Techniques for determining trajectories for a plurality of wells while avoiding collision between wells are presented. The techniques can include determining a zone of uncertainty for individual wells of the plurality of wells, determining a minimum separation factor for individual wells of the plurality of wells, determining a gradient of a separation factor for at least one pair of wells the plurality of pairs of wells, updating a nudge position for at least one well, and providing nudge positions for the individual wells of the plurality of wells.

To control well drilling, information relating to a trajectory of a well is received, and fluid flow in the well is simulated according to the received information. Simulating the fluid production comprises simulating production flow assurance that seeks to reduce occurrence of mixtures of different types of fluids that reduce production of a target fluid. In response to results of the simulating, a further trajectory for further drilling of the well is identified.

To control well drilling, information relating to a trajectory of a well is received, and fluid flow in the well is simulated according to the received information. Simulating the fluid production comprises simulating production flow assurance that seeks to reduce occurrence of mixtures of different types of fluids that reduce production of a target fluid. In response to results of the simulating, a further trajectory for further drilling of the well is identified.

An electrically passive device and method for in-situ acoustic emission, and/or releasing, sampling and/or measuring of a fluid or various material(s) is provided. The device may provide a robust timing mechanism to release, sample and/or perform measurements on a predefined schedule, and, in various embodiments, emits an acoustic signal sequence(s) that may be used for triangulation of the device position within, for example, a hydrocarbon reservoir or a living body.

An electrically passive device and method for in-situ acoustic emission, and/or releasing, sampling and/or measuring of a fluid or various material(s) is provided. The device may provide a robust timing mechanism to release, sample and/or perform measurements on a predefined schedule, and, in various embodiments, emits an acoustic signal sequence(s) that may be used for triangulation of the device position within, for example, a hydrocarbon reservoir or a living body.

A wellbore assembly is provided that can include a first motor housing assembly member and a second motor housing assembly member that can bend relative to the first motor housing assembly at a bend location. The assembly can also include a strain gauge positioned on a first side of the bend location to determine an amount of bend of the second motor housing assembly member relative to the first motor housing assembly member by determining a strain. Based on the strain, the amount of bend or bend direction of the second motor housing assembly member relative to the first motor housing assembly member can be determined.

A wellbore assembly is provided that can include a first motor housing assembly member and a second motor housing assembly member that can bend relative to the first motor housing assembly at a bend location. The assembly can also include a strain gauge positioned on a first side of the bend location to determine an amount of bend of the second motor housing assembly member relative to the first motor housing assembly member by determining a strain. Based on the strain, the amount of bend or bend direction of the second motor housing assembly member relative to the first motor housing assembly member can be determined.

A drilling area network hub is located proximate to a drill rig and includes an uphole transceiver in bidirectional communication with a downhole transceiver by utilizing the drill string as an electrical conductor. Certain information is collected including rig-based and/or location information. At least one field report is generated based on the certain information to characterize at least one of an inground operation, an operational condition of the downhole transceiver, an operational condition of the uphole transceiver, and an operational condition of the drill rig. A drilling area network server receives the field report from the Internet at a remote location and can generate a custom report and/or recommended actions based on field data. Region specific parameters can be applied to the operation of a drilling system. The drilling area network hub can transfer data logs to the remote location according to assigned priorities.

A drilling area network hub is located proximate to a drill rig and includes an uphole transceiver in bidirectional communication with a downhole transceiver by utilizing the drill string as an electrical conductor. Certain information is collected including rig-based and/or location information. At least one field report is generated based on the certain information to characterize at least one of an inground operation, an operational condition of the downhole transceiver, an operational condition of the uphole transceiver, and an operational condition of the drill rig. A drilling area network server receives the field report from the Internet at a remote location and can generate a custom report and/or recommended actions based on field data. Region specific parameters can be applied to the operation of a drilling system. The drilling area network hub can transfer data logs to the remote location according to assigned priorities.

Systems and methods for measuring a parameter of interest in a borehole in an earth formation are provided. The systems include a downhole sensor having a first sensor component with a first temperature and a second sensor component with a second temperature, the downhole sensor disposed on a downhole component. A temperature control system is configured with a thermal control mechanism operatively connected to at least one of the first and second sensor components. The thermal control mechanism is configured to maintain a temperature difference between the first temperature and the second temperature below a pre-determined temperature difference. The downhole sensor is configured to measure the parameter of interest when the temperature difference is below the pre-determined temperature difference.