EP2681410B1 - Bohrlochstopfen und drosseleinsatz für ausserbetriebsetzung - Google Patents

Bohrlochstopfen und drosseleinsatz für ausserbetriebsetzung Download PDF

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Publication number
EP2681410B1
EP2681410B1 EP12706747.8A EP12706747A EP2681410B1 EP 2681410 B1 EP2681410 B1 EP 2681410B1 EP 12706747 A EP12706747 A EP 12706747A EP 2681410 B1 EP2681410 B1 EP 2681410B1
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EP
European Patent Office
Prior art keywords
wellbore
choke device
choke
pressure
valve
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.)
Active
Application number
EP12706747.8A
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English (en)
French (fr)
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EP2681410A2 (de
Inventor
Thomas Eugene FERG
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.)
ConocoPhillips Co
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ConocoPhillips Co
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Publication date
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Publication of EP2681410A2 publication Critical patent/EP2681410A2/de
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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
    • E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
    • E21B21/10—Valve arrangements in drilling-fluid circulation systems
    • 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
    • E21B23/08—Introducing or running tools by fluid pressure, e.g. through-the-flow-line tool systems
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/13—Methods or devices for cementing, for plugging holes, crevices or the like

Definitions

  • This invention relates to a method and apparatus for plugging a wellbore (such as e.g. an oil or gas well), or for preparing wellbore to be plugged, e.g. when it has reached the end of its productive life.
  • the invention also relates to a plugged wellbore.
  • plugging may be achieved by injecting a settable substance or medium, e.g. cement, into the well.
  • a well will normally have production perforations, that is to say apertures in a well liner or casing through which hydrocarbon product enters from the rock formation and travels to the surface.
  • production perforations that is to say apertures in a well liner or casing through which hydrocarbon product enters from the rock formation and travels to the surface.
  • seal production perforations with cement or another settable medium which may then form a permanent barrier to flow across the perforations and out of the well.
  • the plugging process often involves pumping a surfactant liquid, known as a "spacer", into the well.
  • the purpose of the spacer is to remove oil residues from the internal surface of the well casing and/or liner and rock matrix making them “water wet” (allowing better adhesion by cement).
  • cement is pumped down the well to occupy the part of the well casing and/or liner where perforations are to be squeezed.
  • spacer liquid and possibly other liquids may be pumped down the well in order to place the cement at its final designed location.
  • bottom hole pressure sufficient reservoir pressure entering the well (bottom hole pressure) to support a standing column of relatively high specific gravity material, e.g. spacer liquid, cement and displacement fluid, reaching to the top of the well.
  • the spacer and cement and other liquids may then be pumped down against this pressure and thereby an accurate determination of each constituent's location be made at any given point within the process.
  • the bottom hole pressure is insufficient to support a standing column of relatively high specific gravity liquid reaching to the top of the well.
  • positive pressure against the fluid column at the surface cannot be maintained as liquids are introduced into the top of the well. This results in liquid free falling down the wellbore and out through the reservoir completion, i.e. the perforated section of casing/liner.
  • US6520256 discloses a choke for use in cementing casings in oil and gas wells.
  • US2,169,569 discloses a choke which is incorporated into the production tubing.
  • the invention more particularly includes a process for plugging a wellbore wherein the process comprises the steps of installing a choke device into the wellbore by pumping the device down the wellbore, the device having a through bore with a predetermined diameter.
  • the invention is particularly applicable when the bottom hole pressure of the wellbore is insufficient to support a standing column of liquid of specific gravity 1 reaching to the surface.
  • the choke device may be installed by a combination of pumping and allowing it to free fall down the well. If the wellbore includes a nipple, the choke device may bottom out at the nipple.
  • the choke device includes a pump out valve.
  • the pump out valve may be thought of as a device for blocking the through bore until a predetermined pressure is applied e.g. on the proximal side of the valve.
  • the valve may be an arrangement as simple as a deformable plug of spherical or other shape which is located in the through bore between two shoulders; when the pressure increases beyond a certain level the plug is forced out thereby opening the bore for liquid to flow through it.
  • the step of installing the choke device may include inserting the device between the swab valve and the master valve (top or bottom master valve) and then opening the necessary valves below the device to gain access to the wellbore.
  • settable medium such as cement
  • surfactant may be injected into the wellbore before the settable liquid, and another liquid may be injected after.
  • the pressure at the surface would normally be monitored in which case it may be possible to determine from the monitored pressure when the settable medium reaches the choke device.
  • the choke device itself may comprise a body capable of being pumped down a wellbore.
