US20230287768A1 - Controlling fluid pressure at a well head based on an operation schedule - Google Patents
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Classifications
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
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- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B34/00—Valve arrangements for boreholes or wells
- E21B34/02—Valve arrangements for boreholes or wells in well heads
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
- E21B43/2607—Surface equipment specially adapted for fracturing operations
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
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Abstract
A method may include monitoring, for a well head of a hydraulic fracturing system, an operation or a state of one or more subsystems of the hydraulic fracturing system. The hydraulic fracturing system may include one or more fracturing rigs, one or more blending equipment, and one or more power sources electrically connected to a first subset of the one or more fracturing rigs, or one or more fuel sources fluidly connected to a second subset of the one or more fracturing rigs. The hydraulic fracturing system may further include one or more missile valves, one or more zipper valves, one or more well head valves, and one or more well heads. The method may further include controlling, based on an operation schedule for the hydraulic fracturing system and based on monitoring the operation or the state, the state or equipment changes.
Description
- The present disclosure relates generally to a well head, and more particularly, to controlling fluid pressure at a well head based on an operation schedule.
- Hydraulic fracturing is a means for extracting oil and gas from rock, typically to supplement a horizontal drilling operation. In particular, high-pressure fluid is used to fracture the rock, stimulating the flow of oil and gas through the rock to increase the volumes of oil or gas that can be recovered. A hydraulic fracturing rig used to inject high-pressure fluid, or fracturing fluid, includes, among other components, an engine, transmission, driveshaft, and pump.
- Hydraulic fracturing may involve the use of a hydraulic fracturing system that includes multiple hydraulic fracturing rigs operating at the same or different pressures to achieve a flow rate for the fluid (e.g., measured in barrels per minute). The fluid may be injected into one or more wells in the ground via corresponding well heads. However, operation of the hydraulic fracturing system often involves the use of human operators to control fluid pressure at a well head, flow of fluid to the well head, and/or the like. These operators often have to be present on site and often have to be present in the field to perform such activities. This places the safety of the operator at risk, may not allow for sufficiently fast response time to changing well or site conditions, and/or the like.
- U.S. Pat. No. 11,035,207, issued on Jan. 15, 2021 (“the '207 patent”) describes that a pump down station is used when performing zipper hydraulic fracturing operations or during wireline pump down operations happening on one well, while main pumping operations are concurrently happening on a second well. However, the '207 patent does not disclose monitoring an operation or a state of one or more subsystems of a hydraulic fracturing system and controlling fluid pressure at a well based on an operation schedule.
- The present disclosure may solve one or more of the problems set forth above and/or other problems in the art. The scope of the current disclosure, however, is defined by the attached claims, and not by the ability to solve any specific problem.
- In one aspect, a hydraulic fracturing system may include one or more fracturing rigs, one or more blending equipment fluidly connected to inlets of the one or more fracturing rigs, and one or more power sources electrically connected to a first subset of the one or more fracturing rigs, or one or more fuel sources fluidly connected to a second subset of the one or more fracturing rigs. The hydraulic fracturing system may further include one or more missile valves fluidly connected to outlets of the one or more fracturing rigs, one or more zipper valves fluidly connected to outlets of the one or more missile valves, one or more well head valves fluidly connected to outlets of the one or more zipper valves, and one or more well heads fluidly connected to outlets of the one or more well head valves. The hydraulic fracturing system may further include a controller configured to monitor, for a well head of the one or more well heads, an operation or a state of one or more subsystems of the hydraulic fracturing system. The controller may be further configured to control, based on an operation schedule for the hydraulic fracturing system and based on monitoring the operation or the state, the state or equipment changes.
- In another aspect, a method may include monitoring, for a well head of a hydraulic fracturing system, an operation or a state of one or more subsystems of the hydraulic fracturing system. The hydraulic fracturing system may include one or more fracturing rigs, one or more blending equipment fluidly connected to inlets of the one or more fracturing rigs, and one or more power sources electrically connected to a first subset of the one or more fracturing rigs, or one or more fuel sources fluidly connected to a second subset of the one or more fracturing rigs. The hydraulic fracturing system may further include one or more missile valves fluidly connected to outlets of the one or more fracturing rigs, one or more zipper valves fluidly connected to outlets of the one or more missile valves, one or more well head valves fluidly connected to outlets of the one or more zipper valves, and one or more well heads fluidly connected to outlets of the one or more well head valves. The method may further include controlling, based on an operation schedule for the hydraulic fracturing system and based on monitoring the operation or the state, the state or equipment changes.
- In yet another aspect, a controller for a hydraulic fracturing system may be configured to monitor, for a well head of a hydraulic fracturing system, an operation or a state of one or more subsystems of the hydraulic fracturing system. The hydraulic fracturing system may include one or more fracturing rigs, one or more blending equipment fluidly connected to inlets of the one or more fracturing rigs, and one or more power sources electrically connected to a first subset of the one or more fracturing rigs, or one or more fuel sources fluidly connected to a second subset of the one or more fracturing rigs. The hydraulic fracturing system may further include one or more missile valves fluidly connected to outlets of the one or more fracturing rigs, one or more zipper valves fluidly connected to outlets of the one or more missile valves, one or more well head valves fluidly connected to outlets of the one or more zipper valves, and one or more well heads fluidly connected to outlets of the one or more well head valves. The controller may be further configured to control, based on an operation schedule for the hydraulic fracturing system and based on monitoring the operation or the state, the state or equipment changes.
- Other features and aspects of this disclosure will be apparent from the following description and the accompanying drawings.
- The accompanying drawings, which are incorporated in and constitute a part of this specification, illustrate various exemplary embodiments and together with the description, serve to explain the principles of the disclosed embodiments.
