Abstract: The present invention provides drilling systems for drilling subsea wellbores. The drilling system includes a tubing that passes through a sea bottom wellhead and carries a drill bit. A drilling fluid system continuously supplies drilling fluid into the tubing, which discharges at the drill bit bottom and returns to the wellhead through an annulus between the tubing and the wellbore carrying the drill cuttings. A fluid return line extending from the wellhead equipment to the drilling vessel transports the returning fluid to the surface. In a riserless arrangement, the return fluid line is separate and spaced apart from the tubing. In a system using a riser, the return fluid line may be the riser or a separate line carried by the riser. The tubing may be coiled tubing with a drilling motor in the bottom hole assembly driving the drill bit.

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 wellbore drilling system has an umbilical that carries a drill bit in a wellbore. Drilling fluid pumped into the umbilical discharges at the drill bit bottom and returns through an annulus between the umbilical and the wellbore carrying entrained drill cuttings. An active differential pressure device (APD device), such as a jet pump, turbine or centrifugal pump, in fluid communication with the returning fluid creates a differential pressure across the device, which alters the pressure below or downhole of the device. The APD device can be driven by a positive displacement motor, a turbine, an electric motor, or a hydraulic motor. A controller controls the operation of the APD device in response to programmed instructions and/or one or more parameters of interest detected by one or more sensors. A preferred system is a closed loop system that maintains the wellbore at under-balance condition, at-balance condition or over-balance condition.

Abstract: A drilling system for drilling subsea wellbores includes a tubing-conveyed drill bit that passes through a subsea wellhead. Surface supplied drilling fluid flows through the tubing, discharges at the drill bit, returns to the wellhead through a wellbore annulus, and flows to the surface via a riser extending from the wellhead. A flow restriction device positioned in the riser restricts the flow of the returning fluid while an active fluid device controllably discharges fluid from a location below to just above the flow restriction device in the riser, thereby controlling bottomhole pressure and equivalent circulating density (“ECD”). Alternatively, the fluid is discharged into a separate return line thereby providing dual gradient drilling while controlling bottomhole pressure and ECD. A controller controls the energy and thus the speed of the pump in response to downhole measurement(s) to maintain the ECD at a predetermined value or within a predetermined range.

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: The present invention provides an apparatus and method for partially rotating a drill string. The drill string of the present invention comprises upper and lower sections wherein the lower section rotates relative to the upper section of the drill string from the surface at the injector head. The upper and lower sections of the drill string can comprise coiled tubing, jointed tubing or a combination of coiled and jointed tubing. The lower section of the drill string comprises a bottom hole assembly (BHA), which comprises a drill bit and downhole drilling motor. A rotational device is positioned within the drill string in order to rotate the lower section. Upon activation of the rotational device, the lower section of the drill string will be exposed to a continuous rotation.

Abstract: The present invention provides drilling systems for drilling subsea wellbores. The drilling system includes a tubing that passes through a sea bottom wellhead and carries a drill bit. A drilling fluid system continuously supplies drilling fluid into the tubing, which discharges at the drill bit bottom and returns to the wellhead through an annulus between the tubing and the wellbore carrying the drill cuttings. A fluid return line extending from the wellhead equipment to the drilling vessel transports the returning fluid to the surface. In a riserless arrangement, the return fluid line is separate and spaced apart from the tubing. In a system using a riser, the return fluid line may be the riser or a separate line carried by the riser. The tubing may be coiled tubing with a drilling motor in the bottom hole assembly driving the drill bit.

Abstract: The present invention provides drilling systems for drilling subsea wellbores. The drilling system includes a tubing that passes through a sea bottom wellhead and carries a drill bit. A drilling fluid system continuously supplies drilling fluid into the tubing, which discharges at the drill bit bottom and returns to the wellhead through an annulus between the tubing and the wellbore carrying the drill cuttings. A fluid return line extending from the wellhead equipment to the drilling vessel transports the returning fluid to the surface. In a riserless arrangement, the return fluid line is separate and spaced apart from the tubing. In a system using a riser, the return fluid line may be the riser or a separate line carried by the riser. The tubing may be coiled tubing with a drilling motor in the bottom hole assembly driving the drill bit.

Abstract: A tubing handling for subsea oilfield tubing operations, includes an isolation tube to mechanically and/or chemically protect the drill string and improved passage of the drill string and fluid return line to the drilling vessel that further protects them during drilling use. In addition, the improvements include an automatic safety apparatus to hold against unintended movement of the tubular members under extreme length and weight conditions as well as against human error at the rig. Further, the invention includes multi-segment coiled tubing drill strings that can be adapted to drilling requirements in a deep wellbore.

Abstract: This invention provides a bottomhole assembly that contains a thruster for applying an axial force on the drill bit during drilling of the wellbore. The bottomhole assembly includes at least one sensor which provides measurements for determining a parameter of interest relating to the drilling of the wellbore. A power unit supplies power to the thruster to move a member toward the drill bit to apply the force on the drill bit. A processor operatively coupled to the thruster controls the magnitude of the force generated by the thruster in response to one or more parameters interest.

