EP3066295A1 - Système et méthodologie d'alimentation en diluant - Google Patents

Système et méthodologie d'alimentation en diluant

Info

Publication number
EP3066295A1
EP3066295A1 EP14859419.5A EP14859419A EP3066295A1 EP 3066295 A1 EP3066295 A1 EP 3066295A1 EP 14859419 A EP14859419 A EP 14859419A EP 3066295 A1 EP3066295 A1 EP 3066295A1
Authority
EP
European Patent Office
Prior art keywords
diluent
tubing
control unit
recited
flow control
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.)
Withdrawn
Application number
EP14859419.5A
Other languages
German (de)
English (en)
Other versions
EP3066295A4 (fr
Inventor
Dinesh Patel
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Services Petroliers Schlumberger SA
Schlumberger Technology BV
Schlumberger Holdings Ltd
Original Assignee
Services Petroliers Schlumberger SA
Schlumberger Technology BV
Schlumberger Holdings Ltd
Priority date (The priority date 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 date listed.)
Filing date
Publication date
Application filed by Services Petroliers Schlumberger SA, Schlumberger Technology BV, Schlumberger Holdings Ltd filed Critical Services Petroliers Schlumberger SA
Publication of EP3066295A1 publication Critical patent/EP3066295A1/fr
Publication of EP3066295A4 publication Critical patent/EP3066295A4/fr
Withdrawn legal-status Critical Current

Links

Classifications

    • 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
    • E21B43/121—Lifting well fluids
    • E21B43/128—Adaptation of pump systems with down-hole electric drives
    • 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
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/12—Packers; Plugs
    • 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
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/12—Packers; Plugs
    • E21B33/126—Packers; Plugs with fluid-pressure-operated elastic cup or skirt
    • 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
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in wells
    • 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
    • E21B37/00—Methods or apparatus for cleaning boreholes or wells
    • E21B37/06—Methods or apparatus for cleaning boreholes or wells using chemical means for preventing or limiting, e.g. eliminating, the deposition of paraffins or like substances
    • 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
    • E21B2200/00—Special features related to earth drilling for obtaining oil, gas or water
    • E21B2200/04—Ball valves

