Automated pressure control system

Abstract

To compensate for an event, equipment may require a power down sequence of a motor connected to a pump to prevent the pumping of servicing fluid at a high pressure, high pressure fluid may be required to be diverted to a reservoir or otherwise diverted from a wellhead, multiple pumping systems may require that pumping pressure be altered or adjusted or that flow rate be altered or adjust to manage or control the conditions to protect equipment or personnel at a site. Activating, adjusting or altering an operational characteristic of equipment by using a control system may automatically initiate the most efficient and effective mitigation steps for equipment at a site when condition is detected or predicted. Collecting and analyzing information from devices, components, sensors, control systems, other equipment or any combination thereof at a site by a master control system provides automated control of pressure sensitive conditions.

Description

<DP=1>²CA 03072992 2020-02-13²WO 2019 / 108177 PCT / US2017 / 063697 ²AUTOMATED PRESSURE CONTROL SYSTEM²TECHNICAL FIELD²The present disclosure relates generally to an automated pressure control ²system, more²particularly, to control and operation of equipment during or in anticipation ²of an overpressure² event.²BACKGROUND²Hydrocarbons, such as oil and gas, are commonly obtained from subterranean ²formations²that may be located onshore or offshore. The development of subterranean ²operations and the²processes involved in removing hydrocarbons from a subterranean formation are ²complex.²Typically, subterranean operations involve a number of different steps such ²as, for example,²drilling a wellbore at a desired well site, treating the wellbore to optimize ²production of ²hydrocarbons, and performing the necessary steps to produce and process the ²hydrocarbons from ²the subterranean formation.²Several types of equipment, including various valves, pumps, motors, ²transmissions and²manifolds may be used in all phases of well servicing operations including to ²pump water,²cement, fracturing fluids, and other stimulation or servicing fluids as well ²as other pumping ²operations. During a well service operation, a condition may occur (for ²example, an ²overpressure condition or event) or a test may be desired to be ran that ²requires a rapid or ²substantially instantaneous stop, alteration or function of equipment at the ²site. Different types²of equipment require different methods or techniques for altering operation so ²as not to damage²the equipment and not to harm nearby personnel. Traditionally, equipment is ²controlled by ²individual controllers that do not have information associated with other ²equipment at the site. ²Due to the limited information of the individual controllers, when a condition ²occurs, the ²individual controllers may not know of the condition or may implement a ²mitigation that is not²coordinated with the functionality of other equipment at the site, more ²costly, inefficient,²unreliable or not appropriate for the given condition. For example, a ²mitigation of a condition or ²event implemented for certain equipment may require the equipment to be ²rebuilt, reset, ²replaced, or recertified resulting in delays and additional costs. Thus, an ²optimized mitigation is ²needed to maintain efficient and effective operation of equipment at a site.² 1²<DP=2>²CA 03072992 2020-02-13²WO 2019 / 108177 ²PCT / US2017 / 063697²FIGURES²Some specific exemplary embodiments of the disclosure may be understood by ²referring,²in part, to the following description and the accompanying drawings.²Fig. 1 is a diagram illustrating an automated pressure control system for a ²site, according² to one or more aspects of the present disclosure.²Fig. 2 is a diagram illustrating an automated pressure control system for a ²site, according ²to one or more aspects of the present disclosure.²Fig. 3 is a flowchart of a method for automated pressure control of a system, ²according to ²one or more aspects of the present disclosure.²Fig. 4 is a flowchart of a method for automated pressure control of a system, ²according to²one or more aspects of the present disclosure.²Fig. 5 is a diagram illustrating an example information handling system, ²according to²aspects of the present disclosure.²While embodiments of this disclosure have been depicted and described and are ²defined²by reference to exemplary embodiments of the disclosure, such references do ²not imply a²limitation on the disclosure, and no such limitation is to be inferred. The ²subject matter ²disclosed is capable of considerable modification, alteration, and equivalents ²in form and ²function, as will occur to those skilled in the pertinent art and having the ²benefit of this ²disclosure. The depicted and described embodiments of this disclosure are ²examples only, and²not exhaustive of the scope of the disclosure.²2²<DP=3>²CA 03072992 2020-02-13²WO 2019 / 108177 ²PCT / US2017 / 063697²DETAILED DESCRIPTION²The present disclosure relates generally to an automated pressure control ²system, more ²particularly, to control and operation of equipment during or in anticipation ²of a triggering event²or condition, for example an overpressure event. Generally, several types of ²engines may be²used to drive one or more types of pumps for pumping a fluid at a pressure at ²a site. For²example, during hydrocarbon recovery, one or more engines and pumps may be ²used to pump a ²fluid downhole for a stimulation operation at a well site. The same types of ²engines and pumps ²may be used or any combination of types of engines and pumps may be used ²according to a ²configuration and operation at a particular site. Conditions at a site may ²require that any one or²more pumps or engines be stopped immediately or substantially instantaneously ²to prevent²damage to the pump, the motor or powertrain driving the pump, and surrounding ²equipment or ²environment, that a valve be opened or closed, that fluid be diverted to a ²reservoir or container, ²that an operation or function of any other equipment be altered or adjusted or ²any combination ²thereof. For example, a triggering event, such as an overpressure condition, ²may occur or be²anticipated or an operator may require that one or more tests be ran. With a ²diesel engine, the²clutch could be disengaged from the transmission, or the transmission shifted ²to neutral, stopping ²substantially instantaneously the driving of the pump. However, diesel engines ²may not be ²suitable for a given well site environment due to operational parameters or ²characteristics of the ²diesel engine, for example, control over pump rate, exhaust emissions and ²noise emissions. An²electric motor or powertrain may provide the operational parameters or ²characteristics required²for a given well site environment. However, electric motors or powertrains ²comprise a rotor that ²may have substantial inertia that is not easily stopped or ceased during ²operation without causing ²damage to the equipment. Each group of motors, transmissions, driveline ²disconnects, pumps or ²other equipment may be controlled by an individual controller such that each ²group reacts to a²condition independent of other groups. In some instances, such independent ²control may not²provide the most efficient, inexpensive, effective, reliable and acceptable ²mitigation of a ²condition. One or more aspects of the present disclosure provide for ²controlling the equipment ²at a site based on information from one or more groups or individual ²components and equipment ²to provide a coordinated and site-based approach to mitigation of a condition, ²such as an² overpressure condition or an anticipation of an overpressure condition.