US20140076577A1 - System and method for reducing pressure fluctuations in an oilfield pumping system - Google Patents

System and method for reducing pressure fluctuations in an oilfield pumping system Download PDF

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Publication number
US20140076577A1
US20140076577A1 US14/007,845 US201214007845A US2014076577A1 US 20140076577 A1 US20140076577 A1 US 20140076577A1 US 201214007845 A US201214007845 A US 201214007845A US 2014076577 A1 US2014076577 A1 US 2014076577A1
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Prior art keywords
port
fluid
junction
chamber
pressure
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Abandoned
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US14/007,845
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English (en)
Inventor
Rod Shampine
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Schlumberger Technology Corp
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Schlumberger Technology Corp
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Priority to US14/007,845 priority Critical patent/US20140076577A1/en
Assigned to SCHLUMBERGER TECHNOLOGY CORPORATION reassignment SCHLUMBERGER TECHNOLOGY CORPORATION ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: SHAMPINE, ROD
Publication of US20140076577A1 publication Critical patent/US20140076577A1/en
Abandoned legal-status Critical Current

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    • 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
    • E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F16—ENGINEERING ELEMENTS AND UNITS; GENERAL MEASURES FOR PRODUCING AND MAINTAINING EFFECTIVE FUNCTIONING OF MACHINES OR INSTALLATIONS; THERMAL INSULATION IN GENERAL
    • F16L—PIPES; JOINTS OR FITTINGS FOR PIPES; SUPPORTS FOR PIPES, CABLES OR PROTECTIVE TUBING; MEANS FOR THERMAL INSULATION IN GENERAL
    • F16L55/00—Devices or appurtenances for use in, or in connection with, pipes or pipe systems
    • F16L55/04—Devices damping pulsations or vibrations in fluids
    • F16L55/041—Devices damping pulsations or vibrations in fluids specially adapted for preventing vibrations
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F16—ENGINEERING ELEMENTS AND UNITS; GENERAL MEASURES FOR PRODUCING AND MAINTAINING EFFECTIVE FUNCTIONING OF MACHINES OR INSTALLATIONS; THERMAL INSULATION IN GENERAL
    • F16L—PIPES; JOINTS OR FITTINGS FOR PIPES; SUPPORTS FOR PIPES, CABLES OR PROTECTIVE TUBING; MEANS FOR THERMAL INSULATION IN GENERAL
    • F16L55/00—Devices or appurtenances for use in, or in connection with, pipes or pipe systems
    • F16L55/04—Devices damping pulsations or vibrations in fluids
    • F16L55/045—Devices damping pulsations or vibrations in fluids specially adapted to prevent or minimise the effects of water hammer
    • F16L55/05—Buffers therefor

