WO2012166638A2 - Soupape de sureté, système de by-pass à soupape de sureté pour pompe submersible électrique déployée par câble - Google Patents

Soupape de sureté, système de by-pass à soupape de sureté pour pompe submersible électrique déployée par câble Download PDF

Info

Publication number
WO2012166638A2
WO2012166638A2 PCT/US2012/039670 US2012039670W WO2012166638A2 WO 2012166638 A2 WO2012166638 A2 WO 2012166638A2 US 2012039670 W US2012039670 W US 2012039670W WO 2012166638 A2 WO2012166638 A2 WO 2012166638A2
Authority
WO
WIPO (PCT)
Prior art keywords
electrical connection
safety valve
latching mechanism
work string
landing
Prior art date
Application number
PCT/US2012/039670
Other languages
English (en)
Other versions
WO2012166638A3 (fr
Inventor
James D. Vick, Jr.
Leo G. Collins
Tom W. SWAN
Gary L. STEPHENSON
Original Assignee
Halliburton Energy Services, Inc.
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 Halliburton Energy Services, Inc. filed Critical Halliburton Energy Services, Inc.
Priority to US14/119,152 priority Critical patent/US20140083712A1/en
Publication of WO2012166638A2 publication Critical patent/WO2012166638A2/fr
Publication of WO2012166638A3 publication Critical patent/WO2012166638A3/fr

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
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/02—Couplings; joints
    • E21B17/023—Arrangements for connecting cables or wirelines to downhole devices
    • 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
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in wells