²In one or more aspects of the present disclosure, an operation at a site may ²utilize an ²information handling system to control one or more operations including, but ²not limited to, a ²motor or powertrain, one or more valves, one or more disconnects, one or more ²transducers, a ²wellhead, a downstream pressurized fluid system, or any combination thereof. ²For purposes of²3²<DP=4>²CA 03072992 2020-02-13²WO 2019 / 108177 ²PCT / US2017 / 063697²this disclosure, an information handling system may include any ²instrumentality or aggregate of ²instrumentalities operable to compute, classify, process, transmit, receive, ²retrieve, originate, ²switch, store, display, manifest, detect, record, reproduce, handle, or ²utilize any form of ²information, intelligence, or data for business, scientific, control, or other ²purposes. For²example, an information handling system may be a personal computer, a network ²storage device,²or any other suitable device and may vary in size, shape, performance, ²functionality, and price. ²The information handling system may include random access memory (RAM), one or ²more ²processing resources such as a central processing unit (CPU) or hardware or ²software control ²logic, ROM, and / or other types of nonvolatile memory. Additional components of ²the²information handling system may include one or more disk drives, one or more ²network ports for²communication with external devices as well as various input and output (I / 0) ²devices, such as a ²keyboard, a mouse, and a video display. The information handling system may ²also include one ²or more buses operable to transmit communications between the various hardware ²components. ²The information handling system may also include one or more interface units ²capable of² transmitting one or more signals to a controller, actuator, or like device.²For the purposes of this disclosure, computer-readable media may include any ²instrumentality or aggregation of instrumentalities that may retain data ²and / or instructions for a ²period of time. Computer-readable media may include, for example, without ²limitation, storage ²media such as a direct access storage device (for example, a hard disk drive ²or floppy disk drive),²a sequential access storage device (for example, a tape disk drive), compact ²disk, CD-ROM,²DVD, RAM, ROM, electrically erasable programmable read-only memory (EEPROM), ²and / or ²flash memory, as well as communications media such wires, optical fibers, ²microwaves, radio ²waves, and other electromagnetic and / or optical carriers, and / or any ²combination of the ²foregoing.²Illustrative embodiments of the present disclosure are described in detail ²herein. In the²interest of clarity, not all features of an actual implementation may be ²described in this ²specification. It will of course be appreciated that in the development of any ²such actual ²embodiment, numerous implementation-specific decisions must be made to achieve ²the specific ²implementation goals, which will vary from one implementation to another. ²Moreover, it will be²appreciated that such a development effort might be complex and time-²consuming, but would²nevertheless be a routine undertaking for those of ordinary skill in the art ²having the benefit of ²the present disclosure.²Throughout this disclosure, a reference numeral followed by an alphabetical ²character ²refers to a specific instance of an element and the reference numeral alone ²refers to the element²4²<DP=5>²CA 03072992 2020-02-13²WO 2019 / 108177 ²PCT / US2017 / 063697²generically or collectively. Thus, as an example (not shown in the drawings), ²widget "la" refers ²to an instance of a widget class and widget "in" refers to an nth instance of ²a widget class where ²"n" represent any number of widgets, which may be referred to collectively as ²widgets "1" and ²any one of which may be referred to generically as a widget "1". In the ²figures and the² description, like numerals are intended to represent like elements.²To facilitate a better understanding of the present disclosure, the following ²examples of ²certain embodiments are given. In no way should the following examples be read ²to limit, or ²define, the scope of the disclosure. Embodiments of the present disclosure may ²be applicable to ²drilling operations that include but are not limited to target (such as an ²adjacent well) following,²target intersecting, target locating, well twinning such as in SAGD (steam ²assist gravity²drainage) well structures, drilling relief wells for blowout wells, river ²crossings, construction ²tunneling, as well as horizontal, vertical, deviated, multilateral, u-tube ²connection, intersection, ²bypass (drill around a mid-depth stuck fish and back into the well below), or ²otherwise nonlinear ²wellbores in any type of subterranean formation. Embodiments may be applicable ²to injection²wells, and production wells, including natural resource production wells such ²as hydrogen²sulfide, hydrocarbons or geothermal wells; as well as borehole construction ²for river crossing ²tunneling and other such tunneling boreholes for near surface construction ²purposes or borehole ²u-tube pipelines used for the transportation of fluids such as hydrocarbons. ²Embodiments ²described below with respect to one implementation are not intended to be ²limiting.²Fig. 1 is a diagram illustrating an automated pressure control system 150 for ²a site, for²example, well environment 100, according to one or more aspects of the present ²disclosure. ²While Fig. 1 relates to a well environment 100, any one or more components of ²automated ²pressure control system 150 may be implemented at a site that requires pumping ²of a fluid 146 ²under pressure to a wellhead 114 associated with a borehole 152. For example, ²a fluid 146 may²be a well services fluid including, but not limited to a fluid, a solid, a gas ²or any combination²thereof. For example, a fluid 146 may comprise a stimulation fluid, a sand, a ²treatment fluid, ²water, a slurry, a composite, a mixture or any suitable combination thereof. ²While Fig. 1 ²illustrates an automated pumping control system 150, any one or more automated ²pumping ²control systems 150 may be implemented or configured at well environment 100.²In one or more embodiments, an automated pumping control system 150 may ²comprise a²master control system 102 and one or more control systems 104. The master ²control system 102 ²may comprise any one or more information handling systems, for example, one or ²more control ²systems 104. In one or more embodiments, each of the one or more controls ²systems 104 may ²comprise one or more information handling systems, such as one or more control ²systems 104 or²5²<DP=6>²CA 03072992 2020-02-13²WO 2019 / 108177 ²PCT / US2017 / 063697²a master control system 102. For example, in one or more embodiments, the ²master control ²system 102 comprises the one or more control systems 104 and thus any one or ²more elements or ²equipment illustrated in Fig. 1 as coupled directly or indirectly to the one ²or more control ²systems 104 may be coupled directly or indirectly to master control system 102 ²as illustrated in²Fig. 2. In one or more embodiments control system 102, control system 104 or ²any combination²thereof may comprise an information handling system, such as information ²handling system 500 ²of Fig. 5, or any other computer device.²In one or more embodiments, the automated pumping control system 150 comprises ²one ²or more pumping systems 106, for example, pumping systems 106a, 106b and 106n. ²Each²pumping systems 106 may comprise any one or more motors or engines 108, one or ²more²transmissions or driveline disconnects 110 and one or more pumps 112. For ²example, pumping ²system 106a may comprise one or more motors or engines 108a, one or more ²transmissions or ²driveline disconnects 110a and one or more pumps 112a and pumping system 106b ²may ²comprise one or more motors or engines 108b, one or more rotors 154 of motor ²or engine 108b,²one or more transmissions or driveline disconnects 110b and one or more pumps ²112b and²pumping system 106n may comprise one or more motors or engines 108n, one or ²more ²transmissions or driveline disconnects 110n and one or more pumps 112n. A ²motor or engine ²108 may drive or actuate a pump 112, for example, via a transmission or ²driveline disconnect ²110, to pump fluid 146 to wellhead 114. Each pumping system 106 may ²communicatively²couple via a wired or wireless connection or directly or indirectly to a ²control system 104. For²example, pumping system 106a may communicatively couple to control system ²104a, pumping ²system 106b may communicatively couple to control system 104b and pumping ²system 106n ²may communicatively couple to control system 104n. In one or more embodiments, ²any ²combination of pumping systems 106 may be communicatively coupled to any one ²or more²control systems 104. In one or more embodiments, the motor 108 may comprise an ²electric²motor, a diesel engine, natural gas engine, hydraulic motor, a turbine or any ²other type of motor. ²In one or more embodiments, the pumping system 106 may comprise a positive ²displacement ²pump, a hydraulic pump, centrifugal pump or any other type of pump. In one or ²more ²embodiments, the transmission or driveline disconnect 110 may comprise a ²releasable coupling,²shearable coupling, torque-limiting coupling, transmission neutral position, ²or any other type of²transmission or driveline disconnect.