Patent application number | Description | Published |
20100042327 | BOTTOM HOLE ASSEMBLY CONFIGURATION MANAGEMENT - A method for configuring a bottom hole assembly from a plurality of formation evaluation tools, includes: creating a health history for each tool of the plurality of formation evaluation tools; ranking the resulting plurality of health histories according to health; and selecting at least one tool for the bottom hole assembly according to a ranking for the at least one tool. A system and a computer program product are also provided. | 02-18-2010 |
20110114336 | Apparatus and Methods for Multi-Layer Wellbore Construction - In aspects, the present disclosure provides a monobore wellbore construction apparatus and method, which in one embodiment may include a series of overlapping expandable liner sections. In one aspect, the overlapping liner sections may be expanded and pressed to provide no gaps along the length of the liner system. In another aspect, the liner sections may include centralizers and/or circumferential seals that provide sealing functions and spaces between the overlapping liner sections. The liner sections may be lined with a suitable sealing material, including an epoxy or may be filled with cement or another desired materials. | 05-19-2011 |
20110308791 | Apparatus for Use Downhole Including Devices Having Heat Carrier Channels - A method and apparatus for regulating a temperature of a device in a tool used in a wellbore is disclosed. The device generally includes a substrate and a heat source associated with the substrate that induces heat into the substrate. The substrate includes a fluid channel therein. A fluid system provides the fluid into the fluid channel and out of the fluid channel to control the temperature of the component. | 12-22-2011 |
20120024539 | ROTARY COIL TUBING DRILLING AND COMPLETION TECHNOLOGY - An apparatus for performing a drilling operation or a non-drilling wellbore operation may include a string that has a rigid tubular, a connector coupled to the rigid tubular, a non-rigid tubular coupled to the connector; and at least one motor positioned along the string. The string may be disposed into a wellbore to perform one or more tasks. | 02-02-2012 |
20120061097 | Pump Down Liner Expansion Method - A string to be expanded is run in with a running string that supports a swage assembly. The running string is secured to the existing tubular and the top of the string to be expanded is sealed around the supported running string. The pressure applied to the annular space above the seal drives the liner over the swage. A cement shoe is affixed to the lower end of the string that is expanded after becoming detached from the running string assembly. When the expanded liner bottoms on a support, generally the hole bottom, the cement is delivered through the shoe and the expansion of the top of the string into a recess of the string above continues. The swage assembly with the seal and the anchor are then recovered as the running string is removed during the process of expanding the top of the expanded string into the lower end recess of the existing string already in the wellbore. | 03-15-2012 |
20120085549 | Pump Down Swage Expansion Method - The tubular string to be expanded is run in on a running string. The swage assembly has a seal from the running string to the existing tubular and the top of the tubular string to be expanded also has a similar seal against the exiting tubular. Annulus pressure around the running string drives the swage assembly to support the expanded tubular to the exiting tubular and to continue expansion to the end of the tubular. Cementing then takes place followed by reconfiguring the swage assembly to engage the liner hanger seal with the result being a monobore connection in a single trip including the cementing. | 04-12-2012 |
20120089336 | SYSTEM AND METHOD FOR ESTIMATING REMAINING USEFUL LIFE OF A DOWNHOLE TOOL - A system for determining the amount of life consumed for a tool includes at least one sensor associated with the tool for generating observation data, a memory in operable communication with the at least one sensor, the memory including a database for storing the observation data generated by the sensor, and a processor in operable communication with the memory. The processor includes a model generator that generates a current model for a current run of the tool. The current model includes parameters of a functional approximation of the observation data. The processor also includes a classifier that classifies the current model and a current run estimator that determine the amount of life consumed based on the classification of the current model and a time of use associated with the current run. | 04-12-2012 |