Definitions

  • Hydrocarbon fluids such as oil and natural gas are obtained from a subterranean geologic formation, referred to as a reservoir, by drilling a well that penetrates the hydrocarbon-bearing formation. Once a wellbore is drilled, various forms of casing and other well completions may be deployed downhole. Sometimes, completion systems employ or work in cooperation with an electric submersible pumping system which may be used to pump oil or other hydrocarbon fluids to a collection location. In some environments, the fluids may be of relatively high viscosity and can thus inhibit pumping of the fluid via the electric submersible pumping system.
  • a system and methodology are provided for facilitating various well operations by delivering a diluent to a desired location in a borehole.
  • a completion system may be disposed in the borehole and a diluent flow path is routed along an interior of the completion system to a desired location.
  • the diluent is delivered to an artificial lift system, e.g. an electric submersible pumping system, to dilute a fluid being produced.
  • a flow control unit is positioned along the diluent flow path and may be selectively actuated to control flow of the diluent to the desired location.
  • Figure 1 is a schematic illustration of an example of a well system deployed in a borehole, according to an embodiment of the disclosure
  • Figure 2 is a cross-sectional illustration of an example of a flow control unit which may be used in a well system of the type illustrated in Figure 1 , according to an embodiment of the disclosure;
  • Figure 3 is a cross-sectional illustration similar to that of Figure 2 but showing the flow control unit in a different operational position, according to an embodiment of the disclosure
  • Figure 4 is a cross-sectional illustration of another example of a flow control unit which may be used in a well system of the type illustrated in Figure 1 , according to an embodiment of the disclosure;
  • Figure 5 is a cross-sectional illustration similar to that of Figure 4 but showing the flow control unit in a different operational position, according to an embodiment of the disclosure
  • Figure 6 is a cross-sectional illustration of another example of a flow control unit which may be used in a well system of the type illustrated in Figure 1 , according to an embodiment of the disclosure;
  • Figure 7 is a cross-sectional illustration similar to that of Figure 6 but showing the flow control unit in a different operational position, according to an embodiment of the disclosure
  • Figure 8 is a cross-sectional illustration of another example of a flow control unit which may be used in a well system of the type illustrated in Figure 1 , according to an embodiment of the disclosure.
  • Figure 9 is a cross-sectional illustration similar to that of Figure 8 but showing the flow control unit in a different operational position, according to an embodiment of the disclosure.
  • the disclosure herein generally involves a system and methodology which facilitate various well operations by delivering a diluent to a desired location in a borehole.
  • the diluent may be delivered downhole to mix with a production fluid prior to pumping the production fluid to a collection location.
  • the diluent can help reduce the viscosity of the production fluid (or other well fluid) to facilitate pumping of the fluid to the desired collection location.
  • the diluent may comprise various types of substances selected to change other characteristics of the well fluid which is then pumped or otherwise moved to the collection location.
  • a completion system may be disposed in a borehole, e.g. a wellbore.
  • a diluent tubing is used to create a diluent flow path routed along an interior of the completion system to a desired location.
  • the diluent is delivered to an artificial lift system, e.g. an electric submersible pumping system, to dilute a fluid being produced or otherwise moved to a collection location.
  • a flow control unit is positioned along the diluent flow path and may be selectively actuated to control flow of the diluent to the desired location, e.g. a downhole mixing location.
  • a well system 20 is illustrated as deployed in a borehole 22, e.g. a wellbore.
  • the well system 20 comprises a diluent delivery system 24 which is positioned in the borehole 22 to deliver a diluent 26 to a desired location 28.
  • the diluent 26 is mixed with a well fluid 30 so as to adjust the characteristics of the well fluid 30.
  • the diluent 26 may be used to lower the viscosity of the well fluid 30 to facilitate transfer of the well fluid to a desired collection location, e.g. a surface collection location.
  • the well system 20 further comprises an artificial lift system 32 which intakes both the diluent 26 and the well fluid 30 so as to transfer, e.g. produce, a mixture 34 of the well fluid 30 and diluent 26 to the collection location.
  • well system 20 may comprise a wellbore casing 36 having, for example, a primary casing 38 and a liner 40 suspended from the primary casing 38.
  • a lower completion 42 is run downhole into the borehole 22 and suspended within liner 40.
  • the lower completion 42 may be run downhole via a surface rig.
  • lower completion 42 and the overall well system 20 may comprise a wide variety of components and systems.
  • lower completion 42 may comprise a sand control packer 44, a sand screen or a plurality of sand screens 46, and zonal isolation packers 48.
  • well fluid e.g. oil
  • sand screens 46 In production applications, well fluid, e.g. oil, flows from a surrounding formation 50 and into the lower completion 42 through sand screens 46.
  • an upper completion 52 is engaged with lower completion 42.
  • the upper completion 52 may be run downhole simultaneously with lower completion 42; or the upper completion 52 may be run downhole in a subsequent operation for engagement with the pre-positioned lower completion 42.
  • the upper completion 52 also may comprise a variety of components and systems depending on the parameters of a given well operation.
  • the upper completion 52 may comprise a tubing 54, e.g. production tubing through which the well fluid entering via sand screens 46 may be produced to a surface location or other suitable location.
  • the upper completion 52 may comprise a variety of valves, such as inflow control valves 56, chemical injection valves 58, ball valves 60, safety valves 62, an/or other types of valves.
  • valves such as inflow control valves 56, chemical injection valves 58, ball valves 60, safety valves 62, an/or other types of valves.