²In one or more embodiments, any one or more motors 108 may comprise a sensor, ²for²example, motor 108a may comprise a sensor 126, any one or more transmission or ²driveline ²disconnects 110 may comprise a sensor, for example, sensor 128 and any one or ²more pumps²6²<DP=7>²CA 03072992 2020-02-13²WO 2019 / 108177 ²PCT / US2017 / 063697²112 may comprise a sensor, for example sensor 130. In one or more embodiments, ²a pumping ²system 106 may comprise a sensor that couples to any one or more components of ²the pumping ²system 106, for example, pumping system 106n may comprise a sensor 140 that ²couples to ²motor or engine 108, transmission or driveline disconnect 110n, pump 112n or ²any combination²thereof. In one or more embodiments, any one or more sensors 126, 128, 130 and ²140 may²couple to any one or more motors or engines 108, one or more transmissions or ²driveline ²disconnects, one or more pumps 112, one or more pumping systems 106 or any ²combination ²thereof. Sensors 126, 128, 130, and 140 may sense one or more operational ²parameters or ²characteristics of the respective equipment, communicate one or more ²measurements or²information associated with the operational parameters or characteristics of ²the respective²equipment, or both to a control system 104. Any one or more sensors 126, 128, ²130 and 140 ²may communicatively couple to control system 104 via a wired or wireless ²connection or ²directly or indirectly. The control system 104 may control one or more ²operational parameters ²or characteristics of motor or engine 108, transmission or driveline ²disconnect 110, pump 112,²pumping system 106 or any combination thereof based, at least in part, on one ²or more²measurements or information received from one or more sensors 126, 128, 130 ²and 140. For ²example, the control system 104 may control one or more operational parameters ²or ²characteristics of the motor 108 (for example, speed, torque, voltage, ²current, temperature, ²acceleration, deceleration, or any other parameters or characteristics), one ²or more operational²parameters or characteristics of the transmission or driveline disconnect 110 ²(for example,²application of clutches, range selection, temperature, torque converter lock-²up or any other ²operational parameters or characteristics), one or more operational parameters ²or characteristics ²of the pump 112 (for example, discharge rate, pressure, valve operation or any ²other operational ²parameters or characteristics), one or more operational parameters or ²characteristics of the pump²system 106 or any combination thereof. In one or more embodiments, any one or ²more control²systems 104 may be communicatively coupled to any one or more control systems ²104 and may ²be communicatively coupled to one or more different components of pumping ²system 106. In ²one or more embodiments, control system 104 may be located remotely from, ²proximate to or at ²any suitable location with respect to any one or more pumping systems 106 or ²automated² pressure control system 150.²Any one or more pumping systems 106 may be coupled to one or more high ²pressure ²manifolds 116. High pressure manifold 116 may be coupled to a relief valve ²120, a pressure ²transducer 118 and to a wellhead 114. Each high pressure manifold 116, relief ²valve 120 and ²wellhead 114 may comprise one or more sensors 132, 134 and 136, respectively. ²Any one or²7²<DP=8>²CA 03072992 2020-02-13²WO 2019 / 108177 ²PCT / US2017 / 063697²more pumping systems 106 may also be coupled to a boost pump 122 and boost ²pump 122 may ²be coupled to a low pressure reservoir 124. Each of the boost pump 122 and low ²pressure ²reservoir 124 may comprise one or more sensors 138 and 142, respectively. In ²one or more ²embodiments, any one or more of the high pressure manifold 116, pressure ²transducer 118,²wellhead 114, control system 104, relief valve 120, boost pump 122, low ²pressure reservoir 124²may be communicatively coupled wired or wireles sly or directly or indirectly ²to a master control ²system 102. In one or more embodiments, any one or more sensors 132, 134 and ²136 may ²communicatively couple to a control system 104, for example, control system ²104c, via a wired ²or wireless connection or directly or indirectly. The master control system ²102 may control one²or more operational parameters or characteristics of a motor or engine 108, a ²transmission or²driveline disconnect 110, a pump 112, a pumping system 106, a pressure ²transducer 118, a ²manifold 116, a relief valve 120, a wellhead 114 or any combination thereof ²based, at least in ²part, on one or more measurements or information received from any one or more ²sensors 126, ²128, 130, 132, 134, 136, 138, 140, 142, 144, pressure transducer 118. In one ²or more²embodiments, any one or more of sensors 126, 128, 130, 132, 134, 136, 138, ²140, 142 and 144²may be communicatively coupled to master control system 102 either directly or ²indirectly and ²wired or wirelessly. For example, pumping system 106a may be communicatively ²coupled ²directly to master control system 102, indirectly to master control system 102 ²via control system ²104a or both.²Master control system 102, control system 104 or both may comprise hardware, ²software²or any combination thereof to process, analyze, store or any combination ²thereof any information ²received from any one or more sources, for example, any one or more of ²sensors, devices, ²components or equipment, for example, as discussed above and illustrated in ²Fig. 1 at well ²environment 100 or any other site. Master control system 102 may control one ²or more²operational parameters or characteristics of any one or more sensors, devices, ²components or²equipment, for example, as discussed above and illustrated in Fig. 1, based, ²at least in part, on ²the information received. For example, in one or more embodiments, any one or ²more control ²systems 104 or master control system 102 may receive information or one or ²more²measurements from any one or more sources including, but not limited to, any ²one or more²sensors 126, 128, 130, 132, 134, 136, 138, 140, 142 and 144, one or more ²control systems 104,²one or more engines or motors 108, one or more transmissions or driveline ²disconnects 110, one ²or more pumping systems 106, pressure transducer 118, relief valve 120, ²wellhead 114, high ²pressure manifold 116, boost pump 122, low pressure reservoir 124, any other ²component, ²equipment or device at well environment 100 or any combination thereof. The ²information²8²<DP=9>²CA 03072992 2020-02-13²WO 2019 / 108177 ²PCT / US2017 / 063697²received by the master control system 102 from any source may comprise any one ²or more ²operational parameters or characteristics of associated sensors, devices, ²components or ²equipment, for example, any one or more of pump pressure, discharge rate, and ²valve operation ²associated with one or more pumps 112 or any other operational parameter or ²characteristic),².. engine speed associated with one or more motors or engines 108, gear range, ²temperature,²rotational speed torque converter lock-up state, clutch application state, ²torque and disconnect ²condition associated with transmission or driveline disconnect 110, pressure ²associated with ²pressure transducer 118, set condition or state associated with relief valve ²120, pressure, flow ²rate and valve position associated with wellhead 114, pressure, flow rate and ²valve position².. associated with high pressure manifold 116, rotational speed, inlet ²pressure and discharge²pressure associated with boost pump 122, fluid temperature, pressure and fluid ²volume ²associated with low pressure reservoir 124 or any other information associated ²with any other ²component, equipment or device at well environment 100, or any combination ²thereof. Based, at ²least in part, on information received, the master control system 102 may ²determine that a²triggering event or condition, for example, an overpressure event, has ²occurred, is about to or²anticipated to occur, may occur or any combination thereof. For example, the ²master control ²system 102 may compare or otherwise analyze information received to determine ²if a threshold ²for an event, such as an overpressure event, has been reached or exceeded, an ²overpressure event ²falls below or is at a threshold, any other condition has been met or any ²combination thereof.