EP3402960B1 - Bouchon de puits et pièce rapportée d'étranglement pour l'abandon - Google Patents

Bouchon de puits et pièce rapportée d'étranglement pour l'abandon Download PDF

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Publication number
EP3402960B1
EP3402960B1 EP17738827.9A EP17738827A EP3402960B1 EP 3402960 B1 EP3402960 B1 EP 3402960B1 EP 17738827 A EP17738827 A EP 17738827A EP 3402960 B1 EP3402960 B1 EP 3402960B1
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EP
European Patent Office
Prior art keywords
wellbore
choke device
choke
process according
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
EP17738827.9A
Other languages
German (de)
English (en)
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EP3402960A4 (fr
EP3402960A1 (fr
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
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
Priority claimed from US14/992,217 external-priority patent/US9957775B2/en
Application filed by ConocoPhillips Co filed Critical ConocoPhillips Co
Publication of EP3402960A1 publication Critical patent/EP3402960A1/fr
Publication of EP3402960A4 publication Critical patent/EP3402960A4/fr
Application granted granted Critical
Publication of EP3402960B1 publication Critical patent/EP3402960B1/fr
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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
    • 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
    • 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

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 a 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.
  • US2012/222862 A1 discloses a process for plugging a wellbore comprising installing a choke device into a wellbore to increase the back pressure and allow better control when introducing cement to plug the wellbore.
  • the invention includes a method for plugging a wellbore of a predetermined volume and utilizing a choke device to control the settable medium being injected thereto.
  • a process for plugging a wellbore comprising the steps of (a) installing a choke device into a wellbore tubular, the choke device having a through bore with a predetermined diameter, (b) determining the volume inside said wellbore tubular plus a volume of perforations in said wellbore tubular; (c) injecting a settable medium into the wellbore, wherein the volume of the settable medium injected into the wellbore is controlled based upon the determined volume inside said wellbore tubulars plus the volume of the perforations, and (d) plugging the wellbore.
  • Specific choke device configurations are also disclosed.
  • Injections of settable media are frequently made in the wellbore to line a well or annulus. Such applications only require calculating the cross-section of the well and determining the amount of cement needed to obtain a given thickness for the cement lining.
  • the presently disclosed methods are directed to plugging a wellbore, including wellbores with perforated liners. This distinction is important because different volume considerations and calculations are needed to obtain the correct amount of settable medium.
  • an excess or dearth of settable media results in a thicker or thinner lining.
  • plugging a wellbore the injection of too much settable medium or not enough settable media can have negative effects on wellbore plugging.
  • Errors in displacement can result in partially plugged perforations, plugged perforations in the distal part of the wellbore but not the proximal portion, plugged perforations in the proximal portion and blocked access to the distal portion with open perforations and the like.
  • the present methods operate in a tight window to ensure a proper amount of settable medium is injected to effectively squeeze the wellbore.
  • an appropriate amount of settable media can be squeezed into the desired perforations and tubulars without over- or under-displacing the settable media column.
  • Any settable medium can be used and can include major components such as cement (e.g. Portland cement, hydraulic cement, slag cement and the like), cement kiln dust, pumice, and/or ash.
  • cement e.g. Portland cement, hydraulic cement, slag cement and the like
  • cement kiln dust e.g. Portland cement, hydraulic cement, slag cement and the like
  • pumice e.g. pumice, and/or ash.
  • the invention is particularly applicable when the bottom hole pressure of the wellbore is insufficient to support a standing column of liquid having specific gravity of 1 reaching to the surface.
  • the choke device may be installed by allowing it to free fall down the well or it may be pumped down the well, or a combination of the two. If the wellbore includes a nipple, the choke device may bottom out at the nipple.
  • the choke device itself may also comprise a body capable of being passed 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.
