Abstract: A hydraulically powered downhole jet pump is designed to provide greater flexibility in operations of wells producing oil, gas and/or water. The pump consists of a housing and a carrier assembly. The housing is attached to an inner threaded tubular member and run inside the well casing to a depth as required for optimal operations. The one piece carrier assembly is inserted and seals into the housing with proper orientation of the carrier assembly outlet ports with the housing outlet ports resulting from the combination of a helically or tapered cut guide on the exterior of the carrier assembly and an inward positioned pin in the housing.

Abstract: A hydraulically powered downhole jet pump is designed to provide greater flexibility in operations of wells producing oil, gas and/or water. The pump consists of a housing and a carrier assembly. The housing is attached to an inner threaded tubular member and run inside the well casing to a depth as required for optimal operations. The one piece carrier assembly is inserted and seals into the housing with proper orientation of the carrier assembly outlet ports with the housing outlet ports resulting from the combination of a helically or tapered cut guide on the exterior of the carrier assembly and an inward positioned pin in the housing.

Abstract: A fluid actuated packer 10 and collar 36 assembly is provided for positioning on a tubular member 12. The collar 36 is moveable by a running tool 110 positioned within the tubular member and has a closed position and a packer activate position, fluidly connects the collar 36 to the packer element 14 when in the packer activate position, and closes off the flow path 26 when in the closed position. According to a method of the invention, the flow path 26 extends from the collar to the expandable packer element 14 and is open to activate the packer element 14 and closes off the flow path 26 when in the closed position.

Abstract: An improved inflatable packer 10 is provided having a pre-stretched bladder to minimize Z-folding. An expandable outer body 11 includes an inner elastomeric bladder layer 12, a reinforcement layer 14 which may include overlapping slats or cable, and an outer elastomer cover layer 16 which may cover only a portion of the reinforcement layer 14. The bladder 12 may expand non-uniformly due to the variations in the cross-section of the borehole 20, irregularities in construction of the bladder 12, and/or difference in resistance to expansion between the covered portion and the exposed portion of the reinforcement layer 14. An improved inflatable packer and method comprises pre-stretching the bladder 12 to keep the bladder in tension and minimize the occurrence of Z-folds.

Abstract: An improved inflatable packer 10 is provided having a pre-stretched bladder to minimize Z-folding. An expandable outer body 11 includes an inner elastomeric bladder layer 12, a reinforcement layer 14 which may include overlapping slats or cable, and an outer elastomer cover layer 16 which may cover only a portion of the reinforcement layer 14. The bladder 12 may expand non-uniformly due to the variations in the cross-section of the borehole 20, irregularities in construction of the bladder 12, and/or difference in resistance to expansion between the covered portion and the exposed portion of the reinforcement layer 14. An improved inflatable packer and method comprises pre-stretching the bladder 12 to keep the bladder in tension and minimize the occurrence of Z-folds.

Abstract: An inflatable packer 10 includes a sliding collar 86 which opens and closes port 94 to control pressurization of the inflatable packer element 120 with a cementatious fluid. The collar 86 is axially moveable by a setting tool 20 suspended in the well from a work string WS. An annular passageway 76 in the packer body extends from the inlet port 94 to the packer element 120 to provide for reliable inflation with the cementatious fluid. The collar 86 provides metal-to-metal sealing engagement with the radially inner sleeve 76 of the packer body to reliably seal the inflation chamber from the well fluids when the collar 86 is moved closed.

Abstract: A casing circulator 30, 54, 162 is provided for pumping fluid into a casing string to fill the casing string, and for temporarily sealing with an upper end of the casing string to circulate pressurized fluid through the casing string. The casing circulator includes a mandrel 130 axially movable with respect to a circulator body 84 from a retracted position to an extended position in response to fluid pressure acting on a piston 126. In the retracted position, the casing circulator is positioned with respect to the casing string for filling the casing string with fluid. When moved to its extended position, a sealing element 56, 158, 164 supported on the mandrel is in sealing engagement with the upper end of the casing string to circulate fluid through the casing string. According to the method of the invention, pressurized fluid is applied to the casing circulator to move the mandrel to the extended position, and may also be used to expand the sealing element into sealing engagement with the casing string.

Abstract: Improved methods and apparatus are provided for obtaining multiple fluid samples from subterranean formations of interest. The present invention is particularly well suited for testing nuclear migration in ground water utilizing test wells surrounding a nuclear test site. A plurality of flow ports are provided in the casing each at a depth of a formation of interest, and a sliding sleeve is positioned over each port. A wireline tool is lowered to the selective depth, and downhole electric motor energized to power a pump and pass pressurized fluid to move a first dog radially outward. The downhole tool may be axially moved until the first dog locks into a groove provided in the casing. Fluid entering the casing is sealed above and below the sliding sleeve. Fluid pressure may then be applied to move a second dog radially outward to engage the sliding sleeve, and a control valve regulated to apply fluid pressure to axially move the sleeve and open the port.