Definitions

  • Positive displacement pumps may be employed in applications for accessing underground hydrocarbon reservoirs.
  • positive displacement pumps are often employed in large scale high pressure applications directed at a borehole leading to a hydrocarbon reservoir.
  • Such applications may include cementing, coiled tubing, water jet cutting, or hydraulic fracturing of underground rock.
  • a positive displacement pump such as those described above may be a fairly massive piece of equipment with associated engine, transmission, crankshaft and other parts, operating at between about 200 Hp and about 4,000 Hp.
  • An example of a positive displacement pump, such as triplex or quintuplex pump, is disclosed in commonly assigned PCT Publication No. WO2011/027274, the entire contents of which are hereby incorporated by reference into the current disclosure.
  • a large plunger is driven by the crankshaft toward and away from a chamber in the pump to dramatically affect a high or low pressure thereat. This makes it a good choice for high pressure applications. Indeed, where fluid pressure exceeding a few thousand pounds per square inch (PSI) is to be generated, a positive displacement pump is generally employed. Hydraulic fracturing of underground rock, for example, often takes place at pressures of 6,000 to 20,000 PSI or more to direct an abrasive containing fluid through a borehole such as that noted above to release oil and gas from rock pores for extraction.
  • PSI pounds per square inch
  • a positive displacement pump as described above, a centrifugal pump, or some other form of pump for large scale or ongoing operations, one frequently encounters wellbores and piping rig ups where significant pressure fluctuations/perturbations are created. These perturbations can lead to violent tremors of oilfield equipment, such as trucks and treating line/iron, which potentially cause damage to equipment, failed jobs, and personal injuries, etc.
  • Such pressure fluctuations/oscillations may be caused by a variety of phenomena, for example, resonances in the pumps, failed valves, or obstructions (e.g., rocks) in a plunger/valve.
  • These pressure fluctuations produced by pumps can also interfere with or obscure measurements that are important to the course of a job.
  • gas filled rubber bladders are often applied to both the suction and discharge sides of the mud pumps to reduce the large pressure fluctuations associated with duplex single and double acting pumps. While effective, these dampers are impractical to apply to services where significant abrasives, high pressure, and aggressive fluids are employed. Among other possible problems, the bladders of these systems are subject to deterioration when in contact with abrasive fluids at high, fluctuating pressures.
  • One example of a service where significant abrasive, high pressure, and aggressive fluids are employed may be hydraulic fracturing operations or other portable oilfield pumping operations where positive displacement pumps, such as triplex pumps are commonly used.
  • fracturing fluid is not only effective in breaking up underground rock, but would also tend to wear out an elastomeric bladder used for dampening.
  • the commercially available dampers are only rated up to 10,000 PSI, and would fail rapidly when exposed to the complex acids and hydrocarbons employed in fracturing. Constructing a dampening device for a 15,000 PSI rating would entail radical increases in wall thickness, costly material, and the like. Further, these systems are very limited in the range of gas pre-charge to pumping pressure that they can support. For example, a 3:1 ratio between the pre-charge pressure and the maximum reliable operating pressure represents a desirable ratio.
  • Embodiments of the present disclosure provide a pressure dampening apparatus and method which can dampen pressure perturbations in an oilfield pumping system.
  • certain embodiments disclosed herein address the above and other problems by providing a pressure dampening apparatus and method that does not require the use of a bladder, can be self-adjusting for the optimum operating conditions, and is adapted to be resistant to oilfield chemicals and fluids delivered at high, fluctuating pressures.
  • embodiments of the disclosure relate to a system for reducing pressure fluctuations, comprising: at least one pump directing fluid through a junction having a first port, a second port, and a third port; a chamber coupled to the third port of the junction; and a supply of a compressible medium in fluid communication with the chamber; wherein the supply of compressible medium provides the compressible medium to the chamber so as to form an interface between the fluid and the compressible medium such that a pressure fluctuation of fluid passing through the junction is reduced.
