EP3346090A1 - Systèmes et appareils permettant de séparer des fluides de puits de forage et de solides pendant la production - Google Patents

Systèmes et appareils permettant de séparer des fluides de puits de forage et de solides pendant la production Download PDF

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Publication number
EP3346090A1
EP3346090A1 EP18157720.6A EP18157720A EP3346090A1 EP 3346090 A1 EP3346090 A1 EP 3346090A1 EP 18157720 A EP18157720 A EP 18157720A EP 3346090 A1 EP3346090 A1 EP 3346090A1
Authority
EP
European Patent Office
Prior art keywords
separator
fluid
sealing
liner
inlet port
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Withdrawn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
EP18157720.6A
Other languages
German (de)
English (en)
Inventor
Jeffrey Charles Saponja
Robbie Singh Hari
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.)
Production Plus Energy Services Inc
Original Assignee
Production Plus 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 Production Plus Energy Services Inc filed Critical Production Plus Energy Services Inc
Priority claimed from PCT/CA2014/000695 external-priority patent/WO2015035509A1/fr
Publication of EP3346090A1 publication Critical patent/EP3346090A1/fr
Withdrawn legal-status Critical Current

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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
    • E21B43/34—Arrangements for separating materials produced by the well
    • E21B43/38—Arrangements for separating materials produced by the well in the well
    • 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
    • E21B23/00—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or 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
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • 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
    • E21B43/02—Subsoil filtering
    • E21B43/10—Setting of casings, screens, liners or the like 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
    • 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

Definitions

  • the present disclosure relates to artificial lift systems, and related apparatuses, for use in producing hydrocarbon-bearing reservoirs.
  • Gas interference is a problem encountered while producing wells, especially wells with horizontal portions. Gas interference results in downhole pumps becoming gas locked and/or low pump efficiencies. Downhole packer-type gas anchors or separators are provided to remedy gas lock.
  • packer-type gas anchors are generally not design to effectively separate and manage debris. They are also relatively expensive.
  • the packers on packer-type gas anchors are susceptible to having debris accumulate thereon and, as a result, becoming stuck within the wellbore tubular against which it forms a seal and/or reducing their ability to separate gas or blocking flow passages within the packer-type gas anchor.
  • a stuck packer makes it difficult to remove production tubing from the wellbore or to access the wellbore below it, such as during a workover. Such attempt at removal may also damage the packer or wellbore casing, thereby rendering the packer-type gas anchor unusable for future production or even loss of the wellbore.
  • a system for processing at least reservoir fluids within a wellbore that is disposed within an oil reservoir comprising a wellbore fluid conductor disposed within the wellbore, the wellbore fluid conductor comprising: a separator co-operating fluid conductor; a liner, the liner being coupled to and disposed in sealing, or substantially sealing, engagement with the separator co-operating fluid conductor, and including a liner fluid passage for receiving reservoir fluids from the reservoir and for conducting at least reservoir fluids; and a separator including: a first inlet port disposed in fluid communication with the liner fluid passage for receiving at least reservoir fluids from the liner fluid passage; a first outlet port; a reservoir fluid-conducting passage extending between the first inlet port and the first outlet port; a second inlet port disposed downhole relative to the first outlet port; a second outlet port; a gas-depleted fluid conducting passage extending between the second inlet port and the second outlet port; a co-operating surface portion
  • a system for processing at least reservoir fluids within a wellbore that is disposed within an oil reservoir comprising: a wellbore fluid conductor disposed within the wellbore; and a liner coupled to and sealingly, or substantially sealingly, engaged with the wellbore fluid conductor for conducting reservoir fluid, the wellbore fluid conductor including a wellbore fluid conductor passage and the liner defining a liner fluid passage downhole from, and in fluid communication with, the wellbore fluid conductor passage; and a separator disposed in the wellbore fluid conductor passage, the separator including an inlet port for receiving at least reservoir fluid and an outlet port for delivering gas-depleted reservoir fluid, the inlet port being disposed in fluid communication with the liner fluid passage and in substantial sealing engagement with the liner to prevent, or substantially prevent, the reservoir fluid from bypassing the inlet port.
  • a system for processing at least reservoir fluids within a wellbore that is disposed within an oil reservoir comprising a wellbore fluid conductor disposed within the wellbore, the wellbore fluid conductor comprising: a separator co-operating fluid conductor including: a downhole wellbore fluid passage for receiving reservoir fluids from the reservoir and for conducting at least reservoir fluids; and a constricted portion; a separator including: a first inlet port disposed in fluid communication with the downhole wellbore fluid passage for receiving at least reservoir fluids from the downhole wellbore fluid passage; a first outlet port; a reservoir fluid-conducting passage extending between the first inlet port and the first outlet port; a second inlet port disposed downhole relative to the first outlet port; a second outlet port; a gas-depleted fluid conducting passage extending between the second inlet port and the second outlet port; a co-operating surface portion co-operating with the separator co-operating fluid conductor to define an intermediate
  • a system for processing at least reservoir fluids within a wellbore that is disposed within an oil reservoir comprising a wellbore fluid conductor disposed within the wellbore, the wellbore fluid conductor comprising: a separator co-operating fluid conductor including a downhole wellbore fluid passage for receiving reservoir fluids from the reservoir and for conducting at least reservoir fluids; a separator including a first inlet port disposed in fluid communication with the liner fluid passage for receiving at least reservoir fluids from the liner fluid passage; a first outlet port; a reservoir fluid-conducting passage extending between the first inlet port and the first outlet port; a second inlet port disposed downhole relative to the first outlet port; a second outlet port; a gas-depleted fluid conducting passage extending between the second inlet port and the second outlet port; and a co-operating surface portion co-operating with the separator co-operating fluid conductor to define an intermediate fluid passage therebetween for effecting fluid communication between the first outlet port and