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FIG. 1 is a schematic diagram of exemplary hydraulic fracturing systems including a plurality of fracturing rigs, energy sources, and fuel types according to aspects of the disclosure. -
FIG. 2 is a schematic diagram of a data monitoring system and associated controllers of the hydraulic fracturing system ofFIG. 1 , according to aspects of the disclosure. -
FIG. 3 is a diagram illustrating an exemplary optimization program, according to aspects of the disclosure. -
FIG. 4 is a diagram illustrating an exemplary control logic program, according to aspects of the disclosure. -
FIG. 5 illustrates a flowchart depicting an exemplary method for monitoring one or more subsystems of a hydraulic fracturing system and controlling a fluid pressure at a well head, according to aspects of the disclosure. - Both the foregoing general description and the following detailed description are exemplary and explanatory only and are not restrictive of the features, as claimed. As used herein, the terms “comprises,” “comprising,” “has,” “having,” “includes,” “including,” or other variations thereof, are intended to cover a non-exclusive inclusion such that a process, method, article, or apparatus that comprises a list of elements does not include only those elements, but may include other elements not expressly listed or inherent to such a process, method, article, or apparatus. In this disclosure, unless stated otherwise, relative terms, such as, for example, “about,” “substantially,” and “approximately” are used to indicate a possible variation of ±10% in the stated value.
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FIG. 1 illustrates an exemplaryhydraulic fracturing system 2 according to aspects of the disclosure. In particular,FIG. 1 depicts an exemplary site layout according to a well stimulation stage (e.g., hydraulic fracturing stage) of a drilling/mining process, such as after a well has been drilled at the site and the equipment used for drilling removed. Thehydraulic fracturing system 2 may include fluid storage tanks 4, sand storage tanks 6, andblending equipment 8 for preparing a fracturing fluid. The fracturing fluid, which may, for example, include water, sand, and one or more chemicals, may be injected at pressure through one or more lowpressure fluid lines 34 to one or more fracturing rigs 10 (FIG. 1 illustrates tenfracturing rigs 10 and two types of fracturing rigs—4 electric fracturing rigs 10 and 6 hydraulic fracturing rigs 10). One or more types offracturing rigs 10 may be used in connection with certain embodiments, such asmechanical fracturing rigs 10,hydraulic fracturing rigs 10,electric fracturing rigs 10, and/or the like. The one or more fracturingrigs 10 may pump the fracturing fluid at high pressure to a well head 18 (FIG. 1 illustrates four well heads 18) through one or more high-pressure fluid lines 35. The one ormore fracturing rigs 10 may be controlled by one or more rig controllers 19 (e.g., arig controller 19 may receive, process, and/or provide to the fracturing rigs 10 a desired flow or pressure for a job). - A bleed off tank (not shown in
FIG. 1 ) may be provided to receive bleed off liquid or gas from thefluid lines 34 and/or 35 (e.g., via one or more automatic pressure relief valves 13). In addition, nitrogen, which may be beneficial to the hydraulic fracturing process for a variety of reasons, may be stored in tanks, with a pumping system (not shown inFIG. 1 ) used to supply the nitrogen from the tanks to thefluid lines 35 or a well head 18. - In order to control flow of fluid, the
hydraulic fracturing system 2 may include various types of valves. For example, thehydraulic fracturing system 2 may include one or more lowpressure missile valves 11 upstream from the inlet of hydraulic fracturing pumps of the fracturing rigs 10 (e.g., an inlet of the lowpressure missile valves 11 may be fluidly connected tofluid lines 34 and outlets of the lowpressure missile valves 11 may be fluidly connected to the inlets of the hydraulic fracturing pumps). For example, the lowpressure missile valves 11 may control fluid flow fromfluid lines 34 to the hydraulic fracturing pumps of thefracturing rigs 10. Additionally, or alternatively, thehydraulic fracturing system 2 may include one or more check valves 15 (e.g., actuated or one-way check valves 15) that may be upstream from a fracturing tree being served by the fracturing rigs 10 (e.g., outlets of the pumps of thefracturing rigs 10 may be fluidly connected to inlets of thecheck valves 15 and outlets of thecheck valves 15 may be fluidly connected to inlet(s) of the fracturing tree). Additionally, or alternatively, thehydraulic fracturing system 2 may include one or more large bore valves 12 (e.g., on/off ball valves) of a grease system (FIG. 1 illustrates three large bore valves 12). “Large bore” may refer to a line where flow is consolidated into one line andlarge bore valves 12 may shut the well off from missile lines. Thehydraulic fracturing system 2 may include asystem 17 that may gather data related to thehydraulic fracturing system 2 and may provide the data to thecontroller 58 for event correction and/or maintenance monitoring. For example, thecontroller 58 may track maintenance based on the data from thesystem 17 and may send a message to an operator or to thesystem 17 to grease thelarge bore valves 12, e.g., after a certain number of cycles of opening/closing thelarge bore valves 12. One or more other similar systems may be included in thehydraulic fracturing system 2 for monitoring operations of certain elements of thehydraulic fracturing system 2 and/or for taking corrective or maintenance-related actions. Thelarge bore valves 12 may be downstream of outlets of the check valves 15 (e.g., inlets of thelarge bore valves 12 may be fluidly connected to outlets of the check valves 15). Additionally, or alternatively, thehydraulic fracturing system 2 may include one or more automatic pressure relief valves 13 (FIG. 1 illustrates one automatic pressure relief valve 13). For example, the automaticpressure relief valves 13 may be downstream of the one or more large bore valves 12 (e.g., inlets of the one or more automaticpressure relief valves 13 may be fluidly connected to outlets of the one or more large bore valves 12). The automaticpressure relief valves 13 may be controlled and/or triggered automatically to release fluid pressure fromfluid lines 35. - Additionally, or alternatively, the
hydraulic fracturing system 2 may include one or more zipper valves 14 (FIG. 1 illustrates four zipper valves 14) downstream of the automatic pressure relief valves 13 (e.g., outlets of the automaticpressure relief valves 13 may be fluidly connected to inlets of the zipper valves 14). The zipper valves 14 may control fluid flow fromfluid lines 35 to individual well heads 18 via zipper piping 37 (e.g., zipper piping may fluidly connectlarge bore valves 12 to the well heads 18). Thehydraulic fracturing system 2 may further include one or more well head valves 16 (FIG. 1 illustrates four well head valves 16) downstream of the outlet of the zipper valves 14 (e.g., outlets of the zipper valves 14 may be fluidly connected to inlets of the well head valves 16). Thewell head valves 16 may provide further fluid control to the well heads 18 from the fluid lines 35. - The hydraulic fracturing process performed at the site, using the
