Systems and methods for monitoring and / or managing emission properties

Abstract

There is described systems and methods for monitoring emissions properties, such as those from an oil and gas emission (e.g., flare, incinerator, enclosed combustor and / or gas leak). In some examples, the system comprises a data acquisition arrangement configured to acquire data relating to emission properties of a gas emission. The data acquisition arrangement may comprise at least a primary image capture device configured to be positioned relative to a gas emission, and configured to obtain primary image data from that gas emission. The system may be configured to receive and use primary image data, together with ancillary data relating to the gas emissions obtained by the data acquisition arrangement, in order to monitor properties of that gas emission. In some examples, the primary image data may comprise indirect measurement data of particular properties of a gas emission being monitored. That primary image data may be used together ancillary data comprising direct measurement data of particular properties of the gas emission being monitored. The system and method may use a model to monitor properties of the gas emission.

Description

[0001] SYSTEMS AND METHODS FOR MONITORING AND / OR MANAGING EMISSION PROPERTIES

[0002] TECHNICAL FIELD

[0003] There is described systems and methods for monitoring and / or managing emission properties, such as green house gas emissions and / or other potentially harmful emissions including pollutants, and / or combustion properties, and in particular monitoring emissions or the like at an oil and gas installation (e.g., at a well site, which may have flares, or the like, used to burn hydrocarbons, and / or leaks).

[0004] Some particular described examples relate to monitoring for the purposes or reporting and / or reducing significantly (or otherwise minimising) green house gas emissions, or harmful emissions, at oil and gas installations.

[0005] BACKGROUND

[0006] During production or other operations at an oil and installation, such as at a well site, unwanted hydrocarbons and other fluid products may be combusted in the atmosphere in order to dispose of those products. Dedicated burners, or so-called flare burners or otherwise incinerators, enclosed combustors, or the like, may be used in order to allow combustion / destruction of those fluids at site. The emissions from flares (including incinerators) are often released to atmosphere too (e.g., rather than being captured and stored). Further emissions may be released, for example, due to leaks or other gases not being combusted or otherwise destroyed.

[0007] There can be a desire to monitor green house gas emissions and / or other harmful emissions at site and / or to ensure that combustion / destruction occurs as efficiently as possible, or otherwise be able to ascertain the possible emissions at site (e.g., for reporting and / or management). It may be preferable, for example, to ensure that green house gases, such as methane, or other harmful gases such as hydrogen sulphide or nitrogen dioxide are not released or otherwise fully combusted (e.g., including destroyed) during flaring, or the like.

[0008] In some cases in particular, such as well test, the composition of the hydrocarbons being produced from a test well may be estimated, but otherwise unknown in advance. Further conditions of the well in questions may be unknown, such as permeability, pressure, etc., which may affect factors such as flow rates, fluid pressures, etc. Together, these factors can have an effect on the overall efficiency and effectiveness of any combustion or removal of any unwanted products at site. Further, environmental conditions at such sites may vary (e.g., from day to day; week to week; month to month; year to year), which can also affect combustion, and other conditions at an oil and gas installation. This is additionally true at permanent or semi-permanent sites, in which conditions can also vary and / or be unknown.

[0009] There is a desire to improve the way in which emissions are managed and / or monitored (and consequentially controlled and / or reported on) at oil and gas installations. In some cases, it may be desirable to improve the manner with which unwanted products are managed, and for example combusted / destroyed. It may be true, however, that for any such improvements to be made, any proposed solutions ideally should be easy to adopt, cost effective to use, and / or have a meaningful impact. In other words, marginal improvements for high cost implementations may not be adopted and implemented. That said, significant improvement, and even noticeable improvements, may be more likely to be adopted if the costs are reasonable and / or the adoption can occur without significant complication, and knock-on effect on operations at the site or elsewhere. Further, any solution must be adaptable to varying conditions, given that unknowns may vary over time and from well site to well site. As such, bespoke solutions may be less desirable, and solutions with wide applicability may be preferable. Further still, in some cases, it may be desirable to consider (and be able to monitor) emissions across an oil and gas installation site (or portion of it), rather than solely at a very targeted area of that installation so that a better assessment of potential green house gas emissions or the like may be managed.

[0010] There continues to be a need, therefore, for cost effective solutions that are easy to adopt and manage, and which result in managing (and controlling) undesirable emissions at an oil and gas installation (e.g., during burning of hydrocarbon products, or otherwise destruction of harmful products), particular of green house gases, including methane, carbon dioxide, nitrogen dioxide, etc., and / or hazardous gases or conditions, including hydrogen sulphide or the like.

[0011] SUMMARY

[0012] There are described systems and method for monitoring and / or managing emission properties (e.g., at an oil and gas installation).

[0013] The systems and methods described may help provide cost effective solutions that are easy to adopt and manage, and which result in monitored and / or reduced unwanted emissions at an oil and gas installation (e.g., during flaring of hydrocarbon products), particular of green house gases, including methane, carbon dioxide, nitrogen dioxide, etc., and / or hazardous gases or conditions.

[0014] In some described examples, the system may comprise a data acquisition arrangement configured to acquire data relating to emission properties of a gas emission. The data acquisition arrangement may comprise at least a primary image capture device configured to be positioned relative to a gas emission, and may be configured to obtain primary image data from that gas emission. The system may be configured to receive and use primary image data, together with ancillary data relating to the gas emissions obtained by the data acquisition arrangement, in order to monitor properties of that gas emission.

[0015] The primary image data may comprise indirect measurement data of particular properties of a gas emission being monitored. That primary image data may be used together ancillary data, e.g., comprising direct measurement data of particular properties of the gas emission being monitored.

[0016] The image capture device may be configured to obtain primary image data at a particular spectral band, such that the image data relates to indirect measurement of particular properties of a gas emission at that spectral band. The system may be configured to use that primary image data together ancillary spectral data associated with the gas emission to determine emission properties. That ancillary spectral data may comprise direct measurement data relating to particular properties of the gas emission being monitored.

[0017] The ancillary data may comprise one or more of: laser absorption spectroscopy data, differential absorption data, such as differential absorption LiDAR data; single photo counting data, such as time correlated single photo counting data. The ancillary data may comprises bi-spectral data and / or hyperspectral data comprising direct measurement data relating to particular properties of an emission being monitored.

[0018] The particular spectral band from the primary image data may be narrower than that of the different spectral bands in the ancillary spectral data.

[0019] The system may be configured such that the primary image capture device obtains primary image data comprising infrared spectral band. The system may be configured to use that infrared primary image data together with ancillary data comprising image data of one or more different spectral bands associated with the gas emission in order to monitor emission properties. The ancillary data may have been obtained from image data from a different image device, having observed the gas emission.

[0020] The ancillary data from the different image device may comprise direct measurement data usable to determine particular emissions. Examples may include uncombusted organic carbons and / or carbon dioxide. The system may be configured to correlate the ancillary data together with primary image data in order to determine or approximate particular emissions, e.g., using the primary image data.

[0021] The system may be configured to use additional or alternative ancillary data associated with the gas emission in order to determine properties of the gas emission. The further ancillary data may comprise environmental data and / or flow rate data.

[0022] The system may comprise at least a secondary image capture device. The primary image capture device may be configured to capture primary image data associated with a gas emission at a first orientation, and the secondary image device may be configured to capture (e.g., simultaneously) secondary image data associated with a gas emission at a second orientation. The first and second orientations may differ.

[0023] The system may be configured to determine a corresponding particular feature in both primary and secondary image data, and may be configured to use the identified feature to determine the orientation of the first and second image devices relative to that gas emission.

[0024] The system maybe configured to determine an approximate property, such as volume of a gas emission, from primary and secondary image data. The property (or volume) may be defined within a determined or approximated iso-region, such as an iso-surface, which may represent an a region of similar properties values within the primary and secondary image data.

[0025] Such an iso-region may be (i) a region representing similar temperature property values, determined or approximated to have the same or similar temperature within the image data; and / or (ii) a region representing similar emission property values, such as light intensity and / or light wavelength, determined or approximated to have the same or similar emission properties within the image data

[0026] The system may be configured to use a determined volume of a gas emission together with the ancillary data, such as ancillary data comprising environmental data and / or flow rate data associated with the gas emission, in order to determine properties of the gas emission.

[0027] The system may be configured to determine the orientation of the gas emission affected by environmental wind conditions from the primary and secondary image data. In some cases, the system may use the determined orientation together with primary and / or secondary image data in order to determine properties of the gas emission.

[0028] The system may be configured to determine the orientation of the gas emission affected by environmental wind conditions from ancillary data comprising remote vehicle image data, such as drone or satellite image data. The system may be configured to use the determined orientation together with primary and / or secondary image data in order to determine properties of the gas emission.

[0029] The system may be configured to determine or approximate gas emission properties from the primary image data, and to determine or approximate gas emission properties from the secondary image data. The system may be configured to (e.g., then) compare the determined / approximated properties from the primary image data together with the secondary image data in order to determine gas emission properties.

[0030] The first image capture device and second image capture device may be configured to communicate wirelessly,, e.g., and to use location-based signals in order to determine the relative position and / or orientation of the first and second image capture devices.

[0031] Both the first and second image capture devices may be fixed in relative position to one another, or one of the image capture devices may be movable relative to the other, such that at least one image capture device being provided with a remote vehicle, such as a drone or satellite.

[0032] The system may comprise a reference image capture device configured to obtain reference image data associated with the environmental conditions in proximity of a gas emission. The system may be configured to use the reference image data together with the primary image data associated with the gas emission in order to determine properties of the gas emission.

[0033] The system may comprise a reference emitter, configured to emit a reference signal receivable by the reference image capture device. The signal may be transmittable across an environmental region associated with a gas emission. The reference signal maybe of the same or similar wavelength to that receivable by the primary image capture device.

[0034] The system may be configured to use image data together with ancillary data comprising transmittance and / or absorption data associated a water curtain in order to determine emission properties of a gas emission. The system may be configured to determine one or more geometric measurements of a gas emission from image data, e.g., and to use the determined geometric measurement together with ancillary data, in order to monitor properties of that gas emission.

[0035] The system may be configured to determine an approximate volume of a gas emission from image data, e.g., the volume being determined from the determined geometric measurement.

[0036] The geometric measurement may be determined from an iso-region, such as an iso-surface or iso-contour, which may represent a region of similar properties values within image data.

[0037] The system may be configured to determine a distance from a particular point, such as an ignite point, of a gas emission to a determined iso-region, such as a temperature iso-region, in order to determine emission properties.

[0038] Monitored properties of a gas emission may include one or more of: combustion efficiency; destruction and removal efficiency; green house gas emission; methane emission.

[0039] The system may be configured to obtain image data comprising location data, recontructable in order to permit identification of the location of any gas emission (VR). The ancillary data may comprise one or more of environmental data and / or flow rate data. The gas emissions may comprise a flare, incinerator, etc., or a gas leak at an oil an gas installation.

[0040] The system may be further configured to use model data associated with a gas emission in order to monitor properties of that gas emission. The model data may be selectable based on the particular emission being monitored.

[0041] The system maybe configured to revise model data using primary image capture data and ancillary data.

[0042] The system may comprise a flow management arrangement, configured to positioned in line with a hydrocarbon flow, and upstream of a gas emission. The flow management arrangement may be configured to control introduction of a control fluid to that hydrocarbon flow flowing to the gas emission in order to control the emission properties.

[0043] The flow management arrangement may be configured to use fully or partially the flow of fluids in the hydrocarbon flow in order to control introduction of a control fluid to that hydrocarbon flow flowing to the gas emission in order to control the emission properties The flow management system may be configured to communicate ancillary data regarding a hydrocarbon flow to the data acquisition system for use together with image data in order to determine emission properties.

[0044] There is described also a system for monitoring emissions properties, comprising; a data acquisition arrangement configured to acquire data relating to emission properties of a gas emission, the data acquisition arrangement comprising at least an image capture device configured to be positioned relative to a gas emission, and configured to obtain direct measurement data relating to a particular property of that gas emission, and wherein the system is configured to receive and use image data, together with ancillary data relating to the gas emissions obtained by the data acquisition arrangement, in order to monitor properties of that gas emission.

[0045] The image capture device may be configured to obtain data comprises one or more of: laser absorption spectroscopy data, differential absorption data, such as differential absorption LiDAR data; single photo counting data, such as time correlated single photo counting data; bi-spectral data or hyperspectral data comprising direct measurement data relating to particular properties of an emission being monitored.

[0046] In some examples, there is described a data model (e.g., a data model structure) for monitor properties of that gas emission. The data model may comprise image data obtained from monitoring a gas emission. The data model may comprise ancillary data relating to the gas emissions. The data model may comprises instructions that, when executed by a system, determine properties of a gas emission using the image data and ancillary data in order to monitor properties of that gas emission

[0047] In some examples, there is described a method for monitoring and / or managing emissions properties, comprising; obtaining primary image data from a primary image capture device configured to be positioned relative to a gas emission. The method may comprise using the primary image data, together with ancillary data relating to the gas emissions, in order to monitor and / or manage properties of that gas emission.

[0048] The primary image data may comprise indirect measurement data of particular properties of a gas emission being monitored. The method may comprise using that primary image data together with ancillary data comprising direct measurement data of particular properties associated with the gas emission being monitored. The primary image data may have a particular spectral band, such that the image data relates to indirect measurement of particular properties of a gas emission at that spectral band, and wherein the primary image data may be used together ancillary spectral data associated with the gas emission to determine emission properties, that ancillary spectral data possibly comprising direct measurement data associated with particular properties of the gas emission being monitored.

[0049] The ancillary data may comprise one or more of: laser absorption spectroscopy data, differential absorption data, such as differential absorption LiDAR data; single photo counting data, such as time correlated single photo counting data. The ancillary data comprises bi- spectral data or hyperspectral data comprising direct measurement data relating to particular properties of an emission being monitored.

[0050] The particular spectral band from the primary image data may be narrower than that of the different spectral bands in the ancillary spectral data. The method may comprise obtaining primary image data comprising infrared spectral band, and wherein the method may use that infrared primary image data together with ancillary data comprising image data of one or more different spectral bands associated with the gas emission in order to monitor emission properties.

[0051] The method may comprise obtaining the ancillary data from image data from a different image device, having observed the gas emission. The ancillary data from the different image device may comprise direct measurement data usable to determine particular emissions, such as uncombusted organic carbons and / or carbon dioxide, and wherein the method correlates the ancillary data together with primary image data in order to determine or approximate particular emissions, using the primary image data.

[0052] The method may use further ancillary data associated with the gas emission in order to determine properties of the gas emission, and wherein the further ancillary data comprises environmental data and / or flow rate data.

[0053] The method may comprise obtaining primary image data associated with a gas emission at a first orientation, and obtaining secondary image data associated with a gas emission at a second orientation, and wherein the first and second orientations differ.

[0054] The method may comprise determining a corresponding particular feature in both primary and secondary image data, and using the identified feature to determine the orientation of first and second image devices from which the data is obtained, relative to that gas emission. The method may comprise determining an approximate volume of a gas emission from primary and secondary image data. Such a volume may be defined within a determined or approximated iso-region, such as an iso-surface, representing an a region of similar properties values within the primary and secondary image data.

[0055] The iso-region may be (i) a region representing similar temperature property values, determined or approximated to have the same or similar temperature within the image data; and / or (ii) a region representing similar emission property values, such as light intensity and / or light wavelength, determined or approximated to have the same or similar emission properties within the image data

[0056] The method may use the determined volume of a gas emission together with the ancillary data, such as ancillary data comprising environmental data and / or flow rate data associated with the gas emission, in order to determine properties of the gas emission.

[0057] The method may include determining the orientation of the gas emission affected by environmental wind conditions from the primary and secondary image data, e.g., and using the determined orientation together with primary and / or secondary image data in order to determine properties of the gas emission.

[0058] The method may comprise determining the orientation of the gas emission affected by environmental wind conditions from ancillary data comprising remote vehicle image data, such as drone or satellite image data, e.g., and using the determined orientation together with primary and / or secondary image data in order to determine properties of the gas emission.

[0059] The method may comprise determining or approximating gas emission properties from the primary image data. The method may comprise determining or approximating gas emission properties from the secondary image data. The method may comprise comparing the determined / approximated properties from the primary image data together with the secondary image data in order to determine gas emission properties.

[0060] The method may comprise using location-based signals to determine the relative position and / or orientation of first and second image capture devices, from which image data is obtained.

[0061] The image data may be provided from first and second image capture devices that are fixed in relative position to one another, or where one of the image capture devices is movable relative to the other, such as at least one image capture device being provided with a remote vehicle, such as a drone or satellite. The method may comprise obtaining reference image data associated with the environmental conditions in proximity of a gas emission. The method may use the reference image data together with the primary image data associated with the gas emission in order to determine properties of the gas emission.

[0062] The method may comprise emitting a reference signal receivable by the reference image capture device, and transmitting that signal across an environmental region associated with a gas emission. The reference signal may be of the same or similar wavelength to that receivable by the primary image capture device.

[0063] The method may use image data together with ancillary data comprising transmittance and / or absorption data associated a water curtain in order to determine emission properties of a gas emission.

[0064] The method may comprise determining one or more geometric measurements of a gas emission from image data, and using the determined geometric measurement together with ancillary data, in order to monitor properties of that gas emission.

[0065] The method may determine an approximate volume of a gas emission from image data, the volume being determined from the determined geometric measurement.. The geometric measurement may be determined from an iso-region, such as an iso-surface or iso-contour, which represents a region of similar properties values within image data.

[0066] The method may determine a distance from a particular point, such as an ignite point, of a gas emission to a determined iso-region, such as a temperature iso-region, in order to determine emission properties.

[0067] Monitored / managed properties of a gas emission may include one or more of: combustion efficiency; destruction and removal efficiency; green house gas emission; methane emission. Image data may comprise location data, recontructable in order to permit identification of the location of any gas emission (VR). The ancillary data may comprise one or more of environmental data and / or flow rate data. The gas emissions may comprise flares, incinerators, enclosed combustors, or a gas leak at an oil an gas installation.

[0068] The method may further use model data associated with a gas emission in order to monitor properties of that gas emission. The method may comprise selecting the model data based on the particular emission being monitored. The method may comprise revises model data using primary image capture data and ancillary data. The method may further comprise controlling introduction of a control fluid to hydrocarbon flow, upstream of a gas emission, and flowing to the gas emission in order to control the emission properties.