²The master control system 102 may also assess or determine the total energy of ²each²component, device or equipment at a site or well environment, including, but ²not limited to, ²parameters of present energy (for example, pressurized fluid and kinetic ²energy) and connected ²energy input device (for example, engines, motors and pressure sources). This ²energy ²assessment or determination may then be used to select and execute a response ²or mitigation step²to prevent or mitigate one or more undesirable events, such as, an ²overpressure event. The²mitigation step or response may be based, at least in part, on current state ²and projected ²conditions (for example, based, at least in part, on data and related trends ²gathered from the ²devices, components and equipment at the site or well environment).²In one or more embodiments, the master control system 102 may transmit or ²otherwise²communicate a control signal to any one or more of sensors, devices, ²components or equipment,²for example, as discussed above and illustrated in Fig. 1, based at least in ²part on the above ²analysis. For example, the master control system 102 may transmit or ²communicate a control ²signal to one or more engines or motors 108, one or more transmissions or ²driveline disconnects ²110, one or more pumping systems 106, pressure transducer 118, relief valve ²120, wellhead 114,²9²<DP=10>²CA 03072992 2020-02-13²WO 2019 / 108177 ²PCT / US2017 / 063697²high pressure manifold 116, boost pump 122, low pressure reservoir 124, any ²other component, ²equipment or device at well environment 100 or any combination thereof to ²alter or adjust one ²or more operational parameters or characteristics including, but not limited ²to, adjusting or ²altering any one or more operation parameters thereof, for example, the ²operational parameters² discussed above.²Fig. 2 is a diagram illustrating an automated pressure control system 150 for ²a site, for ²example, well environment 200, according to one or more aspects of the present ²disclosure. The ²discussion of Fig. 1 applies likewise to Fig. 2 except instead of one or more ²control systems 104 ²communicatively coupled to a master control system 102, only a master control ²system 102 is²illustrated. In one or more embodiments, master control system 102 comprises ²one or more²control systems 104, one or more master control systems 102 or any combination ²thereof. ²Fig. 3 is a flowchart 300 of a method for automated pressure control of a ²system ²according to one or more aspect of the present disclosure. During one or more ²well servicing²operations or other types of operations, it may be necessary, required or part ²of a job plan or²workflow to monitor, maintain, adjust, alter, or otherwise control the ²pressure of fluid of a²system or a configuration of equipment, for example, equipment at a well ²environment 100 as ²illustrated in Fig. 1. Certain events, triggering events or conditions, such ²as an overpressure ²event, may require immediate, instantaneous or methodical actions or ²responses, for example, ²one or more mitigation steps, to prevent or mitigate damage or destruction of ²equipment or harm²to personnel.²In one or more embodiments, at step 302 a site is configured, for example, ²well ²environment 100 of Fig. 1, according to one or more criteria, a workflow, a ²job plan or any ²combination thereof. Configuration of the site may require that equipment, one ²or more sensors ²associated with the equipment, or both be coupled to one or more control ²systems, for example,²coupled to control system 104, master control system 102, or both as ²illustrated in and discussed²with respect to Fig. 1. The site may be configured in any manner to meet the ²needs and ²requirements of a specific job. Configuration of the site may also include ²setting one or more ²thresholds associated with one or more operational parameters associated with ²one or more ²components, devices or equipment at the site. A threshold may be associated ²with an event, for²example, an overpressure event. In one or more embodiments, a threshold may be ²based, at least²in part, on any one or more threshold parameters or models. The one or more ²threshold ²parameters may include, but are not limited to, a configuration of the system ²at a site, for ²example, well environments 100 and 200 of Fig. 1 and Fig. 2, respectively, a ²fluid pressure, a ²performance rating, a pressure rating, state or health, altitude, temperature, ²age, wear, or any²<DP=11>²CA 03072992 2020-02-13²WO 2019 / 108177 ²PCT / US2017 / 063697²other characteristic or operational parameter associated with a component, ²device or equipment ²at a site. For example, a sensor associated with a braking system may sense ²temperature ²associated with the braking system of a motor or engine, for example, motor or ²engine 108, such ²that the braking system is only allowed to be activated when the temperature ²is below a specified²temperature or threshold. The one or more models may comprise models that ²relate to pressure,²energy, or any other operational parameter or characteristic. For example, one ²or more models ²may comprise a graphical representation of pressure where the shape of the ²pressure curve may ²be used to anticipate peak pressure, time to peak pressure, time to ²incrementally decrease ²pressure, any other pressure characteristic or combination thereof.²At step 304, the operation of the site may begin. For example, any one or more ²pumps²may be actuated to begin pumping a fluid to a wellhead as illustrated in and ²discussed with ²respect to Fig. 1 and Fig. 2. Any one or more alarms or triggers associated ²with a threshold may ²be reset, preset or otherwise initialized. In one or more embodiments, at ²start-up one or more ²start-up thresholds may be utilized while once the configuration is ²operational, one or more run-²time thresholds may be utilized. For example, at start-up a motor or engine ²may operate using a²first current or first power which is reduced to a second current or second ²power once the motor ²or engine has reached the required operational state, for example, a maximum ²efficiency state.²At step 306, one or more sensors, one or more components, devices or equipment ²at the ²site or both detect one or more operational parameters or characteristics ²associated with the site,²for example, associated with one or more components, devices or equipment as ²discussed above²with respect to Fig. 1. For example, a pump 112 or a sensor 144 of a pump 112 ²may detect an ²operational parameter of the pump 112 and communicate that information to ²control system 104 ²or master control system 102 (as illustrated in Fig. 1 and Fig. 2).²At step 308, information associated with an event, a triggering event or ²condition, for²example, an overpressure event, is received. For example, the detected one or ²more operational²parameters or characteristics from step 306 associated with the operation of ²the components, ²devices, equipment or any combination thereof may be received at a control ²system 104, master ²control system 102 or both as illustrated in Fig. 1 and Fig. 2. This ²information may be received ²from any one or more sensors, the one or more components, devices, equipment ²or any²combination thereof either directly or indirectly, wired or wireles sly or any ²combination thereof.²At step 310, the information is processed. In one or more embodiments, the ²information ²from step 308 received at one or more control systems 104 may be communicated ²to a master ²control system 102 for processing as illustrated in Fig. 1 and Fig. 2. In one ²or more²embodiments, the information from step 308 received at one or more information ²handling²11²<DP=12>²CA 03072992 2020-02-13²WO 2019 / 108177 ²PCT / US2017 / 063697²systems, such as control systems 102, master control systems 104, or both, may ²be processed at ²the one or more information handling systems. In one or more embodiments, the ²information ²received from step 308 at an information handling system is processed at the ²master control ²system 102 as illustrated in Fig. 2. The information may be processed to ²determine that an²event, triggering event or condition has occurred, is about or anticipated to ²occur, a prediction,²likelihood or probability of occurrence or any combination thereof.