[go: up one dir, main page]

WO2024137906A1 - Pointe de torche réglable - Google Patents

Pointe de torche réglable Download PDF

Info

Publication number
WO2024137906A1
WO2024137906A1 PCT/US2023/085292 US2023085292W WO2024137906A1 WO 2024137906 A1 WO2024137906 A1 WO 2024137906A1 US 2023085292 W US2023085292 W US 2023085292W WO 2024137906 A1 WO2024137906 A1 WO 2024137906A1
Authority
WO
WIPO (PCT)
Prior art keywords
adjustable
flare tip
data
actuator
control instructions
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Ceased
Application number
PCT/US2023/085292
Other languages
English (en)
Inventor
Hugues Trifol
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Schlumberger Canada Ltd
Services Petroliers Schlumberger SA
Schlumberger Technology BV
Schlumberger Technology Corp
Original Assignee
Schlumberger Canada Ltd
Services Petroliers Schlumberger SA
Schlumberger Technology BV
Schlumberger Technology Corp
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Schlumberger Canada Ltd, Services Petroliers Schlumberger SA, Schlumberger Technology BV, Schlumberger Technology Corp filed Critical Schlumberger Canada Ltd
Publication of WO2024137906A1 publication Critical patent/WO2024137906A1/fr
Anticipated expiration legal-status Critical
Ceased legal-status Critical Current

Links

Classifications

    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23G—CREMATION FURNACES; CONSUMING WASTE PRODUCTS BY COMBUSTION
    • F23G7/00—Incinerators or other apparatus for consuming industrial waste, e.g. chemicals
    • F23G7/06—Incinerators or other apparatus for consuming industrial waste, e.g. chemicals of waste gases or noxious gases, e.g. exhaust gases
    • F23G7/08—Incinerators or other apparatus for consuming industrial waste, e.g. chemicals of waste gases or noxious gases, e.g. exhaust gases using flares, e.g. in stacks
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B41/00—Equipment or details not covered by groups E21B15/00 - E21B40/00
    • E21B41/005—Waste disposal systems
    • E21B41/0071—Adaptation of flares, e.g. arrangements of flares in offshore installations
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/34—Arrangements for separating materials produced by the well
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23G—CREMATION FURNACES; CONSUMING WASTE PRODUCTS BY COMBUSTION
    • F23G5/00—Incineration of waste; Incinerator constructions; Details, accessories or control therefor
    • F23G5/50—Control or safety arrangements
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23N—REGULATING OR CONTROLLING COMBUSTION
    • F23N5/00—Systems for controlling combustion
    • F23N5/02—Systems for controlling combustion using devices responsive to thermal changes or to thermal expansion of a medium
    • F23N5/08—Systems for controlling combustion using devices responsive to thermal changes or to thermal expansion of a medium using light-sensitive elements
    • F23N5/082—Systems for controlling combustion using devices responsive to thermal changes or to thermal expansion of a medium using light-sensitive elements using electronic means
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23N—REGULATING OR CONTROLLING COMBUSTION
    • F23N2229/00—Flame sensors
    • F23N2229/20—Camera viewing

