Abstract: A nuclear tool includes a tool housing; a d-D neutron generator disposed in the tool housing; a d-T neutron generator disposed in the tool housing; and, optionally, a control circuit for controlling pulsing of the d-D neutron generator and the d-T neutron generator. A method for well-logging using a nuclear tool includes disposing the nuclear tool in a wellbore penetrating a formation; pulsing a d-D neutron generator to emit neutrons at a first energy level into the formation; pulsing a d-T neutron generator to emit neutrons at a second energy level into the formation; and measuring signals returning from the formation.

Abstract: A drill bit direction system and method is disclosed that modifies or biases the stochastic movement of the drill bit and/or stochastic interactions between the drill bit and an inner-wall of a borehole being drilled by a drilling system to change the direction of drilling of the drilling system. The direction of the drill bit is monitored to determine if the direction happens to align in some way with a preferred direction. If the direction isn't close enough to a preferred direction, a biasing mechanism modifies the stochastic movement in an attempt to modify the direction closer to the preferred direction. Any of a number of biasing mechanisms can be used. Some embodiments can resort to conventional steering mechanisms to supplement the biasing mechanism.

Abstract: A data repository defined by a single logical specification includes a data store including a plurality of tables and a view of the plurality of tables, a data dictionary including a meta-table and means to generate the data store, where the meta-table is generated from the single logical specification defining the data repository, and a merge engine configured to merge incoming data with the data store based on match attributes defined by the single logical specification, where the incoming data is stored in at least one staging area.

Abstract: A method that involves developing an electromagnetic property model of a near surface area and using this electromagnetic property model and electromagnetic data acquired using one or more electromagnetic transmitters located above the near surface area and one or more electromagnetic receivers located within a wellbore to determine one or more electromagnetic properties of a subsurface area. Also an electromagnetic data acquisition system that includes one or more electromagnetic transmitters capable of being operated on the earth's surface, one or more first electromagnetic receivers capable of being operated within a wellbore and capable of receiving signals from the one or more electromagnetic transmitters, and one or more second electromagnetic receivers capable of being located on the earth's surface near the one or more electromagnetic transmitters and capable of receiving signals from the one or more electromagnetic transmitters. Related embodiments are also described.

Abstract: A drill pipe includes a pin end connector, a box end connector, a first communication connector and a second communication connector. The pin end connector includes a first region to form a threaded connection to join sections of the drill pipe together, and the first region includes at least one thread that begins at one end of the first region and ends at the other end of the first region. The box end connector receives the pin end connector, and the box end connector includes a second region to mate with the first region to form the threaded connection. The first communication connector is attached to the pin end connector and is located in the first region; and the second communication connector is attached to the box end connector and located in the second region to form a communication connection with the first communication connector.

Abstract: A subsurface formation monitoring system comprises: a conductive piping structure 2 comprising either a conductive casing or a non conductive casing fitted with a conductive tubing, the conductive piping being positioned within a borehole BH extending into the subsurface formation GF, a surface installed power and communication module 3, and a downhole installed conductive casing or tubing sub 4A, 4B, 4C comprising at least one sensor 5, 15 mounted on the sub, a data communication module 6 for wireless communication of the sensor measurements to the surface installed power and communication module, and a powering means 7 for providing power to the data communication module 6 and the sensor 5, 15.

Abstract: A system and method are provided for drilling a wellbore. The wellbore is formed with a drilling tool that cuts through a formation. A pumping system removes cuttings from the drilling tool and also transports the cuttings along at least a portion of the wellbore formed behind the drilling tool.

Abstract: An electric power generator includes a conduit disposed in a wellbore penetrating subsurface formations and at least one piezoelectric transducer in contact with the conduit. The piezoelectric transducer is configured to undergo stress in response to vibration in the conduit. The transducer includes a plurality of piezoelectric crystals stacked in a thickness direction and each polarized in the thickness direction. The transducer comprises at least one of a composite rubber layer disposed between successive piezoelectric crystals, and at least one support at a longitudinal end of the transducer configured to cause the crystals to bend in response to vibration in the conduit.

Abstract: Subterranean oilfield high-temperature devices configured or designed to facilitate downhole monitoring and high data transmission rates with laser diodes that are configured for operation downhole, within a borehole, at temperatures in excess of 115 degrees centigrade without active cooling.