hydraulic fracturing system 2 of the present disclosure, and the equipment used in the process, may be managed and/or monitored from a single location, such as adata monitoring system 20, located at the site or at additional or alternative locations. According to an example, thedata monitoring system 20 may be supported on a van, truck or may be otherwise mobile. As will be described below, thedata monitoring system 20 may include auser device 22 for displaying or inputting data for monitoring performance and/or optimizing operation of thehydraulic fracturing system 2 and/or the fracturing rigs 10. According to one embodiment, the data gathered by thedata monitoring system 20 may be sent off-board or off-site for monitoring, recording, or reporting of performance of the hydraulic fracturing system 2 (or elements of the hydraulic fracturing system 2) and/or for performing calculations related to thehydraulic fracturing system 2. - The data monitoring system 20 (or a controller of the data monitoring system 20) may be communicatively connected to one or more controllers of the
hydraulic fracturing system 2 that control subsystems of thehydraulic fracturing system 2. For example, thedata monitoring system 20 may be connected to the controllers via wired orwireless communication channels 24 The controllers may include a wellhead valve controller 26 connected to the one or morewell head valves 16 and/or well heads 18 via a wired orwireless communication channel 28. The wellhead valve controller 26 may be configured to actuate the one or morewell head valves 16 and/or one or more mechanical components of the well heads 18. Actuation of a valve or a well head 18 may include actuating one or more mechanical components to an open state, to a closed state, or to a partially closed or partially open state. Actuation, as described herein, may be performed by an associated actuator that may be integrated with the component to be actuated or may be a separate component (e.g., electric actuation of a valve may be performed through the use of an actuator integrated with a valve whereas hydraulic actuation may be performed through the use of an actuator located remote to the valve). Additionally, or alternatively, the controllers may include azipper valve controller 30 connected to the one or more zipper valves 14 via a wired orwireless communication channel 32. Thezipper valve controller 30 may be configured to actuate the one or more zipper valves 14. - The controllers may, additionally, or alternatively, include a large
bore valve controller 36 connected to the one or morelarge bore valves 12 via a wired orwireless communication channel 38. The largebore valve controller 36 may be configured to actuate the one or morelarge bore valves 12. The controllers may further include avalve controller 40 connected to the one or more lowpressure missile valves 11 and/or the one ormore check valves 15 via a wired orwireless communication channel 42. Thevalve controller 40 may be configured to actuate the one or more lowpressure missile valves 11 and/or the one ormore check valves 15. - Additionally, or alternatively, the controllers may include a
blender controller 44 connected to theblending equipment 8 via a wired orwireless communication channel 46. Theblender controller 44 may be configured to control operations of the blending equipment 8 (e.g., to control preparation of the fracturing fluid). The controllers may further include apower source controller 48 connected to various power sources (e.g.,generators 54, such as gaseous or blendedgenerators 54,energy storages 55, such as batteries or fuel cells, and/or a utility power grid 56) included in thehydraulic fracturing system 2 via a wired orwireless communication channel 50. Thegenerators 54 illustrated inFIG. 1 may bemobile generators 54 and may include turbine-basedgenerators 54 or engine-basedgenerators 54. Other power sources may include renewable energy sources, such as solar cells, wind turbines, and/or the like from a micro-grid. Thepower source controller 48 may be configured to control one or more power sources and/or to control the provisioning of power from the power sources. For example, thepower source controller 48 may power on or power off agenerator 54 to meet power expectations, may switch one or more equipment of thehydraulic fracturing system 2 from consuming power from theutility power grid 56 to consuming power from one ormore generators 54 and/or energy storages 55 (or vice versa), and/or the like. -
Fuel sources 52 may provide fuel (e.g., gas, compressed natural gas (CNG), hydrogen (H2), propane, field gas, diesel, etc.) to the mechanical fracturing rigs 10. The provisioning of fuel to the fracturing rigs 10 may be controlled by a controller associated with thedata monitoring system 20 and/or one or more other controllers associated with the fuel sources. -
Generators 54 may provide energy to fracturingrigs 10. The provisioning of energy to the fracturing rigs 10 may be controlled by a controller associated with thedata monitoring system 20 and/or one or more other controllers associated with the fuel sources. - Elements of the
hydraulic fracturing system 2 may be configured to operate in one or more operational modes. The one or more operational modes may include a manual mode where, for example, an operator programs desired operational parameters for elements of thehydraulic fracturing system 2 via theuser device 22 and the operator ramps thehydraulic fracturing system 2 to the desired operational parameters via theuser device 22. In addition, in the manual mode, the operator may, via theuser device 22, approve or decline optimized operational parameters determined by thedata monitoring system 20 according to certain embodiments described herein. Additionally, or alternatively, the one or more operational modes may include a semi-closed mode where, for example, the operator ramps thehydraulic fracturing system 2 to desired operational parameters via theuser device 22 and acontroller 58 may optimize the operation of thehydraulic fracturing system 2 based on operator input (e.g., fuel optimization, emissions optimization, total cost of ownership optimization, and/or the like). - Additionally, or alternatively, the one or more operational modes may include a closed mode where, for example, the operator programs the desired operational parameters via the
user device 22, and one or more controllers (e.g.,controller 58 and/or controllers 64) ramp the operation of thehydraulic fracturing system 2 to the desired and/or optimized operational parameters. Additionally, or alternatively, the one or more operational modes may include an autonomous mode where, for example, the operator is remote to thedata monitoring system 20 and/or a hydraulic fracturing site, and one or more controllers (e.g.,controller 58 and/or controllers 64) may monitor and control the operational parameters of thehydraulic fracturing system 2 automatically (e.g., automatically ramp operation of thehydraulic fracturing system 2 to desired operational parameters, determine and implement optimized operational parameters, etc.). The autonomous mode may additionally include operating in the closed mode with sub-controllers for valves of thehydraulic fracturing system 2. Additionally, or alternatively, the one or more operational modes may include a multi-site mode where, for example, the operator can monitor and/or control operations of multiplehydraulic fracturing systems 2 at different sites. In some embodiments, the multi-site mode may include operating in the autonomous mode across multiple fracturing sites. - Referring to
FIG. 2 , thedata monitoring system 20 may include theuser device 22 and acontroller 58. Thecontroller 58 may be provided, and may be part of, or may communicate with, thedata monitoring system 20. Thecontroller 58 may reside in whole or in part at thedata monitoring system 20, or elsewhere relative to thehydraulic fracturing system 2. Theuser device 22 and thecontroller 58 may be communicatively connected to each other via one or more wired or wireless connections for exchanging data, instructions, etc. Further, thecontroller 58 may be configured to communicate with one ormore controllers 64 via wired or wireless communication channels. For example, thecontroller 58 may monitor and control, via thecontrollers 64, various subsystems of thehydraulic fracturing system 2. Thecontrollers 64 may include therig controller 19, the wellhead valve controller 26, thezipper valve controller 30, the largebore valve controller 36, thevalve controller 40, theblender controller 44, and/or thepower source controller 48. - The