  • other components of upper completion 52 comprise a production packer 64 which may be sealed against casing 36, e.g. against an internal surface of liner 40.
  • the upper completion 52 also may comprise a seal assembly and/or sand control packer 66.
  • various other and/or additional components and systems may be used by one or both of the lower completion 42 and upper completion 52.
  • the artificial lift system 32 is deployed down into the upper completion 52, e.g. into the tubing 54.
  • the artificial lift system 32 may comprise an electric submersible pumping system 68 having an intake 70 for receiving both the well fluid 30 and the diluent 26 at location 28.
  • the electric submersible pumping system 68 may comprise a variety of components, such as a submersible pump 72, a motor 74 for powering the submersible pump 72, a motor protector or seal section 76, and a discharge 78.
  • the mixture 34 of well fluid 30 and diluent 26 is discharged through the discharge 78 and into an interior 80 of tubing 54 above a packer 82.
  • the packer 82 forms a seal between the electric submersible pumping system 68 and the surrounding tubing 54.
  • a power cable 83 may be routed from the surface and used to supply electrical power to motor 74.
  • the diluent delivery system 24 also may comprise a variety of
  • the diluent delivery system 24 comprises a diluent tubing 84 which establishes a diluent flow path appropriately routed to deliver diluent 26 to the artificial lift system 32, e.g to the electric submersible pumping system 68.
  • the diluent flow path is separate from the well fluid flow path along which the mixture 34 of well fluid 30 and diluent 26 travels to the desired collection location.
  • the diluent tubing 84 may be disposed within tubing 54 such that the diluent tubing 84 extends to a surface location along the interior of tubing 54.
  • the diluent tubing 84 may be in the form of a conveyance coupled to the artificial lift system 32, thus allowing the diluent tubing 84 to be used for delivering the artificial lift system 32 downhole to the desired location within tubing 54.
  • the diluent flow path also is routed along a packer pass through 86 which allows the diluent to flow through the packer 82 to the desired location 28.
  • the diluent delivery system 24 further comprises a flow control unit 88 positioned along the diluent flow path, e.g. along diluent tubing 84.
  • the flow control unit 88 is operable to control the flow of diluent 26.
  • the flow control unit 88 may be actuated to selectively allow or prevent flow of diluent 26 along the diluent flow path.
  • the flow control unit 88 may be selectively actuated via application of a sufficient pressure differential to the flow control unit 88.
  • Flow control unit 88 is mounted along the flow path for diluent 26 and, in the illustrated embodiment, the flow control unit 88 is mounted along diluent tubing 84.
  • the flow control unit 88 may comprise a mounting structure 90 which engages sections of the diluent tubing 84 via a suitable fastening mechanism 92, e.g. threaded regions or other suitable fastening mechanisms.
  • the mounting structure 90 further comprises a flow port or flow ports 94.
  • a spring-loaded seal element 96 such as a cup packer, may be coupled with or positioned in cooperation with mounting structure 90.
  • the spring-loaded seal element 96 comprises a resilient sealing portion 98 and a spring portion 100 which biases the sealing portion 98 toward an inside surface of diluent tubing 84.
  • the spring-loaded seal element/cup packer 96 is oriented to block flow in the direction of arrows 102 when, for example, the pumping of diluent 26 from a surface location is stopped (see Figure 2). However, when a sufficient differential pressure is established across the flow control unit 88 the resilient sealing portion 98 is flexed to an open flow position so that diluent 26 may flow through ports 94 and past the spring- loaded seal element 96, as illustrated in Figure 3 and as represented by arrows 104.
  • the pressure differential may be established by increasing the pressure of diluent 26 in diluent tubing 84 above flow control unit 88 via, for example, a surface diluent pumping system.
  • the spring-loaded seal element 96 is forced to the open flow position.
  • the spring-loaded seal element 96 may be constructed to transition to the open flow position upon exposure to a sufficient pressure differential (PI - P2).
  • PI - P2 a sufficient pressure differential
  • the flow control unit 88 is actuated to an open flow position to allow flow of diluent 26 to the desired location 28.
  • the set point may vary depending on the parameters of a given application. In some embodiments, the set point may be in the range of 250-1000 psi or in a narrower range such as 450-550 psi. However, other applications may utilize other pressure differentials/set points for actuation of the flow control unit 88 between operational positions.
  • FIG. 4 and 5 another embodiment of the flow control unit 88 is illustrated.
  • This embodiment is similar to the embodiment illustrated in Figures 2 and 3, but an inflatable packer 106 is used in place of the spring-loaded seal element 96.
  • the inflatable packer 106 comprises a sealing element 108 which may be expanded to sealingly engage the diluent tubing 84 along an interior of the diluent tubing.
  • the sealing element 108 may be coupled with a pair of base members 110 which are mounted on mounting structure 90 and sealed thereto via a plurality of seals 112.
  • One of the base members 110 may be fixed while the other base member 110 may be floating to enable transition between closed and open flow positions, as illustrated in Figure 4 and Figure 5, respectively.
  • mounting structure 90 comprises an internal cavity
  • the internal cavity 114 which contains a pressurized fluid 116 used to inflate sealing element 108 through a port 117.
  • the internal cavity 114 may be closed to contain the pressurized fluid 116, or the pressurized fluid 116 may be supplied via a suitable control line or other source of supply. Consequently, the actuation of flow control unit 88 is affected by pressure (PI) on one side, pressure (P3) on the opposite side, and pressure (P2) within internal cavity 114 and inside sealing element 108.
  • the sealing element 108 is forced inwardly to the open flow position by spreading the base members 110, as illustrated in Figure 5.
  • the sealing element 108 may be constructed to transition to the open flow position upon exposure to a sufficient pressure differential (PI - P2).
