CA3064218A1 - System for real-time fracking monitoring and feedback based on vibration-analysis amd method therefor - Google Patents
System for real-time fracking monitoring and feedback based on vibration-analysis amd method therefor Download PDFInfo
- Publication number
- CA3064218A1 CA3064218A1 CA3064218A CA3064218A CA3064218A1 CA 3064218 A1 CA3064218 A1 CA 3064218A1 CA 3064218 A CA3064218 A CA 3064218A CA 3064218 A CA3064218 A CA 3064218A CA 3064218 A1 CA3064218 A1 CA 3064218A1
- Authority
- CA
- Canada
- Prior art keywords
- fracking
- vibration
- real
- time
- monitoring
- 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.)
- Pending
Links
Landscapes
- Geophysics And Detection Of Objects (AREA)
Abstract
A fracking-monitoring system has a plurality of vibration-detection units for deployment about a wellbore for detecting vibration signals caused by formation fracturing during a fracking process; and a computing device configured for collecting, in real-time, the vibration signals detected by the plurality of vibration-detection units; calculating, in real-time, the locations of signal sources of the vibration signals; evaluating, in real-time, the fracking process based on a comparison between the calculated locations of the signal sources and a fracking plan of the fracking process; and outputting, in real-time, the evaluating results for adjusting the fracking process.
Description
SYSTEM FOR REAL-TIME FRACKING MONITORING AND FEEDBACK BASED
ON VIBRATION-ANALYSIS AND METHOD THEREFOR
FIELD OF THE DISCLOSURE
The present disclosure relates generally to systems and methods for monitoring downhole fracking and for providing feedback therefore, and in particular, to systems and methods for monitoring downhole fracking and for providing feedback therefore based on analysis of vibration and/or seismic signals caused by formation fracturing.
BACKGROUND
In oil and gas industries, downhole fracking is often a necessary step for preparing a subterranean formation for hydrocarbon production. In downhole fracking, a high-pressure fracking fluid is pumped into a wellbore and jets out from a section of a perforated casing into the formation to create cracks therein. The created cracks facilitate the flow of hydrocarbon into a production wellbore for collection therein. The collected hydrocarbon is then moved to the surface via, e.g., artificial lifting.
An issue in downhole fracking is that the fracking results may vary due to the variation of subterranean formation conditions. However, there generally lacks reliable means in the prior art for monitoring fracking results in real time, thereby causing insufficient fracking and subsequently, reduced hydrocarbon production and/or causing fracking incidents, induced seismicity events, and/or negative environmental impacts in surrounding areas.
SUMMARY
Embodiments disclosed herein relate to systems and methods for monitoring downhole fracking and for providing feedback therefore, based on analysis of vibration and/or seismic data obtained from vibration detection devices such as geophones.
In various embodiments, the system comprises a vibration-sensor network having a plurality of vibration-detection sensors deployed in a fracking area about one or more fracking wellbores. Alternatively, the wellbore may be a drilling, an injection and/or a production well.
In various embodiments, the vibration-detection sensors may be deployed in any suitable layout such as a one-dimensional (1D) arrangement along a line or a curve, a two-dimensional (2D) arrangement, or a three-dimensional (3D) arrangement.
In various embodiments, the vibration-detection sensors may be deployed on the surface, or buried at suitable depths, or installed in wellbores, or combinations thereof. The system records the locations of the vibration-detection sensors and configures the vibration-detection sensors to monitor vibrations caused by downhole-fracking.
During downhole fracking, the fracturing of formations causes micro-seismic signals (which are generally vibration signals) generated at various downhole locations (denoted as fracking and seismic-event locations). The micro-seismic signals travel in the earth and are detected by the vibration-detection sensors.
ON VIBRATION-ANALYSIS AND METHOD THEREFOR
FIELD OF THE DISCLOSURE
The present disclosure relates generally to systems and methods for monitoring downhole fracking and for providing feedback therefore, and in particular, to systems and methods for monitoring downhole fracking and for providing feedback therefore based on analysis of vibration and/or seismic signals caused by formation fracturing.
BACKGROUND
In oil and gas industries, downhole fracking is often a necessary step for preparing a subterranean formation for hydrocarbon production. In downhole fracking, a high-pressure fracking fluid is pumped into a wellbore and jets out from a section of a perforated casing into the formation to create cracks therein. The created cracks facilitate the flow of hydrocarbon into a production wellbore for collection therein. The collected hydrocarbon is then moved to the surface via, e.g., artificial lifting.
An issue in downhole fracking is that the fracking results may vary due to the variation of subterranean formation conditions. However, there generally lacks reliable means in the prior art for monitoring fracking results in real time, thereby causing insufficient fracking and subsequently, reduced hydrocarbon production and/or causing fracking incidents, induced seismicity events, and/or negative environmental impacts in surrounding areas.
SUMMARY
Embodiments disclosed herein relate to systems and methods for monitoring downhole fracking and for providing feedback therefore, based on analysis of vibration and/or seismic data obtained from vibration detection devices such as geophones.
In various embodiments, the system comprises a vibration-sensor network having a plurality of vibration-detection sensors deployed in a fracking area about one or more fracking wellbores. Alternatively, the wellbore may be a drilling, an injection and/or a production well.
In various embodiments, the vibration-detection sensors may be deployed in any suitable layout such as a one-dimensional (1D) arrangement along a line or a curve, a two-dimensional (2D) arrangement, or a three-dimensional (3D) arrangement.
In various embodiments, the vibration-detection sensors may be deployed on the surface, or buried at suitable depths, or installed in wellbores, or combinations thereof. The system records the locations of the vibration-detection sensors and configures the vibration-detection sensors to monitor vibrations caused by downhole-fracking.
During downhole fracking, the fracturing of formations causes micro-seismic signals (which are generally vibration signals) generated at various downhole locations (denoted as fracking and seismic-event locations). The micro-seismic signals travel in the earth and are detected by the vibration-detection sensors.
