PROCESS CONTROL SYSTEM AND METHOD FOR OIL AND/OR GAS PRODUCTION AND TRANSPORTATION SYSTEMS

Abstract

A process control system for use in an oil and/or gas production and/or transportation system, comprises a controller configured to receive an input signal comprising measurement data relating to a production fluid flow in an oil and/or gas production and/or transportation system. The controller is configured to determine from the received input signal an adjustment in the configuration of a flow control arrangement of the production, and provide an output signal indicative of the adjustment in the configuration of the flow control arrangement. The system is configured to mitigate the formation of gas hydrates and/or the accumulation of paraffin wax, asphaltenes or other solids in an oil and/or gas production and/or transportation system by adjusting the flow control arrangement to vary the injection of a chemical into the production and/or transportation system.

Claims

1. A process control system for use in an oil and/or gas production, transportation and/or storage system, comprising: a controller configured to receive an input signal comprising measurement data relating to a production fluid flow in an oil and/or gas production, transportation and/or storage system, the controller configured to determine from the received input signal an adjustment in the configuration of a flow control arrangement of the production wellbore, wherein the controller is configured to provide an output signal indicative of the adjustment in the configuration of the flow control arrangement.

2. The process control system of claim 1, wherein the system is configured to mitigate at least one of the formation of gas hydrates and/or the accumulation of paraffin wax, asphaltenes or other solids in an oil and/or gas production, transportation and/or storage system by adjusting the flow control arrangement to vary the injection of a chemical into the production, transportation and/or storage system.

3. The process control system of claim 2, wherein the system is configured to provide an output signal indicative of an adjustment to the flow control arrangement to vary the injection of THI and/or LDHI hydrate inhibitors (methanol or monoethylene glycol (MEG)) into the production, transportation and/or storage system so as to mitigate the formation of gas hydrates.

4. The process control system of claim 2, wherein the system is configured to provide an output signal indicative of an adjustment to the flow control arrangement to vary the injection of a solvent so as to mitigate the accumulation of paraffin wax, asphaltenes and other solids.

5. The process control system of claim 1, wherein the process control system is operatively associated with an oil and/or gas production, transportation and/or storage system comprising at least one of: a flow line for transporting production fluid; a riser; an oil and/or gas production wellbore.

6. (canceled)

7. The process control system of claim 1, wherein the system is configured to operate autonomously.

8. The process control system of claim 1, wherein the controller is configured to determine the adjustment in the configuration of a flow control arrangement using an artificial intelligence algorithm.

9. The process control system of claim 1, wherein the system is configured to adjust in response to a control command from an operator.

10. The process control system of claim 1, wherein the process control system comprises, is coupled to, or is operatively associated with the flow control arrangement, and wherein optionally the flow control arrangement comprises a production tree.

11. (canceled)

12. The process control system of claim 1, wherein the input signal comprises measurement data relating to a production fluid flow in an oil and/or gas production, transportation and/or storage system.

13. The process control system of claim 12, wherein the measurement data comprises at least one of: fluid flow data; fluid composition data, optionally information relating to the water fraction; data relating to a condition in the production, transportation and/or storage system and/or the production fluid.

14. The process control system of claim 1, wherein the system comprises, is coupled to, or is operatively associated with, a fluid flow meter, optionally comprising a multi-phase flow meter and/or a wet gas flow meter.

15-17. (canceled)

18. The process control system of claim 1, wherein the system comprises, is coupled to, or is operatively associated with a water fraction meter.

19. (canceled)

20. The process control system of claim 1, comprising or coupled to a sensor arrangement comprising at least one of: a temperature sensor configured to measure the temperature in the production, transportation and/or storage system and/or the production fluid; a pressure sensor configured to measure the temperature in the production, transportation and/or storage system and/or the production fluid.

21. The process control system of claim 1, wherein the input signal comprises at least one of: real time data; data relating to a simulated condition in the wellbore; data from manually controlled monitoring systems and equipment; specialist monitoring, analysis, and/or predictive units.

22. The process control system of claim 1, wherein the input signal comprises data from specialist monitoring, analysis, and/or predictive units, and wherein optionally the controller is configured to determine the adjustment in the configuration of a flow control arrangement of the production and/or transportation system by combining the measurement data with the data from the specialist monitoring, analysis, and predictive units.

