Pad force is one of the major parameters in some drilling systems, such as a RSS, that affect steering decisions during drilling. The disclosure recognizes that the pad force can change during drilling due to, for example, unintentional leaking through a pad seal that has been damaged due to the wear and tear of drilling. With a decrease in the pad force, the steering capability of the drilling tool can be compromised. As such, the disclosure provides a method and system that determines pad force information in real time for controlling drilling. The pad force information can be determined based on sensor data, component data, and drilling data. An estimated pad force is one example of the pad force information that can be calculated and used to direct a drilling operation.

Pad force is one of the major parameters in some drilling systems, such as a RSS, that affect steering decisions during drilling. The disclosure recognizes that the pad force can change during drilling due to, for example, unintentional leaking through a pad seal that has been damaged due to the wear and tear of drilling. With a decrease in the pad force, the steering capability of the drilling tool can be compromised. As such, the disclosure provides a method and system that determines pad force information in real time for controlling drilling. The pad force information can be determined based on sensor data, component data, and drilling data. An estimated pad force is one example of the pad force information that can be calculated and used to direct a drilling operation.

A control system for a pressure management apparatus (PMA) of a drilling system has an onsite device in close proximity to and in communication with the PMA and an offsite device at a remote location. Both the onsite and offsite devices are connected to a network, such as the Internet, through which the devices can communicate with one another. The onsite device receives data in real-time from the PMA and the offsite device can access the data in real-time via the network. The offsite device can generate a command based on the data or user input at the offsite device and send the command to the onsite device to modify one or more settings of the PMA. A control panel is displayed on the user interface of the offsite device to allow an operator to remotely control the PMA.

A control system for a pressure management apparatus (PMA) of a drilling system has an onsite device in close proximity to and in communication with the PMA and an offsite device at a remote location. Both the onsite and offsite devices are connected to a network, such as the Internet, through which the devices can communicate with one another. The onsite device receives data in real-time from the PMA and the offsite device can access the data in real-time via the network. The offsite device can generate a command based on the data or user input at the offsite device and send the command to the onsite device to modify one or more settings of the PMA. A control panel is displayed on the user interface of the offsite device to allow an operator to remotely control the PMA.

A method of validating a directional survey includes measuring the gravity and magnetic field vectors using a surveying tool and computing an overall statistical distance of the measurement. The statistical distance may be calculated from reference values associated with the surveying tool using corresponding surveying tool codes with error values. In a further aspect, an error covariance matrix may be used to determine whether the new errors in a survey are consistent or not with errors from one or more previous surveys.

A method of validating a directional survey includes measuring the gravity and magnetic field vectors using a surveying tool and computing an overall statistical distance of the measurement. The statistical distance may be calculated from reference values associated with the surveying tool using corresponding surveying tool codes with error values. In a further aspect, an error covariance matrix may be used to determine whether the new errors in a survey are consistent or not with errors from one or more previous surveys.

A managed pressure drilling (MPD) manifold has one or more valves that are operable by one or more actuators configured to synchronize the opening of one or more passageways in the valves with the closing of one or more of the other passageways in the valves, in order to minimize the likelihood of error and reduce response time. The valves are configured to transition smoothly between positions without fully blocking fluid flow in the manifold while changing the flow direction. The synchronization may be achieved mechanically, electrically, hydraulic, and/or pneumatically. The actuators may be remotely controlled by a control unit having a processor and control logic software, based on data collected by one or more sensors in the MPD manifold. The positions of the valves of the MPD manifold may be automatically adjusted by the control unit via the actuators.

A managed pressure drilling (MPD) manifold has one or more valves that are operable by one or more actuators configured to synchronize the opening of one or more passageways in the valves with the closing of one or more of the other passageways in the valves, in order to minimize the likelihood of error and reduce response time. The valves are configured to transition smoothly between positions without fully blocking fluid flow in the manifold while changing the flow direction. The synchronization may be achieved mechanically, electrically, hydraulic, and/or pneumatically. The actuators may be remotely controlled by a control unit having a processor and control logic software, based on data collected by one or more sensors in the MPD manifold. The positions of the valves of the MPD manifold may be automatically adjusted by the control unit via the actuators.

In some aspects, the present invention comprises a system and method for optimizing the control scheme used for drilling operations based on the complex and large data sets available in realtime during operation of a wellsite and based on existing model data available at the wellsite for past similar drilling operations. Such optimizations typically require downtime to quantify how the realtime values will factor into the control model, but the present invention allows for such optimization in realtime in a closed-loop system that will reduce the non-productive time associated with reservoir operations.

In some aspects, the present invention comprises a system and method for optimizing the control scheme used for drilling operations based on the complex and large data sets available in realtime during operation of a wellsite and based on existing model data available at the wellsite for past similar drilling operations. Such optimizations typically require downtime to quantify how the realtime values will factor into the control model, but the present invention allows for such optimization in realtime in a closed-loop system that will reduce the non-productive time associated with reservoir operations.