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WO2016094053A1 - Complétion esp de puits horizontal à court rayon - Google Patents

Complétion esp de puits horizontal à court rayon Download PDF

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Publication number
WO2016094053A1
WO2016094053A1 PCT/US2015/061730 US2015061730W WO2016094053A1 WO 2016094053 A1 WO2016094053 A1 WO 2016094053A1 US 2015061730 W US2015061730 W US 2015061730W WO 2016094053 A1 WO2016094053 A1 WO 2016094053A1
Authority
WO
WIPO (PCT)
Prior art keywords
pump
pumping system
motor
well
length
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.)
Ceased
Application number
PCT/US2015/061730
Other languages
English (en)
Inventor
Ryan Cox
Colin DREVER
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.)
Schlumberger Canada Ltd
Services Petroliers Schlumberger SA
Schlumberger Technology BV
Schlumberger Technology Corp
Original Assignee
Schlumberger Canada Ltd
Services Petroliers Schlumberger SA
Schlumberger Technology BV
Schlumberger Technology Corp
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 Schlumberger Canada Ltd, Services Petroliers Schlumberger SA, Schlumberger Technology BV, Schlumberger Technology Corp filed Critical Schlumberger Canada Ltd
Publication of WO2016094053A1 publication Critical patent/WO2016094053A1/fr
Anticipated expiration legal-status Critical
Ceased legal-status Critical Current

Links

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
    • F04D13/00—Pumping installations or systems
    • F04D13/02—Units comprising pumps and their driving means
    • F04D13/06—Units comprising pumps and their driving means the pump being electrically driven
    • F04D13/08—Units comprising pumps and their driving means the pump being electrically driven for submerged use
    • F04D13/10—Units comprising pumps and their driving means the pump being electrically driven for submerged use adapted for use in mining bore holes
    • 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
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
    • F04D—NON-POSITIVE-DISPLACEMENT PUMPS
    • F04D13/00—Pumping installations or systems
    • F04D13/12—Combinations of two or more pumps