  • a system for processing at least reservoir fluids within a wellbore that is disposed within an oil reservoir comprising: a separator co-operating fluid conductor disposed within the wellbore, and including a downhole wellbore fluid passage for receiving reservoir fluids from the reservoir and for conducting at least reservoir fluids; a separator including: a first inlet port disposed in fluid communication with the downhole wellbore fluid passage for receiving at least reservoir fluids from the downhole wellbore fluid passage; a first outlet port; a reservoir fluid-conducting passage extending between the first inlet port and the first outlet port; a second inlet port disposed downhole relative to the first outlet port; a second outlet port; a gas-depleted fluid conducting passage extending between the second inlet port and the second outlet port; and a co-operating surface portion co-operating with the separator co-operating fluid conductor to define an intermediate fluid passage therebetween for effecting fluid communication between the first outlet port and the second inlet port; wherein the
  • a system for processing at least reservoir fluids within a wellbore that is disposed within an oil reservoir
  • the wellbore including a wellbore fluid conductor having a fluid passage
  • the wellbore fluid conductor comprising: a separator co-operating fluid conductor disposed within the wellbore, and including a downhole wellbore fluid passage for receiving reservoir fluids from the reservoir and for conducting at least reservoir fluids; a separator including: a first inlet port disposed in fluid communication with the downhole wellbore fluid passage for receiving at least reservoir fluids from the downhole wellbore fluid passage; a first outlet port; a reservoir fluid-conducting passage extending between the first inlet port and the first outlet port; a second inlet port disposed downhole relative to the first outlet port; a second outlet port; a gas-depleted fluid conducting passage extending between the second inlet port and the second outlet port; and a co-operating surface portion co-operating with the separator co-operating fluid conductor to define an intermediate
  • a separator for effecting separation of materials from reservoir fluid within a wellbore fluid conductor disposed within a wellbore, the wellbore fluid conductor including a separator co-operating fluid conductor, the separator co-operating fluid conductor including a downhole wellbore fluid passage for receiving reservoir fluids from the reservoir and for conducting at least reservoir fluids, wherein the separator comprises: a first inlet port for receiving at least reservoir fluids from the downhole wellbore fluid passage; a first outlet port; a reservoir fluid-conducting passage extending between the first inlet port and the first outlet port; a second inlet port, positioned relative to the first outlet port such that, when the separator is disposed within the wellbore and oriented for receiving at least reservoir fluids via the first inlet port, the second inlet portion is disposed downhole relative to the first outlet port; a second outlet port; a gas-depleted fluid conducting passage extending between the second inlet port and the second outlet port; a co-operating surface
  • a separator for separating material from at least reservoir fluid received from a fluid conductor of a wellbore in an oil reservoir, the separator comprising: an inlet port for receiving reservoir fluid from the fluid conductor and an outlet port for delivering gas-depleted reservoir fluid; a seal support member having an outer surface; and a sealing member supported by the seal support member, the sealing member being configured to sealingly, or substantially sealingly, engage the inlet port with the fluid conductor and prevent, or substantially prevent, the reservoir fluid from bypassing the inlet port, the sealing member projecting outwardly, from the outer surface by a distance of less than 2.5 mm.
  • a separator for effecting separation of materials from reservoir fluid within a wellbore fluid conductor disposed within a wellbore, the wellbore fluid conductor including a separator co-operating fluid conductor, the separator co-operating fluid conductor including a downhole wellbore fluid passage for receiving reservoir fluids from the reservoir and for conducting at least reservoir fluids, wherein the separator comprises: a first inlet port for receiving at least reservoir fluids from the downhole wellbore fluid passage; a first outlet port; a reservoir fluid-conducting passage extending between the first inlet port and the first outlet port; a second inlet port, positioned relative to the first outlet port such that, when the separator is disposed within the wellbore and oriented for receiving at least reservoir fluids via the first inlet port, the second inlet portion is disposed downhole relative to the first outlet port; a second outlet port; a gas-depleted fluid conducting passage extending between the second inlet port and the second outlet port; a co-operating surface
  • a separator for effecting separation of materials from reservoir fluid within a wellbore fluid conductor disposed within a wellbore, the wellbore fluid conductor including a separator co-operating fluid conductor and a liner, the separator co-operating fluid conductor including a downhole wellbore fluid passage for receiving reservoir fluids from the reservoir and for conducting at least reservoir fluids, the liner being coupled to and disposed in sealing, or substantially sealing, engagement with the separator co-operating fluid conductor, and including a liner fluid passage, such that the downhole wellbore fluid passage includes the liner fluid passage, wherein the separator comprises: a first inlet port for receiving at least reservoir fluids from the downhole wellbore fluid passage; a first outlet port; a reservoir fluid-conducting passage extending between the first inlet port and the first outlet port; a second inlet port, positioned relative to the first outlet port such that, when the separator is disposed within the wellbore and oriented for receiving at least reservoir fluids via
  • the terms “up”, “upward”, “upper”, or “uphole”, mean, relativistically, in closer proximity to the surface and further away from the bottom of the wellbore, when measured along the longitudinal axis of the wellbore.
  • the terms “down”, “downward”, “lower”, or “downhole” mean, relativistically, further away from the surface and in closer proximity to the bottom of the wellbore, when measured along the longitudinal axis of the wellbore.
  • the wellbore can be straight, curved, or branched.
  • the wellbore can have various wellbore portions.
  • a wellbore portion is an axial length of a wellbore.
  • a wellbore portion can be characterized as "vertical” or “horizontal” even though the actual axial orientation can vary from true vertical or true horizontal, and even though the axial path can tend to "corkscrew” or otherwise vary.
  • the term "horizontal”, when used to describe a wellbore portion refers to a horizontal or highly deviated wellbore portion as understood in the art, such as, for example, a wellbore portion having a longitudinal axis that is between 70 and 110 degrees from vertical.
  • the wellbore may be completed either as a cased-hole completion or an open-hole completion.
  • Well completion is the process of preparing the well for injection of fluids into the oil reservoir, or for production of reservoir fluid from the oil reservoir. This may involve the provision of a variety of components and systems to facilitate the injection and/or production of fluids, including components or systems to segregate oil reservoir zones along sections of the wellbore.
  • Reservoir fluid is fluid that is contained within an oil reservoir.
  • Reservoir fluid may be liquid material, gaseous material, or a mixture of liquid material and gaseous material.
  • the reservoir fluid includes water and hydrocarbons, such as oil, natural gas, or combinations thereof.
  • Fluids may be injected into the oil reservoir through the wellbore to effect stimulation of the reservoir fluid.
  • such fluid injection is effected during hydraulic fracturing, water flooding, water disposal, gas floods, gas disposal (including carbon dioxide sequestration), steam-assisted gravity drainage (“SAGD”) or cyclic steam stimulation (“CSS").