controllers 64 may be configured to communicate with one or more sensors (not shown inFIG. 2 ) located on elements of thehydraulic fracturing system 2. For example, thevalve controller 40 may be configured to communicate with one or more sensors located at one or more valves, at components (e.g., an engine, a pump, etc.) of afracturing rig 10, etc. A sensor may be configured to detect or measure one or more physical properties related to operation and/or performance of the various elements of thehydraulic fracturing system 2. For example, a sensor may be configured to provide a sensor signal indicative of a state of a valve (e.g., open, closed, a percentage open, or a percentage closed) to one or more of thecontrollers 64, which may be configured to provide the sensor signal to thecontroller 58. - The
controller 58 and/or thecontrollers 64 may include a processor and a memory (not illustrated inFIG. 2 ). The processor may include a central processing unit (CPU), a graphics processing unit (GPU), a microprocessor, a digital signal processor and/or other processing units or components. Additionally, or alternatively, the functionality described herein can be performed, at least in part, by one or more hardware logic components. For example, and without limitation, illustrative types of hardware logic components that may be used include field-programmable gate arrays (FPGAs), application-specific integrated circuits (ASICs), application-specific standard products (ASSPs), system-on-a-chip systems (SOCs), complex programmable logic devices (CPLDs), etc. Additionally, the processor may possess its own local memory, which also may store program modules, program data, and/or one or more operating systems. The processor may include one or more cores. - The memory may be a non-transitory computer-readable medium that may include volatile and/or nonvolatile memory, removable and/or non-removable media implemented in any method or technology for storage of information, such as computer-readable instructions, data structures, program modules, or other data. Such memory includes, but is not limited to, random access memory (RAM), read-only memory (ROM), electrically erasable programmable read-only memory (EEPROM), flash memory or other memory technology, compact disc read-only memory (CD-ROM), digital versatile discs (DVD) or other optical storage, magnetic cassettes, magnetic tape, magnetic disk storage or other magnetic storage devices, redundant array of independent disks (RAID) storage systems, or any other medium which can be used to store the desired information and which can be accessed by a computing device (e.g., the
user device 22, a server device, etc.). The memory may be implemented as computer-readable storage media (CRSM), which may be any available physical media accessible by the processor to execute instructions stored on the memory. The memory may have an operating system (OS) and/or a variety of suitable applications stored thereon. The OS, when executed by the processor, may enable management of hardware and/or software resources of thecontroller 58 and/or thecontrollers 64. - The memory may be capable of storing various computer readable instructions for performing certain operations described herein (e.g., operations of the
controller 58 and/or the controllers 64). The instructions, when executed by the processor and/or the hardware logic component, may cause certain operations described herein to be performed. - The
controller 58 may store and/or execute anoptimization program 60 to optimize operations of the hydraulic fracturing system 2 (e.g., based on data stored in the memory or as otherwise provided to thecontroller 58, such as via theuser device 22, gathered by thecontrollers 64, or from a database). Thecontroller 58 may store and/or execute a control logic program 62 (as described in more detail below with respect toFIG. 4 ). Data used by thecontroller 58 may include site configuration-related information, scheduling-related information, cost-related information, emissions-related information, operation-related or state-related information, system operating parameters, and/or the like. However, various other additional or alternative data may be used. -
FIG. 3 is a diagram illustrating anexemplary optimization program 60, according to aspects of the disclosure. As illustrated inFIG. 3 , theoptimization program 60 may receiveinput data 66 and may use theinput data 66 with anoptimization algorithm 76. For example, theoptimization program 60 may receive theinput data 66 from the user device 22 (e.g., a user may input theinput data 66 via the user device 22), from a server device, from a database, from memory of various equipment or components thereof of thehydraulic fracturing system 2, and/or the like. Theoptimization program 60 may receive theinput data 66 as a stream of data during operation of thehydraulic fracturing system 2, prior to starting operations of thehydraulic fracturing system 2, and/or the like. Theinput data 66 may be pre-determined and provided to the optimization program 60 (e.g., may be based on experimental or factory measurements of equipment), may be generated by the controller 58 (e.g., thecontroller 58 may broadcast a ping communication at a site in order to receive response pings from equipment at the site to determine which equipment is present, thecontroller 58 may measure, from sensor signals, theinput data 66, etc.), and/or the like. - The
input data 66 may include site configuration-relatedinformation 68. For example, the site configuration-relatedinformation 68 may include numbers and/or types of elements of thehydraulic fracturing system 2, powertrain types of the fracturing rigs 10 (e.g., mechanical or electric powertrain configurations), sub-types of mechanical powertrains (e.g., fuel types or levels of emission certified combustion engines), sub-types of electric powertrains (e.g., turbine generators, reciprocating engine generators, hydrogen fuel cells, energy storage systems, such as batteries, or direct-to-grid), possible operating modes of the elements of the hydraulic fracturing system 2 (e.g., a manual mode, a semi-closed mode, a closed mode, an autonomous mode, etc.), a maximum allowed pressure or flow rate of afracturing rig 10 at the site, quantities and/or types of other equipment located at the site, ages, makes, models, and/or configurations of the equipment at the site, and/or the like. Additionally, or alternatively, theinput data 66 may include scheduling-relatedinformation 70. For example, the scheduling-relatedinformation 70 may include times, dates, durations, locations, etc. for certain operations of thehydraulic fracturing system 2, such as scheduled times and dates for certain pump pressures, scheduled openings or closings of valves, etc. - Additionally, or alternatively, the