²At step 312, one or more conditions or operational states of any one or more ²of ²components, devices, or equipment at a site are altered, adjusted, maintained ²or otherwise ²controlled based, at least in part, on the information processed at step 310. ²For example, any one²or more operational parameters or characteristics as discussed above may be ²altered, adjusted,²maintained, changed or otherwise controlled to effectuate mitigation of the ²event, triggering ²event or condition by, for example, altering, adjusting, maintaining or ²otherwise controlling any ²one or more the components, devices, or equipment at site, such as well ²environment 100 of Fig. ²1 and well environment 200 of Fig. 2.²Fig. 4 is a flowchart 400 of a method for automated pressure control of a ²system,²according to one or more aspects of the present disclosure. At step 402, ²information or one or ²more measurements are received from one or more sensors, components, devices, ²equipment or ²any combination thereof for a pumping system 106 at a site as discussed with ²respect to step 308 ²of Fig. 3 and illustrated in and discussed with respect to Fig. 1 and Fig. 2.²At step 404, an operational status of the pumping system 106 is determined. ²For²example, an operational status may comprise a rate of change of the fluid ²pressure in the ²pumping system 106, an energy consumption level, a rate of change in kinetic ²energy or any ²combination thereof. For example, the rate of change of the fluid pressure in ²the pumping ²system 106, for example, automated pressure control system 100 or 200 of Fig. ²1 and Fig. 2,²respectively, and kinetic energy may be calculated based, at least in part, on ²any one or more of²inertial mass and velocity of any one or more of the components, devices, ²equipment, or any ²combination thereof of automated pressure control system 100 or 200 of Fig. 1 ²and Fig. 2, ²respectively, volume of fluid, for example, volume of fluid 146, pressure of ²fluid, for example, ²fluid 146, compressibility of fluid, for example, compressibility of fluid ²146, fluid velocity, for²example, fluid velocity of fluid 146, one or more wellhead characteristics, ²for example wellhead²characteristics associated with wellhead 114, one or more borehole ²characteristics (such as ²depth, pipe size, and orientation), for example, borehole characteristics ²associated with borehole ²152, pipe length, for example, pipe length of automated pumping control system ²150, any other ²characteristic or parameter associated with the site or automated pumping ²control system 150,²12²<DP=13>²CA 03072992 2020-02-13²WO 2019 / 108177 ²PCT / US2017 / 063697²and any combination thereof.²The inertial mass and rotational speed may be indicative of energy stored by ²the motor²or engine 108, the transmission or driveline disconnect 110, the pump 112, ²presser transducer ²118, gears, gear reducer, couplings, or any other component, device, or ²equipment at the site.²The angular velocity may be related to the one or more inertial masses and ²velocity of any one or²more components, devices, equipment or any combination thereof of the site. ²The volume of ²fluid in combination with the compressibility of fluid is indicative of the ²increase or decrease in ²pressure or the rate thereof necessary to mitigate an event, such as an ²overpressure event. One or ²more borehole characteristics may comprise resistance of the borehole, for ²example, borehole²152, to receive a fluid, for example, fluid 146. One or more wellhead ²characteristics may²comprise any one or more of pressure, bore diameter, conduit length, pressure ²rating and valve ²position.²At step 406, an event, such as a triggering event, is determined to have ²occurred. In one ²or more embodiments, an overpressure event is determined. Determining an ²event, a triggering²event or a condition may comprise determining that an event has occurred, is ²about to or is²anticipated to occur, may occur or any combination thereof. In one or more ²embodiments, the ²event may be determined based, at least in part, on a comparison of ²operational status to a ²threshold. In one or more embodiments, an overpressure event may be determined ²based, at ²least in part, on the calculated rate of change of fluid pressure compared to ²a threshold associated².. with an overpressure event. The threshold associated with the overpressure ²event may be set as²discussed with respect to step 302 of Fig. 3. For example, the threshold may ²be based, at least in ²part, on any one or more threshold parameters or one or more models. In one or ²more ²embodiments, an overpressure event may be anticipated or determined to have ²occurred based, at ²least in part, on the calculated rate of change of fluid pressure exceeding, ²being equal, or both to² .. a threshold associated with an overpressure event.²At step 408 once an event is determined, one or more mitigation steps are or a ²response is ²determined to mitigate the event. For example, one or more parameters related ²to rate of change ²and assessed energy (including kinetic energy) may be correlated to determine ²an energy balance ²with respect to time that may be used to determine a least disruptive response ²or mitigation step.²In one or more embodiments, one or more mitigation steps may require ²selectively altering one²or more operational states of one or more components, devices or equipment at ²the site, for ²example, sites 100 or 200 of Fig. 1 and Fig. 2, respectively. For example, the ²operational state of ²one or more pumping systems 106 at a site may be selectively altered based on ²the event and ²mitigation step. In one or more embodiments, one or more mitigation steps may ²require²13²<DP=14>²CA 03072992 2020-02-13²WO 2019 / 108177 ²PCT / US2017 / 063697²selectively altering a characteristic of the fluid in the system, for example, ²fluid 146 of Fig. 1, a ²speed of a motor or engine 108 be increased or decreased, an energy of the ²system be increased ²or decreased, activation or deactivation of one or more components, devices or ²equipment, any ²other mitigation step, a cost associated with each mitigation step or any ²combination thereof.²In one or more embodiments, altering or changing an operational state as part ²of a²mitigation step may require any one or more of increasing or decreasing the ²energy stored in the ²inertia of a rotor of a motor or engine, for example, energy stored in a rotor ²may be dissipated, ²for example, the energy stored in rotor 154 of motor or engine 108b of Fig. 1, ²reducing or ²increasing the inertia of a pump or altering the output capability (for ²example, fluid discharge²rate) of the pump, for example a pump 112 of Fig. 1, or both. In one or more ²embodiments,²altering or changing an operational state associated with a mitigation step ²may require any one or ²more of altering or changing a characteristic of a fluid, for example fluid ²146, by increasing or ²decreasing the pressure of the fluid, increasing or decreasing a volume of the ²fluid, for example, ²increasing or decreasing a flow rate of the fluid, diverting or altering a ²flow path of the fluid, or² both.²In one or more embodiments, altering or changing an operational state ²associated with a ²mitigation step may require any one or more of a power down sequence that ²stops, brakes, or ²ramps down the speed of a motor or engine 108, for example, an electric motor, ²gradually to ²prevent damage to the electric motor, other equipment or the surrounding ²environment.²However, during this power down sequence (which generally is not an ²instantaneous or²substantially instantaneous power stoppage of the motor 108) the pump 112 may ²continue ²pumping due to kinetic energy in the motor or engine 108. One or more control ²valves, for ²example, one or more control valves 144 may be activated to prevent or ²throttle the pressurized ²fluid 146 from being pumped by pump 112 to the wellhead 114 during such a ²power down²sequence of the motor or engine 108.