  • SAGD steam-assisted gravity drainage
  • CSS cyclic steam stimulation
  • the same wellbore is utilized for both stimulation and production operations, such as for hydraulically fractured formations or for formations subjected to CSS.
  • different wellbores are used, such as for formations subjected to SAGD, or formations subjected to waterflooding.
  • a cased-hole completion involves running wellbore casing down into the wellbore through the production zone.
  • the wellbore casing at least contributes to the stabilization of the oil reservoir after the wellbore has been completed, by at least contributing to the prevention of the collapse of the oil reservoir within which the wellbore is defined.
  • the annular region between the deployed wellbore casing and the oil reservoir may be filled with cement for effecting zonal isolation (see below).
  • the cement is disposed between the wellbore casing and the oil reservoir for the purpose of effecting isolation, or substantial isolation, of one or more zones of the oil reservoir from fluids disposed in another zone of the oil reservoir.
  • Such fluids include reservoir fluid being produced from another zone of the oil reservoir (in some embodiments, for example, such reservoir fluid being flowed through a production tubing string disposed within and extending through the wellbore casing to the surface), or injected fluids such as water, gas (including carbon dioxide), or stimulations fluids such as fracturing fluid or acid.
  • the cement is provided for effecting sealing, or substantial sealing, of fluid communication between one or more zones of the oil reservoir and one or more others zones of the oil reservoir (for example, such as a zone that is being produced).
  • sealing, or substantial sealing, of such fluid communication, isolation, or substantial isolation, of one or more zones of the oil reservoir, from another subterranean zone (such as a producing formation) is achieved.
  • Such isolation or substantial isolation is desirable, for example, for mitigating contamination of a water table within the oil reservoir by the reservoir fluid (e.g. oil, gas, salt water, or combinations thereof) being produced, or the above-described injected fluids.
  • the cement is disposed as a sheath within an annular region between the wellbore casing and the oil reservoir. In some embodiments, for example, the cement is bonded to both of the production casing and the oil reservoir.
  • the cement also provides one or more of the following functions: (a) strengthens and reinforces the structural integrity of the wellbore, (b) prevents, or substantially prevents, produced reservoir fluid of one zone from being diluted by water from other zones. (c) mitigates corrosion of the wellbore casing, and (d) at least contributes to the support of the wellbore casing.
  • cementing is introduced to an annular region between the wellbore casing and the oil reservoir after the subject wellbore casing has been run into the wellbore. This operation is known as "cementing".
  • the wellbore casing includes one or more casing strings, each of which is positioned within the well bore, having one end extending from the well head.
  • each casing string is defined by jointed segments of pipe. The jointed segments of pipe typically have threaded connections.
  • a wellbore typically contains multiple intervals of concentric casing strings, successively deployed within the previously run casing. With the exception of a liner string, casing strings typically run backup to the surface.
  • a production tubing string is usually installed inside the last casing string.
  • the production tubing string is provided to conduct reservoir fluid, received within the wellbore, to the wellhead.
  • the annular region between the last casing string and the production tubing string may be sealed at the bottom by a packer.
  • the wellbore casing may be perforated, or otherwise include per-existing ports, to provide a fluid passage for enabling flow of reservoir fluid from the reservoir to the wellbore.
  • the wellbore casing is set short of total depth.
  • the liner string can be made from the same material as the casing string, but, unlike the casing string, the liner string does not extend back to the wellhead.
  • Cement may be provided within the annular region between the liner string and the oil reservoir for effecting zonal isolation (see below), but is not in all cases.
  • this liner is perforated to effect fluid communication between the reservoir and the wellbore.
  • the liner string can also be a screen or is slotted.
  • the production tubing string may be stung into the liner string, thereby providing a fluid passage for conducting the produced reservoir fluid to the wellhead.
  • no cemented liner is installed, and this is called an open hole completion.
  • Open-hole completion is effected by drilling down to the top of the producing formation, and then casing the wellbore. The wellbore is then drilled through the producing formation, and the bottom of the wellbore is left open (i.e. uncased), to effect fluid communication between the reservoir and the wellbore.
  • Open-hole completion techniques include bare foot completions, pre-drilled and pre-slotted liners, and open-hole sand control techniques such as stand-alone screens, open hole gravel packs and open hole expandable screens. Packers can segment the open hole into separate intervals.
  • the system 10 includes an artificial lift system 12 a wellbore fluid conductor 100.
  • the artificial lift system 12 is provided to contribute to the production of reservoir fluids from the reservoir 22.
  • Suitable exemplary artificial lift systems include a pump, gas-lift systems, and jet lift systems.
  • a pump 12 is described herein, but it is understood that other artificial lift systems could be used.
  • the pump 12 is provided to, through mechanical action, energize and effect movement of the reservoir fluid from the reservoir 22, through the wellbore 14, and to the surface 24, and thereby effect production of the reservoir fluid.
  • the wellbore fluid conductor 100 includes a fluid passage 101, and is provided for conducting, through the wellbore 14, fluids being energized and moved by at least the pump 12. It is understood that the reservoir fluid may be energized by other means, including by gas-lift, as will be further discussed below with respect to some embodiments.
  • the fluid being conducted by through the fluid passage 101 of the wellbore fluid conductor 100, and also being energized and moved by the pump 12, includes gaseous material supplied from the surface and into the wellbore 14, for effecting gas-lift of the reservoir fluid.
  • the wellbore fluid conductor 100 includes an upstream fluid conductor 102.
  • the upstream fluid 102 conductor receives at least reservoir fluid from the wellbore 14, and conducts the received fluid within the wellbore 14.
  • the upstream fluid conductor 102 is disposed in fluid communication with the pump suction 16 such that at least a fraction of the received fluid being conducted by the upstream fluid conductor 102 is supplied the pump suction.
  • the wellbore fluid conductor 100 includes wellbore casing 130.
  • the wellbore fluid conductor 100 also includes a downstream fluid conductor 104, for conducting fluid, that is being discharged by the pump 12 through the pump discharge 18, to the surface, or gaseous material that has been separated by a separator 108 (see below).
  • the downstream fluid conductor 104 includes a piping or tubing string that extends from the pump discharge 18 to the wellhead 20.