  • embodiments of the disclosure relate to a method for dampening pressure fluctuations in a fluid stream, the method comprising: providing a junction having a first port, a second port, and a third port; connecting the first port to at least one pump, and the second port to a wellbore; connecting a chamber to the third port of the junction; directing a fluid through the junction; supplying a compressible medium to the chamber; and forming an interface between the fluid and the compressible medium so as to reduce a pressure fluctuation in the fluid.
  • embodiments of the disclosure relate to a pressure fluctuation dampening assembly, comprising: a junction having a first port, a second port, and a third port; a chamber coupled to the third port of the junction, and oriented so as to trap gas; and a gas supply tank in fluid communication with the chamber so as to provide gas to the chamber; wherein gas supplied to the chamber forms an interface between a fluid passing through the junction and the gas such that a pressure fluctuation of the fluid is reduced.
  • FIG. 1 illustrates a simplified, schematic view of an oilfield pumping system in accordance with implementations of various technologies and techniques described herein.
  • FIGS. 2A and 2B illustrate schematic views, partially in cross-section, of a junction in fluid communication with the oilfield pumping system in accordance with implementations of various technologies and techniques described herein.
  • FIGS. 3-6 illustrate schematic variations of the oilfield pumping system in accordance with implementations of various technologies and techniques described herein.
  • FIGS. 7-8 illustrate schematic variations of the oilfield pumping system integrated with at least one pump in accordance with implementations of various technologies and techniques described herein.
  • FIG. 9 illustrates a simplified, schematic view of another oilfield pumping system in accordance with implementations of various technologies and techniques described herein.
  • FIG. 10 illustrates a simplified, schematic view of yet another oilfield pumping system in accordance with implementations of various technologies and techniques described herein.
  • FIG. 11 illustrates a schematic view of another oilfield pumping system having multiple pumps in accordance with implementations of various technologies and techniques described herein.
  • FIGS. 12-13 illustrate schematic variations of the oilfield pumping system having multiple dampening chambers in accordance with implementations of various technologies and techniques described herein.
  • FIG. 1 illustrates a simplified, schematic view of an oilfield pumping system 10 for directing fluid to a wellbore 42 .
  • Fluid which may carry oilfield material such as proppant and proppant additives, is pressurized by one or more pumps 12 and directed through a treating line 14 to a pressure dampening device 20 .
  • Pump(s) 12 may include a variety of pumps known in the art, such as positive displacement pumps, crankshaft driven pumps, hydraulic pressure driven pumps, centrifugal pumps, and the like. Pressurizing the fluid with pump(s) 12 inherently creates perturbations or fluctuations in the fluid.
  • the pressure fluctuation dampening assembly, or pressure dampening device 20 is adapted to dampen the perturbations or fluctuations of the fluid.
  • the pressure dampening device 20 comprises a conduit/junction 22 , a dampening chamber 16 , and a fluid/gas supply system 30 .
  • the junction 22 has a first port 23 , a second port 24 and a third port 25 , shown generally in FIG. 1 as a “tee,” but as will be seen hereinafter may comprise various shapes and sizes.
  • the first port 23 acting as an inlet section of the junction 22 receives fluid from the pump(s) 12 via the treating line 14 .
  • the second port 24 acting as an outlet section of the junction 22 is coupled to a treating line 18 for directing fluid to a wellhead 40 or any other means for delivering treatment, such as a cement head or a coiled tubing reel.
  • the third port 25 of the junction 22 leading in a generally upward/vertical direction is coupled to the dampening chamber 16 , which in function acts to reduce the pressure fluctuations of the fluid in coordination with the other elements of the pressure dampening device 20 , but in construction the chamber 16 may be a treating line having a cap 36 at the end.
  • the cap 36 may function as a connection between the chamber 16 and the fluid/gas supply system 30 .
  • the fluid/gas supply system 30 is adapted to supply a compressible medium to the dampening chamber 16 in accordance with the operating conditions (i.e., fluid flow rate, pressure conditions, fluid type, etc.).
  • the compressible medium supplied by the fluid/gas supply system is referred to herein as simply ‘gas’ as a matter of conciseness, but should be understood to also include liquids that are more compressible than the fluid being pumped.
  • Examples of the compressible medium may include nitrogen, argon, air, ethyl alcohol, carbon disulfide, ethyl ether and the like.
