• 专利附录
  • 专利说明
  • 权利要求
  • 类似技术
  • 同族专利
  • 引用文献
  • 法律状态
  • 优先权
    • 专利摘要:
    DRILLING AND DRILLING CONTROL SYSTEMS, AND METHOD FOR CONTROLING A DRILLING PROCESS. A drilling system is described which comprises a drilling parameter sensor in communication with a sensor application that generates processed data from raw data that is received from the drilling parameter sensor. A process application communicates with the sensor application and generates an instruction based on the processed data. A priority controller communicates with the process application and evaluates the instruction for release to an equipment controller, which then issues the instruction to one or more drilling components.
    公开号:BR112014013265B1
    申请号:R112014013265-8
    申请日:2012-11-30
    公开日:2021-01-19
    发明作者:Tony Pink；David Reid；Andrew Bruce
    申请人:National Oilwell Varco, L.P.；
    IPC主号:
    专利说明:

    CROSS REFERENCE TO RELATED REQUESTS
    [0001] This application claims priority to US Patent Application 61 / 565,736, entitled Automatic Drilling System, which was filed on December 1, 2011 and to US Patent Application 61 / 619,500, entitled Drilling Control and Information System, which was filed on April 3, 2012. These priority requests are hereby incorporated by reference in their entirety into this request, to the extent that it is not inconsistent with this request. BACKGROUND OF THE INVENTION
    [0002] This description refers, in general, to methods and apparatus for automating drilling processes. More specifically, this description refers to methods and devices for automating drilling processes using input data from an external interface of the drilling rig on the surface with drilling machinery from a third party source, as well as interacting with bore information below third parties to facilitate a single closed-loop control of a plurality of drilling parameters in the drilling system using a networked control system that can be customized based on the equipment being used and the processes that are carried out so that the user activates all the machinery that drills the well in an automated way with the bore-sensing devices below the users.
    [0003] To recover hydrocarbons from underground formations, in general, wells are constructed by drilling in the formation using a rotary drill bit attached to a drill string. A fluid, commonly known as drilling mud, is circulated down through the drill string to lubricate the drill bit and drive chips out of the well as the fluid resumes to the surface. The methods and equipment in particular used to build a particular well can vary extensively based on the environment and the formation in which the well is being drilled. Many different types of equipment and systems are used in the construction of wells, including, but not limited to, rotary equipment for rotating the drill bit, lifting equipment for raising the drill string, pipe handling systems for handling tubulars used in construction of the well, including the tube that constitutes the drilling column, pressure control equipment to control pressure in the well bore, mud pumps and mud cleaning equipment to treat the drilling mud, directional drilling systems and various drilling tools. hole below.
    [0004] The general efficiency of the construction of a well depends, in general, on all these systems that operate together efficiently and in conjunction with the requirements of the well to effectively drill any given formation. A problem faced in the construction of wells is that maximizing the efficiency of one system can have undesirable effects on other systems. For example, increasing the weight acting on the drill bit, known as drill weight (WOB), can often result in a higher penetration rate (ROP) and faster drilling, but it can also decrease the life of the drill bit , which can increase the drilling time due to the need to replace the drill bit more frequently. Therefore, the performance of each system that is used in the construction of a well must be considered as part of the whole of the system in order to safely and efficiently build the well.
    [0005] Many conventional automated drilling systems are "closed-loop" systems that attempt to improve the drilling process by perceiving a limited number of conditions and adjusting the system's performance, manually or automatically, based on the perceived conditions. Often, these closed-loop systems do not have the ability to monitor or consider the performance of all other systems that are used or to adjust the performance of multiple systems simultaneously. Therefore, it is left to human intervention to ensure that the entire system operates efficiently / satisfactorily.
    [0006] Counting on human intervention can become complicated due to the fact that multiple parts are often involved in the construction of the well. For example, the construction of a single well will often involve the well owner, a drilling contractor busy drilling the well and a multitude of other companies that provide specialized tools and services for the well construction. Because of the significant coordination and cooperation that is required to integrate multiple systems from multiple companies, significant human intervention is required for efficient operation. The integration of multiple systems and companies becomes increasingly problematic as drilling processes advance in complexity.