Definitions

  • Wellbores are sometimes drilled into subterranean formations containing hydrocarbons to allow for recovery of the hydrocarbons.
  • various procedures may be performed that involve temporarily isolating fluid flowing between the surface of a wellbore and the formation through a wellbore tubular.
  • Such procedures can include flow control operations, completion operations, and or interventions.
  • the isolation of the wellbore typically involves the use of a mechanical component being disposed in the flow path to provide a seal. Any additional components disposed within the flow path may interfere with the ability of the mechanical components to form a seal, thereby preventing the isolation of the wellbore as needed.
  • a work string for downhole use in a well comprises a safety valve comprising a sealable flow path; a first electrical connection disposed above the safety valve; a second electrical connection disposed below the safety valve; and a jumper electrically coupling the first electrical connection and the second electrical connection, wherein the jumper does not pass through the sealable flow path of the safety valve.
  • the work string may also include an electric submersible pump electrically coupled to the second electrical connection.
  • the work string may also include a pump landing disposed below the second electrical connection, wherein the electric submersible pump may engage the pump landing.
  • the first electrical connection may be electrically coupled to a power source above the first electrical connection.
  • the first electrical connection may comprise a first landing nipple, and the first landing nipple may comprise a first landing shoulder and a first latching indicator.
  • the work string may also include a first latching mechanism that is electrically coupled to a surface of the well. The first latching mechanism may engage the first landing shoulder and the first latching indicator of the first landing nipple, and the first latching mechanism may be electrically coupled to the first electrical connection when the first latching mechanism engages the first landing shoulder.
  • the second electrical connection may comprise a second landing nipple, and the second landing nipple may comprise a second landing shoulder and a second latching indicator.
  • the work string may also include a second latching mechanism that is electrically coupled to an electric submersible pump.
  • the second latching mechanism may engage the second landing shoulder and the second latching indicator of the second landing nipple, and the second latching mechanism may be electrically coupled to the second electrical connection when the second latching mechanism engages the second landing shoulder.
  • the safety valve may comprise a sealing element configured to substantially seal the sealable flow path in a closed configuration and allow flow through the sealable flow path in an open configuration.
  • the sealing element may comprise a flapper for engaging a corresponding flapper seal, a ball for engaging a ball valve seat, a gate for engaging a gate valve seat, or a sleeve slidingly disposed within a window.
  • a method comprises electrically coupling a first electrical connection with a second electrical connection in a work string disposed within a well and providing an electrical current to the first electrical connection.
  • the work string comprises a safety valve; the first electrical connection disposed above the safety valve; the second electrical connection disposed below the safety valve; and a jumper electrically coupling the first electrical connection and the second electrical connection, wherein the jumper does not pass through a sealable flow path of the safety valve, and wherein the second electrical connection is electrically coupled to a subsurface electric component.
  • the subsurface electric component may comprise an electric submersible pump.
  • the work string may also include a landing disposed below the second electrical connection, and the method may also include engaging the subsurface electric component in the landing.
  • the first electrical connection may comprise a first landing nipple, and the method may also include engaging a first latching mechanism with the first landing nipple, where the first latching mechanism is electrically coupled to a surface of the well.
  • Engaging the first latching mechanism with the first landing nipple may comprise activating the first latching mechanism using a weight, an impact, a hydraulic mechanism, a longitudinal motion, a rotational motion, or any combination thereof.
  • the second electrical connection may comprise a second landing nipple, and the method may also include engaging a second latching mechanism with the second landing nipple, where the second latching mechanism is electrically coupled to the subsurface electric component.
  • Engaging the second latching mechanism with the second landing nipple may comprise activating the second latching mechanism using a weight, an impact, a hydraulic mechanism, a longitudinal motion, a rotational motion, or any combination thereof.
  • a method comprises producing a hydrocarbon from wellbore comprising a work string and isolating a first portion of the wellbore above the safety valve from a second portion of the wellbore below the safety valve using a sealable flow path.
  • the work string comprises: a safety valve comprising the sealable flow path; a first electrical connection disposed above the safety valve, where the first electrical connection is electrically coupled to a power source; a second electrical connection disposed below the safety valve, where the second electrical connection is electrically coupled to an electric pump; and a jumper electrically coupling the first electrical connection and the second electrical connection, where the jumper does not pass through the sealable flow path of the safety valve.
  • Figure 1 is a schematic view of an embodiment of a subterranean formation and wellbore operating environment.
