US20200049153A1 - Systems and methods of optimized pump speed control to reduce cavitation, pulsation and load fluctuation - Google Patents
Systems and methods of optimized pump speed control to reduce cavitation, pulsation and load fluctuation Download PDFInfo
- Publication number
- US20200049153A1 US20200049153A1 US16/314,032 US201616314032A US2020049153A1 US 20200049153 A1 US20200049153 A1 US 20200049153A1 US 201616314032 A US201616314032 A US 201616314032A US 2020049153 A1 US2020049153 A1 US 2020049153A1
- Authority
- US
- United States
- Prior art keywords
- primary mover
- characteristic
- pump
- pumping apparatus
- sensor
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Pending
Links
- 238000000034 method Methods 0.000 title claims description 20
- 230000010349 pulsation Effects 0.000 title description 4
- 238000005086 pumping Methods 0.000 claims abstract description 63
- 239000012530 fluid Substances 0.000 claims abstract description 61
- 230000001133 acceleration Effects 0.000 claims description 11
- 238000006073 displacement reaction Methods 0.000 claims description 10
- 238000002485 combustion reaction Methods 0.000 claims description 6
- 238000012544 monitoring process Methods 0.000 claims description 3
- MROJXXOCABQVEF-UHFFFAOYSA-N Actarit Chemical compound CC(=O)NC1=CC=C(CC(O)=O)C=C1 MROJXXOCABQVEF-UHFFFAOYSA-N 0.000 description 47
- 230000015572 biosynthetic process Effects 0.000 description 8
- 238000005755 formation reaction Methods 0.000 description 8
- 230000008901 benefit Effects 0.000 description 7
- 230000006870 function Effects 0.000 description 6
- 238000011282 treatment Methods 0.000 description 6
- 238000011144 upstream manufacturing Methods 0.000 description 6
- 238000011161 development Methods 0.000 description 3
- 230000007246 mechanism Effects 0.000 description 3
- 230000000638 stimulation Effects 0.000 description 3
- 238000005553 drilling Methods 0.000 description 2
- 229930195733 hydrocarbon Natural products 0.000 description 2
- 150000002430 hydrocarbons Chemical class 0.000 description 2
- 230000000737 periodic effect Effects 0.000 description 2
- 230000004075 alteration Effects 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- 230000006835 compression Effects 0.000 description 1
- 238000007906 compression Methods 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 230000008878 coupling Effects 0.000 description 1
- 238000010168 coupling process Methods 0.000 description 1
- 238000005859 coupling reaction Methods 0.000 description 1
- 125000004122 cyclic group Chemical group 0.000 description 1
- 238000013461 design Methods 0.000 description 1
- 230000006866 deterioration Effects 0.000 description 1
- 230000003628 erosive effect Effects 0.000 description 1
- 239000000446 fuel Substances 0.000 description 1
- ZZUFCTLCJUWOSV-UHFFFAOYSA-N furosemide Chemical compound C1=C(Cl)C(S(=O)(=O)N)=CC(C(O)=O)=C1NCC1=CC=CO1 ZZUFCTLCJUWOSV-UHFFFAOYSA-N 0.000 description 1
- 230000003116 impacting effect Effects 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- -1 oil and gas Chemical class 0.000 description 1
- 238000005457 optimization Methods 0.000 description 1
- 230000008569 process Effects 0.000 description 1
- 230000009467 reduction Effects 0.000 description 1
- 239000002002 slurry Substances 0.000 description 1
Images
Classifications
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
- F04D—NON-POSITIVE-DISPLACEMENT PUMPS
- F04D15/00—Control, e.g. regulation, of pumps, pumping installations or systems
- F04D15/0066—Control, e.g. regulation, of pumps, pumping installations or systems by changing the speed, e.g. of the driving engine
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/06—Measuring temperature or pressure
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
- F04D—NON-POSITIVE-DISPLACEMENT PUMPS
- F04D29/00—Details, component parts, or accessories
- F04D29/66—Combating cavitation, whirls, noise, vibration or the like; Balancing
- F04D29/669—Combating cavitation, whirls, noise, vibration or the like; Balancing especially adapted for liquid pumps
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK 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
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK 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
Definitions
- the present disclosure generally relates to subterranean drilling operations, more particularly, to systems and methods of controlling pump speed to reduce cavitation and load fluctuation in the pumped fluids.
- Hydrocarbons such as oil and gas
- subterranean formations that may be located onshore or offshore.
- the development of subterranean operations and the processes involved in removing hydrocarbons from a subterranean formation are complex.
- subterranean operations involve a number of different steps such as, for example, mixing and pumping fluids into a wellbore at a desired well site.
- Cavitation, pulsation, and load fluctuation are common problems/faults encountered when pumping fluids.
- cavitation can cause accelerated wear and mechanical damage to pump components, couplings, gear trains, and drive motors.
- Cavitation and load fluctuation are often caused by the pulsation of the pumping apparatus.
- Cavitation is the formation of vapor bubbles in the inlet or the suction zone/stroke of the pump. This condition occurs when local pressure drops to below the vapor pressure of the liquid being pumped. These vapor bubbles collapse or implode when they enter a high pressure zone (for example, at the discharge valve during the discharge/power stroke) of the pump causing erosion of or damage to pump components or both.
- FIG. 1 is a schematic view of the pumping apparatus in accordance with certain embodiments of the present disclosure.
- FIG. 2 is a schematic view of an exemplary fracturing apparatus in accordance with certain embodiments of the present disclosure.
- the present disclosure relates to systems and methods for pumping fluids, more particularly, to systems and method of controlling pump speed to reduce cavitation and load fluctuation in the pumped fluids.
- Cavitation is often caused by the improperly configured rig-up jobs.
- a rig-up job may be considered improperly configured for any number of reasons.
- a rig-up job is improperly configured when the hoses that connect the blender to the pumps and the hoses that lead downhole from the pumps vary in length, number, or diameter.
- Cavitation caused by an improperly configured rig-up job is exacerbated by high pump speeds, which are often associated with well stimulation treatments and other downhole operations.
- Well stimulation treatments such as fracturing or acidizing treatments, require high pump speeds in order to generate the requisite pressure to fracture or stimulate a subterranean formation.
- the pumping of slurries in other subterranean operations requires relatively high pump speeds to ensure the particulates remain suspended.
- Cavitation can be reduced by fluctuating the speed of the pump in a periodic manner such that the pump speed effectively prevents vapor bubbles in the pump's inlet from forming.
- a reduction in cavitation may be achieved by varying the speed of the engine or motor that actuates the pump.
- the engine or motor may be a diesel or other combustion engine, an electric motor, or any combination thereof.
- an electric motor is used as more control over the variations in speed may be achieved.
- the engine or motor may be controlled by a controller, such as, an information handling system.
- FIG. 1 is a schematic view of the pumping apparatus 100 in accordance with certain embodiments of the present disclosure.
- Pumping apparatus 100 may be located at a well surface, at a well site along with various types of drilling or fracturing equipment (not expressly shown) or at any other location where an operation requires a pumping apparatus 100 .
- the pumping apparatus 100 comprises a pump 10 coupled to a primary mover 14 by a drive train 12 .
- the pump 10 comprises a positive displacement pump.
- the primary mover 14 comprises a drive mechanism 40 .
- Drive mechanism 40 may comprise an internal combustion engine.
- the internal combustion engine may comprise a diesel engine.
- the drive mechanism 40 may comprise an electric motor.
- the movement of the primary mover 14 actuates the movement of the pump 10 .
- the primary mover 14 is coupled directly to the pump 10 and actuates pumping of pump 10 directly.
- the primary mover 14 is coupled to the drive train 12 and actuates the pumping of pump 10 by actuating the movement of the drive train 12 .
- the speed of the primary mover 14 determines the pumping speed of the pump 10 .
- the speed at which the primary mover 14 operates may determine the rotational speed of pump 10 .
- the primary mover 14 may be controlled to change the rotational speed of the pump 10 in any manner known in the art.
- the pump 10 operates so as to pump fluid from an upstream portion of a fluid channel 28 to a downstream portion of a fluid channel 18 .
- the fluid channels 18 and 28 may comprise hosing, piping, any kind of hosing or piping known in the art or any combination thereof.
- fluid channel 18 is downstream of a blender (not shown).
- fluid channel 18 leads directly into the wellbore 60 as described in FIG. 2 .
- fluid channel 18 couples to a manifold (not shown).
- the pumping apparatus 100 further comprises a controller 16 .
- the controller 16 is electronically coupled to the primary mover 14 .
- the controller 16 may comprise a processor 30 and a memory 32 where the memory 32 comprises one or more instructions, such as a program, that when executed by the processor 30 control the primary mover 14 .
- the primary mover 14 may comprise a memory 34 and a receiver 36 such that the primary mover 14 may receive the one or more commands sent by the controller 16 .
- the controller 16 may throttle the speed at which the primary mover 14 operates. Throttling the speed of the primary mover 14 may cause the speed of the primary mover 14 and thus the pump 10 the primary mover 14 actuates to cyclically decrease and increase continuously.
- the controller 16 may be programmed to optimize one or more characteristics of the pumping apparatus 100 . For example, for a given operation or environment, one or more characteristics of the pumping apparatus 100 may be selected for optimization. In one or more embodiments, the controller 16 may calculate the speed at which the primary mover 14 operates such that the selected characteristic is optimized.
- Characteristics of the pumping apparatus 100 may include, but are not limited to, vibration of a component of the primary mover 14 , torque or force of at least one component of the primary mover 14 , linear or angular displacement of at least one component of the primary mover 14 , linear or angular velocity of at least one component of the primary mover 14 , linear or angular acceleration of at least one component of the primary mover 14 , fuel or electrical power efficiency of the primary mover 14 , emissions produced by the primary mover 14 , vibration of the drivetrain 12 , torque of the drive train 12 , angular velocity of the drivetrain 12 , angular acceleration of the drive train 12 , flow rate of the pump 10 , inlet pressure of the pump 10 , outlet pressure of the pump 10 , vibration of the pump 10 , force of the pump 10 , torque of the pump 10 , in linear or angular displacement of the pump 10 , linear or angular velocity of the pump 10 , linear or angular acceleration of the pump 10 , or any other characteristic.
- the calculated speed is based, at least in part, on one or more characteristics of the pumping apparatus 100 .
- the pump 10 may accelerate fluid according to a well-known function or functions such as slider-crank motion equations, fluid compression and bulk modulus relations, valve force-mass acceleration equations.