Definitions

  • Combustion of hydrocarbon can result various types of emissions, which can include, for example, visible emission, heat energy emission, and smoke.
  • Burner operations e.g., flaring
  • air supply adjustment which may aim to maintain acceptable combustion through variations in fluid properties, flowrates, and weather conditions.
  • a system can include an adjustable flare tip that includes an actuator; an adjustable throat restrictor operatively coupled to the actuator; and an interface for receipt of control instructions, where the actuator responds to the control instructions to adjust the throat restrictor; and a controller that generates the control instructions.
  • FIG. 1 is a series of diagrams of example environments and an example of a burner system.
  • FIG. 2 is a diagram of an example of a burner system.
  • FIG. 3 is a diagram of an example of a burner boom.
  • FIG. 4 is a diagram of an example of a burner system.
  • FIG. 5 is a series of example images and an example graphical user interface.
  • FIG. 6 is a diagram of an example of a system.
  • FIG. 7 is a diagram of an example of an adjustable flare tip mechanism.
  • FIG. 8 is a diagram of examples of adjustable flare tip mechanisms.
  • FIG. 9 is a diagram of examples of adjustable flare tip mechanisms.
  • FIG. 10 is a diagram of an example of a method and an example of a system.
  • FIG. 11 illustrates example components of a system and a networked system.
  • Methane (CH4) is a hydrocarbon that can be classified as an anthropogenic greenhouse gas (GHG) in the atmosphere (e.g., consider carbon dioxide as another type of greenhouse gas).
  • GFG anthropogenic greenhouse gas
  • Satellite data can provide a coarse indicator of potential methane leaks through direct atmospheric methane concentration readings.
  • a couple of public satellites circle the earth every 24 hours and can monitor methane emissions and detect fires.
  • Various satellites can circle the Earth multiple times per day (e.g., consider 2 to 14 times or more).
  • Various satellites have relatively large apertures such that they can observe the entire surface of the Earth (e.g., every day, etc.).
  • resolution some have resolutions that range from approximately 750 m x 750 m (0.56 km 2 ) to 7 km x 7 km (49 km 2 ).
  • Some satellites have finer resolutions, for example, consider the Sentinel 2P satellite with a resolution of approximately 20 m x 20 m (e.g., 400 m 2 ).
  • a cost-effective system can monitor flares in a relatively continuous manner to identify when flares have gone out (e.g., become unlit) and, for example, detect unusual atmospheric methane concentrations and alert when issues are found so appropriate actions can be triggered.
  • an automatic system can detect unlit flares using geospatial data from multiple sources and issue one or more types of signals, for example, when an issue or issues are detected. As explained, such an issue or issues can pertain to an emissions strategy for one or more sites. The issuance of one or more types of signals can provide notifications to take corrective action or control instructions to control equipment to take corrective action.
  • each of the environments 101 can include one or more wellheads 106 (e.g., wellhead equipment).
  • a wellhead can be a surface termination of a wellbore that can include a system of spools, valves and assorted adapters that, for example, can provide for pressure control of a production well.
  • a wellhead may be at a land surface, a subsea surface (e.g., an ocean bottom, etc.), etc.
  • conduits from multiple wellheads may be joined at one or more manifolds such that fluid from multiple wells can be flow in a common conduit.
  • a well may be tested using a process referred to as well testing.
  • well testing reservoir fluids can be produced at a separator at varying rates, for example, according to a predetermined schedule. Such tests may take less than two days to evaluate a single well or may take months to evaluate reservoir extent. As such, flaring, which may depend on test type, etc., may occur over a period of a day or less or more than a month.
  • Well testing can include one or more of a variety of well testing operations where tests may include, for example, one or more of buildup, drawdown, falloff, injection and interference.
  • fluid can flow from a well or wells to surface where the fluid is subjected to one or more well testing operations and generates scrap (e.g., waste fluid), which must be handled appropriately, for example, according to circumstances, regulations, etc.
  • scrap e.g., waste fluid
  • Another manner of handling waste fluid can be through combustion, which can be referred to as burning.
  • burning can be part of a well testing process, whether burning is for handling waste fluid and/or for analyzing one or more aspects of how one or more waste fluids bum.
  • burning may optionally provide data as to one or more characteristics of well fluid (e.g., a component thereof, etc.).
  • disposal of produced hydrocarbons during one or more types of operations may be via burning, which can include on-site burning and/or offsite burning. Burning can be particularly suitable when facilities are not available for storage (e.g., consider mobile offshore drilling rigs, remote locations onshore, etc.).
  • Burning can be particularly suitable when facilities are not available for storage (e.g., consider mobile offshore drilling rigs, remote locations onshore, etc.).
  • FIG. 1 consider well testing as an operation that may be performed, for example, using equipment shown in the marine environment 102 and/or using equipment shown in the land environment 104.
  • an environment may be under exploration, development, appraisal, etc., where such an environment includes at least one well where well fluid can be produced (e.g., via natural pressure, via fracturing, via artificial lift, via pumping, via flooding, etc.).
  • various types of equipment may be on-site, which may be operatively coupled to well testing equipment.
  • FIG. 1 shows an example of a system 110 that can be operatively coupled to one or more conduits that can transport well fluid, for example, from one or more wellheads.
  • the system 110 can include a computational system 111 (CS), which can include one or more processors 112, a memory 114 accessible to at least one of the one or more processors 112, instructions 116 that can be stored in the memory 114 and executable by at least one of the one or more processors 112, and one or more interfaces 118 (e.g., wired, wireless, etc.).
  • CS computational system 111
  • FIG. 1 shows an example of a system 110 that can be operatively coupled to one or more conduits that can transport well fluid, for example, from one or more wellheads.
  • the system 110 can include a computational system 111 (CS), which can include one or more processors 112, a memory 114 accessible to at least one of the one or more processors 112, instructions 116 that can be stored in the memory 114 and executable by at least one of the one
  • the system 110 is shown as including various communication symbols, which may be for transmission and/or reception of information (e.g., data, commands, etc.), for example, to and/or from the computational system 111.
  • the computational system 111 can be a controller that can issue control instructions to one or more pieces of equipment in an environment such as, for example, the marine environment 102 and/or the land environment 104.
  • the computational system 111 may be local, may be remote or may be distributed such that it is in part local and in part remote.
  • the wellhead 106 can include various types of wellhead equipment such as, for example, casing and tubing heads, a production tree, a blowout preventer, etc. Fluid produced from a well can be routed through the wellhead 106 and into the system 110, which can be configured with various features for well testing operations.
  • wellhead equipment such as, for example, casing and tubing heads, a production tree, a blowout preventer, etc.
  • Fluid produced from a well can be routed through the wellhead 106 and into the system 110, which can be configured with various features for well testing operations.
  • the system 110 is shown to include various segments, which may be categorized operationally. For example, consider a well control segment 120, a separation segment 122, a fluid management segment 124, and a burning segment 126.
  • the well control segment 120 is an assembly of various components such as a manifold 130, a choke manifold 132, a manifold 134, a heat exchanger 136 and a meter 138;
  • the separation segment 122 includes a separator 142;
  • the fluid management segment 124 is an assembly of various components such as manifolds and pumps 144, a manifold 146-1 , a manifold 146-2, a tank 148-1 and a tank 148-2;
  • the burning segment 126 includes a burner 152 and one or more cameras 154.