  • Figure 2 is a schematic cross-section of a work string according to an embodiment.
  • Figure 3 is a schematic cross-section of a work string according to an embodiment.
  • Figure 4 is a schematic cross-section of a work string according to an embodiment. DETAILED DESCRIPTION OF THE EMBODIMENTS
  • any use of any form of the terms “connect,” “engage,” “couple,” “attach,” or any other term describing an interaction between elements is not meant to limit the interaction to direct interaction between the elements and may also include indirect interaction between the elements described.
  • the terms “including” and “comprising” are used in an open-ended fashion, and thus should be interpreted to mean “including, but not limited to Reference to up or down will be made for purposes of description with “up,” “upper,” “upward,” or “upstream” meaning toward the surface of the wellbore and with “down,” “lower,” “downward,” or “downstream” meaning toward the terminal end of the well, regardless of the wellbore orientation.
  • zone or “pay zone” as used herein refers to separate parts of the wellbore designated for treatment or production and may refer to an entire hydrocarbon formation or separate portions of a single formation such as horizontally and/or vertically spaced portions of the same formation.
  • a safety valve system may be employed within a well or a wellbore tubular string to enable the flow of fluids from within the wellbore to be isolated during use.
  • Various electrical components can be used within wellbores that require an electrical connection in order to function. When the electrical connection passes through a safety valve, the sealable path may be blocked, thereby preventing the safety valve from forming a seal and isolating the flow of fluids within the well.
  • the work string described herein allows a safety valve function to be maintained even while using a cable deployed downhole tool such as an electrical component deployed below the safety valve.
  • the operating environment comprises a drilling rig 107 that is positioned on the earth's surface 105 and extends over and around a wellbore 115 that penetrates a subterranean formation 103 for the purpose of recovering hydrocarbons.
  • the wellbore 115 may be drilled into the subterranean formation 103 using any suitable drilling technique.
  • the wellbore 115 extends substantially vertically away from the earth's surface 105 over a vertical wellbore portion 117, deviates from vertical relative to the earth's surface 105 over a deviated wellbore portion 137, and transitions to a horizontal wellbore portion 119.
  • a wellbore may be vertical, deviated at any suitable angle, horizontal, and/or curved.
  • the wellbore may be a new wellbore, an existing wellbore, a straight wellbore, an extended reach wellbore, a sidetracked wellbore, a multi-lateral wellbore, and other types of wellbores for drilling and completing one or more production zones.
  • the wellbore may be used for both producing wells and injection wells.
  • the wellbore may be used for purposes other than or in addition to hydrocarbon production, such as uses related to geothermal energy and/or the production of water (e.g., potable water).
  • a wellbore tubular string 121 including a work string comprising the safety valve as described herein may be lowered into the subterranean formation 103 for a variety of drilling, completion, production, workover, and/or treatment procedures throughout the life of the wellbore.
  • the embodiment shown in Figure 1 illustrates the wellbore tubular 121 in the form of a completion and/or work string being lowered into the subterranean formation. It should be understood that the wellbore tubular 121 is equally applicable to any type of wellbore tubular being inserted into a wellbore, including as non-limiting examples drill pipe, production tubing, rod strings, and coiled tubing.
  • the wellbore tubular 121 comprising the safety valve may be conveyed into the subterranean formation 103 in a conventional manner.
  • the safety valve system for use in the wellbore 115 may comprise a safety valve 102 comprising a sealable flow path 104, a first electrical connection 106 disposed above the safety valve 102, a second electrical connection 108 disposed below the safety valve 102, and a jumper 110 electrically coupling the first electrical connection 106 and the second electrical connection 108, where the jumper 110 does not pass through the sealable flow path 104 of the safety valve 102.
  • the drilling rig 107 comprises a derrick 109 with a rig floor 111 through which the wellbore tubular 121 extends downward from the drilling rig 107 into the wellbore 115.
  • the drilling rig 107 comprises a motor driven winch and other associated equipment for extending the wellbore tubular 121 into the wellbore 115 to position the wellbore tubular 121 at a selected depth.
  • FIG. 1 refers to a stationary drilling rig 107 for lowering and setting the wellbore tubular 121 comprising the running tool within a land-based wellbore 115
  • mobile workover rigs such as coiled tubing units
  • wellbore servicing units such as coiled tubing units
  • a wellbore tubular 121 comprising the running tool may alternatively be used in other operational environments, such as within an offshore wellbore operational environment.
  • a vertical, deviated, or horizontal wellbore portion may be cased and cemented and/or portions of the wellbore may be uncased.
  • the safety valve allows for the use of an electrical component (e.g., a cable deployed electric submersible pump (ESP)) while continuing to allow for the proper operation of a downhole safety valve (e.g., a Tubing Retrievable Safety Valve (TRSV)).
  • ESP cable deployed electric submersible pump
  • TRSV Tubing Retrievable Safety Valve
  • the safety valve function is maintained through the safety valve 102 since an electrical connection does not need to pass through the sealable flow path 104 of the safety valve 102.
  • the first electrical connection 106 may be part of a first landing nipple 120