- the controller 16 may be programmed to control the primary mover 14 based on the well-known function to optimize the flow rate of the fluid through the pump 10 . In one or more embodiments, this calculation is based, at least in part, on the signals from one or more sensors discussed in greater detail below.
- the pumping apparatus 100 may further comprise one or more sensors 26 . Any of the one or more sensors 26 may be coupled to the controller 16 . In one or more embodiments, one or more sensors 26 may be disposed within or coupled to the primary mover 14 . The sensor 26 is coupled to the primary mover 14 such that the sensor 26 may monitor at least one characteristic of the primary mover 14 .
- the sensor 26 may monitor at least one of the vibration of a component of the primary mover 14 , the torque or force of at least one component of the primary mover 14 , the linear displacement of at least one component of the primary mover 14 , the linear or angular velocity of at least one component of the primary mover 14 , the linear or angular acceleration of at least one component of the primary mover 14 , or any combination thereof.
- sensor 26 may comprise a pressure sensor, a strain gauge, an accelerometer, a position sensor, a velocity sensor, an acoustic sensor, or any combination thereof.
- the senor 26 may further communicate or transmit the information about the monitored characteristic to the controller 16 at regular intervals, timed intervals, intermittent intervals, predetermined intervals or at any other interval. In some embodiments, the information is communicated continuously.
- the controller 16 may modify the control signal sent to the primary mover 14 based, at least in part, on the information received from sensor 26 , such that the primary mover 14 operates to optimize any one or more characteristics of the pumping apparatus 100 . In one or more embodiments, the sensor 26 monitors any one or more characteristics being optimized by the controller 16 .
- the pumping apparatus 100 may comprise a sensor 22 wherein the sensor 22 is coupled to the controller 16 and the drive train 12 .
- the sensor 22 is coupled to the drive train 12 to monitor at least one characteristic of the drive train 12 .
- the sensor 22 may monitor at least one of the vibration of a component of the drive train 12 , the torque or force of at least one component of the drive train 12 , the linear displacement of at least one component of the drive train 12 , the linear or angular velocity of at least one component of a drive train 12 , the linear or angular acceleration of at least one component of the drive train 12 , or any combination thereof.
- sensor 22 may comprise a pressure sensor, a strain gauge, an accelerometer, a position sensor, a velocity sensor, an acoustic sensor, or any combination thereof.
- the sensor 22 may further communicate the information about the characteristic to the controller 16 at regular intervals, timed intervals, intermittent intervals, predetermined intervals or at any other interval. In one or more embodiments, the information is communicated continuously.
- the controller 16 may modify the control signal the control 16 sends to the primary mover 14 based on the information received from sensor 22 , such that the primary mover 14 operates to optimize a characteristic of the pumping apparatus 100 .
- the characteristic sensor 22 monitors the same characteristic or a different characteristic being optimized by the controller 16 .
- the pumping apparatus 100 may comprise a sensor 24 wherein the sensor 24 is coupled to the controller 16 and the pump 10 .
- the sensor 24 is coupled to the pump 10 such that it may monitor at least one characteristic of the pump 10 .
- the sensor 24 may monitor at least one of the vibration of a component of the pump 10 , the torque or force of at least one component of the pump 10 , the linear displacement of at least one component of the pump 10 , the linear or angular velocity of at least one component of a pump 10 , the linear or angular acceleration of at least one component of the pump 10 , fluid flow, pressure, or any combination thereof.
- sensor 24 may comprise a strain gauge, an accelerometer, a pressure sensor, a position sensor, a velocity sensor, an acoustic sensor, a flow meter, or any combination thereof.
- the sensor 24 may further communicate the information about the characteristic to the controller 16 at regular intervals, timed intervals, intermittent intervals, predetermined intervals or at any other interval. In one or more embodiments, the information is communicated continuously.
- the controller 16 may modify the control signal the controller 16 sends to the primary mover 14 based on the information received from sensor 24 , such that the primary mover 14 operates to optimize a characteristic of the pumping apparatus 100 .
- the characteristic sensor 24 monitors the same characteristic optimized or a different characteristic being by the controller 16 .
- the downstream portion of a fluid 18 may comprise a sensor 20 , wherein the sensor 20 is coupled to the controller 16 .
- the sensor 20 monitors at least one characteristic of the downstream portion of the fluid channel 18 .
- One or more characteristics monitored by sensor 20 may comprise at least one of the vibration of the downstream portion of a fluid channel, fluid flow, pressure, or any combination thereof.
- sensor 20 may comprise an accelerometer, a flow meter, a pressure sensor, or any combination thereof.
- the sensor 20 may further communicate the information about the characteristic to the controller 16 at regular intervals, timed intervals, intermittent intervals, predetermined intervals or at any other interval. In one or more embodiments, the information is communicated continuously.
- the controller 16 may modify the control signal the controller 16 sends to the primary mover 14 based on the information received from sensor 20 , such that the primary mover 14 operates to optimize a characteristic of the pumping apparatus 100 .
- the characteristic sensor 20 monitors the same characteristic optimized by the controller 16 .
- sensor 20 may monitor any one or more characteristics including, but not limited to, the vibration of the downstream portion of the fluid channel 18 , while the controller 16 commands the primary mover 14 to operate to optimize the flow rate of the fluid in fluid channel 18 .
- the sensor 20 may monitor the vibration of the downstream portion of the fluid channel 18 , while the controller 16 commands the primary mover 14 to operate to reduce the vibration of the pump 10 .
- the sensor 20 monitors a different characteristic than the characteristic being optimized by controller 16 .
- the upstream portion of a fluid channel 28 may comprise a sensor 21 , wherein the sensor 21 is coupled to the controller 16 .
- the sensor 21 monitors at least one characteristic of the upstream portion of the fluid channel 28 .
- One or more characteristics monitored by sensor 21 may comprise at least one of: the vibration of the upstream portion of a fluid channel, fluid flow, pressure, or any combination thereof.
- sensor 21 may comprise an accelerometer, a flow meter, a pressure sensor, or any combination thereof.
- the sensor 21 may further communicate the information about the monitored characteristic to the controller 16 at regular intervals, timed intervals, intermittent intervals, predetermined intervals or at any other interval. In one or more embodiments, the information is communicated continuously.
- the controller 16 may modify the control signal the controller 16 sends to the primary mover 14 based on the information received from sensor 21 , such that the primary mover 14 operates to optimize a characteristic of the pumping apparatus 100 .
- the characteristic sensor 21 monitors the same characteristic optimized by the controller 16 . For example, in certain embodiments, the characteristic sensor 21 may monitor the vibration of the upstream portion of the fluid channel 28 , while the controller 16 commands the primary mover 14 to operate to optimize the flow rate of the fluid in fluid channel 28 .
- the senor 21 may monitor the vibration of the upstream portion of the fluid channel 28 , while the controller 16 commands the primary mover 14 to operate to reduce the vibration of the pump 10 . In some embodiments, the sensor 21 monitors a different characteristic than the characteristic being optimized by controller 16 .
- FIG. 2 shows the well 60 during an exemplary fracturing operation using the pumping apparatus 100 in a portion of a subterranean formation of interest 102 surrounding a well bore 104 .
- the apparatus of FIG. 2 may be used in a variety of different well stimulation treatments such as acidizing treatments.
- the well bore 104 extends from the surface 106 , and the fracturing fluid 108 is applied to a portion of the subterranean formation 102 surrounding the horizontal portion of the well bore.
- the well bore 104 may include horizontal, vertical, slant, curved, and other types of well bore geometries and orientations, and the fracturing treatment may be applied to a subterranean zone surrounding any portion of the well bore.
- the well bore 104 can include a casing 110 that is cemented or otherwise secured to the well bore wall.
- the well bore 104 can be uncased or include uncased sections.
- Perforations can be formed in the casing 110 to allow fracturing fluids and/or other materials to flow into the subterranean formation 102 . In cased wells, perforations can be formed using shape charges, a perforating gun, hydro jetting and/or other tools.
- the well is shown with a work string 112 depending from the surface 106 into the well bore 104 .
- the pump and blender system 50 is coupled a work string 112 to pump the fracturing fluid 108 into the well bore 104 .
- the working string 112 may include coiled tubing, jointed pipe, and/or other structures that allow fluid to flow into the well bore 104 .
- the working string 112 can include flow control devices, bypass valves, ports, and or other tools or well devices that control a flow of fluid from the interior of the working string 112 into the subterranean zone 102 .
- the working string 112 may include ports adjacent the well bore wall to communicate the fracturing fluid 108 directly into the subterranean formation 102 , and/or the working string 112 may include ports that are spaced apart from the well bore wall to communicate the fracturing fluid 108 into an annulus in the well bore between the working string 112 and the well bore wall.
- the working string 112 and/or the well bore 104 may include one or more sets of packers 114 that seal the annulus between the working string 112 and well bore 104 to define an interval of the well bore 104 into which the fracturing fluid 108 will be pumped.
- FIG. 2 shows two packers 114 , one defining an uphole boundary of the interval and one defining the downhole end of the interval.
- the fracturing fluid 108 is introduced into well bore 104 (for example, in FIG. 2 , the area of the well bore 104 between packers 114 ) at a sufficient hydraulic pressure, one or more fractures 116 may be created in the subterranean zone 102 .
- the proppant particulates in the fracturing fluid 108 may enter the fractures 116 where they may remain after the fracturing fluid flows out of the well bore. These proppant particulates may “prop” fractures 116 such that fluids may flow more freely through the fractures 116 .
- An embodiment of the present disclosure is a system for pumping fluid comprising a pump, a primary mover coupled to the pump, and a controller coupled to the primary mover, wherein the controller is programmed to control the primary mover so as to optimize a first characteristic of the system, wherein the controller commands the primary mover to throttle its speeds such that the primary mover's speed over time follows a cyclic or periodic function, for example, a sine function.
- Another embodiment of the present disclosure is a method for pumping a fluid comprising providing a pumping apparatus comprising a pump, a primary mover that actuates the pump, and a controller comprising a processor and a memory device programmed to send commands to the primary mover; and using known characteristics of the pump to modify the commands sent to the primary mover such that a characteristic of the pumping apparatus is optimized.