input data 66 may include cost-relatedinformation 72. For example, the cost-relatedinformation 72 may include a cost of fuel or power for thehydraulic fracturing system 2, a total cost of ownership of elements of the hydraulic fracturing system 2 (e.g., including maintenance costs, costs of fracturing fluid, or personnel costs), a cost of emissions (e.g., regulatory costs applied to emissions or costs related to reducing emissions, such as diesel exhaust fluid (DEF) costs), and/or the like. Additionally, or alternatively, theinput data 66 may include emissions-relatedinformation 74. For example, the emissions-relatedinformation 74 may include an amount of emissions from elements of the hydraulic fracturing system 2 (e.g., at different operating levels of the equipment), and/or the like. Additionally, or alternatively, theinput data 66 may include equipmentoperation status information 75. For example, the equipment operation status may include an operational mode of equipment of thehydraulic fracturing system 2, such as for verification of requests to change the operational status of the equipment. Theinput data 66 may include various other types of data depending on the objective to be optimized by theoptimization algorithm 76. For example, theinput data 66 may include transmission gear life predictions, pump cavitation predictions, pump life predictions, engine life predictions, and/or the like. - As described in more detail herein, the
optimization algorithm 76 may process theinput data 66 after receiving theinput data 66. For example, theoptimization algorithm 76 may process theinput data 66 using aparticle swarm algorithm 78. Theoptimization algorithm 76 may then output optimizedoperational parameters 80 for thehydraulic fracturing system 2 to theuser device 22 for viewing or modification, to thecontroller 58 and/or thecontrollers 64 to control operations of thehydraulic fracturing system 2, and/or to a database for storage. Optimizedoperational parameters 80 may include, for example, values for engine power output, gear ratio, engine revolutions, throttle control, pump pressure, flow rate, or transmission speed optimized for emissions output, fuel consumption, lowest cost of operation, and/or the like. -
FIG. 4 is a diagram illustrating an exemplarycontrol logic program 62, according to aspects of the disclosure. As illustrated inFIG. 4 , thecontrol logic program 62 may receive operation-related or state-relatedinformation 82 and may provide this information to controllogic 84. The operation-related or state-related information may include, for example, an operating pressure at a well head 18 or other elements of thehydraulic fracturing system 2, an operating transmission gear or speed of mechanical fracturing rigs 10 or power consumption of electric fracturing rigs 10, a fuel or power consumption rate or elements of thehydraulic fracturing system 2, a mixture of the fracturing fluid, whether certain types of elements or certain instances of certain types of elements are in operation, whether valves are opened or closed (or a degree to which they are opened or closed), and/or the like. - The
control logic program 62 may process the operation-related or state-relatedinformation 82 usingcontrol logic 84. For example, thecontrol logic 84 may be based onsystem operating parameters 86, which may include operating limits, operating expectations, operating baselines, and/or the like for thehydraulic fracturing system 2. Thecontrol logic 84 may then output control signals 88 based on the processing. For example, the control signals 88 may modify the operation of thehydraulic fracturing system 2 to avoid exceeding operating limits, to ramp operation of equipment to operating expectations, to ramp operation of equipment to exceed operating baselines, and/or the like. - The aspects of the
controller 58 of the present disclosure and, in particular, the methods executed by thecontroller 58 may be used to assist in monitoring an operation or a state of one or more subsystems of ahydraulic fracturing system 2 and control a fluid pressure at a well head 18 based on an operation schedule. Thus, by controlling the fluid pressure, certain aspects described herein may provide various advantages to the operation of thehydraulic fracturing system 2, such as helping to ensure that certain events, such as over limiting pressure or well collapse, do not occur. In addition, thecontroller 58 may control a well head 18 according to an operation schedule, which may improve safety at a fracturing site by reducing or eliminating a need for an operator to be present at a well head 18. Similarly, by automatically controlling the well head 18 according to an operation schedule, hydraulic fracturing operations can be more closely aligned to the intended scheduling, which may reduce latency between stages of hydraulic fracturing operations, improve safety at a hydraulic fracturing site by reducing or eliminating implementation of incorrect fracturing operations due deviations from the operation schedule, and/or the like. In addition, thecontroller 58 may monitor and control operations of multiple different well heads 18 at the same time (based on real-time or near real-time information), in a way very difficult or not possible through operator-based operation of thehydraulic fracturing system 2. This may increase an efficiency of fracturing operation of thehydraulic fracturing system 2. -
FIG. 5 illustrates a flowchart depicting anexemplary method 100 for monitoring and controlling operations of a well head 18, according to aspects of the disclosure. Themethod 100 illustrated inFIG. 5 may be implemented by thecontroller 58. The steps of themethod 100 described herein may be embodied as machine readable and executable software instructions, software code, or executable computer programs stored in a memory and executed by a processor of thecontroller 58. The software instructions may be further embodied in one or more routines, subroutines, or modules and may utilize various auxiliary libraries and input/output functions to communicate with other equipment. Themethod 100 illustrated inFIG. 5 may also be associated with an operator interface (e.g., a human-machine interface, such as a graphical user interface (GUI)) through which an operator of thehydraulic fracturing system 2 may configure theoptimization algorithm 76 and/or thecontrol logic 84, may select theinput data 66 or the operation-related or state-relatedinformation 82, may set objectives for the optimization algorithm 76 (e.g., objectives for the particle swarm algorithm 78), and/or the like. Thecontroller 58 may automatically actuate one or more valve systems during closing or opening of a well head 18. For example, thecontroller 58 may close the well head 18-1 and the zipper valves 14-1, and thecontroller 58 may then open the well-head 18-2 and the zipper valves 14-2. Thecontroller 58 may control closing of the well-head 18-1 (e.g., by closing the zipper valves 14-1 slowly) to avoid damage to elements of thehydraulic fracturing system 2. Additionally, or alternatively, thecontroller 58 may determine a manner in which to open the well head 18-2 and open the zipper valves 14-2 based on a configuration of the well head 18-2 and/or the zipper valves 14-2 to avoid damage to elements of thehydraulic fracturing system 2. Additionally, or alternatively, thecontroller 58 may close and open the well heads 18-1 and 18-2 automatically according to a schedule. - At
step 102, thecontroller 58 may monitor, for a well head 18 of one or more well heads 18 of ahydraulic fracturing system 2, an operation or a state of one or more subsystems of thehydraulic fracturing system 2. For example, thecontroller 58 may receive the operation-related or state-relatedinformation 82 as a stream of data, according to a schedule, etc. Additionally, or alternatively, thecontroller 58 may receive the operation-related or state-relatedinformation 82 from a sensor, from one or more of thecontrollers 64, as input via theuser device 22, from a server device, and/or the like. In connection with the monitoring atstep 102, thecontroller 58 may additionally receive a configuration of thesystem operating parameters 86 via theuser device 22, from memory, from a server device, from a remote control center, and/or the like. - A subsystem may include, for a certain well head 18, particular equipment of the