Abstract: To update a subterranean model, an initial subterranean model is provided, and based on the initial subterranean model, changes to subterranean parameters are predicted using a reservoir simulator. Electromagnetic data representing characteristics of a subterranean structure is computed according to the predicted changes to the subterranean parameters, and the initial subterranean model is modified based on comparing the computed electromagnetic data with observed electromagnetic data.

Abstract: A method for estimating hydrocarbon volume in a layered subsurface formation includes determining a vertical resistivity and a horizontal resistivity in the formation. A bound water saturation and a total porosity of individual layers of the formation are determined. Values of horizontal resistivity and vertical resistivity of the formation are calculated based on the bound water saturation and the total porosity for each layer and on an estimated irreducible bulk volume of water in each layer. The estimated values are compared to the determined horizontal resistivity and vertical resistivity. The estimated irreducible water saturation in each layer is adjusted and estimating the values is repeated until differences between the estimated values and the determined vertical and horizontal resistivity values fall below a selected threshold. The hydrocarbon volume is estimated from the adjusted irreducible water saturation for each layer.

Abstract: A method and system is disclosed for automatically correcting for depth errors in measurements taken from a drill-string during the drilling phase of the construction of a hydrocarbon wellbore. The correction is based on a stress profile which in turn is based on the states of the drilling rig, drill string description length spec, borehole description trajectory, friction factor and weight on bit.

Abstract: Methods for density logging utilizes gamma-rays above a pair-production threshold so as to determine lithology information of formations whereby to correct a measured density data.

Abstract: The invention relates to a method for detecting the presence of hydrocarbons near an unmanned offshore oil platform. The method steps include monitoring reflected atmospheric and thermal radiation, detecting the presence of hydrocarbons, and generating an alert based on the presence of hydrocarbons.

Abstract: A packer includes a seal element and a piston. The piston compresses the seal element to form an annular seal in the well. A pressure wave, such as a pressure wave that is caused by a chemical reaction or the detonation of an explosive, is generated in the packer to at least partially assist an operation (the setting of a slip, setting of the seal element, etc.) of the packer. In some implementations, the chemical reaction or explosive detonation occurs in response to a predetermined movement of the piston.

Abstract: According to the invention, a system for determining at least one property of a fluid flow through a conduit is disclosed. The system may include a bearing, at least one blade member, and a monitoring device. The bearing may be coupled with an interior of the conduit, and may include an inner race, where the inner race may rotate. The blade members may be coupled with the inner race, and may extend from the inner race toward the interior of the conduit. The blade members may rotate when a fluid flows through the interior of the conduit, and the inner race of the bearing may rotate when the blade members rotate. The monitoring device may be configured to determine a rate of rotation of the blade members. At least one property of the fluid flow may be determined based at least in part on the rate of rotation.

Abstract: A method of drilling a borehole from a selected location in an existing wellbore (1) penetrating subterranean earth formation having at least one hydrocarbon bearing zone (3) wherein the existing wellbore is provided with a casing (4) and a hydrocarbon fluid production conduit (6) is arranged in the existing wellbore in sealing relationship with the wall of the casing, the method comprising: passing a remotely controlled electrically operated drilling device (12) from the surface through the hydrocarbon fluid production conduit to the selected location in the existing wellbore; operating the drilling device such that cutting surfaces on the drilling device drill the borehole from the selected location in the existing wellbore thereby generating drill cuttings wherein during operation of the drilling device, a first stream of produced fluid flows directly to the surface through the hydrocarbon fluid production conduit and a second stream of produced fluid is pumped over the cutting surfaces of the drilling dev

Abstract: A completion assembly having a force transfer apparatus to assist in the release of a loaded member.

Abstract: Safety apparatus is disclosed for providing ballistic train interruption in a perforating system. The safety apparatus comprises a generally tubular shaped housing having first and second ends which are fabricated to permit the housing to be positioned at any location in the perforating system. The apparatus comprises first and second ballistic sections in the housing and a third ballistic section which is rotatably mounted in the housing to move between a disarmed position and an armed position based on downhole pressure. Upon retrieval of the perforating system from the wellbore, the safety apparatus functions to return a third ballistic section to its disarmed position. Additionally, apparatus is provided to permanently disable the third ballistic section to insure that no inadvertent detonation of the guns occurs when retrieving the system from a wellbore.

Abstract: A technique is provided by which energy is physically/mechanically transmitted down through a wellbore. The transmitted energy is directed downhole along a fluid channel and impinges on an energy converter positioned in the wellbore or at another subterranean location. The energy converter converts the physical energy into electrical energy that can be supplied to a downhole device.