  • the choke device includes a pump out valve and the step of installing the choke device comprises pumping the choke device down the wellbore until it bottoms out at the nipple and then continuing to thereby increasing pressure on the choke device until the pump out valve is actuated.
  • 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 master valve to allow the choke device to enter the wellbore.
  • one or more settable medium (such as cement-based media) may be injected into the wellbore, through the choke device, and into the distal part of the wellbore, that is to say the part beyond the choke device.
  • the process according to the invention further comprises the step of injecting a surfactant liquid into the wellbore prior to injecting the settable medium
  • Surfactant may be injected into the wellbore before the settable liquid, and another fluid may be injected after.
  • the pressure at the surface would normally be monitored, as it may be possible to determine from the monitored pressure when the settable medium reaches the choke device.
  • the process may further comprise the step of injecting a third liquid after injecting the settable medium.
  • the process may comprise monitoring pressure at the surface of surfactant liquid, settable medium and third liquid.
  • the process may further comprise determining from said monitored surface pressure when the settable medium reaches the choke device.
  • 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.
  • a predetermined amount of settable medium can be injected into the wellbore where it will flow through the choke device.
  • the choke device will control the pressure and volume entering the space below the choke, which will allow the settable medium to plug the wellbore without being flushed into the reservoir.
  • the disclosure also relates to a plugged wellbore having located in it a choke device as described above.
  • the present methods includes any of the following embodiments in any combination(s) of one or more thereof:
  • the wellbore may have a proximal part defined between the choke device and the surface and a distal part defined between the choke device and the distal end of the wellbore so that the step of injecting a settable medium comprises injecting some or all of the settable medium through the choke device into the distal part of the wellbore.
  • the choke device can have a body capable of being passed down a wellbore, wherein the body has an external profile which includes a shoulder; a through bore; and a pump out valve which blocks the through bore until a predetermined level of pressure is applied to the valve.
  • the through bore can include a stop surface and the pump out valve can have a ball retained in the through bore by the stop surface.
  • One or more seals may be provided on the external profile of the body.
  • the disclosure also relates to a method of preparing a wellbore to be plugged comprising (i) inserting into the well a choke device, wherein the device comprises a body capable of being passed down a wellbore, wherein the body has an external profile which includes a shoulder a through bore, and a pump out valve which blocks the through bore until a predetermined level of pressure is applied to the valve; and (ii) determining the volume of wellbore tubulars and a volume of a perforated liner, including perforations, to control a volume of a settable medium to be injected into the wellbore.
  • Additional steps in this method include applying pressure at a first level to the choke device, wherein the pressure is below a predetermined pressure level, thereby pumping the device through the wellbore; and subsequently applying pressure to the choke device at a second level at or above the predetermined level, whereby the pump out valve is activated and the through bore unblocked.
  • the choke device can be pumped through the wellbore until it reaches a nipple, which may be adjacent to a production packer of the wellbore.
  • a plugged wellbore having located therein a choke device, wherein the choke device has a body capable of being passed down a wellbore, wherein the body has an external profile that includes a shoulder, a through bore, and a pump out valve which blocks the through bore until a predetermined level of pressure is applied to the valve.
  • the choke device can be installed by allowing the choke device to free-fall down the wellbore or by pumping the choke device down the wellbore. If the wellbore includes a nipple, then the choke device can be installed so that it bottoms out at the nipple.
  • the choke device can include a pump out valve and the step of installing the choke device includes pumping the choke device down the wellbore until it bottoms out at the nipple and then continuing to pump thereby increasing pressure on the device until the pump out valve is actuated.