hydraulic fracturing system 2 associated with pumping fracturing fluid to the well head 18. For example, the one or more subsystems may include theblending equipment 8, certain fracturing rigs 10 (e.g., mechanical and/or electric fracturing rigs 10), components of the fracturing rigs 10 (e.g., engines, pumps, transmissions, etc. for mechanical fracturing rigs 10 or variable frequency drives (VFDs) and electric motors for electric fracturing rigs 10), certain lowpressure missile valves 11, certainlarge bore valves 12, certain zipper valves 14 and/or zipper piping 37 and zipper valve 14 sets, thecheck valves 15, certainwell head valves 16, the wellhead valve controller 26, thezipper valve controller 30, the largebore valve controller 36, thevalve controller 40, thepower source controller 48,certain fuel sources 52, the power sources, and/or the like. For example, a well head 18 may have dedicated valves, fracturingrigs 10, and/or the like, and these may be the subsystems monitored for the well head 18 rather than monitoring all of the valves, fracturingrigs 10, etc. of thehydraulic fracturing system 2. This may conserve computing resources of thecontroller 58 by reducing an amount of information that thecontroller 58 has to process. - In some embodiments, the operation or the state of the one or more subsystems may be monitored for multiple well heads 18 at the same time. For example,
FIG. 1 illustrates thehydraulic fracturing system 2 as including four well heads 18. In this example, thecontroller 58 may monitor the operation or the state of afirst fracturing rig 10, afirst missile valve 11, a firstlarge bore valve 12, a first zipper valve 14, and a firstwell head valve 16 for a first well head 18, may monitor the operation or the state of asecond fracturing rig 10, asecond missile valve 11, a secondlarge bore valve 12, a second zipper valve 14, and a secondwell head valve 16 for a second well head 18, and so forth. - At
step 104, thecontroller 58 may control, based on an operation schedule for thehydraulic fracturing system 2 and based on monitoring the operation or the state, the state or equipment changes. For example, thecontroller 58 may control the state or equipment changes automatically based on determining that the one or more subsystems are not meeting operating expectations or are exceeding operating limits. In some embodiments, thecontroller 58 may process the information received atstep 102 using thecontrol logic 84 to determine whether operational limits have been exceeded, whether the equipment of thehydraulic fracturing system 2 are operating at least at minimum operating baselines or within expected ranges, etc. For example, thecontroller 58 may perform a comparison of the operation-related or state-relatedinformation 82 tosystem operating parameters 86 and may determine that the equipment is not meeting expectations or is beyond operating limits. From this analysis, thecontroller 58 may determine which equipment, components of the equipment, etc. are causing an issue. For example, if thecontroller 58 determines that the fluid pressure at a well head 18 is exceeding a pressure limit and additionally determines that one or more zipper valves 14 are closed to a greater amount than expected, thecontroller 58 may determine that the excessively closed zipper valves 14 are the cause of the excess fluid pressure. - The
controller 58 may then providecontrol signals 88 to thecontrollers 64 and/or directly to equipment of thehydraulic fracturing system 2 to modify the operations of the equipment. For example, thecontroller 58 may providecontrol signals 88 to modify a degree to which one or more valves are opened or closed to modify the fluid pressure at the well head 18. Additionally, or alternatively, thecontroller 58 may output operational parameters (or instructions for modifying operational parameters) to thecontrollers 64, and thecontrollers 64 may generate the control signals 88. In certain embodiments, the operational parameters output from thecontroller 58 may include optimized operational parameters 80 (e.g., thecontroller 58 may perform theoptimization algorithm 76 prior to outputting control signals 88, as described in more detail elsewhere herein). - The operation schedule may include days, times, durations, etc. for operation of the well head 18 and corresponding fluid pressures for the various different days, times, durations, etc. (e.g., for a planned well completion). When controlling the fluid pressure, the
controller 58 may process the operation schedule to determine whether the fluid pressure needs to be modified, to determine optimized operational parameters for achieving a fluid pressure (or preventing a pressure limit from being exceeded), and/or the like. For example, thecontroller 58 may process the operation schedule to determine whether the fluid pressure at the well head 18 matches a scheduled fluid pressure, whether to increase or decrease the fluid pressure based on an amount of time that the fracturing operations have been performed at a site, and/or the like. This may facilitate continuous operation of hydraulic fracturing operations, pre-scheduling of control signals 88, and/or the like in a manner very difficult or not possible with operator-controlled hydraulic fracturing operations, which may increase an efficiency of hydraulic fracturing operations of thehydraulic fracturing system 2. - In connection with the
steps controller 58 may monitor information including an open or closed state of various valves of thehydraulic fracturing system 2, and may control the valves to prevent exceeding a pressure limit at the well head 18 by pumping on a closed pathway. For example, thecontroller 58 may generatecontrol signals 88 to actuate mechanical components of the valves to adjust the degree to which the valves are opened or closed. Additionally, or alternatively, in connection with thesteps controller 58 may monitor and control theblending equipment 8 to prevent thehydraulic fracturing system 2 from falling below a minimum suction pressure or from going lower than the low pressure limit of the system. For example, thecontroller 58 may generatecontrol signals 88 to adjust a mixture of the fracturing fluid, an output flow rate of theblending equipment 8, and/or the like. - Additionally, or alternatively, in connection with the
steps controller 58 may monitor and control pumps of the fracturing rigs 10. For example, thecontroller 58 may monitor an output pressure or flow rate of the pumps (e.g., alone or in connection with pressures at the valves of the hydraulic fracturing system 2) and may generatecontrol signals 88 to increase or decrease a flow rate or pressure from the pumps based on detected downstream pressures at the well heads 18. As another example, thecontroller 58 may monitor and control one or more subsystems within safety limits for fluid pressure. For example, thecontroller 58 may, when thecontroller 58 detects that an operational parameter has exceeded a safety limit or is within a threshold percentage of the safety limit for the fluid pressure, generatecontrol signals 88 to increase or decrease certain operational parameters related to the safety limit, to cause a hard stop of certain equipment of thehydraulic fracturing system 2, and/or the like. - Although the