  • the system 110 includes various features for one or more aspects of well testing operations; noting that the system 110 may include lesser features, more features, alternative features, etc.
  • the system 110 may include lesser features, more features, alternative features, etc.
  • a gas specific gravity meter a water-cut meter, a gas-to-oil ratio sensor, a carbon dioxide sensor, a hydrogen sulfide sensor, or a shrinkage measurement device.
  • Various features may be upstream and/or downstream of a separator segment or a separator.
  • the well control segment 120 With respect to flow of fluid from a well or wells, such fluid may be received by the well control segment 120 and then routed via one or more conduits to the separation segment 122.
  • the well control segment 120 the heat exchanger 136 may be provided as a steam-heat exchanger and the meter 138 for measuring flow of fluid through the well control segment 120.
  • the well control segment 120 can convey fluid received from one or more wells to the separator 142.
  • the separator 142 can be a horizontal separator or a vertical separator, and can be a two-phase separator (e.g., for separating gas and liquids) or a three-phase separator (e.g., for separating gas, oil, and water).
  • a separator may include various features for facilitating separation of components of incoming fluid (e.g., diffusers, mist extractors, vanes, baffles, precipitators, etc.).
  • fluid can be single phase or multiphase fluid where “phase” refers to an immiscible component (e.g., consider two or more of oil, water, and gas).
  • the separator 142 can be used to substantially separate multiphase fluid into its oil, gas, and water phases, as appropriate and as present, where each phase emerging from the separator 142 may be referred to as a separated fluid.
  • Such separated fluids may be routed away from the separator 142 to the fluid management segment 124.
  • the separated fluids may not be entirely homogenous.
  • separated gas exiting the separator 142 can include some residual amount of water or oil and separated water exiting the separator 142 can include some amount of oil or entrained gas.
  • separated oil leaving the separator 142 can include some amount of water or entrained gas.
  • the fluid management segment 124 includes flow control equipment, such as various manifolds and pumps (generally represented by the block 144) for receiving fluids from the separator 142 and conveying the fluids to other destinations, as well as additional manifolds 146-1 and 146-2 for routing fluid to and from fluid tanks 148-1 and 148-2. While two manifolds 146-1 and 146-2 and two tanks 148-1 and 148-2 are depicted in FIG. 1 , it is noted that the number of manifolds and tanks can be varied.
  • the fluid management segment 124 can include a single manifold and a single tank, while in other embodiments, the fluid management segment 124 can include more than two manifolds and more than two tanks.
  • the manifolds and pumps 144 can include a variety of manifolds and pumps, such as a gas manifold, an oil manifold, an oil transfer pump, a water manifold, and a water transfer pump.
  • the manifolds and pumps 144 can be used to route fluids received from the separator 142 to one or more of the fluid tanks 148-1 and 148-2 via one or more of the additional manifolds 146-1 and 146-2, and to route fluids between the tanks 148-1 and 148-2.
  • the manifolds and pumps 144 can include features for routing fluids received from the separator 142 directly to the one or more burners 152 for burning gas and oil (e.g., bypassing the tanks 148-1 and 148-2) or for routing fluids from one or more of the tanks 148-1 and 148-2 to the one or more burners 152.
  • components of the system 110 may vary between different applications (e.g., operations, etc.).
  • equipment within each functional group of the system 110 may also vary.
  • the heat exchanger 136 could be provided as part of the separation segment 122, rather than of the well control segment 120.
  • the system 110 can be a surface well testing system that can be monitored and controlled remotely. Remote monitoring may be effectuated with sensors installed on various components.
  • a monitoring system e.g., sensors, communication systems, and human-machine interfaces
  • the one or more cameras 154 can be used to monitor one or more burning operations of the one or more burners 152, which may aim to facilitate control of such one or more burning operations at least in part through analysis of image data acquired by at least one of the one or more cameras 154.
  • FIG. 2 shows an example of a system 250, which may be referred to as a surface well testing system.
  • the system 250 can include various features of the system 110 of FIG. 1.
  • Various equipment of the system 250 such as flaring equipment, may be present at one or more types of sites (e.g., production sites, well testing sites, etc.).
  • a multiphase fluid (represented here by arrow 252) enters a flowhead 254 and is routed to a separator 270 through a surface safety valve 256, a steam-heat exchanger 260, a choke manifold 262, a flow meter 264, and an additional manifold 266.
  • the system 250 includes a chemical injection pump 258 for injecting chemicals into the multiphase fluid flowing toward the separator 270.
  • the separator 270 is a three-phase separator that generally separates the multiphase fluid 252 into gas, oil, and water components.
  • the separated gas is routed downstream from the separator 270 through a gas manifold 274 to either of the burners 276-1 and 276-2 for flaring gas and burning oil.
  • the gas manifold 274 includes valves that can be actuated to control flow of gas from the gas manifold 274 to one or the other of the burners 276-1 and 276-2.
  • the burners 276-1 and 276-2 may be positioned apart from one another, such as on opposite sides of a rig, etc.
  • the separated oil from the separator 270 can be routed downstream to an oil manifold 280.
  • Valves of the oil manifold 280 can be operated to permit flow of the oil to either of the burners 276-1 and 276-2 or either of the tanks 282 and 284.
  • the tanks 282 and 284 can be of a suitable form, but are depicted in FIG. 2 as vertical surge tanks each having two fluid compartments. This allows each tank to simultaneously hold different fluids, such as water in one compartment and oil in the other compartment.
  • An oil transfer pump 286 may be operated to pump oil through the well testing system 250 downstream of the separator 270.
  • the separated water from the separator 270 can be similarly routed to a water manifold 290.
  • the water manifold 290 includes valves that can be opened or closed to permit water to flow to either of the tanks 282 and 284 or to a water treatment and disposal apparatus 294.
  • a water transfer pump 292 may be used to pump the water through the system.
  • a well test area in which the well testing system 250 (or other embodiments of a well testing system) is installed may be classified as a hazardous area.
  • the well test area is classified as a Zone 1 hazardous area according to International Electrotechnical Commission (IEC) standard 60079- 10-1 :2015.
  • IEC International Electrotechnical Commission
  • a cabin 296 at a wellsite may include various types of equipment to acquire data from the well testing system 250. These acquired data may be used to monitor and control the well testing system 250.
  • the cabin 296 can be set apart from the well test area having the well testing system 250 in a non-hazardous area. This is represented by the dashed line 298 in FIG. 2, which generally serves as a demarcation between the hazardous area having the well testing system 250 and the non-hazardous area of the cabin 296.
  • the equipment of a system can be monitored during a process to verify proper operation and facilitate control of the process.
  • Such monitoring can include taking numerous measurements, examples of which can include choke manifold temperature and pressures (upstream and downstream), heat exchanger temperature and pressure, separator temperature and pressures (static and differential), oil flow rate and volume from the separator, water flow rate and volume from the separator, and fluid levels in tanks of a system.
  • a mobile monitoring system may be provided.
  • monitoring of a process can be performed on a mobile device (e.g., a mobile device suitable for use in Zone 1 hazardous area, like the well test area).
  • a mobile device e.g., a mobile device suitable for use in Zone 1 hazardous area, like the well test area.
  • Various types of information may be automatically acquired by sensors and then presented to an operator via the mobile device.
  • the mobile monitoring system may provide various functions, such as a sensor data display, video display, sensor or video information interpretation for quality-assurance and quality-control purposes, and a manual entry screen (e.g., for a digital tally book for recording measurements taken by the operator).
  • FIG. 3 shows an example of a burner boom 300, which can be configured for horizontal mounting, mounting at an angle, vertical mounting, etc.