[0069] The method may comprising controlling by fully or partially using the flow of fluids in the hydrocarbon flow in order to control introduction of a control fluid to that hydrocarbon flow flowing to the gas emission in order to control the emission properties

[0070] Ancillary data regarding the hydrocarbon flow may be communicated for use together with image data in order to determine emission properties.

[0071] In some examples there is described a method for monitoring emissions properties, comprising; obtaining image data relating to emission properties of a gas emission, the image data having direct measurement data relating to a particular property of that gas emission. The method may comprise receiving and using the image data, together with ancillary data relating to the gas emissions, in order to monitor properties of that gas emission.

[0072] The image data may comprise one or more of: laser absorption spectroscopy data, differential absorption data, such as differential absorption LiDAR data; single photo counting data, such as time correlated single photo counting data; bi-spectral data or hyperspectral data comprising direct measurement data relating to particular properties of an emission being monitored.

[0073] In some described examples, particularly those that may be used to manage emissions, there is provided systems and method for managing emissions properties (e.g., at an oil and gas installation).

[0074] The systems and methods described may help provide cost effective solutions that are easy to adopt and manage, and which result in reduced unwanted emissions at an oil and gas installation (e.g., during flaring or otherwise burning of hydrocarbon products), particular of green house gases, including methane, carbon dioxide, nitrogen dioxide, etc., and / or hazardous gases or conditions.

[0075] In some described examples, the described system may comprise a flow management arrangement, which may be configured to positioned in line with a hydrocarbon flow. The arrangement may be configured to be upstream of a flare burner, or otherwise incinerator burner, or the like, used for burning hydrocarbon in the flow.

[0076] The flow management arrangement may be configured to control the introduction of a control fluid to that hydrocarbon flow flowing to the burner in order to control the emission properties at the combustion. For example, in some cases, the flow management arrangement may be configured to the use fully or partially the flow of fluids in the hydrocarbon flow to control introduction of a control fluid to that hydrocarbon flow flowing to the burner in order to control the emission properties at the combustion location.

[0077] In some examples, there is described a system comprising a data acquisition arrangement, configured to acquire data relating to fluids flowing in a hydrocarbon flow and / or emission properties at the combustion location. Such an arrangement may be used to permit the control of a described flow management arrangement, or other such arrangement.

[0078] The flow management arrangement may comprises one or more intake arrangements. Some or all intake arrangements may comprise a hydrocarbon flow inlet and control fluid inlet. The intake arrangements may comprise a mixing chamber for mixing hydrocarbon flow with control fluid. An flow outlet of the intake arrangement may be configured to outlet mixed hydrocarbon flow. Some or all intake arrangements may be configured to passively control induction of control fluid, using the flow of fluids in the hydrocarbon flow.

[0079] For example, in some cases, the flow management arrangement may comprise one or more jet pump arrangements.

[0080] Some or all intake arrangements may comprise one or more controllable valves. The controllable valves may be provided at one or more of: the hydrocarbon inlet; the control fluid inlet, and the outlet. The valves may be configured to control flow rates of fluids one or more of the inlets / outlets (e.g., restrict;, increase; open / close).

[0081] In any event, the flow management arrangement may be configured to control (e.g., passively) induction of control fluid, using the flow of fluids in the hydrocarbon flow.

[0082] The system may be configured to introduce oxidant, such as inducting air from atmosphere, to the hydrocarbon flow. The system may additionally or alternatively configured to introduce water into the hydrocarbon flow. The system may be configured to permit adjustable introduction of control fluid, such as introduction from atmosphere. Such adjustment may be based on determined and / or assumed conditions at site.

[0083] The system may comprise at least a first flow path and a second flow path. The first and second flow paths may be used to control introduction of control fluids to different extents. The system may be configured to allow selective flow of hydrocarbons through the first flow path, the second flow path, or a though combination of flow paths. The first flow path may be configured to introduce a control fluid to a hydrocarbon flow, and the second flow path may be configured substantially not to introduce control fluid. The first flow path may be configured to introduce control fluid to a hydrocarbon flow at a first particular extent, and the second flow path is configured to introduce control fluid at to second particular extent, wherein the first and second rates are selectively different.

[0084] The system may comprise more than two flow paths. Some or all flow path may be configured to control introduction of control fluids to different extents. At least one of the flow paths may be configured substantially not to introduce control fluid. The system may be configured such that some or all of the flow paths may be fluidly connected to a common source. In some examples, the system may be configured such that some or all the flow paths may be fluidly coupled to alternative sources (e.g., different wells, and / or different separator outlets).

[0085] The system may be configured such that some or all of the flow paths combine upstream of any burner. In some examples, the system may be configured such that some or all of the flow paths combine at the location of combustion, at a burner.

[0086] The flow management arrangement may be configured to control one or both of the flow rate of hydrocarbons and the introduction of control fluid to the hydrocarbon flow. The control of the flow rate of hydrocarbons may be controlled independently of the controlled introduction of control fluid to the hydrocarbon flow.

[0087] The flow management arrangement may be configured to be retrofittable to an existing well structure. The retrofittable flow management arrangement may be configured to be positioned downstream of well test equipment, and upstream of a burner. Any well test equipment upstream of the system may comprises one or more separators. The flow management system may be configured to be positioned downstream of any separators.

[0088] The flow management arrangement may be powered, e.g., at least in part, via the data acquisition arrangement, e.g., when used and in communication.

[0089] The data acquisition arrangement may be configured to acquire data relating to properties, such as emission properties, at the combustion location. For example, the data acquisition arrangement may be configured to acquire data using at least one image capture device. Data from the image capture device(s) may permit determination of one or more of properties of that burner. The one or more determined properties may includes one or more of: composition of emissions, such as the composition of green house gas emissions; temperature; combustion efficiencies; and destruction and removal efficiency. The data acquisition arrangement may be configured to acquire data relating to fluids flowing in the hydrocarbon flow. Such data may comprise one or more properties relating to the composition of fluids in the hydrocarbon flow.

[0090] The system may be configured to use predictive modelling to control introduction of a control fluid to the hydrocarbon flow. For example, any model may use data relating to fluids flowing in the hydrocarbon flow and / or emission properties at a combustion location (e.g., burner).

[0091] The flow management arrangement may be configured to introduce control fluid to that hydrocarbon flow at the burner during combustion, and / or the flow management arrangement may be configured to introduce control fluid into the hydrocarbon flow so as to be mixed with the flow upstream of the burner.

[0092] In some examples, there is described a method for managing emission properties (e.g., at an oil and gas installation).

[0093] Such examples may comprise positioned a flow management arrangement together with (e.g., in line with) a hydrocarbon flow. The arrangement may be provided upstream of a burner for burning hydrocarbons in the flow.

[0094] In some examples, the method may comprise acquiring data relating to fluids flowing in the hydrocarbon flow and / or combustion at the burner.

[0095] The method may comprise controlling introduction of a control fluid to the hydrocarbon flow flowing to the burner. For example, the method may comprise controlling introduction of a control fluid to the hydrocarbon flow flowing to the burner using fully or partially the flow of fluids in the hydrocarbon flow together with the acquired data in order to control the emission properties at the burner.

[0096] The method may comprise using one or more intake arrangements. Some or all intake arrangements may comprise a hydrocarbon flow inlet and control fluid inlet. The method may comprise mixing hydrocarbon flow with control fluid. The method may comprise outletting mixed hydrocarbon flow. The method may comprising passively controlling induction of control fluid, using the flow of fluids in the hydrocarbon flow.

[0097] The method may comprise using one or more jet pump arrangements and controlling introduction of control fluid using the flow of fluids in the hydrocarbon flow. The method may comprising controlling the fluid flow at one or more of: the hydrocarbon inlet; the control fluid inlet, and the outlet. Controlling may comprise controlling flow rates of fluids one or more of the inlets / outlets (e.g., restrict;, increase; open / close).

[0098] The method may include acquiring image data associated with combustion at the burner. Such data may be used to control introduction of a control fluid. Image data may be acquired at intervals. Controlled introduction of control fluid may be determined at or around those intervals. Example intervals include one of hourly, daily, weekly, monthly or yearly.

[0099] The method may comprise (e.g., using the flow management arrangement) flowing fluids along a first flow path and a second flow path. The first and second flow paths may passively control introduction of an control fluid to different extents. The method may comprise selecting one of the first flow path, the second flow path, of a combination of flow paths, to flow hydrocarbons through.

[0100] The method may comprise retrofitting the flow management arrangement upstream of a burner. The method may comprise retrofitting the flow management arrangement downstream of a well test equipment, such as downstream of a separator of well test equipment.

[0101] The method may comprise using the acquired data together with a predictive model to control controlling introduction of a control fluid to the hydrocarbon flow. The method comprising varying the introduction of a control fluid to the hydrocarbon flow over time. The method comprising managing emission properties for non-routine flaring.

[0102] The method may comprise introducing control fluid to the hydrocarbon flow at the burner during combustion, and / or introducing control fluid into the hydrocarbon flow so as to be mixed with the flow downstream of the burner.

[0103] In some examples, there is described a system for managing emission properties, comprising; a flow management arrangement, configured to positioned in line with a hydrocarbon flow, and upstream of a burner for burning hydrocarbon in the flow; wherein the flow management arrangement comprises one or more pumps configured to use the flow hydrocarbon flow to control introduction of a control fluid to the hydrocarbon flow flowing to the burner in order to control the combustion at the burner.

[0104] In some examples, there is described a system for managing emission properties, comprising; a data acquisition arrangement, configured to acquire data relating to emissions at an oil and gas installation, wherein the system is specifically configured to acquire data relating to emissions from a burner (e.g., flare incinerator, or the like), as well as leak emissions from components at an installation.

[0105] In some examples, there is described a method for managing green house gas emissions, comprising: acquiring data relating to emissions from a burner as well as leak emission from components at an oil and gas installation, and using that data to manage green house gas emissions (e.g., the data may be derived from image data). The method may comprise acquiring data relating to emissions from a non-routine burner (e.g., non-routine flare burner).

[0106] In some examples, there is described a method for managing emission properties, comprising; positioning a flow management arrangement in line with a hydrocarbon flow, and upstream of a burner for burning hydrocarbons in the flow; controlling introduction of a control fluid to the hydrocarbon flow flowing to the burner using fully or partially the flow of fluids in the hydrocarbon flow together with the acquired data in order to control the emission properties at the burner. The method may comprise controlling introduction of a control fluid to different extents across two or more flow paths. The method may comprise combining the flow paths at the location of combustion at the burner.

[0107] In some examples, there is described a system for managing emission properties, comprising; a flow management arrangement, configured to positioned in line with a hydrocarbon flow, and upstream of a burner for burning hydrocarbon in the flow; wherein the flow management arrangement is configured to control introduction of a control fluid to that hydrocarbon flow flowing to the burner in order to control the emission properties at the burner; a data acquisition arrangement, configured to acquire data relating to fluids flowing in the hydrocarbon flow and / or emission properties at the combustion location, and to permit the control of the fluid management system.

[0108] In some examples, there is described a method for managing emission properties, comprising; positioning a flow management arrangement in line with a hydrocarbon flow, and upstream of a burner for burning hydrocarbons in the flow; acquiring data relating to fluids flowing in the hydrocarbon flow and / or combustion at the combustion location; controlling introduction of a control fluid to the hydrocarbon flow flowing to the burner using the acquired data in order to control the emission properties at the combustion location.

[0109] The described examples provide systems and methods for controlling or reducing emissions, which are cost effective, and / or easy to adopt and manage, and which result in reduced unwanted emissions during flaring or otherwise combusting, release, etc., of hydrocarbon products. According to a particular example, there is provided a burner (e.g., incinerator, enclosed combustor) comprising: a combustion chamber having an effective volume within which combustion occurs, and a one or more (e.g., a plurality) of flow path inlets configured to introduce fluids to the combustion chamber, and wherein the burner is configured such that the relative position of the flow path inlets and / or the effective volume of the combustion chamber is adjustable (e.g., controllably adjustable) in order to manage / control emissions at the burner.

[0110] The burner may be usable with a system according to any of those described above, and may be configured to be controlled accordingly (e.g., by a flow management arrangement). The

[0111] Thee burner may be configured such that the location of the flow path inlets are controllable (e.g., controlling the location of entry of the flow paths to the burner relative to the geometry of the burner). This may include translating the flow path inlets along and / or around the burner geometry (e.g., movable along the height, and / or around a perimeter or otherwise circumference). This may be in addition to, or as an alternative to, controlling and being selective about the flow to a plurality of inlets / flow paths at the burner.

[0112] In some examples, the combustion chamber of the burner may comprise two or more (e.g., multiple) sections that move relative to another in order to control / adjust the effective volume. Those sections may be configured to slidably engage relative to one another in order to provide different effective volumes (to as to extend and contract to control volume of the chamber 810). The burner may comprise one or more slip joints.

[0113] In some examples, the burner may be additionally or alternatively configured such that the combustion chamber is translatable relative to the position of the flow path inlets (e.g., in particular the base region flow path inlet) in such a way that the effective volume (e.g., the volume within which combustion occurs) can be increased or decreased. This may occur as the combustion chamber is moved, relatively speaking up and down, with respect the flow path inlets.

[0114] In some examples, one, some or all the flow path inlets are fixed relative, and the combustion chamber is movable relative to those fixed inlets.

[0115] According to a particular example, there is method for controlling a burner (e.g., incinerator, enclosed combustor) comprising: controlling the relative position of flow path inlets and / or the effective volume of the combustion chamber of the burner, so as to manage / control emissions at the burner.

[0116] According to a particular example, there is provided a variable combustion location (e.g., incinerator, enclosed combustor). The combustion location may comprise a combustion chamber having an effective volume within which combustion occurs. The combustion location may comprise a one or more (e.g., a plurality) of flow path (e.g., inlets) configured to introduce fluids, such as hydrocarbons, to the combustion chamber. The combustion chamber is configured such that the relative position of the flow paths / inlets and / or the effective volume of the combustion chamber is adjustable (e.g., controllably adjustable) in order to manage / control emissions.

[0117] The burner / combustion location may be used together with a data acquisition arrangement and / or flow management arrangement as described herein.

[0118] Further examples, are given by the following numbered clauses.

[0119] 1. A system for managing emission properties, comprising; a flow management arrangement, configured to positioned in line with a hydrocarbon flow, and upstream of a burner for burning hydrocarbon in the flow; wherein the flow management arrangement is configured to use fully or partially the flow of fluids in the hydrocarbon flow to control introduction of a control fluid to that hydrocarbon flow flowing to the burner in order to control the emission properties at the burner; a data acquisition arrangement, configured to acquire data relating to fluids flowing in the hydrocarbon flow and / or emission properties at the burner, and to permit the control of the flow management system.

[0120] 2. The system according to numbered clause 1 , wherein the flow management arrangement comprises one or more intake arrangements comprising a hydrocarbon flow inlet, and control fluid inlet, a mixing chamber for mixing hydrocarbon flow with control fluid, and a flow outlet for outletting mixed hydrocarbon flow, and wherein the intake arrangement is configured to passively control induction of control fluid, using the flow of fluids in the hydrocarbon flow.

[0121] 3. The system according to numbered clause 1 or 2, wherein the system is configured to introduction oxidant, such as inducting air from atmosphere, to the hydrocarbon flow, and / or introduce water into the hydrocarbon flow. 4. The system according to any preceding numbered clause, wherein the system is configured to permit adjustable introduction of control fluid, such as introduction from atmosphere, based on determined or assumed conditions at site.

[0122] 5. The system according to any of the numbered clauses 1 to 4, wherein the system comprises at least a first flow path and a second flow path, wherein the first and second flow paths are used to control introduction of control fluids to different extents, and where the system is configured to allow selective flow of hydrocarbons through the first flow path, the second flow path, or a though combination of flow paths.

[0123] 6. The system according to numbered clause 5, wherein the first flow path is configured to introduce a control fluid to a hydrocarbon flow, and the second flow path is configured substantially not to introduce control fluid.

[0124] 7. The system according to numbered clause 5, wherein the first flow path is configured to introduce control fluid to a hydrocarbon flow at a first particular extent, and the second flow path is configured to introduce control fluid at to second particular extent, wherein the first and second rates are selectively different.

[0125] 8. The system according to any of the numbered clauses 5 to 7 comprising more than two flow paths, each flow path being configured to control introduction of control fluids to different extents, and wherein at least one of the flow paths is configured substantially not to introduce control fluid.

[0126] 9. The system according to any of the numbered clauses 5 to 8, wherein each of the flow paths are fluidly connected to a common source, or wherein each of the flow paths are fluidly coupled to alternative sources.

[0127] 10. The system according to any of the numbered clauses 5 to 9, wherein some or all of the flow paths combine upstream of any burner, or some or all of the flow paths combine at the location of combustion, at a burner.

[0128] 11. The system according to any preceding numbered clause, wherein the flow management arrangement is configured to control both the flow rate of hydrocarbons and the introduction of control fluid to the hydrocarbon flow.

[0129] 12. The system according to numbered clause 11 , wherein the control of the flow rate of hydrocarbons can be controlled independently of the controlled introduction of control fluid to the hydrocarbon flow. 13. The system according to any preceding numbered clause wherein the flow management arrangement is retrofittable to an existing well structure.

[0130] 14. The system according to numbered clause 13, wherein the retrofittable flow management arrangement is configured to be positioned down stream of well test equipment, and up stream of a burner (e.g., flare burner, incinerator, enclosed combustor, or the like).

[0131] 15. The system according to numbered clause 14, wherein any well test equipment upstream of the system comprises one or more separators, and the flow management system is configured to be positioned down stream of any separators.

[0132] 16. The system according to any of the preceding numbered clause wherein the flow management arrangement is powered, at least in part, via the data acquisition arrangement, when in communication.

[0133] 17. The system according to any of the preceding numbered clauses wherein the data acquisition arrangement is configured to acquire data relating to emission properties at a burner using at least one image capture device, and wherein data from the image capture device permits determination of one or more of properties of that burner.