method 100 illustrated inFIG. 5 is described as includingsteps method 100 may not include all of these steps or may include additional or different steps. For example, thecontroller 58 may, based on the monitoring of the operation or the state of one or more subsystems, control the one or more subsystems within operating limits or based on operating expectations to cause or prevent an occurrence of one or more events. The one or more events may be related to well integrity during hydraulic fracturing operations. For example, the one or more events to be caused may include a well pressure meeting or maintaining a minimum well pressure, the well pressure being within a range of pressure values, an operation speed (e.g., transmission speed) of the one or more subsystems meeting or maintaining a minimum operation speed, the operation speed being within a range of speed values, and/or the like. Additionally, or alternatively, for example, the one or more events to be prevented may include the well pressure exceeding a pressure limit, a well collapse, stalling of the one or more subsystems, a deviation from a fracturing schedule, and/or the like. - Additionally, or alternatively, certain embodiments may prevent cavitation on a low pressure line due to
blender equipment 8 not providing enough pressure. For example, thecontroller 58 may send an instruction to theblender equipment 8 to increase speed before pump speed is increased. Additionally, or alternatively, certain embodiments may control operational efficiency to prevent loss of fuel by controlling fuel pressure, prevent loss of blending by controlling gas pressure, and/or the like. Additionally, or alternatively, certain embodiments may prevent operational interruption of anelectric fracturing rig 10 by preventing loss of power or voltage, preventing start up of anelectric fracturing rig 10 before a power source is ready (e.g., by checking power prior to ramping), and/or the like. - Additionally, or alternatively, the
method 100 may include optimizing operation of one or more subsystems of thehydraulic fracturing system 2 using a particle swarm algorithm or another type of optimization algorithm. For example, a particle swarm algorithm may iteratively tune operational parameters to search for a set of optimized operational parameters 80 (P1, P2, . . . Pn) that achieve an optimization objective. In this way, “optimized,” “optimization” and similar terms used herein may refer to a selection of values (for operational parameters) based on some criteria (an objective) from a set of available values. An objective may be of any suitable type, such as minimizing the cost of fracturing operations of thehydraulic fracturing system 2, minimizing fuel or power consumption of thehydraulic fracturing system 2, minimizing emissions from thehydraulic fracturing system 2, maximizing an operational life of equipment of thehydraulic fracturing system 2, minimizing an overall time of the hydraulic fracturing operations, minimizing a cost of ownership of equipment used in the hydraulic fracturing operation, maximizing a maintenance interval of equipment of thehydraulic fracturing system 2, and/or any combinations thereof. In addition, and as another example, themethod 100 may further include outputting optimizedoperational parameters 80. For example, thecontroller 58 may output the optimizedoperational parameters 80 to one or more destinations for display (e.g., for approval and/or modification by an operator), storage (e.g., for historical comparison or analysis, for later usage, etc.), inclusion into control signals (e.g., control signals 88 that cause elements of thehydraulic fracturing system 2 to operate according to the optimized operational parameters 80), and/or the like. With respect to inclusion in control signals 88, thecontroller 58 may use a processor to generatecontrol signals 88 and may output the control signals 88 to acontroller 64 or to equipment of thehydraulic fracturing system 2 using a transceiver (or a transmitter) to cause the equipment to operate in a particular manner. In this way, thecontroller 58 may conserve equipment life, fuel, emissions, power, etc. of thehydraulic fracturing system 2. - Through optimization of an objective, and generation of corresponding control signals 88 for equipment, certain embodiments may conserve resources (e.g., operational life, power resources, fuel resources, etc.) associated with the
hydraulic fracturing system 2 and may facilitate improvements in a site or system-level efficiency of thehydraulic fracturing system 2. Site or system-level optimization may facilitate further gains in efficiency and conservation of resources compared to optimization of individual equipment through consideration of ways in which certain equipment operations affect site-level or system-level objectives. For example, if the objective for thehydraulic fracturing system 2 is to reduce fuel consumption and emissions below a threshold while maintaining a fluid pressure and an operation schedule, thecontroller 58 may determine that modifying any of the operation ofvarious blending equipment 8 and the operation of various fracturingrigs 10 can reduce the fuel consumption and the emissions to a suitable level, but that just modifying the operation of theblending equipment 8 will keep the hydraulic fracturing operations on schedule. The one or more destinations may include the user device 22 (or a display of the user device 22), a server device, a controller, a database, memory, etc. - In this way, the
controller 58 of certain embodiments can provide real-time (or near real-time) monitoring and controlling of a fluid pressure at a well head 18 based on an operation schedule. This may improve operation of ahydraulic fracturing system 2 from a site-level perspective by facilitating automatic control of the fluid pressure in response to real-time or near real-time conditions, which may improve an efficiency of the operations. In addition, certain embodiments described herein may increase safety at ahydraulic fracturing system 2 by providing for faster responses to changing fluid pressure conditions across multiple well heads 18 and/or multiple fracturing sites, by reducing or eliminating a need for human operators to be physically present at the well heads 18, and/or the like. Furthermore, certain embodiments may reduce or eliminate latency between stages of hydraulic fracturing operations through operation schedule-based control, which may improve an efficiency of thehydraulic fracturing system 2, conserve fuel or power resources by reducing an amount of time needed to perform hydraulic fracturing operations, and/or the like. - It will be apparent to those skilled in the art that various modifications and variations can be made to the disclosed system without departing from the scope of the disclosure. Other embodiments of the system will be apparent to those skilled in the art from consideration of the specification and practice of the system disclosed herein. It is intended that the specification and examples be considered as exemplary only, with a true scope of the disclosure being indicated by the following claims and their equivalents.
Claims (20)
1. A hydraulic fracturing system, comprising:
one or more fracturing rigs;
one or more blending equipment fluidly connected to inlets of the one or more fracturing rigs;
one or more power sources electrically connected to a first subset of the one or more fracturing rigs, or one or more fuel sources fluidly connected to a second subset of the one or more fracturing rigs;
one or more missile valves fluidly connected to outlets of the one or more fracturing rigs;
valves; and
one or more zipper valves fluidly connected to outlets of the one or more missile valves;
one or more well head valves fluidly connected to outlets of the one or more zipper one or more well heads fluidly connected to outlets of the one or more well head valves;
a controller, wherein the controller is configured to:
monitor, for a well head of the one or more well heads, an operation or a state of one or more subsystems of the hydraulic fracturing system, and
control, based on an operation schedule for the hydraulic fracturing system and based on monitoring the operation or the state, the state or equipment changes.