2 In some embodiments, the system processes vibration signals detected by the vibration-detection sensors and uses signal arrival-time differences to calculate the fracking and seismic-event locations. The calculated fracking and seismic-event locations are then compared with the drilling, fracking, injection, and/or production plans to verify the work progress. The progress-verification results are fed back to the operators for facilitating the monitoring and prediction of fracking-progress directions, for determining if any fracking and seismic-event locations deviate from the plans, and/or the like. Necessary adjustments to the fracking process may then be conducted such as slowing down the fracking or injection work activities, adjusting the injection pressure of the fracking liquid, changing the fracking locations, or stopping fracking in the area. Therefore, the system may help in improving hydrocarbon production and/or preventing fracking incidents, induced seismicity events, and/or negative environmental impacts in surrounding areas.
In some embodiments, the system processes vibration signals detected by the vibration-detection sensors and determines the fracking and seismic-event locations. The system then compares the determined fracking and seismic-event locations with predetermined plans for evaluating the fracking results, and automatically uses the evaluation results to adjust the fracking processes.
BRIEF DESCRIPTION OF THE DRAWINGS
FIG. 1 is a schematic diagram of a fracking-monitoring system, according to some embodiments of the present disclosure;
In some embodiments, the system processes vibration signals detected by the vibration-detection sensors and determines the fracking and seismic-event locations. The system then compares the determined fracking and seismic-event locations with predetermined plans for evaluating the fracking results, and automatically uses the evaluation results to adjust the fracking processes.
BRIEF DESCRIPTION OF THE DRAWINGS
FIG. 1 is a schematic diagram of a fracking-monitoring system, according to some embodiments of the present disclosure;
3 FIG. 2A is a schematic plan view of an area for downhole-fracking, according to one embodiment of this disclosure, wherein a plurality of vibration-detection units of the fracking-monitoring system shown in FIG. 1 are deployed in the area on the surface or are buried at suitable depths as a two-dimensional (2D) matrix about a surface-projection of the injection wellbore;
FIG. 2B is a schematic plan view of an area for downhole-fracking, according to another embodiment of this disclosure, wherein a plurality of vibration-detection units of the fracking-monitoring system shown in FIG. I are deployed in the area on the surface or are buried at suitable depths in a 2D circle about a surface-projection of the injection wellbore;
FIG. 2C is a schematic plan view of an area for downhole-fracking, according to yet another embodiment of this disclosure, wherein a plurality of vibration-detection units of the fracking-monitoring system shown in FIG. 1 are deployed in the area on the surface or are buried at suitable depths in a 2D irregular shape about a surface-projection of the injection wellbore;
FIG. 2D is a schematic plan view of an area for downhole-fracking, according to still another embodiment of this disclosure, wherein a plurality of vibration-detection units of the fracking-monitoring system shown in FIG. 1 are deployed in the area on the surface or are buried at suitable depths along a one-dimensional (1D) line about a surface-projection of the injection wellbore;
FIG. 3A shows the hardware structure of a computing device of the fracking-monitoring system shown in FIG. 1;
FIG. 2B is a schematic plan view of an area for downhole-fracking, according to another embodiment of this disclosure, wherein a plurality of vibration-detection units of the fracking-monitoring system shown in FIG. I are deployed in the area on the surface or are buried at suitable depths in a 2D circle about a surface-projection of the injection wellbore;
FIG. 2C is a schematic plan view of an area for downhole-fracking, according to yet another embodiment of this disclosure, wherein a plurality of vibration-detection units of the fracking-monitoring system shown in FIG. 1 are deployed in the area on the surface or are buried at suitable depths in a 2D irregular shape about a surface-projection of the injection wellbore;
FIG. 2D is a schematic plan view of an area for downhole-fracking, according to still another embodiment of this disclosure, wherein a plurality of vibration-detection units of the fracking-monitoring system shown in FIG. 1 are deployed in the area on the surface or are buried at suitable depths along a one-dimensional (1D) line about a surface-projection of the injection wellbore;
FIG. 3A shows the hardware structure of a computing device of the fracking-monitoring system shown in FIG. 1;
4 FIG. 3B shows a simplified software architecture of a computing device of the fracking-monitoring system shown in FIG. 1;
FIG. 4 shows the hardware structure of a vibration-detection unit of the fracking-monitoring system shown in FIG. 1; and FIG. 5 is a flowchart showing the steps of a fracking-monitoring process executed by the fracking-monitoring system shown in FIG. 1.
DETAILED DESCRIPTION
Turning now to FIG. 1, a fracking-monitoring system is shown, and is generally identified using reference numeral 100. As shown, the fracking-monitoring system 100 comprises a server computer 102 and one or more client-computing devices 104 functionally interconnected by a network 106, for example, such as the Internet, a local area network (LAN), a wide area network (WAN), and/or the like, via suitable wired and/or wireless networking connections.
The fracking-monitoring system 100 also comprises one or more fracking devices for fracking subterranean formation through one or more wellbores 114. The fracking-monitoring system 100 further comprises a plurality of vibration-detection units 110 with suitable wired or wireless communication interfaces for functionally connecting to one or more data hubs 112 via suitable wired and wireless networking connections. The data
FIG. 4 shows the hardware structure of a vibration-detection unit of the fracking-monitoring system shown in FIG. 1; and FIG. 5 is a flowchart showing the steps of a fracking-monitoring process executed by the fracking-monitoring system shown in FIG. 1.
DETAILED DESCRIPTION
Turning now to FIG. 1, a fracking-monitoring system is shown, and is generally identified using reference numeral 100. As shown, the fracking-monitoring system 100 comprises a server computer 102 and one or more client-computing devices 104 functionally interconnected by a network 106, for example, such as the Internet, a local area network (LAN), a wide area network (WAN), and/or the like, via suitable wired and/or wireless networking connections.
The fracking-monitoring system 100 also comprises one or more fracking devices for fracking subterranean formation through one or more wellbores 114. The fracking-monitoring system 100 further comprises a plurality of vibration-detection units 110 with suitable wired or wireless communication interfaces for functionally connecting to one or more data hubs 112 via suitable wired and wireless networking connections. The data
5 hubs 112 collect vibration data from the vibration-detection units 110 and transmit the collected data to the server computer 102 via the network 106.
In some embodiments, one or more vibration-detection units 110 may directly communicate with the server computer 102 for directly sending vibration data thereto.
The vibration-detection units 110 may comprise any suitable vibration-detection sensors such as geophones, micro-electromechanical systems (MEMS) sensors, and/or the like.