  • the wellbore has a Christmas tree located at the top of the wellbore. If the Christmas tree has a swab valve and a master valve, then installing the choke device comprises inserting the choke device between the swab valve and the master valve and then opening the master valve to allow the device to enter the wellbore.
  • This process can also be used 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.
  • a surfactant liquid is injecting into the wellbore prior to injecting the settable medium.
  • a third liquid is used after injecting the settable medium. The pressure at the surface can be monitored for the surfactant liquid, settable medium and/or third liquid, which can help determine when the settable medium has reached the choke device.
  • wellbore as used herein shall be taken to mean an oil or gas well or a water injector.
  • settable fluid or “settable medium” are used interchangeable and are taken to mean a composition that over time sets to form a hardened mass. It should be noted that the medium can include other fluids such as water, brine, salt water, sea water and the like to improve flow of the major components through the wellbore.
  • the settable medium can contain additional additives such as fly ash, metakaolin, shale, zeolite, gas, crystalline silica, amorphous silica, salt, fiber, hydratable clay, microspheres, pozzolan, lime, latex cement, and combinations thereof.
  • additional additives such as fly ash, metakaolin, shale, zeolite, gas, crystalline silica, amorphous silica, salt, fiber, hydratable clay, microspheres, pozzolan, lime, latex cement, and combinations thereof.
  • fluid or liquid are used interchangeable to denote a free flowing substance of constant volume.
  • volume of the perforated liner includes the interior volume of the cylindrical shape of the liner plus the volume of any perforations (area of the perforation x thickness of liner) in the liner.
  • liners have one perforation shape that repeats over the length of the liner, thus resulting in one volume equation multiplied by the number of perforations.
  • liners can have multiple shapes and patterns, resulting in the use of more than one volume equation for the perforations.
  • the volumes of the wellbore tubulars and the perforated liner to be plugged are determined so the volume of settable medium column pumped down the well can be controlled to give the best chance of filling the perforated liner with settable medium without over- or under-displacing the settable medium column.
  • the volume is calculated using the equation for a cylinder: Pi ⁇ r 2 ⁇ h, wherein r is the radius and h is height. The volume of each tubular being plugged will be added together.
  • the same equation for the cylinder can be used for the base structure, however additional measurements to account for the perforations must be added thereto.
  • Volume calculations for a variety of shapes are well known and can be applied to the various perforations shapes in a liner.
  • liners come pre-stamped with a particular shape(s) in a particular pattern and with a particular number of perforations.
  • the volume for each shape can be calculated and multiplied by the number of perforations of that shape and added to the base volume of the cylinder.
  • sea water is pumped into 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 gauge device of diameter and length determined by the choke insert and the wellbore 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 choke device is introduced into the wellbore.
  • Figure 1 shows a choke insert 1 having a generally cylindrical shaped, cast body of aluminum. 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, not around it. Extending through the device is a bore 6 having a diameter that 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 a Christmas tree valve arrangement at the top of a wellbore to be plugged.
  • a valve arrangement is often used in wellbores.
  • 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 in region of the top of the reservoir, near the production packer (not shown).
  • 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 inserted into the Christmas tree 20, the swab valve 21 closed, and then the bottom and upper master valves 24, 22 are 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 choke 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. Pumping is continued until the pressure rises sufficiently to displace the ball 10 past the stop surface 12. A sudden drop in monitored pressure indicates that the ball has been displaced. 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 that should be experienced during the placing 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.
  • a settable medium such as cement, is then delivered in a continuous liquid column directly following the spacer fluid. Additional 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 settable medium 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.
  • a further change in surface pressure may be noted due to its unique viscosity and density.