  • the upstream fluid conductor 102 includes a separator co-operating fluid conductor 106, disposed within the wellbore 14, and a separator 108.
  • the separator co-operating fluid conductor 106 co-operates with the separator 108 to effect separation of at least a fraction of gaseous material from reservoir fluid being conducted through the upstream fluid conductor 102, prior to its introduction to the pump suction 16, as described below.
  • the wellbore fluid conductor 100 includes wellbore casing 130, and the wellbore casing 130 includes the separator co-operating fluid conductor 106.
  • the separator co-operating fluid conductor 106 includes an inlet port 110 for receiving reservoir fluids from the reservoir 20, and a downhole wellbore fluid passage 112 for effecting conducting (e.g. flowing) of the received fluid, including reservoir fluid, to the separator 108.
  • the separator 108 functions to effect depletion of gaseous material from the fluid being supplied by the downhole wellbore fluid passage 112, such that a fluid, depleted in gaseous material, is supplied to the pump suction.
  • Reservoir fluid may contain gaseous material.
  • the system 10 may include a gas lift component, in which case suitable infrastructure is provided so as to supply gaseous material for admixing with reservoir fluid received within the wellbore 14 so as to effect a density reduction in the fluid disposed within the wellbore 14 for conduction (such as by flowing) to the pump suction 16 (such density reduction effects a reduction in pressure of the fluid within the wellbore 14, increases drawdown, and thereby facilitates an increased rate of production of reservoir fluid from the reservoir 22).
  • the separator 108 in co-operation with the separator co-operating fluid conductor 106, is provided to, amongst other things, perform this function.
  • the separator 108 includes a first inlet port 114 and a first outlet port 116.
  • the first inlet port 114 is disposed in fluid communication with the downhole wellbore fluid passage 112 for receiving at least reservoir fluids (see directional arrow 502) from the downhole wellbore fluid passage 112.
  • a reservoir fluid-conducting passage 118 extends between the first inlet port 114 and the first outlet port 116.
  • the separator 108 also includes a second inlet port 120 and a second outlet port 122.
  • the second inlet port 120 is disposed downhole relative to the first outlet port 116.
  • a gas-depleted fluid conducting passage 124 extends between the second inlet port 120 and the second outlet port 122.
  • the first inlet port 114 of the separator 108 is disposed downhole relative to the second outlet port 122 of the separator 108.
  • the separator 108 further includes a co-operating surface portion 125.
  • the co-operating surface portion 125 co-operates with the separator co-operating fluid conductor 106 to define an intermediate fluid passage 126 (such as an annular fluid passage) therebetween for effecting fluid communication between the first outlet port 116 and the second inlet port 120. While at least reservoir fluid is flowing within the intermediate fluid passage 126 (see directional arrow 504), at least a fraction of gaseous material, within the downwardly flowing fluid within the intermediate fluid passage 126, is separated from the downwardly flowing fluid in response to buoyancy forces, to produce a gaseous material-depleted fluid.
  • the separated gaseous material is conducted uphole to the wellhead 20 through a conductor 131 that is disposed in fluid communication with the intermediate fluid passage 126.
  • the conductor 131 defines a gas conducting passage 131a disposed between the wellbore fluid conductor 100 (such as a wellbore casing) and a pressurized fluid conductor 128 that is extending uphole from a pump discharge 18 (see below).
  • the gaseous material-depleted fluid is conducted (see directional arrow 506) to the pump suction 16 via the gas-depleted fluid conducting passage 124.
  • the separator 108 is sealingly, or substantially sealingly, disposed relative to the separator co-operating fluid conductor 106.
  • the sealing, or substantially sealing, disposition is effected downhole relative to the second inlet port 120.
  • the sealing disposition is such that a sealing interface 300 is defined, and such that fluid flow, across the sealed interface 300, is prevented, or substantially prevented.
  • the sealing, or substantially sealing, disposition of the separator 108 relative to the separator co-operating fluid conductor 106 is with effect that fluid flow, across the sealed interface 300, in at least a downhole direction, is prevented, or substantially prevented.
  • the sealing, or substantially sealing, disposition of the separator 108 relative to the separator co-operating fluid conductor 106 is with effect that fluid, that is being conducted in a downhole direction within the intermediate fluid passage 126, is directed to the second inlet port 120.
  • the gaseous material-depleted fluid produced after the separation of gaseous material within the intermediate fluid passage 126, is directed to the second inlet port 122 (see directional arrow 508), and conducted to the pump suction 16 (see directional arrow 506) via the gas-depleted fluid conducting passage 124.
  • the wellbore fluid conductor 100 may also include a liner 132 that is connected or coupled to (for example, hung from), and sealed, or substantially sealed, relative to, the separator co-operating fluid conductor 106.
  • the liner 132 includes a liner fluid passage 134, such that the downhole wellbore fluid passage 112 includes the liner fluid passage 132.
  • the sealed, or substantially sealed, disposition of the liner 132 relative to the separator co-operating fluid conductor 108 is effected by a packer 136 disposed between the liner 132 and the wellbore casing 130.
  • the coupling and sealing, or substantially sealing, engagement between the liner 132 and the separator co-operating fluid conductor includes coupling and sealing, or substantially sealing, engagement between the liner 132 and the wellbore casing 130.
  • the separator co-operating fluid conductor 106 includes a constricted portion 138 of wellbore casing 130.
  • the separator 108 includes, or carries, a sealing member 202 for effecting the sealing, or substantially sealing, disposition of the separator 108 relative to the separator co-operating fluid conductor 106.
  • the sealing member 202 is a compressible sealing member.
  • the sealing member 202 includes one or more o-rings.
  • the wellbore casing 130 includes a casing fluid passage 1311, and the liner fluid passage 132 is disposed downhole from the casing fluid passage 1311.
  • the separator 108 is disposed within the casing fluid passage 1311.
  • the separator 108 includes a downhole fluid conductor 150 and a flow diverter 160.
  • the downhole fluid conductor 150 includes the first inlet port 114, a first intermediate outlet port 152, and a downhole reservoir fluid-conducting passage 154.
  • the downhole reservoir fluid-conducting passage 154 extends between the first inlet port 114 and the intermediate outlet port 152.
  • the downhole fluid conductor 150 also includes a separator sealing surface 156, such as a separator sealing surface defined by the sealing member 140.