    [0007] Thus, there is a continuing need in the technology for methods and apparatus to automate drilling processes that overcome these and other limitations of the prior technology. SUMMARY OF THE INVENTION
    [0008] One embodiment of the description provides a drilling system that has a drilling parameter sensor in communication with a sensor application that generates processed data from raw data that is received from the drilling parameter sensor. A process application communicates with the sensor application and generates an instruction based on the processed data. A priority controller communicates with the process application and evaluates the instruction for release to an equipment controller, which then issues the instruction to one or more drilling components. BRIEF DESCRIPTION OF THE DRAWINGS
    [0009] For a more detailed description of the modalities of the present description, reference will now be made to the attached drawings.
    [00010] Figure 1 is a simplified diagram of an automatic drilling system.
    [00011] Figure 2 is a simplified schematic diagram of a drill string used as part of an automatic drill system.
    [00012] Figure 3 is a simplified diagram of a control system for an automatic drilling system. DETAILED DESCRIPTION
    [00013] It should be understood that the following description describes several exemplary modalities for implementing different features, structures or functions of the invention. Exemplary modalities of components, arrangements and configurations are described below to simplify the present description; however, these exemplary embodiments are provided as examples only and are not intended to limit the scope of the invention. In addition, the present description may repeat numbers and / or letters of reference in the various exemplary modalities and through the figures provided herein. This repetition is for the purpose of simplicity and clarification, and does not in itself indicate a relationship between the various modalities and / or exemplary configurations discussed in the various figures. Furthermore, the formation of a first resource on a second resource, or in it, in the description that follows may include modalities in which the first and second resources are formed in direct contact, and may also include modalities in which additional resources can be formed by interposing the first and second resources, in such a way that the first and second resources may not be in direct contact. Finally, the exemplary modalities presented below can be combined in any combination of ways, that is, any element from an exemplary modality can be used in any other exemplary modality, without departing from the scope of the description.
    [00014] Additionally, certain terms are used throughout the following description and claims to refer to particular components. As those skilled in the art realize, several entities may refer to the same component by different names and, as such, the naming convention for the elements described herein is not intended to limit the scope of the invention, unless otherwise specifically defined herein. . In addition, the naming convention used here is not intended to distinguish between components that differ in name, but not in function. In addition, in the following discussion and in the claims, the terms "including" and "comprising" are used in an open manner and thus must be interpreted to mean "including, but not limited to". All numerical values in this description may be exact or approximate values, unless otherwise specifically stated. In this way, various types of description can deviate from the numbers, values and ranges described here without departing from the intended scope. Furthermore, as used in the claims or specification, the term "or" is intended to cover both exclusive and inclusive cases, that is, "A or B" is intended to be synonymous with "at least one of A and B ", unless otherwise expressly specified herein. For the purposes of this application, the term "in real time" means without significant delay.
    [00015] Initially in relation to figure 1, the automated drilling system 10 can include a drilling parameter sensor 12 which is in bidirectional communication with a control system 14 by means of a high-speed communication system 16 which can be capable of real-time or near real-time communication. The drilling parameter sensor 12 can be any sensor operable to perceive at least one drilling parameter and provide raw data related to the drilling parameter for control system 14. The drilling parameter sensor 12 can also be configured to receive instructions of operation from the control system 14.
    [00016] The drilling parameter sensor 12 can be mounted in any location necessary to perceive the drilling parameter being monitored. For example, the drilling parameter sensor 12 can be a sensor in the bellow below or a sensor mounted on the drilling tower. A hole drilling parameter sensor below 12 can be arranged in the hole assembly below (BHA) or anywhere along a drilling column and can include sensors to measure drilling parameters of the hole below, including, but not limited to , WOB, torque, revolutions per minute (RPM), temperature, vibration, acceleration, pressure, formation characterization, well drilling condition and drilling fluid condition. A drilling parameter sensor mounted on drilling tower 12 can be configured to monitor a component of the drilling system, including, but not limited to, top drives, main winches, pipe handling equipment, pressure control equipment, equipment mud cleaners, pumps, overflow safety systems, construction sites, tube storage shelves, centrifuges, agitators, displacement compensators, dynamic positioning systems, accumulators and valves, to measure one or more drilling parameters, including, but not limited to, without limitations, WOB, torque, revolutions per minute (RPM), temperature, vibration, acceleration, and pressure.