In some embodiments, the vibration-detection units 110 may comprise high-sensitivity vibration-detection sensors for detecting the micro-seismic signals caused by formation fracturing. In some alternative embodiments, the vibration-detection units 110 may comprise conventional vibration-detection sensors with moderate sensitivity and may use suitable signal processing techniques to detect the micro-seismic signals. An example of such techniques is described in Applicant's PCT Patent Application Serial No. PCT/CA2017/051359, the content of which is incorporated herein by reference in its entirety.
The vibration-detection units 110 may be deployed about the one or more wellbores 114 or about the projection of the one or more wellbores 114 to the surface in any suitable one-dimensional (1D), two-dimensional (2D), or three-dimensional (3D) manner.
For example, FIG. 2A is a schematic plan view of an area for downhole-fracking in one embodiment. The vibration-detection units 110 are deployed in the area on the surface or buried at suitable depths as a 2D matrix 116 about a surface-projection of the injection wellbore 114, wherein the neighboring vibration-detection units 110 are spaced at a same distance.
In some embodiments, one or more vibration-detection units 110 may directly communicate with the server computer 102 for directly sending vibration data thereto.
The vibration-detection units 110 may comprise any suitable vibration-detection sensors such as geophones, micro-electromechanical systems (MEMS) sensors, and/or the like.
In some embodiments, the vibration-detection units 110 may comprise high-sensitivity vibration-detection sensors for detecting the micro-seismic signals caused by formation fracturing. In some alternative embodiments, the vibration-detection units 110 may comprise conventional vibration-detection sensors with moderate sensitivity and may use suitable signal processing techniques to detect the micro-seismic signals. An example of such techniques is described in Applicant's PCT Patent Application Serial No. PCT/CA2017/051359, the content of which is incorporated herein by reference in its entirety.
The vibration-detection units 110 may be deployed about the one or more wellbores 114 or about the projection of the one or more wellbores 114 to the surface in any suitable one-dimensional (1D), two-dimensional (2D), or three-dimensional (3D) manner.
For example, FIG. 2A is a schematic plan view of an area for downhole-fracking in one embodiment. The vibration-detection units 110 are deployed in the area on the surface or buried at suitable depths as a 2D matrix 116 about a surface-projection of the injection wellbore 114, wherein the neighboring vibration-detection units 110 are spaced at a same distance.
6 FIG. 2B is a schematic plan view of an area for downhole-fracking in another embodiment. The vibration-detection units 110 are deployed in the area on the surface or are buried at suitable depths in a 2D circle 116 about a surface-projection of the injection wellbore 114, wherein the neighboring vibration-detection units 110 are spaced apart at a selected same distance.
FIG. 2C is a schematic plan view of an area for downhole-fracking in yet another embodiment. The vibration-detection units 110 are deployed in the area on the surface or are buried at suitable depths in a 2D irregular shape 116 about a surface-projection of the injection wellbore 114, wherein the neighboring vibration-detection units 110 are spaced apart at different distances.
FIG. 2D is a schematic plan view of an area for downhole-fracking in still another embodiment. The vibration-detection units 110 are deployed in the area on the surface or are buried at suitable depths along a 1D line 116 about a surface-projection of the injection wellbore 114, wherein the neighboring vibration-detection units 110 are spaced apart at a selected same distance. This deployment of the vibration-detection units 110 in this embodiment may be useful for monitoring the fracking process and preventing formation-fracturing from expanding to an environmentally sensitive neighboring area.
Although not shown, the vibration-detection units 110 in some embodiments may be deployed in a 3D manner on the surface or may be buried at suitable depths for adapting to the geographic characteristics of the area about the injection wellbore 114.
FIG. 2C is a schematic plan view of an area for downhole-fracking in yet another embodiment. The vibration-detection units 110 are deployed in the area on the surface or are buried at suitable depths in a 2D irregular shape 116 about a surface-projection of the injection wellbore 114, wherein the neighboring vibration-detection units 110 are spaced apart at different distances.
FIG. 2D is a schematic plan view of an area for downhole-fracking in still another embodiment. The vibration-detection units 110 are deployed in the area on the surface or are buried at suitable depths along a 1D line 116 about a surface-projection of the injection wellbore 114, wherein the neighboring vibration-detection units 110 are spaced apart at a selected same distance. This deployment of the vibration-detection units 110 in this embodiment may be useful for monitoring the fracking process and preventing formation-fracturing from expanding to an environmentally sensitive neighboring area.
Although not shown, the vibration-detection units 110 in some embodiments may be deployed in a 3D manner on the surface or may be buried at suitable depths for adapting to the geographic characteristics of the area about the injection wellbore 114.
7 In some embodiments, at least some of the vibration-detection units 110 may be deployed in the injection wellbore 114.
In some embodiments, at least some of the vibration-detection units 110 may be deployed under water.
Referring back to FIG. 1, depending on implementation, the server computer 102 may be a server-computing device and/or a general purpose computing device acting as a server computer while also being used by a user. The server computer 102 executes one or more server programs.
Each client-computing device 104 executes one or more client application programs and for users to use. The client-computing devices 104 in these embodiments are preferably portable computing devices such as laptop computers, tablets, smartphones, Personal Digital Assistants (PDAs) and the like. However, those skilled in the art will appreciate that one or more client-computing devices 104 may be non-portable computing devices such as desktop computers in some alternative embodiments.
Generally, the computing devices 102 and 104 have a similar hardware structure such as a hardware structure 120 shown in FIG. 3A. As shown, the computing device comprises a processing structure 122, a controlling structure 124, a memory or storage 126, a networking interface 128, a coordinate input 130, a display output 132, and other input and output modules 134 and 136, all functionally interconnected by a system bus 138.
The processing structure 122 may be one or more single-core or multiple-core computing processors such as INTEL microprocessors (INTEL is a registered trademark of
In some embodiments, at least some of the vibration-detection units 110 may be deployed under water.
Referring back to FIG. 1, depending on implementation, the server computer 102 may be a server-computing device and/or a general purpose computing device acting as a server computer while also being used by a user. The server computer 102 executes one or more server programs.
