Abstract: An improved rotating head that utilizes a box assembly that stores at least one locking element that that allows for movement of the locking balls within the box assembly such that a liner inserted into the box assembly biases the locking elements to a locked position to couple the box assembly and the outer barrel. An integrated wear surface of the present invention seals the bearing elements to extend the life of the rotating head and reduce downtime caused by necessary maintenance of the rotating head.

Abstract: A top drive apparatus for a well drilling head comprises a top drive structure, a seal body and a plurality of resilient members. The top drive structure is configured for being fixedly attached to an upper end portion of a bearing assembly and having a seal-carrying portion. The seal body has a mounting portion and a wiper portion extending from the mounting portion. The mounting portion is slideably disposed within a groove of the seal-carrying portion of the top drive structure. The plurality of resilient members are disposed within the groove between the mounting portion of the seal body and the top drive structure such that the entire seal body is resiliently displaceable with respect to the top drive structure.

Abstract: Disclosed are hydrocarbon recovery drill string apparatus, subterranean hydrocarbon recovery drilling methods, and subterranean hydrocarbon recovery methods. In one embodiment, a hydrocarbon recovery drill string apparatus includes an elongated assembly within which a rotatable drill rod is received. The assembly comprises a longitudinal axis, a drill rod entrance end, and a drill rod exit end. The assembly comprises a tailcuttings diverter pipe proximate the drill rod exit end, with the tailcuttings diverter pipe defining an initial fluid flow path of the tailcuttings from the longitudinal axis which is acute from the longitudinal axis. Other apparatus and method aspects are contemplated.

Abstract: The present invention relates to rotating heads for oil and gas wells and more particularly, to an improved rotating head that utilizes a dual rubber cartridge that fixedly attaches at least one rubber to an inner barrel for rotation with the inner barrel. The present invention further utilizes components to at least partially enclose fasteners to prevent removal of the fasteners during normal operation. By enclosing the fasteners, the present invention extends the life of the rotating head and reduces downtime caused by necessary maintenance of the rotating head.

Abstract: A well drilling head comprises a housing having a sidewall structure defining a central bore and a bearing assembly removably seated within the central bore of the housing. The bearing assembly includes an outer barrel having a central bore, an inner barrel at least partially disposed within the central bore of the outer barrel and bearing units coupled between the barrels for providing concentric alignment of the barrels and allowing rotation therebetween. The inner barrel includes a central bore and a plurality of cooling structures protruding from a surface thereof within the central bore.

Abstract: A well drilling head housing comprises a sidewall structure, a ram and selective displacement means. The sidewall structure defines a central bore configured for having a bearing assembly removably seated therein. The ram is slideably mounted on the side wall structure and is disposed within a passage extending through the sidewall structure. The selective displacement means is coupled between the ram and the sidewall structure. The selective displacement means, is configured for moving the ram to an engaged position in which the ram is engaged with the bearing assembly for securing the bearing assembly in a seated position within the central bore and a disengaged position in which the ram is disengaged from the bearing assembly thereby allowing the bearing assembly to be removed from within the central bore.

Abstract: A bearing cooling system comprises a bearing assembly, a heat exchanger, a coolant flow circuit apparatus and a lubricant flow circuit apparatus. The bearing assembly is configured for being removably seated within a well drilling head housing and for having a stripper rubber assembly attached thereto. The bearing assembly includes bearings and a lubricant flow path configured for allowing lubricant to be circulated through the bearings. The heat exchanger has a lubricant core portion and a coolant core portion, which are jointly configured for allowing heat transfer between respective fluids of the core portions. The coolant flow circuit apparatus is coupled to the coolant core portion and is configured for circulating coolant through the coolant core portion. The lubricant flow circuit apparatus is coupled to the lubricant core portion and lubricant flow path, and is configured for circulating lubricant through the coolant core portion and the lubricant flow path.

Abstract: A wellhead seal unit for sealing a subsea oil and/or gas well at the wellhead. The unit comprises a sleeve, sealingly engaged to the workstring and to which, blow out preventer rams can engage. The unit allows the workstring to be rotated and reciprocated within the wellbore without releasing the seal. Methods of cleaning the sealed well and performing an inflow test are described.