  • the body may have an external profile including a shoulder, a through bore and a pump out valve which blocks the through bore until a predetermined pressure is applied to the valve.
  • the pump out valve may be a ball retained in the through bore by a stop surface. Seals may be provided on the external profile of the body.
  • a method of preparing a wellbore for plugging may comprise inserting into the wellbore a choke device as described above.
  • the method may include applying pressure to the choke device thereby pumping the device through the wellbore and subsequently increasing the pressure to a level at which the pump out valve is actuated and the through bore unblocked. This preferably happens when the device has reached a nipple in the wellbore, e.g. adjacent a production packer.
  • the invention also relates to a plugged wellbore having located in it a choke device as described above.
  • wellbore as used herein shall be taken to mean an oil or gas well or a water injector.
  • Figure 1 shows a choke insert 1. It comprises a cast body of aluminum having a generally cylindrical shape. Its outer profile includes a proximal portion 2 and a distal portion 3 of reduced diameter compared with the proximal portion.
  • proximal and distal relate to the orientation of the device when in place in a well: the proximal portion being closer to the surface and the distal portion closer to the end of the well.
  • a shoulder 4 Between the proximal and distal portions is a shoulder 4. On the outer profile in the reduced diameter distal portion are two seals 5. The function of the seals 5 is to restrict fluid flow around the outside of the insert 1 such that all flow is directed through the device. Extending through the device is a bore 6 having a diameter which decreases towards the distal end of the device; at its most distal end, the bore 6 has a diameter 7 as shown in Figure 1 .
  • the bore 6 is provided with a flared proximal end 8, to help to reduce turbulence within the fluid flow regime.
  • An end plug 11 is screwed into the distal end of the bore of the insert 1 which provides an internal shoulder or stop surface 12.
  • the end plug has a bore 13 of the same diameter 7 as the most distal part of the bore 6 through the main body of the choke insert 1.
  • the bore 13 also has a flared end 9 to help reduce turbulence.
  • a ball 10 of Phenolic plastic which sits adjacent the stop surface 12.
  • the ball 10 is retained between the stop surface 12 and the distal end of the bore 6 in the main body.
  • the dimensions and elastic modulus of the ball are carefully established, relative to the diameter 7, such that the ball will deform and pass the stop surface 12 if a predetermined pressure is applied to the proximal side of the ball 10.
  • Figure 2 shows the Christmas tree valve arrangement at the top of a wellbore to be plugged.
  • the length of the choke insert 1 is chosen so that it will fit into the christmas tree 20 between the swab valve 21 and the upper master valve 22.
  • the overall outer diameter is chosen so that it will pass down the well to a point just above the reservoir.
  • the dimensions of the distal portion 3 and the shoulder 4 are chosen so that the choke insert device 1 will rest against a nipple 31 (see Figure 3 ) in the wellbore 30 in region of the top of the reservoir, near the production packer (not shown).
  • sea water is pumped down the well to determine whether it is possible to inject liquid into the perforations in the producing part of the well (not shown) which it is desired to squeeze (block with cement or other settable plugging fluid).
  • a gage device of diameter and length determined by the choke insert and the tubular being traversed, is also lowered into the well to determine whether any obstructions are present which may obstruct and prevent the correct positioning of the choke insert.
  • the bottom master valves and swab valve are closed and any trapped pressure is bled off between them at the wing valve 23.
  • the swab valve is then opened and the choke insert 1 is then inserted into the Christmas tree 20, the swab valve 21 closed, and then the bottom and upper master valves are 24, 22 opened.
  • the choke insert 1 then free falls down the well.
  • the choke may reach the desired location (nipple 31) without pumping. Normally, however, the friction will be too great and/or the well has an inclined or horizontal portion and the insert has to be pumped. Sea water is normally used for this purpose. Pumping continues until an increase in back pressure is noted which is indicative of the choke having come to rest at the profile nipple 31.
  • Step rate tests are then conducted to determine the back pressure created by the choke at increasing injection rates. This data is used to refine the predicted surface treating pressure profile which should be experienced during the place of the plugging fluid.
  • Spacer fluid a specialized mixture of chemicals including surfactants, is then pumped down the well at a rate sufficient to maintain positive pressure and contact with the top of the fluid column.
  • the choke insert 1 with its small diameter bore, allows the fluid column to maintain the positive back pressure.
  • Cement is then delivered in a continuous liquid column directly following the spacer fluid.
  • a further liquid or liquids e.g. further spacer fluid or other liquids, follow the cement in a continuous liquid column. Pressure continues to be applied to the cement via this liquid column, and monitoring of back pressure continues.
  • a pressure change may be recorded at surface due to its unique viscosity and density.
  • the volume of the wellbore tubulars can be determined as well as the volume of the perforated liner, so the volume of cement pumped down the well can be controlled to give the best chance of filling the perforated liner with cement.
  • a further change in surface pressure may be noted due to its unique viscosity and density. The aim is to squeeze all the perforations but not to over- or under-displace the cement column.