  • the pressure (P2) within cavity 114 and within sealing element 108 is adjustable to enable adjustment of the pressure differential or set point at which the sealing element 108 transitions from the closed position ( Figure 4) to the open flow position ( Figure 5).
  • the flow control unit 88 is selectively transitioned to the open flow position when the pressure differential (PI - P3) is greater than the predetermined set point.
  • FIG. 6 and 7 another embodiment of the flow control unit 88 is illustrated.
  • This embodiment is similar to the embodiment illustrated in Figures 4 and 5, but an inflatable balloon 118 is used in place of the inflatable packer 106.
  • the inflatable balloon 118 comprises a sealing element 120 having a slidable end 122 which may slide along mounting structure 90 similar to the movable base member 110.
  • the slidable end 122 is able to float which enables transition between closed and open flow positions, as illustrated in Figure 6 and Figure 7, respectively.
  • a balloon support 123 may be located at the fixed end of the sealing element 120 along mounting structure 90.
  • the sealing element 120 comprises an internal cavity 124 which may be inflated to a desired pressure P3 so as to establish a desired pressure differential/set point at which the flow control unit 88 is transitioned between closed and open flow positions.
  • the actuation of flow control unit 88 is affected by pressure (PI) on one side and pressure (P2) on the opposite side of the flow control unit 88.
  • PI pressure
  • P2 pressure
  • the sealing element 120 is forced inwardly to the open flow position by shifting the slidable end 122, as illustrated in Figure 7.
  • the pressure (P3) within internal cavity 124 of sealing element 120 is selected to establish a desired pressure differential or set point at which the sealing element 120 transitions from the closed position ( Figure 6) to the open flow position ( Figure 7).
  • the flow control unit 88 is selectively transitioned to the open flow position when the pressure differential (PI - P2) is greater than the predetermined set point.
  • FIG. 8 another embodiment of the flow control unit 88 is illustrated.
  • flow of diluent 26 is controlled by a ball valve 126 positioned along the diluent flow path, e.g. along diluent tubing 84.
  • the ball valve 126 may be mounted in a ball valve housing 128 and selectively actuated, e.g. pivoted, via a ball valve operator 130 slidably mounted in a chamber 132 of ball valve housing 128.
  • the ball valve operator 130 comprises a piston 134 sealably engaging an inside surface defining chamber 132 via a suitable seal 136.
  • a spring 138 acts against piston 134 to bias the ball valve operator 130 and thus the ball valve 126 to a closed position, as illustrated in Figure 8.
  • a pressure relief valve 140 may be positioned within a ball 142 of ball valve 126.
  • spring 138 biases ball valve operator 130 and ball valve 126 to the closed position when the artificial lift system 32, e.g. electric
  • submersible pumping system 68 is off.
  • the electric submersible pumping system 68 When the electric submersible pumping system 68 is turned on and operated, the fluid discharged into tubing 54 via discharge 78 establishes a discharge pressure (Pd) which acts on piston 134 via a port 144 extending through the ball valve housing 128.
  • the port 144 is positioned on a side of piston 134 opposite spring 138 so as to operate against the spring.
  • another port 146 is located through ball valve housing 128 on an opposite side of piston 134.
  • the port 146 is exposed to an electric submersible pumping system intake pressure (Pi) via a passageway 148, e.g. tubing, routed to an intake side of the packer 82.
  • a passageway 148 e.g. tubing
  • one side of piston 134 is exposed to a reduced intake pressure (Pi) and the other side of the piston 134 is exposed to an increased discharge pressure (Pd) when the electric submersible pumping system 68 is operated.
  • Pd - Pi When the pressure differential (Pd - Pi) reaches a predetermined or set level, the force exerted by spring 138 is overcome and piston 134 is shifted.
  • Pressure relief valve 140 may be constructed to allow flow through ball valve 126 once ball valve 126 is in an open position and after a pressure differential acting on pressure relief valve 140 rises above a predetermined or set level. Additionally, pressure relief valve 140 may be constructed as a check valve which prevents back flow through the ball valve 126.
  • the diluent 26 flows along the diluent flow path to the desired location 28.
  • the diluent 26 flows down through diluent tubing 84, through ball valve 126, through packer 82 via packer pass through passages 86, and then to the desired location 28 at the intake of electric submersible pumping system 68. If the electric submersible pumping system 68 is shut off, then Pd equals Pi and spring 138 once again shuts the ball valve 126 to block flow of diluent 26.
  • the diluent delivery system 24 may have a variety of configurations.
  • the diluent delivery system 24 may be operated with no control line from the surface.
  • Embodiments of diluent delivery system 24 also prevent uncontrolled flow of diluent injection by effectively providing check valve functionality. In other words, no diluent 26 is discharged from the diluent tubing 84 when the surface system is not pumping diluent 26.
  • the system when the surface system is pumping diluent 26 downhole to the desired location 28, the system is able to provide a back pressure which prevents sucking of the diluent 26 into the formation 50 or into the electric submersible pumping system 68 if not desired.
  • a variety of diluent surface systems may be used to provide a desired flow rate of the diluent 26 with an appropriately limited surface supply pressure.
  • the overall well system 20 may have a variety of components and configurations.
  • the lower completion 42 and the upper completion 52 may have many types of components, sizes, and/or configurations.
  • the lower completion and upper completion may be combined into a single completion conveyed downhole as a single unit.
  • additional completions may be used to perform a desired well operation.
  • the diluent delivery system may be used in production operations and in other well servicing operations, e.g. injection operations. Additionally, artificial lift systems other than electric submersible pumping systems may be used in some applications.
  • the type of diluent and the flow path for delivering diluent to the desired location in a given borehole also may be selected or changed according to the parameters of a given application.