Abstract: An RCD is used to provide a system and method for sealing a marine riser having a rotatable tubular. A bypass internal channel or external line may be used to allow fluid to bypass the RCD seal. An RCD seal assembly seal could be a mechanically extrudable seal or a hydraulically expanded seal to seal the RCD with the riser.

Abstract: Force balancing adjusts hydraulic fluid pressure in an upper piston area of a Rotating Pressure Control Device (RPCD) that has an inner housing rotatably engaged within an outer housing by an upper bearing and a lower bearing. The hydraulic fluid pressure is adjusted to balance net force in a upper piston area and a lower piston area. The fluid pressure adjustment creates a force differential that balances the total load transmitted through the upper bearing and the lower bearing and thereby extends the life of the sealing element and bearings. Additionally, a wear indicator signals the end of the useful life of the drill pipe sealing element.

Abstract: A well drilling head comprises a well drilling head housing, a bearing assembly, a first lubricant manifold and a second lubricant manifold. The well drilling head housing has a sidewall structure defining a central bore. The bearing assembly is configured for being removably seated within the well drilling head housing and for having a stripper rubber assembly attached to a lower end portion thereof. The bearing assembly includes a plurality of bearings and a bearing lubricant flow path configured for allowing bearing lubricant to be circulated through the bearings. The first lubricant manifold has a bearing lubricant passage coupled to the first end portion of the bearing lubricant flow path. The second lubricant manifold has a bearing lubricant passage coupled to a second end portion of the bearing lubricant flow path.

Abstract: An upper stripper rubber canister system comprises a canister body and a canister body lid. The canister body includes an upper end portion, a lower end portion and a central passage extending therebetween. The central passage is configured for having a stripper rubber assembly disposed therein. The upper end portion of the body includes a plurality of bayonet connector structures. The canister body lid includes an exterior surface, an upper end portion, a lower end portion and a central passage extending between the end portions thereof. The exterior surface is configured for fitting within the central passage of the canister body. The canister body lid includes a plurality of bayonet connector structures integral with its exterior surface. Each canister body lid bayonet connector structure is configured for being engaged with one of the canister body bayonet connector structures for interlocking the canister body lid with the canister body.

Abstract: An upper stripper rubber canister apparatus has a canister body and a canister body lid. An upper end portion of the canister body includes a breech lock structure exposed within the canister body central passage. A lower end portion of the canister body lid is configured for fitting within the central passage of the canister body. The canister body lid includes a breech lock structure that is configured for allowing the canister body lid to be fixedly engaged with the canister body by inserting a lower end portion of the canister body lid into a canister body central passage and rotating the canister body lid with respect to the canister body such that at least a portion of the canister body breech lock structure become at least partially overlapped with a respective one of the canister body lid breech lock structure.

Abstract: A riser assembly includes a rotating control housing connected between an upper portion and a lower portion of a riser assembly, and a packing element rotatable with respect to the rotating control housing, wherein the packing element is configured to isolate an annulus of the lower portion from the upper portion when a drillstring is engaged through the packing element, and wherein the packing element is configured to be retrieved and replaced through the upper portion.

Abstract: A stripper rubber insert comprises a central bore and a plurality of retention member bores substantially perpendicular to the central bore. The retention member bores are angularly spaced apart around a perimeter of the stripper rubber insert. Each one of the retention member bores extends through an exterior insert edge face and an interior insert edge face. Each one of the retention member bores includes a respective retention member securing structure therein.

Abstract: A top drive apparatus for a well drilling head comprises a top drive structure, a seal body and a plurality of resilient members. The top drive structure is configured for being fixedly attached to an upper end portion of a bearing assembly and having a seal-carrying portion. The seal body has a mounting portion and a wiper portion extending from the mounting portion. The mounting portion is slideably disposed within a groove of the seal-carrying portion of the top drive structure. The plurality of resilient members are disposed within the groove between the mounting portion of the seal body and the top drive structure such that the entire seal body is resiliently displaceable with respect to the top drive structure.