  • the burner boom 300 can be mounted on a rig with a rotating base plate and guy lines.
  • horizontal guy lines can help to orient the burner boom 300;
  • vertical guy lines which are fixed to the rig’s main structure, can support the burner boom 300.
  • a rotating base can enable horizontal and vertical positioning of the burner boom 300 and its burner.
  • the burner boom 300 may be positioned slightly above horizontal so that oil left in piping after flaring operations does not leak out.
  • Flaring equipment such as the burner boom 300 may be present at one or more types of sites (e.g., production sites, well testing sites, etc.) to provide for flaring operations.
  • a burner can be boom mounted or mounted on another type of support structure.
  • a structure can support various conduits that provide fluid such as, for example, one or more of air, water, oil, and propane.
  • conduits or lines include an additional gas line 310, pilot line cables 320, an oil line 330, a water line 340, a water wall screen line 350, an air line 360, and a main gas line 370.
  • a burner boom 300 of FIG. 3 its burner can be configured and controlled to perform in a desirable manner. For example, it may be desired to bum in a fallout-free and smokeless manner for combustion of liquid hydrocarbons produced during well testing.
  • a burner geometry can utilize pneumatic atomization and enhanced air induction.
  • a burner can be equipped with one or more pilots, a flame-front ignition system (BRFI), and a built-in water screen to reduce heat radiation.
  • BRFI flame-front ignition system
  • a burner can be fitted with an automatic shutoff valve that prevents oil spillage at the beginning and end of a burning run.
  • a burner can include a high turn-down feature (e.g., 1 :5), which may be optionally further extended to a higher ratio (e.g., 1 :30) using a multirate kit (BMRK) option, which allows for selecting the number of operating nozzles.
  • BMRK multirate kit
  • a skid may be utilized for skid-mounting.
  • a burner may be suited for high efficiency burning with one or more types of oil (e.g., including particularly heavy and waxy oils).
  • a burner may operate effectively up to a water cut rating (e.g., up to 25 percent water cut), which may be desirable for various types of cleanup operations.
  • a burner may be operational in a manner that provides for substantially no liquid fallout and substantially no visible smoke emissions, such a burner may be particularly suited for operations in environmentally sensitive areas.
  • FIG. 4 is a system diagram of an example of a burner control system 400.
  • the system 400 includes at least one camera 407-1 and 407-2 positioned to capture one or more images 402-1 and 402-2 of a flare emitted by a burner 401 .
  • two cameras 407-1 and 407-2 are shown capturing images 402-1 and 402-2 from different locations to acquire image data from more than one image plane of the flare.
  • the burner 401 includes a fuel feed 403 that flows fuel to the burner 401 (see, e.g., the burners 276-1 and 276-2 of FIG. 2, the burner 300 of FIG. 3, etc.).
  • the burner 401 also includes an air feed 405 that flows air to the burner 401 .
  • Flow rate of the air feed 405 is controlled by a control valve 408, where an air flow sensor 411 senses flow rate of air into the burner 401 .
  • a fuel flow sensor 413 senses flow rate of fuel to the burner 401.
  • Other sensors 404, along with the at least one camera 407-1 and 407-2, are operatively coupled to local electronic equipment 420.
  • the sensors 404 may sense, and produce signals representing, combustion effective parameters such as temperature, wind speed, and ambient humidity.
  • the sensors 404, 411 , and 413, and the cameras 407-1 and 407-2 send data, including data representing the images 402-1 and 402-2, along with data representing readings of the sensors 404, 411 , and 413, directly and/or indirectly, to the local electronic equipment 420, which may be present at a wellsite in a production phase and/or a drilling phase (e.g., in a doghouse, a cabin, etc.).
  • the data sent to the local electronic equipment 420 can represent a state of combustion taking place at the burner 401 .
  • the local electronic equipment 420 can be in communication with remote electronic equipment 440.
  • remote electronic equipment 440 For example, consider use of one or more wired and/or wireless interfaces that allow for communications between the local and remote electronic equipment 420 and 440.
  • various computational tasks may be executed locally and/or remotely.
  • a local computing device that can include an application that can render a graphical user interface (GUI) to a display.
  • GUI graphical user interface
  • the GUI can include control graphics that are selectable to issue instructions such as, for example, one or more application programming interface (API) calls, which may be directed to the local electronic equipment 420, the remote electronic equipment 440, etc., to cause one or more actions to occur such as formulation of a response to an API call.
  • API application programming interface
  • the local and remote electronic equipment 420 and 440 may be configured in a client-server arrangement where the local electronic equipment 420 operates as a client and the remote electronic equipment 440 operates as a server.
  • data acquired by the local electronic equipment 410 e.g., as part of the system 400
  • the remote electronic equipment 440 can include one or more cloud-based resources.
  • the remote electronic equipment 440 may provide services such as, for example, software as a service.
  • control effectuated by the system 400 to control the burner 401 can be based on local and/or remote computing (e.g., using the local electronic equipment 420, the remote electronic equipment 440, etc.).
  • a model can be used, which may be a physicsbased model, a machine learning model, a hybrid model, etc.
  • a modelbased approach can allow for prediction of various parameters such as, for example, air control parameters based on the data from the sensors 404, 411 , and 413 and the at least one of the one or more cameras 407-1 and 407-2.
  • one or more air control parameters can be applied to the control valve 408 to control air supply to the burner 401 , which can be part of a combustion process that generates a flare that can be captured, as depicted in the one or more images 402-1 and 402-2.
  • Camera means an imaging device.
  • a camera can capture an image of electromagnetic (EM) radiation in a medium that can be converted to data for use in digital processing. The conversion can take place within the camera or in a separate processor.
  • the camera may capture images in one wavelength or across a spectrum (e.g., or spectra), which may encompass the ultraviolet (UV) spectrum, the visible spectrum, and/or the infrared spectrum. For example, a camera may capture an image of wavelengths from approximately 350 nm to approximately 1 ,500 nm.
  • a broad spectrum imaging device such as a LIDAR detector
  • a narrower spectrum detector such as a charged-coupled device (CCD) array
  • a short-wave infrared detector can be used as an imaging device or as imaging devices.
  • Cameras can be monovision cameras or stereo cameras.
  • the local electronic equipment 420 is shown as including an image processing unit 410, which may include and/or be operatively coupled to a model or models for purposes of processing one or more of the images 402-1 and 402-2 as captured by the at least one camera 407-1 and 407-2.
  • a data set along with sensor data representing oil flow rate, gas flow rate, water or steam flow rate, air flow rate, pressure, temperature, wind speed, ambient humidity, and other combustion effective parameters, can be considered different types of inputs.
  • a model can receive input or inputs and can output one or more air control parameters, such as flow rate, pressure, and/or temperature, for the burner 401 (e.g., or burners) controlled by the system 400.
  • a machine learning model such a model can be a neural network model (NN model).
  • NN model neural network model
  • a trained ML model can be utilized to control one or more burners.
  • a trained ML model can be trained with respect to a particular burner and/or type of burner. In such an approach, a trained ML model can be selected based at least in part on burner specifications (e.g., manufacturer, model, features, history, etc.).
  • Various types of data may be acquired and optionally stored, which may provide for training one or more ML models and/or for offline analysis, etc.
  • air control parameters output by a trained NN model can be stored in digital storage for later analysis, which may include further training, training a different ML model, etc.
  • one or more air control parameters can be transmitted to one or more control valves that control air supply to one or more burners as may be operatively coupled to the system controlled by the control system.
