string of casing in a well. This casing jack is connected to a string of casing and can operate down-hole tools attached to the lower end of the casing by actuating the casing. The casing jack is supported at the surface by the wellhead and can be incorporated into a series of drilling spools and blowout preventer valves that are commonly utilized during drilling operations. The casing jack consists of a housing and a hollow piston whose internal diameter is similar in size to the concentric casing. The similar sizing allows drill bits and bottom hole assemblies to pass through the hollow center of the casing jack and the attached string of casing. The piston is equipped with external seals to hold hydraulic pressure between the hollow piston and the body of the jack.

Abstract: Apparatus and method for inserting or removing a string of tubulars from a subsea borehole, comprising:

Abstract: A device for introducing high-pressure fluid through a well having a vertical passage with at least one valve and into a well having a well tubing into said vertical passage, has a lower part removably attachable to the well tubing, a hollow mandrel adapted to extend through the inner passage of the lower part and having a passage through which a high pressure fluid can be introduced, an upper part firmly connected with the mandrel to hold the mandrel and movable relative to the lower part between a distal position in which the upper part is spaced from the lower part and the mandrel is not introduced into the well tubing and a proximal position in which the upper part is located close to the lower part and the mandrel is introduced into the well tubing and passes through an area of the well tubing provided with the valve, so that when the high pressure fluid is introduced through the mandrel it can not affect the valve, the upper part having a port communicating the inner passage of the upper part with an ou

Abstract: A tubular injector with snubbing jack and oscillator, which eliminates the need for overhead tubular and oscillator support structure and utilizes resonant vibration to remove tubulars (2) and other objects which are stuck in a well. In a first embodiment the apparatus includes a mechanical oscillator (22) mounted on a snubbing jack (30), wherein the tubular load on the snubbing jack (30) can be released and transferred to the oscillator (22) when the tubular (2) is stuck, for vibrating and loosening the tubular (2) in the well. In another embodiment the apparatus is designed to handle coiled tubing (6) and a snubbing-type jack (39) is used in association with a conventional coiled tubing guide (37) and a coiled tubing injector (14), for guiding the coiled tubing (6) from a reel through the guide (37) and through a hollow tubular stem (9) in the oscillating apparatus (22), into the injector (14) and the well.

Abstract: The invention relates to a safety switching system for a clamping device, provided with clamping wedges and operable by a flowing medium for holding and/or lowering or raising a pipe string, with which a borehole is lined in order to support the rock and create a transport line, characterized in that there is attached to a clamping wedge holder of the clamping device a trip cam for a safety switching valve which is mounted at the basic body of the clamping device and is actively connected to the trip cam when the clamping wedges assume their prescribed clamping position on the pipe string.

Abstract: A power tong set, with lead and back-up tongs, is mounted on the slip bowl of the traveling jack head of a snubbing unit and rotates with the slip bowl. Service lines (or umbelicals) for the tong set are not connected during string rotation. In an alternate version of the apparatus a fluid feed through swivel is mounted on the tong set, secured to the necessary tong operating and control service fluid line, or lines, such that the tong set can rotate with tong service lines between the tong set and the snubbing unit attached during rotation. In an alternate form, the tong set is mounted on the jack head, independently of the rotary table, and the tong set does not rotate when the rotary table rotates.

Abstract: The present invention relates to a method and apparatus for the servicing or workover of a hydrocarbon well. The apparatus includes a pair of hydraulic cylinders pivotally mounted to a pair of base beams connected to each other. The cylinders are moveable from a horizontal position for transportation to a vertical position for operation in which position the two cylinders flank a wellhead and are adapted to lift the wellhead and attached production tubing using a workover beam and a lifting sub. The wellhead and production tubing can be rotated as or after they are elevated. A motor may be mounted to the workover beam to rotate the wellhead and the tubing. A calibrated pressure gauge may be used to indicate the weight being lifted. The apparatus can be wheel mounted and towed behind a crane truck. The advantage is a safe, economical and timesaving apparatus for performing jobs that previously required the setup and operation of a workover rig.