  • the second electrical connection 108 may be part of a second landing nipple 122
  • the first landing nipple 120 may comprise a first landing shoulder 112 and a first latching indicator 114
  • the second landing nipple 122 may comprise a second landing shoulder 116 and a second latching indicator 118.
  • the safety valve 102 may be disposed between the first landing nipple 120 and the second landing nipple 122, and the safety valve 102 may comprise a sealing element (e.g., flapper 124) generally located in a sealable flow path 104 that may include those known in the art for providing fluid isolation within a wellbore.
  • the sealing element is configured to substantially seal the sealable flow path in a closed configuration and allow flow through the sealable flow path in an open configuration.
  • Such safety valves may be automatically activating or controlled through the use of a control line using, for example, fluid pressure or an electrical signal to actuate the safety valve 102.
  • the sealing element may comprise a flapper 124 for engaging a corresponding flapper seal.
  • the sealing element may comprise a ball for engaging a ball valve seat, a gate for engaging a gate valve seat, a sleeve slidingly disposed within a window, combinations thereof, and any additional sealing mechanism known to one of ordinary skill in the art.
  • the safety valve 102 may be a tubing retrievable safety valve or a cable retrievable safety valve.
  • the safety valve 102 comprises a flapper- type safety valve as illustrated in Figures 2-4.
  • a flapper-type safety valve generally comprises a tubular body member with a longitudinal bore (e.g., sealable flow path 104) that extends therethrough.
  • An actuator usually referred to as a flow tube, may be disposed within the body member and is configured to longitudinally translate between the open position of the safety valve 102 and the closed position of the safety valve 102 within the body member.
  • a biasing member such as a spring may be disposed about the actuator to act upon the actuator, thereby biasing the actuator away from a sealing element, which is usually referred to as a flapper 124.
  • the sealing element is pivotably mounted via a hinge (typically with a hinge spring to bias the sealing element into the flow path to provide a closed position) within the body member to control fluid flow through the longitudinal bore.
  • a rod-piston system, or other hydraulic operating piston, such as an annular piston may be provided to controllably translate the actuator within the longitudinal bore, and to actuate the sealing element between an open position and a closed position and/or a closed position and an open position.
  • the safety valve 102 may generally comprise a control line inlet that can be connected to a control line and provide a control fluid to the piston. Once connected, the control line is configured to be in fluid communication with a piston disposed within a piston rod chamber.
  • a first end of the piston may be in contact with hydraulic fluid provided thereto through the control line.
  • a second end of the piston is operatively connected, in any suitable manner, to the actuator.
  • the piston When the pressure of hydraulic fluid in the control line exceeds the force needed to compress the biasing member (e.g., spring), the piston is forced downwardly, thereby causing the actuator (e.g., the flow tube) to come into contact with, and open, the sealing element.
  • the biasing member forces the actuator upwardly away from the closure member.
  • the closure member is then rotated, and biased, into a closed position by action of a hinge spring to a normally closed position to prevent fluid flow into the actuator and through the longitudinal bore.
  • the safety valve 102 may comprise a ball valve.
  • a ball valve generally comprises a variety of components to provide a seal (e.g., a ball/seat interface) and actuate a ball disposed within a body of the valve.
  • a ball valve assembly may comprise cylindrical retaining members disposed on opposite sides of the ball.
  • One or more seats or seating surfaces may be disposed above and/or below the ball to provide a fluid seal with the ball.
  • the ball generally comprises a truncated sphere having planar surfaces on opposite sides of the sphere. Planar surfaces may each have a spigot comprising a projection (e.g.
  • actuation member having two parallel arms may be positioned about the ball and the retaining members.
  • the spigots may be received in windows through each of the arms.
  • Actuation pins may be provided on each of the inner sides of the arms, and the pins may be received within the grooves on the ball.
  • the ball In the open position, the ball is positioned so as to allow the flow of fluid through the ball valve by allowing fluid to flow through an interior fluid passageway (e.g., a bore or hole) extending through the ball.
  • the interior flow passage may have its longitudinal axis disposed at about 90 degrees to the longitudinal axis when the ball is in the closed position, and the interior flow passage may have its longitudinal axis substantially aligned with the longitudinal axis when the ball is in the open position
  • the ball may be rotated by linear movement of the actuation member along the longitudinal axis.
  • the pins move as the actuation member moves, causing the ball to rotate due to the positioning of the pins within the grooves on the ball.
  • the ball is actuated from an open position to a closed position by rotating the ball such that the interior flow passage is rotated out of alignment with the flow of fluid, thereby forming a fluid seal with one or more seats or seating surfaces and closing the valve.
  • the ball is actuated from a closed position to an open position by rotating the ball such that the interior flow passage is rotated into alignment with the flow of fluid.
  • the first electrical connection 106, the second connection 108, and the jumper 110 may comprise one or more electrical connection pathways.