2. The hydraulic fracturing system of claim 1 , wherein the one or more subsystems are associated with pumping a fracturing fluid to the well head and the one or more subsystems comprise pumps of at least one of the one or more fracturing rigs, at least one of the one or more missile valves, at least one of the one or more well head valves, or at least one of the one or more zipper valves.
3. The hydraulic fracturing system of claim 1 , wherein the controller is further configured to:
control one or more valve states for at least one of the one or more missile valves, at least one of the one or more zipper valves, or at least one of the one or more well head valves based on the operation schedule, the operation, or the state.
4. The hydraulic fracturing system of claim 3 , wherein the controller is further configured, when monitoring the operation or the state, to:
monitor an open or a closed state of the one or more missile valves, the one or more well head valves, or the one or more zipper valves; and
wherein the controller is further configured, to control a fluid pressure in order to:
control the one or more missile valves, the one or more well head valves, or the one or more zipper valves to prevent the hydraulic fracturing system from exceeding a pressure limit by pumping on a closed pathway.
5. The hydraulic fracturing system of claim 1 , wherein the controller is further configured, when controlling the state or the equipment changes, to:
close a first well head of the one or more well heads and close a first subset of the one or more zipper valves associated with the first well head; and
after closing the first well head and closing the first subset, open a second well head of the one or more well heads and open a second subset of the of the one or more zipper valves associated with the second well head.
6. The hydraulic fracturing system of claim 1 , wherein the controller is further configured to operate in one or more operational modes, wherein the one or more operational modes comprise at least one of:
a closed mode,
an autonomous mode, or
a multi-site mode.
7. The hydraulic fracturing system of claim 1 , wherein the monitoring of the operation or the state are performed for multiple hydraulic fracturing sites.
8. A method, comprising:
monitoring, for a well head of a hydraulic fracturing system, an operation or a state of one or more subsystems of the hydraulic fracturing system, wherein the hydraulic fracturing system comprises:
one or more fracturing rigs,
one or more blending equipment fluidly connected to inlets of the one or more fracturing rigs,
one or more power sources electrically connected to a first subset of the one or more fracturing rigs, or one or more fuel sources fluidly connected to a second subset of the one or more fracturing rigs,
one or more missile valves fluidly connected to outlets of the one or more fracturing rigs,
one or more zipper valves fluidly connected to outlets of the one or more missile valves,
one or more well head valves fluidly connected to outlets of the one or more zipper valves, and
one or more well heads fluidly connected to outlets of the one or more well head valves; and
controlling, based on an operation schedule for the hydraulic fracturing system and based on monitoring the operation or the state, the state or equipment changes.
9. The method of claim 8 , wherein the monitoring of the operation or the state further comprises:
monitoring an open or a closed state of the one or more missile valves, the one or more well head valves, or the one or more zipper valves; and
wherein the controlling further comprises:
controlling the open or the closed state of the one or more missile valves, the one or more well head valves, or the one or more zipper valves to prevent a fluid pressure from exceeding a pressure limit for the hydraulic fracturing system by pumping on a closed pathway.
10. The method of claim 8 , wherein the operation schedule is for a planned well completion.
11. The method of claim 8 , further including controlling a fluid pressure by:
shutting down a fracturing rig of the one or more fracturing rigs and a blending equipment of the one or more blending equipment;
closing a first well head of the one or more well heads and a first subset of zipper valves associated with the first well head;
opening a second well head of the one or more well heads and a second subset of zipper valves associated with the second well head; and
starting the fracturing rig and the blending equipment.
12. The method of claim 11 , wherein the controlling of the fluid pressure further comprises:
controlling the fluid pressure within a pressure limit for the hydraulic fracturing system.
13. The method of claim 8 , wherein the one or more subsystems are associated with pumping a fracturing fluid to the well head and the one or more subsystems comprise at least one of the one or more blending equipment, at least one of the one or more missile valves, at least one of the one or more zipper valves, or at least one of the one or more well head valves.
14. The method of claim 8 , wherein the monitoring of the operation or the state further comprises:
monitoring operational parameters of one or more pumps of at least one of the one or more fracturing rigs; and
wherein the controlling further comprises:
controlling the operational parameters of the one or more pumps to cause the hydraulic fracturing system to operate at a particular fluid pressure.
15. The method of claim 8 , wherein the monitoring and the controlling are performed for multiple hydraulic fracturing sites and one or more other well heads of the one or more well heads.
16. A controller for a hydraulic fracturing system, the controller being configured to:
monitor, for a well head of a hydraulic fracturing system, an operation or a state of one or more subsystems of the hydraulic fracturing system, wherein the hydraulic fracturing system comprises:
one or more fracturing rigs,
one or more blending equipment fluidly connected to inlets of the one or more fracturing rigs,
one or more power sources electrically connected to a first subset of the one or more fracturing rigs, or one or more fuel sources fluidly connected to a second subset of the one or more fracturing rigs,
one or more missile valves fluidly connected to outlets of the one or more fracturing rigs,
one or more zipper valves fluidly connected to outlets of the one or more missile valves,
one or more well head valves fluidly connected to outlets of the one or more zipper valves, and
one or more well heads fluidly connected to outlets of the one or more well head valves; and
control, based on an operation schedule for the hydraulic fracturing system and based on monitoring the operation or the state, the state or equipment changes.
17. The controller of claim 16 , further configured, when monitoring the operation or the state, to:
monitor the operation or the state of the one or more blending equipment; and
wherein the controller is further configured to:
control the one or more blending equipment to prevent a fluid pressure from falling below a minimum suction pressure.
18. The controller of claim 16 , further configured, when monitoring the operation or the state, to:
monitor the operation or the state of pumps of at least one of the one or more fracturing rigs; and
wherein the controller is further configured to:
control the pumps to meet an expected fluid pressure.
19. The controller of claim 16 , further configured, when monitoring the operation or the state, to:
monitor the operation or the state based on information from one or more valve controllers or one or more valve sensors.
20. The controller of claim 16 , further configured to:
control a fluid pressure within one or more safety limits.
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CN202310224387.8A CN116733430A (en) | 2022-03-11 | 2023-03-09 | Controlling fluid pressure at a wellhead based on an operating schedule |
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