Definitions

  • a submersible pumping system such as an electrical submersible pump (ESP) system
  • ESP electrical submersible pump
  • ESP systems can include various other components, such as a motor and a motor protector.
  • a typical submersible pumping system comprises several components, such as a submersible electric motor that supplies energy to a submersible pump.
  • the system may further comprise a variety of additional components, such as a motor protector and/or a connector used to connect the submersible pumping system to a deployment system.
  • Conventional deployment systems include production tubing, cable, and coiled tubing.
  • ESPs can be utilized in a variety of wellbore configurations, including deviated wellbores.
  • a deviated wellbore is a wellbore that has been intentionally turned from its natural path. Deviated wellbores may be created using various methods, such as, for example, directional drilling techniques. Setting or running an ESP assembly through a deviated or curved section of a wellbore can induce bending moments on the components that make up the ESP assembly.
  • ESPs When fully assembled, ESPs may range in length from, for example, 8 to 25 meters.
  • a length of an ESP, as used herein, is meant to generally describe a sum of the lengths of the components of an ESP.
  • a wellbore pumping system includes a first pumping system and a second pumping system having an outlet in fluid communication with the intake of the first pumping system.
  • a well system in accordance to one or more aspects of the disclosure includes a first pumping system located in a lower portion of a well and a second pumping system located in an upper portion of the well.
  • a method includes driving a first pump located in a horizontal wellbore section of a well, pumping a fluid from the horizontal wellbore section into a vertical wellbore section in response to driving the first pump and driving a second pump located in the vertical wellbore section and thereby producing the fluid to a surface of the well.
  • Figure 1 illustrates a steam assisted gravity drainage well system incorporating a short radius electric submersible pump in accordance to one or more aspects of the disclosure.
  • Figure 2 illustrates an example of an electric submersible pump system according to one or more aspects of the disclosure.
  • Figure 3 illustrates a well system utilizing is a short radius electric submersible pump in accordance to one or more aspects of the disclosure.
  • connection, connection, connected, in connection with, and connecting may be used to mean in direct connection with or in connection with via one or more elements.
  • couple, coupling, coupled, coupled together, and coupled with may be used to mean directly coupled together or coupled together via one or more elements.
  • Terms such as up, down, top and bottom and other like terms indicating relative positions to a given point or element are may be utilized to more clearly describe some elements. Commonly, these terms relate to a reference point such as the surface from which drilling operations are initiated.
  • FIG. 1 illustrates a steam assisted gravity drainage (SAGD) well system 10 according to one or more embodiments.
  • Well system 10 includes a steam injection well 12 and a production well 14 drilled from the surface 16 into a reservoir formation 18.
  • Each of the wells includes a substantially vertical wellbore section 20 that turns at a bend or dogleg 22 into a horizontal wellbore section 24. It will be understood by those skilled in the art that reference to a the vertical wellbore section 20 includes sections that may deviate from an absolute vertical, as illustrated by the "Z" axis extending in the direction of gravity.
  • the horizontal wellbore section 24 may deviate from being parallel to a horizontal direction, as illustrated by the "X" axis extending perpendicular to the direction of gravity and still be a horizontal wellbore.
  • dogleg 22 is a short radius turn from the substantially vertical wellbore section 20 of the production well 14 to the substantially horizontal wellbore section 24.
  • the horizontal sections 24 of the respective wells 12, 14 may be positioned in close proximity to one another and aligned with one substantially vertically over the other.
  • a downhole steam generator 26 is shown disposed in the steam-injection well 12.
  • the steam generator 26 generates steam in the injection well 12, for example, based on supplies of water and fuel from surface conduits. While a downhole steam generator is shown, steam may be alternatively, or additionally, generated at the surface.
  • a desirable resource such as heavy oil.
  • Arrows 28 indicate steam passing into the reservoir formation. As the resource is heated, its viscosity decreases, allowing it to flow more readily to the production well 14.
  • Arrows 30 indicate resources flowing into the production well 14.
  • the production well 14 is shown utilizing a pair of downhole pumps or pumping systems, generally denoted by the numeral 32, to produce the resource, i.e., reservoir or well fluid 30, to the surface.
  • the downhole pumping systems are generally identified with the numeral 32 and individual as 32-1 and 32-2 for the purpose of description.
  • a first or lower pump 32-1 is positioned in the horizontal wellbore section 24.
  • the lower pump 32-1 will drawdown pressure in the horizontal wellbore section and pump the fluid 30 toward the surface.
  • a second or upper pump 32-2 is positioned in the vertical wellbore section 20 with its intake in fluid communication with the discharge of the lower pump 32-1.
  • the upper pump 32-2 will produce the fluid 30 to the surface 16.
  • the lower pump 32-1 may be sized with a reduced length so as to pass through dogleg 22 and or to reduce the bending moments applied to the lower pump 32-1 as it is moved through the dogleg so that it can be positioned in the horizontal wellbore section to maximize drawdown and enhance the productivity of the well, i.e., reservoir.
  • each of the pump systems is an electrical submersible pump system which may have gas handling features.
  • FIG. 2 illustrates an example of a downhole pumping system 32 in accordance to one or more aspects of the disclosure.
  • the depicted downhole pumping system 32 is an electric submersible pump or pumping (ESP) system.
  • the depicted ESP system 32 is shown deployed in a well 14 (i.e., wellbore) and includes a pump 34 having an intake 36 and a discharge 37, and a motor 38 coupled to the pump (mechanically, magnetically, or otherwise) to drive the pump.
  • the pump 34 may be deployed on a conveyance or conduit 40 that is connected for example to the discharge 37 of the pump.
  • the motor 38 may be connected for example via a cable 42 to an electrical power source 44 and surface controller 46.
  • the pump 34 may include a gas handling device 48 such as impellers for mixing the gas and liquid content to reduce the formation of gas bubbles, which are known to cause gas lock.
  • the pumping system 32 may include a motor protector 50 connected between the motor and the pump.
  • the protector for example, may be but is not limited to, a labyrinth-type protector, elastomer bag, piston protector, bellows, and/or gas chamber or positive pressure protector.
  • the protector may provide the capability of compensating volume changes due to thermal expansion of the oil in the motor, isolating the motor oil from the wellbore fluids (water, hydrocarbons) and sealing the motor from the fluids in the pump.
  • the protector e.g. a seal section, may also carry the axial load of the pump such as via thrust bearings in connection with the motor.
  • the pumping system 32 illustrated in Figure 2 includes a monitoring device or tool 52 connected for example with the motor to be deployed in the wellbore.
  • the monitoring tool 52 may include sensors for detecting conditions of the pumping system and the wellbore.
  • the monitoring tool 52 may include for example a pressure sensor, temperature sensor, a flow meter, and a vibration sensor.
  • the monitoring tool may be in communication with a surface controller for example through wireless communication or for example through a cable.
  • FIG. 3 illustrates a well system 10 in accordance to one or more aspects of the disclosure.
  • Well system 10 includes a well 14, e.g., wellbore, extending from a surface 16 in to a reservoir formation 18.
  • Well 14 has a vertical wellbore section 20 extending downward from surface 16 and a horizontal wellbore section 24.
  • the well is completed with a first or lower pumping system 32-1 deployed in the horizontal wellbore section 24 and a second pumping system 32-2 deployed in the vertical wellbore section 20 above the dogleg 22.
  • the dogleg 22 is a short radius curve.
  • the upper pump 32-2 has a length 54 which is longer than the length 56 of the lower pump 32-1.
  • the upper pumping system 32-2 is deployed in the vertical wellbore section 20 with a conveyance or conduit 40, e.g., tubing, that is hung for example from a wellhead 62.
  • the pumping system 32-2 produces fluids to the surface.
  • the lower pumping system 32-1 is deployed in the horizontal wellbore section 24 for example on a conveyance or conduit 58, e.g., tubular, which conducts the wellbore fluid 30 from the discharge 37 of the pumping system 32-1 via conduit 58 to the upper pumping system 32-2.
  • the wellbore is completed with a barrier 60, e.g. packer, in the vertical wellbore section 20 above the dogleg 22.
  • the lower pumping system 32-1 is hung from the barrier 60 by the conduit 58. In operation the lower pumping system 32-1 draws down the pressure in the horizontal wellbore section and pumps the reservoir fluid 30 from the horizontal wellbore section 24 through conduit 58 to the intake 36 of the upper pumping system 32-1 above the barrier 60.
  • the length 56 of the lower pumping system 32-1 is shorter than the length 54 of the upper pumping system 32-2. Reducing the length of the lower pumping system reduces a likelihood that the ESP will be damaged from bending moments when passing through the dogleg and provides for positioning a pump in the horizontal section to achieve a desired reservoir drawdown.
  • the upper pumping system is described with reference to Figure 3 as being longer than the lower pumping system, the upper and lower pumping systems may have the same length or the lower pump may be longer.