- Another embodiment of the present disclosure is a method for pumping a fluid comprising providing a pumping apparatus comprising a pump, a primary mover mechanically coupled to the pump by a drive train such that the primary mover actuates the pump, a controller that sends commands to the primary mover, and a sensor coupled to the controller; pumping the fluid downhole; monitoring a first characteristic of the pumping apparatus with the sensor, sending a signal to the controller indicative of the magnitude of the first characteristic being monitored by the sensor; determining an appropriate command signal to send to the primary mover to optimize a second characteristic of the pumping apparatus; and sending the appropriate command signal to the primary mover to optimize the second characteristic of the pumping apparatus.
Landscapes
- Engineering & Computer Science (AREA)
- Mechanical Engineering (AREA)
- General Engineering & Computer Science (AREA)
- Mining & Mineral Resources (AREA)
- Life Sciences & Earth Sciences (AREA)
- Geology (AREA)
- Physics & Mathematics (AREA)
- Geophysics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Control Of Positive-Displacement Pumps (AREA)
- Structures Of Non-Positive Displacement Pumps (AREA)
Abstract
Description
- The present disclosure generally relates to subterranean drilling operations, more particularly, to systems and methods of controlling pump speed to reduce cavitation and load fluctuation in the pumped fluids.
- Hydrocarbons, such as oil and gas, are commonly obtained from subterranean formations that may be located onshore or offshore. The development of subterranean operations and the processes involved in removing hydrocarbons from a subterranean formation are complex. Typically, subterranean operations involve a number of different steps such as, for example, mixing and pumping fluids into a wellbore at a desired well site.
- Cavitation, pulsation, and load fluctuation are common problems/faults encountered when pumping fluids. In particular, cavitation can cause accelerated wear and mechanical damage to pump components, couplings, gear trains, and drive motors. Cavitation and load fluctuation are often caused by the pulsation of the pumping apparatus. Cavitation is the formation of vapor bubbles in the inlet or the suction zone/stroke of the pump. This condition occurs when local pressure drops to below the vapor pressure of the liquid being pumped. These vapor bubbles collapse or implode when they enter a high pressure zone (for example, at the discharge valve during the discharge/power stroke) of the pump causing erosion of or damage to pump components or both. If a pump runs for an extended period under cavitation conditions, permanent damage may occur to the pump structure and accelerated wear and deterioration of pump internal surfaces and seals may occur. Depending on the type of pump, other problems may occur such as inlet or outlet blockage, leakage of air into the system due to faulty pump seals or valves, leaky or damaged valves, internal parts impacting the pump casing, etc. Consequently, a need exists for improved systems and methods for preventing cavitation, pulsation, and load fluctuation in pumps.
- For a more complete understanding of the present disclosure and its features and advantages, reference is now made to the following description, taken in conjunction with the accompanying drawing, in which:
-
FIG. 1 is a schematic view of the pumping apparatus in accordance with certain embodiments of the present disclosure. -
FIG. 2 . is a schematic view of an exemplary fracturing apparatus in accordance with certain embodiments of the present disclosure. - While embodiments of this disclosure have been depicted, such embodiments do not imply a limitation on the disclosure, and no such limitation should be inferred. The subject matter disclosed is capable of considerable modification, alteration, and equivalents in form and function, as will occur to those skilled in the pertinent art and having the benefit of this disclosure. The depicted and described embodiments of this disclosure are examples only, and not exhaustive of the scope of the disclosure.
- Illustrative embodiments of the present disclosure are described in detail herein. In the interest of clarity, not all features of an actual implementation are described in this specification. It will of course be appreciated that in the development of any such actual embodiment, numerous implementation specific decisions must be made to achieve developers' specific goals, such as compliance with system related and business related constraints, which will vary from one implementation to another. Moreover, it will be appreciated that such a development effort might be complex and time consuming, but would nevertheless be a routine undertaking for those of ordinary skill in the art having the benefit of the present disclosure. Furthermore, in no way should the following examples be read to limit, or define, the scope of the disclosure.
- The present disclosure relates to systems and methods for pumping fluids, more particularly, to systems and method of controlling pump speed to reduce cavitation and load fluctuation in the pumped fluids.
- Cavitation is often caused by the improperly configured rig-up jobs. A rig-up job may be considered improperly configured for any number of reasons. For example, a rig-up job is improperly configured when the hoses that connect the blender to the pumps and the hoses that lead downhole from the pumps vary in length, number, or diameter. Cavitation caused by an improperly configured rig-up job is exacerbated by high pump speeds, which are often associated with well stimulation treatments and other downhole operations. Well stimulation treatments, such as fracturing or acidizing treatments, require high pump speeds in order to generate the requisite pressure to fracture or stimulate a subterranean formation. Furthermore, the pumping of slurries in other subterranean operations requires relatively high pump speeds to ensure the particulates remain suspended.
- Cavitation can be reduced by fluctuating the speed of the pump in a periodic manner such that the pump speed effectively prevents vapor bubbles in the pump's inlet from forming. A reduction in cavitation may be achieved by varying the speed of the engine or motor that actuates the pump. In one or more embodiments, the engine or motor may be a diesel or other combustion engine, an electric motor, or any combination thereof. In one or more embodiments, an electric motor is used as more control over the variations in speed may be achieved. The engine or motor may be controlled by a controller, such as, an information handling system.
- The present disclosure may be understood with reference to
FIG. 1 , where like numbers are used to indicate like and corresponding parts.FIG. 1 is a schematic view of thepumping apparatus 100 in accordance with certain embodiments of the present disclosure.Pumping apparatus 100 may be located at a well surface, at a well site along with various types of drilling or fracturing equipment (not expressly shown) or at any other location where an operation requires apumping apparatus 100. - The
pumping apparatus 100 comprises apump 10 coupled to aprimary mover 14 by adrive train 12. In certain embodiments, thepump 10 comprises a positive displacement pump. In certain embodiments, theprimary mover 14 comprises adrive mechanism 40.Drive mechanism 40 may comprise an internal combustion engine. In certain embodiments, the internal combustion engine may comprise a diesel engine. In certain embodiments, thedrive mechanism 40 may comprise an electric motor. In certain embodiments the movement of theprimary mover 14 actuates the movement of thepump 10. In certain embodiments, theprimary mover 14 is coupled directly to thepump 10 and actuates pumping ofpump 10 directly. In certain embodiments, theprimary mover 14 is coupled to thedrive train 12 and actuates the pumping ofpump 10 by actuating the movement of thedrive train 12. In certain embodiments, the speed of theprimary mover 14 determines the pumping speed of thepump 10. A person of skill in the art with the benefit of this disclosure would see that the speed at which theprimary mover 14 operates may determine the rotational speed ofpump 10. Furthermore, a person of skill in the art with the benefit of this disclosure would appreciate that theprimary mover 14 may be controlled to change the rotational speed of thepump 10 in any manner known in the art. - The
pump 10 operates so as to pump fluid from an upstream portion of afluid channel 28 to a downstream portion of afluid channel 18. Thefluid channels fluid channel 18 is downstream of a blender (not shown). In one or more embodiments,fluid channel 18 leads directly into thewellbore 60 as described inFIG. 2 . In one or more embodiments,fluid channel 18 couples to a manifold (not shown). - The
pumping apparatus 100 further comprises acontroller 16. Thecontroller 16 is electronically coupled to theprimary mover 14. Thecontroller 16 may comprise aprocessor 30 and amemory 32 where thememory 32 comprises one or more instructions, such as a program, that when executed by theprocessor 30 control theprimary mover 14. In one or more embodiments, theprimary mover 14 may comprise a memory 34 and areceiver 36 such that theprimary mover 14 may receive the one or more commands sent by thecontroller 16. Thecontroller 16 may throttle the speed at which theprimary mover 14 operates. Throttling the speed of theprimary mover 14 may cause the speed of theprimary mover 14 and thus thepump 10 theprimary mover 14 actuates to cyclically decrease and increase continuously. - Additionally, the
controller 16 may be programmed to optimize one or more characteristics of thepumping apparatus 100. For example, for a given operation or environment, one or more characteristics of thepumping apparatus 100 may be selected for optimization. In one or more embodiments, thecontroller 16 may calculate the speed at which theprimary mover 14 operates such that the selected characteristic is optimized. Characteristics of thepumping apparatus 100 may include, but are not limited to, vibration of a component of theprimary mover 14, torque or force of at least one component of theprimary mover 14, linear or angular displacement of at least one component of theprimary mover 14, linear or angular velocity of at least one component of theprimary mover 14, linear or angular acceleration of at least one component of theprimary mover 14, fuel or electrical power efficiency of theprimary mover 14, emissions produced by theprimary mover 14, vibration of thedrivetrain 12, torque of thedrive train 12, angular velocity of thedrivetrain 12, angular acceleration of thedrive train 12, flow rate of thepump 10, inlet pressure of thepump 10, outlet pressure of thepump 10, vibration of thepump 10, force of thepump 10, torque of thepump 10, in linear or angular displacement of thepump 10, linear or angular velocity of thepump 10, linear or angular acceleration of thepump 10, or any other characteristic. In some embodiments, the calculated speed is based, at least in part, on one or more characteristics of thepumping apparatus 100. For example, in one or more embodiments, thepump 10 may accelerate fluid according to a well-known function or functions such as slider-crank motion equations, fluid compression and bulk modulus relations, valve force-mass acceleration equations. Thecontroller 16 may be programmed to control theprimary mover 14 based on the well-known function to optimize the flow rate of the fluid through thepump 10. In one or more embodiments, this calculation is based, at least in part, on the signals from one or more sensors discussed in greater detail below. - The
pumping apparatus 100 may further comprise one ormore sensors 26. Any of the one ormore sensors 26 may be coupled to thecontroller 16. In one or more embodiments, one ormore sensors 26 may be disposed within or coupled to theprimary mover 14. Thesensor 26 is coupled to theprimary mover 14 such that thesensor 26 may monitor at least one characteristic of theprimary mover 14. For example, in one or more embodiments thesensor 26 may monitor at least one of the vibration of a component of theprimary mover 14, the torque or force of at least one component of theprimary mover 14, the linear displacement of at least one component of theprimary mover 14, the linear or angular velocity of at least one component of theprimary mover 14, the linear or angular acceleration of at least one component of theprimary mover 14, or any combination thereof. In one or more embodiments,sensor 26 may comprise a pressure sensor, a strain gauge, an accelerometer, a position sensor, a velocity sensor, an acoustic sensor, or any combination thereof. - In one or more embodiments, the