    [00017] The control system 14 can also be in bidirectional communication with the drilling components 18 by means of a network communication system (wired or wireless is not specifically relevant). The control system 14 can provide operating instructions for the drilling components 18 in response to the drilling parameters perceived by the drilling parameter sensors 12. The drilling components 18 may include, but are not limited to, top drives, main winches, tube handling equipment, pressure control equipment, mud cleaning equipment, pumps, overflow safety systems, construction sites, tube storage shelves, centrifuges, agitators, displacement compensators, dynamic positioning systems, accumulators and valves . The drilling components 18 may include one or more sensors that can monitor the performance of the equipment and provide feedback on the performance of the equipment to the control system 14.
    [00018] The sensor application 22 and the process application 24 can be in two-way communication with the control system 14. The sensor application 22 and the process application 24 are operable to work with the control system 14 to process data received from the drilling parameter sensor 12, and other sensors, and provide operating instructions for one or more drilling components 18. In this way, the automated drilling system 10 allows the drilling process to be controlled and executed as well as adjusted and adapted, using verification or command data collected by the drilling parameter sensor 12 or by the third party system.
    [00019] In operation, the raw data collected by the drilling parameter sensor 12 are retransmitted by the communication system 16 to the control system 14. These data then enter the control system 14, where they are prioritized and distributed to one or more sensor applications 22. Data from a single drill parameter sensor 12 can be provided for one or more sensor applications 22. Likewise, a single sensor application 22 can receive data from one or more sensors perforation parameter 12. The sensor application 22 can process the data received by the perforation parameter sensor 12, or by other sensors, and communicate the processed data back to the control system 14.
    [00020] The control system 14 prioritizes and distributes the processed data to one or more process applications 24. The processed data can be received by one or more process applications 24 that can generate an instruction to modify an operational parameter of one or more more drilling components 18. Process applications 24 receive data, including, but not limited to, data processed by sensor applications 22, and analyze this data to assess the performance of the drilling components and issue instructions to modify operating parameters of one or more drilling components 18, as needed. For example, a process application 24 can be configured to provide instructions for drilling components 18 to manage WOB on the surface, torque and RPM in response to WOB data in the hole below, torque in the hole below and vibration in the hole below collected by the drilling parameter sensor 12. Other process applications 24 may include, but are not limited to, applications to manage control hole cleanliness, equivalent circulation density (ECD) management, managed pressure drilling (MPD), pressure detection gas jet, directional drilling and drilling efficiency.
    [00021] The control station 20 can be in bidirectional communication with the control system 14 and provide a user interface that can be accessed by an operator in the drilling tower or at a remote location. The control station 20 provides a place to provide manual insertion into the control system 14 and for manual cancellation of the control system 14, if necessary. The control station 20 can provide visual representation of the operation of the system, including the status of one or more drilling components 18 and a real-time representation of the data received from the drilling parameter sensors 12.
    [00022] The automated drilling system 10 provides a customizable open concept control system, where sensor applications 22 and / or customized process applications 24 allow the drilling process to be adapted to meet the specific needs of drilling contractors and drilling tower operators. The automated drilling system 10 allows a plurality of sensor applications 22 and / or process applications 24 to be developed and selectively integrated into the control system 14, as needed. This enables the automated drilling system 10 to be easily adapted for a variety of implementations.
    [00023] Now, in relation to figure 2, an exemplary BHA 40 can include a drill 42, a steering system 44, a sensor module 46 and a communication substitute 48. BHA 40 can be coupled to the rotating system 52, or other surface equipment, via drill pipe 50. Each of drill bit 42, steering system 44, sensor module 46 and drill pipe 50 can include one or more drill parameter sensors 12 to measure a parameter drilling rig including, but not limited to, WOB, torque, RPM, temperature, vibration, acceleration and pressure.
    [00024] The perforation parameter sensors 12 can be in bidirectional communication with the communication substitute 48 through a wired or wireless connection. Communication substitute 48 can be operable to receive data collected from each of the drilling parameter sensors 12 and transmit the data to the surface via communication system 16. Communication substitute 48 can also be operable to receive control signals and other signals from the surface and relay these signals to one or more sensors 12 or other tools in the BHA 40.