Abstract: A well drilling head comprises a housing and a bearing assembly. The housing has a sidewall structure defining a central bore. The bearing assembly includes an outer barrel, an inner barrel, bearing units and a preload force exerting member. The outer barrel has a central bore and the inner barrel is removably seated within the housing central bore. The bearing units are coupled between the barrels for providing concentric alignment of the barrels and allowing rotation therebetween. A first one of the bearing units is configured for carrying loads exerted radially between the barrels and a second one of the bearing units is configured for carrying loads exerted longitudinally between the barrels. The preload force exerting member maintains force on the longitudinal load carrying bearing unit and said barrels thereby preloading the longitudinal load carrying bearing unit.

Abstract: An improved valve for sealing a wellbore and method of use, in particular for prevention of well blow outs. In one embodiment, the apparatus is designed to seal a well through rotation of rams. The rams may be actuated to seal the well without having to work against full well pressure as fluid volumes in the apparatus housing, which also contains the rams, are preserved. This functionality allows the apparatus to be constructed with smaller dimensions than existing prior art blow out prevention valves aiding handling and manoeuvrability. The improved valve according to one embodiment also has a mechanism that guides a wireline or a pipeline being run in the wellbore to the centre of the bore and allows a seal to be formed around the wireline or pipeline.

Abstract: Force balancing adjusts hydraulic fluid pressure in an upper piston area of a Rotating Pressure Control Device (RPCD) that has an inner housing rotatably engaged within an outer housing by an upper bearing and a lower bearing. The hydraulic fluid pressure is adjusted to balance net force in a upper piston area and a lower piston area. The fluid pressure adjustment creates a force differential that balances the total load transmitted through the upper bearing and the lower bearing and thereby extends the life of the sealing element and bearings. Additionally, a wear indicator signals the end of the useful life of the drill pipe sealing element.

Abstract: A stripper rubber comprising a resilient stripper rubber body, an insert support, and a plurality of stripper rubber inserts. The resilient stripper rubber body has a drillstring bore extending therethrough. The insert support is at least partially within the body. The insert support includes a central opening generally aligned with the drillstring bore thereby allowing a drillstring to pass jointly through the central opening and the drillstring bore. The plurality of stripper rubber inserts are each at least partially disposed within the body. The inserts are arranged in a side-by-side manner around the drillstring bore with a first end portion thereof pivotably engaged with the insert support. Each one of the inserts is offset from the drillstring bore for precluding the inserts from being exposed from within the body at the drillstring bore.

Abstract: A packing element for a blowout preventer includes an annular flexible non-metallic composite body disposed about a longitudinal axis that is adapted to be compressively displaced inwardly towards the axis. A plurality of non-metallic composite inserts are embedded in the body in generally circular fashion spaced apart in respective radial planes extending form the axis for reinforcing the body. Each of the inserts includes upper and lower flanges, and a web element extending between the flanges. The web element includes trailing and leading edges, each having outer arcuate surface that are substantially semicircular in cross-section for distributing the loads applied to a bond line between the insert and the flexible non-metallic composite body during the operation of the packing element. A central rib extends between the leading and trailing edges. The replacement of metal inserts with non-metallic composite inserts eliminates sparks and scoring of string, which leads to explosions.

Abstract: A Rotating Pressure Control Head (RPCH) with a rapid engagement mechanism is disclosed. The RPCH comprises an upper body and a lower body. The rapid engagement mechanism allows the upper body to be quickly disengaged from the lower body and replaced with a new upper body. The upper body comprises a sealing element and an inner housing that rotates with respect to an outer housing. The sealing element contains a plurality of internal cavities. The plurality of cavities control the constriction of the sealing element around the drill pipe.

Abstract: A connector system is provided for connecting parts of an apparatus. A first part having one or more bayonet connectors and one or more retention pin receptacles cooperatively mates to a second part having one or more mating bayonet connectors. The second part further provides one or more retention pin bores. The first and second parts assemble to form a bayonet connection such that at least one pin retention bore aligns with at least one retention pin receptacle. At least one retention pin assembly disposed through the at least one pin retention bore selectively engages the retention pin receptacle to secure the connection of the first part to the second part of the apparatus.