23. The process control system of claim 1, wherein the output signal comprises chemical metering data.

24. The process control system of claim 1, wherein the system comprises, is coupled to, or is operatively associated with a chemical injection metering valve (CIMV).

25. The process control system of claim 1, wherein the system comprises, is coupled to, or is operatively associated with a chemical injection arrangement.

26. The process control system of claim 25, wherein the chemical injection arrangement comprises at least one of: one or more flow line; a chemical store.

27. The process control system of claim 25, wherein the output signal comprises choke control data.

28. The process control system of claim 1, wherein the system comprises, is coupled to, or operatively associated with a choke valve.

29. The process control system of any preceding claim, wherein the system comprises, is coupled to or operatively associated a safety valve, e.g. a subsurface safety valve (SCSV).

30. The process control system of any preceding claim, wherein the system is configured to communicate data to and/or from a data historian system.

31. An oil and/or gas production, transportation and/or storage system comprising the process control system of claim 1.

32. A process control method for use in an oil and/or gas production, transportation and/or storage system, comprising: receiving an input signal comprising measurement data relating to a production fluid flow in an oil and/or gas production, transportation and/or storage system; determining from the received input signal an adjustment in the configuration of a flow control arrangement of the production, transportation and/or storage system; and providing an output signal indicative of the adjustment in the configuration of the flow control arrangement.

33. The process control method of claim 32, wherein the method employs the system of claim 1.

34. The process control method of claim 32, comprising at least one of: adjusting the configuration of the flow control arrangement; operating the system according to the adjusted configuration to generate a second measurement data set; determining, from the acquired second data set, a further adjustment to the flow control arrangement.

35. The process control method of claim 32, wherein the conditions relative to which the configuration of the flow control arrangement is to be improved or optimised are assessed continuously or at intervals.

36. A processing system, computer program product or carrier medium comprising a signal, configured to implement the system of claim 1 or the method of claim 32.

Description

BRIEF DESCRIPTION OF THE DRAWINGS

[0132] These and other aspects will now be described, by way of example only, with reference to the accompanying drawings, in which:

[0133] FIG. 1 shows a diagrammatic view of an oil and/or gas wellbore system;

[0134] FIG. 2 shows a schematic view of a process control system of the wellbore system shown in FIG. 1;

[0135] FIG. 3 shows a schematic view of the sensor arrangement of the process control system shown in FIG. 2;

[0136] FIG. 4 shows a schematic diagram of the interaction of the AI algorithm with other parts of the process control system;

[0137] FIG. 5 shows a diagrammatic view of the system integration of the AI algorithm;

[0138] FIG. 6 shows a flowchart illustrating operation of the AI algorithm.

DETAILED DESCRIPTION OF THE DRAWINGS

[0139] Referring first to FIG. 1 of the accompanying drawings, there is shown a diagrammatic view of an oil and/or gas production system 10. As shown in FIG. 1, the production system 10 takes the form of a subsea production system and comprises a wellbore 12 extending from a wellhead 14 located at the seabed S. A flow control arrangement 16, which in the illustrated wellbore system 10 takes the form of a subsea Christmas tree, is located on the wellhead 14. In use, the flow control arrangement 16 is configured to control production fluid flow and facilitate well isolation. The flow control arrangement 16 also controls access into the production system 10 for tools, equipment, and fluid. A marine riser 18 couples the flow control arrangement 16 to a surface vessel V.

[0140] As shown in FIG. 1, the system 10 further comprises a process control system, generally depicted at 20. While the process control system 20 shown in FIG. 1 is shown located on the flow control arrangement 16, it will be understood that the process control system 20, or part of the process control system 20, may be located at a remote location, such as on the seabed, at surface, onshore facility or other suitable location.

[0141] Referring now also to FIG. 2 of the accompanying drawings, there is shown a schematic view of the part of the system 10 and the process control system 20 in more detail.

[0142] As shown in FIG. 2, the flow control arrangement 16 comprises a choke valve 22, a valve actuator arrangement 24, a sensor arrangement 26 and a chemical injection arrangement 28. In the illustrated system 10, the choke valve 22, valve actuator arrangement 24, sensor arrangement 26 and chemical injection valve 28 form part of the flow control arrangement 14, the choke valve 22 and valve actuator 24 taking the form of a DC choke valve and DC valve actuator of the flow control arrangement 14 and the chemical injection valve 28 taking the form of a chemical injection valve of the flow control arrangement 14. As shown in FIG. 2, the chemical injection valve 28 forms part of a chemical injection arrangement and is coupled to a chemical supply 30 via chemical supply line 32.

