WO2017123579A1 - Well plug and abandonment choke insert - Google Patents
Well plug and abandonment choke insert Download PDFInfo
- Publication number
- WO2017123579A1 WO2017123579A1 PCT/US2017/012922 US2017012922W WO2017123579A1 WO 2017123579 A1 WO2017123579 A1 WO 2017123579A1 US 2017012922 W US2017012922 W US 2017012922W WO 2017123579 A1 WO2017123579 A1 WO 2017123579A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- wellbore
- choke device
- bore
- choke
- pressure
- Prior art date
Links
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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 DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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 DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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 the 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.
- US6520256 discloses a choke for use in cementing casings in oil and gas wells.
- 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.
- the process comprises the steps of (a) installing a choke device into the wellbore, the device having a through bore with a predetermined diameter, (b) determining the volume of the wellbore tubulars, liners, and perforations in the liners for the space being plugged; (c) injecting a controlled amount of settable medium into the wellbore, wherein the amount is based on the volume of the wellbore tubulars, liner and perforations in the liners, and (d) plugging the wellbore.
- Specific choke device configurations are also disclosed.
- 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.
- 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 about 1 from 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.
- 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.
- one or more settable medium such as cement-based media
- one or more settable medium 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.
- 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.
- 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 invention also relates to a plugged wellbore having located in it a choke device as described above.
- a process for plugging a wellbore comprising the steps of installing a choke device having a through bore with a predetermined diameter into the wellbore, determining a volume of wellbore tubulars and a volume of a perforated liner and its perforations, injecting a controlled, known volume of settable medium into the wellbore, wherein the volume of the settable medium is based upon the determined volume of the wellbore tubulars, perforated liner, and liner holes, and plugging the wellbore with the settable medium.
- 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.
- 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.
- Figure 1 is a side view of a choke insert in accordance with the invention.
- Figure 2 is a side view, partly in section, of a well Christmas tree showing the choke insert of Figure 1 in place;
- Figure 3 is a side view, partly in section, of part of a wellbore showing the choke insert of Figure 1 located against a nipple in the wellbore.
- 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 30 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
- 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.
Abstract
Description
Claims
Priority Applications (3)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
BR112018014157-7A BR112018014157B1 (en) | 2016-01-11 | 2017-01-11 | WELL CAP AND ABANDONMENT CHOKE INSERT |
AU2017207293A AU2017207293B2 (en) | 2016-01-11 | 2017-01-11 | Well plug and abandonment choke insert |
EP17738827.9A EP3402960B1 (en) | 2016-01-11 | 2017-01-11 | Well plug and abandonment choke insert |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US14/992,217 | 2016-01-11 | ||
US14/992,217 US9957775B2 (en) | 2011-03-01 | 2016-01-11 | Well plug and abandonment choke insert |
Publications (1)
Publication Number | Publication Date |
---|---|
WO2017123579A1 true WO2017123579A1 (en) | 2017-07-20 |
Family
ID=59311421
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/US2017/012922 WO2017123579A1 (en) | 2016-01-11 | 2017-01-11 | Well plug and abandonment choke insert |
Country Status (3)
Country | Link |
---|---|
EP (1) | EP3402960B1 (en) |
AU (1) | AU2017207293B2 (en) |
WO (1) | WO2017123579A1 (en) |
Citations (7)
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 |
US20120222862A1 (en) | 2011-03-01 | 2012-09-06 | Conocophillips Company | Well plug and abandonment choke insert |
US20160123110A1 (en) * | 2011-03-01 | 2016-05-05 | Conocophillips Company | Well plug and abandonment choke insert |
-
2017
- 2017-01-11 WO PCT/US2017/012922 patent/WO2017123579A1/en active Application Filing
- 2017-01-11 AU AU2017207293A patent/AU2017207293B2/en active Active
- 2017-01-11 EP EP17738827.9A patent/EP3402960B1/en active Active
Patent Citations (7)
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 |
US20120222862A1 (en) | 2011-03-01 | 2012-09-06 | Conocophillips Company | Well plug and abandonment choke insert |
US20160123110A1 (en) * | 2011-03-01 | 2016-05-05 | Conocophillips Company | Well plug and abandonment choke insert |
Also Published As
Publication number | Publication date |
---|---|
AU2017207293A1 (en) | 2018-08-02 |
EP3402960B1 (en) | 2020-05-20 |
AU2017207293B2 (en) | 2021-10-28 |
EP3402960A1 (en) | 2018-11-21 |
EP3402960A4 (en) | 2019-10-09 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
US9957775B2 (en) | Well plug and abandonment choke insert | |
US9670750B2 (en) | Methods of operating well bore stimulation valves | |
US9581003B2 (en) | Completing a well in a reservoir | |
EP3752704B1 (en) | Curing a lost circulation zone in a wellbore | |
US20150368997A1 (en) | Packer Setting Method Using Disintegrating Plug | |
AU2012223708B2 (en) | Well plug and abandonment choke insert | |
AU2017207293B2 (en) | Well plug and abandonment choke insert | |
RU2516062C1 (en) | Construction finishing method for horizontal producer | |
US4759408A (en) | Method of shutting off a portion of a producing zone in a hydrocarbon producing well | |
US10465478B2 (en) | Toe valve | |
US20130092401A1 (en) | Method and Flexible Bodies for Subterrain Sealing | |
US11098557B2 (en) | Liner wiper plug with rupture disk for wet shoe | |
BR112018014157B1 (en) | WELL CAP AND ABANDONMENT CHOKE INSERT | |
US10047586B2 (en) | Backpressure ball | |
EP3321469A1 (en) | Backpressure ball | |
US11619109B2 (en) | Methods of sealing polished bore receptacles by localized sealant injection | |
AU2016265971A1 (en) | Backpressure ball | |
CA2950230A1 (en) | Backpressure ball | |
RU2515740C1 (en) | Construction finishing method for horizontal steam injector | |
US20180355694A1 (en) | Pressure differential plug and method | |
RU2344273C1 (en) | Method of well hole operation and making | |
RU2326230C1 (en) | Method for pay isolation at casing cementing |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
121 | Ep: the epo has been informed by wipo that ep was designated in this application |
Ref document number: 17738827 Country of ref document: EP Kind code of ref document: A1 |
|
NENP | Non-entry into the national phase |
Ref country code: DE |
|
REG | Reference to national code |
Ref country code: BR Ref legal event code: B01A Ref document number: 112018014157 Country of ref document: BR |
|
ENP | Entry into the national phase |
Ref document number: 2017207293 Country of ref document: AU Date of ref document: 20170111 Kind code of ref document: A |
|
WWE | Wipo information: entry into national phase |
Ref document number: 2017738827 Country of ref document: EP |
|
ENP | Entry into the national phase |
Ref document number: 2017738827 Country of ref document: EP Effective date: 20180813 |
|
ENP | Entry into the national phase |
Ref document number: 112018014157 Country of ref document: BR Kind code of ref document: A2 Effective date: 20180711 |