Abstract: A high-pressure stripper rubber provides inserts and support members that cooperatively support the profile of the rubber against elastic deformation. The inserts dynamically cooperate to resist elastic deformation of the rubber due to down hole pressure. The stripper rubber has a generally cylindrical upper moiety and a dynamic, generally frusto-conical, lower moiety, that cooperatively define a bore for receiving oilfield equipment. A generally ring-shaped adapter insert, at least partially within the stripper rubber, is disposed toward the upper moiety for attaching the stripper rubber to drilling head equipment. A structural retention insert assembly provides (1) one or more support members proximately and movably attached to the adapter insert, and (2) one or more structural retention inserts at least partially within the stripper rubber and distally attached to the one or more support members.

Abstract: Methods and apparatus for rotating a stripper assembly in use with a rotating drilling head. A drive system is disposed external to the rotating drilling head and generates rotational motion to match the rotation of a drillstring running through the rotating drilling head. A connection transfers rotational motion from the drive system to the stripper assembly. In one embodiment, the drive system comprises a housing disposed about the drillstring and a one or more contact members connected to said housing and operable to contact the drillstring. One or more biasing members urge the contact members into contact with the drillstring so as to transfer rotational motion from the drillstring to the housing.

Abstract: A high-pressure stripper rubber provides inserts and support members that cooperatively support the profile of the rubber against elastic deformation. The inserts dynamically cooperate to resist elastic deformation of the rubber due to down hole pressure. The stripper rubber has a generally cylindrical upper moiety and a dynamic, generally frusto-conical, lower moiety that cooperatively define a bore for receiving oilfield equipment. A generally ring-shaped adapter insert, at least partially within the stripper rubber, is disposed toward the upper moiety for attaching the stripper rubber to drilling head equipment. A structural retention insert assembly provides (1) one or more support members proximately, movably and selectively attached to the adapter insert, and (2) one or more structural retention inserts at least partially within the stripper rubber and distally attached to the one or more support members.

Abstract: An armored stripper rubber is provided that protects the drillstring bore of the stripper rubber from substrate infiltration, yet pivotally dilates to facilitate the passage of drillstring components through the bore while effectively maintaining a fluid-tight seal. Additionally, the stripper rubber substantially inhibits resilient contraction of the stripper rubber to an internal bore diameter smaller than a pre-selected internal diameter. The armored stripper rubber, or armadillo, substantially prevents rubber inversion and puckering under high operational well pressures. Also provided are stripper rubber inserts and insert assemblies.

Abstract: A high-pressure stripper rubber provides inserts and support members that cooperatively support the profile of the rubber against elastic deformation. The inserts dynamically cooperate to resist elastic deformation of the rubber due to down hole pressure. The stripper rubber has a generally cylindrical upper moiety and a dynamic, generally frusto-conical, lower moiety that cooperatively define a bore for receiving oilfield equipment. A generally ring-shaped adapter insert, at least partially within the stripper rubber, is disposed toward the upper moiety for attaching the stripper rubber to drilling head equipment. A structural retention insert assembly provides (1) one or more support members proximately and movably attached to the adapter insert, and (2) one or more structural retention inserts at least partially within the stripper rubber and distally attached to the one or more support members.

Abstract: A connector system is provided for connecting parts of an apparatus. A first part having one or more bayonet connectors and one or more retention pin receptacles cooperatively mates to a second part having one or more mating bayonet connectors. The second part further provides one or more retention pin bores. The first and second parts assemble to form a bayonet connection such that at least one pin retention bore aligns with at least one retention pin receptacle. At least one retention pin assembly disposed through the at least one pin retention bore selectively engages the retention pin receptacle to secure the connection of the first part to the second part of the apparatus.

Abstract: A packing assembly for use with a rotary drilling swivel having a cylindrical wash pipe comprising a housing assembly including a packing gland forming a sealing assembly chamber around the wash pipe, the packing gland including an injection port in open communication with the chamber, a sealing assembly disposed in the chamber and including a first annular seal ring surrounding and in sealing engagement with the wash pipe, an annular containment member disposed in the chamber in surrounding relation to the wash pipe and axially spaced from the first seal ring and an injectable packing composition in sealing engagement with the wash pipe and disposed between the first seal ring and the containment member, one of the wash pipe and the packing assembly being rotatable relative to the other.