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  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • Physics & Mathematics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Mechanical Engineering (AREA)
  • Consolidation Of Soil By Introduction Of Solidifying Substances Into Soil (AREA)
  • Fluid-Pressure Circuits (AREA)
  • Management, Administration, Business Operations System, And Electronic Commerce (AREA)

Claims (14)

  1. Ein Verfahren zum Verstopfen eines Bohrlochs (30), dadurch gekennzeichnet, dass besagtes Verfahren folgende Schritte umfasst:
    - Installation einer Drosselvorrichtung (1) in ein Bohrloch, wobei die Vorrichtung eine Durchgangsbohrung (6) eines prädeterminierten Durchmessers hat;
    - Einspritzung in das Bohrloch eines setzbaren Mediums;
    dadurch gekennzeichnet, dass der Schritt der Installation der Drosselvorrichtung das Pumpen der Drosselvorrichtung im Bohrloch nach unten umfasst.
  2. Das Verfahren gemäß Anspruch 1 oder Anspruch 2, dadurch gekennzeichnet, dass der Bodenlochdruck des Bohrlochs (30) nicht ausreicht, um eine Standsäule einer Flüssigkeit einer spezifischen Schwerkraft 1 zu tragen, welche die Oberfläche erreicht.
  3. Das Verfahren gemäß einem der vorstehenden Ansprüche, dadurch gekennzeichnet, dass der Schritt der Installation der Drosselvorrichtung (1) der Drosselvorrichtung ermöglicht, frei im Bohrloch nach unten zu fallen.
  4. Das Verfahren gemäß einem der vorstehenden Ansprüche, dadurch gekennzeichnet, dass das Bohrloch (30) einen Nippel (31) umfasst, wobei sich die Installation der Drosselvorrichtung (1) den Drosselvorrichtungsboden außerhalb des Nippels (31) befindet.
  5. Das Verfahren gemäß Anspruch 4, dadurch gekennzeichnet, dass die Drosselvorrichtung (1) ein Auspumpventil umfasst und der Schritt der Installation der Drosselvorrichtung das Pumpen der Vorrichtung in das Bohrloch (30) hinunter umfasst, bis sie den Tiefpunkt am Nippel (31) erreicht und durch das Weiterpumpen der Druck auf die Vorrichtung so erhöht wird, bis das Auspumpventil aktiviert wird.
  6. Das Verfahren gemäß einem der vorstehenden Ansprüche, dadurch gekennzeichnet, dass sich oben am Bohrloch ein Eruptionskreuz (20) mit einem Swab-Ventil (21) und einem Master-Ventil (22) befindet, wobei der Schritt der Installation der Drosselvorrichtung (1) die Einführung der Drosselvorrichtung zwischen dem Swab-Ventil (21) und dem Master-Ventil (22) sowie das anschließend Öffnen des Master-Ventils umfasst, um der Vorrichtung (1) zu ermöglichen, in das Bohrloch (30) einzudringen.
  7. Das Verfahren gemäß einem der vorstehenden Ansprüche, dadurch gekennzeichnet, dass ein proximaler Teil des Bohrlochs (30) zwischen der Drosselvorrichtung (1) und der Oberfläche und ein distaler Teil des Bohrlochs (30) zwischen der Drosselvorrichtung (1) und dem distalen Ende des Bohrlochs definiert ist, und wo der Schritt der Injizierung des setzbaren Medium die Injizierung von einem Teil oder des gesamten setzbaren Mediums durch die Drosselvorrichtung (1) in den distalen Teil des Bohrlochs (30) umfasst.