sensor 26 may further communicate or transmit the information about the monitored characteristic to thecontroller 16 at regular intervals, timed intervals, intermittent intervals, predetermined intervals or at any other interval. In some embodiments, the information is communicated continuously. Thecontroller 16 may modify the control signal sent to theprimary mover 14 based, at least in part, on the information received fromsensor 26, such that theprimary mover 14 operates to optimize any one or more characteristics of thepumping apparatus 100. In one or more embodiments, thesensor 26 monitors any one or more characteristics being optimized by thecontroller 16. - In one or more embodiments, the
pumping apparatus 100 may comprise asensor 22 wherein thesensor 22 is coupled to thecontroller 16 and thedrive train 12. Thesensor 22 is coupled to thedrive train 12 to monitor at least one characteristic of thedrive train 12. For example, thesensor 22 may monitor at least one of the vibration of a component of thedrive train 12, the torque or force of at least one component of thedrive train 12, the linear displacement of at least one component of thedrive train 12, the linear or angular velocity of at least one component of adrive train 12, the linear or angular acceleration of at least one component of thedrive train 12, or any combination thereof. In one or more embodiments,sensor 22 may comprise a pressure sensor, a strain gauge, an accelerometer, a position sensor, a velocity sensor, an acoustic sensor, or any combination thereof. - In one or more embodiments, the
sensor 22 may further communicate the information about the characteristic to thecontroller 16 at regular intervals, timed intervals, intermittent intervals, predetermined intervals or at any other interval. In one or more embodiments, the information is communicated continuously. Thecontroller 16 may modify the control signal thecontrol 16 sends to theprimary mover 14 based on the information received fromsensor 22, such that theprimary mover 14 operates to optimize a characteristic of thepumping apparatus 100. In some embodiments, thecharacteristic sensor 22 monitors the same characteristic or a different characteristic being optimized by thecontroller 16. - In some embodiments, the
pumping apparatus 100 may comprise asensor 24 wherein thesensor 24 is coupled to thecontroller 16 and thepump 10. Thesensor 24 is coupled to thepump 10 such that it may monitor at least one characteristic of thepump 10. For example, thesensor 24 may monitor at least one of the vibration of a component of thepump 10, the torque or force of at least one component of thepump 10, the linear displacement of at least one component of thepump 10, the linear or angular velocity of at least one component of apump 10, the linear or angular acceleration of at least one component of thepump 10, fluid flow, pressure, or any combination thereof. In some embodiments,sensor 24 may comprise a strain gauge, an accelerometer, a pressure sensor, a position sensor, a velocity sensor, an acoustic sensor, a flow meter, or any combination thereof. - In one or more embodiments, the
sensor 24 may further communicate the information about the characteristic to thecontroller 16 at regular intervals, timed intervals, intermittent intervals, predetermined intervals or at any other interval. In one or more embodiments, the information is communicated continuously. Thecontroller 16 may modify the control signal thecontroller 16 sends to theprimary mover 14 based on the information received fromsensor 24, such that theprimary mover 14 operates to optimize a characteristic of thepumping apparatus 100. In one or more embodiments, thecharacteristic sensor 24 monitors the same characteristic optimized or a different characteristic being by thecontroller 16. - In one or more embodiments, the downstream portion of a fluid 18 may comprise a
sensor 20, wherein thesensor 20 is coupled to thecontroller 16. Thesensor 20 monitors at least one characteristic of the downstream portion of thefluid channel 18. One or more characteristics monitored bysensor 20 may comprise at least one of the vibration of the downstream portion of a fluid channel, fluid flow, pressure, or any combination thereof. In one or more embodiments,sensor 20 may comprise an accelerometer, a flow meter, a pressure sensor, or any combination thereof. - In one or more embodiments, the
sensor 20 may further communicate the information about the characteristic to thecontroller 16 at regular intervals, timed intervals, intermittent intervals, predetermined intervals or at any other interval. In one or more embodiments, the information is communicated continuously. Thecontroller 16 may modify the control signal thecontroller 16 sends to theprimary mover 14 based on the information received fromsensor 20, such that theprimary mover 14 operates to optimize a characteristic of thepumping apparatus 100. In one or more embodiments, thecharacteristic sensor 20 monitors the same characteristic optimized by thecontroller 16. For example, in certain embodiments,sensor 20 may monitor any one or more characteristics including, but not limited to, the vibration of the downstream portion of thefluid channel 18, while thecontroller 16 commands theprimary mover 14 to operate to optimize the flow rate of the fluid influid channel 18. In certain embodiments, thesensor 20 may monitor the vibration of the downstream portion of thefluid channel 18, while thecontroller 16 commands theprimary mover 14 to operate to reduce the vibration of thepump 10. In some embodiments, thesensor 20 monitors a different characteristic than the characteristic being optimized bycontroller 16. - In one or more embodiments, the upstream portion of a
fluid channel 28 may comprise asensor 21, wherein thesensor 21 is coupled to thecontroller 16. Thesensor 21 monitors at least one characteristic of the upstream portion of thefluid channel 28. One or more characteristics monitored bysensor 21 may comprise at least one of: the vibration of the upstream portion of a fluid channel, fluid flow, pressure, or any combination thereof. In one or more embodiments,sensor 21 may comprise an accelerometer, a flow meter, a pressure sensor, or any combination thereof. - In one or more embodiments, the
sensor 21 may further communicate the information about the monitored characteristic to thecontroller 16 at regular intervals, timed intervals, intermittent intervals, predetermined intervals or at any other interval. In one or more embodiments, the information is communicated continuously. Thecontroller 16 may modify the control signal thecontroller 16 sends to theprimary mover 14 based on the information received fromsensor 21, such that theprimary mover 14 operates to optimize a characteristic of thepumping apparatus 100. In one or more embodiments, thecharacteristic sensor 21 monitors the same characteristic optimized by thecontroller 16. For example, in certain embodiments, thecharacteristic sensor 21 may monitor the vibration of the upstream portion of thefluid channel 28, while thecontroller 16 commands theprimary mover 14 to operate to optimize the flow rate of the fluid influid channel 28. In certain embodiments, thesensor 21 may monitor the vibration of the upstream portion of thefluid channel 28, while thecontroller 16 commands theprimary mover 14 to operate to reduce the vibration of thepump 10. In some embodiments, thesensor 21 monitors a different characteristic than the characteristic being optimized bycontroller 16. -
FIG. 2 shows the well 60 during an exemplary fracturing operation using thepumping apparatus 100 in a portion of a subterranean formation ofinterest 102 surrounding awell bore 104. Apart from fracturing operations, the apparatus ofFIG. 2 may be used in a variety of different well stimulation treatments such as acidizing treatments. The well bore 104 extends from thesurface 106, and the fracturingfluid 108 is applied to a portion of thesubterranean formation 102 surrounding the horizontal portion of the well bore. Although shown as vertical deviating to horizontal, the well bore 104 may include horizontal, vertical, slant, curved, and other types of well bore geometries and orientations, and the fracturing treatment may be applied to a subterranean zone surrounding any portion of the well bore. The well bore 104 can include acasing 110 that is cemented or otherwise secured to the well bore wall. The well bore 104 can be uncased or include uncased sections. Perforations can be formed in thecasing 110 to allow fracturing fluids and/or other materials to flow into thesubterranean formation 102. In cased wells, perforations can be formed using shape charges, a perforating gun, hydro jetting and/or other tools. - The well is shown with a
work string 112 depending from thesurface 106 into thewell bore 104. The pump and blender system 50 is coupled awork string 112 to pump the fracturingfluid 108 into thewell bore 104. The workingstring 112 may include coiled tubing, jointed pipe, and/or other structures that allow fluid to flow into thewell bore 104. The workingstring 112 can include flow control devices, bypass valves, ports, and or other tools or well devices that control a flow of fluid from the interior of the workingstring 112 into thesubterranean zone 102. For example, the workingstring 112 may include ports adjacent the well bore wall to communicate the fracturingfluid 108 directly into thesubterranean formation 102, and/or the workingstring 112 may include ports that are spaced apart from the well bore wall to communicate the fracturingfluid 108 into an annulus in the well bore between the workingstring 112 and the well bore wall. - The working
string 112 and/or the well bore 104 may include one or more sets ofpackers 114 that seal the annulus between the workingstring 112 and well bore 104 to define an interval of the well bore 104 into which the fracturingfluid 108 will be pumped.FIG. 2 shows twopackers 114, one defining an uphole boundary of the interval and one defining the downhole end of the interval. When the fracturingfluid 108 is introduced into well bore 104 (for example, inFIG. 2 , the area of the well bore 104 between packers 114) at a sufficient hydraulic pressure, one ormore fractures 116 may be created in thesubterranean zone 102. The proppant particulates in the fracturingfluid 108 may enter thefractures 116 where they may remain after the fracturing fluid flows out of the well bore. These proppant particulates may “prop”fractures 116 such that fluids may flow more freely through thefractures 116. - An embodiment of the present disclosure is a system for pumping fluid comprising a pump, a primary mover coupled to the pump, and a controller coupled to the primary mover, wherein the controller is programmed to control the primary mover so as to optimize a first characteristic of the system, wherein the controller commands the primary mover to throttle its speeds such that the primary mover's speed over time follows a cyclic or periodic function, for example, a sine function.
- Another embodiment of the present disclosure is a method for pumping a fluid comprising providing a pumping apparatus comprising a pump, a primary mover that actuates the pump, and a controller comprising a processor and a memory device programmed to send commands to the primary mover; and using known characteristics of the pump to modify the commands sent to the primary mover such that a characteristic of the pumping apparatus is optimized.
- Another embodiment of the present disclosure is a method for pumping a fluid comprising providing a pumping apparatus comprising a pump, a primary mover mechanically coupled to the pump by a drive train such that the primary mover actuates the pump, a controller that sends commands to the primary mover, and a sensor coupled to the controller; pumping the fluid downhole; monitoring a first characteristic of the pumping apparatus with the sensor, sending a signal to the controller indicative of the magnitude of the first characteristic being monitored by the sensor; determining an appropriate command signal to send to the primary mover to optimize a second characteristic of the pumping apparatus; and sending the appropriate command signal to the primary mover to optimize the second characteristic of the pumping apparatus.
- Therefore, the present disclosure is well adapted to attain the ends and advantages mentioned as well as those that are inherent therein. The particular embodiments disclosed above are illustrative only, as the present disclosure may be modified and practiced in different but equivalent manners apparent to those skilled in the art having the benefit of the teachings herein. Furthermore, no limitations are intended to the details of construction or design herein shown, other than as described in the claims below. It is therefore evident that the particular illustrative embodiments disclosed above may be altered or modified and all such variations are considered within the scope and spirit of the present disclosure. Also, the terms in the claims have their plain, ordinary meaning unless otherwise explicitly and clearly defined by the patentee.