²In one or more embodiments, an altering or changing operational state ²associated with a ²mitigation step may require that the master control system 102 initiate a ²pumping sequence to ²prevent or throttle the flow of pressurized fluid 146 from the pumping system ²106 based, at least ²in part, an information from any one or more of one or more pumping systems ²106, one or more²sensors 126, 128, 130, 132, 134, 136, 138, 140 and 142. For example, in one or ²more²embodiments, the master control system 102 may initiate a pumping sequence ²based, at least in ²part, on any one or more of a detection of a power down sequence of the motor ²or engine 108 ²(for example, information from sensor 126 may be indicative of a power down ²sequence of the ²motor or engine 108), one or more operator inputs, information from sensor 126 ²(for example,²14²<DP=15>²CA 03072992 2020-02-13²WO 2019 / 108177 ²PCT / US2017 / 063697²information from sensor 126 may be indicative of an overpressure condition), a ²flag, alert, ²semaphore, program instruction or timed interval (for example, testing ²procedures may be ²scheduled), or any other indicator. In one or more embodiments, the master ²control system 102 ²may be coupled to pumping system 106 and may send a signal or command to the ²motor or² engine 108 to initiate a power down sequence.²In one or more embodiments, altering or changing an operational state ²associated with a ²mitigation step may require any one or more of opening or closing a pressure ²release valve, for ²example, relief valve 120, engaging or disengaging a transmission or driveline ²disconnect 110, ²disable the output of the pump, divert flow of a fluid 146, or any combination ²thereof. In one or²more embodiments, diverting flow of a fluid 146 may require opening relief ²valve 120 so that²fluid 146 flows to a low pressure reservoir 124, reducing rate of pumping from ²one or more ²pumping systems 106, introducing an additional one or more pumping systems ²106, for example, ²activating or initiating an additional pumping system 106, or any combination ²thereof.²At step 410, the event, triggering event or condition is mitigated by ²implementing or²initiating one or more mitigation steps. As each of the one or more mitigation ²steps are²implemented, the master control system or any one or more control systems, ²such as master ²control system 102 and control system 104 of Fig. 1 and Fig. 2, continuously ²implement any one ²or more of steps 402-406 such that at any point in time the one or more ²mitigation steps currently ²being implemented are changed, altered or adjusted based on up to date or real-²time information.²For example, any one or more sensors or devices, components or equipment may ²provide²information or feedback to the one or more control systems 104 and the master ²control system ²102 on a real-time, automatic, or both bases such that any one or more ²mitigation steps are based ²on up to date or current operational status at the site.²At step 412, any one or more operational states of the pumping system 106 or ²any one or²more other components, devices or equipment at the site may be resumed. For ²example, once an²event, triggering event or condition, such as an overpressure event, has been ²mitigated, the ²master control system 102, one or more control system 104 or both may send a ²signal to a ²selected pumping system 106 for the pumping system 106 to resume the ²operational state of the ²pumping 106 that existed prior to the overpressure event or the initiation of ²the mitigation step.²In certain embodiments, the master control system 102, the control system 104 ²or both²may comprise an information handling system with at least a processor and a ²memory device ²coupled to the processor that contains a set of instructions that when ²executed cause the ²processor to perform certain actions. In any embodiment, the information ²handling system may ²include a non-transitory computer readable medium that stores one or more ²instructions where²<DP=16>²CA 03072992 2020-02-13²WO 2019 / 108177 ²PCT / US2017 / 063697²the one or more instructions when executed cause the processor to perform ²certain actions. As ²used herein, an information handling system may include any instrumentality or ²aggregate of ²instrumentalities operable to compute, classify, process, transmit, receive, ²retrieve, originate, ²switch, store, display, manifest, detect, record, reproduce, handle, or ²utilize any form of²information, intelligence, or data for business, scientific, control, or other ²purposes. For²example, an information handling system may be a computer terminal, a network ²storage device, ²or any other suitable device and may vary in size, shape, performance, ²functionality, and price. ²The information handling system may include random access memory (RAM), one or ²more ²processing resources such as a central processing unit (CPU) or hardware or ²software control²logic, read only memory (ROM), and / or other types of nonvolatile memory. ²Additional²components of the information handling system may include one or more disk ²drives, one or ²more network ports for communication with external devices as well as various ²input and ²output (I / 0) devices, such as a keyboard, a mouse, and a video display. The ²information ²handling system may also include one or more buses operable to transmit ²communications² between the various hardware components.²Fig. 5 is a diagram illustrating an example information handling system 500, ²according to ²aspects of the present disclosure. The master control system 102, control ²system 104 or both ²may take a form similar to the information handling system 500. A processor or ²central ²processing unit (CPU) 501 of the information handling system 500 is ²communicatively coupled²to a memory controller hub or north bridge 502. The processor 501 may include, ²for example a²microprocessor, microcontroller, digital signal processor (DSP), application ²specific integrated ²circuit (ASIC), or any other digital or analog circuitry configured to ²interpret and / or execute ²program instructions and / or process data. Processor 501 may be configured to ²interpret and / or ²execute program instructions or other data retrieved and stored in any memory ²such as memory²403 or hard drive 407. Program instructions or other data may constitute ²portions of a software²or application for carrying out one or more methods described herein. Memory ²403 may include ²read-only memory (ROM), random access memory (RAM), solid state memory, or ²disk-based ²memory. Each memory module may include any system, device or apparatus ²configured to ²retain program instructions and / or data for a period of time (for example, ²computer-readable²non-transitory media). For example, instructions from a software program or an ²application may²be retrieved and stored in memory 403 for execution by processor 501.²Modifications, additions, or omissions may be made to Fig. 5 without departing ²from the ²scope of the present disclosure. For example, Fig. 5 shows a particular ²configuration of²components of information handling system 500. However, any suitable ²configurations of²16²<DP=17>²CA 03072992 2020-02-13²WO 2019 / 108177 ²PCT / US2017 / 063697²components may be used. For example, components of information handling system ²500 may be ²implemented either as physical or logical components. Furthermore, in some ²embodiments, ²functionality associated with components of information handling system 500 ²may be ²implemented in special purpose circuits or components. In other embodiments, ²functionality².. associated with components of information handling system 500 may be ²implemented in²configurable general purpose circuit or components. For example, components of ²information ²handling system 500 may be implemented by configured computer program ²instructions.²Memory controller hub (MCH) 502 may include a memory controller for directing²information to or from various system memory components within the information ²handling²system 500, such as memory 503, storage element 506, and hard drive 507. The ²memory²controller hub 502 may be coupled to memory 503 and a graphics processing unit ²504. Memory ²controller hub 502 may also be coupled to an I / 0 controller hub (ICH) or south ²bridge 505. I / 0 ²hub 505 is coupled to storage elements of the information handling system 500, ²including a ²storage element 506, which may comprise a flash ROM that includes a basic ²input / output system²(BIOS) of the computer system. I / 0 hub 505 is also coupled to the hard drive ²507 of the²information handling system 500. I / 0 hub 505 may also be coupled to a Super ²I / 0 chip 508, ²which is itself coupled to several of the I / 0 ports of the information ²handling system, including ²keyboard 509 and mouse 510. In one or more embodiments, one or more databases ²512 may be ²accessible by or included within information handling system 500. Hard drive ²507 may²comprise a database 512a. Super I / 0 chip 508 may be communicatively coupled to ²a database²512n either directly or indirectly, wired or wireles sly. In one or more ²embodiments, database 512 ²may be internal (for example, as part of hard drive 507), external or both to ²information handling ²system 500.