[0134] 18. The system according to numbered clause 17, wherein the one or more determined properties includes one or more of: composition of emissions, such as the composition of green house gas emissions; temperature; combustion efficiencies; and destruction and removal efficiency

[0135] 19. The system according to any of the preceding numbered clauses wherein the data acquisition arrangement is configured to acquire data relating to fluids flowing in the hydrocarbon flow, and wherein the data comprises one or more properties relating to the composition of fluids in the hydrocarbon flow.

[0136] 20. The system according to any preceding numbered clause, wherein the system is configured to use predictive modelling to control introduction of a control fluid to the hydrocarbon flow, the model using data relating to fluids flowing in the hydrocarbon flow and / or emission properties at a combustion locations (e.g., flare, incinerator, or the like).

[0137] 21. The system according to any of the numbered clauses 1 to 20, wherein the flow management arrangement is configured to introduce control fluid to that hydrocarbon flow at the burner during combustion, and / or the flow management arrangement is configured to introduce control fluid into the hydrocarbon flow so as to be mixed with the flow downstream of the burner. 22. A method for managing emission properties, comprising; positioned a flow management arrangement in line with a hydrocarbon flow, and upstream of a burner (e.g., flare, incinerator) for burning hydrocarbons in the flow; acquiring data relating to fluids flowing in the hydrocarbon flow and / or combustion at the burner; controlling introduction of a control fluid to the hydrocarbon flow flowing to the burner using fully or partially the flow of fluids in the hydrocarbon flow together with the acquired data in order to control the emission properties at the burner.

[0138] 23. The method according to numbered clause 22, wherein the method comprising using one or more intake arrangements comprising a hydrocarbon flow inlet, and control fluid inlet, a mixing chamber for mixing hydrocarbon flow with control fluid, and a flow outlet for outletting mixed hydrocarbon flow, and wherein the method comprises controlling introduction of control fluid using the flow of fluids in the hydrocarbon flow.

[0139] 24. The method according to numbered clause 22 or 23, wherein the method includes acquiring image data associated with combustion at the burner, and wherein that data is used to control introduction of a control fluid.

[0140] 25. The method according to numbered clause 24, wherein the image data is acquired at intervals, and wherein controlled introduction of control fluid is determined at or around those intervals.

[0141] 26. The method according to numbered clause 25, wherein the intervals include one of hourly, daily, weekly, monthly or yearly.

[0142] 27. The method according to any of the numbered clause 22 to 26, wherein the flow management arrangement comprises at least a first flow path and a second flow path, wherein the first and second flow paths passively control introduction of an control fluid to different extents, and where the method comprises selecting one of the first flow path, the second flow path, of a combination of flow paths, to flow hydrocarbons through.

[0143] 28. The method according to any of the numbered clause 22 to 27, wherein the method comprises retrofitting the flow management arrangement upstream of a burner, and downstream of a separator of well test equipment. 29. The method according to any of the numbered clause 22 to 28, wherein the method comprise using the acquired data together with a predictive model to control controlling introduction of a control fluid to the hydrocarbon flow.

[0144] 30. The method according to numbered clause 29, wherein the method comprising varying the introduction of a control fluid to the hydrocarbon flow over time.

[0145] 31. The method according to any of the numbered clause 22 to 30, wherein the method comprising managing emission properties for non-routine flaring.

[0146] 32. The method according to any of the numbered clauses 22 to 31 , wherein the method comprising introducing control fluid to the hydrocarbon flow at the burner during combustion, and / or introducing control fluid into the hydrocarbon flow so as to be mixed with the flow downstream of the burner.

[0147] 33. A system for managing emission properties, comprising; a flow management arrangement, configured to positioned in line with a hydrocarbon flow, and upstream of a burner for burning hydrocarbon in the flow; wherein the flow management arrangement comprises one or more pumps configured to use the flow hydrocarbon flow to control introduction of a control fluid to the hydrocarbon flow flowing to the burner in order to control the combustion at the burner.

[0148] 34. A system for managing emission properties, comprising; a data acquisition arrangement, configured to acquire data relating to emissions at an oil and gas installation, wherein the system is specifically configured to acquire data relating to emissions from a burner as well as leak emissions from components at an installation.

[0149] 35. A method for managing green house gas emissions, comprising acquiring data relating to emissions from a burner as well as leak emission from components at an oil and gas installation, and using that data to manage green house gas emissions.

[0150] 36. The method according to numbered clause 35, wherein the data derived from image data.

[0151] 37. The method according to any of the numbered clause 35 or 36, wherein the method comprises acquiring data relating to emissions from a non-routine flare burner. 38. A method for managing emission properties, comprising; positioning a flow management arrangement in line with a hydrocarbon flow, and upstream of a burner for burning hydrocarbons in the flow; controlling introduction of a control fluid to the hydrocarbon flow flowing to the burner using fully or partially the flow of fluids in the hydrocarbon flow together with the acquired data in order to control the emission properties at the burner.

[0152] 39. The method according to numbered clause 38, wherein the method comprising controlling introduction of a control fluid to different extents across two or more flow paths.

[0153] 40. The method according to numbered clause 39, comprising combining the flow paths at the location of combustion at the burner.

[0154] 41. A system for managing emission properties, comprising; a flow management arrangement, configured to positioned in line with a hydrocarbon flow, and upstream of a burner for burning hydrocarbon in the flow; wherein the flow management arrangement is configured to control introduction of a control fluid to that hydrocarbon flow flowing to the burner in order to control the emission properties at the burner; a data acquisition arrangement, configured to acquire data relating to fluids flowing in the hydrocarbon flow and / or emission properties at the burner, and to permit the control of the fluid management system.

[0155] 42. A method for managing emission properties, comprising; positioning a flow management arrangement in line with a hydrocarbon flow, and upstream of a burner for burning hydrocarbons in the flow; acquiring data relating to fluids flowing in the hydrocarbon flow and / or combustion at the burner; controlling introduction of a control fluid to the hydrocarbon flow flowing to the burner using the acquired data in order to control the emission properties at the burner.

[0156] In some examples, there is described a computer program, such as a computer program product, comprising instructions that, when executed on a system, are configured to provide the method. The program may be a non-transitory computer program product, provided on a computer readable medium, and comprising instructions that, when executed on a system, are configured to provide the any of the described methods.

[0157] The above summary is intended to be merely exemplary and non-limiting, and features may be combined across example as would be understood to a skilled reader without the need to describe in detail those further examples.

[0158] BRIEF DESCRIPTION OF THE FIGURES

[0159] Figure 1 shows an example setup of well test equipment and a combustion location / burner (e.g., flare stack);

[0160] Figure 2 shows an example of the set up of Figure 1 , comprising a system for managing and / or monitoring emission properties;

[0161] Figures 3a and 3b show an example of a system similar to Figure 2 comprising primary image capture devices;

[0162] Figures 4a and 4b show spectral plots from image capture devices;

[0163] Figure 5a and 5b show modelling and calculating (or estimating) emission properties;

[0164] Figure 6a and 6b shows an example of a system comprising primary and secondary image capture devices, and Figure 6c shows example images; and

[0165] Figures 7a and 7b show examples of a system comprising reference image capture device, and Figure 7c shows an example of image capture devices with an incinerator;

[0166] Figures 8a-8d show flow management arrangements used with the system of Figure 2, and Figure 9 shows a intake arrangement, such as a jet pump, used with the flow management arrangement of Figure 8a-8d;

[0167] Figures 10a and 10b show further examples of a flow management arrangement;

[0168] Figure 11 shows the flow management arrangement of Figure 8a-8d together with a data acquisition arrangement;

[0169] Figures 12a-12e shows examples system / flow management arrangement together with an incinerator;

[0170] Figure 13 shows parameters and / or data acquired from the data acquisition arrangement of Figure 11 ;

[0171] Figure 14 shows an example of managing emissions from multiple flares / burners; and

[0172] Figure 15 shows a further example of the system at an oil and gas installation.

[0173] DETAILED DESCRIPTION

[0174] Figure 1 shows a simplified representation of an oil and gas installation, which in this case is a well site 10, and in particular a well test site. Well test equipment 20 has been deployed at the site 10, and ongoing testing activity is being performed at a well (not shown). In this example, the site 10 may be considered to conduct non-routine flaring, or otherwise combusting of hydrocarbons at a particular location. Non-routine flaring may be distinct in some cases from routine flaring, in which the flaring may be considering permanent and perpetual.

[0175] It will be appreciated that in such circumstances, fluids including hydrocarbons (and often other constituents) may be produced during well test in order to appraise a well in development. Those hydrocarbons, and other constituents, may be flowed from a well, via specific well test equipment 20, to a particular combustion location or otherwise burner 40 (for ease shown as comprising a flare burner in Figure 1 , but could comprise - additionally or alternatively - one or more incinerators, enclosed combustor, or the like). The burner 40 is used to combust (which may include destruct) hydrocarbons and other constituents during well test. The composition of the hydrocarbons and other fluids that may flow through a conduit or other such hydrocarbon flow 30 to the burner 40 may be approximated, but otherwise unknown, prior to well test. In some cases, those fluids may be combusted / destroyed or otherwise vented together, but in other examples the well test equipment 20 (e.g., including separators) may be used to separate out consistent fluids (e.g., oils and gases) to allow selective burning / removal / destruction of those separated fluids (e.g., selective burning of gas).

[0176] A skilled reader will appreciate that the following described examples may be suitable for either scenario, and can be modified as needed. That is to say that the following examples are not described specifically in relation to use with separated gases and oils (which then may be combusted separately), or multiphase or mixed flow of gases and oils, which are not separated, but are combusted / destroyed together. The following examples may be adapted to either scenario, and need not be limited to one or the other. Further, it will be appreciated that in some examples, flow lines (gas and / or oil) from multiple wells may be combined and combusted, etc. (e.g., multiple wells flowing to a single burner), and again the following examples may be adapted accordingly.

[0177] It will be appreciated that well test can often occur in challenging and varying environmental conditions. Further, the potentially unknown (and potentially varying) properties of fluids being produced from a well under test means that combustion / destruction at the burner 40 may be non-ideal, and harmful emissions such as green house gases, e.g., methane, hydrogen sulphide, or the like, may be released to atmosphere, and in some cases without being fully combusted (even when enclosed, e.g., an exhausted to atmosphere). Other harmful emissions such as such as nitrogen dioxide, or the like, may also be produced. Further, capture and storage of such gases may be problematic should gases such as methane, or hydrogen sulphide remain, given the volatility or lethality of those products. As such, there may be a desire to minimise or avoid certain emissions, such as green house gas emissions, such as methane, nitrogen dioxide, and / or other gases such as hydrogen sulphide, in such circumstances. In particular, there may be a desire to minimise such emissions cost effectively and / or with ease. There may also be a desire to be able to assess (e.g., for reporting purposes) the effective emissions, such as green house gas emission, and any reductions that have been made (and / or improvements that could be made), as well as other properties such as combustion efficiency, destruction and removal efficiency (DRE), or the like.

[0178] It will be appreciated that while the following examples have been described in relation to well test, in other examples the same or similar systems and methods may be used for with alternative permanent or semi-permanent well site arrangements, or indeed other oil and gas installations, and the embodiments need not be limited to well test arrangements. Further, while the examples may be particularly useful for non-routine flaring due to the possibility for varying conditions, nevertheless the systems and methods may be used with routing flaring.

[0179] While in the following examples, reference may be made specifically to combustion of particular products, it will readily be appreciated that in some examples this may include - or otherwise relate to - the effective destruction / removal of particular constituents from those products (e.g., destruction / removal of hydrogen sulphide, or the like). In some examples, combustion may also include cold venting (e.g., from time to time, when considered appropriate to do so, based on conditions at the well).

[0180] Further still, while the following examples have been described primarily in relation to a combustion, such as flaring, incineration, enclosed combustion, or other burning events of a gas emission to be monitored / managed (e.g., measuring emissions as a result of combustion, and / or specifics of a flare structure itself, and / or properties of equipment, such as shape, temperature, colour, etc.), it will readily be appreciated that the systems and method may equally be used with leaks, or other such gas or fluid emissions. In either case, it will be appreciated that management and / or monitoring may include direct measurement of a leak, or burner (e.g., flare), but may additionally or alternatively include indirect measurement (e.g., when measuring, for example, temperatures at apparatus associated with the combustion location, or leak location. Some examples of indirect measurement may include measurement / imaging of the temperature at, or across, features of an incinerator, or at or across leaking pipework (e.g., due to Joule-Thomson effects, or the like). A skilled reader will readily be able to implement those alternatives accordingly. Consider now Figure 2, which shows a system 100 for monitoring / managing emission properties, e.g. at a well site 10, which in this example is undergoing well test, and may use non-routine flaring to dispose of hydrocarbons or the like (other examples may use different methods of combusting the hydrocarbons). Non routine flaring may be used when flaring is not expected to be a permanent solution, and / or where flaring is used only from time to time.

[0181] The system 100 comprises a data acquisition arrangement 120. In this particular example, the data acquisition arrangement 120 may be considered to be portable - in that is can be relocated to alternative sites or locations. For example, the data acquisition arrangement 120 may not be physically connected (or permanently physically connected) at site.

[0182] By way of an example only, the system 100 in Figure 2 also comprises a flow management arrangement 110, which here is shown in communication with the data acquisition arrangement 120. The flow management arrangement 110 can be considered to obtain data relating the flow of hydrocarbons. Further examples of the flow managements arrangements 110 that may be used together with the exemplary data acquisition arrangement 120, or otherwise used independently, are shown and described in relation to Figures 8-14. In the following examples, such flow management arrangement 110 may additionally control the flow.

[0183] For example, the flow management arrangement 110 may be configured to be positioned together with the flow 30 (e.g., in line with the hydrocarbon flow 30), and upstream of a combustion location, e.g., burner 40 for burning hydrocarbons in the flow, which is exemplified here with a flare 40. Here, the flow management arrangement 110 is also positioned downstream of any well test equipment 20, e.g., any separators or other such well test equipment 20. In some cases, the flow management arrangement 110 may be retrofit to the hydrocarbon flow path 30, or at least installed together with expected flow tubing or the like that may be used to fluidly couple the well test equipment 20 to the burner 40. In that way, the system 100 and / or flow management arrangement 110 may be configured to be agnostic to the existing well set-up and well test equipment 20, which may provide a cost effective solution to allow the system 100 to operate at site with various different equipment and apparatus. In any event, the flow management arrangement 110 can be specifically configured such that hydrocarbons flow through the arrangement 110 from the well test equipment 20 to the burner 40. In some examples, certain features of the flow management arrangement 110 may be positioned at the combustion location, or indeed downstream of the (main) combustion location. This may occur in examples in which the flow management arrangement 110 may be configured to control gas flow, or the like, at the burner 40, as will be appreciated from the following examples. Further, it will be appreciated that the flow management arrangement 110 may be mechanically and fluidly connected to tubing or pipework that exists, e.g., that has been installed at the site 10 previously. In some cases, the flow management arrangement 110 may be formed generally as a pipe joint section or the like, so that it can be readily fitted to a existing section of the hydrocarbon flow 30, e.g., by removing and replacing an existing section of pipe work.

[0184] In some examples, the flow management arrangement 110 may be specifically configured to control intake (e.g., introduction, and in this particular example, induction) of a control fluid into the hydrocarbon flow, which flows along the flow path 30 to the burner 40. That control fluid may be used to modify or otherwise control combustion properties of the hydrocarbon flow. In other words, the control fluid may be used (or introduced accordingly) in order to manage combustion / destruction at the burner 40. In some examples, the control fluid may comprise fluids usable to increase the combustion or otherwise destruction of particular constituents of the hydrocarbon flow, such as oxidants (e.g., air comprising oxygen, and in some cases water). In some examples, the control fluid may comprise fluids usable to decrease the combustion of the hydrocarbon flow (e.g., water, cardon dioxide, potassium, or other such retardants).

[0185] Further, in this particular example, the flow management arrangement 110 may be configured to mix control fluid with hydrocarbon fluids. Here, such mixing is provided in a manner upstream of the burner 40. Such control may provide adjustment and control of the combustion properties at the burner 40. In this particular example, the flow management arrangement 110 is specifically configured to use (e.g., fully or partially) the flow of fluids in the hydrocarbon flow to assist with introduction (e.g. induction) of a control fluid into that hydrocarbon flow flowing to the burner 40, in order to control the combustion properties at the combustion location / burner 40. In other similar words, the flow management arrangement 110 may be considered to be able to operate passively in so far as energy from the flow itself can be used to power the arrangement 110, and provide for introduction (e.g., induction) of any control fluid. In that way, the arrangement can, for example, be easily deployed at site without the need for additional power.

[0186] In this particular example however, as will be described, the motive force (or otherwise flow) of the hydrocarbon flow itself effectively powers fully the arrangement 110 and causes introduction (e.g., induction) of control fluids into the flow. Here, the arrangement 110 comprises an intake arrangement 130 configured to introduce a control fluid into hydrocarbon flow using the fluids flowing in the hydrocarbon flow, e.g., based on Venturi principles. While in this example, the motive force (or otherwise flow) of the hydrocarbon flow itself may effectively power the intake arrangement 130 and cause the introduction or induction of control fluid (e.g., oxidant), it will be appreciated that in other examples, alternative (or additional) means may be used to assist with induction of a control fluid. For example, power derived from the flow may be used alternatively or additionally to introduce (e.g., pump) control fluid to the hydrocarbon flow. In such ways, introduction of control fluid may be considered to be actively introduced (e.g., rather than passive). One such example may comprise used powering a particular intake arrangement (e.g., from battery, or other local power supply). In some examples, energy may be extracted from the flow itself using one or more turbine arrangements, positioning within the flow, which may then be utilised to power a particular intake arrangement 130 (e.g., comprising a powered pump). In that event, the flow may be fully or partially used to introduce control fluid. In some further examples, power derived not from the flow may be used to supplement power from the flow (e.g., an auxiliary power source may additionally or alternatively be used).

[0187] Here, the data acquisition arrangement 120 is configured to be in communication with the flow management arrangement 110 and configured to communicate data or otherwise information with the flow management arrangement 110. The data acquisition arrangement 120 may also store data and / or communicate data (e.g., reporting data) offsite. It will be appreciated that any communication may be wired or wireless, or combination thereof.