Claims (20)
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
PCT/US2016/048198 WO2018038710A1 (en) | 2016-08-23 | 2016-08-23 | Systems and methods of optimized pump speed control to reduce cavitation, pulsation and load fluctuation |
Publications (1)
Publication Number | Publication Date |
---|---|
US20200049153A1 true US20200049153A1 (en) | 2020-02-13 |
Family
ID=61245162
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US16/314,032 Pending US20200049153A1 (en) | 2016-08-23 | 2016-08-23 | Systems and methods of optimized pump speed control to reduce cavitation, pulsation and load fluctuation |
Country Status (3)
Country | Link |
---|---|
US (1) | US20200049153A1 (en) |
CA (1) | CA3030110C (en) |
WO (1) | WO2018038710A1 (en) |
Cited By (35)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US10954770B1 (en) | 2020-06-09 | 2021-03-23 | Bj Energy Solutions, Llc | Systems and methods for exchanging fracturing components of a hydraulic fracturing unit |
US10961908B1 (en) | 2020-06-05 | 2021-03-30 | Bj Energy Solutions, Llc | Systems and methods to enhance intake air flow to a gas turbine engine of a hydraulic fracturing unit |
US10961912B1 (en) | 2019-09-13 | 2021-03-30 | Bj Energy Solutions, Llc | Direct drive unit removal system and associated methods |
US10961914B1 (en) | 2019-09-13 | 2021-03-30 | BJ Energy Solutions, LLC Houston | Turbine engine exhaust duct system and methods for noise dampening and attenuation |
US10968837B1 (en) | 2020-05-14 | 2021-04-06 | Bj Energy Solutions, Llc | Systems and methods utilizing turbine compressor discharge for hydrostatic manifold purge |
US10989180B2 (en) | 2019-09-13 | 2021-04-27 | Bj Energy Solutions, Llc | Power sources and transmission networks for auxiliary equipment onboard hydraulic fracturing units and associated methods |
US11002189B2 (en) | 2019-09-13 | 2021-05-11 | Bj Energy Solutions, Llc | Mobile gas turbine inlet air conditioning system and associated methods |
US11015594B2 (en) | 2019-09-13 | 2021-05-25 | Bj Energy Solutions, Llc | Systems and method for use of single mass flywheel alongside torsional vibration damper assembly for single acting reciprocating pump |
US11015536B2 (en) | 2019-09-13 | 2021-05-25 | Bj Energy Solutions, Llc | Methods and systems for supplying fuel to gas turbine engines |
US11022526B1 (en) | 2020-06-09 | 2021-06-01 | Bj Energy Solutions, Llc | Systems and methods for monitoring a condition of a fracturing component section of a hydraulic fracturing unit |
US11028677B1 (en) | 2020-06-22 | 2021-06-08 | Bj Energy Solutions, Llc | Stage profiles for operations of hydraulic systems and associated methods |
US11066915B1 (en) | 2020-06-09 | 2021-07-20 | Bj Energy Solutions, Llc | Methods for detection and mitigation of well screen out |
US11109508B1 (en) | 2020-06-05 | 2021-08-31 | Bj Energy Solutions, Llc | Enclosure assembly for enhanced cooling of direct drive unit and related methods |
US11111768B1 (en) | 2020-06-09 | 2021-09-07 | Bj Energy Solutions, Llc | Drive equipment and methods for mobile fracturing transportation platforms |
US11125066B1 (en) | 2020-06-22 | 2021-09-21 | Bj Energy Solutions, Llc | Systems and methods to operate a dual-shaft gas turbine engine for hydraulic fracturing |
US11149533B1 (en) | 2020-06-24 | 2021-10-19 | Bj Energy Solutions, Llc | Systems to monitor, detect, and/or intervene relative to cavitation and pulsation events during a hydraulic fracturing operation |
US11193360B1 (en) | 2020-07-17 | 2021-12-07 | Bj Energy Solutions, Llc | Methods, systems, and devices to enhance fracturing fluid delivery to subsurface formations during high-pressure fracturing operations |
US11208953B1 (en) | 2020-06-05 | 2021-12-28 | Bj Energy Solutions, Llc | Systems and methods to enhance intake air flow to a gas turbine engine of a hydraulic fracturing unit |
US11208880B2 (en) | 2020-05-28 | 2021-12-28 | Bj Energy Solutions, Llc | Bi-fuel reciprocating engine to power direct drive turbine fracturing pumps onboard auxiliary systems and related methods |
US11220895B1 (en) | 2020-06-24 | 2022-01-11 | Bj Energy Solutions, Llc | Automated diagnostics of electronic instrumentation in a system for fracturing a well and associated methods |
US11236739B2 (en) | 2019-09-13 | 2022-02-01 | Bj Energy Solutions, Llc | Power sources and transmission networks for auxiliary equipment onboard hydraulic fracturing units and associated methods |
US11268346B2 (en) | 2019-09-13 | 2022-03-08 | Bj Energy Solutions, Llc | Fuel, communications, and power connection systems |
US11273531B2 (en) * | 2018-09-10 | 2022-03-15 | Fanuc America Corporation | Smart coolant pump |
US11408794B2 (en) | 2019-09-13 | 2022-08-09 | Bj Energy Solutions, Llc | Fuel, communications, and power connection systems and related methods |
US11415125B2 (en) | 2020-06-23 | 2022-08-16 | Bj Energy Solutions, Llc | Systems for utilization of a hydraulic fracturing unit profile to operate hydraulic fracturing units |
US11428165B2 (en) | 2020-05-15 | 2022-08-30 | Bj Energy Solutions, Llc | Onboard heater of auxiliary systems using exhaust gases and associated methods |
US11473413B2 (en) | 2020-06-23 | 2022-10-18 | Bj Energy Solutions, Llc | Systems and methods to autonomously operate hydraulic fracturing units |
US11560845B2 (en) | 2019-05-15 | 2023-01-24 | Bj Energy Solutions, Llc | Mobile gas turbine inlet air conditioning system and associated methods |
US11608725B2 (en) | 2019-09-13 | 2023-03-21 | Bj Energy Solutions, Llc | Methods and systems for operating a fleet of pumps |
US11624326B2 (en) | 2017-05-21 | 2023-04-11 | Bj Energy Solutions, Llc | Methods and systems for supplying fuel to gas turbine engines |
US11635074B2 (en) | 2020-05-12 | 2023-04-25 | Bj Energy Solutions, Llc | Cover for fluid systems and related methods |
US11639654B2 (en) | 2021-05-24 | 2023-05-02 | Bj Energy Solutions, Llc | Hydraulic fracturing pumps to enhance flow of fracturing fluid into wellheads and related methods |
US11867118B2 (en) | 2019-09-13 | 2024-01-09 | Bj Energy Solutions, Llc | Methods and systems for supplying fuel to gas turbine engines |
US11933153B2 (en) | 2020-06-22 | 2024-03-19 | Bj Energy Solutions, Llc | Systems and methods to operate hydraulic fracturing units using automatic flow rate and/or pressure control |
US11939853B2 (en) | 2020-06-22 | 2024-03-26 | Bj Energy Solutions, Llc | Systems and methods providing a configurable staged rate increase function to operate hydraulic fracturing units |
Citations (9)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4553590A (en) * | 1981-03-19 | 1985-11-19 | Hidden Valley Associates | Apparatus for pumping subterranean fluids |
US6167965B1 (en) * | 1995-08-30 | 2001-01-02 | Baker Hughes Incorporated | Electrical submersible pump and methods for enhanced utilization of electrical submersible pumps in the completion and production of wellbores |
US7009707B2 (en) * | 2001-04-06 | 2006-03-07 | Thales Underwater Systems Uk Limited | Apparatus and method of sensing fluid flow using sensing means coupled to an axial coil spring |
US20070017672A1 (en) * | 2005-07-22 | 2007-01-25 | Schlumberger Technology Corporation | Automatic Detection of Resonance Frequency of a Downhole System |
US7357021B2 (en) * | 2004-04-08 | 2008-04-15 | Welldynamics, Inc. | Methods of monitoring downhole conditions |
US7624800B2 (en) * | 2005-11-22 | 2009-12-01 | Schlumberger Technology Corporation | System and method for sensing parameters in a wellbore |
US20090317266A1 (en) * | 2006-07-27 | 2009-12-24 | William Hugh Salvin Rampen | Digital hydraulic pump/motor torque modulation system and apparatus |
US20110027110A1 (en) * | 2008-01-31 | 2011-02-03 | Schlumberger Technology Corporation | Oil filter for downhole motor |
US20160265321A1 (en) * | 2015-03-11 | 2016-09-15 | Encline Artificial Lift Technologies LLC | Well Pumping System Having Pump Speed Optimization |
Family Cites Families (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US8146665B2 (en) * | 2007-11-13 | 2012-04-03 | Halliburton Energy Services Inc. | Apparatus and method for maintaining boost pressure to high-pressure pumps during wellbore servicing operations |
US20100300683A1 (en) * | 2009-05-28 | 2010-12-02 | Halliburton Energy Services, Inc. | Real Time Pump Monitoring |
US8926291B2 (en) * | 2010-07-19 | 2015-01-06 | Michael Orndorff | Speed control for diaphragm pump |
US9546652B2 (en) * | 2012-03-28 | 2017-01-17 | Imo Industries, Inc. | System and method for monitoring and control of cavitation in positive displacement pumps |
US9410546B2 (en) * | 2014-08-12 | 2016-08-09 | Baker Hughes Incorporated | Reciprocating pump cavitation detection and avoidance |
-
2016
- 2016-08-23 WO PCT/US2016/048198 patent/WO2018038710A1/en active Application Filing
- 2016-08-23 CA CA3030110A patent/CA3030110C/en active Active
- 2016-08-23 US US16/314,032 patent/US20200049153A1/en active Pending
Patent Citations (9)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4553590A (en) * | 1981-03-19 | 1985-11-19 | Hidden Valley Associates | Apparatus for pumping subterranean fluids |
US6167965B1 (en) * | 1995-08-30 | 2001-01-02 | Baker Hughes Incorporated | Electrical submersible pump and methods for enhanced utilization of electrical submersible pumps in the completion and production of wellbores |
US7009707B2 (en) * | 2001-04-06 | 2006-03-07 | Thales Underwater Systems Uk Limited | Apparatus and method of sensing fluid flow using sensing means coupled to an axial coil spring |