20130002268 | DISTRIBUTED SENSORS TO MEASURE CEMENT STATE - A system for determining a curing state for cement disposed in a borehole penetrating the earth that includes a transceiver that includes a transmitting coil and that is configured to provide an input signal to the coil that sweeps through a frequency range and to measure the magnitude of the voltage across the coil. The system also includes a plurality of sensor nodes disposed in the concrete. The sensor nodes include a receiving coil and a capacitor coupled to the receiving coil to form a receiving circuit and that has a capacitance that changes as one of pressure or strain in the cement changes. | 01-03-2013 |
20130048308 | Integrated Continuous Liner Expansion Method - An additional string is run through an existing string using a running string. With the strings overlapping an upper inflatable secures them together leaving gaps. The upper inflatable creates an upper expanded zone where the swage assembly is then built. The swage assembly has a seal and upon pressure being applied between the upper inflatable and the seal the swage assembly releases the running string and is pushed to expand the additional string until tagging a cement shoe. The running string is rejoined to the swage assembly and after cementing a lower inflatable is deployed to make a bell and to set an external packer if used. If there is an external packer the shoe releases and on the way out of the hole the upper inflatable sets a seal in the lap. | 02-28-2013 |
20130056228 | Annular Seal for Expanded Pipe with One Way Flow Feature - The seal has a base ring that expands with the underlying supporting tubular. Extending from the base ring is a pleated structure with segments folded over each other so that the run in shape is small and up against the supporting tubular for run in. The pleated segments can have internal stiffeners that also add a bias radially outwardly when the structure is freed to move in that direction. A retaining band keeps the assembly retracted until tubular expansion defeats the band to allow the unitary structure to move out radially to the wellbore or surrounding tubular. The pleated portion unfolds and spans outwardly from the base ring to retain pressure differential in one direction while allowing fluid flow in the opposite direction. The assembly can be attached to a swage device so that pressure from above into the set seal can drive one or more swage members to expand a tubular. | 03-07-2013 |
20130098634 | MONOBORE EXPANSION SYSTEM - ANCHORED LINER - Methods for forming a wellbore may include placing an upper section of inside a lower section of a parent liner; positioning an upper sealing member and a lower sealing member in the wellbore to form a pressure chamber, and expanding the second liner using the pressure chamber. The sealing members move axially relative to one another and the second liner has an inner bore that is hydraulically isolated from the pressure chamber. A related apparatus may include upper and lower sealing members that cooperate to form a pressure chamber that is hydraulically isolated from an inner bore of the second liner. A work string may include the sealing members, a connector that extends through the pressure chamber and the second liner; and an expander. The expander expands the second liner in response to the axial separation of the sealing members. | 04-25-2013 |
20130145590 | POSITIONING SYSTEM AND METHOD FOR AUTOMATED ALIGNMENT AND CONNECTION OF COMPONENTS - A system for aligning and connecting components including a support structure and a measuring apparatus coupled to the support structure. The measuring apparatus is arranged to spatially analyze a first tubular component with respect to a second tubular component for determining an adjustment vector therebetween. An alignment apparatus is coupled to the support structure and in data communication with the measuring apparatus. The alignment apparatus includes a plurality of actuators operatively arranged in parallel for moving at least one of the first or second tubular components relative to the other for coaxially arranging the first and second tubular components in accordance with the adjustment vector. A connection apparatus is coupled to the support structure and operatively arranged for connecting the first and second tubular components together. | 06-13-2013 |
20130284442 | Heat Treatment for Removal of Bauschinger Effect or to Accelerate Cement Curing - Materials are delivered within an expanded string before the string is subsequently compressively loaded such that the heat given off by the reaction of the delivered materials raises the fluid temperature in the recently expanded string to temperatures in a range of about 150-300 degrees Centigrade. The materials can be separated for delivery and then allowed to contact to initiate the reaction. Alternatively the materials can be delivered in separate conveyances for more immediate start of the exothermic reaction at the needed location or locations. To the extent there is curing cement about the expanded tubular, then the heat generated also reduces curing time to full setup of the sealing material. The applied heat counteracts or eliminates the Bauschinger effect. | 10-31-2013 |