²In one or more embodiments an automated pressure control system comprises a ²plurality²of pumping systems, wherein the plurality of pumping systems pump a fluid to a ²wellhead and a²control system coupled to the plurality of pumping systems, wherein the ²control system ²comprises a processor and a non-transitory memory, wherein the non-transitory ²memory stores ²one or more instructions that when executed by the processor, cause the ²processor to determine ²that a triggering event has occurred based, at least in part, on the one or ²more operational²parameters, determine the mitigation step based, at least in part, on the one ²or more operational²parameters, and initiate the mitigation step, wherein initiating the ²mitigation step comprises ²identifying at least one pumping system of the plurality pumping systems ²based, at least in part, ²on the one or more operational parameters and selectively altering an ²operational state of the at ²least one pumping system. In one or more embodiments, the automated pressure ²control system²17²<DP=18>²CA 03072992 2020-02-13²WO 2019 / 108177 ²PCT / US2017 / 063697²further comprises initiating the mitigation step further comprises that ²initiating the mitigation ²step further comprises resuming operation of the at least one pumping system. ²In one or more ²embodiments, the automated pressure control system further comprises that the ²one or more ²operational parameters are received at a control system coupled to the ²plurality of pumping²systems, wherein the control system controls operation of the plurality of ²pumping systems. In²one or more embodiments, the one or more instructions that when executed by ²the processor, ²further cause the processor to receive at a master control system the one or ²more operational ²parameters from the control system, assess a total energy associated with the ²well environment ²and communicate the mitigation step to the control system. In one or more ²embodiments, the²automated pressure control system further comprises that initiating the ²mitigation step further²comprises resuming operation of the at least one pumping system. In one or ²more embodiments, ²the automated pressure control system further comprises that the one or more ²operational ²parameters are received at a control system coupled to the plurality of ²pumping systems, wherein ²the control system controls operation of the plurality of pumping systems. In ²one or more²embodiments, the automated pressure control system further comprises that ²selectively altering²the operational state of the at least one pumping system comprises at least ²one of altering an ²inertia of the at least one pumping system, altering a pressure of the fluid, ²altering a flow rate of ²the fluid, and altering a flow path of the fluid.²In one or more embodiments, a method for mitigating a triggering event for a ²well²environment comprises receiving one or more operational parameters associated ²with a plurality²of pumping systems at the well environment, wherein the plurality of pumping ²systems pump a ²fluid to a wellhead, determining that the triggering event has occurred based, ²at least in part, on ²the one or more operational parameters, determining the mitigation step based, ²at least in part, on ²the one or more operational parameters and initiating the mitigation step, ²wherein initiating the²mitigation step comprises identifying at least one pumping system of the ²plurality pumping²systems based, at least in part, on the one or more operational parameters and ²selectively altering ²an operational state of the at least one pumping system. In one or more ²embodiments, the ²method further comprises that initiating the mitigation step further comprises ²resuming operation ²of the at least one pumping system. In one or more embodiments, the method ²further comprises²that the one or more operational parameters are received at a control system ²coupled to the²plurality of pumping systems, wherein the control system controls operation of ²the plurality of ²pumping systems. In one or more embodiments, the method further comprises ²receiving at a ²master control system the one or more operational parameters from the control ²system, assessing ²a total energy associated with the well environment and communicating the ²mitigation step to the²18²<DP=19>²CA 03072992 2020-02-13²WO 2019 / 108177 ²PCT / US2017 / 063697²control system. In one or more embodiments, the method further comprises that ²the one or more ²operational parameters comprise at least one of pump pressure, discharge rate ²and valve ²operation associated with the plurality of pumping systems. In one or more ²embodiments, the ²method further comprises that at least one of the one or more operational ²parameters is²associated with at least one of a transmission, a relief valve and a wellhead. ²In one or more²embodiments, the method further comprises that selectively altering the ²operational state of the ²at least one pumping system comprises at least one of altering an inertia of ²the at least one ²pumping system, altering a pressure of the fluid, altering a flow rate of the ²fluid, and altering a ²flow path of the fluid.²In one or more embodiments, a non-transitory computer readable medium storing ²one or²more instructions that, when executed by a processor, cause the processor to ²receive one or more ²operational parameters associated with a plurality of pumping systems at a ²well environment, ²wherein the plurality of pumping systems pump a fluid to a wellhead, determine ²that a triggering ²event has occurred based, at least in part, on the one or more operational ²parameters, determine²the mitigation step based, at least in part, on the one or more operational ²parameters and initiate²the mitigation step, wherein initiating the mitigation step comprises ²identifying at least one ²pumping system of the plurality pumping systems based, at least in part, on ²the one or more ²operational parameters and selectively alter an operational state of the at ²least one pumping ²system. In one or more embodiments of the non-transitory computer readable ²medium, the²initiating the mitigation step further comprises resuming operation of the at ²least one pumping²system. In one or more embodiments of the non-transitory computer readable ²medium, the one ²or more operational parameters are received at a control system coupled to the ²plurality of ²pumping systems, wherein the control system controls operation of the ²plurality of pumping ²systems. In one or more embodiments, the one or more instructions, when ²executed, further²cause the processor to receive at a master control system the one or more ²operational parameters²from the control system, assess a total energy associated with the well ²environment; and ²communicate the mitigation step to the control system. In one or more ²embodiments of the non-²transitory computer readable medium, the initiating the mitigation step ²further comprises ²resuming operation of the at least one pumping system. In one or more ²embodiments of the non-²transitory computer readable medium, the selectively altering the operational ²state of the at least²one pumping system comprises at least one of altering an inertia of the at ²least one pumping ²system, altering a pressure of the fluid, altering a flow rate of the fluid, ²and altering a flow path ²of the fluid.²The particular embodiments disclosed above are illustrative only, as the ²present²19²<DP=20>²CA 03072992 2020-02-13²WO 2019 / 108177 ²PCT / US2017 / 063697²disclosure may be modified and practiced in different but equivalent manners ²apparent to those ²skilled in the art having the benefit of the teachings herein. Furthermore, no ²limitations are ²intended to the details of construction or design herein shown, other than as ²described in the ²claims below. It is therefore evident that the particular illustrative ²embodiments disclosed above²may be altered or modified and all such variations are considered within the ²scope and spirit of ²the present disclosure. Also, the terms in the claims have their plain, ²ordinary meaning unless ²otherwise explicitly and clearly defined by the patentee.²

Claims