    [00025] The communication system 16 can be any system suitable for the transmission of data and other signals between the BHA 40 to the surface at relatively high speed rates. In certain embodiments, the communication system 16 supports continuous real-time communication between the BHA 40 and the surface. Suitable communication systems 16 can use communication methods that include, but are not limited to, electrical signals along the attached drill pipe, mud pulse telemetry, optical fiber, wireless signals, acoustic signals and electromagnetic signals.
    [00026] Data transmitted from BHA 40 can be received on the surface by communications link on surface 54. The communications link on surface 54 can be integrated into a component, such as a swivel, internal overflow safety system ( IBOP) or in an instrumented oil glove attached to the drill string. The communications link on the surface 54 can be configured to transmit data to the communication controller 56 via a wired or wireless connection 58. The communication controller 56 can be coupled to the control system 14 and operable to manage the flow between the control system 14 and the surface communications link 54. The communications controller 56 can also be in bidirectional communication with other sensors located on the surface, including sensors mounted on drilling components 18.
    [00027] Now, with reference to figure 3, the control system 14 can include an internal communication bus 26, a network interface 28, a priority controller 30, data storage 32, a simulator interface 34 and a controller hardware36. The internal communication bus 26 can also be in bidirectional communication with one or more sensor applications 22, one or more process applications 24, a control station 20 and the communication controller 56. The network interface 28 can also be in bidirectional communication with external sources and users of information, so that drilling operations and drilling tower performance can be remotely monitored and controlled.
    [00028] In operation, raw data from drilling parameter sensors 12, and other sources, are received by the internal communication bus 26 via communication controller 56. The internal communication bus 26 sends the data to the interface network 28. Network interface 28 receives raw data from the plurality of drilling parameter sensors 12, other sensors, and from external sources, such as specialist engineers or technicians outside the workplace. The network interface 28 categorizes and classifies this data and then distributes the data back through the internal communication bus 26 to the sensor applications 22 and / or the process applications 24 that can process this data.
    [00029] In order to provide flexibility and support the use of control system 14 with a variety of drilling and completion operations, control system 14 can be configured with customized sensor applications 22 and process applications 24 as needed, for the particular operation. This allows the control system 14 to be easily customized for use with specific drilling parameter sensors and the equipment available in a specific drilling tower. If the drilling rig tower or drilling parameter sensors are changed, the corresponding applications in the control system 14 can also be changed without having to reprogram the entire control system.
    [00030] The sensor application 22 can be operable to receive raw data from one or more drilling parameter sensors 12, or other sensors, and generate processed data. The sensor application 22 can be operable to generate processed data representing conditions of the hole below, including, but not limited to, WOB, torque, RPM, temperature, vibration, acceleration and pressure. The processed data is then transmitted by the internal communication bus 26 to the process applications 24 which can use the processed data to generate an instruction.
    [00031] Processed data can be received by one or more process applications 24 that can generate an instruction that can modify an operational parameter of one or more drilling components 18, display a status of the drilling operation or cause another one function is performed. Process applications 24 receive data, including, but not limited to, data processed by sensor applications 22, and analyze this data to evaluate the performance of drilling components and issue instructions for modifying the operational parameters of one or more components of drilling drill 18 as needed. For example, a process application 24 can be configured to provide instructions for drilling components 18 to manage WOB on the surface, torque and RPM in response to WOB data in the hole below, torque in the hole below and vibration in the hole below collected by a drilling parameter sensor 12. Other process applications 24 may include, but are not limited to, applications for managing control hole cleanliness, equivalent circulation density (ECD) management, managed pressure drilling (MPD), detection gas jet, directional drilling and drilling efficiency.
    [00032] Multiple sensor applications 22 and process applications 24 can be simultaneously in bidirectional communication with the control system 14. As exposed, sensor applications 22 and / or process applications 24 can analyze and / or process collected data to generate a response, which may include an instruction, measurement, operational condition, data point or other information. Instructions generated by the process applications are then transmitted to the priority 30 controller.