[0188] It will also be appreciated that the data acquisition arrangement 120 may additionally or alternatively be configured to output data or information, e.g., data readily usable by the flow management arrangement 110 (e.g., rather that being in communication directly). For example, the data acquisition arrangement 120 may be additionally or alternatively configured to output specific instructions or reporting (e.g., at a user interface associated with the data acquisition arrangement 120) or other information to permit monitoring of gas emissions, and / or indeed control of the flow management arrangement 110 such that an operator or the like may then control the flow management arrangement 110. (e.g., control intakes, or shut off flow in the event of sulphur dioxide emissions).

[0189] Further still, in some examples, the data acquisition arrangement 120 (or indeed some other additional power supply of the system 100), may be configured to communicate power with the flow management system 110. In some of those examples, the flow management arrangement 110 itself may be unpowered, e.g., not have its own power supply. Power communicated to the flow management arrangement 110 (e.g., from time to time) may be usable to adjust the functionality of the system 100 / flow management arrangement 110, without the need for ongoing power. In that way, the flow management arrangement 110 may be unpowered (or essentially unpowered) when in use at site 10. Of course, it will readily be appreciated that in other examples, the flow management arrangement 110 may not need to receive power from an external source (e.g., is configured to operate passively or otherwise be fully powered itself), or indeed may comprise its own dedicated power supply (e.g., PV cells, and energy storage device) for fully or partially powering the arrangement 110.

[0190] In any event, the data acquisition arrangement 120 may be configured to acquire data relating to one or more of: fluids or materials flowing in the hydrocarbon flow (e.g., when a flow management arrangement 110 is used); emission properties, such as combustion at the flare; and / or environmental conditions, etc. For example, the data acquisition arrangement 120 may be configured to measure or obtain flow rates, measure or obtain fluid compositions or the like, (e.g., which may be at one or both of an upstream location and downstream location in the flow path 30, relative to the flow management arrangement 110, such as by using strap- on sensors). Additionally or alternatively, the data acquisition arrangement 120 may be configured to measure otherwise acquire environmental data, such as temperatures, wind speeds, RH, etc. Those data, including flow data, may be acquired at site, and / or via communication from further apparatus, e.g., via cellular or other network connectivity (not shown). Some or all data may be acquired in real time.

[0191] It will be appreciated that the data acquisition arrangement 120 may comprise dedicated hardware, that includes firmware and software (e.g., memory and processors, for example, configured using application specific integrated circuits, programmable logic controllers, or the like), and may comprise a plurality of input / outputs and sensor units as needed, configured to communicate data to / from the hardware in order to perform functions. The data acquisition arrangement 120 may comprise a user interface, which may comprise a display (e.g., and input device, such as a touchscreen). A skilled reader will readily be able to implement such arrangements, as appropriate.

[0192] Turning now specifically to the data acquisition arrangement 120 in Figure 2, in this particular example, the arrangement 120 comprises an image capture device 125 (e.g., a camera arrangement), which may be considered to be primary image capture device specifically configured to acquire primary image data relating to emission properties, and in this case combustion / destruction at the burner 40. In some examples, the primary image capture device 125 is configured to obtain an image of the flare itself being combusted and, from that data, particular information such as temperature, gas composition, etc., which can be determined by the data acquisition arrangement 120. In other examples, the image capture 125 may be configured to obtain images of one or more features of an incinerator, or other apparatus associated with an combustion location (and again particular information such as temperature, gas composition, etc., may can be determined by the data acquisition arrangement 120). In either case, observing the temperature, intensity and / or wavelength emissions (e.g., brightness and / or colour) of a particular flare, or radiation from an incinerator, or the like, may then be correlated that with particular combustion / destruction properties. In some examples, the image capture device 125 is configured to determine at least spectral data (e.g., from a flare or the like), across one or more wavelength bands. That spectral data may be considered to be hyperspectral data, and may provide data across the visible wavelengths and / or other wavelengths (e.g., ultraviolet and / or infrared wavelengths), or at least high resolution spectral data at particular wavelengths known to be associated with particular emissions. That emission data / information, and optionally other data / information acquired regarding flow rate, temperatures, etc., if used, may be provided in order to assess the emission properties, such as combustion, at the burner. In some cases, that information may be used to control or otherwise operate the flow management arrangement 110, and / or otherwise report or record emission properties. For examples, particular wavelengths may indicate (e.g., directly and / or indirectly) the completeness of combustion, which may optionally be used together with temperature (e.g., environmental and / or combustion location), and optionally other factors, such as relative humidity, to assess the emissions (e.g., completeness of combustion, likelihood of harmful emissions, etc.), and any improvement that may be possible.

[0193] Consider now Figure 3a, which shows a further example of the system 200 for monitoring / managing emissions properties. Here, the system 200 comprises a data acquisition arrangement 220 in a similar manner to that described in Figure 2. The system 200 may (or may not) comprise a flow management arrangement 110 as shown in Figure 2, but is nevertheless not shown here for ease. Any such flow management arrangement 110 if present may be controllable, however, using data from the data acquisition arrangement 220, and / or may communicate data with the data acquisition arrangement 220 (e.g., flow rate data, composition data, introduced control fluid data, or the like). This may assist when managing the emission properties.

[0194] Here, the data acquisition arrangement 220 is configured to acquire data relating to emission properties of a gas emission, e.g., a flare 40 in the example shown. It will be appreciated that the same or similar system 200 may monitor incinerators, enclosed combustors, gas leaks, or indeed other fluid emissions, and equally be usable to allow for monitoring of emissions, combustion efficiency, destruction and removal efficiency, etc., accordingly, as will be described. A skilled reader will readily be able to adapt the following embodiments. The data acquisition arrangement 220 comprises at least a primary image capture device 225 configured to be positioned relative to a gas emission, e.g., flare 40, and configured to obtain primary image data from that gas emission, e.g., flare 40. In this example, the system 200 is configured to receive and use primary image data, together with ancillary data relating to the gas emission obtained or provided by the data acquisition arrangement 220, in order to monitor properties of that gas emission 40.

[0195] As will be described, such ancillary data may include, for example, environmental data (e.g., wind speed, temperature, relative humidity, or the like), and / or may include flow data (e.g., flow rates, compositions, fractions or cuts, control fluid intake, etc.), and / or further data such as ancillary image data, or the like. Ancillary data may include well parameters, such as formation data (e.g., formation structure, porosity, permeability). The ancillary data may include well test data, including data relating to well test equipment, such as separator fractions or the like. Such data, together, may allow for particularly help modelling / predicting, and so monitoring, of emissions. The data acquisition arrangement 220 may be configured to monitor emission properties so as to determine or estimate combustion efficiency; destruction and removal efficiency; green house gas emission; methane emission, or other emissions, including pollutants, such as PM2.5, ozone, nitrogen oxide, benzo(a) pyrene, or the like. In some examples, monitoring data may be used for reporting purposes, and / or may be used to control the flow using the flow management arrangement so as to modify / manage the emissions (e.g., controlling introduction of control fluids, such as oxidants (e.g., air) and / or water into the flow in order to control flow and emissions).

[0196] In monitoring (or otherwise managing) the emissions, it will be appreciated that any burner 40 (and / or other gas leak, or fluid emission) may emit broadband emissions of electromagnetic radiation. That is to say that any such gas emissions may themselves also emit electromagnetic energies at a wide range of wavelengths, or indeed associated apparatus may emit radiation (e.g., incinerator surface). In some cases, such emissions may primarily be at the infrared, ultraviolet and / or visible wavelengths, but in other cases emissions may include radiation beyond those wavelengths, particularly when combusting hydrocarbons in atmosphere. Spectral data in any image data that can be obtained across the various spectra bands may help identify or determine properties of any particular gas emissions. For example, the presence of particular gases or composition is the emission may be apparent from spectral data (e.g., presence and / or absorption).

[0197] In some cases, direct measurement data may be obtained using high resolution spectral data (e.g., bi-spectral or hyperspectral imagining) to directly measure specific properties of an emission (e.g., directly seek to observe an identify a particularly constituent, component or effect, as explained above). Such imaging may be high resolution in terms of pixel densities and / or across a range of spectra wavelengths. That imaging may be able to obtain data across a range of spectra wavelengths and / or at significantly granular wavelengths (e.g. high spectral resolution) such that a direct measurement of particular properties of the emission may be possible. Information determinable from such spectral data may be usable to monitor emissions. For example, training a hyperspectral image device on a burner 40, or the like, and measuring the spectral data across a range of particular wavelengths may permit direct identification and classification of particular emissions, such as carbon dioxide, methane, nitrogen dioxide, sulphur dioxide, and other compositions, given that the presence or absence of those material may provide particular signatures in any spectral data (e.g., at or around the burner), which can be used to determine or estimate the presence and extent of such compositions or materials. Specific spectral data, such as that from a bi-spectral device, may directly measure two compositions / emissions, such as methane and CO2.

[0198] In some cases, the spectral intensity and / or spectral profile across particular spectral bands may relate (e.g., directly) to the emission of one or more compositions at a burner, for example. Monitoring that spectral band, using image data, may then allow for determination of emissions. In other cases, determining the spectral profile across a wide band of spectral data may be used to determine the overall composition of many properties at a burner 40 in a similar manner. Further, in other cases, direct measurement data may be provided additionally or alternatively using laser absorption spectroscopy data, differential absorption data, such as differential absorption LiDAR data, single photo counting data, such as time correlated single photo counting data, or the like.

[0199] That said, in any case, hardware and / or computation analysis of significant data, such as hyperspectral data, or scanning data from single photo counting, can be expensive and / or time consuming. In those cases, it can be helpful to implement methods and systems to reduce costs and / or complexity of determining emission properties. This may be particularly helpful when controlling a flow management arrangement 110 (and particularly when any flow composition may be variable such as flow well test), to ensure that control of the flow, and so the emissions, is appropriately prompt (e.g., in real time).

[0200] Consider now again Figure 3a. For the purposes of this example, the primary imaging device 225 can be considered to be a hyperspectral imaging device, although it may use other direct measurement techniques. In any event, in this case the primary imaging device 225 is able to obtain spectral data across many particular wavelengths and with many pixels and with significant resolution. The spectral bands may include wavelengths from or within 10'2m to 10'8m (e.g., microwave to ultraviolet), and may include spectral bands of visible light and infrared. Determining emission properties of the burner 40 may ordinarily require analysis of significant data from the spectral image data over time. In the system 200 of Figure 3a, however, the system 200 (and in particular the data acquisition arrangement 220), is configured to use primary image data together ancillary data associated with the gas emission to determine emission properties. Here, that ancillary data may include, for example, environmental data (e.g., temperature, wind speed / direction, and / or RH, etc.) and / or flow data (e.g., flow rate, flow composition, etc.). The system 200 may be configured to use the ancillary data to then selectively analyse particular data (e.g., particular spectral bands within the image data) in order to efficiently determine properties of the gas emission, or otherwise to predict emissions in order to resolve composition analysis.

[0201] For example, by determining that the flow composition was primarily non-sulphurous gas (rather than oil), at a particular flow rate, then only particular selected spectral bands from the imaging device 225 may be processed by the system 200 in order to determine properties of the gas emission. Likewise, if the flow or environmental conditions changes such that different emissions were predicted, expected or measured, then the system 200 may selectively process an alternative (e.g., more, or indeed less) spectral data band from the image data in order to determine properties of the gas emission. The system 200 may be configured to vary (e.g., continually vary) the spectral measurements based on ancillary data relating to the environment and / or flow. For example, in some cases, if the data acquisition arrangement 120 observes, or is provided data, that indicates or confirms that hydrogen sulphide is present in the hydrocarbon flow (e.g., which may happen intermittently), then the system 200 may configure the image capture device 125 to specifically be able to identify hydrogen sulphide and / or indeed sulphur dioxide at the emission.

[0202] In this and other similar ways, the system 200 may be adaptive to different (e.g., continually changing) conditions in order to optimise processing of image data. The system 200 is able to accurately monitor and control emissions. For example, the accurate detection of a residual of hydrogen sulphide in those cases, may then cause the system 200 to control a flow management arrangement 110 as described in order to fully destroy any remaining hydrogen sulphide. Similar adaptive arrangements may be employed to monitor and manage, for example, methane emissions, nitrogen dioxide emission, etc.

[0203] It will be appreciated that in some cases, look up tables, models or other databases of expected emissions based on particular flow / environmental conditions may be stored on a database 222 to allow the system 200 to selectively choose particular spectral bands or other image data based on that ancillary data. Those models may be developed from previous data, obtained at site (or at a remote location, such as a laboratory). In some cases, the models are developed using machine learning of the data collected at site (as training data). In any event, in such a way, quick, efficient and / or adaptive measuring (and optional management) gas emissions may be performed. Such a system 200 may be able to adapt to different conditions, efficiently and effectively. Further, feedback control of any flow management arrangement 110 may happen quick and effectively. For example, if emissions comprising harmful emissions are identified as exemplified above, then the system 200 may be configured to selectively monitor the emissions for the particular composition and control the flow management arrangement 110 until such emissions are reduced or eliminated. This may be particularly useful in examples where a well remains under test, and the flow constituents may still vary from time to time.

[0204] As will be appreciated, however, in some cases the continual use of a measurement device, such as a hyperspectral imaging device (or laser absorption spectroscopy device, differential absorption LiDAR device, or single photo counting device) as a primary imaging device 225 (and the processing requirements) may be cost and / or time prohibitive for ongoing monitoring (e.g., in direct monitoring of a burner, for example). In such cases, it may be helpful to use an alternative imaging device instead of, or alongside, such devices.

[0205] Consider now Figure 3b which shows an example the system 200 in which the primary image capture device 225 is configured to obtain primary image data comprising indirect measurement data of particular properties of a gas emission being monitored. That primary image data is used together ancillary data, e.g., comprising direct measurement data of particular properties of the gas emission being monitored, as will be described.

[0206] In this context, by comparison, direct measurement may be considered to mean that the unknown property to be obtained or estimated can be derived directly from the measurement itself (e.g., a measurement of property of a material that directly relates to temperature, in order to measure the temperature, or wavelength absorption that directly relates to the presence of absence of a compound). This could be contrasted with an indirect measurement in which the property to be discovered is not directly obtainable (or ordinarily obtainable) from the measurement itself. For example, this may be measuring a property associated with pressure, to determine pressure and then using that measured pressure to determine temperature (e.g., using additional data, such as volume, with the pressure, to then obtain, estimate or guess the temperature). Similarly, an direct measurement may include determine the presence of methane by using a methane detector, whereas an indirect measurement may comprise measuring temperature (e.g., using the primage image device) and, from that temperature, concluding the likely presence of absence of methane (e.g., based on previous examples / data of temperatures at which methane was detected, using the combustion temperature of methane to conclude the expected presence of methane). In some examples, indirect measurement may additionally or alternatively use the variation of measurements over time in order to predict, determine, or estimate a properly (e.g., assessing a variation in time with a corresponding model, comprising temporal data).

[0207] That is to say that direct measurement data may directly relate to - and provide for - the measurement of a particular unknown itself, whereas the indirect measurement data may be usable together with additional data as part of the system (e.g., additional data may included trained data, model data, which may also be temporal in nature) in order to predict, derive (e.g. infer) or estimate the measurement of a particular unknown. It will be appreciated that in some cases, indirect measurement data may, on occasion, be less accurate than direct measurement data, but nevertheless remain valuable (and sometime computationally / capitally less expensive). On some occasions, the use of direct measurement data together with indirect measurement data may improve the robustness of the overall measurement (e.g., mitigate erroneous readings).

[0208] Additionally or alternatively, the use of direct and indirect measurement data be used to develop models / correlations (e.g., for future use) of indirect measurement data, e.g., indirectly measurement data solely or mainly as a primary data source (e.g., in the absence of direct measurements, which may happen from time to time, or consistent after initial training). That means that direct measurement data may be used for a period time along side measurement data in order to train a model (e.g., provide correlations), such that latterly the system may be able to operate and measure properties using mainly or solely indirect measurement data (e.g., and optionally including further data) (e.g., when direct measurement data is not being used or available).

[0209] Here, the primary image capture device 225 is configured to obtain primary image data at a particular spectral band, such that the image data relates to measurement of particular properties of a gas emission at that spectral band (e.g., but more so indirectly), and wherein the system is configured to use that primary image data together ancillary spectral data associated with the gas emission to determine emission properties. In some cases, of course, the image capture device may be configured to measure temperature and / or brightness, and measuring directly specific compositions. Here, the primary image device may be considered to provide a narrower spectral band than that of Figure 3a and / or lower spectral resolution. In this particular example, the primary image capture device 225 may be configured to capture infrared and / or visible wavelength image data, which may comprises some information regarding the emissions, but not as directly (or to the same precision, in the absence of further data) as the above described arrangement in Figure 3a. In Figure 3b, the system 200 further comprises an ancillary image capture device 235, which may be configured to obtain direct measurement data of particular properties (e.g., specific / precise measurements), such as CO2, methane, or the like. As example, the ancillary image capture device may be a hyperspectral camera (or at least an image capture device configured to obtain more spectral data that the primary image capture device 225). By way of an example, Figure 4a shows a plot of primary spectral image data 300, over which available range has a particular spectral resolution (i.e., the ability to obtain data from particular spectral wavelengths). Figure 4b, however, shows a first example of a plot of ancillary spectral image data 310a derivable from the ancillary image capture device 225, which is able to obtain a wider range of spectral data. Figure 4c shows a further example of a plot of ancillary spectral image data 310b derivable from the ancillary image capture device 225, which shows particular spectral bands 315 at which significant spectral data may be obtained at a greater fidelity from that of Figure 4a (e.g., which may be directly associated with the presence of particular emissions, such as cardon dioxide or the like). In either case, it will be appreciated that the primary spectral image data provides less information / data than the ancillary spectral data, whether that be because the spectral band is narrower (as per Figure 4a / 4b) and / or whether the spectral resolution is less. It may also be considered that the ancillary spectral data directly obtains particular properties of the emissions, whereas the primary data may not directly.

[0210] In use, ancillary spectral data is collected by the ancillary image capture device 235, and processed by system 200, in order to determine or estimate gas emission property of the burner (e.g., across one or more spectral bands). That ancillary spectral data may be used together with other ancillary data, such as flow data and / or environmental data in order to determine properties of gas emissions (e.g., combustion efficiency, destruction and removal efficiency, green house gas composition, etc.). In some examples, the ancillary data (e.g., flow composition) may also be used to help selectively process particular spectral bands, in the manner above as described with reference to Figure 3a.