<DP=1>²What is claimed is:²1. A well pumping system, comprising:²a plurality of pumping systems, wherein the plurality of pumping systems pump ²a fluid to²a wellhead; and²a control system coupled to the plurality of pumping systems, wherein the ²control system²comprises:²a processor; and²a non-tansitory memory, wherein the non-transitory memory stores one or more²instructions that when executed by the processor, cause the processor to:²receive one or more operational parameters associated with the plurality of²pumping systems at the well environment;²determine that a triggering event has occurred based, at least in part, on the ²one or²more operational parameters; and²initiate a mitigation step in response to the triggering event, wherein ²initiating the²mitigation step comprises:²(a) altering an operational state of a selected one or more of the plurality ²of pumping systems to decrease an energy of the selected one or more of the ²plurality of pumping systems, comprising:²engaging a transmission disconnect between a motor and a pump ²of the selected one or more of the plurality of pumping systems and ²opening a pressure relief valve; or²(b) altering an operational state of a selected one or more of the plurality ²of pumping systems without decreasing the energy of the selected one or more ²of ²the plurality of pumping systems, comprising:²initiating a power down sequence to the motor of the selected one ²or more of the plurality of pumping systems and opening a pressure relief ²valve.²21²Date Recue / Date Received 2024-03-11²<DP=2>²2. The system of claim 1, wherein the one or more instructions that when ²executed by the ²processor, further cause the processor to resume operation of the selected one ²or more of the ²plurality of pumping systems.²3. The system of claim 1 or 2, wherein the control system controls ²operation of the plurality ²of pumping systems.²4. The system of any one of claims 1 to 3, wherein altering the operational ²state of the ²selected one or more of the plurality of pumping systems to decrease an energy ²of the selected ²one or more of the plurality of pumping systems further comprises altering a ²pressure of the ²fluid, or altering a flow path of the fluid.²5. The system of claim 1, wherein the one or more operational parameters ²comprise at least ²one of pump pressure, discharge rate and valve operation associated with the ²plurality of ²pumping systems.²6. The system of claim 1, wherein at least one of the one or more ²operational parameters is ²associated with at least one of a transmission, the pressure relief valve and ²the wellhead.²7. The system of claim 1, wherein the triggering event comprises an ²overpressure event.²8. The system of claim 1, wherein the energy of the pumping system ²comprises the energy ²stored in inertia of a rotor of the motor of the selected one or more of the ²plurality of pumping ²systems.²9. A method for mitigating a triggering event for a well environment, ²comprising:²receiving one or more operational parameters associated with a plurality of ²pumping ²systems at the well environment, wherein the plurality of pumping systems pump ²a fluid to a ²wellhead;²determining that the triggering event has occurred based, at least in part, on ²the one or more ²operational parameters; and²22²Date Recue / Date Received 2024-03-11²<DP=3>²initiating a mitigation step in response to the triggering event, wherein ²initiating the ²mitigation step comprises:²(a) altering an operational state of a selected one or more of the plurality ²of ²pumping systems to decrease an energy of the selected one or more of the ²plurality of ²pumping systems, comprising:²engaging a transmission disconnect between a motor and a pump of the ²selected one or more of the plurality of pumping systems and opening a ²pressure ²relief valve; or²(b) altering an operational state of a selected one or more of the plurality ²of²pumping systems without decreasing the energy of the selected one or more of ²the ²plurality of pumping systems, comprising:²initiating a power down sequence to the motor of the selected one or more ²of the plurality of pumping systems and opening a pressure relief valve.²10. The method as claimed in claim 9, wherein initiating the mitigation ²step further ²comprises resuming operation of the selected one or more of the plurality of ²pumping systems.²11. The method as claimed in claim 9 or 10, wherein a control system ²controls operation of ²the plurality of pumping systems.²12. The method as claimed in any one of claims 9 to 11, wherein the one or ²more operational ²parameters comprise at least one of pump pressure, discharge rate and valve ²operation associated ²with the plurality of pumping systems.²13. The method as claimed in any one of claims 9 to 12, wherein at least ²one of the one or ²more operational parameters is associated with at least one of a transmission, ²the pressure relief ²valve and the wellhead.²14. The method as claimed in any one of claims 9 to 13, wherein altering ²the operational ²state of the selected one or more of the plurality of pumping systems to ²decrease an energy of the²23²Date Recue / Date Received 2024-03-11²<DP=4>²selected one or more of the plurality of pumping systems further comprises ²altering a pressure of ²the fluid or altering a flow path of the fluid.²15. The method of claim 9, wherein the triggering event comprises an ²overpressure event.²16. The method of claim 9, wherein the energy of the pumping system ²comprises the energy ²stored in inertia of a rotor of the motor of the selected one or more of the ²plurality of pumping ²systems.²17. A non-transitory computer readable medium storing one or more ²instructions that, when ²executed by a processor, cause the processor to:²receive one or more operational parameters associated with a plurality of ²pumping ²systems at a well environment, wherein the plurality of pumping systems pump a ²fluid to a ²wellhead;²determine that a triggering event has occurred based, at least in part, on the ²one or more ²operational parameters; and²initiate a mitigation step in response to the triggering event, wherein ²initiating the ²mitigation step comprises:²opening a pressure relief valve or diverting flow of the fluid; and²(a) altering an operational state of a selected one or more of the plurality ²of ²pumping systems by decreasing an energy of the selected one or more of the ²plurality of ²pumping systems, comprising:²engaging a transmission disconnect between a motor and a pump of the ²selected one or more of the plurality of pumping systems; or²(b) altering an operational state of a selected one or more of the plurality ²of²pumping systems without decreasing the energy of the selected one or more of ²the ²plurality of pumping systems, comprising:²initiating a power down sequence to the motor of the selected one or more ²of the plurality of pumping systems.²24²Date Recue / Date Received 2024-03-11²<DP=5>²18. The non-transitory computer readable medium of claim 17, wherein the ²one or more ²instructions that when executed by the processor, further cause the processor ²to resume operation ²of the selected one or more of the plurality of pumping systems.²19. The non-transitory computer readable medium of claim 17, wherein the ²one or more ²instructions cause the processor to receive the one or more operational ²parameters at a control ²system coupled to the plurality of pumping systems, wherein the control system ²controls operation ²of the plurality of pumping systems.²20. The non-transitory computer readable medium of claim 17, wherein ²selectively altering ²the operational state of the selected one or more of the plurality of pumping ²systems to decrease ²an energy of the selected one or more of the plurality of pumping systems ²further comprises ²altering a pressure of the fluid, altering a flow rate of the fluid, altering ²a flow path of the fluid, ²or combinations thereof.²21. The non-tansitory computer readable medium of claim 17, wherein the one ²or more ²operational parameters comprise at least one of pump pressure, discharge rate ²and valve ²operation associated with the plurality of pumping systems.²22. The non-transitory computer readable medium of claim 17, wherein at ²least one of the ²one or more operational parameters is associated with at least one of a ²transmission, the pressure ²relief valve and the wellhead.²23. The non-transitory computer readable medium of claim 17, wherein the ²energy of the ²pumping system comprises the energy stored in inertia of a rotor of the motor ²of the selected one ²or more of the plurality of pumping systems.² Date Recue / Date Received 2024-03-11²