WO2018038710A1 - Systèmes et procédés de régulation de vitesse de pompe optimisée pour réduire la cavitation, la pulsation et la fluctuation de charge - Google Patents
Systèmes et procédés de régulation de vitesse de pompe optimisée pour réduire la cavitation, la pulsation et la fluctuation de charge Download PDFInfo
- Publication number
- WO2018038710A1 WO2018038710A1 PCT/US2016/048198 US2016048198W WO2018038710A1 WO 2018038710 A1 WO2018038710 A1 WO 2018038710A1 US 2016048198 W US2016048198 W US 2016048198W WO 2018038710 A1 WO2018038710 A1 WO 2018038710A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- primary mover
- characteristic
- pump
- pumping apparatus
- sensor
- Prior art date
Links
- 238000000034 method Methods 0.000 title claims description 18
- 230000010349 pulsation Effects 0.000 title description 5
- 238000005086 pumping Methods 0.000 claims abstract description 62
- 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
- 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
- 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
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
- 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 DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- 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
- 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 DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
- E21B43/2607—Surface equipment specially adapted for fracturing operations
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.
- 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 Figure 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. For example, in one or more embodiments 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.
- 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 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.
- Figure 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 Figure 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 1 10 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 1 10 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 1 12 depending from the surface 106 into the well bore 104.
- the pump and blender system 50 is coupled a work string 1 12 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 1 12 into the subterranean zone 102.
- the working string 1 12 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 1 12 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 1 12 and the well bore wall.
- the working string 1 12 and/or the well bore 104 may include one or more sets of packers 1 14 that seal the annulus between the working string 1 12 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 1 14, 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 Figure 2, the area of the well bore 104 between packers 1 14) at a sufficient hydraulic pressure, one or more fractures 1 16 may be created in the subterranean zone 102.
- the proppant particulates in the fracturing fluid 108 may enter the fractures 1 16 where they may remain after the fracturing fluid flows out of the well bore. These proppant particulates may "prop" fractures 1 16 such that fluids may flow more freely through the fractures 1 16.
- 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.
Abstract
La vitesse d'une pompe peut être régulée pour réduire la cavitation et réduire la fluctuation de débit et de pression dans le fluide pompé. Un système de pompage d'un fluide peut comprendre une pompe, un dispositif de déplacement principal couplé à la pompe, et un dispositif de commande couplé au dispositif de déplacement primaire, le dispositif de commande étant programmé pour commander le dispositif de déplacement primaire de façon à optimiser une caractéristique du système. Le pompage d'un fluide peut comprendre la fourniture d'un appareil de pompage qui comprend une pompe, un dispositif de déplacement principal qui actionne la pompe, et un dispositif de commande qui envoie des commandes au dispositif de déplacement principal. Une ou plusieurs caractéristiques de l'appareil de pompage peuvent être utilisées pour modifier la vitesse de la pompe.
Priority Applications (3)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
CA3030110A CA3030110C (fr) | 2016-08-23 | 2016-08-23 | Systemes et procedes de regulation de vitesse de pompe optimisee pour reduire la cavitation, la pulsation et la fluctuation de charge |
PCT/US2016/048198 WO2018038710A1 (fr) | 2016-08-23 | 2016-08-23 | Systèmes et procédés de régulation de vitesse de pompe optimisée pour réduire la cavitation, la pulsation et la fluctuation de charge |
US16/314,032 US20200049153A1 (en) | 2016-08-23 | 2016-08-23 | Systems and methods of optimized pump speed control to reduce cavitation, pulsation and load fluctuation |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
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PCT/US2016/048198 WO2018038710A1 (fr) | 2016-08-23 | 2016-08-23 | Systèmes et procédés de régulation de vitesse de pompe optimisée pour réduire la cavitation, la pulsation et la fluctuation de charge |
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WO2018038710A1 true WO2018038710A1 (fr) | 2018-03-01 |
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PCT/US2016/048198 WO2018038710A1 (fr) | 2016-08-23 | 2016-08-23 | Systèmes et procédés de régulation de vitesse de pompe optimisée pour réduire la cavitation, la pulsation et la fluctuation de charge |
Country Status (3)
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US (1) | US20200049153A1 (fr) |
CA (1) | CA3030110C (fr) |
WO (1) | WO2018038710A1 (fr) |
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