Each client-computing device 104 executes one or more client application programs and for users to use. The client-computing devices 104 in these embodiments are preferably portable computing devices such as laptop computers, tablets, smartphones, Personal Digital Assistants (PDAs) and the like. However, those skilled in the art will appreciate that one or more client-computing devices 104 may be non-portable computing devices such as desktop computers in some alternative embodiments.
Generally, the computing devices 102 and 104 have a similar hardware structure such as a hardware structure 120 shown in FIG. 3A. As shown, the computing device comprises a processing structure 122, a controlling structure 124, a memory or storage 126, a networking interface 128, a coordinate input 130, a display output 132, and other input and output modules 134 and 136, all functionally interconnected by a system bus 138.
The processing structure 122 may be one or more single-core or multiple-core computing processors such as INTEL microprocessors (INTEL is a registered trademark of
8 Intel Corp., Santa Clara, CA, USA), AMD microprocessors (AMD is a registered trademark of Advanced Micro Devices Inc., Sunnyvale, CA, USA), ARM microprocessors (ARM
is a registered trademark of Arm Ltd., Cambridge, UK) manufactured by a variety of manufactures such as Qualcomm of San Diego, California, USA, under the ARM
architecture, or the like.
The controlling structure 124 comprises a plurality of controllers, such as graphic controllers, input/output chipsets and the like, for coordinating operations of various hardware components and modules of the computing device 102/104.
The memory 126 comprises a plurality of memory units accessible by the processing structure 122 and the controlling structure 124 for reading and/or storing data, including input data and data generated by the processing structure 122 and the controlling structure 124. The memory 126 may be volatile and/or non-volatile, non-removable or removable memory such as RAM, ROM, EEPROM, solid-state memory, hard disks, CD, DVD, flash memory, or the like. In use, the memory 126 is generally divided to a plurality of portions for different use purposes. For example, a portion of the memory 126 (denoted as storage memory herein) may be used for long-term data storing, for example, for storing files or databases. Another portion of the memory 126 may be used as the system memory for storing data during processing (denoted as working memory herein).
The networking interface 128 comprises one or more networking modules for .. connecting to other computing devices or networks through the network 106 by using suitable wired or wireless communication technologies such as Ethernet, WI-FI , (WI-Fl is a registered trademark of Wi-Fi Alliance, Austin, TX, USA), BLUETOOTH
(BLUETOOTH
is a registered trademark of Arm Ltd., Cambridge, UK) manufactured by a variety of manufactures such as Qualcomm of San Diego, California, USA, under the ARM
architecture, or the like.
The controlling structure 124 comprises a plurality of controllers, such as graphic controllers, input/output chipsets and the like, for coordinating operations of various hardware components and modules of the computing device 102/104.
The memory 126 comprises a plurality of memory units accessible by the processing structure 122 and the controlling structure 124 for reading and/or storing data, including input data and data generated by the processing structure 122 and the controlling structure 124. The memory 126 may be volatile and/or non-volatile, non-removable or removable memory such as RAM, ROM, EEPROM, solid-state memory, hard disks, CD, DVD, flash memory, or the like. In use, the memory 126 is generally divided to a plurality of portions for different use purposes. For example, a portion of the memory 126 (denoted as storage memory herein) may be used for long-term data storing, for example, for storing files or databases. Another portion of the memory 126 may be used as the system memory for storing data during processing (denoted as working memory herein).
The networking interface 128 comprises one or more networking modules for .. connecting to other computing devices or networks through the network 106 by using suitable wired or wireless communication technologies such as Ethernet, WI-FI , (WI-Fl is a registered trademark of Wi-Fi Alliance, Austin, TX, USA), BLUETOOTH
(BLUETOOTH
9 is a registered trademark of Bluetooth Sig Inc., Kirkland, WA, USA), ZIGBEE
(ZIGBEE is a registered trademark of ZigBee Alliance Corp., San Ramon, CA, USA), 3G and 4G wireless mobile telecommunications technologies, and/or the like. In some embodiments, parallel ports, serial ports, USB connections, optical connections, or the like may also be used for connecting other computing devices or networks although they are usually considered as input/output interfaces for connecting input/output devices.
The display output 132 comprises one or more display modules for displaying images, such as monitors, LCD displays, LED displays, projectors, and the like. The display output 132 may be a physically integrated part of the computing device 102/104 (for example, the display of a laptop computer or tablet), or alternatively, it may be a display device physically separate from but functionally coupled to other components of the computing device 102/104 (for example, the monitor of a desktop computer).
The coordinate input 130 comprises one or more input modules for one or more users to input coordinate data wherein the input modules may be touch-sensitive screens, touch-sensitive whiteboards, trackballs, computer mouse, touch-pads, or other human interface devices (HID), and the like. The coordinate input 130 may be a physically integrated part of the computing device 102/104 (for example, the touch-pad of a laptop computer or the touch-sensitive screen of a tablet), or it may be a display device physically separate from, but functionally coupled to, other components of the computing device 102/104 (for example, a computer mouse). The coordinate input 130, in some implementation, may be integrated with the display output 132 to form a touch-sensitive screen or a touch-sensitive whiteboard.
The computing device 102/104 may also comprise other inputs 134 such as keyboards, microphones, scanners, cameras, and the like. The computing device 102/104 may further comprise other outputs 136 such as speakers, printers, positioning modules for example GPS
modules, and the like.
The system bus 138 interconnects various components 122 to 136 enabling them to transmit and receive data and control signals to and from each other.
FIG. 3B shows a simplified software architecture 200 of a computing device 102/104.
The software architecture 200 comprises an application layer 202, an operating system 206, an input interface 208, an output interface 212 and a logic memory 220. The application layer 202 comprises one or more application programs 204 executed or run by the processing structure 122 for performing various jobs. The operating system 206 manages various hardware components of the computing device 102/104 via the input interface 208 and the output interface 212, manages the logic memory 220, and manages and supports the application programs 204. The operating system 206 is also in communication with other computing devices (not shown) via the network 106 to allow application programs 204 to communicate with application programs running on other computing devices.
As those skilled in the art will appreciate, the operating system 206 may be any suitable operating system such as MICROSOFT WINDOWS (MICROSOFT and WINDOWS are registered trademarks of the Microsoft Corp., Redmond, WA, USA), APPLE OS X, APPLE
iOS (APPLE is a registered trademark of Apple Inc., Cupertino, CA, USA), Linux, ANDROID (ANDRIOD is a registered trademark of Google Inc., Mountain View, CA, USA), or the like. The computing devices 102/104 of the fracking-monitoring system 100 may all have the same operating system, or may have different operating systems.