Abstract: A rotary blowout preventer has a first and a second fluid circuit. Each of the fluid circuits are defined into and out of a stationary body and between the stationary body, a rotating body, and two seals. The first fluid circuit is physically independent from the second fluid circuit although they share a seal interface. A fluid is introduced into the first fluid circuit at a pressure responsive to the well bore pressure. A fluid is introduced into the second fluid circuit at a pressure responsive to and lower than the pressure of the fluid in the first circuit. Adjustable orifices are connected to the outlet of the first and second fluid circuits to control such pressures within the circuits. Such pressures affect the wear rates of the seals. The system can therefore control the wear rate of one seal relative to another seal. A thrust bearing is added to share the load placed upon the upper bearings. The thrust bearing is connected between the top end of a packer sleeve and the stationary body.

Abstract: A stripper assembly for sealing around a drill pipe includes an outer housing having a lateral outlet. The outer housing is mounted at an upper end of a well for receiving an upward flow of drilling fluid and diverting the drilling fluid through the lateral outlet. An inner member is rotatably mounted in the outer housing. A rigid cartridge housing is mounted to the inner member for rotation therewith. The cartridge housing is open to drilling fluid. An annular elastomeric seal member is located in the cartridge housing. The cartridge housing limits upward, downward and outward movement of the seal member as it deforms against the drill pipe due to drilling fluid pressure.

Abstract: A rotating drilling head seals around drill pipe while drilling. The drilling head has an outer housing that mounts to the rig floor. An inner housing is rotatably mounted in the outer housing. An annular bladder is mounted in the inner housing. An annular elastomeric gripping member is mounted in the bladder. The inner housing having a passage for delivering hydraulic fluid pressure to the outer surface of the bladder to cause the bladder to deform inwardly, thereby forcing the gripping member to deform inwardly to grip and rotate with a drill pipe. The gripping member has a first end secured to the inner housing for rotating the inner housing as the drill pipe rotates and a second end that is free to move axially to allow the bladder to elongate in response to the deformation by the bladder.

Abstract: A pump drive head for a progressing cavity pump comprises a top mounted stuffing box rotatably disposed around a compliantly mounted standpipe with a self or manually adjusting pressurization system for the stuffing box. To prevent rotary and vertical motion of the polish rod while servicing the stuffing box, a polished rod lock-out clamp is provided with the pump drive head integral with or adjacent to a blow-out-preventer which can be integrated with the pump drive head to save space and cost. A centrifugal backspin braking system located on the input shaft and actuated only in the backspin direction and a gear drive between the input shaft and output shaft are provided.

Abstract: A rotary blowout preventer has a first and a second fluid circuit. Each of the fluid circuits are defined into and out of a stationary body and between the stationary body, a rotating body, and two seals. The first fluid circuit is physically independent from the second fluid circuit although they share a seal interface. A fluid is introduced into the first fluid circuit at a pressure responsive to the well bore pressure. A fluid is introduced into the second fluid circuit at a pressure responsive to and lower than the pressure of the fluid in the first circuit. Adjustable orifices are connected to the outlet of the first and second fluid circuits to control such pressures within the circuits. Such pressures affect the wear rates of the seals. The system can therefore control the wear rate of one seal relative to another seal. A thrust bearing is added to share the load placed upon the upper bearings. The thrust bearing is connected between the top end of a packer sleeve and the stationary body.

Abstract: A rotary drilling head assembly for a well bore, including an erosion resistant bowl apparatus. The bowl comprises a bowl member, the bowl member having a central receiving cavity configured to receive a rotary sealed bearing assembly, the bowl member having a discharge nozzle extending therefrom, the discharge nozzle fluidly communicating with the receiving cavity, and at least one diverter member extending from an inner surface of the receiving cavity of the bowl, the diverter member formed and configured to disrupt patterns of fluid flow within the bowl during drilling operations. The apparatus preferably includes at least one nozzle diverter member extending from an inner surface of the discharge nozzle. A plurality of diverter members preferably extend from an inner surface of the receiving cavity of the bowl and from the discharge nozzle.

