Abstract: A method and corresponding apparatus for automatically enabling and disabling an Optical Network Terminal (ONT) to communicate upstream with a network device, such as an Optical Line Terminal (OLT), is provided. The ONT includes at least one timing mechanism to time a duration of the ONT's being in an enabled or disabled state of upstream communications. After a timing mechanism times a desired duration, the ONT automatically changes between states of upstream communications (e.g., from enabled state to disabled state). The ONT may alternate between the enabled and disabled states of upstream communications until communications are established with the OLT. This method and corresponding apparatus prevent prolonged installation time because a technician can install the ONT without consideration of the ONT's state of upstream communications.

Abstract: A method and apparatus to restore default settings in an Optical Network Terminal (ONT) prevents the ONT from retaining previous ONT settings after the ONT is removed from a network. One example embodiment notifies a management system that an ONT is removed from the network and updates settings of the ONT with default settings via an Optical Line Terminal (OLT) in operative communication with the management system. The default settings disable at least one service, such as voice, data, or video service, between the OLT and ONT. Through use of the example embodiment, ONTs can be properly deleted from a network prior to or after removal from the network, which simplifies redeployment of ONTs and control over the ONTs.

Abstract: A method and apparatus for maintaining the heart rate of a user of a fitness apparatus at a scheduled target rate by varying the resistance of a first resistance mechanism with respect to a second resistance mechanism. To increase the heart rate, the resistance of the first resistance mechanism is increased to a maximum level before an adjustment is made to the second resistance mechanism. To decrease the heart rate, the resistance of the second resistance mechanism is decreased to a minimum level before an adjustment is made to the first resistance mechanism. The invention may be incorporated into a treadmill having resistance mechanisms including a mechanism to vary the speed of the treadmill belt and a mechanism to vary the grade of the treadmill.

Abstract: An iterative planning and monitoring method for drilling (and completing) difficult boreholes which avoids unnecessary risk or cost. The method provides multiple point value probability estimates of an indicator of drilling problems based upon a range of possible drilling variables, supplanting single point estimates. Expected drilling variables are perturbed within physically feasible bounds, and multiple estimates of the corresponding indicator values are made. The probability of each estimate is used to calculate the likelihood of an indicator of an unwanted condition. Mitigation measures are implemented if the probability of an unwanted condition exceeding a threshold value is unacceptable and the mitigated probability is reassessed. If the perturbed indicator change is not significant, the drilling variable is deleted from further analysis. Critical variables are thus quickly identified, allowing monitoring and selection of mitigation measures which are the most cost effective.

Abstract: A tube turning tool allows laterals to be drilled and completed without the need for articulated bending tools, underreaming, high fluid pressure, or a separate running of completion tools. The turning tool uses a rigid bent pipe section capable of being run downhole within many standard diameter well tubulars, supported in a desired position, and bending coil tubing at an ultra short radius of curvature as it is being run into the wellbore so that it can jet drill a lateral. After jet drilling a lateral, the lateral can also be completed using the coil tubing, e.g., gravel packed by pumping a slurry through the coil tubing while withdrawing the tubing from the lateral.

Abstract: A method for rotary drilling and removing cuttings provides a underbalanced drilling fluid pressure at the drilling face but overbalanced pressure in the wellbore. The preferred method uses a rotary drill within a housing which also encloses a jet pump which draws and pressurizes the cuttings and drilling fluid, a separator of the cuttings and a portion of the pressurized drilling fluid, and a nozzles to supply separated and reduced pressure drilling fluid back to drilling face while the cuttings and remaining pressurized drilling fluid flows up towards the surface. The method avoids overpressure strengthening of the drill face and underpressure damage to the wellbore.

Abstract: Rotary drag during drilling is reduced by 1) adding roller bearings to a tubular string and drill bit, and/or 2) adding a bearing assembly to the tubular string, and/or 3) adding a rotary discoupling tool to the tubular string. At the drill bit, this is achieved by miniature rollers built into the gauge section. Along the drill string periodic roller bearings or bearing standoff assemblies are placed along the string length and/or a rotary discoupling tool capable of sealing fluid and transmitting compression and tensile loads is placed in the string. The combination minimizes bit whirl and rotational drag, especially during the drilling of extended reach wellbores.

Abstract: A low-cost method drilling and completing wells attaches a non-rotating jet drilling tool to coiled tubing. After drilling, the tubing portion outside the well is cut and the remaining tubing becomes the liner or casing for the well. By also using a residual bend remover, centralizers, and injecting a thermal cement slurry, very low cost steam injector wells can be drilled and completed.