[0211] In any event, those determined properties of the gas emission may be correlated with the primary image data (and optionally the ancillary data). In other words, the determination of particular emissions may be used (e.g., correlated) together the particular primary image data, and optionally ancillary data, in order to develop a model 400 of the gas emission properties for particular primary image data (and optionally ancillary data 320), such that the primary image data may be used to indirectly measure properties of the emissions (with or without the ancillary spectral image data). By way of an example, consider Figure 5a, with shows a simplified representation determining emission properties using the system 200. Here, flow ancillary data 510 together with environmental ancillary data 520 are communicated to, or obtained by, the data acquisition arrangement 220. Further, the data acquisition arrangement 220 is configured to receive primary image data 530 (e.g., lower resolution infrared / visible spectral data, or other indirect measurement data) and ancillary image data 540 (e.g., high resolution, and potentially wider band spectral data - direct measurement data). The system 200 is configured, from at least the ancillary image data 540, to determine emissions property data 550 (e.g., composition, combustion efficiency, DRE, etc.). That emission property data 550 may be usable for reporting and / or controlling the flow to modify emissions.

[0212] The system 200 is further configured, however, to store and develop an emissions model 400. That model 400 may comprise data obtained 510, 520, 530, 540 together with determined or estimated emission properties (e.g., direct measurement data). The model may additional begin to correlate determined emission properties together with at least the primary image data (and optionally the ancillary data), e.g. such that the primary image data (and optionally the ancillary data) may be used (e.g., used subsequently) to provide indirect measurement data of emission properties. In some cases, the data collected when using ancillary image data may be considering training data, and used to train the model 400 (e.g., when using machine learning). Over time, the model 400 may be developed to predict emission properties based on a subset of input data 510, 520, 530, 540 (e.g., without needing or always using direct measurement data, such as ancillary image data). In other words, the model may be adapted as needed, and need not always use all data, but rather data (e.g., environment data, primary image data, etc.) may be selectively used based on one or more of: cost; processing times; requirement for precision; availability of direct measurement data; etc. The system / model may be adapted to the conditions as needed.

[0213] For example, consider now Figure 5b in which the system 200 is configured to use flow ancillary data 510, environmental ancillary data 520, and primary image spectral data 530, but together with the model 400 in order to determine or predict emission property data 550 (e.g., indirectly). In this example, the model 400 can be used instead of the ancillary spectral data (e.g., instead of the direct measurement data) in order to accurately predict emission properties. Further, the prediction or calculation may be used to further develop the model 400.

[0214] It will be appreciated that in such cases, emission properties may be determined or predicted without necessarily the ongoing need to obtain direct measurement data (e.g., measure ancillary image data across a relatively wide spectral band (e.g., continuously), or other such techniques). In other words, in such cases, the ancillary image data / determined emission properties may be usable as training data (e.g., using machine learning) to develop a model of the properties of the gas emission that can be then derived from indirect measurement data, which may be usable under differing flow and / or environmental conditions (which may be particular to that combustion location, e.g., flare burner 40). In that way, the system 200 can be usable to determine, from indirect measurement data, such as the primary image data and / or ancillary data, approximate properties of the gas emissions (combustion efficiency, destruction and removal efficiency, green house gas composition, other pollutants, etc). In this way, and after development of a model 400, the ancillary image device 235 may be removed (or used more sparingly), directed at other burners / leaks (e.g., trained and moveable across multiple flares), or the like, such that they system 200 is operable to determine properties of gas emissions without such direct measurements (e.g., using relatively narrowband and / or lower resolution primary imagine capture device 225, and / or ancillary data).

[0215] Such a configuration not only is able to reduce the ongoing complexity and cost of the hardware arranged to monitor / manage gas emissions properties, but may additionally or alternatively reduce computation complexity and processing requirements at the system 200 (e.g., when deployed for longer periods of time).

[0216] It will readily be appreciated that in some examples, an appropriate model 400 may be developed over a period of hours, days, weeks or even months (e.g., and may be usable to correlate / predict temporal data). In some examples, (e.g., when conditions between sites or burners 40 are similar) an existing model may be used, without the need to deploy, for example, an ancillary image capture device 235 at site. In those cases, the system 200 may be configured to store model data at a database 222, or have the model data accessible for use (e.g., via a wireless / cellular Internet connection 224) (see Figure 3a and 3b). In some examples, direct measurement data may have been obtained at an alternative location, such as at a laboratory environment or alternative ancillary image capture device, and may be usable with the model. As such, the system 200 may be configured to use primary image data and / or ancillary data together with model data to monitor emissions properties (e.g., without (e.g., continuously) requiring direct measurement data at site). In any event, such monitoring of emission properties may allow for reporting and / or control of the flow or the like, in order to modify emissions so as to reduce or eliminate harmful emissions.

[0217] It will be appreciated that in some examples, the model 400 may be updated from time to time, e.g., downloaded, and without having to update the hardware at site. Further, the same system 200 may be used across many different scenarios and environments, given that the system uses models that can be adapted as needed (e.g., same hardware can be used to measure CO2, but then can also be adapted to measure SO2, or combination). While in Figure 3b, the primary image capture device 225 and ancillary image capture device 235 are shown opposing sides of a burner 40 (e.g., flare), it will be appreciated that this is principally to assist with representation, and need not always be the case. Both the primary and ancillary image capture devices 225, 235 may be collocated or located in sufficient proximity to one another so as to observe the same (or similar) image of the gas emission 40.

[0218] Further, it will be appreciated that in some cases, more than one or two imaging capture devices may be used (e.g., two or more primary image capture devices 235), which may be helpful in certain circumstances. In some examples, having more than one primary image capture device 225 and / or ancillary image capture device 235 may be helpful, and may permit image data to be obtained from alternative orientations at a gas emissions 40. Such alternative orientations may be helpful to construct an understanding of the emission in, for example, different wind conditions, and / or based on alternative presentations of the emission, and so help better monitor (e.g., determine or estimate) emission properties. Again, such data may be used by any model 400 to predict or determine emission properties.

[0219] Consider now Figures 6a and 6b, which show a primary image capture device 425a as well as secondary image capture device 425b. In this example, the primary and secondary image capture devices 425a, 425b may have similar spectral bands to that described in Figure 3b, e.g., infrared and / or visible wavelengths (but of course the following may be used with direct measurement data devices too). Here, the first image capture device 425a is configured to capture primary image data associated with a gas emission at a first orientation, and the secondary image device is configured to capture secondary image data (e.g., simultaneously) associated with a gas emission 40 at a second orientation. As shown, the first and second orientations differ.

[0220] Figure 6b shows a plan view of the orientation of primary and secondary image capture devices 425a, 425b, shown in Figure 6a. As is shown, in this example, the image capture devices are in position in a common plane (horizontally, with respect the burner 40), but oriented at an angle of approximately of between 135 degrees and 60 degrees, and more particularly between 130 degrees and 90 degrees. In the example shown, the devices 425a, 425b are positioned approximately 120 degrees from one another, which may be helpful when processing image data as described below. It will be appreciated here that while two devices 425a and 425b are shown, in some cases more devices may be used (e.g., at commonly spaced orientation intervals, such as 60, 90 or 120 degrees intervals). Further, while in this example, image capture devices 425a, 425b are shown in the same plane, it will be appreciated that in other examples, those devices may be out of plane, or at least angled out of plane to capture images of the gas emission 60. Further still, in some examples, the system 200 comprises one or more additional image capture devices 425c configured to capture a plan view image of the gas emission 40. Such an image capture device 425c may be positioned on a boom or arm, but also may be positioned on an overhead vehicle, such as a drone or satellite. The following described examples may be adapted for use with multiple such image capture devices 425a, 425b, 425c accordingly.

[0221] Here, however, and for ease of explanation two image devices 425a, 425b are described, which are fixed relative to one another (although it may be in other cases that one or more of the devices is provided on a movable fixing, or vehicle, such as a drone or satellite, such that relative position can be adjusted). In this case, image data (e.g., spectral data) from the two image capture devices 425a, 425b may be usable individually or cumulatively in order to monitor properties of the combustion location (e.g., burner 40).

[0222] It will be appreciated that aspects of the following example may or may not be used together with the flow management arrangement 110, and / or indeed the example of developing a model 400 as described above. For example, any model 400 developed as per the examples above may use image data (e.g., spectral image data) from primary and secondary image devices 425a, 425b (or more devices) individually or cumulatively in order to predict or monitor emission properties (e.g., the model may use indirect measurement data from both first and second devices in order to monitor emissions). In some examples, the emission properties may be determined using the primary spectral data from the first device, and emission properties may separately be determined using the secondary spectral data from the second device, with the results being used together (e.g., compared, and / or averaged, etc.) in order to monitor emission properties. In further examples, the image data from each device may be used together to help build the model. While the following examples may be described in relation to primary / secondary image capture devices having lower resolution infrared / visible capabilities, it will be appreciated that one or more hyperspectral image capture devices, and / or other direct measurement devices (e.g., LiDAR), may additionally or alternatively be used. A skilled reader will readily be able to implement those various embodiments.

[0223] In use, in some examples, the specific orientation of the image capture devices (e.g., primary and secondary devices) may be unknown when deployed, or at least unknown to a specific resolution. In such cases, it may be helpful to be able to calibrate (e.g., self calibrate) the devices 425a, 425b to determine their orientation with respect to one another.

[0224] Consider now Figure 6c, which shows reconstructed and simplified images 625a, 625b from primary and secondary capture devices 425a, 425b shown in Figure 6a and 6b. In this example, the system 200 is configured to use image data from both devices 425b, 425c, and to determine a corresponding particular feature 610 in both primary and secondary image data 625a, 625b. That feature 610 may be a property of the emission, and may be considered to be an artefact in the emission 610 which is assumed to be common (e.g., but rotated) in each image. Example features, or otherwise artefacts, may include common regions of temperature, specific areas of radiation intensity (e.g., brightness), and / or wavelength (e.g., colour), profile or contours determined from edge-detection techniques. In one particular example, the system 200 is configured to determine a temperature profile of a region of the image (e.g., using infrared spectral data). Such a region may be identified also using edge detection techniques in the image. The temperature profile region may corresponded with a similar (but likely oriented / rotated) feature in the secondary image data. Assuming that each device 425a, 425b is observing the same feature, but at different orientations, then the system 200 may be configured to approximate or determine the relative orientation of the devices 425a, 425b. This orientation may be determined over time (e.g. by sampling image data for a period of time (e.g., minutes, hours). The image capture devices 425a, 425b may additionally or alternately use parallax data to help determine the relative position and / or orientation of the image capture devices 425a, 425b. In other examples, of course, the position / orientation of the devices may be known or set during the installation process, without the need to determine from the image data. It will also be appreciated that in the example of multiple image capture devices, that they may additionally communicate wirelessly with one another. In such cases, use location-based signals may be used (additionally or alternatively) in order to determine the relative position and / or orientation of the first and second image capture devices. The use of both location based signal and identified features may be helpful when deploying at site with many devices.

[0225] In any event, when using multiple (e.g., two or more) image capture devices, the system 200 may be configured to construct or determine a particular approximation, such as a volumetric approximation / calculation, of the gas emission from the primary and secondary image data (and / or additional image data). Such a volumetric or 3D approximation of the gas emission may allow for emission properties to be better determined. Such volumetric approximation / determination may be used in any model 400.

[0226] Consider now again the example images in Figure 6c. Here, the images 625a, 625b can be considered to be representation from an image capture device 425a, 425b having infrared spectral band (e.g., thermal spectral band). In this example, common temperature values in the image data can be represented as regions of similar properties values within the primary and secondary image data 625a, 625b. In the images, iso-regions 620a, 620b (e.g., iso- contour or iso-surfaces) represent regions of similar properties values (e.g., similar temperatures), and may be contiguous profile or contour across a portion of the image. It is typical, during combustion, for there to be a temperature gradient across, in this example, the flare 40, where broadly speaking the flare cools further from the flare 40. Similarly, with gas leaks, there may be a temperature gradient across the emission, whereby gases warm (or at least heat closer to ambient) further from the gas leak they emit. Further still, with examples likes incinerators, there may be temperature profile across the surface (e.g., outer surface) of those incinerators. In these cases, an iso-region of temperature may be selected or many be represented.

[0227] The system 200, in the present embodiment however, is configured to selectively identify isoregions of particular temperatures (e.g., approximately 500 degrees). At particular temperatures (e.g., 500 degrees) certain gases such as methane, for example, may fully - or almost fully - combust, whereas below such set temperature the gases may not. Here, the system 200 is configured to selectively identify iso-regions of particular temperatures and construct (or determine) one or more volumes that are defined within determined or approximated iso-regions. On other words, the system 200 is configured to determine from the images, the particular volume of gases that may be defined within an iso-region, and so generally considered to be above (or below) (or at least within / outside) a particular temperature. The system 200 may be configured to use a determined volume of a gas emission in any model 400. For example, the volume of gas emission at or above a particular temperature may be used to together with the ancillary data comprising environmental data and / or flow rate data associated with the gas emission in order to determine properties of the gas emission. For example, the system 200 may determine from a comparison of the flow rate, and / or flow species and the volume of emission above a particular temperature, that green house gases, such as methane, may not be fully combusted, and may be released to atmosphere. In those cases, the extent of emissions may be provided. It will be appreciated that this approach may be used with or without the modelling described in relation to Figure 5c, or if such modelling occurs, then in some cases, direct measurement data, such as that provided from hyperspectral data, need not be used for the model with the emission properties predicted using the volumetric data. That said, in some examples, determination of volumetric data may be used together other data in the modelling of Figure 5c in order to more accurately determine properties of the emission.

[0228] Further still, the system 200 of this described example may also be configured to determine particular geometric measurements of a gas emission from image data, which may be used as ancillary data in order to monitor properties of that gas emission. For example, in some cases, the system 200 is configured to determine particular geometric parameters such as distances from one position in the image to another position in the image, associated with the gas emission. As an example, the system 200 here is further configured to determine, from image data, geometric measurement data representing the distance from point of a gas emission (or other feature of the flare) to a particular determined iso-region, such as a temperature iso-region (which may include brightness and / or colour region) in order to determine emission properties (e.g., see D1 and D2 in Figure 6c). This geometric data measurements, D1 , D2, may be used additionally or alternatively with volumetric data or other data in order to monitor emissions.

[0229] In some examples, particular geometric measurements between two or more locations may be used together with other data in order to indirectly measure emission properties. In some examples, geometric measurements may be used to model and predict such conditions.

[0230] It will be appreciated that in many examples, wind strength and direction may be determined and provided as ancillary data, based on measurements taken locally, or by data provided to the system (e.g., via the Internet 224). In other examples, however, the orientation of the gas emission affected by environmental wind conditions may be determined from the primary and secondary image data itself. For example, a burner 40 (or gases associated with a burner) may distort in presence of wind in an observable manner such that wind speed and / or direction can be estimated or calculated based on the shape of the flare / emission. This may be particularly possible using multiple image devices. Such determined wind orientation / environmental data, derived from the images, may be used together with further primary and / or secondary image data (e.g., one or more of volumes, spectral profiles, geometric measurements) in order to determine properties of the gas emission. In some examples, the system 200 is configured to determine the orientation of the gas emission affected by environmental wind conditions from ancillary data comprising satellite image data, and to use the determined orientation together with primary and / or secondary image data in order to determine properties of the gas emission.

[0231] In some particular examples, the system 200 may be deployed in harsh environments, which may impact on the performance of image capture devices 425a, 425b at site. One example includes semi-arid desert environments (e.g., the Arabian desert), or offshore conditions (e.g., the North Sea). Weather conditions, such as sand, fret, precipitation, or other inclement conditions, can affect image capture devices and the data obtained. Similarly, however, other conditions at site, e.g., water curtains, which may be temporary, may also affect the performance of such devices. It may be helpful therefore to be able to ensure that emission properties can be monitored during these varying condition, particularly when using or adopting models.

[0232] Consider now Figure 7a, which shows the system 200 of Figure 6b, but in this example the system 200 further comprises a reference image capture device 700. The reference image capture device 700 is configured to obtain reference image data associated with the environmental conditions in proximity of a gas emission. Here, a reference emitter 710 is configured to communicate a particular signals, such as electromagnetic signal, to the image capture device 700. In particular, in this example, the emitter 710 is configured to emit a reference signal receivable by the reference image capture device 700, and transmittable across an environmental region associated with a gas emission 40, wherein the reference signal is of the same or similar wavelengths to that receivable by the primary image capture device. For example, the emitter 710 may be configured to emit a signal in the infrared or visible spectrum. The system 200 may be configured to determine, from the received reference signal, particular absorption and / or scatter characteristics associated with environment. In doing so, the system 200 may be configured to use the reference data together with other data (e.g., the primary / secondary, etc., image data) associated with the gas emission in order to determine properties of the gas emission in order to accommodate for varying environmental conditions.

[0233] For example, it will be appreciated that the system 200 may be configured to use image data together with ancillary data comprising transmittance and / or absorption data (which may be as a result of a temporary water curtain, dust, significant precipitation, or the like) in order to determine emission properties of a gas emission.

[0234] Figure 7b shows a further example of the system 200 in which the reference emitter 710 is configured to communicate a reference signal for receipt at the primary and / or secondary image capture devices 415a, 425b. In this example, the primary and / or secondary image capture devices 425a, 425b act also as reference image capture devices 700. Here, a region 720 of the image is used to receive the reference signal. Properties of the signal (e.g., the intensity of the signal) may be determined in order to approximate the variation of environmental conditions. This information may be used as ancillary data in any of the examples described above, or used to adjust calculations / models accordingly.

[0235] While in the above examples, image data is collected and processed in order to determine emission properties, it will be appreciated that in some cases the image data may be supplemented with location and positional based data. Such additional location-based data may be usable to reconstruct a 3D or spatial image of the gas emission. Such data may be helpful to assist with repair or maintenance of a gas leak, for example (e.g., when using virtual or augmented reality solutions).

[0236] The above described examples may be helpful in monitored properties of a gas emission include one or more of: combustion efficiency; destruction and removal efficiency; green house gas emission; methane emission, pollutants, etc. In particular examples, such gas emissions may comprise a flare, incinerators, or the like, or a gas leak at an oil an gas installation. It will be appreciated that monitoring of a emissions of a burner may comprising monitoring of the emissions provided from the burner to atmosphere, as well as the structure of, for example, combustion itself (the flare itself, i.e., the fluids being combusted, whether or not yet combusted), and / or properties of the apparatus associated with combustion. In any event, the monitoring of such emissions may assist with reporting and management.