Abstract: This invention provides a tubing injection system that contains one injector for moving a tubing from a source thereof to a second injector. The second injector moves the tubing into the wellbore. In an alternative embodiment for subsea operations, the system may contain a first injector placed under water over the wellhead equipment for moving the tubing to and from the wellbore. A second injector at the surface moves the tubing to the first injector and a third injector moves the tubing from the tubing source to the second injector. In each of the tubing injection systems sensors are provided to determine the radial force on the tubing exerted by the injectors, tubing speed, injector speed, and the back tension on the source. A control unit containing a computer continually maintains the tubing speed, tension and radial pressure on the tubing within predetermined limits.

Abstract: The present invention provides apparatus and method for killing or suppressing a subsea wellbore. The system includes a pressure intensifier adjacent the wellhead. The output of the pressure intensifier is coupled to a “kill” inlet at the wellhead equipment. Power is supplied from the surface to the pressure intensifier, which increases the pressure by a known multiple, usually 3 to 5, and supplies the high pressure fluid to the wellbore. A control unit at the surface controls the operation of the pressure intensifier in response to the predefined criteria or programmed instructions. One or more sensors provide measurements to the control unit of the wellbore conditions, which are used to determine the timing of activation of the pressure intensifier.

Abstract: This invention provides a tubing injection system that contains one injector for moving a tubing from a source thereof to a second injector. The second injector moves the tubing into the wellbore. In an alternative embodiment for subsea operations, the system may contain a first injector placed under water over the wellhead equipment for moving the tubing to and from the wellbore. A second injector at the surface moves the tubing to the first injector and a third injector moves the tubing from the tubing source to the second injector. In each of the tubing injection systems sensors are provided to determine the radial force on the tubing exerted by the injectors, tubing speed, injector speed, and the back tension on the source. A control unit containing a computer continually maintains the tubing speed, tension and radial pressure on the tubing within predetermined limits.

Abstract: An apparatus for injection of coiled tubing or jointed tubulars into a well bore, using an injector head capable of handling either type of tubular. The injector head and a working platform are mounted on a structure over the well head, with the injector being positioned so as to allow personnel access to the tubing on the working platform without having to relocate the injector head away from the well head location. The injector can be mounted below the working platform, or it can be mounted spaced above the working platform on a vertically movable trolley on a mast. When the injector is mounted below the working platform, the tubulars and any bottom hole assembly are accessible to personnel on top of the working platform, whether coiled tubing or jointed tubulars are being used.

Abstract: Completion method for avoiding formation impairment in the completion of a wellbore by anchoring and activating a plug at a selected position in the wellbore to seal off a selected portion of the wellbore from other portions of the wellbore. The plug is positioned at the selected position in the wellbore and anchored at that position. A seal in the plug is then activated such that fluid cannot pass the plug. Other parts of the wellbore can then be operated at different pressures than the isolated part of the wellbore without impairment of the formation resulting from the loss of well fluids into the formation.

Abstract: Apparatus for handling pipe, coiled tubing, casing, and conventional tubing in well drilling and servicing operations.

Abstract: An apparatus for injection of coiled tubing or jointed tubulars into a well bore, using an injector head capable of handling either type of tubular. The injector head and a working platform are mounted on a structure over the well head, with the injector being positioned so as to allow personnel access to the tubing on the working platform without having to relocate the injector head away from the well head location. The injector can be mounted below the working platform, or it can be mounted spaced above the working platform on a vertically movable trolley on a mast. When the injector is mounted below the working platform, the tubulars and any bottom hole assembly are accessible to personnel on top of the working platform, whether coiled tubing or jointed tubulars are being used.

Abstract: The present invention provides a drilling rig which includes an electrically-controllable tubing injection system. The injection system contains a fixed injector head with two movable injection blocks which are remotely operable to provide a desired opening therebetween. Each injection block contains a plurality of gripping members for holding a range of tubing sizes. The injection blocks automatically adjust to provide the required gripping force and tubing speed according to programmed instructions. A resilient tubing guidance system is positioned above the injector head directs the tubing into the injector head. The rig system contains sensors for determining the radial force on the tubing exerted by the injector head, tubing speed, injector head speed, weight-on-bit during the drilling operations, bulk weight of the drill string, compression of the tubing guidance memeber during operations and the back tension on the tubing reel.

Abstract: Apparatus for handling pipe, coiled tubing, casing and conventional tubing in well drilling and servicing operations.

Abstract: An apparatus for injection of coiled tubing or jointed tubulars into a well bore, using an injector head capable of handling either type of tubular. The injector head and a working platform are mounted on a structure over the well head, with the injector being positioned so as to allow personnel access to the tubing on the working platform without having to relocate the injector head away from the well head location. The injector can be mounted below the working platform, or it can be mounted spaced above the working platform on a vertically movable trolley on a mast. When the injector is mounted below the working platform, the tubulars and any bottom hole assembly are accessible to personnel on top of the working platform, whether coiled tubing or jointed tubulars are being used.