  • the fluid/gas supply system 30 comprises a gas pump 32 to pressurize gas supplied by a gas supply tank 34 . Gas may also be supplied to the pressure dampening device 20 by various means.
  • gas may be supplied via a Dewar containing liquefied gas (e.g. liquid nitrogen); moreover, a nitrogen-rich gas may be supplied via a separating membrane in fluid communication with a compressed air tank.
  • a valve 31 may be used as part of the fluid/gas supply system 30 to control the amount of gas supplied by the gas supply tank 34 .
  • the fluid/gas supply system 30 may further comprise at least one check valve 38 along a gas supply line 33 so as to ensure that the fluid does not enter the gas pump 32 .
  • a bleed valve 37 may also be fitted to the cap 36 to drain fluid and/or release pressure built up in the chamber 16 . The bleed valve 37 may be located elsewhere in the system, and should not be limited to the location shown.
  • fluid/gas supply system 30 may also be coupled upstream of the junction 22 so that gas travel along with the fluid and be trapped in the dampening chamber 16 . It should also be noted that the fluid/gas supply system 30 may include boosting means to sufficiently pressurize the gas into the dampening chamber 16 .
  • a sonic choke 50 may optionally be located before or after (the latter is shown) the junction 22 , or even in both locations.
  • the sonic choke 50 which will be described in more detail hereinafter with reference to FIG. 2 , provides additional resistance and reflection to pressure fluctuations in the fluid.
  • FIG. 2A illustrates a schematic view, partially in cross-section, of the junction 22 of FIG. 1 in fluid communication with the oilfield pumping system 10 .
  • Gas is introduced into the dampening chamber 16 to create a gas filled space, referenced as 19 , and a gas to liquid interface 17 .
  • the interface 17 may optionally include an object/device, such as a floating mass or Wier-type device, so as to prevent splashing of the fluid into the chamber 16 and/or lower the resonant frequency of the system.
  • the object/device located at the interface 17 may also be tagged so as to measure the volume of gas/liquid in the chamber 16 .
  • any solids, for example oilfield material, in the fluid 15 flowing from the pump(s) 12 may become entrained in the dampening chamber 16 . Due in part to the orientation of the dampening chamber 16 , gravity will assist any solids in falling out of the dampening chamber 16 and preventing it from being blocked. However, it should be noted that the chamber 16 may be angled in a variety of directions so as to be oriented to trap gas and thereby provide a dampening effect on the pressure fluctuations of the fluid.
  • the sonic choke 50 is shown in more detail here in FIG. 2A connected between the second port 24 of the junction 22 and the treating line 18 leading to a wellbore 42 .
  • the sonic choke 50 functions herein as a differential pressure conduit and may comprise a Venturi having a converging, diverging and throat section (shown herein), an orifice plate, or the like for providing additional reduction to the pressure fluctuations in the fluid 15 .
  • the chamber 16 may be charged using the gas pump 32 as soon as the system pressure has been brought up near the operating pressure.
  • the chamber 16 can be re-charged at any time the treating pressure is reduced significantly and then raised again.
  • a flow of gas into the chamber 16 may be maintained at all times, or during times where the overall pressure is changing significantly. As the interface 17 moves up and down, excess gas may exit the chamber 16 into the junction 22 and flow downstream eventually into the wellbore 42 .
  • the pressure fluctuations of the fluid 15 may vary between 6,500 PSI and 5,500 PSI.
  • the gas 19 in the chamber 16 is compressed, moving the interface 17 towards the cap 36 , thereby reducing the pressure of the fluid 15 at the outlet 24 .
  • the gas 19 in the chamber 16 may compress the fluid, moving the interface 17 towards the junction 22 , and possibly releasing gas into the fluid stream 13 .
  • FIG. 2B illustrates a schematic view, partially in cross-section, of a variation of the junction 22 , wherein the junction 22 comprises a cavity 26 for collecting a certain amount of solids 13 contained in the fluid so as to act as a barrier against any jetting action created by movement of the interface 17 , and further reduce the pressure fluctuation of the fluid 15 .
  • the cavity 26 may also lengthen the overall life of the junction 22 and reduce washout, or erosion of the junction 22 .
  • FIG. 3 illustrates a schematic view of another embodiment of the oilfield pumping system 10 wherein the junction 22 is formed as a lateral so that the flow can be substantially aligned with the direction of the motion of the gas to liquid interface in the chamber 16 , thereby reducing the pressure fluctuations of the fluid.