  • various metallic structures within the wellbore such as the casing, the tubing, and the like may provide a conduction path, thereby allowing for the electrical connections to comprise a single electrical conductor and provide a single electrical connection pathway.
  • a plurality of conduction pathways may be contained within the electrical connections, allowing for a plurality of electrical connection pathways.
  • a wireline with a plurality of conductors may be contained in the cable and/or the jumper 110, and the first electrical connection 106 and/or the second electrical connection 108 may be configured to provide a corresponding number of electrical pathways.
  • the first electrical connection 106 may be electrically coupled to a power source above the first electrical connection 106, for example at the surface of the well.
  • a first latching mechanism 302 may be used to couple a connector 304 (e.g., a cable) to the first electrical connection 106.
  • the first latching mechanism 302 may engage the first landing shoulder 112 and the first latching indicator 114 of the first landing nipple 120.
  • the first latching mechanism 302 may be electrically coupled to the first electrical connection 106 when the first latching mechanism is engaged with the first landing shoulder 112.
  • the work string may also include a second latching mechanism 306 that is electrically coupled to an electric component 308 such as an electric submersible pump.
  • the second latching mechanism 306 may engage the second landing shoulder 116 and the second latching indicator 118 of the second landing nipple 122. Further, the second latching mechanism 306 may be electrically coupled to the second electrical connection 108 when the second latching mechanism 306 is engaged with the second landing shoulder 116.
  • the work string may also include a pump landing 310 disposed below the second electrical connection 108, and the electric component 308 (e.g., an ESP) may engage the pump landing 310.
  • a cable 312 may electrically couple the second latching mechanism 306 and the electric component 308.
  • the work string may also include an electric submersible pump electrically coupled to the second electrical connection 108.
  • the first latching mechanism 302 may be ported (e.g., comprise one or more ports 314) to provide fluid communication through the first latching mechanism 302 and the first landing nipple 120 and past the first latching mechanism 302.
  • the second latching mechanism 306 may be ported (e.g., comprise one or more ports 316) to provide fluid communication through the second latching mechanism 306 and the second landing nipple 122 and past the second latching mechanism 306.
  • a method of using the work string comprises electrically coupling a subsurface electric component 308 with a second electrical connection 108 in a work string disposed within a well, and providing an electrical current to a first electrical connection 106 coupled to the second electrical connection 108.
  • the work string may comprise a safety valve 102, a first electrical connection 106 disposed above the safety valve 102, the second electrical connection 108 disposed below the safety valve 102, and a jumper 110 electrically coupling the first electrical connection 106 and the second electrical connection 108, where the jumper 110 does not pass through a sealable flow path 104 of the safety valve 102.
  • the subsurface electric component 308 may comprise an electric submersible pump.
  • the electric component 308 may be coupled to the second electrical connection 108 using a second latching mechanism 306 disposed on a suitable conveyance device.
  • Suitable conveyance devices may include, but are not limited to, a slickline, wireline, an electrical connector, or coiled tubing.
  • the safety valve 102 is actuated to the open position to allow the electrical component 308, connector 312, and second latching mechanism 306 to pass through the safety valve 102.
  • the second latching mechanism 306 may be configured to engage and electrically couple to the second electrical connection 108.
  • the second latching mechanism 306 may be activated so that the second latching mechanism 306 engages the second landing shoulder 116, and a biased button 318 on the second latching mechanism 306 engages the second latching indicator 118 to secure the second latching mechanism 306 in place.
  • the second latching mechanism 306 may be engaged with the second landing nipple 122 by activating the latching mechanism using weight, impact, a hydraulic mechanism, longitudinal motion, rotational motion, or any combination thereof.
  • a pressure signal may be supplied to the second landing nipple 122 and used to actuate a hydraulic mechanism (e.g., a piston) forming part of the second latching mechanism 306, and/or a hydraulic mechanism forming part of the second landing nipple 122.
  • a hydraulic mechanism e.g., a piston
  • the second electrical connection 108 may be formed as part of the second latch indicator 118 on the second landing nipple 122.
  • an electrical connection may be formed when the biased button 318 engages and/or contacts a counterpart contact plate in the second latch indicator 118.
  • the presence of an electrical signal (for example, detectable at the surface) may indicate the successful landing/engagement of the second latch mechanism 306 with the second landing nipple 122.
  • an electrical connection may then be established with the first electrical connection 106 using a connector 304 and the first latching mechanism 302 coupled to a power source.
  • the power source may include an electrical source at the surface of the wellbore, and/or a downhole power source such as a downhole generator and/or battery pack.
  • the first latching mechanism 302 may be disposed on a suitable conveyance device. Suitable conveyance devices may include, but are not limited to, a slickline, wireline, an electrical connector, or a coiled tubing.
  • the connector 304 may comprise the conveyance device.
  • the first latching mechanism 302 may be configured to engage and electrically couple to the first electrical connection 106.