[0237] While the above examples have been described in relation to flares, it will readily be appreciated that that same systems and method may be used with other burners (e.g., incinerators, enclosed combustors or the like), or indeed gas emissions (e.g., at site). It will be appreciated that unwanted emission (e.g., leaks) at site may not only be a potential hazard, but also may result in lost revenue, e.g., due to extended periods of downtime when problems are not identified early, and / or lost hydrocarbons. A skilled reader will readily appreciate that the simple and cost effective nature of the above described solution.

[0238] For example, consider Figure 7c, which shows a burner 800, which in this example is an incinerator 800. The incinerator 800 partially encloses a combustion chamber / location 810, which hydrocarbons are combusted (e.g., and exhausted to atmosphere). Hydrocarbons may be flowed from one or more flow lines 820a-820c (e.g., via a flow management arrangement 110 of Figure 2 (not shown here), which may be configured to be positioned together with the flow 30). In this example, image capture devices 825 are positioned relative to the incinerator so at to obtain image capture data from the outer surface of the incinerator 800 (e.g., temperature profiles). By way of an example, further image capture devices 830 are shown here positioned so as to obtain image capture data from emissions exhausting from the incinerator 800. It will readily be appreciated that in use, any of the methods and aspects of data acquisition arrangements 120 described in the above examples may be equally applied here.

[0239] It will also be appreciated that n some cases, monitoring of the combustion location may additionally or alternatively help control a flow management arrangement (e.g., configured to positioned in line with a hydrocarbon flow, and upstream or indeed at a gas emission) as described above. Such a flow management system may be configured to communicate ancillary data regarding a hydrocarbon flow to the data acquisition system for use together with image data in order to determine emission properties. That said, it will be appreciated that in some examples, the data acquisition system 120 (e.g., including image capture device(s)) may be used without the flow management arrangement. In those cases, the data acquisition arrangement be used to identify emissions from one or more burners and / or components. Collected data may be used for reporting purposes, and / or may be usable to take particular action at site.

[0240] In terms of flow management, consider again, for example, Figure 2, which shows the system 100 for monitoring / managing emission properties, e.g. at a well site 10. The system 100 in Figure 2 also comprises a flow management arrangement 110, which is explained is shown in optional communication with the data acquisition arrangement 120 (e.g., as exemplified above). The flow management arrangement 110 may obtain data relating the flow of hydrocarbons, as will now be described. Additionally or alternatively, the flow management arrangement 110 may control the flow. In Figure 2, the flow management arrangement 110 is configured to be positioned in line with the hydrocarbon flow 30. This may be upstream of a burner 40 for burning hydrocarbons in the flow, as shown, and / or at the burner / combustion location itself.

[0241] Here, the flow management arrangement 110 is also positioned, however, downstream of any well test equipment 20, e.g., any separators or other such well test equipment 20. In some cases, the flow management arrangement 110 may be retrofit to the hydrocarbon flow path 30, or at least installed together with expected flow tubing or the like that may be used to fluidly couple the well test equipment 20 to the burner 40. In that way, the system 100 and / or flow management arrangement 110 may be configured to be agnostic to the existing well set-up and well test equipment 20, which may provide a cost effective solution to allow the system 100 to operate at site with various different equipment and apparatus. In any event, the flow management arrangement 110 is specifically configured such that hydrocarbons flow through the arrangement 110 from the well test equipment 20 to the burner 40.

[0242] Again, for the purposes of below, it will be appreciated that the flow management arrangement 110 may be mechanically and fluidly connected to tubing or pipework that exists, e.g., that has been installed at the site 10 previously. In some cases, the flow management arrangement 110 may be formed generally as a pipe joint section or the like, so that it can be readily fitted to a existing section of the hydrocarbon flow 30, e.g., by removing and replacing an existing section of pipe work. Consider now Figure 8a, which shows an example of the flow management arrangement 110 in more detail. Here, the flow management arrangement 110 is specifically configured to control intake (e.g., introduction, and in this particular example, induction) of a control fluid into the hydrocarbon flow, which flows along the flow path 30 to the burner 40. That control fluid may be used to modify or otherwise control combustion / destruction properties associated with the hydrocarbon flow. In other words, the control fluid may be used (or introduced accordingly) in order to manage combustion / destruction at the burner 40. In some examples, the control fluid may comprise fluids usable to increase the combustion / destruction of the hydrocarbon flow, such as oxidants (e.g., air comprising oxygen, and in some cases water). In some examples, the control fluid may comprise fluids usable to decrease the combustion of the hydrocarbon flow (e.g., water, cardon dioxide, potassium, or other such retardants).

[0243] Further, in this particular example, the flow management arrangement 110 is configured to mix control fluid with hydrocarbon fluids. Here, such mixing is provided in a manner upstream of the burner 40, but may be provided additionally or alternatively at the burner or combustion location. Such control may provide adjustment and control of the combustion properties at the burner 40. In this particular example, the flow management arrangement 110 is specifically configured to use (e.g., fully or partially) the flow of fluids in the hydrocarbon flow to assist with introduction (e.g. induction) of a control fluid into that hydrocarbon flow flowing to the burner 40, in order to control the combustion properties at the burner 40. In other similar words, the flow management arrangement 110 may be considered to be able to operate passively in so far as energy from the flow itself can be used to power the arrangement 110, and provide for introduction (e.g., induction) of any control fluid. In thatway, the arrangement can, for example, be easily deployed at site without the need for additional power (or course active power may additionally or alternatively be used).

[0244] In this particular example however, as will be described, the motive force (or otherwise flow) of the hydrocarbon flow itself effectively powers fully the arrangement 110 and causes introduction (e.g., induction) of control fluids into the flow. Here, the arrangement 110 comprises an intake arrangement 130 configured to introduce a control fluid into hydrocarbon flow using the fluids flowing in the hydrocarbon flow.

[0245] Figure 9 shows one example of an example intake arrangement 130 in more detail.

[0246] While in this example, the motive force (or otherwise flow) of the hydrocarbon flow itself may effectively power the intake arrangement 130 and cause the introduction or induction of control fluid (e.g., oxidant), it will be appreciated that in other examples, alternative (or additional) means may be used to assist with induction of a control fluid. For examples, power derived from the flow may be used alternatively or additionally to introduce (e.g., pump) control fluid to the hydrocarbon flow. One such example may comprise extracting energy from the flow using one or more turbine arrangements, positioning within the flow, which may then be utilised to power a particular intake arrangement 130 (e.g., comprising a powered pump) instead of, or to supplement, that shown in Figure 9. In any event, the flow may be fully or partially used to introduce control fluid. In some further examples, power derived not from the flow (e.g., and auxiliary power source may additionally or alternatively be used).

[0247] In this particular example, and with reference to Figure 9, the intake arrangement 130 can be considered to intake (e.g., induct) oxidant (e.g., air, oxygen, etc.) as a control fluid at a second inlet 130b, and to mix that control fluid within a mixing chamber 130c with fluids that have flowed along the flow path 30 to a first inlet 130a. An outlet 130d is used to communicate mixed flow from the arrangement 130. The first inlet 130a comprises a restriction 135 which can be used to cause an effective reduction in pressure in the flow, and provide for introduction of the control fluid at the second inlet 130b. The motive flow of the hydrocarbon flow essentially being used to induct the control fluid. In some examples, the restriction 135 may be controllable in order to control the flow through the arrangement (e.g., more open vs more closed).

[0248] In this case, (e.g., see Fig. 8a-8c) a controllable first valve arrangement 140 may additionally or alternatively be provided at the first inlet 130a to the intake arrangement 130, which can be used to restrict the flow through the intake arrangement 130. Additionally or alternatively, a controllable second valve arrangement 150 may be provided at a second inlet 140b to the intake arrangement 130, which can likewise be used to restrict the flow of control fluid. Although not shown, a similar controllable valve arrangement may additionally or alternatively be provided at the outlet 130d. The rate of flow and / or valves may be set such that, in use, the flow management arrangement 110 may require little or no power supply (e.g., external power, but may be powered from energy extracted from the flow).

[0249] It will be appreciated that although one or both of the first and second valve arrangements 140, 150 (and / or optionally and outlet valve arrangement; restriction) may be implemented, nevertheless the process of introducing (e.g., inducing) and mixing control fluid into the hydrocarbon flow may occur passively. That is to say that no additional power requirements may be needed. In those cases, the values may similar control the extent of flow. As mentioned, the motive force of the hydrocarbon flow itself may effectively power the flow management arrangement 110 / intake arrangement 130. Further, the flow rates and rates or induction / mixing, may be set (e.g., using the valves or otherwise) such that the burner 40 does not perceive any change in conditions when the flow management arrangement 110 is installed (e.g., in a retrofit manner from Figure 1 to Figure 2). In other words, in this example (and other examples) there may be no or little perceived pressure change at the burner 40 with the system 100 installed compared to without the system installed. In other similar words, the pressure of fluid flow at the burner 40 can be maintained.

[0250] It will be appreciated that while is may be helpful to describe the arrangement in Figure 8a (and later Figures) comprising first and second valve arrangements 140, 150, it will be appreciate that that need not always be the case. In some cases, one, some or all, of the valves may not be used, as needed.

[0251] Returning to Figure 8a, and by way of an example only, the system 100 (and in this case the flow management arrangement 110) may be considered to comprise at least a first flow path 30a and a second flow path 30b through the arrangement 110. The first flow path flows through the arrangement 110 to the burner 40 such that hydrocarbons are mixed with oxidant to a particular extent (e.g., controlled by the intake arrangement 130, etc.). The second flow path 30b, however, is configured such that hydrocarbons are mixed with oxidant to a different extent and, in this example, no mixing occurs as hydrocarbons flow in the second flow path 30b to the burner 40. Here, the second flow path recombines with the first flow path downstream of the intake arrangement 130, but upstream of the burner 40, such that the combined flow from the first and second flow paths then travels to the burner 40 for combustion. In this example, the second flow path 30b may be considered a bypass flow path.

[0252] It will be appreciated, however, that this arrangement may be provided differently. In some examples some or all of the flow paths 30a, 30b need not combine prior to the burner 40, but rather may combine at the location of combustion (e.g., at the flare, such as the tip of the flare). In such cases, little or no mixing of the flows may occur prior to combustion. Figure 8b shows such an example in which the second flow path 30b and the first flow path 30a combine at the location of combustion (e.g., at the burner tip itself, rather than upstream of the burner 40). Depending of the system 100 (e.g., fluid being combusted), such an arrangement may allow for improved control of combustion properties at the burner 40. In some examples, the second flow path 30b may be considered to be a primary flow path along which the greater proportion of flow occurs (e.g., greater than 60%, 70%, 80% or indeed 90% of fluid flow). In that way, between 0-40% of fluid fraction may flow via the intake arrangement 130. This arrangement may be particularly helpful when managing any backpressure at the flow management arrangement 110. Of course, in other examples (e.g., when backpressure may not be considered), then the greater fraction of fluid may pass along the first flow path. In any event (e.g., Figure 8a or Figure 8b) a selector 160 may optionally be provided upstream of the first and second flow paths 30a, 30b, and can be configured to allow selective flow of hydrocarbons through the first flow path 30a, the second flow path 30b, or a though combination of flow paths 30a, 30b (e.g. proportionally). It will be appreciated that in some examples, the selector 160 maybe configured as a divertor. Further, it will be appreciated that in some examples, the selector 160 may be used without the need for a first valve arrangement 140, whereby restricting flow to the first inlet 130a of the intake arrangement 130 increases flow (e.g., proportion of flow) along the second fluid path 30b (and vice versa).

[0253] In further examples (e.g., when the fluids from a well have been separated) it may be that a selector is not required, but rather the output of a separator is fed to the system 100 such that one particular flow paths is used for a first fluid (e.g., gases), while the other particular flow path is used for a second fluid (e.g., oil). The first and second fluids may be different.

[0254] Figures 8c and 8d show examples of the system 100 having a first flow path 35a, and a second flow path 35b, in a similar to Figure 8a and 8b. Here, however, in Figure 8c the first and second flow paths 35a, 35a may be fluidly connected to different sources (e.g., different separator outlets, and / or different wells, rather than the same source). For example, the first flow path 35a may be fluidly connected to a first source (e.g., first well test arrangement), while the second flow path 35b may be fluidly connected to second oil source (e.g., second well test arrangement). Here, the second flow path 35b combines with the first flow path downstream of flow arrangement, but upstream of the burner 40. In doing so, the fluid flowing in the second flow path 35b is mixed with fluid, which has been mixed with control fluid, in the first flow path, prior to combustion. Such an arrangement may help manage emission at site with multiple sources of different quality, for example. Figure 8d shows an example similar to Figure 8c, but in this case, the second flow path combines at the location of combustion (e.g., rather than upstream of the burner 40). In those cases, it may be possible to introduce control fluid into one or more of the flow paths (e.g. oil), but not others (e.g., gas), in order to control emissions, e.g., from multiple sources (e.g., oil or gas, and / or different wells). Such a configuration may allow for efficient controlled combustion during varying conditions during well test, or varying sources, or the like. For example, it may be helpful to introduce control fluid into oil, but not desired to introduce into gas.

[0255] In use, a well site 10 may be initially appraised for suitability of installing (and optionally retrofitting) the flow management arrangement 110 (e.g., as exemplified in any of the above examples). For example, in some cases, the data acquisition arrangement 120 (according to any of the above examples) may be positioned at site and used to acquire data relating to the effective combustion of an existing or possible burner 40 (e.g., flares, incinerators, etc.) and to provide improvement recommendations. The flow management arrangement 110 may then be fitted (or retrofitted) to pipework or the like. Initially, when using the examples shown in Figure 8a or 8b, fluid may be permitting to flow entirely though the second flow path 30b to confirm operations. The data acquisition arrangement 120 may then be able to communicate with the flow management arrangement 110, e.g., either directly or via an operator, in order to configure the flow management arrangement 110 in order to minimise green house gas emissions and / or other emissions / destructions. In some cases, power may be supplied at that time to the flow management arrangement 110 (e.g., using external power or via the data acquisition arrangement 120, 220). After being set, flow may then be diverted fully or partially through the first flow path 30a in order to introduce and mix appropriately control fluid (e.g., oxidant) with the hydrocarbon flow, and so control emissions, e.g., minimise green house gas emissions, improve destructions, etc.. Feedback, such as realtime feedback, from the data acquisition arrangement (e.g., via image data) may be used to confirm optimal performance, and control emissions. In some cases, the system may be considered to act autonomously.

[0256] While in the example described, the control fluid has been described comprising an oxidant, which may help improve the combustion efficiency / destruction and for example allow methane to be combusted (e.g., managing green house gas production), in other examples, there may be a desire to affect combustion in different ways, which may in fact help to reduce harmful emissions.

[0257] For example, it may be determined that the particular temperature of combustion could give rise to the production of green house gases, such as nitrogen dioxide or the like, or otherwise may be harmful (e.g., excessive temperature being hazardous to surrounding environment or equipment). In such examples, reduction of the temperature of combustion may be desired, e.g., to avoid or minimise any such production (and in fact minimise the effective green house gas emissions). As such, a control fluid that may reduce the temperature of combustion may be used, such as water, carbon dioxide, potassium or the like. In similar words, the control fluid may comprise a retardant. Similarly, in some examples, the production of hydrogen sulphide, or other highly toxic gases, may be identified (or estimated), and management of the combustion / destruction may be desired in order to minimise the production of any such gases. In those cases, any control fluid may be used to minimise combustion (e.g., cold vent) and / or avoid hydrogen sulphide production. A skilled reader will readily be able to implement those embodiments.

[0258] It will be appreciated that in some examples, the data acquisition arrangement 120, 220 may be configured to acquire data for a period of time (e.g., over a day, week, month or the like) over which conditions may likely vary. Based on any observed or expected variations in conditions, the data acquisition arrangement 120, 220 may be configured to provide optimal settings for the flow management arrangement over that particular period (e.g., to provide the least green house gas emissions cumulatively over that period). For example, it may be that environmental temperature are known or measured to vary over the course of a day, and the flow management arrangement 110 may be set (e.g., set statically over that period) to provide optimal performance over that period.

[0259] In some cases, the data acquisition arrangement 120, 220 may be configured to model or predict expected performance of the flow management arrangement 110 over a period of time, such as over a day, week, month or year, and so communicate instructions or information to the flow management arrangement for that ongoing operations (e.g., on an ongoing basis or once / at intervals even when the data acquisition system is no longer in communication with the flow management arrangement 110). It will be appreciated that any such prediction of control may use predictive models based on present data and / or previous data acquired. Predictive models may be used to initially control (or otherwise set) the performance of the flow management arrangement 110, which then may be validated and / or varied as appropriate.

[0260] In further examples, of course, the system 100 may be configured to vary in real time the operation of the flow management arrangement 110, and in some cases the data acquisition system 120 may remain in communication with the flow management arrangement 110 during such operations, (e.g., dynamic / real time operations).

[0261] In any event, the system 100 described may be configured in one example to ensure that green house gas production, and / or other combustible production, or other harmful emissions are minimised or otherwise eliminated. This may be achieved by monitoring data (e.g., flow, image, etc.) and ensuring that appropriate control fluids are provided such that harmful gases or any other such combustible is fully burned, and / or other emissions managed.

[0262] It will be appreciated however that in some examples using oxidant, adding further oxidant may also result in cold flaring or venting of particular components at the combustion location 40, without using a retardant. In those cases, green house gases may be released, and so choking oxidant may be required. This may benefit from being dynamically varied in examples, such as well test (or other non-routine flaring examples).

[0263] Further still, it will be appreciated that in some examples, the emission of gases, such as green house gases, may be controlled collectively to ensure that minimum (or optimal) emissions from the burner 40 may be achieved. For example, green house gas emissions may comprise methane as well as carbon dioxide, nitrogen dioxide, etc. (or indeed other green house gases). Some carbon dioxide, or other gases for example, may be present in the flow already, and so difficult to eliminate. As such, measurement simply of the cardon dioxide at the combustion location 40 may be misleading as it may suggest combustion, whereas that green house gas was already present in the flow. In some examples, the system 100 may be configured to control combustion such that a balance of green house gases are controlled and minimised (or otherwise reported), with the cumulative effective of green house gas emissions being controlled or minimised (e.g., methane, and other gases, such as CO2 ). The system may be configured to weigh particular emissions (e.g., based on each component gas’s relative green house effect), and to control overall emissions such that the effective cumulative greenhouse gas emissions, and / or other harmful emissions, are controlled or minimised.