  • FIG. 4 illustrates a schematic view of yet another embodiment of the oilfield pumping system 10 wherein the junction 22 is formed as a double lateral wherein a cavity section 26 opposes the pressure dampening chamber 16 to further reduce fluctuations.
  • FIG. 5 illustrates a schematic view of another embodiment of the oilfield pumping system 10 wherein the junction 22 is formed as a lateral so that the flow is aligned with the direction of the motion of the gas to liquid interface in the chamber 16 .
  • FIG. 6 illustrates a schematic view of yet another embodiment of the oilfield pumping system 10 wherein the junction 22 is formed as a reversal chamber to reduce erosion due to the change in direction of flow.
  • FIG. 7 illustrates a schematic view of an embodiment of the oilfield pumping system 10 wherein the pressure dampening device 20 is integrated directly to the pump(s) 12 .
  • fluid enters the pump(s) 12 via a suction header 62 .
  • a suction damper 64 may be integrated into the suction header 62 to smooth out the fluctuations of the flow on the suction side.
  • a pump head 66 may contain valves and a plunger system for delivering fluid at a high pressure (higher than the pressure of the fluid entering the suction header 62 ) out of a discharge port, referenced herein as 14 .
  • the pressure dampening device 20 is fitted to the discharge port 14 so as to reduce the pressure fluctuations of the fluid discharged from the pump(s) 12 .
  • the pressure dampening device 20 may be integrated into multiple locations along the oilfield pumping system 10 . While not shown, it should be understood that the pressure dampening device 20 may be integrated into the wellhead 40 , wherein the wellhead 40 is adapted to form the junction 22 coupled to the dampening chamber 16 and gas supply system 30 .
  • FIG. 8 illustrates a schematic view of another embodiment of the oilfield pumping system 10 wherein the pressure dampening device 20 is integrated directly to the pump(s) 12 .
  • the dampening chambers 16 a / 16 b / 16 c are coupled to the discharge covers 68 a / 68 b / 68 c on the pump head 66 .
  • Using more than one chamber 16 reduces the length of the chamber 16 required due to a distribution of pressure fluctuation across multiple chambers 16 a / 16 b / 16 c .
  • locating the pressure dampening device 20 closer to the source of the fluctuations may provide an additional benefit in reducing the overall pressure fluctuations of the system 10 .
  • FIG. 9 illustrates a schematic view of yet another embodiment of the oilfield pumping system 10 wherein the chamber 16 is substantially larger in diameter than the treating line.
  • the pressure dampening device 20 comprises an adapter 27 coupled to the third port 25 so as to allow the installation of the chamber 16 that is substantially larger in diameter than the treating line.
  • FIG. 10 illustrates a simplified, schematic view of an oilfield pumping system 10 wherein the sonic choke 50 is placed upstream of the junction 22 so as to dampen the pressure fluctuations of the fluid prior to forming an interface between the fluid and the gas.
  • FIG. 11 illustrates a schematic view of another embodiment of the oilfield pumping system 10 wherein two groups of pumps direct pressurized fluid through a pressure dampening device 20 having multiple inlets 23 a / 23 b and outlets 24 c / 24 d.
  • One or more sonic chokes 50 a / 50 b / 50 c / 50 d may be place on the inlets 23 a / 23 b and outlets 24 c / 24 d to further dampen the pressure fluctuations.
  • FIGS. 12 and 13 illustrate schematic views of embodiments of the oilfield pumping system 10 depicting a pressure dampening device 20 having multiple dampening chambers 16 a / 16 b / 16 c coupled to the third ports 25 a / 25 b / 25 c of the junctions 22 a / 22 b / 22 c. Similar to the function of the arrangement in FIG. 8 , the array of chambers 16 a / 16 b / 16 c may be employed to reduce the length of the chambers 16 a / 16 b / 16 c.
  • FIG. 12 shows that the gas supply system 30 may be connected to each chamber 16 a / 16 b / 16 c with a common gas supply line 33 . Whereas, FIG.
  • FIG. 13 shows that the gas supply system 30 may be connected to any one of the chambers (shown here as 16 a ), upstream of the junctions 22 b and 22 c such that gas fed into chamber 16 a will be carried by the fluid into the subsequent chambers 16 b and 16 c .
  • a change in elevation of the junctions 22 a / 22 b / 22 c that may aid in distribution of the gas in the chambers 16 a / 16 b / 16 c.
  • junction 22 is shown as having ports and connections with treating line, it should be understood that the junction may be integrated with flow lines to be one piece.
  • gas supply system Accordingly, the foregoing description should not be read as pertaining only to the precise structures described and shown in the accompanying drawings, but rather should be read as consistent with and as support for the following claims, which are to have their fullest and fairest scope.