[0143] As shown in FIG. 2, in use production fluid flow (shown by the solid line arrows in FIG. 2) passes through subsurface safety valve 34, choke 22, and sensor arrangement 26 before being transported to surface vessel V via the marine riser 18 (shown in FIG. 1) while the chemical injection arrangement (shown by the dashed line arrows in FIG. 2) is arranged to supply a chemical from the chemical supply 30 to the chemical injection valve 28. In the illustrated system 10, the chemical injection arrangement is configured to inject monoethylene glycol (MEG) in order to mitigate gas hydrate formation. However, it will be recognised that other suitable chemicals may be used where appropriate.

[0144] As shown in FIG. 2, the controller 22 of control system 20 is configured to receive an input signal comprising measurement data 36 from the sensor arrangement 26 relating to the production fluid in the wellbore 10. In the illustrated system 10, the controller 22 is also configured to receive data 38 from specialist monitoring, analysis, and/or predictive units, shown collectively at 40. While in the illustrated system 10, the control system 20 is configured to utilise data from specialist monitoring, analysis, and/or predictive units 40, the control system 20 may alternatively utilise data from one or more of these tools.

[0145] In use, the controller 22 is configured to determine an adjustment in the configuration of the flow control arrangement 16 from the received data 36, 38 and to provide an output signal indicative of the adjustment in the configuration of the flow control arrangement 16. In the illustrated system 10, the output signal comprises choke control data 42 and chemical metering data 44. As shown in FIG. 2, the choke control data 42 is fed to the valve actuator arrangement 24 while the chemical metering data 44 is fed to the chemical injection valve 28.

[0146] Beneficially, embodiments of the system permit operations to be managed more efficiently than conventional techniques and methodologies which rely on manual control. Moreover, embodiments of the system and method may reduce the environmental impact on the surrounding environment, for example by reducing or eliminating the waste due to overuse of chemicals used in gas hydrate management and/or paraffin wax management operations, and the associated equipment footprint.

[0147] Referring briefly to FIG. 3 of the accompanying drawings, there is shown a schematic view of the sensor arrangement 26 of the process control system 20 shown in FIG. 2 in more detail.

[0148] As shown in FIG. 3, the sensor arrangement 26 comprises a SCADA system including a multiphase flowmeter (MPFM) 46, a wet gas flowmeter (WGFM) 48 and a water fraction meter (WFM) 50.

[0149] While the illustrated sensor arrangement 26 includes all three of the multiphase flowmeter (MPFM) 46, wet gas flowmeter (WGFM) 48 and water fraction meter (WFM) 50, it will be understood that the sensor arrangement 26 may alternatively comprise one of the multiphase flowmeter (MPFM) 46, wet gas flowmeter (WGFM) 48 and water fraction meter (WFM) 50, and more usually two of the multiphase flowmeter (MPFM) 46, wet gas flowmeter (WGFM) 48 and water fraction meter (WFM) 50 so as to avoid significant cost escalation.

[0150] In the illustrated sensor arrangement 26, the multiphase flowmeter 46, wet gas flowmeter 48 and water fraction meter 50 form part of the flow control arrangement 14 and comprise their own hardware and software such as PLCs or the like. As described above, the sensor arrangement 26 communicates with the controller 22. As shown in FIG. 3, the sensor arrangement 26 also communicates with a production operator 52, e.g. via a human machine interface (HMI)—shown schematically at 54. The production operator 52 in turn is capable of communication to/from the controller 22. The control system 20 is thus configured to adjust in response to a control command from an operator. Beneficially, embodiments of the system permit autonomous operation while also permitting manual intervention or override where required.

[0151] The control system 20 is capable of operating autonomously, the controller 22 configured to determine the adjustment in the configuration of a flow control arrangement 16 of the production system 10 using an artificial intelligence algorithm.