  8. Das Verfahren gemäß einem der vorstehenden Ansprüche, dadurch gekennzeichnet, dass es darüber hinaus vor der Injizierung des setzbaren Mediums den Schritt der Injizierung einer Tensid-Flüssigkeit in das Bohrloch (30) sowie - optional - den Schritt der Injizierung einer dritten Flüssigkeit nach der Injizierung des setzbaren Mediums umfasst, wobei das Verfahren optional die Drucküberwachung an der Oberfläche des Tensids, des setzbaren Mediums und der dritten Flüssigkeit und optional darüber hinaus ab dem überwachten Oberflächendruck die Determinierung des Moments umfasst, in dem das setzbare Medium die Drosselvorrichtung (1) erreicht.
  9. Eine Drosselvorrichtung (1) zur Verwendung in einem Verfahren zum Verstopfen eines Bohrlochs, dadurch gekennzeichnet, dass die Vorrichtung einen Körper umfasst, der geeignet ist, in ein Bohrloch (30) heruntergepumpt zu werden, wobei der Körper folgendes umfasst:
    a) ein externes Profil mit einer Schulter (4);
    b) eine Durchgangsbohrung (6);
    c) ein Auspumpventil, welches die Durchgangsbohrung solange blockiert, bis das Ventil mit einem vorgegebenen Druck beaufschlagt wird.
  10. Die Drosselvorrichtung gemäß Anspruch 9, dadurch gekennzeichnet, dass die Durchgangsbohrung (6) eine Anschlagfläche (12) enthält, wobei das Auspumpventil eine Kugel (10) umfasst, die durch die Anschlagfläche (12) in der Durchgangsbohrung (6) zurückgehalten wird.
  11. Die Drosselvorrichtung gemäß Anspruch 9 oder 10, dadurch gekennzeichnet, dass auf dem externen Profil des Körpers eine oder mehrere Dichtungen (5) angebracht sind.
  12. Ein verstopftes Bohrloch mit, in seinem Innern, einer Drosselvorrichtung (1) gemäß einem der Ansprüche 9 bis 11.
  13. Ein Verfahren zur Vorbereitung eines zu verstopfenden Bohrlochs (30), welche die Einführung in das Bohrloch (30) einer Drosselvorrichtung (1) gemäß einem der Ansprüche 9 bis 11 umfasst.
  14. Das Verfahren gemäß Anspruch 13, dadurch gekennzeichnet, dass sie darüber hinaus die folgenden Schritte umfasst:
    a) Beaufschlagung, auf einem ersten Niveau, der Drosselvorrichtung (1) mit einem Druck, wobei der besagte Druck unter dem besagten vorgegebenen Druckniveau ist, wobei die Vorrichtung (1) hierdurch durch das Bohrloch (30) gepumpt wird, und die Vorrichtung optional durch das Bohrloch gepumpt wird, bis sie einen Nippel (31) erreicht, und wobei der Nippel (31) optional an eine Abdichtung des Bohrlochs angrenzt; und
    b) die subsequente Beaufschlagung, auf einem zweiten Niveau, der Drosselvorrichtung (1) mit einem Druck, der über dem oder am vorgegebenen Niveau liegt und wobei das besagte Auspumpventil aktiviert und die Durchgangsbohrung (6) entriegelt wird.
EP12706747.8A 2011-03-01 2012-02-13 Bohrlochstopfen und drosseleinsatz für ausserbetriebsetzung Active EP2681410B1 (de)

