Abstract: A field-installable rod guide for a rod moveable within an oilfield tubular having an interior tubular surface for driving a downhole pump to pump liquids to the surface through the oilfield tubular. The rod guide comprises a body including interfitting body members. An outer tapered surface on one body member is engaged by an inner taper-engagement surface on the other body member, to urge the body members toward a rod gripping position about the rod. The mechanism disclosed provides a particularly strong engagement with the rod, so that the rod guide may be used for either reciprocating or rotating rods. For rotating type rod guides, an outer sleeve may be included about the body.

Abstract: A fluid recovery system 10 for collecting formation fluid at the surface of a well 12 includes a downhole jet pump 20 and a surface diaphragm pump 40 having a plurality of diaphragms 42. The jet pump includes a fluid nozzle 22, an intake 24 directing the formation fluid into a jet 26, a mixing tube 28 for mixing the power fluid and the formation fluid, and a diffuser 30 for converting the velocity of the mixed fluid to pressure. A flow meter 50 and a pressure sensor 52 monitor the quantity and pressure of the power fluid to the jet pump.

Abstract: A closure includes a hub having a bore in fluid communication with the port of a vessel. A door is removably positioned within the bore of the hub, and a locking ring is threaded with the hub thread for moving the door to a closed and circumferentially sealed position against the shoulder. At least one rotatable actuator element, such as a plurality of gears, engages the locking ring and is rotated to rotate the locking ring. A breaker bar or impact wrench could be used to rotatable drive the actuator elements.

Abstract: A power tong 10 rotates a tubular during makeup or breakout of the threaded connection. A tong frame 12, a rotatable ring 20, and a cage plate assembly may each have an open throat for receiving the tubular. A plurality of dies 32 are preferentially manufactured from aluminum, and each have a knurled surface for engaging the tubular. A fluid powered cylinder 54 increases tension between the brake band 50 and the cage plate assembly. Neutral cam portions of the cam surface one positioned radially outward substantially from the makeup and breakout cam portions.

Abstract: An apparatus for use in clamping a structure at its edge, the structure having opposed surfaces, the apparatus comprising a stanchion, a first clamping assembly attached to the stanchion and a second clamping assembly selectively slidably moveable longitudinally along the stanchion, the second clamping assembly including a support plate extending laterally outward in a direction away from the stanchion, the support plate being positioned closely adjacent one of the opposed surfaces of the structure when the structure is clamped between the first and second clamping assemblies.

Abstract: The liner hanger assembly seals with casing 8 and supports a liner 98 within a well. The tubular liner hanger 48 and a tubular expander 40 may be position downhole on a running tool at a desired depth along the casing string 8. An actuator assembly 6 may forcably move the tubular expander 40 into the tubular hanger, expanding the liner hanger to seal and secure the hanger against the casing string 8. After the running tool has been removed, a seal nipple may be sealed to the sealing sleeve of the tubular expander. A selectively releasable clutch 73 is provided for allowing rotation of the liner to rotate the liner with the running tool, and thereafter to disengage and release the running tool from the set liner hanger.

Abstract: A jacketed pipe flange (10) for connection to an end of an inner pipe (12) and to an end of a jacketed outer pipe (14) surrounding the inner pipe includes a central throughport (16) for mating with the inner pipe. The first annular sealing surface (18) surrounds a central throughport for sealing fluid within the inner pipe, a second annular sealing surface (20) surrounds the first sealing surface, and a third annular sealing surface (22) surrounds the second annular sealing surface for sealing fluid in the jacketed outer pipe from the exterior of the flange. An annular gap (24) separates the first and second sealing surfaces, and a test port (26) fluidly connects the annular gap with an exterior port in the flange. A plurality of axially extending throughports (34) in the flange between the second and third sealing surfaces pass fluid through the jacketed outer pipe and the flange to downstream components.

Abstract: A tool 10 for suspending in a well retrieves various metal debris from the well, and includes an elongate tool body 12 within a plurality of circumferentially shaped slots 14. Each slot having a radially outward portion with a circumferential width less than a circumferential width of a radially inward portion. The plurality of magnets 16 are provided in each slot, and one or more stop rings 18 retain the plurality of magnets in the slots while allowing for removal of the magnets from the slots. Each of the plurality of magnets 16 may be substantially enclosed within a non-ferrous carrier 26 having an outer configuration for fitting within a respective of one of the plurality of slots. According to the method of invention, the magnets are postioned within the slots and are retained within the slots by the one or more stop rings, and the elongate tool body and the plurality of the magnets are suspended in a well.

Abstract: An inner riser adjustable hanger and seal assembly are provided for applying tension to a casing string secured at a lower end within a well and supported at an upper end by a wellhead housing. The wellhead housing has a locking member on an inner surface thereof. A tensioning mechanism tensions the casing string and secures the upper end to the wellhead housing. A seal body locking member is radially moveable into engagement with the housing locking member to fix the axial position of the seal body relative to the wellhead housing. An upper seal assembly seals between the seal body and the wellhead housing, and a lower assembly seals between the seal body and the casing string. The casing string is tensioned without appreciable rotation of the hanger body or the upper and lower seal assemblies.

Abstract: A borehole may be drilled utilizing the bottom hole assembly 10, 50 with a downhole motor 14, which may offset at a selected bend angle. A gauge section 34 is secured to the bit 16 has a uniform diameter bearing surface along an axial length of at least 60% of the bit diameter. The axial spacing between the bend and the bit face is controlled to less than fifteen times the bit diameter. After drilling a section of the well with the BHA according to the present invention, a tubular may be inserted in the well by passing the tubular through an upper tubular, then the inserted tubular expanded while downhole to a diameter substantially equal to the expanded tubular.

Abstract: A system and method estimates the distance between a borehole and a subsurface boundary of interest in a geophysical region. In one embodiment, available existing sensor data for the geophysical region is used to create a resistivity model of the region, with the model reflecting changes in resistivity across the boundary. A hypothetical borehole has a number of segments along its length that are spaced-apart from the boundary by different, preselected distances. The ratio between two selected resistivity curves in each of the respective spaced-apart segments is computed, and these ratio values are plotted as a function of distance from the boundary. A curve-fitting algorithm is applied to derive an equation, which may be applied to actual sensor data from a sensor package.

Abstract: A tubular assembly 10 is disclosed for passing fluids within a hydrocarbon recovery well. The tubular assembly 10 has an insulated connection 12 between insulated tubing segments 14, 16. Tubing segments 14, 16 are connected via a threaded connection, and the resulting joint 10 is insulated by an external insulating sleeve 18. The insulating sleeve 18 may have unitary construction, such that the sleeve 18 may only be installed or removed by first breaking apart the joint 10. Alternatively, the sleeve 18 may comprise a plurality of arcuate partial-sleeves, which may be assembled about or removed from the completed joint 10 without first breaking apart the joint 10.

Abstract: A movable arm 10 engages a flexible line 50 at a well site for positioning the flexible line between run-in position for passing the flexible line with a tubular through a well hole in the rig floor and a clamping position wherein the flexible line is adjacent the tubular above the rig floor for clamping the line to the tubular. The arm 10 extends upward from the rig floor 70, and includes a line guide, such as roller 12, for engaging the flexible line when in the run-in position. A powered drive 14 moves the arm between the run-in position and the clamping position. A spacer 82 may be used for positioning two or more flexible lines at a desired spacing relative to one another prior to positioning the lines within a clamp secured to the tubular. A slip bowl assembly 60 may be laterally movable so that slips do not engage the flexible line as it is run in the well.