US7357021B2 (en) * | 2004-04-08 | 2008-04-15 | Welldynamics, Inc. | Methods of monitoring downhole conditions |
US20070017672A1 (en) * | 2005-07-22 | 2007-01-25 | Schlumberger Technology Corporation | Automatic Detection of Resonance Frequency of a Downhole System |
US7624800B2 (en) * | 2005-11-22 | 2009-12-01 | Schlumberger Technology Corporation | System and method for sensing parameters in a wellbore |
US20090317266A1 (en) * | 2006-07-27 | 2009-12-24 | William Hugh Salvin Rampen | Digital hydraulic pump/motor torque modulation system and apparatus |
US20110027110A1 (en) * | 2008-01-31 | 2011-02-03 | Schlumberger Technology Corporation | Oil filter for downhole motor |
US20160265321A1 (en) * | 2015-03-11 | 2016-09-15 | Encline Artificial Lift Technologies LLC | Well Pumping System Having Pump Speed Optimization |
Cited By (138)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US11624326B2 (en) | 2017-05-21 | 2023-04-11 | Bj Energy Solutions, Llc | Methods and systems for supplying fuel to gas turbine engines |
US11273531B2 (en) * | 2018-09-10 | 2022-03-15 | Fanuc America Corporation | Smart coolant pump |
US11560845B2 (en) | 2019-05-15 | 2023-01-24 | Bj Energy Solutions, Llc | Mobile gas turbine inlet air conditioning system and associated methods |
US11555756B2 (en) | 2019-09-13 | 2023-01-17 | Bj Energy Solutions, Llc | Fuel, communications, and power connection systems and related methods |
US11725583B2 (en) | 2019-09-13 | 2023-08-15 | Bj Energy Solutions, Llc | Mobile gas turbine inlet air conditioning system and associated methods |
US10982596B1 (en) | 2019-09-13 | 2021-04-20 | Bj Energy Solutions, Llc | Direct drive unit removal system and associated methods |
US10989180B2 (en) | 2019-09-13 | 2021-04-27 | Bj Energy Solutions, Llc | Power sources and transmission networks for auxiliary equipment onboard hydraulic fracturing units and associated methods |
US11002189B2 (en) | 2019-09-13 | 2021-05-11 | Bj Energy Solutions, Llc | Mobile gas turbine inlet air conditioning system and associated methods |
US11613980B2 (en) | 2019-09-13 | 2023-03-28 | Bj Energy Solutions, Llc | Methods and systems for operating a fleet of pumps |
US11867118B2 (en) | 2019-09-13 | 2024-01-09 | Bj Energy Solutions, Llc | Methods and systems for supplying fuel to gas turbine engines |
US11015536B2 (en) | 2019-09-13 | 2021-05-25 | Bj Energy Solutions, Llc | Methods and systems for supplying fuel to gas turbine engines |
US10961914B1 (en) | 2019-09-13 | 2021-03-30 | BJ Energy Solutions, LLC Houston | Turbine engine exhaust duct system and methods for noise dampening and attenuation |
US11971028B2 (en) | 2019-09-13 | 2024-04-30 | Bj Energy Solutions, Llc | Systems and method for use of single mass flywheel alongside torsional vibration damper assembly for single acting reciprocating pump |
US11060455B1 (en) | 2019-09-13 | 2021-07-13 | Bj Energy Solutions, Llc | Mobile gas turbine inlet air conditioning system and associated methods |
US11608725B2 (en) | 2019-09-13 | 2023-03-21 | Bj Energy Solutions, Llc | Methods and systems for operating a fleet of pumps |
US11604113B2 (en) | 2019-09-13 | 2023-03-14 | Bj Energy Solutions, Llc | Fuel, communications, and power connection systems and related methods |
US11092152B2 (en) | 2019-09-13 | 2021-08-17 | Bj Energy Solutions, Llc | Systems and method for use of single mass flywheel alongside torsional vibration damper assembly for single acting reciprocating pump |
US11098651B1 (en) | 2019-09-13 | 2021-08-24 | Bj Energy Solutions, Llc | Turbine engine exhaust duct system and methods for noise dampening and attenuation |
US11598263B2 (en) | 2019-09-13 | 2023-03-07 | Bj Energy Solutions, Llc | Mobile gas turbine inlet air conditioning system and associated methods |
US11578660B1 (en) | 2019-09-13 | 2023-02-14 | Bj Energy Solutions, Llc | Direct drive unit removal system and associated methods |
US11629584B2 (en) | 2019-09-13 | 2023-04-18 | Bj Energy Solutions, Llc | Power sources and transmission networks for auxiliary equipment onboard hydraulic fracturing units and associated methods |
US11401865B1 (en) | 2019-09-13 | 2022-08-02 | Bj Energy Solutions, Llc | Direct drive unit removal system and associated methods |
US11560848B2 (en) | 2019-09-13 | 2023-01-24 | Bj Energy Solutions, Llc | Methods for noise dampening and attenuation of turbine engine |
US11149726B1 (en) | 2019-09-13 | 2021-10-19 | Bj Energy Solutions, Llc | Systems and method for use of single mass flywheel alongside torsional vibration damper assembly for single acting reciprocating pump |
US11156159B1 (en) | 2019-09-13 | 2021-10-26 | Bj Energy Solutions, Llc | Mobile gas turbine inlet air conditioning system and associated methods |
US10961912B1 (en) | 2019-09-13 | 2021-03-30 | Bj Energy Solutions, Llc | Direct drive unit removal system and associated methods |
US11408794B2 (en) | 2019-09-13 | 2022-08-09 | Bj Energy Solutions, Llc | Fuel, communications, and power connection systems and related methods |
US11530602B2 (en) | 2019-09-13 | 2022-12-20 | Bj Energy Solutions, Llc | Power sources and transmission networks for auxiliary equipment onboard hydraulic fracturing units and associated methods |
US11015594B2 (en) | 2019-09-13 | 2021-05-25 | Bj Energy Solutions, Llc | Systems and method for use of single mass flywheel alongside torsional vibration damper assembly for single acting reciprocating pump |
US11761846B2 (en) | 2019-09-13 | 2023-09-19 | Bj Energy Solutions, Llc | Fuel, communications, and power connection systems and related methods |
US11649766B1 (en) | 2019-09-13 | 2023-05-16 | Bj Energy Solutions, Llc | Mobile gas turbine inlet air conditioning system and associated methods |
US11512642B1 (en) | 2019-09-13 | 2022-11-29 | Bj Energy Solutions, Llc | Direct drive unit removal system and associated methods |
US11655763B1 (en) | 2019-09-13 | 2023-05-23 | Bj Energy Solutions, Llc | Direct drive unit removal system and associated methods |
US11473503B1 (en) | 2019-09-13 | 2022-10-18 | Bj Energy Solutions, Llc | Direct drive unit removal system and associated methods |
US11236739B2 (en) | 2019-09-13 | 2022-02-01 | Bj Energy Solutions, Llc | Power sources and transmission networks for auxiliary equipment onboard hydraulic fracturing units and associated methods |
US11859482B2 (en) | 2019-09-13 | 2024-01-02 | Bj Energy Solutions, Llc | Power sources and transmission networks for auxiliary equipment onboard hydraulic fracturing units and associated methods |
US11852001B2 (en) | 2019-09-13 | 2023-12-26 | Bj Energy Solutions, Llc | Methods and systems for operating a fleet of pumps |
US11473997B2 (en) | 2019-09-13 | 2022-10-18 | Bj Energy Solutions, Llc | Fuel, communications, and power connection systems and related methods |
US11268346B2 (en) | 2019-09-13 | 2022-03-08 | Bj Energy Solutions, Llc | Fuel, communications, and power connection systems |
US11619122B2 (en) | 2019-09-13 | 2023-04-04 | Bj Energy Solutions, Llc | Methods and systems for operating a fleet of pumps |
US11346280B1 (en) | 2019-09-13 | 2022-05-31 | Bj Energy Solutions, Llc | Direct drive unit removal system and associated methods |
US11280331B2 (en) | 2019-09-13 | 2022-03-22 | Bj Energy Solutions, Llc | Systems and method for use of single mass flywheel alongside torsional vibration damper assembly for single acting reciprocating pump |
US11280266B2 (en) | 2019-09-13 | 2022-03-22 | Bj Energy Solutions, Llc | Mobile gas turbine inlet air conditioning system and associated methods |
US11287350B2 (en) | 2019-09-13 | 2022-03-29 | Bj Energy Solutions, Llc | Fuel, communications, and power connection methods |
US11767791B2 (en) | 2019-09-13 | 2023-09-26 | Bj Energy Solutions, Llc | Mobile gas turbine inlet air conditioning system and associated methods |
US11460368B2 (en) | 2019-09-13 | 2022-10-04 | Bj Energy Solutions, Llc | Fuel, communications, and power connection systems and related methods |
US11459954B2 (en) | 2019-09-13 | 2022-10-04 | Bj Energy Solutions, Llc | Turbine engine exhaust duct system and methods for noise dampening and attenuation |
US11719234B2 (en) | 2019-09-13 | 2023-08-08 | Bj Energy Solutions, Llc | Systems and method for use of single mass flywheel alongside torsional vibration damper assembly for single acting reciprocating pump |
US11319878B2 (en) | 2019-09-13 | 2022-05-03 | Bj Energy Solutions, Llc | Direct drive unit removal system and associated methods |
US11415056B1 (en) | 2019-09-13 | 2022-08-16 | Bj Energy Solutions, Llc | Turbine engine exhaust duct system and methods for noise dampening and attenuation |
US11708829B2 (en) | 2020-05-12 | 2023-07-25 | Bj Energy Solutions, Llc | Cover for fluid systems and related methods |
US11635074B2 (en) | 2020-05-12 | 2023-04-25 | Bj Energy Solutions, Llc | Cover for fluid systems and related methods |
US10968837B1 (en) | 2020-05-14 | 2021-04-06 | Bj Energy Solutions, Llc | Systems and methods utilizing turbine compressor discharge for hydrostatic manifold purge |
US11898504B2 (en) | 2020-05-14 | 2024-02-13 | Bj Energy Solutions, Llc | Systems and methods utilizing turbine compressor discharge for hydrostatic manifold purge |
US11698028B2 (en) | 2020-05-15 | 2023-07-11 | Bj Energy Solutions, Llc | Onboard heater of auxiliary systems using exhaust gases and associated methods |
US11959419B2 (en) | 2020-05-15 | 2024-04-16 | Bj Energy Solutions, Llc | Onboard heater of auxiliary systems using exhaust gases and associated methods |
US11542868B2 (en) | 2020-05-15 | 2023-01-03 | Bj Energy Solutions, Llc | Onboard heater of auxiliary systems using exhaust gases and associated methods |