Landscapes

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

Abstract

Système de puits comprenant un premier système de pompage situé dans une section de puits de forage horizontale et un second système de pompage est situé dans une section de puits de forage verticale. Le premier système de pompage pompe un fluide depuis la section de puits de forage horizontale jusque dans la section de puits de forage verticale et le second système de pompage produit le fluide jusqu'à la surface.
PCT/US2015/061730 2014-12-10 2015-11-20 Complétion esp de puits horizontal à court rayon Ceased WO2016094053A1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US201462090050P 2014-12-10 2014-12-10
US62/090,050 2014-12-10

Publications (1)

Publication Number Publication Date
WO2016094053A1 true WO2016094053A1 (fr) 2016-06-16

Family

ID=56107938

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/US2015/061730 Ceased WO2016094053A1 (fr) 2014-12-10 2015-11-20 Complétion esp de puits horizontal à court rayon

Country Status (1)

Country Link
WO (1) WO2016094053A1 (fr)

Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5154588A (en) * 1990-10-18 1992-10-13 Oryz Energy Company System for pumping fluids from horizontal wells
US6325143B1 (en) * 1999-01-04 2001-12-04 Camco International, Inc. Dual electric submergible pumping system installation to simultaneously move fluid with respect to two or more subterranean zones
US20080093083A1 (en) * 2006-10-19 2008-04-24 Schlumberger Technology Corporation Gas Handling In A Well Environment
WO2012112983A2 (fr) * 2011-02-20 2012-08-23 Saudi Arabian Oil Company Appareil et procédés pour la conception de la complétion d'un puits afin d'éviter une érosion et une grande perte par frottement grâce à des systèmes de pompes submersibles électriques déployés à câble d'alimentation
US20140341755A1 (en) * 2011-12-15 2014-11-20 Raise Production, Inc. Horizontal and vertical well fluid pumping system

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5154588A (en) * 1990-10-18 1992-10-13 Oryz Energy Company System for pumping fluids from horizontal wells
US6325143B1 (en) * 1999-01-04 2001-12-04 Camco International, Inc. Dual electric submergible pumping system installation to simultaneously move fluid with respect to two or more subterranean zones
US20080093083A1 (en) * 2006-10-19 2008-04-24 Schlumberger Technology Corporation Gas Handling In A Well Environment
WO2012112983A2 (fr) * 2011-02-20 2012-08-23 Saudi Arabian Oil Company Appareil et procédés pour la conception de la complétion d'un puits afin d'éviter une érosion et une grande perte par frottement grâce à des systèmes de pompes submersibles électriques déployés à câble d'alimentation
US20140341755A1 (en) * 2011-12-15 2014-11-20 Raise Production, Inc. Horizontal and vertical well fluid pumping system

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