The input interface 208 comprises one or more input device drivers 210 for communicating with respective input devices including the coordinate input 150. The output interface 212 comprises one or more output device drivers 214 managed by the operating system 206 for communicating with respective output devices including the display output 152. Input data received from the input devices via the input interface 208 are sent to the application layer 202, and are processed by one or more application programs 204. The output generated by the application programs 204 is sent to respective output devices via the output interface 212.
The logical memory 220 is a logical mapping of the physical memory 146 for facilitating access by the application programs 204. In this embodiment, the logical memory 220 comprises a storage memory area that may be mapped to a non-volatile physical memory, such as hard disks, solid state disks, flash drives, and the like, for generally long-term storage of data therein. The logical memory 220 also comprises a working memory area that is generally mapped to a high-speed, and in some implementations, volatile, physical memory such as RAM, for application programs 204 to generally temporarily store data during program execution. For example, an application program 204 may load data from the storage memory area into the working memory area, and may store data generated during its execution into the working memory area. The application program 204 may also store some data into the storage memory area as required or in response to a user's command.
In a server computer 102 or a client-computing device when acting as a server 102, the application layer 202 generally comprises one or more server application programs 204, which provide server-side functions for managing network communication with client-computing devices 104, and facilitate the vibration analysis processes.
In a client-computing device 104, the application layer 202 generally comprises one or more client-application programs 204 which provide client-side functions for communicating with the server application programs 204, displaying information and data on the graphic user interface (GUI) thereof, receiving user's instructions, and collaborating with the server application programs 204 for managing the data hubs 112 and/or the vibration-detection units 110, collecting vibration data, and the like.
The vibration-detection units 110 are usually deployed in an application field or site, and may operate continuously or intermittently to collect vibration/seismic data. Each sensing unit operates independently and transmits collected data to a receiving device via suitable wired or wireless means.
FIG. 4 is a block diagram showing the structure of a vibration-detection unit 110. As shown, the vibration-detection unit 110 in these embodiments comprises a plurality of components or modules interconnected via a bus or necessary circuit 300. In particular, the vibration-detection unit 110 comprises a vibration-detection sensor 302 such as a geophone, a MEMS sensor, or the like. The output vibration signal of the vibration-detection sensor 302 is processed by an analog-to-digital (AID) converter 304 to convert into a digital vibration signal which is then sent to a network module 306 for communication with a receiving device such as a data hub 112 or the server computer 102 to transmit the digital vibration signal thereto. The network module 306 may use any suitable wired or wireless communication technology to communicate with the data hub 112 or the server computer 102.
However, in these embodiments, it is preferable that the network module 306 uses a suitable wireless communication technology such as BLUETOOTH , ZIGBEE , 3G and 4G wireless mobile telecommunications technologies, and/or the like to communicate with the data hub 112 or the server computer 102.
The digital vibration signal may also be temporarily stored in a storage 308 for various purposes. For example, the digital vibration signal output from the A/D
converter 304 may be temporarily stored in the storage 308 when the wireless communication module 306 fails to .. establish a connection with the data hub 112.
The vibration-detection unit 110 may also comprise a positioning module 310 such as a GPS module for providing the location information of the vibration-detection unit 110.
Therefore, the vibration-detection units 110 may be easily relocated without the need for manually recording the locations thereof. The locations of the vibration-detection units 110 are recorded in the system 100 such as in a database of the server computer 102 for determining the fracking and seismic-event locations.
The vibration-detection unit 110 may further comprise a local communication interface 312 for communication with a receiving device in proximity therewith and for downloading the vibration data thereto. In some embodiments, the local communication interface 312 may be a wired connection interface such as a USB port, a HDMI
port, a serial port, a parallel port, and the like. In some alternative embodiments, the local communication interface 312 may be a wireless connection interface such as a near-field communication (NFC) interface. In some embodiments, a receiving device in proximity with a vibration-detection unit 110 may also communicate with the network module 306 for downloading the vibration data.
The vibration-detection unit 110 also comprises a control circuit 314 which may be a programmable micro-controller or a suitable circuitry such as an integrated circuit (IC) for example, a field-programmable gate array (FPGA), an application-specific integrated circuit (ASIC), or the like, for controlling the operation of various modules 302 to 312, and for performing other functions such as signal processing, self-temperature monitoring and adjustment, signal quality control, clock trimming, power reservation, and/or the like. A
power source 316 such as a rechargeable battery pack and/or a solar panel, powers the modules 302 to 314 for extended operation times without recharging. In these embodiments, the control circuit 314 also controls the operation of the power source 316.
In some embodiments, the control circuit 314 communicates with a controller device such as the server computer 102 or a client-computing device 104 through the network module 306 and via the network 106 for remotely turning the vibration-detection unit 110 on or off.
FIG. 5 is a flowchart showing the steps of a fracking-monitoring process 400 executed by the system 100. The process 400 starts when one or more vibration-detection sensors 302 deployed at a site are powered on and initialized (step 402). Each vibration-detection sensor 302 detects vibration (step 404) and sends the detected vibration data and the position thereof to the data hub 112 (step 406).
Each data hub 112 is functionally connected to one or more vibration-detection sensors 302 and collects data including the vibration data and the position information from the vibration-detection sensors 302 connected thereto (step 408). The data hub 112 then forwards the collected data to the sever computer 102 (step 410).
At step 412, the server computer 102 receives vibration data and the associated position information. At step 416, the server computer 102 processes the vibration data and calculates the fracking and seismic-event locations.
At this step, the server computer 102 may use any suitable method to calculate the fracking and seismic-event locations. For example, in one embodiment, the server computer 102 may use signal arrival-time differences (i.e., the differences between the times of the vibration-signals arriving the vibration-detection sensors 302) to calculate the fracking and seismic-event locations.