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  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Mechanical Engineering (AREA)
  • Consolidation Of Soil By Introduction Of Solidifying Substances Into Soil (AREA)

Claims (12)

  1. Procédé de bouchage d'un puits de forage, le procédé comprenant les étapes consistant à :
    a) installer un dispositif d'étranglement (1) dans un tube (30) de puits de forage, le dispositif d'étranglement (1) ayant un trou traversant (6) d'un diamètre prédéfini ;
    b) déterminer un volume à l'intérieur dudit tube (30) de puits de forage plus un volume de perforations dans ledit tube (30) de puits de forage ;
    c) injecter un milieu durcissable dans le puits de forage, un volume du milieu durcissable injecté dans le puits de forage étant commandé sur la base du volume déterminé à l'intérieur desdits tubes (30) de puits de forage plus le volume des perforations ; et
    d) boucher ledit puits de forage.
  2. Procédé selon la revendication 1, la pression de fond du trou de forage étant insuffisante pour supporter une colonne verticale de liquide de gravité spécifique 1 atteignant la surface.
  3. Procédé selon la revendication 1, l'installation du dispositif d'étranglement (1) comprenant l'étape consistant à laisser le dispositif d'étranglement (1) tomber en chute libre dans le puits de forage.
  4. Procédé selon la revendication 1, l'installation du dispositif d'étranglement (1) comprenant l'étape consistant à pomper le dispositif d'étranglement (1) vers le bas du puits de forage.
  5. Procédé selon la revendication 1, le puits de forage comprenant un mamelon (31) et l'installation du dispositif d'étranglement (1) comprenant l'étape consistant à avoir le dispositif d'étranglement (1) en bas au niveau du mamelon (31).
  6. Procédé selon la revendication 5, le dispositif d'étranglement (1) comprenant un robinet de mise sous vide (10) et l'installation du dispositif d'étranglement (1) comprenant les étapes consistant à pomper le dispositif d'étranglement (1) vers le bas du puits de forage jusqu'à ce qu'il atteigne le fond au niveau du mamelon (31) puis à poursuivre le pompage, augmentant ainsi la pression sur le dispositif d'étranglement (1) jusqu'à ce que le robinet de mise sous vide (10) soit actionné.
  7. Procédé selon la revendication 1, un arbre de Noël (20) avec une vanne à piston (21) et une vanne principale (22) étant situé au sommet du puits de forage et l'installation du dispositif d'étranglement (1) comprenant l'étape consistant à insérer le dispositif d'étranglement (1) entre la vanne à piston (21) et la vanne principale (22) puis à ouvrir la vanne principale (22) pour permettre au dispositif d'étranglement (1) de pénétrer dans le puits de forage.
  8. Procédé selon la revendication 1, une partie proximale du puits de forage étant définie entre le dispositif d'étranglement (1) et la surface et une partie distale du puits de forage étant définie entre le dispositif d'étranglement (1) et l'extrémité distale du puits de forage et l'injection d'un milieu durcissable comprenant l'étape consistant à injecter une partie ou la totalité du milieu durcissable à travers le dispositif d'étranglement (1) dans la partie distale du puits de forage.
  9. Procédé selon la revendication 1, comprenant en outre l'étape consistant à injecter un liquide tensioactif dans le puits de forage avant l'injection du milieu durcissable.
  10. Procédé selon la revendication 9, comprenant en outre l'étape consistant à injecter un troisième liquide après l'injection du milieu durcissable.
  11. Procédé selon la revendication 10, comprenant l'étape consistant à surveiller la pression à la surface du liquide tensioactif, du milieu durcissable et du troisième liquide.
  12. Procédé selon la revendication 11, comprenant en outre l'étape consistant à déterminer, à partir de ladite pression de surface surveillée, le moment où le milieu durcissable atteint le dispositif d'étranglement (1) .
EP17738827.9A 2016-01-11 2017-01-11 Bouchon de puits et pièce rapportée d'étranglement pour l'abandon Active EP3402960B1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US14/992,217 US9957775B2 (en) 2011-03-01 2016-01-11 Well plug and abandonment choke insert
PCT/US2017/012922 WO2017123579A1 (fr) 2016-01-11 2017-01-11 Bouchon de puits et pièce rapportée d'étranglement pour l'abandon

Publications (3)

Publication Number Publication Date
EP3402960A1 EP3402960A1 (fr) 2018-11-21
EP3402960A4 EP3402960A4 (fr) 2019-10-09
EP3402960B1 true EP3402960B1 (fr) 2020-05-20

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ID=59311421

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Application Number Title Priority Date Filing Date
EP17738827.9A Active EP3402960B1 (fr) 2016-01-11 2017-01-11 Bouchon de puits et pièce rapportée d'étranglement pour l'abandon

Country Status (3)

Country Link
EP (1) EP3402960B1 (fr)
AU (1) AU2017207293B2 (fr)
WO (1) WO2017123579A1 (fr)

Family Cites Families (7)

* 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
US2169569A (en) * 1938-06-03 1939-08-15 Halliburton Oil Well Cementing Plugging off bottom hole water under pressure
US4589495A (en) * 1984-04-19 1986-05-20 Weatherford U.S., Inc. Apparatus and method for inserting flow control means into a well 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
US9957775B2 (en) * 2011-03-01 2018-05-01 Conocophillips Company Well plug and abandonment choke insert
US20120222862A1 (en) 2011-03-01 2012-09-06 Conocophillips Company Well plug and abandonment choke insert

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
None *

Also Published As

Publication number Publication date
EP3402960A4 (fr) 2019-10-09
EP3402960A1 (fr) 2018-11-21
AU2017207293B2 (en) 2021-10-28
AU2017207293A1 (en) 2018-08-02
WO2017123579A1 (fr) 2017-07-20

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