EP3631150B1 - Bohrlochwerkzeugeinsetzanordnung mit verbesserter heizerentfernbarkeit und verfahren zur anwendung davon - Google Patents

Bohrlochwerkzeugeinsetzanordnung mit verbesserter heizerentfernbarkeit und verfahren zur anwendung davon Download PDF

Info

Publication number
EP3631150B1
EP3631150B1 EP18728449.2A EP18728449A EP3631150B1 EP 3631150 B1 EP3631150 B1 EP 3631150B1 EP 18728449 A EP18728449 A EP 18728449A EP 3631150 B1 EP3631150 B1 EP 3631150B1
Authority
EP
European Patent Office
Prior art keywords
alloy
tubular
heater
assembly
downhole
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
EP18728449.2A
Other languages
English (en)
French (fr)
Other versions
EP3631150A1 (de
Inventor
Paul Carragher
Lance Underwood
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.)
Bisn Tec Ltd
Original Assignee
Bisn Tec Ltd
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 PCT/GB2017/051458 external-priority patent/WO2017203248A1/en
Application filed by Bisn Tec Ltd filed Critical Bisn Tec Ltd
Publication of EP3631150A1 publication Critical patent/EP3631150A1/de
Application granted granted Critical
Publication of EP3631150B1 publication Critical patent/EP3631150B1/de
Active legal-status Critical Current
Anticipated expiration legal-status Critical

Links

Images

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
    • E21B33/12—Packers; Plugs
    • E21B33/1208—Packers; Plugs characterised by the construction of the sealing or packing means
    • E21B33/1212—Packers; Plugs characterised by the construction of the sealing or packing means including a metal-to-metal seal element
    • 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
    • E21B29/00—Cutting or destroying pipes, packers, plugs or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground
    • E21B29/10—Reconditioning of well casings, e.g. straightening
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/12—Packers; Plugs
    • E21B33/124—Units with longitudinally-spaced plugs for isolating the intermediate space
    • 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
    • E21B36/00—Heating, cooling or insulating arrangements for boreholes or wells, e.g. for use in permafrost zones
    • 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
    • E21B36/00—Heating, cooling or insulating arrangements for boreholes or wells, e.g. for use in permafrost zones
    • E21B36/008—Heating, cooling or insulating arrangements for boreholes or wells, e.g. for use in permafrost zones using chemical heat generating means
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/02—Subsoil filtering
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/02—Subsoil filtering
    • E21B43/04—Gravelling of wells
    • E21B43/045—Crossover tools