  • Subsequent images and sensor data acquisitions can be captured, and the control cycle repeated as many times as desired. Frequency of repetition can depend on various time constants of the system 400.
  • a cycle may be as short as a fraction of a second or as long as five to ten minutes.
  • a 1 Hz operational frequency where several images are captured in a one second interval as in a video feed where computing air control parameters and applying the computed air control parameters to a control valve controlling air supply to the burner are based on the images in the one second interval.
  • video may be live, with some amount of latency due to transmission and processing time, or video may be deliberately delayed by a delay amount.
  • the image processing unit 410 can convert signals derived from photons received by the one or more cameras 407-1 and 407-2 into data.
  • the image processing unit 410 may be within or separate from a camera.
  • the image processing unit 410 can convert signals received from the one or more cameras 407-1 and 407-2 into digital data representing photointensity in defined areas of the image and can assign position information to each digital data value.
  • photointensity may be deconvolved into constituent wavelengths to produce a spectrum for each pixel. Such a spectrum may be sampled in defined bins, and the data from such sampling structured into a data set representing spectral intensity of the received image, for example, as a function of x-y position in the image.
  • a timestamp can be added.
  • camera circuitry can include a digital clock and/or network circuitry that can receive a clock signal.
  • an image can be a pixel image with pixel position coordinate, a pixel depth and a timestamp.
  • depth various conventions may be utilized and depend on equipment and/or processing. Where color is utilized, a color depth can be referenced.
  • Standards can include, for example, monochrome (e.g., 1 -bit) to 4K (e.g., 12-bit color, which provides 4096 colors), etc.
  • a method for assessing imagery can include accessing one or more resources as to color models (e.g., as a plug-in, external executable code, etc.). For example, consider a method that includes instructions to access an algorithm of a package, a computing environment, etc., such as, for example, the MATLAB computing environment (marketed by MathWorks, Inc., Natick, MA).
  • the MATLAB computing environment includes an image processing toolbox, for example, with algorithms for color space (e.g., color model) conversions, transforms, etc.
  • the MATLAB computing environment includes functions “rgb2hsv” and “hsv2rgb” to convert images between the RGB and HSV color spaces (see, e.g., http://www.mathworks.com/help/irnages/converting-color-data-between-color- spaces.html).
  • a model may be a simulated version of an environment, which may include one or more sites of possible emissions.
  • a simulator may include features for simulating physical phenomena in an environment based at least in part on a model or models.
  • a simulator such as a weather simulator, can simulate fluid flow in an environment based at least in part on a model that can be generated via a framework that receives satellite data.
  • a simulator can be a computerized system (e.g., a computing system) that can execute instructions using one or more processors to solve a system of equations that describe physical phenomena subject to various constraints.
  • the system of equations may be spatially defined (e.g., numerically discretized) according to a spatial model (e.g., of the Earth, the atmosphere, the oceans, etc.).
  • a system can monitor flares from space and detect when flares are unlit by fusing geospatial data from multiple sources and alerting when issues are detected.
  • an alert may be issued via a network interface to one or more destinations, which may include workstations, controllers, etc.
  • destinations which may include workstations, controllers, etc.
  • VIPS Visible Infrared Imaging Radiometer Suite
  • the TROPOspheric Monitoring Instrument (TROPOMI) sensor which is onboard on the Sentinel 5P Precursor satellite, from the European Space Agency (ESA) uses a short-wave infrared radiation sensor can measure methane concentrations on columns with a base area of 7 x 3.5 km 2 .
  • ESA European Space Agency
  • SLSTR Sea and Land Surface Temperature Radiometer
  • the Sentinel 2 satellite which, as mentioned, has a resolution as fine as 20 m x 20 m.
  • the VIIRS sensor provides for observation of gas flaring. At night, the VIIRS sensor records data in three near- to short-wave infrared channels (NIR and SWIR) designed for daytime imaging. With sunlight eliminated (e.g., night time), features detected in these three channels include combustion sources.
  • the shortwave IR channel at 1 .61 pm, is at a wavelength at, or proximate to, peak radiant emissions from gas flares.
  • the 4-pm channel widely used in satellite fire detection, detects large flares due to the fact that it falls on the trailing edge of gas flare radiant emissions and observes a mixture of flare plus background radiant emissions.
  • flare radiant emissions in the 4-pm channel are about a third of the emissions at 1.65 pm, which limits detection of smaller flares in standard satellite fire products based on channels set at the 4 pm wavelength.
  • a method can include accessing satellite data as raw data and/or as processed data.
  • processed satellite data as to radiant heat and/or flow rate measurements can be received, which may be associated with flares (e.g., identified and/or not identified in the processed satellite data).
  • images from satellites, environmental data from weather stations, and high frequency satellite imagery can be fed to a system and processed to identify unlit flares.
  • FIG. 5 shows example imagery 510 and imagery with a graphical user interface 530.
  • the imagery 510 shows a combination of TROPOMI and flares from VIIRS satellite data for a region of Amsterdam.
  • the imagery 510 shows methane mixing ratio on the grid where the markers indicate detected flares.
  • the flares are sized based on amount of radiant heat that is output.
  • imagery and GUI 530 it shows some testing related operations in Norway based on an event where a flare had gone off where the lower portion is an alternative or additional way to render VIIRS and TROPOMI data.
  • imagery can provide data as to one or more types of flares for one or more types of flaring operations (e.g., production, well testing, etc.).
  • High levels of gas flaring can present various types of issues for producers of hydrocarbons, which can include environmental issues, human safety issues, regulatory issues, etc.
  • CBAM carbon border adjustment mechanism
  • EU European Union
  • CBAM carbon border adjustment mechanism
  • Such regulations may impact a region such as Amsterdam which, in 2020, exported 35 percent (approximately 364,000 b/d) of its total crude oil production to the EU.
  • FIG. 6 shows an example of a workflow diagram 600.
  • various sources of data 620, 640, 660 and 680 are shown, for example, consider VIIRS source data, Sentinel 5P source data, Sentinel 3 source data and weather data, noting that one or more alternative and/or additional types of source data may be included.
  • VIIRS source data For example, consider one or more of local site data, local control data, solar wind data, etc.
  • various data can be fused using a method 610.
  • the system 600 can include a weather data source or sources 680.
  • weather variables information e.g., wind speed, direction, cloud cover, etc.
  • Such information can be utilized in a weather data spatial and/or temporal analysis, which may, for example, provide for aggregating weather data on a temporal basis and/or spatial basis.
  • data may be joined per a join block 611 where such data, or a portion thereof, can be utilized to train one or more machine learning (ML) models per a train block 612, which may provide output as to wind control per a wind control block 613.
  • ML machine learning
  • a trained ML model can predict how to control flaring for particular wind conditions, which can be for a particular location.
  • the method 610 can evaluate a wind control output per an evaluation block 614. For example, consider using a digital twin (e.g., an avatar) of a flaring site where the digital twin can be subject to wind conditions and the wind control to determine if a result is favorable or unfavorable. In such an example, the method 610 may proceed to implement the wind control per a control block 616, for example, where the evaluation is favorable (e.g., or optionally neutral).
  • the evaluation is favorable (e.g., or optionally neutral).
  • the system 600 can include features for evaluation of regional flare metrics, continuous and/or intermittent behaviors, flare presence or absence, etc.; can include features for evaluation of methane mixing ratio signals; can include features for evaluation of flare classification; and can include features for evaluation of weather variables.
