EP2463477B1 - Système et procédé pour l'exploitation de plusieurs vannes - Google Patents

Système et procédé pour l'exploitation de plusieurs vannes Download PDF

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Publication number
EP2463477B1
EP2463477B1 EP11192992.3A EP11192992A EP2463477B1 EP 2463477 B1 EP2463477 B1 EP 2463477B1 EP 11192992 A EP11192992 A EP 11192992A EP 2463477 B1 EP2463477 B1 EP 2463477B1
Authority
EP
European Patent Office
Prior art keywords
valve
state
providing
valves
tubular
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.)
Not-in-force
Application number
EP11192992.3A
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German (de)
English (en)
Other versions
EP2463477A1 (fr
Inventor
Kristoffer Braekke
Geir Lunde
Roger Antonsen
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.)
I-TEC AS
I Tec AS
Original Assignee
I-TEC AS
I Tec AS
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Publication of EP2463477A1 publication Critical patent/EP2463477A1/fr
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Publication of EP2463477B1 publication Critical patent/EP2463477B1/fr
Not-in-force 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
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in wells
    • E21B34/14—Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
    • E21B34/142—Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools unsupported or free-falling elements, e.g. balls, plugs, darts or pistons
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B2200/00—Special features related to earth drilling for obtaining oil, gas or water
    • E21B2200/04—Ball valves
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B2200/00—Special features related to earth drilling for obtaining oil, gas or water
    • E21B2200/06—Sleeve valves