At step 418, the locations are then compared with the drilling, fracking, injection, and production plans to verify the work progress. The progress-verification results may be used for monitoring and predicting fracking directions, determining if any fracking and seismic-event locations deviate from the plans, and/or the like. In this embodiment, the progress-verification results are used for controlling the one or more fracking devices 108 to adjust the fracking process such as slowing down the fracking or injection work activities, adjusting the injection pressure of the fracking liquid, changing fracking location, or stopping fracking in the area. The server computer 102 may also send the progress-verification results to one or more client-computing devices 104 for users to review.
With above-described design, the system 100 may monitor fracking progresses and make necessary adjustments thereto in real-time and help in improving hydrocarbon production and/or preventing fracking incidents, induced seismicity events, and/or negative environmental impacts in surrounding areas.
In above embodiments, each vibration-detection unit 110 comprises a positioning module 310 for providing position information to the server computer 102. In some alternative embodiments, at least one vibration-detection unit 110 does not comprise any positioning module 310. In these embodiments, such a vibration-detection unit 110 is deployed at a known location, and server computer 102 stores the location thereof. In the event that such vibration-detection unit 110 is redeployed, the new position thereof may be manually obtained for updating the corresponding record stored by the server computer 102.
Although in above embodiments, the fracking-monitoring system 100 is used for monitoring downhole fracking processes, those skilled in the art will appreciate that the fracking-monitoring system 100 may be used in other processes that may cause subterranean earth-fracturing.
For example, during hydrocarbon production, waste water may be injected into predrilled or obsolete wellbores for disposal. The injection of waste water may cause undesired subterranean earth-fracturing that may lead to negative environmental impacts. In some embodiments, the fracking-monitoring system 100 may be used for monitoring possible subterranean earth-fracturing during waste-water injection processes and providing alerts or adjusting the waste-water injection processes if subterranean earth-fracturing occurs or if subterranean earth-fracturing has expanded beyond a predefined threshold range.
In some embodiments, the fracking-monitoring system 100 may be used for monitoring geothermal-production processes wherein low-temperature water is injected into a geothermal-wellbore for heat exchange and cycles back to surface with a high-temperature.
The water injection may cause undesired subterranean earth-fracturing that may lead to negative environmental impacts. In these embodiments, the fracking-monitoring system 100 may be used for monitoring possible subterranean earth-fracturing during geothermal-production processes and providing alerts or adjusting the geothermal-production processes if subterranean earth-fracturing occurs or if subterranean earth-fracturing has expanded beyond a predefined threshold range.
In some embodiments, the fracking-monitoring system 100 may be used for monitoring steam-injection processes in Steam-assisted gravity drainage (SAGD) projects wherein high-temperature steam is injected into a wellbore for heating the hydrocarbon in a subterranean formation for reducing the viscosity thereof and subsequently increasing hydrocarbon production. The steam injection may cause undesired subterranean earth-fracturing (such as fracturing the caprock in surrounding areas) that may lead to negative environmental impacts. In these embodiments, the fracking-monitoring system 100 may be used for monitoring possible subterranean earth-fracturing or caprock-fracturing during steam-injection processes and providing alerts or adjusting the steam-injection processes if subterranean earth-fracturing occurs or if subterranean earth-fracturing has expanded beyond a predefined threshold range.
(ZIGBEE is a registered trademark of ZigBee Alliance Corp., San Ramon, CA, USA), 3G and 4G wireless mobile telecommunications technologies, and/or the like. In some embodiments, parallel ports, serial ports, USB connections, optical connections, or the like may also be used for connecting other computing devices or networks although they are usually considered as input/output interfaces for connecting input/output devices.
The display output 132 comprises one or more display modules for displaying images, such as monitors, LCD displays, LED displays, projectors, and the like. The display output 132 may be a physically integrated part of the computing device 102/104 (for example, the display of a laptop computer or tablet), or alternatively, it may be a display device physically separate from but functionally coupled to other components of the computing device 102/104 (for example, the monitor of a desktop computer).
The coordinate input 130 comprises one or more input modules for one or more users to input coordinate data wherein the input modules may be touch-sensitive screens, touch-sensitive whiteboards, trackballs, computer mouse, touch-pads, or other human interface devices (HID), and the like. The coordinate input 130 may be a physically integrated part of the computing device 102/104 (for example, the touch-pad of a laptop computer or the touch-sensitive screen of a tablet), or it may be a display device physically separate from, but functionally coupled to, other components of the computing device 102/104 (for example, a computer mouse). The coordinate input 130, in some implementation, may be integrated with the display output 132 to form a touch-sensitive screen or a touch-sensitive whiteboard.
The computing device 102/104 may also comprise other inputs 134 such as keyboards, microphones, scanners, cameras, and the like. The computing device 102/104 may further comprise other outputs 136 such as speakers, printers, positioning modules for example GPS
modules, and the like.
The system bus 138 interconnects various components 122 to 136 enabling them to transmit and receive data and control signals to and from each other.
FIG. 3B shows a simplified software architecture 200 of a computing device 102/104.
The software architecture 200 comprises an application layer 202, an operating system 206, an input interface 208, an output interface 212 and a logic memory 220. The application layer 202 comprises one or more application programs 204 executed or run by the processing structure 122 for performing various jobs. The operating system 206 manages various hardware components of the computing device 102/104 via the input interface 208 and the output interface 212, manages the logic memory 220, and manages and supports the application programs 204. The operating system 206 is also in communication with other computing devices (not shown) via the network 106 to allow application programs 204 to communicate with application programs running on other computing devices.
As those skilled in the art will appreciate, the operating system 206 may be any suitable operating system such as MICROSOFT WINDOWS (MICROSOFT and WINDOWS are registered trademarks of the Microsoft Corp., Redmond, WA, USA), APPLE OS X, APPLE
iOS (APPLE is a registered trademark of Apple Inc., Cupertino, CA, USA), Linux, ANDROID (ANDRIOD is a registered trademark of Google Inc., Mountain View, CA, USA), or the like. The computing devices 102/104 of the fracking-monitoring system 100 may all have the same operating system, or may have different operating systems.
The input interface 208 comprises one or more input device drivers 210 for communicating with respective input devices including the coordinate input 150. The output interface 212 comprises one or more output device drivers 214 managed by the operating system 206 for communicating with respective output devices including the display output 152. Input data received from the input devices via the input interface 208 are sent to the application layer 202, and are processed by one or more application programs 204. The output generated by the application programs 204 is sent to respective output devices via the output interface 212.