  • the first latching mechanism 302 may be activated so that the first latching mechanism 302 engages the first landing shoulder 112, and a biased button 320 on the first latching mechanism 302 engages the first latching indicator 114 to secure the first latching mechanism 302 in place.
  • the first latching mechanism 302 may be engaged with the first landing nipple 120 using a latching mechanism that uses weight, impact, a hydraulic mechanism, longitudinal motion, rotational motion, or any combination thereof.
  • a pressure signal may be supplied to the first landing nipple 120 and used to actuate a hydraulic mechanism (e.g., a piston) forming part of the second latching mechanism 306, and/or a hydraulic mechanism forming part of the first landing nipple 120.
  • the first electrical connection 106 may be formed as part of the first latch indicator 114 on the first landing nipple 120.
  • an electrical connection may be formed when the biased button 320 engages and/or contacts a counterpart contact plate in the first latch indicator 114.
  • the presence of an electrical signal (for example, detectable at the surface) may indicate the successful landing/engagement of the first latch mechanism 302 with the first landing nipple 120.
  • the first latching mechanism 302, the second latching mechanism 306, the first landing nipple 120, and/or the second landing nipple 122 may be ported or otherwise configured (e.g., with flow paths, fluid channels/grooves, or the like) to allow fluid to flow through the first latching mechanism 302, the second latching mechanism 306, the first landing nipple 120, and/or the second landing nipple 122 to the surface of the wellbore during production.
  • the safety valve 102 may be operated at any point during the production of the wellbore to isolate a first portion of the wellbore above the safety valve 102 from a second portion of the wellbore below the safety valve 102 using the sealable flow path 104.
  • a method of operating a wellbore may comprise producing a hydrocarbon from the wellbore comprising a work string, and isolating a first portion of the wellbore above the safety valve from a second portion of the wellbore below the safety valve using the sealable flow path.
  • Producing the hydrocarbon from the wellbore may include, for example, supplying electrical current to the electric component (e.g., an electric submersible pump) via the electrical connections described herein, where the electric component pumps the hydrocarbon to the surface via the sealable flow path 104.
  • the work string may comprise a safety valve, a first electrical connection disposed above the safety valve, wherein the first electrical connection is electrically coupled to a power source, a second electrical connection disposed below the safety valve, wherein the second electrical connection is electrically coupled to an electric submersible pump, and a jumper electrically coupling the first electrical connection and the second electrical connection, wherein the jumper does not pass through a sealable flow path of the safety valve.
  • various embodiments may include, but are not limited to:
  • a work string for downhole use in a well comprises a safety valve comprising a sealable flow path; a first electrical connection disposed above the safety valve; a second electrical connection disposed below the safety valve; and a jumper electrically coupling the first electrical connection and the second electrical connection, where the jumper does not pass through the sealable flow path of the safety valve.
  • an electric submersible pump electrically coupled to the second electrical connection.
  • sealing element comprises a flapper for engaging a corresponding flapper seal, a ball for engaging a ball valve seat, a gate for engaging a gate valve seat, or a sleeve slidingly disposed within a window.
  • a method comprises electrically coupling a subsurface electric component with a second electrical connection in a work string disposed within a well, wherein the work string comprises: a safety valve; a first electrical connection disposed above the safety valve; the second electrical connection disposed below the safety valve; and a jumper electrically coupling the first electrical connection and the second electrical connection, wherein the jumper does not pass through a sealable flow path of the safety valve; and providing an electrical current to the first electrical connection.
  • engaging the first latching mechanism with the first landing nipple comprises activating a latching mechanism that uses weight, impact, a hydraulic mechanism, longitudinal motion, rotational motion, or any combination thereof.
  • sealing element comprises a flapper for engaging a corresponding flapper seal, a ball for engaging a ball valve seat, a gate for engaging a gate valve seat, or a sleeve slidingly disposed within a window.
  • a method comprises producing a hydrocarbon from wellbore comprising a work string, wherein the work string comprises: a safety valve; a first electrical connection disposed above the safety valve, wherein the first electrical connection is electrically coupled to a power source; a second electrical connection disposed below the safety valve, wherein the second electrical connection is electrically coupled to an electric pump; and a jumper electrically coupling the first electrical connection and the second electrical connection, wherein the jumper does not pass through a sealable flow path of the safety valve; and isolating a first portion of the wellbore above the safety valve from a second portion of the wellbore below the safety valve using the sealable flow path.
  • R R i+k*(R u -Ri), wherein k is a variable ranging from 1 percent to 100 percent with a 1 percent increment, i.e., k is 1 percent, 2 percent, 3 percent, 4 percent, 5 percent, ... 50 percent, 51 percent, 52 percent, 95 percent, 96 percent, 97 percent, 98 percent, 99 percent, or 100 percent.
  • any numerical range defined by two R numbers as defined in the above is also specifically disclosed.