Landscapes

  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Mining & Mineral Resources (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • Physics & Mathematics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Chemical & Material Sciences (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • General Chemical & Material Sciences (AREA)
  • Structures Of Non-Positive Displacement Pumps (AREA)
  • Control Of Non-Positive-Displacement Pumps (AREA)

Abstract

L'invention concerne une technique facilitant diverses opérations de puits en délivrant un diluant dans un emplacement souhaité dans un trou de forage. Un système d'achèvement peut être disposé dans le trou de forage et un trajet d'écoulement de diluant est acheminé le long d'un intérieur du système d'achèvement à un emplacement souhaité. Dans certaines applications, le diluant est délivré à un système de levage artificiel, par exemple, un système de pompage submersible électrique, pour diluer un fluide étant produit. Une unité de régulation de débit est positionnée le long du trajet d'écoulement de diluant et peut être sélectivement actionnée pour réguler l'écoulement du diluant vers l'emplacement souhaité.
EP14859419.5A 2013-11-08 2014-11-07 Système et méthodologie d'alimentation en diluant Withdrawn EP3066295A4 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US201361901762P 2013-11-08 2013-11-08
PCT/US2014/064457 WO2015069968A1 (fr) 2013-11-08 2014-11-07 Système et méthodologie d'alimentation en diluant

Publications (2)

Publication Number Publication Date
EP3066295A1 true EP3066295A1 (fr) 2016-09-14
EP3066295A4 EP3066295A4 (fr) 2016-11-30

Family

ID=53042108

Family Applications (1)

Application Number Title Priority Date Filing Date
EP14859419.5A Withdrawn EP3066295A4 (fr) 2013-11-08 2014-11-07 Système et méthodologie d'alimentation en diluant

Country Status (3)

Country Link
US (1) US20160290111A1 (fr)
EP (1) EP3066295A4 (fr)
WO (1) WO2015069968A1 (fr)

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CN110219621A (zh) * 2019-06-21 2019-09-10 陈俊丽 一种油田井口多级耦合降粘装置
US11634975B2 (en) * 2019-08-28 2023-04-25 Liquid Rod Lift, LLC Method and apparatus for producing well fluids

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Also Published As

Publication number Publication date
EP3066295A4 (fr) 2016-11-30
US20160290111A1 (en) 2016-10-06
WO2015069968A1 (fr) 2015-05-14

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