US11624321B2 (en) | 2020-05-15 | 2023-04-11 | Bj Energy Solutions, Llc | Onboard heater of auxiliary systems using exhaust gases and associated methods |
US11434820B2 (en) | 2020-05-15 | 2022-09-06 | Bj Energy Solutions, Llc | Onboard heater of auxiliary systems using exhaust gases and associated methods |
US11428165B2 (en) | 2020-05-15 | 2022-08-30 | Bj Energy Solutions, Llc | Onboard heater of auxiliary systems using exhaust gases and associated methods |
US11814940B2 (en) | 2020-05-28 | 2023-11-14 | Bj Energy Solutions Llc | Bi-fuel reciprocating engine to power direct drive turbine fracturing pumps onboard auxiliary systems and related methods |
US11208880B2 (en) | 2020-05-28 | 2021-12-28 | Bj Energy Solutions, Llc | Bi-fuel reciprocating engine to power direct drive turbine fracturing pumps onboard auxiliary systems and related methods |
US11603745B2 (en) | 2020-05-28 | 2023-03-14 | Bj Energy Solutions, Llc | Bi-fuel reciprocating engine to power direct drive turbine fracturing pumps onboard auxiliary systems and related methods |
US11313213B2 (en) | 2020-05-28 | 2022-04-26 | Bj Energy Solutions, Llc | Bi-fuel reciprocating engine to power direct drive turbine fracturing pumps onboard auxiliary systems and related methods |
US11365616B1 (en) | 2020-05-28 | 2022-06-21 | Bj Energy Solutions, Llc | Bi-fuel reciprocating engine to power direct drive turbine fracturing pumps onboard auxiliary systems and related methods |
US11627683B2 (en) | 2020-06-05 | 2023-04-11 | Bj Energy Solutions, Llc | Enclosure assembly for enhanced cooling of direct drive unit and related methods |
US11300050B2 (en) | 2020-06-05 | 2022-04-12 | Bj Energy Solutions, Llc | Systems and methods to enhance intake air flow to a gas turbine engine of a hydraulic fracturing unit |
US11598264B2 (en) | 2020-06-05 | 2023-03-07 | Bj Energy Solutions, Llc | Systems and methods to enhance intake air flow to a gas turbine engine of a hydraulic fracturing unit |
US10961908B1 (en) | 2020-06-05 | 2021-03-30 | Bj Energy Solutions, Llc | Systems and methods to enhance intake air flow to a gas turbine engine of a hydraulic fracturing unit |
US11109508B1 (en) | 2020-06-05 | 2021-08-31 | Bj Energy Solutions, Llc | Enclosure assembly for enhanced cooling of direct drive unit and related methods |
US11891952B2 (en) | 2020-06-05 | 2024-02-06 | Bj Energy Solutions, Llc | Systems and methods to enhance intake air flow to a gas turbine engine of a hydraulic fracturing unit |
US11723171B2 (en) | 2020-06-05 | 2023-08-08 | Bj Energy Solutions, Llc | Enclosure assembly for enhanced cooling of direct drive unit and related methods |
US11208953B1 (en) | 2020-06-05 | 2021-12-28 | Bj Energy Solutions, Llc | Systems and methods to enhance intake air flow to a gas turbine engine of a hydraulic fracturing unit |
US11746698B2 (en) | 2020-06-05 | 2023-09-05 | Bj Energy Solutions, Llc | Systems and methods to enhance intake air flow to a gas turbine engine of a hydraulic fracturing unit |
US11378008B2 (en) | 2020-06-05 | 2022-07-05 | Bj Energy Solutions, Llc | Systems and methods to enhance intake air flow to a gas turbine engine of a hydraulic fracturing unit |
US11129295B1 (en) | 2020-06-05 | 2021-09-21 | Bj Energy Solutions, Llc | Enclosure assembly for enhanced cooling of direct drive unit and related methods |
US11208881B1 (en) | 2020-06-09 | 2021-12-28 | Bj Energy Solutions, Llc | Methods and systems for detection and mitigation of well screen out |
US11174716B1 (en) | 2020-06-09 | 2021-11-16 | Bj Energy Solutions, Llc | Drive equipment and methods for mobile fracturing transportation platforms |
US11939854B2 (en) | 2020-06-09 | 2024-03-26 | Bj Energy Solutions, Llc | Methods for detection and mitigation of well screen out |
US11566506B2 (en) | 2020-06-09 | 2023-01-31 | Bj Energy Solutions, Llc | Methods for detection and mitigation of well screen out |
US11643915B2 (en) | 2020-06-09 | 2023-05-09 | Bj Energy Solutions, Llc | Drive equipment and methods for mobile fracturing transportation platforms |
US11512570B2 (en) | 2020-06-09 | 2022-11-29 | Bj Energy Solutions, Llc | Systems and methods for exchanging fracturing components of a hydraulic fracturing unit |
US11111768B1 (en) | 2020-06-09 | 2021-09-07 | Bj Energy Solutions, Llc | Drive equipment and methods for mobile fracturing transportation platforms |
US11867046B2 (en) | 2020-06-09 | 2024-01-09 | Bj Energy Solutions, Llc | Systems and methods for exchanging fracturing components of a hydraulic fracturing unit |
US11629583B2 (en) | 2020-06-09 | 2023-04-18 | Bj Energy Solutions, Llc | Systems and methods for exchanging fracturing components of a hydraulic fracturing unit |
US10954770B1 (en) | 2020-06-09 | 2021-03-23 | Bj Energy Solutions, Llc | Systems and methods for exchanging fracturing components of a hydraulic fracturing unit |
US11085281B1 (en) | 2020-06-09 | 2021-08-10 | Bj Energy Solutions, Llc | Systems and methods for exchanging fracturing components of a hydraulic fracturing unit |
US11261717B2 (en) | 2020-06-09 | 2022-03-01 | Bj Energy Solutions, Llc | Systems and methods for exchanging fracturing components of a hydraulic fracturing unit |
US11319791B2 (en) | 2020-06-09 | 2022-05-03 | Bj Energy Solutions, Llc | Methods and systems for detection and mitigation of well screen out |
US11066915B1 (en) | 2020-06-09 | 2021-07-20 | Bj Energy Solutions, Llc | Methods for detection and mitigation of well screen out |
US11022526B1 (en) | 2020-06-09 | 2021-06-01 | Bj Energy Solutions, Llc | Systems and methods for monitoring a condition of a fracturing component section of a hydraulic fracturing unit |
US11015423B1 (en) | 2020-06-09 | 2021-05-25 | Bj Energy Solutions, Llc | Systems and methods for exchanging fracturing components of a hydraulic fracturing unit |
US11339638B1 (en) | 2020-06-09 | 2022-05-24 | Bj Energy Solutions, Llc | Systems and methods for exchanging fracturing components of a hydraulic fracturing unit |
US11236598B1 (en) | 2020-06-22 | 2022-02-01 | Bj Energy Solutions, Llc | Stage profiles for operations of hydraulic systems and associated methods |
US11939853B2 (en) | 2020-06-22 | 2024-03-26 | Bj Energy Solutions, Llc | Systems and methods providing a configurable staged rate increase function to operate hydraulic fracturing units |
US11028677B1 (en) | 2020-06-22 | 2021-06-08 | Bj Energy Solutions, Llc | Stage profiles for operations of hydraulic systems and associated methods |
US11598188B2 (en) | 2020-06-22 | 2023-03-07 | Bj Energy Solutions, Llc | Stage profiles for operations of hydraulic systems and associated methods |
US11572774B2 (en) | 2020-06-22 | 2023-02-07 | Bj Energy Solutions, Llc | Systems and methods to operate a dual-shaft gas turbine engine for hydraulic fracturing |
US11732565B2 (en) | 2020-06-22 | 2023-08-22 | Bj Energy Solutions, Llc | Systems and methods to operate a dual-shaft gas turbine engine for hydraulic fracturing |
US11639655B2 (en) | 2020-06-22 | 2023-05-02 | Bj Energy Solutions, Llc | Systems and methods to operate a dual-shaft gas turbine engine for hydraulic fracturing |
US11125066B1 (en) | 2020-06-22 | 2021-09-21 | Bj Energy Solutions, Llc | Systems and methods to operate a dual-shaft gas turbine engine for hydraulic fracturing |
US11952878B2 (en) | 2020-06-22 | 2024-04-09 | Bj Energy Solutions, Llc | Stage profiles for operations of hydraulic systems and associated methods |
US11408263B2 (en) | 2020-06-22 | 2022-08-09 | Bj Energy Solutions, Llc | Systems and methods to operate a dual-shaft gas turbine engine for hydraulic fracturing |
US11898429B2 (en) | 2020-06-22 | 2024-02-13 | Bj Energy Solutions, Llc | Systems and methods to operate a dual-shaft gas turbine engine for hydraulic fracturing |
US11208879B1 (en) | 2020-06-22 | 2021-12-28 | Bj Energy Solutions, Llc | Stage profiles for operations of hydraulic systems and associated methods |
US11933153B2 (en) | 2020-06-22 | 2024-03-19 | Bj Energy Solutions, Llc | Systems and methods to operate hydraulic fracturing units using automatic flow rate and/or pressure control |
US11661832B2 (en) | 2020-06-23 | 2023-05-30 | Bj Energy Solutions, Llc | Systems and methods to autonomously operate hydraulic fracturing units |
US11649820B2 (en) | 2020-06-23 | 2023-05-16 | Bj Energy Solutions, Llc | Systems and methods of utilization of a hydraulic fracturing unit profile to operate hydraulic fracturing units |
US11473413B2 (en) | 2020-06-23 | 2022-10-18 | Bj Energy Solutions, Llc | Systems and methods to autonomously operate hydraulic fracturing units |
US11466680B2 (en) | 2020-06-23 | 2022-10-11 | Bj Energy Solutions, Llc | Systems and methods of utilization of a hydraulic fracturing unit profile to operate hydraulic fracturing units |
US11428218B2 (en) | 2020-06-23 | 2022-08-30 | Bj Energy Solutions, Llc | Systems and methods of utilization of a hydraulic fracturing unit profile to operate hydraulic fracturing units |
US11415125B2 (en) | 2020-06-23 | 2022-08-16 | Bj Energy Solutions, Llc | Systems for utilization of a hydraulic fracturing unit profile to operate hydraulic fracturing units |
US11719085B1 (en) | 2020-06-23 | 2023-08-08 | Bj Energy Solutions, Llc | Systems and methods to autonomously operate hydraulic fracturing units |
US11939974B2 (en) | 2020-06-23 | 2024-03-26 | Bj Energy Solutions, Llc | Systems and methods of utilization of a hydraulic fracturing unit profile to operate hydraulic fracturing units |
US11566505B2 (en) | 2020-06-23 | 2023-01-31 | Bj Energy Solutions, Llc | Systems and methods to autonomously operate hydraulic fracturing units |