Definitions

  • the present invention relates to a valve system and method for providing fluid flow between the interior and exterior of a tubular through several radial openings disposed along an axial length of the tubular. It allows opening multiple valves by one drop ball, and it may find applications in recovery of hydrocarbons from subterranean formations.
  • a subterranean formation containing hydrocarbons consists of at least one layer of soft or fractured rock to contain the hydrocarbons, in the following called a production layer. Each production layer must be covered by a layer of impermeable rock preventing the hydrocarbons from escaping.
  • the production layers in an oil or gas field are collectively known as the reservoir.
  • a production well extending through the reservoir is conventionally divided into production zones, one or more production zones per production layer.
  • a production well may extend several thousand meters vertically through the formation, and be connected to horizontal branches extending up to several kilometres through a production layer.
  • One or more injection wells may be provided at a distance from the production well(s) in a field.
  • the injection wells can be used to pump water, brine or gas into the formation in order to increase the pressure.
  • Additives such as acid, solvents or surfactants may be added to the fluid in order to enhance production of hydrocarbons in processes known as "stimulating a zone”.
  • the production and injection wells and horizontal branches are typically lined with a steel pipe cemented to the formation and penetrated at the production layer(s).
  • this pipe consists of sections having a decreasing diameter as the distance from the surface increases.
  • casing all steel pipes lining a borehole.
  • a smaller diameter production pipe or riser is provided within the casing of a production well, and used for conveying formation fluid typically consisting of a mixture of oil, water and gas, to the surface.
  • Steel pipes of different diameters used for casing, production pipes or risers are collectively known as tubulars.
  • Production zones may be separated by packers sealing the annulus formed by the outer surface of a production pipe and the inner surface of a casing.
  • the annulus formed by the borehole walls and outer circumference of a casing is usually sealed by cement and sometimes by open hole packers.
  • Hydraulic fracturing is a technique to enhance the flow of fluid from the formation, where the hydraulic pressure in a production zone is increased until fractures or cracks in the formation are enlarged.
  • a slurry containing fracturing material e.g. sand, ceramic balls or similar particles, is pumped into the cracks. When the fracturing pressure is removed, the fracturing material remains in the cracks, keeping them open.
  • the slurry containing fracturing material, e.g. sand, ceramic balls or similar particles, used for hydraulic fracturing is highly abrasive, especially where the flow of slurry changes direction from an axial direction through a pipe to a radial movement through openings in a valve.
  • a valve used for hydraulic fracturing may be lined with a hard material, e.g. tungsten carbide (WC).
  • WC tungsten carbide
  • Valves are used to control the flow of formation fluid from a production zone into the production pipe through the casing, possibly through a horizontal branch. Valves are also used for controlling an injection fluid from an injection well into a zone of the formation to be stimulated.
  • the production zone is shut down, typically by means of one or more valves.
  • the valves are operated between open and closed, and possibly choked, positions using a variety if techniques, including the use of wireline tools, strings of pipes, coiled tubing, self-propagating tools known as well tractors, and drop balls.
  • Some valves may be operated using separate hydraulic control lines. However, the space and cost required for providing separate hydraulic control lines and relatively expensive hydraulic valves quickly make hydraulically operated valves impractical for use in a tubular with many valves. This is especially true if the valves are to be opened once, and then left open.
  • a drop ball may be dropped or pumped into a tubular. Once it lands on a seat of a device, it prevents further fluid flow through the tubular, and hydraulic pressure builds up behind it. This hydraulic pressure may be used to operate the device, e.g. to open a valve.
  • a drop ball may provide a simple, inexpensive and convenient way to open a valve. It does not require expensive equipment like a string of pipes, coiled tubing or a well tractor, and it can be delivered to a device in less time than it takes to make up a string, insert coiled tubing or for a well tractor to crawl to the device.
  • fluid e.g. sea water or CO 2
  • fluid may be pumped into a production layer from an injection well.
  • the injected fluid ideally forces the hydrocarbons in front of it into a production pipe, e.g. a horizontal branch or a sealed off production zone of a production zone, and further through a riser to the surface.
  • a production pipe e.g. a horizontal branch or a sealed off production zone of a production zone
  • the flow of injected fluid will follow the easiest path to the nearest exit through a valve in a horizontal or vertical tubular, possibly leaving a substantial amount of desirable hydrocarbons in dead zones passed over by the easy path.
  • Devices monitoring the formation fluid from this zone would correctly detect a break through of injected fluid.
  • a break through of injected fluid may cause a decision to shut down the production zone, i.e. preventing more formation fluid flowing from the zone from entering the production pipe or riser, thus leaving valuable hydrocarbons in the dead zone in the formation permanently.
  • valves When two valves are open, an even larger pressure drop must be compensated to open the third valve, etc.
  • the valves should preferably have large radial openings, or nozzles, such that each valve tends to contribute a correspondingly large pressure drop as it is opened. This, in turn, may limit the number of valves operable by a drop ball in a tubular.
  • US 2006/060352 A1 , US 2006/196668 A1 and US2006/124310 A1 disclose a valve with close, intermediate and open positions.
  • a main objective of the present invention is to provide a tubular with a large number of valves while avoiding expensive valves, hydraulic control lines and/or expensive production time spent for operating the valves by means of wireline tools, strings, well tractors, etc.
  • a further objective is to handle the pressure drop associated with opening a valve, thereby reducing the hydraulic pressure available for opening the next valve by means of a drop ball.
  • valve system for providing fluid flow through radial openings disposed along an axial length of a tubular, wherein at least one valve group comprises at least two valves operable by e.g. one drop ball, each valve having a closed state, an intermediate state providing an intermediate opening for at least the time required to open all the remaining valves in the valve group, and an open state providing a full radial opening larger than the intermediate opening.
  • the present invention provides a method for providing fluid flow through radial openings disposed along an axial length of a tubular, comprising the steps of: disposing at least one valve group associated with a section of the tubular, the valve group containing at least two valves operable by e.g. one drop ball in the tubular, each valve having a closed state, an intermediate state providing an intermediate opening for at least the time required to open all the remaining valves in the group, and an open state providing a full radial opening larger than the intermediate opening; altering the state of each valve from the closed state to the intermediate state in turn using the drop ball, and altering the state of each valve from the intermediate to the open state.
  • the intermediate state is provided by an inset made of standard steel having a small opening and set into a harder lining, and altering from the intermediate to the open state involves pumping abrasive material through the inset until it is eroded away. Then, the harder lining provides a full radial opening.