    [00033] The priority controller 30 monitors the performance of the entire drilling process and determines whether the instructions generated by the process applications 24 can be implemented. For example, if a process application 24 generates an instruction for a drilling component to perform a certain function, the priority controller 30 determines whether this function can be safely performed. Once an instruction has been authorized by the priority controller 30, this response is released by the priority controller 30 and can be sent to the hardware controller36 or another component of the control system. The needs of the drilling operation will be given priority after the system has assessed the priority, and solely as an example, a priority plan can be listed as follows: (1) safety considerations defined by conditions in the workplace; (2) machine limitations (can be assessed based on the work that still needs to be done before maintenance is performed and materials available for maintenance) that can be defined by suppliers and equipment supply chain; (3) well constraints to prevent collapse or fracture that can be defined by the geologist and verified by personnel defined at the workplace; (4) accuracy of the formation target that can be defined by the directional punch; (5) penetration rate that can be defined by the company's professional; and (6) well quality that can be defined by the petrophysicist.
    [00034] Once the instruction has been released by the priority 30 controller, it can be routed to one or more of the hardware controller36, simulator interface 34, data store 32 or other system components. Hardware controller36, which may include one or more primary logic controllers and / or single-board controllers, can provide operating instructions for one or more drilling components 18. Data storage 32 can store both raw and processed data, as well as any instructions sent to the drilling components 18. The simulator interface 34 can receive all the instructions that the hardware controller36 sends to the drilling components 18, so that these instructions can be provided for a drilling simulator that can replicate instructions and predict the result of the operation.
    [00035] In one embodiment, a sensor application 22 can monitor one or more drilling parameter sensors 12 to compute a specific mechanical energy (MSE) and ROP. This data can be transmitted to a process application 24 which can vary one or more drilling parameters, including, but not limited to, WOB on the surface, torque on the surface and pressure of the mud motor. Process application 24 can then continue to receive information from the sensor application and adjust drilling parameters in order to optimize the drilling process as desired by both minimizing MSE and maximizing ROP. Other sensor applications 22 can provide real-time measurements of the hole below WOB in the hole below, torque in the hole below and RPM in the hole below that the process application 24 can use to optimize the drilling process.
    [00036] In another embodiment, a sensor application 22 can receive data from one or more drilling parameter sensors 12 to determine vibrations, oscillations, spontaneous oscillation movement in the hole below, or other dynamic movement in the drilling column which can reduce the efficiency of the drilling process. Processed data can be sent to a process application 24 that will vary drilling parameters, including, but not limited to, surface RPM and surface WOB, in order to reduce any unwanted movements.
    [00037] In yet another embodiment, a process application 24 can be a pump pressure management application that uses processed data generated by one or more sensor applications 22 that acquire raw data from the drilling parameter sensors that they monitor pressure in the bore below, pump pressure, pressure in the annular space and other pressures in the well bore. The pump pressure management application can control the pressure of the fluid being pumped into the well bore by varying the pressure of the pump and then monitor the pressure returning to the surface to assess a variety of conditions drilling, including, but not limited to, gas jet detection, bore cleaning, well hole stability, and other flow issues.
    [00038] Although the description is susceptible to several modifications and alternative forms, specific modalities of this are shown by way of example in the drawings and in the description. It should be understood, however, that the drawings and the detailed description are not intended to limit the description to the particular form described, but, on the contrary, the intention is to cover all modifications, equivalents and alternatives that fall in the spirit and scope of the this description.
    权利要求:
    Claims (20)
    [0001]
    1. Drilling system, characterized by the fact that it comprises: a plurality of drilling parameter sensors; a plurality of sensor applications, each of the plurality of sensor applications communicating with at least one of the plurality of drilling parameter sensors and is operable to generate processed data from the raw data that is received from at least one of the plurality of perforation parameter sensors; a plurality of process applications, each of the plurality of process applications communicating with at least one of the plurality of sensor applications and is operable to generate an instruction based on the processed data generated by at least one of the plurality of sensor applications; a priority controller in communication with the plurality of process and operable applications to evaluate the instructions for release according to a priority plan; and an equipment controller in communication with the priority controller and operable to issue instructions to one or more drilling components when instructions are released by the priority controller.
    [0002]
    2. System according to claim 1, characterized by the fact that it additionally comprises an operable network interface to control the data transmission between the plurality of drilling parameter sensors, the plurality of process applications and the plurality of sensor applications .