US11391137B2 (en) | 2020-06-24 | 2022-07-19 | Bj Energy Solutions, Llc | Systems and methods to monitor, detect, and/or intervene relative to cavitation and pulsation events during a hydraulic fracturing operation |
US11149533B1 (en) | 2020-06-24 | 2021-10-19 | Bj Energy Solutions, Llc | Systems to monitor, detect, and/or intervene relative to cavitation and pulsation events during a hydraulic fracturing operation |
US11746638B2 (en) | 2020-06-24 | 2023-09-05 | Bj Energy Solutions, Llc | Automated diagnostics of electronic instrumentation in a system for fracturing a well and associated methods |
US11542802B2 (en) | 2020-06-24 | 2023-01-03 | Bj Energy Solutions, Llc | Hydraulic fracturing control assembly to detect pump cavitation or pulsation |
US11299971B2 (en) | 2020-06-24 | 2022-04-12 | Bj Energy Solutions, Llc | System of controlling a hydraulic fracturing pump or blender using cavitation or pulsation detection |
US11274537B2 (en) | 2020-06-24 | 2022-03-15 | Bj Energy Solutions, Llc | Method to detect and intervene relative to cavitation and pulsation events during a hydraulic fracturing operation |
US11255174B2 (en) | 2020-06-24 | 2022-02-22 | Bj Energy Solutions, Llc | Automated diagnostics of electronic instrumentation in a system for fracturing a well and associated methods |
US11512571B2 (en) | 2020-06-24 | 2022-11-29 | Bj Energy Solutions, Llc | Automated diagnostics of electronic instrumentation in a system for fracturing a well and associated methods |
US11220895B1 (en) | 2020-06-24 | 2022-01-11 | Bj Energy Solutions, Llc | Automated diagnostics of electronic instrumentation in a system for fracturing a well and associated methods |
US11506040B2 (en) | 2020-06-24 | 2022-11-22 | Bj Energy Solutions, Llc | Automated diagnostics of electronic instrumentation in a system for fracturing a well and associated methods |
US11668175B2 (en) | 2020-06-24 | 2023-06-06 | Bj Energy Solutions, Llc | Automated diagnostics of electronic instrumentation in a system for fracturing a well and associated methods |
US11692422B2 (en) | 2020-06-24 | 2023-07-04 | Bj Energy Solutions, Llc | System to monitor cavitation or pulsation events during a hydraulic fracturing operation |
US11193360B1 (en) | 2020-07-17 | 2021-12-07 | Bj Energy Solutions, Llc | Methods, systems, and devices to enhance fracturing fluid delivery to subsurface formations during high-pressure fracturing operations |
US11193361B1 (en) | 2020-07-17 | 2021-12-07 | Bj Energy Solutions, Llc | Methods, systems, and devices to enhance fracturing fluid delivery to subsurface formations during high-pressure fracturing operations |
US11920450B2 (en) | 2020-07-17 | 2024-03-05 | Bj Energy Solutions, Llc | Methods, systems, and devices to enhance fracturing fluid delivery to subsurface formations during high-pressure fracturing operations |
US11608727B2 (en) | 2020-07-17 | 2023-03-21 | Bj Energy Solutions, Llc | Methods, systems, and devices to enhance fracturing fluid delivery to subsurface formations during high-pressure fracturing operations |
US11255175B1 (en) | 2020-07-17 | 2022-02-22 | Bj Energy Solutions, Llc | Methods, systems, and devices to enhance fracturing fluid delivery to subsurface formations during high-pressure fracturing operations |
US11365615B2 (en) | 2020-07-17 | 2022-06-21 | Bj Energy Solutions, Llc | Methods, systems, and devices to enhance fracturing fluid delivery to subsurface formations during high-pressure fracturing operations |
US11603744B2 (en) | 2020-07-17 | 2023-03-14 | Bj Energy Solutions, Llc | Methods, systems, and devices to enhance fracturing fluid delivery to subsurface formations during high-pressure fracturing operations |
US11994014B2 (en) | 2020-07-17 | 2024-05-28 | Bj Energy Solutions, Llc | Methods, systems, and devices to enhance fracturing fluid delivery to subsurface formations during high-pressure fracturing operations |
US11867045B2 (en) | 2021-05-24 | 2024-01-09 | Bj Energy Solutions, Llc | Hydraulic fracturing pumps to enhance flow of fracturing fluid into wellheads and related methods |
US11732563B2 (en) | 2021-05-24 | 2023-08-22 | Bj Energy Solutions, Llc | Hydraulic fracturing pumps to enhance flow of fracturing fluid into wellheads and related methods |
US11639654B2 (en) | 2021-05-24 | 2023-05-02 | Bj Energy Solutions, Llc | Hydraulic fracturing pumps to enhance flow of fracturing fluid into wellheads and related methods |
Also Published As
Publication number | Publication date |
---|---|
CA3030110C (en) | 2021-04-13 |
WO2018038710A1 (en) | 2018-03-01 |
CA3030110A1 (en) | 2018-03-01 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
CA3030110C (en) | Systems and methods of optimized pump speed control to reduce cavitation, pulsation and load fluctuation | |
US11415123B2 (en) | Controlled stop for a pump | |
CN111148885B (en) | Downhole oscillation device | |
AU2017441045B2 (en) | Automated pressure control system | |
US11513024B2 (en) | Determining operational health of a pump | |
US5911278A (en) | Calliope oil production system | |
US8789609B2 (en) | Submersible hydraulic artificial lift systems and methods of operating same | |
CN103998783A (en) | Horizontal and vertical well fluid pumping system | |
US20190390538A1 (en) | Downhole Solid State Pumps | |
US20170260820A1 (en) | Method and Apparatus for Suction Monitoring and Control in Rig Pumps | |
Barree | Potential issues with extreme limited entry in horizontal wells | |
US20160060997A1 (en) | Frac head apparatus | |
US11761317B2 (en) | Decoupled long stroke pump | |
Han et al. | Simulation of multiphase fluid-hammer effects during well startup and shut-in | |
CA3081545C (en) | Pump down isolation plug | |
CN104153982A (en) | Method and device for acquiring characteristic curve of rod-pumped well underground system | |
WO2017065912A1 (en) | A flow control and injection arrangement and method | |
RU60616U1 (en) | INSTALLATION FOR SIMULTANEOUSLY SEPARATE INFLATION OF A WORKING AGENT IN TWO PRODUCTIVE LAYERS | |
AU2019309219B2 (en) | Fluid injection valve | |
Oberbichler | Alternative Artificial Lift Systems with Special Focus on Hydraulic Pumps | |
US11060385B2 (en) | Artificial lift system for a resource exploration and recovery system | |
WO2017099878A1 (en) | Wireline-deployed positive displacement pump for wells | |
US20110265999A1 (en) | Reverse torque drive system | |
AU2023233189A1 (en) | Surge control system for managed pressure drilling operations | |
Jensen et al. | Hollow Rods: A Summary of Four Years of Field Experiences of This New Technology for PCP and Tubing-Less Completions |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
AS | Assignment |
Owner name: HALLIBURTON ENERGY SERVICES, INC., TEXAS Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:HEADRICK, DICKEY CHARLES;BEISEL, JOE A.;WEIGHTMAN, GLENN HOWARD;SIGNING DATES FROM 20160824 TO 20160831;REEL/FRAME:047866/0549 |
|
STPP | Information on status: patent application and granting procedure in general |
Free format text: DOCKETED NEW CASE - READY FOR EXAMINATION |
|
STPP | Information on status: patent application and granting procedure in general |
Free format text: NON FINAL ACTION MAILED |
|
STPP | Information on status: patent application and granting procedure in general |
Free format text: RESPONSE TO NON-FINAL OFFICE ACTION ENTERED AND FORWARDED TO EXAMINER |
|
STPP | Information on status: patent application and granting procedure in general |
Free format text: NON FINAL ACTION MAILED |
|
STPP | Information on status: patent application and granting procedure in general |
Free format text: NON FINAL ACTION MAILED Free format text: RESPONSE TO NON-FINAL OFFICE ACTION ENTERED AND FORWARDED TO EXAMINER |
|
STPP | Information on status: patent application and granting procedure in general |
Free format text: RESPONSE TO NON-FINAL OFFICE ACTION ENTERED AND FORWARDED TO EXAMINER |
|
STPP | Information on status: patent application and granting procedure in general |
Free format text: FINAL REJECTION MAILED |
|
STPP | Information on status: patent application and granting procedure in general |
Free format text: RESPONSE AFTER FINAL ACTION FORWARDED TO EXAMINER |
|
STPP | Information on status: patent application and granting procedure in general |
Free format text: ADVISORY ACTION MAILED |
|
STPP | Information on status: patent application and granting procedure in general |
Free format text: DOCKETED NEW CASE - READY FOR EXAMINATION |
|
STPP | Information on status: patent application and granting procedure in general |
Free format text: NON FINAL ACTION MAILED |
|
STPP | Information on status: patent application and granting procedure in general |
Free format text: FINAL REJECTION MAILED |
|
STPP | Information on status: patent application and granting procedure in general |
Free format text: RESPONSE AFTER FINAL ACTION FORWARDED TO EXAMINER |
|
STPP | Information on status: patent application and granting procedure in general |
Free format text: ADVISORY ACTION MAILED |
|
STPP | Information on status: patent application and granting procedure in general |
Free format text: DOCKETED NEW CASE - READY FOR EXAMINATION |
|
STPP | Information on status: patent application and granting procedure in general |
Free format text: NON FINAL ACTION MAILED |
|
STPP | Information on status: patent application and granting procedure in general |
Free format text: RESPONSE TO NON-FINAL OFFICE ACTION ENTERED AND FORWARDED TO EXAMINER |