  • the downhole fluid conductor 150 includes a piping or tubing string.
  • the downhole fluid conductor 150 includes, or carries, the sealing member 202.
  • the downhole fluid conductor 150 is configured such that received fluid (including reservoir fluids) is conducted through the downhole fluid conductor 150, and the conducting of the received fluid is such that the superficial gas velocity of gaseous material, of the received fluid, being conducted through the downhole fluid conductor 150, is greater than five (5) feet per second.
  • the flow diverter 160 includes a first intermediate inlet port 162, the first outlet port 116, and an uphole reservoir fluid-conducting passage 164.
  • the uphole reservoir fluid-conducting passage 164 extends between the intermediate inlet port and the first outlet port 116.
  • the flow diverter 160 also includes the second inlet port 120, the second outlet port 122, and the gas-depleted fluid conducting passage 124.
  • the gas-depleted fluid conducting passage 124 extends between the second inlet port 120 and the second outlet port 122.
  • the flow diverter 160 also includes the co-operating surface portion 125.
  • FIG. 3 to 7 An embodiment of a flow diverter 160 is illustrated in Figures 3 to 7 .
  • the flow diverter 160 includes a plurality of first outlet ports 116a, 116b, 116c, 116d and the uphole reservoir fluid-conducting passage 164 includes a plurality of branched fluid passage portions 164a, 164b, 164c, 164d (two are shown) that extend into corresponding first outlet ports 116a, 116b, 116c, 116d, for effecting fluid coupling with the first intermediate inlet port 162.
  • the flow diverter 160 further includes a plurality of second inlet ports 120a, 120b, 120c, 120d, and the gas-depleted fluid conducting passage 124 includes a plurality of branched fluid passage portions 124a, 124b, 124c, 124d (two are shown) extending from the second inlet ports 120a, 120b, 120c, 120d for effecting fluid coupling with the second outlet port 122.
  • the fluid diverter 160 includes a shroud (or "skirt") 161 extending downwardly below the second inlet ports 120a, 120b, 120c, 120d. This provides increased residence time for separation of gaseous material within the intermediate fluid passage 126.
  • the combination of the downhole fluid conductor 150 and the flow diverter 160 is such that the reservoir fluid-conducting passage 118 includes the downhole reservoir fluid-conducting passage 154 and the uphole reservoir fluid-conducting passage 164.
  • the downhole fluid conductor 150 is connected to the flow diverter 100 such that the intermediate outlet port 152 of the downhole fluid conductor 150 is disposed in fluid communication with the intermediate inlet port 162 of the flow diverter 160 , thereby effecting supplying of fluid from the intermediate outlet port 152 to the intermediate inlet port 162.
  • the downhole reservoir fluid conductor 150 is threadably connected to the flow diverter 160.
  • the axis of the second outlet port 122 of the flow diverter 160 is disposed in alignment, or substantial alignment, with the axis of the downhole reservoir fluid-conducting passage 154 of the downhole fluid conductor 150.
  • the separator 108 is connected to the pump 12 such that the second outlet port 122 is fluidly coupled to the pump suction 16 for supplying gaseous material-depleted fluid to the pump suction 16.
  • the connection is a threaded connection.
  • the pump 12 functions to effect transport of at least reservoir fluid from the reservoir 22 to the surface 24.
  • the pump 12 is a sucker rod pump.
  • Other suitable pumps include screw pumps, electrical submersible pumps, and jet pumps.
  • the pressurized fluid conductor 128 is connected to the pump discharge 18 such that an inlet port 129 of the pressurized fluid conductor 128 is fluidly coupled to the pump discharge 18 for receiving pressurized gaseous material-depleted fluid being discharged by the pump 12.
  • the pressurized fluid conductor 128 extends to the surface 24 via the wellhead 20 , to thereby effect transport of the gaseous material-depleted fluid to the surface 24 (see directional arrow 512).
  • the pressurized fluid conductor 128 is hung from the wellhead.
  • the reservoir fluid produced through the pressurized fluid conductor 128 may be discharged through the wellhead 20 to a collection facility, such as a storage tank within a battery.
  • the wellbore fluid conductor 100 is further configured to assist with production of reservoir fluids from the reservoir 22 by providing infrastructure to enable gas lift of the reservoir fluid received within the wellbore 14 from the reservoir.
  • the wellbore fluid conductor 100 includes a gaseous fluid conductor 170 for conducting gaseous material (see directional arrow 514) being supplied from a gaseous material source.
  • the gaseous fluid conductor 170 extends from the surface 124 and into the wellbore 14.
  • the gaseous fluid conductor 170 includes a piping or tubing string. In some of these embodiments, the piping or tubing string extends from the wellhead 20 and into the wellbore 14.
  • the gaseous fluid conductor 170 includes an outlet port 172 disposed in fluid communication with the inlet port 114 of the separator 108, for effecting admixing of gaseous material with reservoir fluid to produce a density-reduced fluid that includes the reservoir fluid.
  • the admixing is effected upstream of the inlet port 114, such that the inlet port 114 is disposed for receiving the density-reduced fluid.
  • the "at least reservoir fluid" includes the gaseous material that has been supplied from the surface.
  • the gaseous fluid conductor 170 includes an uphole gaseous fluid conductor 174, including an uphole gas conducting passage 175, and a downhole gaseous fluid conductor 176.
  • the uphole gaseous fluid conductor 174 extends between the surface 24 and the flow diverter 1160.
  • the uphole gaseous fluid conductor 174 is connected to the wellhead 20 and extends from the wellhead 20, and is disposed in fluid communication with a gaseous material supply source, disposed at the surface 24, via the wellhead 20 and through an inlet port 178 of the uphole gaseous fluid conductor 174, for receiving gaseous material from the gaseous material supply source and conducting the received gaseous material to the flow diverter 1160.
  • the uphole gaseous fluid conductor 174 is connected to the flow diverter 1160 such that an outlet port 180 of the uphole gaseous fluid conductor 174 is fluidly coupled to an inlet port 1602 of the flow diverter 160 for supplying the conducted gaseous material to the inlet port 1602 of the flow diverter 1160.