    [0003]
    3. System according to claim 2, characterized by the fact that it additionally comprises data storage coupled to the network interface.
    [0004]
    4. System according to claim 1, characterized by the fact that it additionally comprises a simulator interface operable to receive instructions from the priority controller.
    [0005]
    5. System according to claim 1, characterized by the fact that it additionally comprises a control station coupled to the equipment controller and operable to display the status of one or more drilling components.
    [0006]
    6. System according to claim 1, characterized by the fact that at least one of the plurality of process applications is operable to generate an instruction based on the processed data generated by more than one of the plurality of sensor applications.
    [0007]
    7. System according to claim 1, characterized by the fact that at least one of a plurality of perforation parameter sensor is a hole sensor below.
    [0008]
    8. System according to claim 1, characterized by the fact that at least one of the plurality of drilling parameter sensors is a sensor mounted on the drilling tower.
    [0009]
    9. Method for controlling a drilling process, characterized by the fact that it comprises: collecting data using a plurality of drilling parameter sensors; transmitting the data to a control system that includes a plurality of sensor applications and a plurality of process applications; processing the data using at least one of the plurality of sensor applications to provide a representation of a drilling parameter; generate an instruction by analyzing the representation of a drilling parameter using at least one of a plurality of process applications; evaluate the instruction with a priority controller to determine whether the instruction can be released according to a priority plan; and transmitting the instruction to one or more drilling components when the instruction is released by the priority controller.
    [0010]
    10. Method according to claim 9, characterized in that it additionally comprises transmitting additional data to the control system from a network interface.
    [0011]
    Method according to claim 10, characterized in that it additionally comprises coupling the data storage to the network interface.
    [0012]
    12. Method according to claim 9, characterized in that it additionally comprises transmitting the instruction to a simulator interface.
    [0013]
    13. Method according to claim 9, characterized in that it additionally comprises displaying a state of one or more drilling components in a control station.
    [0014]
    14. Method according to claim 9, characterized by the fact that the priority controller is operable to evaluate a plurality of instructions issued by the plurality of process applications.
    [0015]
    15. Method according to claim 9, characterized in that at least one of a plurality of drilling parameter sensors is a hole sensor below.
    [0016]
    16. Method according to claim 9, characterized in that at least one of the plurality of drilling parameter sensor is a sensor mounted on the drilling tower.
    [0017]
    17. Drilling control system, characterized by the fact that it comprises: a plurality of operable sensor applications to generate drilling data processed from raw drilling data that is received from one or more sensors; a plurality of process applications operable to generate operating instructions based on the processed drilling data that is generated by the plurality of sensor applications; an operable priority controller for selectively evaluating and releasing operating instructions according to a priority plan; a plurality of equipment controllers operable to receive operating instructions that have been released by the priority controller and to issue released operating instructions to one or more drilling components.
    [0018]
    18. System according to claim 17, characterized in that it additionally comprises a control station operable to display the status of one or more drilling components.
    [0019]
    19. System according to claim 17, characterized in that the one or more sensors comprise a hole sensor below.
    [0020]
    20. System according to claim 17, characterized by the fact that the one or more sensors comprise a sensor mounted on the drilling tower.
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    同族专利:
    公开号 | 公开日
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    EP2785969A2|2014-10-08|
    CA2857650C|2017-09-26|
    WO2013082498A3|2014-03-20|
    WO2013082498A2|2013-06-06|
    BR112014013265A2|2017-06-13|
    CA2857650A1|2013-06-06|
    DK2785969T3|2017-09-18|
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    法律状态:
    2018-12-04| B06F| Objections, documents and/or translations needed after an examination request according art. 34 industrial property law|
    2019-12-31| B06U| Preliminary requirement: requests with searches performed by other patent offices: suspension of the patent application procedure|
    2020-12-08| B09A| Decision: intention to grant|
    2021-01-19| B16A| Patent or certificate of addition of invention granted|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 30/11/2012, OBSERVADAS AS CONDICOES LEGAIS. |
    优先权:
    申请号 | 申请日 | 专利标题
    US201161565736P| true| 2011-12-01|2011-12-01|
    US61/565736|2011-12-01|
    PCT/US2012/067402|WO2013082498A2|2011-12-01|2012-11-30|Automated drilling system|
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