Abstract: A rotary blowout preventer has a first and a second fluid circuit. Each of the fluid circuits are defined into and out of a stationary body and between the stationary body, a rotating body, and two seals. The first fluid circuit is physically independent from the second fluid circuit although they share a seal interface. A fluid is introduced into the first fluid circuit at a pressure responsive to the well bore pressure. A fluid is introduced into the second fluid circuit at a pressure responsive to and lower than the pressure of the fluid in the first circuit. Adjustable orifices are connected to the outlet of the first and second fluid circuits to control such pressures within the circuits. Such pressures affect the wear rates of the seals. The system can therefore control the wear rate of one seal relative to another seal. A thrust bearing is added to share the load placed upon the upper bearings. The thrust bearing is connected between the top end of a packer sleeve and the stationary body.

Abstract: A rotating drilling head seals around drill pipe while drilling. The drilling head has an outer housing that mounts to the rig floor. An inner housing is rotatably mounted in the outer housing. An annular bladder is mounted in the inner housing. An annular elastomeric gripping member is mounted in the bladder. The inner housing having a passage for delivering hydraulic fluid pressure to the outer surface of the bladder to cause the bladder to deform inwardly, thereby forcing the gripping member to deform inwardly to grip and rotate with a drill pipe. The gripping member has a first end secured to the inner housing for rotating the inner housing as the drill pipe rotates and a second end that is free to move axially to allow the bladder to elongate in response to the deformation by the bladder.

Abstract: A stripper assembly for sealing around a drill pipe includes an outer housing having a lateral outlet. The outer housing is mounted at an upper end of a well for receiving an upward flow of drilling fluid and diverting the drilling fluid through the lateral outlet. An inner member is rotatably mounted in the outer housing. A rigid cartridge housing is mounted to the inner member for rotation therewith. The cartridge housing is open to drilling fluid. An annular elastomeric seal member is located in the cartridge housing. The cartridge housing limits upward, downward and outward movement of the seal member as it deforms against the drill pipe due to drilling fluid pressure.

Abstract: A mount for a bonnet of a blowout preventer includes at least one support member coupled to a body of the blowout preventer, and a bonnet mounting member moveably coupled to the at least one support member and adapted to move substantially normal to a face of the body of the blowout blowout preventer, wherein the bonnet is coupled to the bonnet mounting member.

Abstract: A rotary blowout preventer has a first and a second fluid circuit. Each of the fluid circuits are defined into and out of a stationary body and between the stationary body, a rotating body, and two seals. The first fluid circuit is physically independent from the second fluid circuit although they share a seal interface. A fluid is introduced into the first fluid circuit at a pressure responsive to the well bore pressure. A fluid is introduced into the second fluid circuit at a pressure responsive to and lower than the pressure of the fluid in the first circuit. Adjustable orifices are connected to the outlet of the first and second fluid circuits to control such pressures within the circuits. Such pressures affect the wear rates of the seals. The system can therefore control the wear rate of one seal relative to another seal. A thrust bearing is added to share the load placed upon the upper bearings. The thrust bearing is connected between the top end of a packer sleeve and the stationary body.

Abstract: A rotary drilling head assembly for a well bore, including an erosion resistant bowl apparatus. The bowl comprises a bowl member, the bowl member having a central receiving cavity configured to receive a rotary sealed bearing assembly, the bowl member having a discharge nozzle extending therefrom, the discharge nozzle fluidly communicating with the receiving cavity, and at least one diverter member extending from an inner surface of the receiving cavity of the bowl, the diverter member formed and configured to disrupt patterns of fluid flow within the bowl during drilling operations. The apparatus preferably includes at least one nozzle diverter member extending from an inner surface of the discharge nozzle. A plurality of diverter members preferably extend from an inner surface of the receiving cavity of the bowl and from the discharge nozzle.