  • the VIIRS sensor which exists on the NOAA-20 satellite, can be used for detecting and characterizing combustion sources.
  • the TROPOMI sensor which is onboard on the Sentinel 5P Precursor satellite, from the European Space Agency using a short-wave infrared radiation sensor can measure methane concentrations on columns with a base area of 7 x 3.5 km 2 .
  • the Sentinel 3 satellite with the Sea and Land Surface Temperature Radiometer (SLSTR) instrument from the European Space Agency may also be used to measure gas flares and give confidence to the VIIRS sensor.
  • SLSTR Sea and Land Surface Temperature Radiometer
  • various emission sources may be located using such weather data, for example, by analyzing plume sources, plume shapes and wind conditions (speed and direction).
  • satellite imagery e.g., day time and/or night time
  • a method can include utilizing a trained machine learning model to identify sites in one or more images for a region imaged.
  • pattern-based identification e.g., pattern recognition
  • lit flares can define a pattern, which may change over time due to wind conditions.
  • the system 600 can provide for flaring optimization in unfavorable wind conditions.
  • Such a system may provide for control of flaring during testing operations, bleed off and flowback operations, one or more other onshore and/or offshore operations involving gas flaring, etc.
  • a control action can provide for configuring gas flaring for onshore and/or offshore facilities with unfavorable wind conditions.
  • a system can provide for performing process computations, computational fluid dynamics (CFD) and dispersion studies, monitoring and acquisition and automation.
  • CFD computational fluid dynamics
  • a defined flare sizing and configuration can be determined and/or controlled that can be utilized onshore and/or offshore to optimize the dispersion of combustion gases and mitigate the associated risks. Where determinations can be made in real-time or near real-time, actions may be taken more rapidly, which may reduce detrimental aspects of non-optimal flaring. As an example, a system can reduce lost time and emissions when the wind conditions are unfavorable. Such a system can help to achieve proper dispersion of combustion gases.
  • a system can utilize multiple flare tip sizes at defined angles to achieve efficient dispersion of combustion gases under various wind conditions, which can include a zero wind condition (e.g., less than 0.01 kph, etc.) or even a sudden gust of wind in an opposite direction.
  • a zero wind condition e.g., less than 0.01 kph, etc.
  • a system can provide for a selected combination of monitoring, data logging and programmable automated equipment control.
  • a system can incorporate such features into a deployable framework to ensure rapid reaction times and to reduce risks of human error associated with flaring operations.
  • a system may be deployable as a combination of hardware and software that can include site-based hardware and optionally remote hardware (e.g., circuitry, processors, memory, etc.). Such a system may be deployed to retrofit one or more existing well testing packages, optionally with minimal modifications to the core process equipment.
  • an adjustable flare tip can include a combination of hardware, circuitry (e.g., hardware and optionally software), one or more sensors, one or more interfaces (e.g., data, network, etc.), etc.
  • an adjustable flare tip can be temporarily installed at a site for purposes of determining an optimal type of flare tip and/or may be permanently installed as at site, for example, to provide for adjustments to the flare tip, optionally responsive to control instructions, etc.
  • a flare tip is sized for maximum flow rate, back pressure in steady state. This means that for others conditions (e.g., lower most of the time) the sizing is not optimum and does not fit evolving process conditions. As such, there can be poor combustion of gas, dispersion issues, HSE risks for the personnel, etc.
  • a flare tip can be adjustable such that one or more selected parameters directly affecting combustion, dispersion, velocity, pressure in the line, etc., can be adjusted.
  • a flare tip can be adjusted in a manner capable to flow at the maximum rate at a given line pressure but also adjusted in a manner capable outside of such process values, for example, to maintain an optimum size of the flare tip.
  • Being capable to adapt to transient processes can be beneficial for surface processes when flowing a well, bringing in a well, change rate, adding or removing well, etc.
  • a mechanism can be utilized to adjust the orifice size of a flare tip where the mechanism may be fit to a flare.
  • a diaphragm mechanism e.g., an iris design
  • a perforated disks rotating one versus the other mechanism e.g., a perforated disks rotating one versus the other mechanism
  • an adjustable vanes mechanism e.g., an adjustable jet engine nozzle, etc.
  • a system can include an actuator that can adjust a flare tip or flare tips.
  • one or more flare tips may be adjusted to control line back pressure.
  • back pressure can affect various flare tip parameters, which can include speed, dispersion, combustion, etc.
  • a system may be deployed at surface on a permanent basis or on a temporary basis.
  • a system may be deployed to optimize one or more flare tip parameters and then removed where operations may continue using optimized parameter values.
  • a flare tip tends to be sized for maximum flow rate and back pressure in steady-state. Thus, for other conditions (e.g., lower most of the time), sizing is not optimal.
  • a system can provide for flare tip adjustment in a more optimal manner, which can include, for example, making adjustments responsive to evolving process conditions (e.g., production conditions, testing conditions, environmental conditions, etc.). Such an approach can improve combustion of gas, dispersion, reduction of HSE risks for personnel, etc.
  • a system can include a flare tip that adjusts to one or more selected parameters that can directly affect one or more of combustion, dispersion, velocity, pressure in a line, etc.
  • a system can provide a flare tip that is capable of flowing the maximum rate at a given line pressure but also adjusting when outside of such process values where adjustments can aim to maintain the optimum size of the flare tip.
  • Such a system can adapt to transient processes, which can occur when flowing a well, when bringing in a well, when changing a rate, when adding or removing well, when testing a well, etc.
  • a flare tip may be adjustable using one or more mechanisms, which may include, for example, one or more of a diaphragm (e.g., an iris design), perforated disks rotating one versus another, an adjustable nozzle that may include one or more features of an adjustable jet engine nozzle, etc.
  • a diaphragm e.g., an iris design
  • perforated disks rotating one versus another e.g., an iris design
  • a system may provide for adjustments in low to no wind conditions such that one or more sizes of one or more flare tips are appropriate.
  • one or more flare tips can be activated that can best suit one or more goals (e.g., combustion, back pressure, dispersion, etc.).
  • a system may aim to provide for laminar flow for a desired length or volume size from a flare tip or flare tips, which can depend on back pressure and hence flare tip configuration (e.g., angle, size, etc.), for example, to provide desirable dispersion.
  • a desirable dispersion pattern may be one in which the risk of flow back towards a rig and/or other facility is reduced.
  • a flare tip or flare tips are sized for maximum flow, at times, conditions can exist where dispersion does result in flow back towards a rig and/or other facility.
  • FIG. 7 shows an example of a diaphragm mechanism 700 that can provide for adjusting a throat area of a flare tip.
  • the diaphragm mechanism 700 can include a series of leaves.
  • an iris or irises include of an array of curved, spring-steel leaves whose orientation is determined by a relative position of two rings.
  • a pin handle on one of the rings can provide for adjustment to the aperture without risk of obstructing a flow path through the aperture.
  • FIG. 8 shows an example of a rotating disks mechanism 800 and a rotating vanes mechanism 810, where each of the mechanisms 800 and 810 can be utilized to adjust a flare tip.
  • FIG. 9 shows examples of adjustable mechanisms 900 and 910 that include a series of elements that can be controlled to adjust a flare tip.
  • the mechanisms 900 and 910 can form and adjust nozzles, which can be flare tip nozzles.
  • a mechanism may change and maintain its configuration by actuators. As shown in FIG. 9, actuators may be selected from one or more types.
  • one or more CFD simulations may be performed to determine one or more flare tip parameters for desirable flaring and/or flaring-related behaviors.