[0264] While in some of the above example, the system 100 may be described as being retrofittable to an existing well structure, it will be appreciate that that need not always be the case, and that the system 100 may be installed at the same time as the well infrastructure (e.g., for permanent installation).

[0265] In those cases, or indeed other cases, the flow management arrangement 110 may again be configured to control (e.g., passively) combustion at a combustion location 40 by manging or otherwise controlling the flow and extent of control fluid being introduced to the hydrocarbon flow, e.g., either at a burner or that flows to such a burner 40. It will be appreciated, however, that some arrangements 110 (e.g., permanent install) may need only comprise the first flow path 30a, and introduction of control fluid may be controlled without the option of flowing via a second flow path 30b. That said, utilizing the second flow path 30b may permit a greater control of control fluid use / mix, particularly under varying conditions, as well as - should it be required - the ability to allow flow to pass through the device without additional control fluid. In the example described in relation to Figure 8a and 8b, the second inlet 130b may be fluidly coupled to atmosphere in order to deliver air comprising oxidant to the flow. It will be appreciated that in other examples, however, alternative control fluid sources may be used, such as stored oxidant (e.g., oxygen) and / or retardant (e.g., water). In some examples, the control fluid may be selected or indeed selectively changed between oxidant or retardant at the inlet to the system 100 (e.g., second valve arrangement 150). In the examples in which, for example, air from atmosphere is used, it will be appreciated that flow management arrangement 110 may further comprise a filter arrangement (e.g., media and / or a labyrinthtype flow path) in order to remove unwanted particulates or the like.

[0266] While in the examples described in relation to Figure 8a-8d two flow paths 30a, 35a, 30b, 35b are described as usable to control introduction (e.g., passively control induction using the flow, but also could be active) of a control fluid to different extents, and wherein the second flow path was configured substantially not to introduce control fluid, it will be appreciated that in further examples additional or alternative flow paths may be provided. Consider now, by way of an example, the system of Figure 10a, which is similar to that shown in Figure 8a, but with multiple units 3000a, 3000b configured to introduce particular control fluids (e.g., unit similar to Figure 8a, 8b, 8c, 8d and 9, may be used, for example). Each unit 3000a, 3000b may comprise a intake arrangement 2300a, 2300b as before, and may configured along a separate flow path. At least two of the units / intake arrangements 3000a, 3000b are provided on alternative flow paths 30c, 30d in Figure 10a. By way of an example, a flow path 30e without a intake arrangement (as per 30b in Figure 8a / 8b) is also shown. This need not always be used, of course.

[0267] In this particular example, the intake arrangement 2300a of the first unit 3000a may provide alternative performance characteristics to the intake arrangement 2300b of the second unit 3000b. In that way, the intake arrangement (or ratio of flow to each intake arrangement) may be operative selected in order to control rate of control fluid introduction. For example, some or all intake arrangements / units 3000a, 3000b may be configured to operate on different flow rates; different pressures, or different fluid (e.g., oil or mainly oil, versus gas or mainly gas), or indeed may be configured to use different control fluids (e.g., alternative oxidants / retardants, or even a combination of different oxidants and retardants). In that way, the same system 100 can be operatively used for varying conditions, or sets ups, without having to reconfigure the arrangement. As such, the flow management arrangement 110 may be usable across a wide variety of well sites, irrespective of the well in question. Further, the flow management arrangement 110 may be controllable to appropriately minimise green house gas emissions at those various alternative sites or other emissions, with minimal reconfiguration.

[0268] While in Figure 10a, the flow paths are combined together downstream of the burner 40, it will readily be appreciated that this need not always be the case and that, in some examples, some or all of the flow paths comprising control fluid may combine at the location of combustion in order to control emissions (e.g., as per any of Figures 8b, 8d), without the need to describe those further examples. A skilled reader will readily be able to implement those embodiments accordingly.

[0269] While in the example in Figure 10a, the system may be considered to control the introduction of control fluids within parallel flow paths (e.g., 30c, 30d, 30e). That is to say that, some of the fluid flow to the system may be selectively allowed to flow through alternative units 3000a, 3000b, as shown in Figure 10a. It will be appreciated, however, that in further examples, the system may additionally or alternatively be configured so as to permit different control of control fluids in series, along flow paths. Consider by way of an example, Figure 10b, which shows an arrangement similar to Figure 10a, but in which intake arrangements / units 3000c and 3000d are arranged in series along a flow path 30f. Here, each arrangement 3000c, 3000d, may be configured to provide alternative performance characteristics, and may be operatively used in order to control rate of control fluid introduction. For example, some or all intake arrangements 3000c, 3000d may be configured to operate on different flow rates; different pressures, or different fluid (e.g., oil or mainly oil, versus gas or mainly gas), or indeed may be configured to use different control fluids (e.g., alternative oxidants / retardants, or even a combination of different oxidants and retardants). Here, one, some or all arrangements in series may be selectively operable (e.g., can allow no introduction of control fluids) so to operatively select one or more of the arrangements for use. Further, in the example shown, the second flow path 30e, may be combinable between units 3000a, 3000d, and / or after units, and / or at the location of combustion. It will be appreciated that the series arrangement may be used together with one or more of the parallelly arranged units in Figure 10a.

[0270] It will further be appreciated that based on the hydrocarbons being produced, that the system 100 described in Figures 8a, 8b, 8c, 8d and Figures 10a and 10b can be used to supply and mix control fluids with the flow (e.g., passively) so as to control and improve combustion properties, as desired. In some cases, the ratio of control fluid being mixed can be controlled to ensure that methane, and / or other green house gas production is reduced, minimised or even eliminated and / or other harmful emissions destroyed / removed. It will be appreciated that in some cases, an optimal condition may present whereby too little control fluid may not be sufficient to combust all the methane or the like, whereas too much control fluid (e.g., in the form of air, so also including nitrogen) may lead to cold flaring, or otherwise venting of methane. In the examples described the valve arrangements (and optionally flow paths) may be controlled or otherwise set in order to (e.g., using power from the flow) control the combustion at the combustion location 40 (e.g., flare , incinerator, or the like). In the example described in relation to Figure 9 or other examples, it will be appreciated that alternative arrangements (e.g., different pump geometries) may be implemented and selected with ease.

[0271] As explained, in some examples, the settings or control of such valves or flow paths may be effected by an operator. It may be that the operator is informed of those settings from the data acquisition arrangement (e.g., via a user interface) or, as shown in Figure 11 , the data acquisition arrangement may be in communication with the flow management arrangement so as to permit control of the flow management arrangement.

[0272] While in the above examples, the flow management arrangement 110 is used to manage and control flow to a burner 40 by inducing an control fluid, or the like, it will readily be appreciated that the flow management arrangement 110 may control the flow to one or more of multiple flow lines to a burner. This may be additional or alternative to inducing a control fluid. Consider now, by way of an example, the burner 800 shown in Figure 12a.

[0273] In this example, the burner 800 is provided as an incinerator 800, similar to that described in Figure 7c, and which partially encloses a combustion chamber / location 810 within which hydrocarbons are combusted (e.g., and exhausted to atmosphere), and / or harmful constituents destroyed. Hydrocarbons may be flowed from one or more flow lines 820a-820c (e.g., via a flow management arrangement 110 of Figure 2, 8-11 , or the like), which may be configured to be positioned together with the flow 30). It will be appreciated that in some examples, the flows lines may enter the burner 800 at different locations around and / or along the height of the incinerator 800. In such a way, fluid to be combusted at the incinerator may be distributed within the combustion chamber itself (e.g., unlike a flare tip). Further one or more of the flow lines 820a, 820b, 820c may be configured together with flow management arrangement 110 so as to (variably) introduce flow comprising control fluid at that location.

[0274] Further still, while all the flow lines may have equal flow rates, in other examples, the system may comprise a main flow line 820b to the incinerator 800, together with one or more ancillary flow lines 820a, 820c (in this example two ancillary lines 820a, 820c). Here, the main flow line 820b is positioned at the base region of the incinerator 800, while the ancillary flow lines are positioned around the side region of the incinerator 800. In this way, flow (and control fluid) may be operatively controlled between these regions in order to control / manage emissions. In some example, the greater proportion of the flow may be passed via the main flow line, whereas the ancillary flow lines comprise a lesser proportion of flow. In those examples, it may be that a greater proportion of control fluid is communicated via the ancillary flow lines. In that way, any backpressure at the flow arrangement 110 may be managed.

[0275] In this example again, image capture devices 825 are positioned relative to the incinerator 800 so at to obtain image capture data from the surface of the incinerator (e.g., temperature profiles), as well as being (optionally) positioned so as to obtain image capture data from emissions exhausting from the incinerator 800.

[0276] Here, the flow management arrangement 110 is configured control one or more (e.g., some or all) of the control flow lines 820a, 820b, 820c flowing to the incinerator 800 so as to control combustion at the incinerator. In some cases, the flow management arrangement 110 may be configured to control the flow rate of hydrocarbons flowing within a flow line, and / or may be configured to control in the introduction of control fluid within a flow line. For example, the flow management arrangement 110 may be configured to restrict or increase the flow within one or more flow lines, and / or increase / reduce the control fluid (e.g., oxidant) in particular flow lines, in order to improve combustion efficiency / destruction at the incinerator 800. In some examples, the data acquisition arrangement 120 may monitor properties of fluid flowing (e.g., from a well test site), and adjust the ongoing flow to the incinerator 800 accordingly. In further examples, the data acquisition arrangement 120 may additionally or alternatively measure properties of the burner 800, and manage the flow accordingly. For example, image capture devices 825, 830 may be configured to monitor a property (e.g., temperature) at a location of the burner 800 (e.g., an outer surface location of the incinerator), and, based on that property, modify the flow within one or more of the flow lines. This may, in turn, modify the combustion at one or more locations within the incinerator. In one example, the image capture devices 825, 830 may be configured to monitor a temperature profile at the surface of the incinerator and, responsive to observing a region of changed (reduced or increased) temperature, the flow management arrangement 110 may be configured to manage the flow accordingly (e.g., in real time), such as increasing / restricting flow at one or more flow lines 820a-820c, and / or introducing / restricting control fluid, in order to manage the combustion.

[0277] In the above examples, the flow management arrangement 110 is configured to control / manage the flow to the burner 800 or otherwise combustion location, and in some cases that may include restricting / increasing or stopping / starting flow to particular regions / flow paths at the burner 800. In other examples, as shown in Figures 12b and 12c, the system / flow management arrangement 110 may additionally or alternatively be configured to control specific properties of the combustion location itself e.g., burner 800, in order to manage emissions. For example, in some particular cases, the burner 900 (e.g., incinerator, enclosed combustor, etc.) may be controllable such that the relative position of flow path inlets and / or the effective volume of the combustion chamber is adjustable (e.g., controllably adjustable) in order to manage / control emissions at the burner.

[0278] As shown in Figure 12b and 12c, this may include controlling the location of entry of the flow paths to the burner 800 (e.g., the relative location of the inlets to the geometry of the burner). This may mean that those flow paths inlets are effectively translatable along and / or around the burner 800 geometry (e.g., movable along the height, and / or around the circumference). This may be in addition to, or as an alternative to, controlling and being selective about the flow to a plurality of inlets / flow paths at the burner 800. Figure 12d shows further example in which the combustion chamber 810 itself is controllable in order to control / manage emissions (e.g., in addition or as an alternative to controlling the flow paths). Here, the burner 800 is configured such that combustion chamber 810 has an adjustable effective volume. In Figure 12d, two or more concentric sections of the burner are configured to slidably engageable (e.g., in a similar manner to a slip joint) to as to extend and contract to control volume of the chamber 810. In other words, the section of burner 800 may extend relative to a another (e.g., fixed) section so as to adjust the overall effective volume of the burner (e.g. incinerator, combustion chamber, or the like). It will readily be appreciated that this control may be used in addition to, or as an alternative to, the control of fluid in flow lines, and / or adjustment of the position of the flow lines inlets.

[0279] While in some examples, the burner 400 may comprise multiple sections that move relative to another in order to control / adjust the effective volume, it will readily be appreciated that in other examples that need not be the case. Consider now Figure 12e, which shows a further example of a burner comprising a controllable effective volume of combustion chamber 810. Here, the combustion chamber 810 itself is translatable relative to the position of the flow path inlets (e.g., in particular the base region flow path inlet) in such a way that the effective volume (e.g., the volume within which combustion occurs) can be increased or decreased. This may occur at the combustion chamber is moved, relatively speaking up and down, with respect the flow path inlets.

[0280] In either of the examples of Figure 12d and 12e, it will be appreciated that the flow path inlets in some cases may be fixed in position, such that the combustion chamber moves relative to those fixed inlets. This may assist with pipework or the like, which may be non-flexible. Otherwise, however, some or all of the flow paths may comprise a flexible pipework or the like (e.g., extendable / retractable), which may provide for translation.

[0281] As explained, in the above examples, the data acquisition arrangement 120, 220 may be in continuous communication with the flow management arrangement 110, but in other examples, the data acquisition arrangement 120, 220 may only be in communication from time to time, for example at intervals, which may be periodic intervals (e.g., daily, weekly, yearly). In particular, the data acquisition arrangement 120 may be portable, and relocatable from site to site. In that way, a single data acquisition arrangement 120 may be configured to be usable with multiple flow management arrangements 110. Further, predictive models developed by the data acquisition system 120 for other sites / burners may be usable with the flow management arrangement (e.g., at least as a first best guess). By way of an example shown with a flare arrangement as the burner, Figure 13 shows an example of data that may be collected or used by the system 100 / data acquisition arrangement 120, 220 and which may be used as input for a predictive model (either to obtain an output, or as training data). Some or all of that data may be presented at a dashboard or the like, which may provide prompts for an operator to select (e.g., at a user interface). Otherwise, the dashboard may inform the operator of decisions being made by the system 100. This may allow the operator to observe (and potentially override) operations at site. The dashboard may also permit visual representation for reporting purposes. For example, he dashboard may provide reporting functionality including green house gas reduction, or other harmful emission reduction. Further, the data may include data associated with the flow of hydrocarbons in the flowline, such as composition (e.g., cut), hydrocarbon BTU / LVH, process data. The data may include environmental data. The data may include data associated with the combustion at the flare (e.g., derived from image data), including one or more of: flare CE, flare BTU / LHV, flare temperature, flare colour, etc., methane composition, CO2 composition, nitrogen dioxide composition, hydrogen sulphide composition, destructions and removal efficiency, etc. The data may include effective green house gas emissions at an oil and gas installation (e.g., well site). It will be appreciated that the above example may be readily adapted for use with an alternative burner, such as an incinerator.

[0282] While in the above example, specific reference has been given to managing or otherwise controlling emissions at a burner 40, 400 it will readily be appreciated that the systems and methods described need not be limited to a burner 40, 400 and some or all aspects may be used across a wider oil and gas installation. Consider now, by way of an example, Figure 14, which shows such an oil and gas installation 300 comprising three burners 40a, 40b, 40c (exemplified as flares), in a similar manner to as above. In this case, each burner 40a, 40b, 40c is associated with a particular well site or pad, and is in fluidic communication with respective flow management arrangements 110a, 110b, 110c as before. In this example, a single data acquisition arrangement 120 is in communication (or can be configured to be in communication, e.g., at different times) with each of the flow management arrangements 110a, 110b, 110c. Here, the image capture device 125 is configured to operatively move or be repositioned so as to obtain image data as above from each of the burners / flares (e.g., relocate, pan, tilt, rotate). In doing so, a single image capture device 125 may be used to collect image data to allow for control and management of emissions across each of the burners 40a, 40b, 40c.

[0283] In some examples, it will be appreciated that the data acquisition arrangement 120 may be configured to wirelessly communicate with one or more of the flow management arrangement 110a-c. Further, it will readily be appreciated that the image capture device 125 may be configured to be moved from time to time between burners 40a, 40b, 40c (e.g., periodically, such as every hour, day, week, or the like), or may continuously sweep a particular area (e.g., a region of the well installation). In some examples, the image capture device 125 may be portable and relocated at site in order to capture data. In such a way, multiple burners may be managed with minimum cost.

[0284] It will be appreciated that while combustion of hydrocarbons (e.g., using flares, or incinerators, or enclosed combustors) may provide a source of green house gas emissions at site, nevertheless there are other sources of emissions at site which may affect the overall emissions of oil and gas activity. Therefore, it may be valuable to take a holistic approach to emissions at site in order to control (e.g., minimise) emissions.

[0285] Consider now, by way of an example, Figure 15, which shows a further example of a system 400, which again comprises a data acquisition arrangement 420 as well as, in this example, a flow management arrangement 410, which can be in communication with one another. That data acquisition arrangement 420 further comprises an image capture device 425 as before (multiple of course may be provided). Here, however, while the image capture device 425 is configured to observe properties at or around a burner 40, 400 (e.g., measuring composition, combustion efficiency, etc. in order to inform the flow management arrangement 410), in this particular example, the image capture device 425 is further configured to observe (or otherwise identify) emissions from other sources at the oil and gas installation. Such an installation may be a production facility, rig or platform, or any other installation. Such other sources may include unintended emissions (e.g., leaks) at particular components 500. Those components 500 may include well test equipment (e.g., shown as 20 in Figure 1), or other aspect of the infrastructure, such a pipework, valves, etc. The system 400 may be configured to be trained at and observe particular components 500 (e.g., known or potential problem components) in a similar manner to observing a combustion location, or may be configured to sweep an area across the installation. Either way, the image capture device 425 and the data acquisition arrangement 420 may identify leaks or problems at site. In some cases, the system 400 may be configured to alert an operator or the like in order to schedule maintenance, or otherwise may be configured to take preventative action when identifying leaks or potential leaks. In other cases, the system may additionally or alternatively be used to record such emissions for reporting purposes, or other actions (e.g., using the dashboard arrangement described above). It will be appreciated that in some examples, the data acquisition system (120 e.g., including image capture device) may be used without the flow management arrangement 110. In those cases, the data acquisition arrangement be used to identify emissions from one or more burners and / or components. Collected data may be used for reporting purposes, and / or may be usable to take particular action at site.

