US20110297395A1 - Remote drilling and completions management - Google Patents

Abstract

A methodology reduces the needed number of personnel on a rig by enabling performance of a variety of functions from a remote location. The method comprises utilizing a plurality of observation devices which monitor rig parameters remotely. Data from the observation devices is transmitted to a remote operations center used to analyze the data for determining operational changes to the rig. Control instructions may then be transmitted to the rig to implement the operational changes.

Description

CROSS-REFERENCE TO RELATED APPLICATION
• The present document is based on and claims priority to U.S. Provisional Application Ser. No. 61/290967, filed Dec. 30, 2009.
BACKGROUND
• A variety of subterranean fluids are recovered from underground formations through the use of wells drilled into or through the underground formations. Wells may be used for exploration and production related to a variety of fluids, including oil, gas, water, geothermal fluids and other types of liquids and/or gases. In many applications, a rig is employed to facilitate drilling and other well construction activities. Traditionally, a relatively large number of rig operators and other personnel have been employed on the rig to perform the complex operations related to construction of the well. However, the requirement of these relatively large numbers at the rig location adds to the expense and complexity of the operation.
SUMMARY
• In general, the present invention provides a methodology for reducing the number of personnel on a rig. The method comprises utilizing a plurality of observation devices which monitor rig parameters remotely. Data from the observation devices is transmitted to a remote operations center, at which the data is analyzed for determining operational changes to the rig. Control instructions may then be transmitted to the rig to implement the operational changes.
BRIEF DESCRIPTION OF THE DRAWINGS
• Certain embodiments of the invention will hereafter be described with reference to the accompanying drawings, wherein like reference numerals denote like elements, and:
• FIG. 1 is a schematic illustration of a remote operations center in communication with a rig over a well, according to an embodiment of the present invention;
• FIG. 2 is a schematic illustration of control systems which may be utilized in the remote operations center and on the rig, according to an embodiment of the present invention;
• FIG. 3 is a schematic illustration of a computer-based control system which may be employed in the remote operations center to process data and/or output operational commands to the rig, according to embodiment of the present invention;
• FIG. 4 is a schematic illustration of the control system used on a rig to correspond with the remote operations center and/or to carry out rig related operational functions, according to an embodiment of the present invention;
• FIG. 5 is a schematic illustration of a hierarchy for operational control of a rig utilizing the remote operations center, according to an embodiment of the present invention; and
• FIG. 6 is schematic illustration of a remote operations center, according to an embodiment of the present invention.
DETAILED DESCRIPTION
• In the following description, numerous details are set forth to provide an understanding of the present invention. However, it will be understood by those of ordinary skill in the art that the present invention may be practiced without these details and that numerous variations or modifications from the described embodiments may be possible.
• The present invention generally relates to a methodology which enables reductions in the number of personnel required on a rig. A plurality of observation devices is employed to monitor rig parameters remotely at, for example, a remote operations center. This allows the remote processing of data so that decisions may be made at the remote operations center regarding operational changes to the rig. Commands are then sent to the rig to implement the operational changes. In some embodiments, the collection of data at the rig is performed in real-time, and the real-time data is automatically transmitted to the remote operations center. The real-time data is then processed to determine the need for operational changes at the rig. If such operational changes are required, command signals may be relayed from the remote operations center to initiate automatic changes at the rig.
• According to an embodiment of the present invention, the methodology may be employed generally with respect to hydrocarbon and water exploration and production. By way of example, the methodology and system to carry out the methodology may be employed for remote management of oil, gas, geothermal, and water well construction and recovery operations.
• Embodiments of the present invention involve high volume drilling and completions activities, with similar well profiles, for enabling construction in an efficient manner. Such embodiments comprise new work processes and work flows that utilize technology to reduce the number of people required to perform certain tasks, as compared to traditional operations. Related patent documents include: U.S. Publication No. US2008-0208475, entitled “Drilling Collaboration Infrastructure,” to Schlumberger Technology Corporation by inventors George Karr, et al; U.S. Publication No. US-2009-0225630, entitled “Data Aggregation For Drilling Operations,” to Schlumberger Technology Corporation by inventors Shunfeng Zheng. U.S. Publication No. US2008-0208475 and U.S. Publication No. US2009-0225630 are hereby incorporated by reference.
• Various embodiments of the present invention include new ways of constructing wells (for oil, gas, geothermal, water) with the main supervision of such well construction located in a remote site, instead of the rig itself. This new process utilizes new technology enablers in the areas of telecommunications, data acquisition and software technology, and facilitates efficiency improvements in well construction operations based on:
• improved collaboration,
• reduced man-power requirements, and
• focused decision making processes.
• In remote well drilling and completions management, the rig is an important component, because all physical operations happen at the rig. The rig comprises a crew of personnel for facilitating rig-based operations. An embodiment of the present invention includes a process having the steps of taking real-time digital measurements of important parameters on the rig (for example, through the use of sensors and/or video cameras, microphones, video-conference equipment, and so forth) and sending such measurements to a remotely located operations center, which may have an expert and/or management team. This remote operations center is in charge of receiving the real-time data, analyzing it, interpreting it, and making informed decisions based on such interpretations. In many applications, processing and analysis is performed automatically on, for example, a computer-based processor to enable decisions regarding rig operational changes. Those decisions are then communicated back to the rig crew personnel—which is reduced in number due to the role of the remote operations center—for execution. As described below, the implementation of those decisions may be automated and executed via a control system at the rig.