  • the abrasive material can be a slurry containing material otherwise used for hydraulic fracturing.
  • the valve system may comprise one or more additional valves to shut down fluid flow from a group of valves when the concentration of hydrocarbons in the formation fluid flowing from the group falls below a predetermined level.
  • Fig. 1 is a schematic cross sectional view of a well system used in production of hydrocarbons, i.e. oil and/or gas, from a subterranean reservoir.
  • a hole or wellbore 101 is drilled through several layers of rock in the formation.
  • two production layers 100 and 200 are shown.
  • the wellbore is lined with a steel casing 102, which is cemented to the formation.
  • the production layers 100 and 200 contain hydrocarbons, and they are separated by rock layers that do not contain hydrocarbons.
  • the casing 102 may be penetrated at depths corresponding to the productive layers 100 and 200, and hydraulic fracturing may be used to create and open cracks in the formation to facilitate fluid flow from the formation into the production well.
  • Horizontal wells 100', 100" and 200' may branch out from a vertical production well, and extend several kilometres through a production layer 100, 200 containing hydrocarbons.
  • a production pipe 103 is provided within the casing 102, and the completed well can be divided into several production zones by using packers (not shown) to seal off the annular space formed by the outer surface of production pipe 103 and the inner surface of casing 102.
  • the valves 110A-C, 210A-C, ... shown in Fig.1 are disposed with predetermined distance(s) along the axial length of the production pipe 103 and control fluid flow from a formation 100, 200 into the segment of production pipe corresponding to the production zone.
  • the valves can generally be of different design or types, e.g. sliding sleeve valves, butterfly valves and ball valves of different sizes and designs, and used for different purposes as known in the art.
  • fluid flowing from several zones (shown by arrows 120) at different rates can be mixed and conveyed up the production pipe to the surface 10.
  • one or more injection wells 300 may be provided at a certain distance from the production well.
  • An injection well injects fluid into one or more zones, e.g. to increase the pressure in the reservoir or to provide some chemical composition(s), and can be made in a similar manner as the production well.
  • a typical oil or gas field can comprise one or more production wells and zero or more injection wells.
  • ball operated device is intended to include these and other devices when hydraulically operated using a drop ball, dart or similar device. All such ball operated devices comprises a seat on which the ball, dart or similar device can land.
  • the ball seat can be a cage- or tubular- or circular-shaped element displaced within a valve arrangement or sleeve and with a ring-shaped lug having a diameter less than the diameter of the ball, dart or similar device that is to land thereon.
  • drop balls of different sizes may be provided as in a conventional drop ball system. The difference is that a drop ball will pass groups of seats having similar sizes until it operates a group of valves rather than just one single device passed and operated on by conventional drop ball systems.
  • Fig. 2A-2B show a tubular 110 which can be a part of the production pipe 103 and with at least one group of at least two valves 110A-C, all of which are disposed within the tubular along the axial length thereof and with predetermined distance(s) from each other and can be provided with an expandable ball seat, for example as disclosed in US patent application 12/705,428 being herein incorporated by reference in its entirety, and thus can be opened one after the other using one and only one drop ball.
  • the valve 110A is closest to the surface, and hence opened first by e.g. the drop ball.
  • the valve 110A In fig. 2A the valve 110A is shown in a closed position, while in fig. 2B the valve 110A is shown in an open position.
  • Each valve 110A-110C can comprise means for providing for the three states of the valve or at least one radial opening therein.
  • the valve 110A is being opened (i.e. the radial openings or ports of the valve are being opened), e.g. by means of the drop ball (not shown), at least one valve nozzle 301 therein is providing for an intermediate state of the respective radial opening having an intermediate radial opening for at least some time that is required to open all the remaining valves 110B-110C in the valve group, and providing thereafter for an open state of the respective radial opening having a full radial opening larger than the intermediate radial opening.
  • an inset 302 in the valve nozzle 301 (shown in Fig 3 ), which can be made of e.g. tungsten carbide (WC) and is being arranged within at least one of the radial openings in the cylindrical valve wall, provides a small radial hole from the interior of tubular 110 to the surrounding formation.
  • the radial openings, that can comprise nozzles 301 can be circumferentially disposed in the valve (e.g. its tubular wall or sleeve) with any suitable or appropriate predetermined pattern and not only with the pattern shown in the drawings.
  • the inset 302 can be made of e.g.
  • valve 110B can comprise at least one nozzle 301 having an inset 302 being the same as or similar to the one in valve 110A, thus creating a new, small pressure drop. These pressure drops are made sufficiently small that they can be compensated in a relatively simple manner.
  • said altering means for providing for the three states of the valve or at least one radial opening therein can be associated with the ball seat arrangement operable by the drop ball or the like which provides for going from closed state to intermediate open state, and the nozzle 301 with the inset 302 which provides for going from intermediate open state to full open state.
  • said altering means can be associated with an inset 302 being a concentric ring (e.g. 301 in fig. 2B ) (with corresponding merging or overlapping intermediate holes) having an outer circumference firmly engaging the inner surface of the valve cylinder and covering all or at least some of the radial openings associated with said valve, thus providing for going from intermediate open state to full open state of said valve.
  • a recess in the inner area or surface or wall of the valve associated with the radial opening(s) for the further accommodation of the inset for further providing for the firmly engagement and for not allowing the ring-shaped inset to slide along the axis of the tubular or the valve.
  • the intermediate holes or openings of the inset can be overlapping or merging with the radial openings. All this means that the inset can be placed within/into (e.g. in form of a kind of a nozzle) or covering onto (e.g. in form of a concentric ring or cylinder) the associated radial opening(s) associated with said valve and/or its wall or sleeve.
  • the material providing for the full radial opening should be harder than the material providing for the intermediate opening (e.g. of the inset).
  • these materials should not be limited only to tungsten carbide (WC) and steel respectively.
  • the abrasive material can e.g. be a slurry with about 5% ceramic balls or sand, such as the medium used for hydraulic fracturing. In this case the slurry flows comparatively slowly in the central bore. When it reaches a hole, the speed increases. Hence the abrasion is much larger at the radial ports or openings or nozzles than in the central bore.
  • the ports can be lined with a hard material, e.g. tungsten carbide (WC), but not limited only thereto, providing the final openings. Ordinary steel can be set within the hard inner surface.
  • the hard liner can be a cylinder
  • the erodible steel inset can be shaped as a concentric ring having an outer circumference engaging the inner hard surface of the hard liner. Tests have shown that normal grade steel is removed from the liner within 1-2 hours using material(s) otherwise used for hydraulic fracturing thus providing for the full open state of the radial openings.
  • the liners need not be cylindrical and the insets do not need to be annular, but they can be elliptical or rectangular or have another suitable or appropriate shape or form.