Landscapes

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

Abstract

L'invention porte sur un train de tiges de travail utilisable dans un trou de forage dans un puits, qui comprend, dans un mode de réalisation, une soupape de sureté comprenant un trajet d'écoulement obturable ; un premier raccordement électrique disposé au-dessus de la soupape de sureté ; un second raccordement électrique disposé au-dessous de la soupape de sureté et un raccord qui accouple électriquement la première connexion électrique et la seconde connexion électrique, la jarretelle ne passant pas à travers le trajet d'écoulement obturable de la soupape de sureté.
PCT/US2012/039670 2011-05-27 2012-05-25 Soupape de sureté, système de by-pass à soupape de sureté pour pompe submersible électrique déployée par câble WO2012166638A2 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
US14/119,152 US20140083712A1 (en) 2011-05-27 2012-05-25 Safety Valve By-Pass System for Cable-Deployed Electric Submersible Pump

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US201161490984P 2011-05-27 2011-05-27
US61/490,984 2011-05-27

Publications (2)

Publication Number Publication Date
WO2012166638A2 true WO2012166638A2 (fr) 2012-12-06
WO2012166638A3 WO2012166638A3 (fr) 2013-03-28

Family

ID=47260226

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/US2012/039670 WO2012166638A2 (fr) 2011-05-27 2012-05-25 Soupape de sureté, système de by-pass à soupape de sureté pour pompe submersible électrique déployée par câble

Country Status (2)

Country Link
US (1) US20140083712A1 (fr)
WO (1) WO2012166638A2 (fr)

Cited By (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2018129013A1 (fr) * 2017-01-03 2018-07-12 Saudi Arabian Oil Company Dispositif de suspension souterrain pour pompe submersible électrique déployée ombilicale
WO2020223245A1 (fr) * 2019-05-01 2020-11-05 Saudi Arabian Oil Company Fonctionnement d'une soupape de sécurité souterraine à l'aide d'une pompe de fond de trou
US11499563B2 (en) 2020-08-24 2022-11-15 Saudi Arabian Oil Company Self-balancing thrust disk
US11591899B2 (en) 2021-04-05 2023-02-28 Saudi Arabian Oil Company Wellbore density meter using a rotor and diffuser
US11644351B2 (en) 2021-03-19 2023-05-09 Saudi Arabian Oil Company Multiphase flow and salinity meter with dual opposite handed helical resonators
US11913464B2 (en) 2021-04-15 2024-02-27 Saudi Arabian Oil Company Lubricating an electric submersible pump
US11920469B2 (en) 2020-09-08 2024-03-05 Saudi Arabian Oil Company Determining fluid parameters
US11994016B2 (en) 2021-12-09 2024-05-28 Saudi Arabian Oil Company Downhole phase separation in deviated wells

Families Citing this family (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US10465477B2 (en) 2016-11-17 2019-11-05 Saudi Arabian Oil Company Subsurface safety valve for cable deployed electrical submersible pump
US10151187B1 (en) 2018-02-12 2018-12-11 Eagle Technology, Llc Hydrocarbon resource recovery system with transverse solvent injectors and related methods
US10502041B2 (en) 2018-02-12 2019-12-10 Eagle Technology, Llc Method for operating RF source and related hydrocarbon resource recovery systems
US10577905B2 (en) 2018-02-12 2020-03-03 Eagle Technology, Llc Hydrocarbon resource recovery system and RF antenna assembly with latching inner conductor and related methods
US10767459B2 (en) 2018-02-12 2020-09-08 Eagle Technology, Llc Hydrocarbon resource recovery system and component with pressure housing and related methods
US10577906B2 (en) 2018-02-12 2020-03-03 Eagle Technology, Llc Hydrocarbon resource recovery system and RF antenna assembly with thermal expansion device and related methods
CN111425176B (zh) * 2020-04-02 2022-03-18 西安科技大学 一种煤岩层高压封孔及保压卸压装置
US11506020B2 (en) 2021-03-26 2022-11-22 Halliburton Energy Services, Inc. Textured resilient seal for a subsurface safety valve

Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4614233A (en) * 1984-10-11 1986-09-30 Milton Menard Mechanically actuated downhole locking sub
US4621689A (en) * 1985-09-04 1986-11-11 Trw Inc. Cable suspended submergible pumping system with safety valve
US20050077050A1 (en) * 2003-10-14 2005-04-14 Mackay Graham Installation of downhole electrical power cable and safety valve assembly
US20080223585A1 (en) * 2007-03-13 2008-09-18 Schlumberger Technology Corporation Providing a removable electrical pump in a completion system