• Examples of some of the systems/tasks which may be automated according to the methodology described herein include: downlink-to-rotary steerable systems, control over mud pumps, control over weight on the bit, setting block position, and setting RPMs. Over time, rigs will become more and more automated, allowing for more machine-automated execution, hence reducing the personnel requirements on the rig even more. Still the concepts of embodiments of the present invention will remain the same, because the execution can be done by a machine, a person(s), or a combination of both.
• In embodiments of the present invention described below, parties involved in the remote well management process may include, but are not limited to:
• Well Site Supervisor (Company Man),
• Directional Drilling Personnel,
• Measurement-While-Drilling Personnel,
• Optimization Engineer(s),
• Well Engineer(s),
• Drilling Engineer(s),
• Drilling Superintendent,
• Mud representative(s),
• Rig representative(s),
• Information Technology expert(s),
• Software expert(s), and
• Completions Personnel.
• Other parties are optional and may include: Wireline personnel, Cementing personnel, Fracturing personnel, Coil Tubing personnel, and Testing personnel.
• Referring generally toFIG. 1, a schematic illustration is provided of aremote operations center20 in communication with arig22 positioned over a well24 which may be defined by one ormore wellbores26. In this embodiment, theremote operations center20 may be located a substantial distance fromrig22, and may be positioned at a headquarters or at a variety of other locations around the world. Communications between therig22 and theremote operations center20 are represented byline28, and those communications may be via hard wire, e.g. land lines, wireless, or combinations of hard wired and wireless communication systems. By way of example, wireless, satellite-based communications may be applied to transmit data fromrig22 toremote operations center20 and/or fromremote operations center20 to rig22.
• As illustrated inFIG. 2, both theremote operations center20 and therig22 comprisesignal transmitters30,32, respectively, to transmit signals therebetween. The specific type ofsignal transmitter30,32 depends on the form of communication/communication lines28 employed to deliver data fromrig22 toremote operations center20 and/or to deliver control signals fromremote operations center20 to rig22. In this example,signal transmitter30 further cooperates with acontrol system34 which may be a computer-based control system located atremote operations center20. Thesignal transmitter32 may be coupled into cooperation with acorresponding control system36 located onrig22. Theremote control system34 is used to receive and process data fromrig22. The processing of data may be accomplished solely oncontrol system34, or the processing may be accomplished in cooperation with experts and other personnel atremote operations center20. Therig control system36 is employed to collect and facilitate transmission of data toremote operations center20, but thecontrol system36 also may be employed for carrying out commands regarding operational changes on therig22.
• According to one embodiment,control system36 is used to obtain real-time digital measurements of parameters onrig22. Thecontrol system36 in cooperation withsignal transmitter32 is further employed to automatically transmit the real-time digital measurements to theremote operations center20 for processing. Once the data is processed and/or further analyzed atremote operations center20, a determination is made as to whether rig operational changes are required. If so required, command data related to the operational changes is transmitted back to rig22 viacontrol system34 in cooperation withsignal transmitter30. These rig operational changes are then implemented at therig22 by, for example, automated actions, e.g. utilizing downlink-to-rotary steerable systems, controlling mud pumps, controlling weight on the bit, setting block position, automatically adjusting a toolface position of a downhole motor, automatically adjusting a toolface position of a downhole turbine, automatically adjusting properties, e.g. viscosity, density, fluid loss, and/or other properties, of drilling mud and/or completions mud, and changing drill string RPMs.
• In the embodiment illustrated inFIG. 2, the acquisition of data, e.g. the acquisition of real-time digital measurements of rig parameters, may be accomplished with a variety of different types ofobservation devices38. By way of example,observation devices38 may comprise one ormore video cameras40,microphones42 orsensors44. In the example illustrated,video cameras40,microphones42, andsensors44 are located above the surface onrig22. However, a variety ofobservation devices38 also may be located downhole inwellbore26. Depending on the specific application, a variety ofdownhole sensors46 or other observation devices may be deployed on or in cooperation with various types ofdownhole equipment48. In one example,downhole equipment48 comprises abottom hole assembly50 having a drilling system for rotating adrill bit52 in a wellbore drilling operation. As illustrated, thebottom hole assembly50 may be deployed downhole by asuitable conveyance54, such as drill string, extending down from therig22 positioned at asurface location56.
• The data collected by thevarious observation devices38 is relayed to controlsystem36 viaappropriate communication lines58 which may be wired or wireless communication lines. In this example, the data is accumulated in real-time viacontrol system36 and, in cooperation withsignal transmitter32, is transmitted toremote operations center20. The rig parameters observed and the type ofobservation devices38 employed can vary depending on the specific operation, e.g. drilling operation or other service operation, carried out atrig22.
• Depending on the specific systems and methodology employed,control system34 andcontrol system36 may be constructed according to a variety of configurations. According to one example,control system34 comprises a computer-basedcontrol system60, as illustrated inFIG. 3. In at least some applications, the computer-basedcontrol system60 is an automated system programmed to process and evaluate data received fromrig22 and to automatically transmit command data back to the rig to implement rig operational changes. The computer-basedcontrol system60 may comprise a central processing unit (CPU)62 which is coupled withrig control system36 viasignal transmitters30,32 and communication system/lines28. Additionally, computer-basedcontrol system60 may comprise amemory64, aninput device66, and anoutput device68.