Applications Claiming Priority (3)

Application Number Priority Date Filing Date Title
US201161447789P 2011-03-01 2011-03-01
US13/371,784 US20120222862A1 (en) 2011-03-01 2012-02-13 Well plug and abandonment choke insert
PCT/US2012/024867 WO2012118611A2 (en) 2011-03-01 2012-02-13 Well plug and abandonment choke insert

Publications (2)

Publication Number Publication Date
EP2681410A2 EP2681410A2 (de) 2014-01-08
EP2681410B1 true EP2681410B1 (de) 2016-05-04

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EP12706747.8A Active EP2681410B1 (de) 2011-03-01 2012-02-13 Bohrlochstopfen und drosseleinsatz für ausserbetriebsetzung

Country Status (5)

Country Link
US (1) US20120222862A1 (de)
EP (1) EP2681410B1 (de)
AU (1) AU2012223708B2 (de)
BR (1) BR112013021998B1 (de)
WO (1) WO2012118611A2 (de)

Families Citing this family (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US9957775B2 (en) * 2011-03-01 2018-05-01 Conocophillips Company Well plug and abandonment choke insert
US10047586B2 (en) * 2014-03-02 2018-08-14 Thomas Eugene FERG Backpressure ball
AU2017207293B2 (en) 2016-01-11 2021-10-28 Conocophillips Company Well plug and abandonment choke insert

Family Cites Families (13)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US1339955A (en) * 1919-02-26 1920-05-11 Hardel Jean Amedee Apparatus for and process of lining wells
US2212086A (en) * 1936-10-27 1940-08-20 Charles W Thornhill Float collar and guide shoe
US2169569A (en) * 1938-06-03 1939-08-15 Halliburton Oil Well Cementing Plugging off bottom hole water under pressure
US2274093A (en) * 1938-10-19 1942-02-24 Standard Oil Dev Co Apparatus for completing submarine wells
US2263566A (en) * 1938-11-28 1941-11-25 Boynton Alexander Cementing device
US2382578A (en) * 1943-06-08 1945-08-14 Arthur J Penick Producing equipment for wells
US4589495A (en) * 1984-04-19 1986-05-20 Weatherford U.S., Inc. Apparatus and method for inserting flow control means into a well casing
US5277255A (en) * 1992-04-30 1994-01-11 Atlantic Richfield Company Well liner running shoe
US5890537A (en) * 1996-08-13 1999-04-06 Schlumberger Technology Corporation Wiper plug launching system for cementing casing and liners
US6279654B1 (en) * 1996-10-04 2001-08-28 Donald E. Mosing Method and multi-purpose apparatus for dispensing and circulating fluid in wellbore casing
US6520256B2 (en) * 2001-04-20 2003-02-18 Phillips Petroleum Co Method and apparatus for cementing an air drilled well
US7275595B2 (en) * 2004-05-13 2007-10-02 Schlumberger Technology Corporation Method and apparatus to isolate fluids during gravel pack operations
US7866392B2 (en) * 2007-12-12 2011-01-11 Halliburton Energy Services Inc. Method and apparatus for sealing and cementing a wellbore

Also Published As

Publication number Publication date
AU2012223708B2 (en) 2016-12-01
EP2681410A2 (de) 2014-01-08
WO2012118611A3 (en) 2013-08-01
BR112013021998B1 (pt) 2021-02-17
AU2012223708A1 (en) 2013-10-17
BR112013021998A2 (pt) 2016-11-29
WO2012118611A2 (en) 2012-09-07
US20120222862A1 (en) 2012-09-06

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