Patent Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4614233A (en) * 1984-10-11 1986-09-30 Milton Menard Mechanically actuated downhole locking sub
US4621689A (en) * 1985-09-04 1986-11-11 Trw Inc. Cable suspended submergible pumping system with safety valve
US20050077050A1 (en) * 2003-10-14 2005-04-14 Mackay Graham Installation of downhole electrical power cable and safety valve assembly
US20080223585A1 (en) * 2007-03-13 2008-09-18 Schlumberger Technology Corporation Providing a removable electrical pump in a completion system

Cited By (12)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2018129013A1 (fr) * 2017-01-03 2018-07-12 Saudi Arabian Oil Company Dispositif de suspension souterrain pour pompe submersible électrique déployée ombilicale
CN110168189A (zh) * 2017-01-03 2019-08-23 沙特阿拉伯石油公司 用于脐带缆部署式电潜泵的地下悬挂器
US10584543B2 (en) 2017-01-03 2020-03-10 Saudi Arabian Oil Company Subsurface hanger for umbilical deployed electrical submersible pump
CN110168189B (zh) * 2017-01-03 2021-11-23 沙特阿拉伯石油公司 用于脐带缆部署式电潜泵的地下悬挂器
WO2020223245A1 (fr) * 2019-05-01 2020-11-05 Saudi Arabian Oil Company Fonctionnement d'une soupape de sécurité souterraine à l'aide d'une pompe de fond de trou
US10927643B2 (en) 2019-05-01 2021-02-23 Saudi Arabian Oil Company Operating a subsurface safety valve using a downhole pump
US11499563B2 (en) 2020-08-24 2022-11-15 Saudi Arabian Oil Company Self-balancing thrust disk
US11920469B2 (en) 2020-09-08 2024-03-05 Saudi Arabian Oil Company Determining fluid parameters
US11644351B2 (en) 2021-03-19 2023-05-09 Saudi Arabian Oil Company Multiphase flow and salinity meter with dual opposite handed helical resonators
US11591899B2 (en) 2021-04-05 2023-02-28 Saudi Arabian Oil Company Wellbore density meter using a rotor and diffuser
US11913464B2 (en) 2021-04-15 2024-02-27 Saudi Arabian Oil Company Lubricating an electric submersible pump
US11994016B2 (en) 2021-12-09 2024-05-28 Saudi Arabian Oil Company Downhole phase separation in deviated wells

Also Published As

Publication number Publication date
WO2012166638A3 (fr) 2013-03-28
US20140083712A1 (en) 2014-03-27

Similar Documents

Publication Publication Date Title
US20140083712A1 (en) Safety Valve By-Pass System for Cable-Deployed Electric Submersible Pump
US9587462B2 (en) Safety valve system for cable deployed electric submersible pump
US8272443B2 (en) Downhole progressive pressurization actuated tool and method of using the same
CA2590594C (fr) Procede et appareil de derivation de fluides d'un outil de forage
US8733449B2 (en) Selectively activatable and deactivatable wellbore pressure isolation device
US20120181043A1 (en) Electric submersible pumping completion flow diverter system
US8893811B2 (en) Responsively activated wellbore stimulation assemblies and methods of using the same
EP2699761B1 (fr) Bouchon de sécurité de robinet à tournant sphérique
US20140202713A1 (en) Well Intervention Pressure Control Valve
US9650863B2 (en) Safety valve system for cable deployed electric submersible pump
AU2016201706B2 (en) Debris barrier for hydraulic disconnect tools
WO2014193405A1 (fr) Ensemble obturateur à bille activé dans l'espace annulaire
US9822607B2 (en) Control line damper for valves
WO2016014075A1 (fr) Soupape à bille de fond de trou
US20210348479A1 (en) Ball valves, methods to close a ball valve, and methods to form a well barrier
US8770300B2 (en) Debris barrier for hydraulic disconnect tools
AU2012384917B2 (en) Control line damper for valves

Legal Events

Date Code Title Description
121 Ep: the epo has been informed by wipo that ep was designated in this application

Ref document number: 12793896

Country of ref document: EP

Kind code of ref document: A2

WWE Wipo information: entry into national phase

Ref document number: 14119152

Country of ref document: US

NENP Non-entry into the national phase

Ref country code: DE

122 Ep: pct application non-entry in european phase

Ref document number: 12793896

Country of ref document: EP

Kind code of ref document: A2