  • the downhole gaseous fluid conductor 176 extends downhole from the flow diverter 1160 to a position whereby the outlet port 172 of the downhole gaseous fluid conductor 176 is disposed for supplying the conducted gaseous material for admixing with reservoir fluid to produce a density-reduced fluid, upstream of the inlet port 114 of the downhole reservoir fluid conductor 150, such that the density-received fluid is disposed in fluid communication with the inlet port 114 of the downhole fluid conductor 150 for receiving by the inlet port 114 of the downhole fluid conductor 1160.
  • the downhole gaseous fluid conductor 176 is connected to the flow diverter 160 such that fluid communication between an outlet port 1604 of the flow diverter 1160 and an inlet port 184 of the downhole gaseous fluid conductor 176 is effected.
  • a gas-conducting passage 1606 which fluidly couples the inlet and outlet ports 1602, 1604, such that the fluid coupling of the outlet port 1604 of the flow diverter 1160 and the inlet port 184 of the downhole gaseous fluid conductor 176 effects supplying of the gaseous material, being conducted through the uphole gaseous fluid conductor 174, to the downhole gaseous fluid conductor 176.
  • the flow diverter 1160 effects fluid coupling between the uphole and downhole gaseous fluid conductors 174,176.
  • the downhole gas conducting passage 177 is disposed within the downhole fluid conductor 150, along with the downhole reservoir fluid-conducting passage 154.
  • the downhole fluid conductor 150 includes the downhole gas conducting passage 177 and the downhole reservoir fluid-conducting passage 154.
  • the downhole fluid conductor 150 includes the downhole gaseous fluid conductor 176, including the downhole gas conducting passage 177, and a downhole reservoir fluid conductor 190, including the downhole reservoir fluid-conducting passage 154, and the downhole reservoir fluid conductor 190 is nested within the downhole gaseous fluid conductor 176, such that the downhole gas conducting passage 177 is defined by an intermediate passage (such as an annulus) between the downhole gaseous fluid conductor 176 and the downhole reservoir fluid conductor 190.
  • an intermediate passage such as an annulus
  • the liner 132 is connected or coupled to (for example, hung from), and is disposed in sealing, or substantially sealing, engagement with the separator co-operating fluid conductor 106, and the separator 108 is disposed in sealing, or substantially sealing, engagement with the liner 132.
  • the first inlet port 114 is disposed for receiving at least reservoir fluid via the liner fluid passage 134.
  • the separator 108 further includes a latch seal assembly 200 releasably coupled to the liner 132, wherein the sealing, or substantially sealing, engagement between the liner 132 and the separator 108 is effected by the latch seal assembly 130.
  • a suitable latch seal assembly 130 is a WeatherfordTM Thread-Latch Anchor Seal Assembly.
  • the sealing, or substantially sealing, engagement includes sealing, or substantially sealing, engagement of the liner 132 to a separator sealing surface 156 of the separator 108, and the separator sealing surface 156 includes one or more o-rings.
  • the sealing, or substantially sealing, engagement includes sealing, or substantially sealing, engagement of the separator 108 to a polished bore receptacle 131 of the liner 132.
  • the separator 108 is disposed in an interference fit with the liner 132.
  • the separator 108 is landed or "stung" within the liner 132.
  • the combination of at least: (a) the sealing, or substantially sealing, engagement of the liner 132 with the wellbore casing 130, and (b) the sealing, or substantially sealing, engagement of the separator 108 with the liner 132 effects the sealing, or substantially sealing, disposition of the separator 108 (and, more specifically, the separator sealing surface 156) relative to the separator co-operating fluid conductor 106.
  • the combination of at least: (i) the sealing, or substantially sealing, engagement between the liner 132 and the separator co-operating fluid conductor 106, and (ii) the sealing, or substantially sealing, engagement between the separator sealing surface 156 and the liner 132, is such that the separator sealing surface 156 is sealed, or substantially sealed, relative to the separator co-operating fluid conductor 106 and thereby defines the sealed interface 301, such that fluid flow, across the sealed interface 301, is prevented or substantially prevented.
  • the combination of at least: (i) the sealing, or substantially sealing, engagement between the liner 132 and the separator co-operating fluid conductor 106, and (ii) the sealing, or substantially sealing, engagement between the separator sealing surface 156 and the liner 132, is with effect that fluid flow, across the sealed interface 301, in at least a downhole direction, is prevented or substantially prevented.
  • the combination of at least: (i) the sealing, or substantially sealing, engagement between the liner 132 and the separator co-operating fluid conductor 106 , and (ii) the sealing, or substantially sealing, engagement between the separator sealing surface 156 and the liner 132, is with effect that fluid, that is being conducted in a downhole direction within the intermediate fluid passage 126, is directed to the second inlet port 120.
  • the separator 108 includes (or carries) a sealing member 202, and the sealing member 202 is disposed between a sealing member engaging surface portion 157a of the separator 108 and the sealing member engaging surface portion 157b of the liner 132 for effecting sealing, or substantial sealing, of the sealing member engaging portion 157a of the separator 108 relative to the sealing member engaging portion 157b of the liner 132.
  • the sealing, or substantially sealing, disposition of the separator sealing member engaging surface portion 157a of the separator 108 relative to the separator co-operating fluid conductor 106 is effected downhole relative to the second inlet port 120. Further, this sealing, or substantially sealing, disposition is such that fluid flow, across the sealed interface 302, is prevented or substantially prevented.
  • the sealing member 202 having an exposed surface portion 202a, that is disposed in fluid communication with the intermediate fluid passage 126, is extending across a gap 204a, between the separator 108 and the liner 132, having a minimum distance of less than 2.5 millimitres.
  • the gap 204a has a minimum distance of less than one (1.0) millimetre.
  • the inlet port 114 is disposed in fluid communication with the liner fluid passage 134 and in sealing, or substantially sealing, engagement with the liner 132 to prevent, or substantially prevent, the at least reservoir fluid from bypassing the inlet port 114.
  • a separator sealing surface 156 is disposed in sealing, or substantially sealing, engagement with a constricted portion 138 of wellbore casing 130, such that the sealing, or substantially sealing, disposition of the separator sealing surface 156 relative to the separator co-operating fluid conductor 106 is effected by the sealing, or substantially sealing, engagement of the separator sealing surface 156 with the constricted portion 138 and defines a sealed interface 304.
  • the sealing, or substantially sealing, engagement of the separator sealing surface 156 with the constricted portion 138 is effected downhole relative to the second inlet port 120 and is with effect that fluid flow, across the sealed interface 304, is prevented, or substantially prevented.
