A device which: optically detects the presence of, measures the flow rate of, and identifies the characteristics of venting fugitive gas emissions. Specifically the device provides a spectral analysis of emission gas constituents; selective detection of the presence of venting hydrocarbons; measurement of venting emissions flow rates, the measurement of shut-in and flowing venting system pressures and the venting system temperatures. The flow rates are corrected, relative to the detection of the gas constituents and standard temperature and pressure (STP). These devices are configured to collect such data electronically and transmit via various telemetry systems, to a secure remote data network for reporting, access, evaluation, real-time monitoring and archiving as required.

A device which: optically detects the presence of, measures the flow rate of, and identifies the characteristics of venting fugitive gas emissions. Specifically the device provides a spectral analysis of emission gas constituents; selective detection of the presence of venting hydrocarbons; measurement of venting emissions flow rates, the measurement of shut-in and flowing venting system pressures and the venting system temperatures. The flow rates are corrected, relative to the detection of the gas constituents and standard temperature and pressure (STP). These devices are configured to collect such data electronically and transmit via various telemetry systems, to a secure remote data network for reporting, access, evaluation, real-time monitoring and archiving as required.

A method includes initiating, by a computer system, a shear ram closure in a central bore of a blow-out preventer stack in response to a determination by the computer system of a loss of well control event and a determination by the computer system, based on a measurement received by the computer system from a joint locator sensor, that a tubing joint is not present within the central bore of the blow-out preventer stack. A pipe ram closure is initiated in response to a determination by the computer system that the shear ram has not fully closed after a predetermined time period since the initiation of the shear closure sequence.

A method includes initiating, by a computer system, a shear ram closure in a central bore of a blow-out preventer stack in response to a determination by the computer system of a loss of well control event and a determination by the computer system, based on a measurement received by the computer system from a joint locator sensor, that a tubing joint is not present within the central bore of the blow-out preventer stack. A pipe ram closure is initiated in response to a determination by the computer system that the shear ram has not fully closed after a predetermined time period since the initiation of the shear closure sequence.

In an example method a system obtains first data regarding a first oil well, including one or more first thermal images of the oil well generated by one or more first thermal cameras. The system determines, using computerized neural network, a presence of a gas leak at one or more locations on the first oil well based on the first data. The one or more locations include at least one of a first location along a pipeline configured to convey gas to a flare area of the first oil well, or a second location at a rig floor of the first oil well. In response to determining the presence of the gas leak at the one or more locations, the system generates a notification indicating the presence of the gas leak at the one or more locations.

In an example method a system obtains first data regarding a first oil well, including one or more first thermal images of the oil well generated by one or more first thermal cameras. The system determines, using computerized neural network, a presence of a gas leak at one or more locations on the first oil well based on the first data. The one or more locations include at least one of a first location along a pipeline configured to convey gas to a flare area of the first oil well, or a second location at a rig floor of the first oil well. In response to determining the presence of the gas leak at the one or more locations, the system generates a notification indicating the presence of the gas leak at the one or more locations.

Apparatus for use in sensing temperature in a wellbore, comprising: tubing comprising a plurality of temperature sensor modules provided at locations along the inside of the tubing, said temperature sensor modules comprising temperature sensors provided at least in part by at least one semiconductor element having electrical properties that vary with temperature; an electrical network configured to electrically connect to the semiconductor elements to in use allow measuring of the respective electrical properties of the semiconductor elements to infer a thermal characteristic of the semiconductor element; and at least one control module electrically connected to multiple temperature sensor modules, via the electrical network, and configured to receive and process an electrical signal associated with the temperature sensor modules to enable inference of the temperature of the semiconductor elements and the environment to which the tubing is exposed at the location of that semiconductor element.

A partially dissolvable plug is to be deployed in a position in a wellbore formed in a subsurface formation. The partially dissolvable plug comprises a first portion comprising a dissolvable material that is to dissolve over time after exposure to a downhole ambient environment in the wellbore and a second portion comprising a non-dissolvable material that is to create a flow restriction as the flow of fluid passes through the partially dissolvable plug. The first portion is to prevent a flow of fluid from downhole to a surface of the wellbore until at least a portion of the dissolvable material is dissolved. A flow rate is to be determined based on a detected change in a downhole attribute that is to change in response to the flow of fluid passing through the partially dissolvable plug after at least a portion of the partially dissolvable plug is dissolved.

A partially dissolvable plug is to be deployed in a position in a wellbore formed in a subsurface formation. The partially dissolvable plug comprises a first portion comprising a dissolvable material that is to dissolve over time after exposure to a downhole ambient environment in the wellbore and a second portion comprising a non-dissolvable material that is to create a flow restriction as the flow of fluid passes through the partially dissolvable plug. The first portion is to prevent a flow of fluid from downhole to a surface of the wellbore until at least a portion of the dissolvable material is dissolved. A flow rate is to be determined based on a detected change in a downhole attribute that is to change in response to the flow of fluid passing through the partially dissolvable plug after at least a portion of the partially dissolvable plug is dissolved.

A method for remotely testing wellhead integrity of a well is disclosed. The method includes connecting valves and associated gauges of the well remotely to a supervisory control and data acquisition (SCADA) system, obtaining real time pressure and temperature readings through the SCADA system, detecting, using a thermal infrared camera installed at a wellhead tree and flow lines of the well, potential oil/gas leak, and determining, by the SCADA system and based at least on the real time pressure and temperature readings and a detection result of the thermal infrared camera, integrity of the valves.