The logical memory 220 is a logical mapping of the physical memory 146 for facilitating access by the application programs 204. In this embodiment, the logical memory 220 comprises a storage memory area that may be mapped to a non-volatile physical memory, such as hard disks, solid state disks, flash drives, and the like, for generally long-term storage of data therein. The logical memory 220 also comprises a working memory area that is generally mapped to a high-speed, and in some implementations, volatile, physical memory such as RAM, for application programs 204 to generally temporarily store data during program execution. For example, an application program 204 may load data from the storage memory area into the working memory area, and may store data generated during its execution into the working memory area. The application program 204 may also store some data into the storage memory area as required or in response to a user's command.
In a server computer 102 or a client-computing device when acting as a server 102, the application layer 202 generally comprises one or more server application programs 204, which provide server-side functions for managing network communication with client-computing devices 104, and facilitate the vibration analysis processes.
In a client-computing device 104, the application layer 202 generally comprises one or more client-application programs 204 which provide client-side functions for communicating with the server application programs 204, displaying information and data on the graphic user interface (GUI) thereof, receiving user's instructions, and collaborating with the server application programs 204 for managing the data hubs 112 and/or the vibration-detection units 110, collecting vibration data, and the like.
The vibration-detection units 110 are usually deployed in an application field or site, and may operate continuously or intermittently to collect vibration/seismic data. Each sensing unit operates independently and transmits collected data to a receiving device via suitable wired or wireless means.
FIG. 4 is a block diagram showing the structure of a vibration-detection unit 110. As shown, the vibration-detection unit 110 in these embodiments comprises a plurality of components or modules interconnected via a bus or necessary circuit 300. In particular, the vibration-detection unit 110 comprises a vibration-detection sensor 302 such as a geophone, a MEMS sensor, or the like. The output vibration signal of the vibration-detection sensor 302 is processed by an analog-to-digital (AID) converter 304 to convert into a digital vibration signal which is then sent to a network module 306 for communication with a receiving device such as a data hub 112 or the server computer 102 to transmit the digital vibration signal thereto. The network module 306 may use any suitable wired or wireless communication technology to communicate with the data hub 112 or the server computer 102.
However, in these embodiments, it is preferable that the network module 306 uses a suitable wireless communication technology such as BLUETOOTH , ZIGBEE , 3G and 4G wireless mobile telecommunications technologies, and/or the like to communicate with the data hub 112 or the server computer 102.
The digital vibration signal may also be temporarily stored in a storage 308 for various purposes. For example, the digital vibration signal output from the A/D
converter 304 may be temporarily stored in the storage 308 when the wireless communication module 306 fails to .. establish a connection with the data hub 112.
The vibration-detection unit 110 may also comprise a positioning module 310 such as a GPS module for providing the location information of the vibration-detection unit 110.
Therefore, the vibration-detection units 110 may be easily relocated without the need for manually recording the locations thereof. The locations of the vibration-detection units 110 are recorded in the system 100 such as in a database of the server computer 102 for determining the fracking and seismic-event locations.
The vibration-detection unit 110 may further comprise a local communication interface 312 for communication with a receiving device in proximity therewith and for downloading the vibration data thereto. In some embodiments, the local communication interface 312 may be a wired connection interface such as a USB port, a HDMI
port, a serial port, a parallel port, and the like. In some alternative embodiments, the local communication interface 312 may be a wireless connection interface such as a near-field communication (NFC) interface. In some embodiments, a receiving device in proximity with a vibration-detection unit 110 may also communicate with the network module 306 for downloading the vibration data.
The vibration-detection unit 110 also comprises a control circuit 314 which may be a programmable micro-controller or a suitable circuitry such as an integrated circuit (IC) for example, a field-programmable gate array (FPGA), an application-specific integrated circuit (ASIC), or the like, for controlling the operation of various modules 302 to 312, and for performing other functions such as signal processing, self-temperature monitoring and adjustment, signal quality control, clock trimming, power reservation, and/or the like. A
power source 316 such as a rechargeable battery pack and/or a solar panel, powers the modules 302 to 314 for extended operation times without recharging. In these embodiments, the control circuit 314 also controls the operation of the power source 316.
In some embodiments, the control circuit 314 communicates with a controller device such as the server computer 102 or a client-computing device 104 through the network module 306 and via the network 106 for remotely turning the vibration-detection unit 110 on or off.
FIG. 5 is a flowchart showing the steps of a fracking-monitoring process 400 executed by the system 100. The process 400 starts when one or more vibration-detection sensors 302 deployed at a site are powered on and initialized (step 402). Each vibration-detection sensor 302 detects vibration (step 404) and sends the detected vibration data and the position thereof to the data hub 112 (step 406).
Each data hub 112 is functionally connected to one or more vibration-detection sensors 302 and collects data including the vibration data and the position information from the vibration-detection sensors 302 connected thereto (step 408). The data hub 112 then forwards the collected data to the sever computer 102 (step 410).
At step 412, the server computer 102 receives vibration data and the associated position information. At step 416, the server computer 102 processes the vibration data and calculates the fracking and seismic-event locations.
At this step, the server computer 102 may use any suitable method to calculate the fracking and seismic-event locations. For example, in one embodiment, the server computer 102 may use signal arrival-time differences (i.e., the differences between the times of the vibration-signals arriving the vibration-detection sensors 302) to calculate the fracking and seismic-event locations.
At step 418, the locations are then compared with the drilling, fracking, injection, and production plans to verify the work progress. The progress-verification results may be used for monitoring and predicting fracking directions, determining if any fracking and seismic-event locations deviate from the plans, and/or the like. In this embodiment, the progress-verification results are used for controlling the one or more fracking devices 108 to adjust the fracking process such as slowing down the fracking or injection work activities, adjusting the injection pressure of the fracking liquid, changing fracking location, or stopping fracking in the area. The server computer 102 may also send the progress-verification results to one or more client-computing devices 104 for users to review.
With above-described design, the system 100 may monitor fracking progresses and make necessary adjustments thereto in real-time and help in improving hydrocarbon production and/or preventing fracking incidents, induced seismicity events, and/or negative environmental impacts in surrounding areas.