  • the separator 108 is disposed in an interference fit with the constricted portion 138.
  • the constricted portion 138 ofwellbore casing 130 includes an inwardly extending projection.
  • the sealing, or substantially sealing, engagement between the separator sealing surface 156 and the constricted portion 138 is with effect that fluid flow, across the sealed interface 304, in at least a downhole direction, is prevented, or substantially prevented.
  • the sealing, or substantially sealing, engagement between the separator sealing surface 156 and the constricted portion 138 is with effect that fluid, that is being conducted in a downhole direction within the intermediate fluid passage 126, is directed to the second inlet port 120.
  • the separator 108 includes (or carries) a sealing member 202, and the sealing, or substantially sealing, engagement between the separator sealing surface 156 and the constricted portion 138 is effected by the sealing member 202.
  • the sealing member 202 is disposed between a sealing member engaging surface portion 157a of the separator 108 and a sealing member engaging portion 157c of the constricted portion 138 such that a sealed interface 306 is thereby defined, and such that fluid flow, across the sealed interface 306, is prevented, or substantially prevented.
  • the sealing member 202 having an exposed surface portion 202a, that is disposed in fluid communication with the intermediate fluid passage 126, is extending across a gap 204b, between the separator 208 and the constricted portion 138, having a minimum distance of less than 2.5 millimetres.
  • the gap 204b has a minimum distance of less than one (1) millimetre.
  • the above-described configurations for sealing, or substantially sealing, disposition of the separator 108 relative to the separator co-operating fluid conductor 106 provide for conditions which minimize solid debris accumulation in the joint between the separator 108 and the separator co-operating fluid conductor 106. By providing for conditions which minimize solid debris accumulation within the joint, interference to movement of the separator 108 relative to the separator co-operating fluid conductor 106, which could be effected by accumulated solid debris, is mitigated.
  • the space between: (a) the second inlet port 120 of the separator 108, and (b) the sealed interface (such as of sealed interface 300, 302, 304, or 306), defines a sump 206 for collection of solid particulate that is entrained within fluid being discharged from the first outlet port 116 of the separator 108, and the sump 206 has a volume of at least 0.1 m 3 .
  • the volume is at least 0.5 m 3 .
  • the volume is at least 1.0 m 3 .
  • the volume is at least 3.0 m 3 .
  • the space between: (a) the second inlet port 120 of the separator 108, and (b) the sealed interface (such as sealed interface 300, 302, 304, or 306), defines a sump 206 for collection of solid particulate that is entrained within fluid being discharged from the first outlet port 116 of the separator 108, and the minimum separation distance between: (a) the second inlet port 120 of the separator 108 , and (b) the sealed interface (such as sealed interface 300, 302, 304. or 306), measured along a line parallel to the axis of the fluid passage of the wellbore fluid conductor 100, is at least 30 feet, is at least 30 feet.
  • the minimum separation distance is at least 45 feet. In some embodiments, for example, the minimum separation distance is at least 60 feet.
  • the wellbore fluid conductor 100 includes the wellbore casing 130, and the wellbore casing 130 includes the separator co-operating fluid conductor 106, and the sealing, or substantially sealing, disposition of the separator 108 relative to the separator co-operating fluid conductor 106 is effected by at least a packer 208 disposed between the separator 108 and the wellbore casing 130.
  • the packer 208 is carried by the separator 108.
  • the packer 208 is disposed downhole relative to the second inlet port 120.
  • the wellbore fluid conductor further includes a liner 132, the liner 132 being connected or coupled to (such as, for example, by being hung from the wellbore casing 130), and being disposed in sealing, or substantially sealing, engagement with the wellbore casing 130 such that the above-described sealed interface is defined (as sealed interface 308).
  • the liner 132 includes a liner fluid passage 134, such that the downhole wellbore fluid conductor fluid passage 112 includes the liner fluid passage 112, and such that the first inlet port 114 is disposed for receiving at least reservoir fluids via the liner fluid passage 134.
  • the sealing, or substantially sealing, engagement between the liner and the wellbore casing is with effect that fluid flow, across the sealed interface 308, at least in a downhole direction, is prevented or substantially prevented at the sealing engagement.
  • the sealing, or substantially sealing, engagement between the liner 132 and the wellbore casing 130 is effected by a packer 136 disposed between the liner 132 and the wellbore casing 130.
  • the separator co-the liner 132 is connected or coupled to (such as, for example, being hung from) the separator co-operating fluid conductor 106 and disposed in sealing, or substantially sealing, engagement with the separator co-operating fluid conductor 106, and including a liner fluid passage 134, such that the downhole wellbore fluid passage 112 includes the liner fluid passage 134.
  • the separator 108 is disposed in sealing, or substantially sealing engagement with the liner 132.
  • the sealing, or substantially sealing, disposition of the separator 108 relative to the separator co-operating fluid conductor 106 is effected by at least: (a) the sealing, or substantially sealing, engagement of the liner 132 with the separator co-operating fluid conductor 106, and (b) the sealing, or substantially sealing, engagement of the separator 108 with the liner 132.
  • the first inlet port 114 is disposed for receiving at least reservoir fluid via the liner fluid passage 134.
  • the separator 108 further includes a latch seal assembly 200 releasably coupled to the liner 132, wherein the sealing, or substantially sealing, engagement between the liner 132 and the separator 108 is effected by the latch seal assembly 200.
  • the sealing, or substantially sealing, engagement between the liner 132 and the separator co-operating fluid conductor 106 is effected by a packer 136 disposed between the liner 132 and the separator co-operating fluid conductor 106.
  • the separator co-operating fluid conductor 106 includes a constricted portion 138, and the separator 108 is disposed in sealing, or substantially sealing, engagement with the constricted portion 138, such that the sealing, or substantially sealing, disposition of the separator 108 relative to the separator co-operating fluid conductor 106 is effected by at least the sealing, or substantially sealing, engagement of the separator 108 with the constricted portion 138.
  • the sealing, or substantially sealing, engagement between the separator 108 and the constricted portion 136 is effected by at least a sealing member 202 that is carried by the separator 108.
  • the separator 108 is disposed in an interference fit relationship with the constricted portion 138.