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  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (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)
  • Check Valves (AREA)
  • Taps Or Cocks (AREA)
  • Lift Valve (AREA)

Claims (7)

  1. Système de soupapes pour la fourniture d'un flux de fluide via des ouvertures radiales disposées sur la longueur axiale d'un tube (110), comprenant au moins un groupe de soupapes comprenant au moins deux soupapes (110A-C, 210A-C) disposées sur la longueur axiale du tube (110) à une distance prédéterminée l'une de l'autre, caractérisé en ce que chaque soupape (110A-C, 210A-C) comprend en son sein des moyens d'obtenir trois états de la soupape : un état fermé, un état intermédiaire fournissant une ouverture intermédiaire pendant au moins le temps requis pour ouvrir toutes les soupapes restantes dans le groupe, et un état ouvert fournissant une ouverture radiale complète, plus large que l'ouverture intermédiaire, l'ouverture intermédiaire étant réalisée par un insert (302) monté sur ou dans l'ouverture radiale complète, un premier matériau constituant l'ouverture radiale complète étant plus dur qu'un deuxième matériau constituant l'insert (302), l'insert étant adapté de manière à être éliminé par l'érosion provoquée par une matière abrasive pompée via l'insert (302) afin de modifier l'état de chaque soupape (110A-C, 210A-C) la faisant passer de l'état intermédiaire à l'état ouvert.
  2. Système de soupapes selon la revendication 1, dans lequel au moins un groupe de soupapes (110A-C, 210A-C) peut fonctionner à l'aide d'au moins une sphère afin de faire passer les soupapes (110A-C, 210A-C) du groupe de soupapes de l'état fermé à l'état intermédiaire.
  3. Système de soupapes selon la revendication 1 ou 2, dans lequel chaque soupape (110A-C, 210A-C) dans ledit au moins un groupe de soupapes comprend un siège de sphère expansible dont le diamètre est adapté à la sphère.
  4. Système de soupapes selon l'une quelconque des revendications 1 à 5, comprenant en outre au moins une soupape pouvant être mise en oeuvre pour fermer le flux de fluide via le tube (110).
  5. Procédé de fourniture d'un flux de fluide via des ouvertures radiales disposées sur la longueur axiale d'un tube (110), comprenant les étapes suivantes :
    - disposer au moins un groupe de soupapes associé à une section du tube (110), le groupe de soupapes comprenant au moins deux soupapes (110A-C, 210A-C) disposées sur la longueur axiale du tube (110) à une distance prédéterminée l'une de l'autre, caractérisé en ce que chaque soupape (110A-C, 210A-C) comprend en son sein des moyens d'obtenir trois états de la soupape : un état fermé, un état intermédiaire fournissant une ouverture intermédiaire pendant au moins le temps requis pour ouvrir toutes les soupapes restantes dans le groupe, et un état ouvert fournissant une ouverture radiale complète, plus large que l'ouverture intermédiaire,
    - modifier l'état de chaque soupape (110A-C, 210A-C) la faisant passer alternativement de l'état fermé à l'état intermédiaire, et
    - modifier l'état de chaque soupape (110A-C, 210A-C) la faisant passer de l'état intermédiaire à l'état ouvert en pompant une matière abrasive via les ouvertures.
  6. Procédé selon la revendication 5, dans lequel au moins une sphère est utilisée pour faire passer les soupapes (110A-C, 210A-C) du groupe de soupapes de l'état fermé à l'état intermédiaire.
  7. Procédé selon la revendication 5 ou 6, comprenant en outre les étapes suivantes :
    - suivre le fluide traversant chaque section de soupape, et
    - fermer la section du tube (110) associée à une section de soupape lorsque le fluide qui la traverse ne satisfait plus des critères prédéterminés.
EP11192992.3A 2010-12-13 2011-12-12 Système et procédé pour l'exploitation de plusieurs vannes Not-in-force EP2463477B1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
NO20101748 2010-12-13
NO20111679A NO333111B1 (no) 2010-12-13 2011-12-09 System og fremgangsmate for handtering av en gruppe ventiler