In above embodiments, each vibration-detection unit 110 comprises a positioning module 310 for providing position information to the server computer 102. In some alternative embodiments, at least one vibration-detection unit 110 does not comprise any positioning module 310. In these embodiments, such a vibration-detection unit 110 is deployed at a known location, and server computer 102 stores the location thereof. In the event that such vibration-detection unit 110 is redeployed, the new position thereof may be manually obtained for updating the corresponding record stored by the server computer 102.
Although in above embodiments, the fracking-monitoring system 100 is used for monitoring downhole fracking processes, those skilled in the art will appreciate that the fracking-monitoring system 100 may be used in other processes that may cause subterranean earth-fracturing.
For example, during hydrocarbon production, waste water may be injected into predrilled or obsolete wellbores for disposal. The injection of waste water may cause undesired subterranean earth-fracturing that may lead to negative environmental impacts. In some embodiments, the fracking-monitoring system 100 may be used for monitoring possible subterranean earth-fracturing during waste-water injection processes and providing alerts or adjusting the waste-water injection processes if subterranean earth-fracturing occurs or if subterranean earth-fracturing has expanded beyond a predefined threshold range.
In some embodiments, the fracking-monitoring system 100 may be used for monitoring geothermal-production processes wherein low-temperature water is injected into a geothermal-wellbore for heat exchange and cycles back to surface with a high-temperature.
The water injection may cause undesired subterranean earth-fracturing that may lead to negative environmental impacts. In these embodiments, the fracking-monitoring system 100 may be used for monitoring possible subterranean earth-fracturing during geothermal-production processes and providing alerts or adjusting the geothermal-production processes if subterranean earth-fracturing occurs or if subterranean earth-fracturing has expanded beyond a predefined threshold range.
In some embodiments, the fracking-monitoring system 100 may be used for monitoring steam-injection processes in Steam-assisted gravity drainage (SAGD) projects wherein high-temperature steam is injected into a wellbore for heating the hydrocarbon in a subterranean formation for reducing the viscosity thereof and subsequently increasing hydrocarbon production. The steam injection may cause undesired subterranean earth-fracturing (such as fracturing the caprock in surrounding areas) that may lead to negative environmental impacts. In these embodiments, the fracking-monitoring system 100 may be used for monitoring possible subterranean earth-fracturing or caprock-fracturing during steam-injection processes and providing alerts or adjusting the steam-injection processes if subterranean earth-fracturing occurs or if subterranean earth-fracturing has expanded beyond a predefined threshold range.
Claims
1. A fracking-monitoring system comprising:
a plurality of vibration-detection units for deploying about a wellbore for detecting vibration signals caused by formation fracturing during a fracking process;
and a computing device configured for:
collecting, in real-time, the vibration signals detected by the plurality of vibration-detection units;
calculating, in real-time, the locations of signal sources of the vibration signals;
evaluating, in real-time, the fracking process based on a comparison between the calculated locations of the signal sources and a fracking plan of the fracking process; and outputting, in real-time, the evaluating results for adjusting the fracking process.
a plurality of vibration-detection units for deploying about a wellbore for detecting vibration signals caused by formation fracturing during a fracking process;
and a computing device configured for:
collecting, in real-time, the vibration signals detected by the plurality of vibration-detection units;
calculating, in real-time, the locations of signal sources of the vibration signals;
evaluating, in real-time, the fracking process based on a comparison between the calculated locations of the signal sources and a fracking plan of the fracking process; and outputting, in real-time, the evaluating results for adjusting the fracking process.
Applications Claiming Priority (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US201862778614P | 2018-12-18 | 2018-12-18 | |
| US62/778,614 | 2018-12-18 |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CA3064218A1 true CA3064218A1 (en) | 2020-06-18 |
Family
ID=71107207
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA3064218A Pending CA3064218A1 (en) | 2018-12-18 | 2019-12-09 | System for real-time fracking monitoring and feedback based on vibration-analysis amd method therefor |
Country Status (1)
| Country | Link |
|---|---|
| CA (1) | CA3064218A1 (en) |
-
2019
- 2019-12-09 CA CA3064218A patent/CA3064218A1/en active Pending
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| JP7237949B2 (en) | Wellbore non-recovery detection system | |
| US11215045B2 (en) | Characterizing responses in a drilling system | |
| US10859725B2 (en) | Resource production forecasting | |
| US11236596B2 (en) | Real-time diversion control for stimulation treatments using fiber optics with fully-coupled diversion models | |
| US8705318B2 (en) | Data aggregation for drilling operations | |
| US20170045636A1 (en) | Enhancing reservoir characterization using real-time srv and fracture evolution parameters | |
| CA3040926C (en) | Improved stimulation using fiber-derived information and fracturing modeling | |
| CA2985433C (en) | Vibration-analysis system and method therefor | |
| NO20210927A1 (en) | Multi-objective completion parameters optimization for a wellbore using bayesian optimization | |
| Lu | Supervisory control and data acquisition system design for CO2 enhanced oil recovery | |
| GB2472675A (en) | Virtual reservoir sensor | |
| AU2018427119B2 (en) | Virtual real time operation | |
| CA3193666A1 (en) | System and method for monitoring well operations | |
| CA3064218A1 (en) | System for real-time fracking monitoring and feedback based on vibration-analysis amd method therefor | |
| RU2649706C1 (en) | Transmitting warnings upon danger of crossing wells to remote device | |
| US11585202B2 (en) | Method and system for optimizing field development | |
| US20230272711A1 (en) | Optimizing hydrocarbon recovery through integrated utilization of geomechanics and injection/production using machine learning | |
| WO2019227037A1 (en) | Enhanced caprock integrity integration for subsurface injection operations | |
| WO2016105351A1 (en) | Microseismic monitoring sensor uncertainty reduction | |
| EP3465253B1 (en) | Seismic determination of location | |
| TWI767827B (en) | Intelligent pumping control system and control method thereof | |
| US20230304389A1 (en) | Systems And Method For Creating A Predictive Model For Optimizing Drill Parameters | |
| US20240272320A1 (en) | Determining Well Productivity for Hydraulically Fractured Wells | |
| CN114718547A (en) | Shale gas productivity prediction method and device | |
| WO2023245051A1 (en) | Hydraulic fracturing system |