[0152] In use, the control system 20 may, for example, be configured to arrange and organise data, extract patterns and detect trends that are too complex and/or subtle to be detected by humans or by current computerised techniques. The system is capable of automatically devising optimal operational strategies (such as those for hydrate formation prevention) which can either be implemented by the system or passed to a human operator for approval. Moreover, the system is capable of learning operator decisions on the proposed strategies and operator defined changes to any proposed steps, using changes automatically verified as successful to automatically improve the existing strategies. This process may identify human decisions resulting in the deterioration of operating conditions, use this knowledge to avoid such decisions being reused, and flag them to the human decision makers in future operations.

[0153] FIGS. 4, 5 and 6 of the accompanying drawings illustrate the configuration and operation of the real-time artificial intelligence algorithm of the system 10.

[0154] As shown in FIG. 4, the AI algorithm communicates with sensor arrangement 26 via the SCADA, with specialist monitoring, analysis, and/or predictive units 40, and production operator 52. The AI algorithm also communicates with chemical injection valve 28. The production operator 52 also communicates with the chemical injection valve 28.

[0155] As shown in FIG. 5, the AI algorithm is configured to communicate with sensor arrangement 26 via an Application Programming Interface API.sub.S and with OSI Pi historian via Application Programming Interface API.sub.Pi. The AI algorithm receives and configures the sensor data for input into a hydrate model 56 via Application Programming Interface API.sub.H. As will be described below, the AI algorithm receives and converts the data to produce results and a reporting GUI interface.

[0156] As shown in FIG. 6, during operation the AI algorithm first requests and receives data, including for example but not exclusively data from the specialist monitoring, analysis, and/or predictive units 40, sensor data from the sensor arrangement 26, such as pressure, temperature, or other data.

[0157] Next, the AI sends the data to a hydrates model. The AI then executes the computational commands to operate the software of the hydrates model, organises the received results, and extracts the results back from the hydrates model

[0158] Next, the AI displays the results via a graphical user interface, together with actionable commands including: [0159] 1. Accept; [0160] 2. Decline; [0161] 3. Suggest action.

[0162] On receiving an Accept command, the AI either automatically operates the chemical injection valve to adjust flow rates of the required chemical inhibitor. The AI may alternatively present the command option to the operator to initiate the command to operate the valve.

[0163] On receiving a Decline command, no action is initiated.

[0164] On receiving a Suggest action command, the AI presents justification for the results presented.

[0165] It should be understood that the embodiment described herein is merely exemplary and that various modifications may be made thereto without departing from the scope of the invention.

[0166] The controller 22 shall also be able to accommodate a range of specific plug-in data modules such as (but not limited to) those for risk assessments and other production critical operations that can be performed without the reliance of a production operator to manually intervene. The list of plug-in data modules may, for example include: flocculation data; erosion data; corrosion data; CFD data; 5D data; CO.sub.2 (geo-sequestration or carbon capture) data; reservoir geology data; reservoir surveillance data, integrated reservoir modelling (static and/or dynamic) data; reservoir data acquisition and conditioning data; reservoir ROI data; risk assessment data; fiscal model data; OpEx/CapEx finance model data, integrated asset modelling data, asset integrity monitoring data, pipeline slugging control data, liquid loading/handling data, well prioritisation data, enhanced predictive operations data; performance monitoring data; process optimisation data; sand production data; salt detection & monitoring data; production balancing management data; choke performance data; RAM optimisation data; safety data; environmental data; optimisation chemical utilisation; HMI reduction data; flow measurement; subsea processing monitoring; remote chemical storage conditioning; inhibitor quality monitoring data; uncertainty modelling data; tree valve condition data; SCM/SEN condition monitoring data; cathodic protection level/balancing data; training data; forecasting data; upset condition modelling data; line packing/unpacking data; steady state/transient monitoring data; diagnostics data; subsea field infrastructure, design, operation, decommissioning data, monitor data; gas composition tracking data; and data analytics.

[0167] Amongst other things, the described system and method beneficially provides an integrated system and method for measuring required changes in the concentration of chemicals used for the prevention and/or mitigation of potentially hazardous solids such as gas hydrates, clathrates, paraffin wax and/or asphaltenes, as well as facilitating predictive and/or preventative strategies for these and other materials. Moreover, the system and method also has particular applicability to the fields of gas production and subsea engineering design, glycol regeneration, and/or flow assurance.