• Input device66 may comprise a variety of devices, such as a keyboard, mouse, voice recognition unit, touchscreen, other input devices, or combinations of such devices.Output device68 may comprise a visual and/or audio output device, such as a monitor having agraphical user interface69.Input device66 andoutput device68 may comprise individual or multiple devices which may be used to facilitate interaction with experts or other personnel located at theremote operations center20. Additionally, the processing may be done on a single device or multiple devices located at theremote operations center20. For example,control system34 may comprise a plurality of computer-basedcontrol systems60 which are networked together or otherwise combined to facilitate remote processing and analysis of data on a variety of rig parameters.
• Rig control system36 similarly may comprise a variety of control systems in the form of individual control devices or plural control devices which function in cooperation. In the embodiment illustrated inFIG. 4,rig control system36 is a computer based processing system designed to intake data on rig parameters from thevarious observation devices38, such as video cameras, microphones, surface sensors, downhole sensors, and other devices designed to detect/measure desired parameters related to the operation ofrig22. Additionally,rig control system36 may be designed to receive control commands from theremote operations center20 via itstransmitter32. Various rig operational changes may be carried out by rig personnel, but those rig operational changes also may be automatically implemented byrig control system36 in many applications. During automated control,rig control system36 communicates with various devices70 (located on therig22 and/or located downhole in the well24) viacommunication lines72 which may be wired or wireless communication lines. Examples of automated functions which may be carried out byrig control system36 include utilizing downlink-to-rotary steerable systems, controlling mud pumps, controlling weight on the bit, setting block position, automatically adjusting a toolface position of a downhole motor, automatically adjusting a toolface position of a downhole turbine, automatically adjusting properties, e.g. viscosity, density, fluid loss, and/or other properties, of drilling mud and/or completions mud, and changing drill string RPMs.
• As described above, the ability to readily communicate data betweenrig22 andremote operations center20 facilitates an improved control over implementation of a given rig operation. Additionally, the ability to perform processing and analysis at theremote operations center20 reduces the number of people that would otherwise be employed on therig22. By implementing the methodology described herein, a relatively small number of personnel may be deployed onrig22, while other personnel are located at a more convenient location, i.e. at theremote operations center20. The combination of automated processing and handling of data combined with the reduced number of rig personnel provides for more efficient and enhanced drilling operations and other rig-based operations.
• The particular arrangement of personnel onrig22 and atremote operations center20 can vary substantially from one application to another. Regardless, the present methodology enables cooperation between a variety of participants without requiring the presence of those participants at therig22. Referring generally toFIG. 5, an example of the interaction of rig personnel and remote operations center personnel to achieve a more efficient rig operation is illustrated.
• In the example illustrated, both adrilling supervisor74 and arig superintendent76 may communicate with each other, observe data, provide instructions, and interact with other systems and personnel onrig22 and atremote operations center20. For example, communications may be established withfactory drilling supervisors78 and withdrilling supervisors80 at one or both locations. Consequently, eachfactory drilling supervisor78 ordrilling supervisor80 is better able to provide input to and receive input from other personnel, includingcompany personnel82,drilling crew personnel84, and other persons and/or equipment atremote operations center20 and/orrig22. For example, the system and methodology enable easy person to person access and interaction with thecontrol systems34,36, e.g. data servers. The interaction between persons/equipment also may include interaction withassistant drilling supervisors86, with regional support centers, withrig safety coordinators88, and with cooperatingthird parties90.
• The staff atremote operations center20 may vary in number and responsibility according to the specific rig operation carried out viarig22. As represented schematically inFIG. 6, examples of functional personnel stationed atremote operations center20 to interact withcontrol system34 may include adirectional driller92 andfactory drilling supervisor78. Other examples of possible personnel stationed atremote operations center20 include anoptimization engineer96 and awell engineer98. Each person may have access to controlsystem34 viaappropriate input devices66 andoutput devices68. The various personnel may monitor data received from theobservation devices38 at the rig site, and they may provide input to improve the manual and/or automated control overrig22. For example, programming adjustments may be made to adjust the automatic control over rig operational changes in response to data received fromobservational devices38. The personnel atremote operations center20 also may perform a variety of additional functions related to monitoring of the rig operation, adjusting the rig operation, communicating information to other interested parties (seeFIG. 5), and carrying out rig operational functions previously conducted by persons stationed on the rig.
• As discussed above, the methodology and systems are employed to simplify control over rig operations with reduced rig personnel. The methodology may be implemented for a variety of rig operations, including drilling operations, which utilize many types of downhole tools and equipment. Several types of bottom hole assemblies and/or other drilling equipment and servicing equipment may be controlled downhole via input from rig personnel and/or remotely located personnel. Additionally, the number and type of observation devices, including downhole sensors, surface sensors, video monitoring equipment, audio equipment, and other types of observation devices may be employed to obtain data for processing and analysis at the remote operations center. The data may be processed and analyzed by different types of processing systems according to desired programs and algorithms alone or in combination with input from personnel at the remote operations center. Various levels of automated control also may be exercised over rig operational changes via control systems located at the remote operations center and/or at the rig.
• Accordingly, although only a few embodiments of the present invention have been described in detail above, those of ordinary skill in the art will readily appreciate that many modifications are possible without materially departing from the teachings of this invention. Such modifications are intended to be included within the scope of this invention as defined in the claims.