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  • Engineering & Computer Science (AREA)
  • General Engineering & Computer Science (AREA)
  • Mining & Mineral Resources (AREA)
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  • Life Sciences & Earth Sciences (AREA)
  • Mechanical Engineering (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • Physics & Mathematics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Reciprocating Pumps (AREA)
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US14/007,845 2011-03-29 2012-03-29 System and method for reducing pressure fluctuations in an oilfield pumping system Abandoned US20140076577A1 (en)

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US14/007,845 US20140076577A1 (en) 2011-03-29 2012-03-29 System and method for reducing pressure fluctuations in an oilfield pumping system
PCT/US2012/031323 WO2012135555A2 (fr) 2011-03-29 2012-03-29 Système et procédé pour réduire des fluctuations de pression dans système de pompage de champ pétrolifère

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Cited By (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2016176531A1 (fr) * 2015-04-30 2016-11-03 Schlumberger Technology Corporation Fracturation à l'aide d'un échangeur de pression optimisé
WO2019013612A1 (fr) * 2017-07-12 2019-01-17 Hernandez Sanchez Jorge Angel Dispositif compensant la pression de fluides, pour du matériel de pompage et des systèmes de distribution de fluides
US20190024470A1 (en) * 2017-07-18 2019-01-24 Schlumberger Technology Corporation Choke manifold for drilling and producing a surface wellbore
US11157025B2 (en) 2016-11-04 2021-10-26 Schlumberger Technology Corporation Pressure exchanger manifold resonance reduction
US20220221097A1 (en) * 2016-01-27 2022-07-14 Liberty Oilfield Services Llc Modular configurable wellsite surface equipment
US11460140B2 (en) 2017-10-26 2022-10-04 Performance Pulsation Control, Inc. Mini-dampeners at pump combined with system pulsation dampener
US11473711B2 (en) * 2017-10-26 2022-10-18 Performance Pulsation Control, Inc. System pulsation dampener device(s) substituting for pulsation dampeners utilizing compression material therein
US11591859B2 (en) * 2020-10-12 2023-02-28 Performance Pulsation Control, Inc. Surface equipment protection from borehole pulsation energies

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PL3218632T3 (pl) * 2014-11-10 2020-11-02 Nuovo Pignone S.R.L. Aparat z urządzeniem do tłumienia pulsacji ciśnienia w strumieniu gazu

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US1622843A (en) * 1924-08-16 1927-03-29 Meriam Company Primary gauge stabilizer
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Cited By (9)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2016176531A1 (fr) * 2015-04-30 2016-11-03 Schlumberger Technology Corporation Fracturation à l'aide d'un échangeur de pression optimisé
US20220221097A1 (en) * 2016-01-27 2022-07-14 Liberty Oilfield Services Llc Modular configurable wellsite surface equipment
US11157025B2 (en) 2016-11-04 2021-10-26 Schlumberger Technology Corporation Pressure exchanger manifold resonance reduction
WO2019013612A1 (fr) * 2017-07-12 2019-01-17 Hernandez Sanchez Jorge Angel Dispositif compensant la pression de fluides, pour du matériel de pompage et des systèmes de distribution de fluides
US20190024470A1 (en) * 2017-07-18 2019-01-24 Schlumberger Technology Corporation Choke manifold for drilling and producing a surface wellbore
US10738555B2 (en) * 2017-07-18 2020-08-11 Schlumberger Technology Corporation Choke manifold for drilling and producing a surface wellbore
US11460140B2 (en) 2017-10-26 2022-10-04 Performance Pulsation Control, Inc. Mini-dampeners at pump combined with system pulsation dampener
US11473711B2 (en) * 2017-10-26 2022-10-18 Performance Pulsation Control, Inc. System pulsation dampener device(s) substituting for pulsation dampeners utilizing compression material therein
US11591859B2 (en) * 2020-10-12 2023-02-28 Performance Pulsation Control, Inc. Surface equipment protection from borehole pulsation energies

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WO2012135555A2 (fr) 2012-10-04
WO2012135555A3 (fr) 2012-11-29

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