Latch position indicator systems remotely determine whether a latch assembly is latched or unlatched. The latch assembly may be a single latch assembly or a dual latch assembly. An oilfield device may be positioned with the latch assembly. Non-contact (position), contact (on/off and/or position) and hydraulic (flowmeter), both direct and indirect, embodiments include fluid measurement systems, an electrical switch system, a mechanical valve system, and proximity sensor systems.

This disclosure is directed to initiating adjustment of an operation associated with an underwater drilling system, which may include receiving at least one underwater image; identifying the reference object in the at least one underwater image, wherein a position of the reference object is fixed relative to an underwater borehole or an underwater cloud; determining a first parameter associated with the reference object; identifying the underwater cloud in the at least one underwater image; determining a second parameter associated with the underwater cloud; adjusting the second parameter associated with the underwater cloud based on the first parameter associated with the reference object; and initiating an adjustment of the operation associated with the underwater drilling system based on the adjusted second parameter associated with the underwater cloud.

This disclosure is directed to initiating adjustment of an operation associated with an underwater drilling system, which may include receiving at least one underwater image; identifying the reference object in the at least one underwater image, wherein a position of the reference object is fixed relative to an underwater borehole or an underwater cloud; determining a first parameter associated with the reference object; identifying the underwater cloud in the at least one underwater image; determining a second parameter associated with the underwater cloud; adjusting the second parameter associated with the underwater cloud based on the first parameter associated with the reference object; and initiating an adjustment of the operation associated with the underwater drilling system based on the adjusted second parameter associated with the underwater cloud.

A method of performing line insulation monitoring of a pair of conductor lines at least partially located in a cable is provided, comprising the steps of providing a first power switch in a first conductor line of the pair and a second power switch in a second conductor line of the pair, providing a line insulation monitor at a first end of the pair of conductor lines, electrically connected to the pair of conductor lines, at the second end of the pair of conductor lines, electrically connecting the first and second conductor lines, placing the first and second power switches into a monitoring configuration wherein the first power switch is closed while the second power switch is open, and using the line insulation monitor to monitor the insulation of the conductor lines.

A sensor apparatus for wellbore applications includes an electrical conductor extending within an armored tubular jacket to protect the electrical conductor. The electrical conductor is isolated from wellbore fluids when the sensor is placed in a wellhead flange by redundant seals such that the tubular jacket around the conductor does not provide a leak path to the surrounding subsea or surface environment. To isolate the electrical conductor, a connector housing may be provided that establishes a glass-metal seal or a PEEK-metal seal with the electrical conductor. The connector housing may be welded or otherwise sealed to a Christmas tree flange that connects to the wellhead flange. The welds and seals of the sensor apparatus may be proof tested to ensure their effectiveness before the Christmas tree flange is installed in the subsea or surface environment.

A sensor apparatus for wellbore applications includes an electrical conductor extending within an armored tubular jacket to protect the electrical conductor. The electrical conductor is isolated from wellbore fluids when the sensor is placed in a wellhead flange by redundant seals such that the tubular jacket around the conductor does not provide a leak path to the surrounding subsea or surface environment. To isolate the electrical conductor, a connector housing may be provided that establishes a glass-metal seal or a PEEK-metal seal with the electrical conductor. The connector housing may be welded or otherwise sealed to a Christmas tree flange that connects to the wellhead flange. The welds and seals of the sensor apparatus may be proof tested to ensure their effectiveness before the Christmas tree flange is installed in the subsea or surface environment.

A method of assessing fluid flow in a conduit, the fluid comprising hydrocarbons, the method comprising the steps of: (a) measuring optical variances resulting from at least one circumferential mode of vibration of the conduit by directing a monochromatic light source, such as from a vibrometer, onto an external surface of the conduit thereby providing a measured vibration of the conduit as a result of fluid flow in the conduit. The data normally accurately measures velocity of the conduit usually considered to be wideband noise. Accordingly, sample rates are high, such as at least 5,000 times per second. The data is then assessed, for example by using a Fourier Transform, and a pre-trained algorithm to predict fluid flow at that point in the conduit, or upstream or downstream thereof. An associated apparatus is also disclosed. Embodiments of the invention can thus provide a non-invasive method and apparatus for providing information on the nature of flow regimes in pipelines, such as subsea pipelines which can be useful to optimise production and reduce well testing and/or downtime.

A method of assessing fluid flow in a conduit, the fluid comprising hydrocarbons, the method comprising the steps of: (a) measuring optical variances resulting from at least one circumferential mode of vibration of the conduit by directing a monochromatic light source, such as from a vibrometer, onto an external surface of the conduit thereby providing a measured vibration of the conduit as a result of fluid flow in the conduit. The data normally accurately measures velocity of the conduit usually considered to be wideband noise. Accordingly, sample rates are high, such as at least 5,000 times per second. The data is then assessed, for example by using a Fourier Transform, and a pre-trained algorithm to predict fluid flow at that point in the conduit, or upstream or downstream thereof. An associated apparatus is also disclosed. Embodiments of the invention can thus provide a non-invasive method and apparatus for providing information on the nature of flow regimes in pipelines, such as subsea pipelines which can be useful to optimise production and reduce well testing and/or downtime.

A drilling or work-over vessel (10) is disclosed comprising a number of operational equipment (300), wherein the drilling or work-over vessel comprises at least one operational control and/or state unit (100) comprising at least one processing unit (102), wherein the at least one operational control and/or state unit (100) comprises or are in connection with a memory and/or storage (103), and at least one sensor unit (200), wherein the at least one sensor unit (200) is adapted to obtain one or more measured physical values and to provide data representing the one or more measured physical values and/or derived values thereof to the at least one operational control and/or state unit (100), the memory and/or storage (103) comprises a data representation of a computational physics model of at least a part of the drilling or work-over rig, and the at least one processing unit (102) is adapted to derive data representing an estimation of one or more physical states (such as defined by limits of forces, relative motion between operational equipment and vessel, or between other two pieces of operational equipment) estimated to act on at least one operational equipment (300) in response to the data representing the one or more measured physical values and/or derived values thereof as provided by the at least one sensor unit (200).

A drilling or work-over vessel (10) is disclosed comprising a number of operational equipment (300), wherein the drilling or work-over vessel comprises at least one operational control and/or state unit (100) comprising at least one processing unit (102), wherein the at least one operational control and/or state unit (100) comprises or are in connection with a memory and/or storage (103), and at least one sensor unit (200), wherein the at least one sensor unit (200) is adapted to obtain one or more measured physical values and to provide data representing the one or more measured physical values and/or derived values thereof to the at least one operational control and/or state unit (100), the memory and/or storage (103) comprises a data representation of a computational physics model of at least a part of the drilling or work-over rig, and the at least one processing unit (102) is adapted to derive data representing an estimation of one or more physical states (such as defined by limits of forces, relative motion between operational equipment and vessel, or between other two pieces of operational equipment) estimated to act on at least one operational equipment (300) in response to the data representing the one or more measured physical values and/or derived values thereof as provided by the at least one sensor unit (200).