Abstract: A rotatable mount for a blowout preventer bonnet. A slide mounting bar is slidably couples to a body of the blowout preventer. The slide mounting bar is adapted to move along an axis of a side opening of the body of the blowout preventer. A swivel is coupled to the mounting bar and to the bonnet. The swivel is adapted to enable rotation of the bonnet when the bonnet is disengaged from the body of the blowout preventer.

Abstract: A system and method provides a barrier between two different fluid densities in a riser while drilling in deepwater. An internal housing and a rotating control head are positioned in a first housing when a blowout preventer is in the sealed position. When the blowout preventer is in the sealed position about the internal housing, a pipe can be rotated for drilling with the pressure of the fluid in the open borehole at one density and the fluid above the seal at another density. When the blowout preventer seal is in the open position, the threadedly connected bearing assembly and internal housing can be removed relatively quickly from the riser.

Abstract: A monolithic pumping tree combining a bottom connection, production blow-out preventer section, flow tee section and top connection is cast so as to provide an access port extending downwardly through the side wall of the tree from its outer surface, to connect with either the central vertical bore of the tree or its horizontal bottom surface, thereby enabling coiled tubing to be inserted either into the tubing string bore or into the annulus between the tubing and production casing strings.

Abstract: A rotary blowout preventer has a first and a second fluid circuit. Each of the fluid circuits are defined into and out of a stationary body and between the stationary body, a rotating body, and two seals. The first fluid circuit is physically independent from the second fluid circuit although they share a seal interface. A fluid is introduced into the first fluid circuit at a pressure responsive to the well bore pressure. A fluid is introduced into the second fluid circuit at a pressure responsive to and lower than the pressure of the fluid in the first circuit. Adjustable orifices are connected to the outlet of the first and second fluid circuits to control such pressures within the circuits. Such pressures affect the wear rates of the seals. The system can therefore control the wear rate of one seal relative to another seal. A thrust bearing is added to share the load placed upon the upper bearings. The thrust bearing is connected between the top end of a packer sleeve and the stationary body.

Abstract: The rotary drilling head assembly of the present invention includes a housing having a bore for receiving a drive member. The drive member has an outer diameter of less than 17 ½ inches to pass through a 17½ inch opening in a rotary table. A bearing assembly is disposed between the housing and drive member allowing the drive member to rotate within the housing and includes an outer stationary portion and an inner rotating portion. Retaining clamps attach the outer stationary portion to the housing and the rotating portion to the drive member. Rotary seal assemblies isolate the bearing assembly and its lubrication system from the drilling fluid and prevent premature wear and failure of the bearing. The bearing assembly includes a plurality of opposing disc-like members that have flat bearing surfaces meeting on a substantially planar surface of contact. The disc-like members are preferably made of a polycrystalline diamond material.

Abstract: A rotatable head assembly wherein there is an outer housing that carries a cartridge assembly that permits rotational movement. The cartridge assembly made up of a cartridge housing and cartridge body that is rotatable within the cartridge housing. Static seals are used to provide fluid seals between the radially outer surface of the cartridge housing and the outer housing. Fluid passages within the cartridge housing carry lubricating fluid from the static seals to dynamic seals that allow the cartridge body to rotate easily within the cartridge housing. Fluid passages are also provided within the cartridge housing for carrying spent fluid out through the cartridge housing. There may be multiple fluid inlets and outlets within the cartridge housing without requiring a multiplicity of stepped increases in the diameter of the cartridge housing and the outer housing.

Abstract: The rotatable blowout preventer 10 comprises a stationary outer housing 12 and a rotatable inner housing 38 having a curved surface 42 thereon defining a portion of a sphere. An annular packer assembly 46 includes spherical packer elements for sliding engagement with the curved surface of the inner housing such that a packer assembly may seal against various sized tubulars. A lower rotary seal 98 between a piston 56 and the outer housing 12 is exposed to the differential between pressurized hydraulic fluid and the well pressure within a lower end of the bore 32 within the outer housing. A flow restriction member 114 between the rotatable inner housing and the outer housing reduces fluid pressure downstream from the flow restriction to less than 40% of the upstream pressure. The upper rotary seal 120 is open to atmospheric pressure and is subjected to this reduced pressure.