  • a suitable space is provided for collecting relative large volumes of solid debris, such that interference by the accumulated solid debris with the production of oil through the system is mitigated. This increases the run-time of the system before any maintenance is required. As well, because the solid debris is deposited over a larger area, the propensity for the collected solid debris to interfere with movement of the separator 108 relative to the separator co-operating fluid conductor 106, such as during maintenance (for example, a workover) is reduced.
  • a separator 108 is provided for effecting separation of materials from reservoir fluid within a wellbore fluid conductor 100 disposed within a wellbore
  • the wellbore fluid conductor 100 including a separator co-operating fluid conductor 106, the separator co-operating fluid conductor 106 including a downhole wellbore fluid passage for receiving reservoir fluids from the reservoir and for conducting at least reservoir fluids.
  • the separator 108 includes:
  • the sealing member 202 is supported by the seal support portion 1081.
  • the sealing member 202 is configured for sealingly, or substantially sealingly, engaging the separator co-operating fluid conductor 106.
  • the sealing member 202 is positioned relative to the second inlet port 120 such that, when the separator 108 is disposed within the wellbore 114 and oriented for receiving at least reservoir fluids via the first inlet port 114, the sealing member 202 is disposed downhole relative to the second inlet port 120 and in sealing, or substantially sealing, engagement with the separator co-operating fluid conductor 106.
  • the sealing member 202 is further configured such that, when the separator 108 is disposed within the wellbore 14 and oriented for receiving at least reservoir fluids via the first inlet port 114, and the sealing member 202 is sealingly, or substantially sealingly, engaged to the separator co-operating fluid conductor 106, the sealing member 202, having an exposed surface portion 202, that is disposed in fluid communication with the intermediate fluid passage 126, is extending across a gap, between the separator 108 and the separate co-operating fluid conductor 106, having a minimum distance of less than 2.5 millimetres. In some embodiments, for example, the gap has a minimum distance of less than one (1.0) millimetre.
  • the sealing member 202 projects outwardly from the outer surface 103 by a distance of less than 2.5 millimetres, such as less than one (1.0) millimetre.
  • the sealing member 202 is retractable, such that, in the retracted state, the sealing member 202 projects outwardly from the outer surface 103, by a distance of less than 2.5 millimetres, such as less than one (1.0) millimetre (it is understood that, in an extended state, such sealing member may project outwardly more than 2.5 millimitres when there is no resistance to deployment of the sealing member).
  • the separator 108 further includes a latch seal assembly 200, carrying the sealing member 202, and co-operatively configured for releasable connection to the separate co-operating fluid conductor 106.
  • the above-described configurations for the sealing member 202 of the separator 108 provide for conditions which minimize solid debris accumulation in the joint between the separator 108 and a separator co-operating fluid conductor 106, when the separator 108 is installed downhole and coupled to the separator co-operating fluid conductor 106.
  • conditions which minimize solid debris accumulation within the joint interference to movement of the separator 108 relative to the separator co-operating fluid conductor 106, which could be effected by accumulated solid debris, is mitigated.

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  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Fluid Mechanics (AREA)
  • Environmental & Geological Engineering (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Physics & Mathematics (AREA)
  • Physical Or Chemical Processes And Apparatus (AREA)
  • Separation Using Semi-Permeable Membranes (AREA)
  • Degasification And Air Bubble Elimination (AREA)
  • Cyclones (AREA)
  • Physical Water Treatments (AREA)
  • Feeding, Discharge, Calcimining, Fusing, And Gas-Generation Devices (AREA)
  • Sampling And Sample Adjustment (AREA)
  • Mechanical Engineering (AREA)
  • Carbon And Carbon Compounds (AREA)
EP18157720.6A 2013-09-13 2014-09-12 Systèmes et appareils permettant de séparer des fluides de puits de forage et de solides pendant la production Withdrawn EP3346090A1 (fr)

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
US14/026,170 US20150075772A1 (en) 2013-09-13 2013-09-13 System and Method for Separating Gaseous Material From Formation Fluids
CA2827459A CA2827459A1 (fr) 2013-09-13 2013-09-17 Systeme et procede pour separer une matiere gazeuse de fluides de formation
EP14844941.6A EP3044408A4 (fr) 2013-09-13 2014-09-12 Systèmes et appareils pour la séparation de fluides et de solides de trou de forage pendant la production
PCT/CA2014/000695 WO2015035509A1 (fr) 2013-09-13 2014-09-12 Systèmes et appareils pour la séparation de fluides et de solides de trou de forage pendant la production

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EP3346090A1 true EP3346090A1 (fr) 2018-07-11

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EP18157720.6A Withdrawn EP3346090A1 (fr) 2013-09-13 2014-09-12 Systèmes et appareils permettant de séparer des fluides de puits de forage et de solides pendant la production
EP14844941.6A Withdrawn EP3044408A4 (fr) 2013-09-13 2014-09-12 Systèmes et appareils pour la séparation de fluides et de solides de trou de forage pendant la production

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US (1) US20150075772A1 (fr)
EP (2) EP3346090A1 (fr)
CN (1) CN105705729A (fr)
AU (2) AU2014321104A1 (fr)
BR (1) BR112016005572A8 (fr)
CA (2) CA2827459A1 (fr)
CL (1) CL2016000607A1 (fr)
EA (1) EA201690585A1 (fr)
MX (1) MX2016003272A (fr)

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CA3050382A1 (fr) * 2018-07-25 2020-01-25 Heal Systems Lp Vanne de separation des gaz des liquides ouvrante et fermante sur le debit de fond de puits
CN109611035B (zh) * 2018-11-26 2023-11-10 中国石油大学(北京) 导管承载力加强装置及其使用方法
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Also Published As

Publication number Publication date
CA2923984A1 (fr) 2015-03-19
BR112016005572A8 (pt) 2020-02-18
US20150075772A1 (en) 2015-03-19
MX2016003272A (es) 2016-10-28
EP3044408A4 (fr) 2017-08-23
AU2014321104A1 (en) 2016-04-07
CA2827459A1 (fr) 2015-03-13
AU2019201116A1 (en) 2019-03-07
CN105705729A (zh) 2016-06-22
EP3044408A1 (fr) 2016-07-20
CL2016000607A1 (es) 2016-09-02
EA201690585A1 (ru) 2016-09-30

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