Abstract: Improved methods and apparatus are provided for inputting fluid into the uppermost end of a casing string gripped by an elevator supported from a traveling block by a pair of bails. The concepts of the present invention may be used to provide circulation from adjacent the lower end of the casing string and into a well bore to enable the casing string to be more easily lowered into the well bore, and may also be used to fill the casing string as it is lowered into the well bore. The casing circulator is provided for lowering into the uppermost end of the casing string above the rig floor, and for sealing with an interior surface of the uppermost end of the casing string. A support sub includes a hanger for suspending from the traveling block, and the casing circulator is supported from the support sub by a pup joint.

Abstract: Improved methods and apparatus are provided for obtaining multiple fluid samples from subterranean formations of interest. The present invention is particularly well suited for testing nuclear migration in ground water utilizing test wells surrounding a nuclear test site. A plurality of flow ports are provided in the casing each at a depth of a formation of interest, and a sliding sleeve is positioned over each port. A wireline tool is lowered to the selective depth, and downhole electric motor energized to power a pump and pass pressurized fluid to move a first dog radially outward. The downhole tool may be axially moved until the first dog locks into a groove provided in the casing. Fluid entering the casing is sealed above and below the sliding sleeve. Fluid pressure may then be applied to move a second dog radially outward to engage the sliding sleeve, and a control valve regulated to apply fluid pressure to axially move the sleeve and open the port.

Abstract: A method of receiving returns from a well being drilled in which the hydrostatic pressure of the drilling fluid cannot contain the formation pressure and controlling the flow and pressure of the returns and separating the oil, gas, and drilling fluids on the surface and returning the drilling fluids to the well while disposing of the oil and gas.

Abstract: An inflatable packer is provided for setting downhole in an oil or gas well to prevent fluid flow past the packer. The packer is of the type which includes an upper and lower packer head, an inflatable elastomer bladder, a radially outward tubular packer cover, and a plurality of overlapping metal reinforcing members positioned in the annulus between the bladder sleeve and the tubular packer cover. Each reinforcing member is slidably movable relative to another reinforcing member during setting of the packer, and includes a stop member between the packer heads for limiting to a preselected amount the relative sliding movement, such that gaps between reinforcing members are minimized or eliminated. These stop members on the reinforcing members may be formed by a stamping operation, wherein a recess stamped in one reinforcing member is adapted to receive a lip stamped in an adjacent reinforcing member.

Abstract: A downhole tool is provided suitable for multiple setting and unsetting operations in a well bore during a single trip. The downhole tool is suspended in the wellbore from a tubing string, and is activated by dropping a metal ball which plugs the passageway through the tubing string, such that tubing pressure may thereafter be increased to activate the downhole tool. A sleeve is axially movable within a control sub from a ball stop position to a ball release position, and has a cylindrical-shaped interior surface with a diameter only slightly greater than the ball. Collet fingers carried on the sleeve are radially movable from an inward position to an outward position to stop or release the ball as a function of the axial position of the sleeve.

Abstract: A packer assembly is provided suitable for multiple setting and unsetting operations in a well bore during a single trip to seal the annulus between the interior walls of the well bore and a tubing string. Thge packer is set by dropping a metal ball which plugs the passageway through the tubing string, such that tubing pressure may thereafter be increased to inflate the packer. A sleeve is axially movable within a control sub from a ball stop position to a ball release position, and has a cylindrical-shaped interior surface with a diameter only slightly greater than the ball. Collet fingers carried on the sleeve are radially movable from an inward position to an outward position to stop or release the ball as a function of the axial position of the sleeve.

Abstract: An inflatable packer for sealing across downhole conduits comprises a pair of rigid tubular packer heads coaxially interconnected by an inflatable tubular packer body. A bladder in the form of an elongate, flexible elastomeric sleeve includes a central section lining the packer body and having an outer diameter which, in a relaxed state of the bladder, is less than the deflated inner diameter of the packer body. The central section of the bladder is folded upon itself within the packer body in its deflated configuration. An inner reinforcing layer of the packer body is exposed in an annular area between the ends of the packer body.

Abstract: A downhole packer assembly includes a first packer tool with a flexible tubular packer body which is radially extendable by virtue of fluid pressure in a packer set chamber. A generally annular packer foundation, including an upper packer head, is connected to the upper end of the packer body. The tool defines a bypass flow system for permitting flow of fluid from the packer set chamber to a central longitudinal flowway of the assembly and from this central flowway to the exterior of the assembly. A control sub adjacent the packer foundation is movable with respect to the packer foundation between a first position, for opening the bypass system, and a second position, closing the bypass system. The control sub is preferably further operative, in its first position, to permit communication between the central flowway and the packer set chamber, and in its second position, to close the packer set chamber. A second packer tool is connected in tandem with the first tool.

Abstract: An apparatus and method for the selective placement of ball sealers for fluid treatment of a well, said ball sealers having a density less than the density of said fluid comprising a tubular member, means on said tubular member for positioning said apparatus in said well casing and means on said tubular member for deploying and blocking said well casing to prevent upward movement of said ball sealers past said apparatus.

Abstract: A method and apparatus for sampling the composition of fluid flowing through a conduit which includes a sampling conduit having an inlet disposed within said conduit and transverse to the axis of fluid flow in said conduit and an outlet connected to said conduit downstream of said inlet, and means for measuring the composition of fluid flowing through the sampling conduit. The sampling conduit is sized in relation to the conduit to cause isokinetic withdrawal of fluid from said conduit into said sampling conduit.