  • a system may be operable in a fail safe manner, for example, where it can automatically return to the maximum opening in case of a system failure, for example, to reduce risk of over pressurizing a flare line.
  • a mechanism can provide for restricting flaring at one or more locations, for example, such that a method can provide for controlling combustion and/or dispersion by changing the flow conditions (flow type, pressure, velocity, etc.).
  • a system may monitor, analyze, control, etc., one or more operations in a basin region such as, for example, an onshore and/or an offshore region. For example, consider the Permian Basin, where gas production can exceed pipeline capacity exiting the Permian Basin region, which may result in increased flaring.
  • the Permian Basin is predominantly a shale oil play and has large quantities of associated gas production.
  • NNL Permian crude and natural gas liquids
  • FIG. 10 shows an example of a method 1000 and an example of a system 1090.
  • the method 1000 includes a reception block 1010 for receiving wind conditions data; a determination block 1020 for determining a control action to control a flaring operation at a site using the wind conditions data; and an issuance block 1030 for issuing the control action to control the flaring operation.
  • the method 1000 is shown as including various computer-readable storage medium (CRM) blocks 1011 , 1021 , and 1031 that can include processorexecutable instructions that can instruct a computing system, which can be a control system, to perform one or more of the actions described with respect to the method 1000.
  • CRM computer-readable storage medium
  • the system 1090 includes one or more information storage devices 1091 , one or more computers 1092, one or more networks 1095 and instructions 1096.
  • each computer may include one or more processors (e.g., or processing cores) 1093 and a memory 1094 for storing the instructions 1096, for example, executable by at least one of the one or more processors 1093 (see, e.g., the blocks 1011 , 1021 and 1031 ).
  • a computer may include one or more network interfaces (e.g., wired or wireless), one or more graphics cards, a display interface (e.g., wired or wireless), etc.
  • the method 1000 may be a workflow that can be implemented using one or more frameworks that may be within a framework environment.
  • the system 1090 can include local and/or remote resources. For example, consider a browser application executing on a client device as being a local resource with respect to a user of the browser application and a cloudbased computing device as being a remote resources with respect to the user.
  • the user may interact with the client device via the browser application where information is transmitted to the cloud-based computing device (or devices) and where information may be received in response and rendered to a display operatively coupled to the client device (e.g., via services, APIs, etc.).
  • an adjustable flare tip can include an actuator; an adjustable throat restrictor operatively coupled to the actuator; and an interface for receipt of control instructions, where the actuator responds to the control instructions to adjust the throat restrictor.
  • the throat restrictor can include one or more of an iris mechanism, a rotating disc, rotating vanes, shapable elements, and adjustable elements that form a nozzle.
  • an adjustable flare tip can include a fail safe mode that adjusts an adjustable throat restrictor to a maximum flow position to reduce risk of over pressurizing a fuel supply line.
  • an adjustable flare tip can generate, issue and/or respond to control instructions to control fuel line back pressure.
  • an adjustable throat restrictor can be adjustable responsive to wind speed. For example, consider a controller that can receive wind speed information and issue an instruction to an actuator to adjust an adjustable throat restrictor. As an example, an adjustable throat restrictor can be adjustable responsive to plume dispersion, wind speed and/or combustion quality. As an example, an adjustable throat restrictor can be adjustable responsive to presence and absence of combustion.
  • a system can include an adjustable flare tip that includes an actuator; an adjustable throat restrictor operatively coupled to the actuator; and an interface for receipt of control instructions, where the actuator responds to the control instructions to adjust the throat restrictor; and a controller that generates the control instructions.
  • the actuator may be driven by an electromagnetic mechanism (e.g., a motor, etc.), a hydraulic actuator, a mechanical actuator, etc.
  • a system can include a controller that can include a sensor interface that receives sensor data where such sensor data may include one or more of wind data, plume dispersion data, combustion data, back pressure data, and flow data indicative of laminar and/or non-laminar flow.
  • sensor data may include one or more of wind data, plume dispersion data, combustion data, back pressure data, and flow data indicative of laminar and/or non-laminar flow.
  • a computer-readable storage medium is non-transitory, not a signal and not a carrier wave. Rather, a computer- readable storage medium is a physical device that can be considered to be circuitry or hardware.
  • FIG. 11 shows components of an example of a computing system 1100 and an example of a networked system 1110 with a network 1120.
  • the system 1100 includes one or more processors 1102, memory and/or storage components 1104, one or more input and/or output devices 1106 and a bus 1108.
  • instructions may be stored in one or more computer-readable media (e.g., memory/storage components 1104). Such instructions may be read by one or more processors (e.g., the processor(s) 1102) via a communication bus (e.g., the bus 1108), which may be wired or wireless.
  • the one or more processors may execute such instructions to implement (wholly or in part) one or more attributes (e.g., as part of a method).
  • a user may view output from and interact with a process via an I/O device (e.g., the device 1106).
  • a computer-readable medium may be a storage component such as a physical memory storage device, for example, a chip, a chip on a package, a memory card, etc. (e.g., a computer-readable storage medium).
  • components may be distributed, such as in the network system 1110.
  • the network system 1110 includes components 1122-1 , 1122-2, 1122-3, . . . 1122-N.
  • the components 1122-1 may include the processor(s) 1102 while the component(s) 1122-3 may include memory accessible by the processor(s) 1102.
  • the component(s) 1122-2 may include an I/O device for display and optionally interaction with a method.
  • the network may be or include the Internet, an intranet, a cellular network, a satellite network, etc.
  • a device may be a mobile device that includes one or more network interfaces for communication of information.
  • a mobile device may include a wireless network interface (e.g., operable via IEEE 802.11 , ETSI GSM, BLUETOOTH, satellite, etc.).
  • a mobile device may include components such as a main processor, memory, a display, display graphics circuitry (e.g., optionally including touch and gesture circuitry), a SIM slot, audio/video circuitry, motion processing circuitry (e.g., accelerometer, gyroscope), wireless LAN circuitry, smart card circuitry, transmitter circuitry, GPS circuitry, and a battery.
  • a mobile device may be configured as a cell phone, a tablet, etc.
  • a method may be implemented (e.g., wholly or in part) using a mobile device.
  • a system may include one or more mobile devices.
  • a system may be a distributed environment, for example, a so-called “cloud” environment where various devices, components, etc. interact for purposes of data storage, communications, computing, etc.
  • a device or a system may include one or more components for communication of information via one or more of the Internet (e.g., where communication occurs via one or more Internet protocols), a cellular network, a satellite network, etc.
  • a method may be implemented in a distributed environment (e.g., wholly or in part as a cloud-based service).
  • information may be input from a display (e.g., consider a touchscreen), output to a display or both.
  • information may be output to a projector, a laser device, a printer, etc. such that the information may be viewed.
  • information may be output stereographically or holographically.
  • a printer consider a 2D or a 3D printer.
  • a 3D printer may include one or more substances that can be output to construct a 3D object.
  • data may be provided to a 3D printer to construct a 3D representation of a subterranean formation.
  • layers may be constructed in 3D (e.g., horizons, etc.), geobodies constructed in 3D, etc.
  • holes, fractures, etc. may be constructed in 3D (e.g., as positive structures, as negative structures, etc.).