Publications (2)

Publication Number Publication Date
EP2463477A1 EP2463477A1 (fr) 2012-06-13
EP2463477B1 true EP2463477B1 (fr) 2018-03-21

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EP11192992.3A Not-in-force EP2463477B1 (fr) 2010-12-13 2011-12-12 Système et procédé pour l'exploitation de plusieurs vannes

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EP (1) EP2463477B1 (fr)
CA (1) CA2761477C (fr)
NO (2) NO333111B1 (fr)

Families Citing this family (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
NO340047B1 (no) 2012-09-21 2017-03-06 I Tec As Fremgangsmåte, ventil og ventilsystem for komplettering, stimulering og senere restimulering av brønner for hydrokarbonproduksjon

Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6053250A (en) * 1996-02-22 2000-04-25 Halliburton Energy Services, Inc. Gravel pack apparatus
US20060060352A1 (en) * 2004-09-22 2006-03-23 Vidrine William L Sand control completion having smart well capability and method for use of same
US20060196668A1 (en) * 2005-03-05 2006-09-07 Inflow Control Solutions Limited Method, device and apparatus
WO2006134446A2 (fr) * 2005-06-15 2006-12-21 Paul Bernard Lee Nouveau mecanisme d'actionnement permettant de commander le fonctionnement d'un outil de fond

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Publication number Priority date Publication date Assignee Title
US5048611A (en) * 1990-06-04 1991-09-17 Lindsey Completion Systems, Inc. Pressure operated circulation valve
US6253861B1 (en) * 1998-02-25 2001-07-03 Specialised Petroleum Services Limited Circulation tool
CA2412072C (fr) * 2001-11-19 2012-06-19 Packers Plus Energy Services Inc. Methode et appareil pour le traitement de fluides de forage
US7387165B2 (en) * 2004-12-14 2008-06-17 Schlumberger Technology Corporation System for completing multiple well intervals
US9010447B2 (en) * 2009-05-07 2015-04-21 Packers Plus Energy Services Inc. Sliding sleeve sub and method and apparatus for wellbore fluid treatment

Patent Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6053250A (en) * 1996-02-22 2000-04-25 Halliburton Energy Services, Inc. Gravel pack apparatus
US20060060352A1 (en) * 2004-09-22 2006-03-23 Vidrine William L Sand control completion having smart well capability and method for use of same
US20060196668A1 (en) * 2005-03-05 2006-09-07 Inflow Control Solutions Limited Method, device and apparatus
WO2006134446A2 (fr) * 2005-06-15 2006-12-21 Paul Bernard Lee Nouveau mecanisme d'actionnement permettant de commander le fonctionnement d'un outil de fond

Also Published As

Publication number Publication date
NO333111B1 (no) 2013-03-04
CA2761477C (fr) 2019-01-22
NO2463477T3 (fr) 2018-08-18
EP2463477A1 (fr) 2012-06-13
CA2761477A1 (fr) 2012-06-13
NO20111679A1 (no) 2012-06-14

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