Claims (20)

1. A method for constructing a well, comprising:

obtaining real-time digital measurements of parameters on a rig;

automatically transmitting the real-time digital measurements to a remote operations center;

processing the real-time digital measurements at the remote operations center to determine rig operational changes;

transmitting data on the rigged operational changes back to the rig; and

implementing the rig operational changes.

2. The method as recited inclaim 1, wherein obtaining comprises utilizing sensors mounted on the rig.

3. The method as recited inclaim 1, wherein obtaining comprises utilizing cameras located on the rig.

4. The method as recited inclaim 1, wherein obtaining comprises utilizing microphones located on the rig.

5. The method as recited inclaim 1, wherein implementing comprises automatically adjusting a rotary steerable system via a downlink-to-rotary steerable system.

6. The method as recited inclaim 1, wherein implementing comprises automatically adjusting the operation of a mud pump.

7. The method as recited inclaim 1, wherein implementing comprises automatically adjusting the weight on a drill bit.

8. The method as recited inclaim 1, wherein implementing comprises automatically adjusting a block position on the rig.

9. The method as recited inclaim 1, wherein implementing comprises automatically adjusting the RPM of a drilling system.

10. The method as recited inclaim 1, wherein implementing comprises automatically adjusting a toolface position of a downhole motor.

11. The method as recited inclaim 1, wherein implementing comprises automatically adjusting a toolface position of a downhole turbine.

12. The method as recited inclaim 1, wherein implementing comprises automatically adjusting fluid properties of a mud fluid.

13. A method for constructing a well, comprising:

monitoring rig parameters via a plurality of different types of observation devices;

sending data on the rig parameters to a processing system at a remote operations center;

processing and analyzing the data at the remote operations center; and

controlling rig operational changes from the remote operations center based on results obtained from processing and analyzing the data.

14. The method as recited inclaim 13, wherein monitoring comprises obtaining real-time digital measurements.

15. The method as recited inclaim 14, wherein sending comprises automatically sending real-time digital measurement data to the remote operations center.

16. The method as recited inclaim 13, wherein processing and analyzing comprises processing and analyzing the data on a computer-based processing system and outputting results to a graphical user interface.

17. The method as recited inclaim 16, wherein controlling comprises utilizing the computer-based processing system and the remote operations center to automatically control the rig operational changes.

18. A method for efficient well construction, comprising:

reducing the number of personnel on a rig;

utilizing a plurality of observation devices to monitor rig parameters remotely;

making decisions regarding operational changes to the rig at a remote operations center; and

implementing the operational changes from the remote operations center.

19. The method as recited inclaim 18, wherein making decisions comprises processing data from the observation devices on a computer-based processing system located at the remote operations center.

20. The method as recited inclaim 18, wherein implementing comprises automatically changing a plurality of functions on the rig.

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