[0286] It will be appreciated that unwanted emission (e.g., leaks) at site may not only be a potential hazard, but also may result in lost revenue, e.g., due to extended periods of downtime when problems are not identified early, and / or lost hydrocarbons. A skilled reader will readily appreciate that the simple and cost effective nature of the above described solution.

[0287] It will be apparent to those skilled in the art that various modifications and variations can be made to the disclosed facilities, systems, methods, and apparatus. Other embodiments will be apparent to those skilled in the art from consideration of the specification and practice of the disclosed systems, methods, apparatus, etc. It is intended that the specification and examples be considered as exemplary only, with a true scope being indicated by the following claims and their equivalents.

Claims

CLAIMS1. A system for monitoring emissions properties, comprising; a data acquisition arrangement configured to acquire data relating to emission properties of a gas emission, the data acquisition arrangement comprising at least a primary image capture device configured to be positioned relative to a gas emission, and configured to obtain primary image data from that gas emission, and wherein the system is configured to receive and use primary image data, together with ancillary data relating to the gas emissions obtained by the data acquisition arrangement, in order to monitor properties of that gas emission.

2. The system according to claim 1 , wherein the primary image data comprises indirect measurement data of particular properties of a gas emission being monitored, and that primary image data is used together ancillary data comprising direct measurement data of particular properties of the gas emission being monitored in order to specifically acquire data relating to emission properties of a gas emission.

3. The system according to claim 2, wherein image capture device is configured to obtain primary image data at a particular spectral band, such that the image data relates to indirect measurement of particular properties of a gas emission at that spectral band, and wherein the system is configured to use that primary image data together ancillary spectral data associated with the gas emission to determine emission properties, that ancillary spectral data comprising direct measurement data relating to particular properties of the gas emission being monitored.

4. The system according to claim 2 or 3, wherein the ancillary data comprises one or more of: laser absorption spectroscopy data, differential absorption data, such as differential absorption LiDAR data; single photo counting data, such as time correlated single photo counting data.

5. The system according to any of the claims 1 to 4, wherein the ancillary data comprises bi-spectral data or hyperspectral data comprising direct measurement data relating to particular properties of an emission being monitored.

6. The system according to claim 5, wherein the particular spectral band from the primary image data is narrower than that of the different spectral bands in the ancillary spectral data.

7. The system according to any of the claims 2 to 6, configured such that the primary image capture device obtains primary image data comprising infrared spectral band, and wherein the system is configured to use that infrared primary image data together with ancillary data comprising image data of one or more different spectral bands associated with the gas emission in order to monitor emission properties.

8. The system according to any of the claims 2 to 7, wherein the ancillary data has been obtained from image data from a different image device, having observed the gas emission.

9. The system according to claim 8, wherein the ancillary data from the different image device comprises direct measurement data usable to determine particular emissions, such as uncombusted / undestroyed organic carbons and / or carbon dioxide, and wherein the system is configured to correlate the ancillary data together with primary image data in order to determine or approximate particular emissions, using the primary image data, and optionally wherein the system is configured to develop / use a model of emission properties using direct ancillary data together with indirect primary image data, and further optionally wherein that model is usable subsequently with indirect measurement data in order to monitor properties of that gas emission.

10. The system according to any of the claims 2 to 9, wherein the system is configured to use further ancillary data associated with the gas emission in order to determine properties of the gas emission, and wherein the further ancillary data comprises environmental data and / or flow rate data.11 . The system according to any of the claims further comprising at least a secondary image capture device, wherein the primary image capture device is configured to capture primary image data associated with a gas emission at a first orientation, and the secondary image device is configured to simultaneously capture secondary image data associated with a gas emission at a second orientation, and wherein the first and second orientations differ.

12. The system according to claim 11 , wherein the system is configured to determine a corresponding particular feature in both primary and secondary image data, and to use the identified feature to determine the orientation of the first and second image devices relative to that gas emission.

13. The system according to any of the claims 11 or 12, wherein the system is configured to determine an approximate volume of a gas emission from primary and secondary image data, the volume being defined within a determined or approximated iso-region, such as aniso-surface, representing an a region of similar properties values within the primary and secondary image data.

14. The system according to claim 13, wherein the iso-region is (i) a region representing similar temperature property values, determined or approximated to have the same or similar temperature within the image data; and / or (ii) a region representing similar emission property values, such as light intensity and / or light wavelength, determined or approximated to have the same or similar emission properties within the image data15. The system according to any of the claim 13 or 14, wherein the system is configured to use a determined volume of a gas emission together with the ancillary data, such as ancillary data comprising environmental data and / or flow rate data associated with the gas emission, in order to determine properties of the gas emission.

16. The system according to any of the claims 11 to 15, wherein the system is configured to determine the orientation of the gas emission affected by environmental wind conditions from the primary and secondary image data, and the use the determined orientation together with primary and / or secondary image data in order to determine properties of the gas emission.

17. The system according to any of the claims 11 to 15, wherein the system is configured to determine the orientation of the gas emission affected by environmental wind conditions from ancillary data comprising remote vehicle image data, such as drone or satellite image data, and to use the determined orientation together with primary and / or secondary image data in order to determine properties of the gas emission.

18. The system according to any of the claims 14 to 17, wherein the system is configured to determine or approximate gas emission properties from the primary image data, and to determine or approximate gas emission properties from the secondary image data, and then to compare the determined / approximated properties from the primary image data together with the secondary image data in order to determine gas emission properties.

19. The system according to any of the claims 11 to 18, wherein the first image capture device and second image capture device are configured to communicate wirelessly, and to use location-based signals in order to determine the relative position and / or orientation of the first and second image capture devices.

20. The system according to any of the claims 14 to 19, wherein both the first and second image capture devices are fixed in relative position to one another, or where one of the imagecapture devices is movable relative to the other, such as at least one image capture device being provided with a remote vehicle, such as a drone or satellite.

21. The system according to any preceding claim, wherein the system comprises a reference image capture device configured to obtain reference image data associated with the environmental conditions in proximity of a gas emission, and wherein the system is configured to use the reference image data together with the primary image data associated with the gas emission in order to determine properties of the gas emission.

22. The system according to claim 21 , wherein system comprises a reference emitter, configured to emit a reference signal receivable by the reference image capture device, and transmittable across an environmental region associated with a gas emission, and wherein the reference signal is of the same or similar wavelength to that receivable by the primary image capture device.

23. The system according to any preceding claim wherein system is configured to use image data together with ancillary data comprising transmittance and / or absorption data associated a water curtain in order to determine emission properties of a gas emission.

24. The system according to any preceding claim, wherein the system is configured to determine one or more geometric measurements of a gas emission from image data, and to use the determined geometric measurement together with ancillary data, in order to monitor properties of that gas emission.

25. The system according to claim 24, wherein the system is configured to determine an approximate volume of a gas emission from image data, the volume being determined from the determined geometric measurement.

26. The system according to claim 24 or 25, wherein the geometric measurement is determined from an iso-region, such as an iso-surface or iso-contour, which represents a region of similar properties values within image data.

27. The system according to claim 26, wherein the system is configured to determine a distance from a particular point, such as an ignite point, of a gas emission to a determined isoregion, such as a temperature iso-region, in order to determine emission properties.

28. The system according to any preceding claims wherein monitored properties of a gas emission include one or more of: combustion efficiency; destruction and removal efficiency; green house gas emission; methane emission.

29. The system according to any preceding claim, wherein the system is configured to obtain image data comprising location data, recontructable in order to permit identification of the location of any gas emission (VR)30. The system according to any of the preceding claims, wherein the ancillary data comprises one or more of environmental data and / or flow rate data.

31. The system according to any preceding claims, wherein the gas emissions comprise a flare, incinerator, enclosed combustor, and / or a gas leak at an oil an gas installation.

32. The system according to any preceding claims, wherein the system is further configured to use model data associated with a gas emission in order to monitor properties of that gas emission.

33. The system according to claim 32, wherein the model data is selectable based on the particular emission being monitored.

34. The system according to any preceding claims, wherein the system is configured to revise model data using primary image capture data and ancillary data.

35. The system according to any preceding claim, further comprising a flow management arrangement, configured to positioned in line with a hydrocarbon flow, and upstream of a gas emission; wherein the flow management arrangement is configured to control introduction of a control fluid to that hydrocarbon flow flowing to the gas emission in order to control the emission properties.

36. The system according to claim 35, wherein the flow management arrangement is configured to use fully or partially the flow of fluids in the hydrocarbon flow in order to control introduction of a control fluid to that hydrocarbon flow flowing to the gas emission in order to control the emission properties.

37. The system according to claim 35 or 36, wherein the flow management system is configured to communicate ancillary data regarding a hydrocarbon flow to the data acquisition system for use together with image data in order to determine emission properties.

38. A system for monitoring emissions properties, comprising; a data acquisition arrangement configured to acquire data relating to emission properties of a gas emission, the data acquisition arrangement comprising at least an image capture device configured to be positioned relative to a gas emission, and configured to obtain directmeasurement data relating to a particular property of that gas emission, and wherein the system is configured to receive and use image data, together with ancillary data relating to the gas emissions obtained by the data acquisition arrangement, in order to monitor properties of that gas emission.

39. The system according to claim 38, wherein the image capture device is configured to obtain data comprises one or more of: laser absorption spectroscopy data, differential absorption data, such as differential absorption LiDAR data; single photo counting data, such as time correlated single photo counting data; bi-spectral data or hyperspectral data comprising direct measurement data relating to particular properties of an emission being monitored.

40. A data model structure for monitor properties of that gas emission, the data model structure comprising: image data obtained from monitoring a gas emission, and ancillary data relating to the gas emissions, and wherein the data model structure comprises instructions that, when executed by a system, determine properties of a gas emission using the image data and ancillary data in order to monitor properties of that gas emission41 . A method for monitoring emissions properties, comprising; obtaining primary image data from a primary image capture device configured to be positioned relative to a gas emission, and using the primary image data, together with ancillary data relating to the gas emissions, in order to monitor properties of that gas emission.

42. The method according to claim 41 , wherein the primary image data comprises indirect measurement data of particular properties of a gas emission being monitored, and the method comprises using that primary image data together with ancillary data comprising direct measurement data of particular properties associated with the gas emission being monitored.

43. The method according to claim 42, wherein the primary image data has a particular spectral band, such that the image data relates to indirect measurement of particular properties of a gas emission at that spectral band, and wherein the primary image data is used together ancillary spectral data associated with the gas emission to determine emissionproperties, that ancillary spectral data comprising direct measurement data associated with particular properties of the gas emission being monitored.

44. The method according to claim 43, wherein the ancillary data comprises one or more of: laser absorption spectroscopy data, differential absorption data, such as differential absorption LiDAR data; single photo counting data, such as time correlated single photo counting data.

45. The method according to any of the claims 41 to 44, wherein the ancillary data comprises bi-spectral data or hyperspectral data comprising direct measurement data relating to particular properties of an emission being monitored.

46. The method according to claim 45, wherein the particular spectral band from the primary image data is narrower than that of the different spectral bands in the ancillary spectral data.

47. The method according to any of the claims 42 to 46, wherein the method comprising obtaining primary image data comprising infrared spectral band, and wherein the method uses that infrared primary image data together with ancillary data comprising image data of one or more different spectral bands associated with the gas emission in order to monitor emission properties.

48. The method according to any of the claims 42 to 47, comprising obtaining the ancillary data from image data from a different image device, having observed the gas emission.

49. The method according to claim 48, wherein the ancillary data from the different image device comprises direct measurement data usable to determine particular emissions, such as uncombusted / undestroyed organic carbons and / or carbon dioxide, and wherein the method correlates the ancillary data together with primary image data in order to determine or approximate particular emissions, using the primary image data.

50. The method according to any of the claims 42 to 49, wherein the method uses further ancillary data associated with the gas emission in order to determine properties of the gas emission, and wherein the further ancillary data comprises environmental data and / or flow rate data.51 . The method according to any of the claim 41 to 50 comprising obtaining primary image data associated with a gas emission at a first orientation, and obtaining secondary image data associated with a gas emission at a second orientation, and wherein the first and second orientations differ.

52. The system according to claim 51 , wherein the method comprises determining a corresponding particular feature in both primary and secondary image data, and using the identified feature to determine the orientation of first and second image devices from which the data is obtained, relative to that gas emission.

53. The method according to any of the claims 51 or 52, wherein the method comprises determining an approximate volume of a gas emission from primary and secondary image data, the volume being defined within a determined or approximated iso-region, such as an iso-surface, representing an a region of similar properties values within the primary and secondary image data.

54. The method according to claim 53, wherein the iso-region is (i) a region representing similar temperature property values, determined or approximated to have the same or similar temperature within the image data; and / or (ii) a region representing similar emission property values, such as light intensity and / or light wavelength, determined or approximated to have the same or similar emission properties within the image data55. The method according to any of the claim 53 or 54, wherein the method uses the determined volume of a gas emission together with the ancillary data, such as ancillary data comprising environmental data and / or flow rate data associated with the gas emission, in order to determine properties of the gas emission.

56. The method according to any of the claims 51 to 55, wherein the method includes determining the orientation of the gas emission affected by environmental wind conditions from the primary and secondary image data, and using the determined orientation together with primary and / or secondary image data in order to determine properties of the gas emission.

57. The method according to any of the claims 51 to 55, wherein the method comprises determining the orientation of the gas emission affected by environmental wind conditions from ancillary data comprising remote vehicle image data, such as drone or satellite image data, and using the determined orientation together with primary and / or secondary image data in order to determine properties of the gas emission.

58. The method according to any of the claims 54 to 57, wherein the method comprises determining or approximating gas emission properties from the primary image data, and determining or approximating gas emission properties from the secondary image data, and comparing the determined / approximated properties from the primary image data together with the secondary image data in order to determine gas emission properties.

59. The method according to any of the claims 51 to 58, comprising using location-based signals to determine the relative position and / or orientation of first and second image capture devices, from which image data is obtained.

60. The method according to any of the claims 54 to 59, wherein the image data is provided from first and second image capture devices that are fixed in relative position to one another, or where one of the image capture devices is movable relative to the other, such as at least one image capture device being provided with a remote vehicle, such as a drone or satellite.61 . The method according to any of the claims 41 to 60, wherein the method comprises obtaining reference image data associated with the environmental conditions in proximity of a gas emission, and wherein the method uses the reference image data together with the primary image data associated with the gas emission in order to determine properties of the gas emission.

62. The method according to claim 61 , comprising emitting a reference signal receivable by the reference image capture device, and transmitting that signal across an environmental region associated with a gas emission, and wherein the reference signal is of the same or similar wavelength to that receivable by the primary image capture device.

63. The method according to any of the claims 41 to 62 wherein the method uses image data together with ancillary data comprising transmittance and / or absorption data associated a water curtain in order to determine emission properties of a gas emission.

64. The method according to any of the claims 41 to 63, comprising determining one or more geometric measurements of a gas emission from image data, and using the determined geometric measurement together with ancillary data, in order to monitor properties of that gas emission.

65. The method according to claim 64, wherein the method determines an approximate volume of a gas emission from image data, the volume being determined from the determined geometric measurement.

66. The method according to claim 64 or 65, wherein the geometric measurement is determined from an iso-region, such as an iso-surface or iso-contour, which represents a region of similar properties values within image data.

67. The method according to claim 66, wherein the method determines a distance from a particular point, such as an ignite point, of a gas emission to a determined iso-region, such as a temperature iso-region, in order to determine emission properties.

68. The method according to any of the claims 41 to 67 wherein monitored properties of a gas emission include one or more of: combustion efficiency; destruction and removal efficiency; green house gas emission; methane emission.

69. The system according to any of the claims 41 to 68, wherein the method obtains image data comprising location data, recontructable in order to permit identification of the location of any gas emission (VR)70. The method according to any of the claims 41 to 69, wherein the ancillary data comprises one or more of environmental data and / or flow rate data.71 . The method according to any the claims 41 to 70, wherein the gas emissions comprise a flare, incinerator, enclosed combustor, or a gas leak at an oil an gas installation.

72. The method according to any of the claims 41 to 71 , wherein the method further uses model data associated with a gas emission in order to monitor properties of that gas emission.

73. The method according to claim 72, wherein comprising selecting the model data based on the particular emission being monitored.

74. The method according to any preceding claims, wherein the method comprises revises model data using primary image capture data and ancillary data.

75. The method according to any of the claims 41 to 74, further comprising controlling introduction of a control fluid to hydrocarbon flow, upstream of a gas emission, and flowing to the gas emission in order to control the emission properties.

76. The method according to claim 75, comprising fully or partially using the flow of fluids in the hydrocarbon flow in order to control introduction of a control fluid to that hydrocarbon flow flowing to the gas emission in order to control the emission properties77. The method according to claim 75 or 76, wherein ancillary data regarding the hydrocarbon flow is communicated for use together with image data in order to determine emission properties.

78. A method for monitoring emissions properties, comprising; obtaining image data relating to emission properties of a gas emission, the image data having direct measurement data relating to a particular property of that gas emission, andreceiving and using the image data, together with ancillary data relating to the gas emissions, in order to monitor properties of that gas emission.

79. The method according to claim 78, wherein the image data comprises one or more of: laser absorption spectroscopy data, differential absorption data, such as differential absorption LiDAR data; single photo counting data, such as time correlated single photo counting data; bi-spectral data or hyperspectral data comprising direct measurement data relating to particular properties of an emission being monitored.

80. A system according to any of the claims 1 to 39, further comprising a burner, such as an incinerator, and wherein the burner comprises a combustion chamber having an effective volume within which combustion occurs, and a one or more flow path inlets configured to introduce fluids to the combustion chamber, and wherein the burner is configured such that the relative position of the flow path inlets and / or the effective volume of the combustion chamber is controllably adjustable in order to manage / control emissions at the burner.81 A computer program, such as a computer program product, comprising instructions that, when executed on a system, are configured to provide the method of any of the claims 41 to 79.81 . A non-transitory computer program product, provided on a computer readable medium, and comprising instructions that, when executed on a system, are configured to provide the method of any of the claims 41 to 79.

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