20130299169 | One Trip Casing or Liner Directional Drilling With Expansion and Cementing - A tubular string is advanced with a bottom hole assembly as the hole is drilled and reamed in a desired direction with the aid of directional drilling equipment adjacent the bit. When the advanced tubular forms the desired lap to the existing tubular, the assembly can be configured to cement the tubular and expansion can then be accomplished to fill the annular space and enhance the cement bonding. The expansion equipment can create a bottom bell on the expanded tubular and expand the top end into a bell of the existing tubular so that a monobore is created as the process is repeated with each added string. Numerous variations are contemplated for each single trip including but not limited to the direction of expansion, whether cementing or expansion occurs first, reforming folded tubing in the hole as well as the nature of the expansion tool and pressure control when drilling. | 11-14-2013 |
20140131953 | Self-energized Seal or Centralizer and Associated Setting and Retraction Mechanism - A self energizing structure can function as a centralizer or as a seal when allowed to spring out after a retainer is moved away from an overlying position for run in to protect the structure. Segments extend from a common base ring and are radially offset during run in. Alternating segments have landing surfaces on opposed ends such that on release of the structure the intervening segments land on such surfaces to form a cohesive single layer with all segments circumferentially aligned and against a surrounding tubular or the borehole wall. The structure is held retracted with a bi-directionally movable sleeve operable in a variety of ways from the surface. Internally the sleeve has splines to push the segments with the landing surfaces back so that the structure can collapse back into the sleeve for removal. Structures can be stacked and used as centralizers with alternating segments removed. | 05-15-2014 |
20140191016 | Tubular Friction Welding Joining Method without Rotation of the Tubulars - Tubulars are joined to each other without rotation of the tubulars. A coupling is placed between the aligned tubulars and is supported for rotation or oscillating about its longitudinal axis. The tubulars are clamped in a manner that allows a compressive force to be transmitted to the coupling as the coupling is rotated. An induction device can preheat each connection site before friction welding and/or provide heat as the connection is made and is allowed to cool down. The process can continuously create a string of casing or liner that can be run in or drilled into a wellbore. | 07-10-2014 |
20140209293 | DOWNHOLE ASSEMBLY - A downhole assembly includes a wave seal packer including a wave portion having a wave form shape in an un-expanded condition. The wave portion configured to radially encircle a tubular with alternating and interconnected uphole and downhole portions. The packer having a substantially uniform internal radius in the un-expanded condition. | 07-31-2014 |
20140216816 | CONTINUOUS CIRCULATION AND COMMUNICATION DRILLING SYSTEM - An apparatus for performing a wellbore operation includes a drill string having a rigid tubular section formed of a plurality of jointed tubulars and a plurality of valves positioned along the rigid tubular section. Each valve may have a radial valve controlling flow through a wall of the rigid tubular section and a signal relay device configured to convey information-encoded signals. Wellbore operations may be performed by transmitting signals using the signal relay devices. | 08-07-2014 |
20140345858 | Automated Wellbore Equipment Feeding System - An apparatus for manipulating objects include a plurality of actuators distributed on a rig. The actuators cooperate to orient and move the well equipment. Each actuator may include at least one non-rigid tension member configured to engage the well equipment, and at least one sensor generating a signal representative of at least one parameter of: (i) a length of at least one of the at least one non-rigid tension members, (ii) a tension along at least one of the at least one non-rigid tension members, (iii) a position of at least one of the at least one non-rigid tension members; and (iv) an orientation of at least one of the at least one non-rigid tension members. The actuators may also each include a drum guiding each of the at least one non-rigid tension members and a motor rotating each drum. The apparatus further includes a controller in communication with the actuators, the controller being programmed to move the object based on the at least one sensor signals. | 11-27-2014 |