Landscapes

  • Engineering & Computer Science (AREA)
  • Environmental & Geological Engineering (AREA)
  • Mining & Mineral Resources (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Geology (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Fluid Mechanics (AREA)
  • Physics & Mathematics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Chemical & Material Sciences (AREA)
  • Combustion & Propulsion (AREA)
  • Control Of Combustion (AREA)

Abstract

La présente invention concerne un système qui peut comprendre une pointe de torche réglable qui comprend un actionneur ; un restricteur de gorge réglable accouplé fonctionnellement à l'actionneur ; et une interface pour la réception d'instructions de commande, l'actionneur répondant aux instructions de commande pour ajuster le restricteur de gorge ; et un dispositif de commande qui génère les instructions de commande.
PCT/US2023/085292 2022-12-23 2023-12-21 Pointe de torche réglable Ceased WO2024137906A1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US202263476981P 2022-12-23 2022-12-23
US63/476,981 2022-12-23

Publications (1)

Publication Number Publication Date
WO2024137906A1 true WO2024137906A1 (fr) 2024-06-27

Family

ID=91589989

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/US2023/085292 Ceased WO2024137906A1 (fr) 2022-12-23 2023-12-21 Pointe de torche réglable

Country Status (1)

Country Link
WO (1) WO2024137906A1 (fr)

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB2628711A (en) * 2023-02-27 2024-10-02 Schlumberger Technology Bv Flaring optimization responsive to wind conditions

Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4094492A (en) * 1977-01-18 1978-06-13 The United States Of America As Represented By The United States Department Of Energy Variable orifice using an iris shutter
US20130143170A1 (en) * 2010-08-23 2013-06-06 Thyssenkrupp Uhde Gmbh Crude gas torch comprising an adjustable opening cross-section for flaring combustible gases and method for burning crude gases
US20150293506A1 (en) * 2014-04-14 2015-10-15 Honeywell International Inc. Feedback control for reducing flaring process smoke and noise
US20200387120A1 (en) * 2019-06-07 2020-12-10 Honeywell International Inc. Method and system for connected advanced flare analytics
US20220325887A1 (en) * 2021-04-05 2022-10-13 Baker Hughes Holdings Llc Emission monitoring and control of flare systems

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4094492A (en) * 1977-01-18 1978-06-13 The United States Of America As Represented By The United States Department Of Energy Variable orifice using an iris shutter
US20130143170A1 (en) * 2010-08-23 2013-06-06 Thyssenkrupp Uhde Gmbh Crude gas torch comprising an adjustable opening cross-section for flaring combustible gases and method for burning crude gases
US20150293506A1 (en) * 2014-04-14 2015-10-15 Honeywell International Inc. Feedback control for reducing flaring process smoke and noise
US20200387120A1 (en) * 2019-06-07 2020-12-10 Honeywell International Inc. Method and system for connected advanced flare analytics
US20220325887A1 (en) * 2021-04-05 2022-10-13 Baker Hughes Holdings Llc Emission monitoring and control of flare systems

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB2628711A (en) * 2023-02-27 2024-10-02 Schlumberger Technology Bv Flaring optimization responsive to wind conditions
GB2628711B (en) * 2023-02-27 2025-06-04 Schlumberger Technology Bv Flaring optimization responsive to wind conditions

Similar Documents

Publication Publication Date Title
EP3500725B1 (fr) Détection de fuite de réseau de production de fluide
US10920982B2 (en) Burner monitoring and control systems
US20240161495A1 (en) Unlit flare detection using satellite images
AU2019281866B2 (en) Geological feature search engine
EP3794215A1 (fr) Système et procédé de conseil en matière de production assistés par intelligence artificielle
US20240288166A1 (en) Flaring optimization responsive to wind conditions
US20230105422A1 (en) Analogue identification and evaluation for field development and planning
NO20220761A1 (en) Burner control
CN109477367A (zh) 模块式试井系统和方法
US20240386445A1 (en) Field emissions system
WO2024137906A1 (fr) Pointe de torche réglable
Al Eidan et al. Technical challenges in the conversion of CO2-EOR projects to CO2 storage projects
US20240005431A1 (en) Continuous monitoring system for detecting, locating, and quantifying fugitive emissions
US20250252522A1 (en) Field operations framework
CA3216382A1 (fr) Optimisation de torche en temps reel au moyen d'un dispositif peripherique
Wildenborg et al. Large-scale CO2 injection demos for the development of monitoring and verification technology and guidelines (CO2 ReMoVe)
US12474257B2 (en) Determining a property of a gas plume produced by burning hydrocarbon effluent
CN119630865A (zh) 水力压裂阀门系统
CN119948318A (zh) 流量计校准
US20250054308A1 (en) Field vision control framework
US12032521B2 (en) Visualization of energy domain data
WO2024137441A1 (fr) Détermination de l'efficacité de combustion d'effluent d'hydrocarbures
KUMAR Real-Time Reservoir Management for CO₂ Enhanced Oil Recovery and Geological Sequestration: An Integrated Framework for Monitoring, Modeling, and Optimization in Offshore Fields
WO2024173803A1 (fr) Fondation de données géothermiques
WO2025072348A1 (fr) Optimisation de planification de développement de champ génératif

Legal Events

Date Code Title Description
121 Ep: the epo has been informed by wipo that ep was designated in this application

Ref document number: 23908492

Country of ref document: EP

Kind code of ref document: A1

NENP Non-entry into the national phase

Ref country code: DE

122 Ep: pct application non-entry in european phase

Ref document number: 23908492

Country of ref document: EP

Kind code of ref document: A1