Abstract: A ported float shoe (5) and a landing collar (16) are attached at a first end of a portion of a casing string (4) and a sliding air trapping insert (20) is attached at the other end. The air trapping insert (20) includes a fluid flow passageway (24) blocked by a plug (22) attached by shear pins to the insert (20) or the air trapping insert is an inflatable insert (55) having a conduit (60) providing a fluid passageway to the first end. The air trapping insert and float shoe form an air cavity (12a or 12b) within the string portion (4). The air cavity provides buoyant forces during running, cementing or other casing operations within a borehole (2), reducing running drag and the related chance of a differentially stuck casing (4). It also allows reciprocation and rotation during cementing and avoids separate removal steps.

Abstract: A hydraulic setting and release system for run in and cementing of a work string and tubular within a borehole has a small diameter pipe string extending from a release tool through a packer to within the tubular. The system forms at least one annulus between the pipe string and tubular. The pipe string includes a ported nipple and a seat subassembly downstream of the ported nipple. The pipe string allows the packer to anchor the tubular, by being inflated through the port even when the seat is blocked. The pipe string also forms a flotation annulus which is sealed by, and the pipe string is supported by, a drag/seal subassembly downstream of the seat assembly. The system also includes a safety release tool for reliable uncoupling. Uncoupling is accomplished after run in, displacing a cement slurry slug separated by a plug or dart using a following pump down fluid which can land on the seat and block further flow and displacement of cement slurry, and anchoring.

Abstract: A hydraulic setting and release tool has a shear out setting assembly attached to a string coupling member. Upon reaching a predetermined hydraulic pressure, a piston of the tool shears restraining shear pins and moves in a body of the tool to release dogs that engage the coupling member. When used in running in a liner, the coupling member is a running head that rotates the liner during running in and cementing. When used as a drill string release tool, the coupling member is a release sub, the tool being placed serially with other string components. If the drill string gets stuck, it is separated by merely increasing the hydraulic pressure sufficiently to shear the pins and allow the piston to move and the dogs to retract to separate the release sub from the shear out assembly.

Abstract: A ported float shoe (5) and a landing collar (16) are attached at a first end of a portion of a casing string (4) and a sliding air trapping insert (20) is attached at the other end. The air trapping insert (20) includes a fluid flow passageway (24) blocked by a plug (22) attached by shear pins to the insert (20) or the air trapping insert is an inflatable insert (55) having a conduit (60) providing a fluid passageway to the first end. The air trapping insert and float shoe form an air cavity (12a or 12b) within the string portion (4). The air cavity provides buoyant forces during running, cementing or other casing operations within a borehole (2), reducing running drag and the related chance of a differentially stuck casing (4). It also allows reciprocation and rotation during cementing and avoids separate removal steps.

Abstract: A hydraulic setting and release tool has a shear out setting assembly attached to a string coupling member. Upon reaching a predetermined hydraulic pressure, a piston of the tool shears restraining shear pins and moves in a body of the tool to release dogs that engage the coupling member. When the dogs release, springs retract the dogs from engagement in sockets of the coupling member and the shear out setting assembly separates from the coupling member. When used in running in a liner, the coupling member is a running head that rotates the liner during running in and cementing. When used as a drill string release tool, the coupling member is a release sub, the tool being placed serially with other string components. If the drill string gets stuck, it is separated by merely increasing the hydraulic pressure sufficiently to shear the pins and allow the piston to move and the dogs to retract to separate the release sub from the shear out assembly.

Abstract: An oil tool release joint with a top sub that has a pin end which inserts into an opening in a bottom sub provides an alternative remote tool for separating pipe string segments after rotation. The subs are held together by shear pins which are wedged through holes in the bottom sub into recesses in the top sub. The bottom sub has uphole extending splines that engage slots in the top sub when the subs are connected. The splines and slots translate rotational motion from one sub to the other. The joint releases upon the application of a force sufficient to shear the shear pins either by hydraulic pressure in the drill string, an upward pull on the top sub or both. A guide ring encircles the uphole ends of the splines to guide material into the bottom sub when the joint is separated.

Abstract: A ported float shoe and a landing collar are attached at one end of a casing string and a sliding air trapping insert attached by shear pins at the other end. The air trapping insert includes a fluid flow passageway blocked by a plug attached by shear pins to the insert. The air trapping insert and float shoe form an air cavity within the string portion. After running the string into a deviated well bore, the shear pin supported plug is pressure actuated open to allow air to be vented and drilling mud to flow into the cavity. A wiper plug followed by pressurized cement slurry shears away the attached insert, opens the float shoe, moves the insert to the bottom of the well, and allows cementing of the casing. Moved apparatus (near well bottom) forms a single drillable unit until drilled out in normal post-cementing operations. The flotation method reduces insertion drag and the related chance of a differentially stuck casing, and avoids the separate removal steps required by current flotation techniques.