Definitions

  • the present invention relates to tools for use in downhole environments such as oil and gas wells.
  • the present invention relates to tools capable of being temporarily deployed downhole and subsequently removed.
  • One common task is the carrying out of repairs to the existing well tubing, which due to the downhole environment can develop fractures/leaks over time.
  • Another common task is to isolate (whether temporarily or semi-permanently) a region of a well from the rest of the production tubing.
  • Various downhole tools are employed in such situations. Some of the most commonly used include: bridge plugs, patches, scab and straddles. In order to secure the downhole tool within a well such tools are typically provided with hydraulically actuated means that can be operated to engage with the surface of a surrounding tubing (e.g. a well casing, well liner or production tubing).
  • a surrounding tubing e.g. a well casing, well liner or production tubing.
  • a plurality of these engagement means which are commonly referred to as 'dogs' or 'slips', are normally provided on a downhole tool so that once the tool is in place they can be actuated to lock the tool in position relative to the surrounding tubing.
  • the 'dogs' or 'slips' can be retracted and the tool can be retrieved from the well.
  • the 'dogs' or 'slips' are capable of retaining a downhole tool in position within a well, they do not form a gas tight seal with the surrounding tubing. In view of this, on occasions where a gas tight seal is required the downhole tool is provided with additional sealing means. This can increase the possibility of a malfunction of the downhole tool.
  • Some types of downhole tools such as expandable patches, are secured in position by expanding the main body of the downhole tool so that it pushes against the inner surface of the outer tubing.
  • Another approach which has been developed by the applicant, utilises the interesting properties of eutectic/bismuth based alloys to help securely locate tools within downhole target regions.
  • a heat source is inserted into the tubular tool and positioned at a point within the tool that is adjacent to the externally mounted alloy. Once in position the heat source is used to melt the alloy, which flows a short distance before it begins to cool and turn back into a solid.
  • the alloy can form a connection between the tubular tool and the nearby surrounding structure, which will typically be a well casing or tubing but could also be formation.
  • the alloy forms a metal to metal connection between the tubular tool and the surrounding well casing/tubing.
  • the heater is retrieved leaving the interior of the secured tool clear.
  • the retrieval of the heater is relatively straight forward because the heater and the alloy are prevented from coming into direct contact with one another by the main body of the tubular tool.
  • the retrieval of the heater becomes much more challenging when the heater and the alloy are allowed to come into direct contact with one another. This can occur in more slim-line, low profile tools where no intermediate tubing is present and the alloy is mounted directly on the heater. This is because the alloy, as it cools and turns back into a solid, can trap a portion of the heater body and prevent its extraction.
  • US 3,208,530 A relates to an apparatus for setting bridge plugs that employs bismuth containing alloys.
  • US 2006/0144591 A1 relates to a method and an apparatus for repairing downhole structures using meltable repair materials, wherein the repair materials are melted using an exothermic reaction material, such as therm ite.
  • the present invention provides an improved downhole tool deployment assembly and methods of using such.
  • a downhole tool deployment assembly in accordance with claim 1 is provided.
  • the weight saving made from not extending the intermediate tubing along the entire length of the heater, as has been done in the past, can enable additional alloy and/or chemical heat source material to be carried by the assembly.
  • tubular heat conducting member coaxially on the tubular heater body of the heater enables the heater to continue to heat the melted alloy even after it has slumped away from, and out of direct contact with, the tubular heater body. This ensures that the necessary clearance is achieved between the heater and the tool when the alloy cools so that the heater does not become trapped by the alloy.
  • releasably mounting the tubular heat conducting member on the heater primarily using the alloy facilitates the detachment of the heater from the tool once the alloy has melted.
  • the tool itself may serve as a plug if the tubular member is blocked (e.g. with an end plate or burst disk).
  • the clearance between the heater tubular body and the annular heat conducting member ensures that, once the alloy has melted and slumped, the heater can be retrieved from within the annular heat conducting member so as to reveal the internal cavity of the annular heat conducting member.
  • the collar is positioned at the trailing end of the tubular heat conducting member to ensure that the melted alloy cannot flow into the clearance gap provided between the heater tubular body and the tubular heat conducting member. It is envisaged that if the alloy was able to flow into the clearance gap it could form a connection between the body and member that would hamper the retrieval of the heater.
  • the alloy may be at least partially enclosed within an insulating sleeve.
  • Providing a sleeve with insulating properties is considered highly beneficial because it serves to reduce heat loss from the tool of the present invention. This means that any heat generated by the tool is used more efficiently, which in turn means that less chemical heat source material, for example, is needed to achieve a certain heat output. This again allows the weight of the assembly to be reduced.
  • This more efficient use of the chemical heat source material also means that less space needs to be given over to the cavity in the heater body, which in turn enables the overall diameter of the tool to be decreased without necessarily also increasing the length of the heater.
  • Providing an outer sleeve with insulating properties also helps to prevent heat being 'sucked away' from the tool as a consequence of the environmental conditional within the target region.
  • insulating the tool in this way prevent heat loss as a result of 'cross-flow' within the well.
  • Providing the insulation also helps to ⁇ super heat' the alloy that is held between the heater body and the sleeve. This enables the molten alloy to penetrate further into the surrounding environment when it eventually leaves the tool. This is considered particularly beneficial when forming seals in wells located in sand pack formations, (e.g. OHGPs).
  • the insulating sleeve may comprise one or more openings in the region adjacent to the collar.
  • the insulating sleeve may comprise one or more weakened points in the region adjacent to the collar; said weakened points being configured to fail before the rest of the insulating sleeve.
  • tubular heat conducting member may be formed from aluminium. However it is envisaged that steel alloys may alternatively be used.
  • the assembly comprises a skirt portion located at the end of the tubular heat conducting member remote from the collar.
  • the skirt portion facilitates the cooling of the molten alloy as it flows down the assembly because it enables cooler downhole fluids to collect within the open end of the skirt.
  • the tubular heat conducting member may further comprise an end plate located at the end of the tubular heat conducting member remote from the collar.
  • the end plate closes off the tubular heat conducting member so that the tool, once deployed, forms a plug in the well.
  • end plate together with the collar, limits the extent to which the tubular heater body can be received within the tubular heat conducting member.
  • additional releasable fixing means may be provided to retain the heater within the tubular heat conducting member.
  • a suitable releasable fixing means would be shear pins.
  • Another alternative releasable fixing means is a shear ring.
  • the internal cavity of the tubular heater body may contain a chemical reaction heat source.
  • the chemical reaction heat source may comprise a plurality of stacked blocks (e.g. thermite blocks), wherein the heating characteristics of each block may vary along the stack.
  • the chemical reaction heat source may also be provided as fragmented thermite blocks (i.e. crumble) and/or in powdered form.
  • the inner walls of the tubular heater body may be provided with a layer of a refractory material.
  • a refractory material examples include fibre glass, Kevlar ® and a coating of ceramic material, such as zirconium oxide (ZrO 2 ), aluminium oxide, magnesium oxide.
  • ZrO 2 zirconium oxide
  • Other suitable refractory materials will be appreciated by the skilled person upon consideration of the following explanation.
  • Coating the inside of the tubular heater body with a refractory lining provides a number of benefits.
  • a lining within the heater body prevents the chemical heat source material (e.g. thermite) from sticking to the inside surface of the tubular heater body. This is a problem in heaters where it is desirable for the molten heat source to flow within the tubular heater body.
  • the refractory lining serves to reduce the wettability of the inside surface of the heater body and prevent the heat source material clumping within the cavity.
  • Preventing the molten heat source material from sticking to the tubular heater body stops the heat source material from concentrating heat in a particular spot and melting through the wall of the heater body at that point.
  • refractory lining affords some heat shielding to walls of the tubular heater body, which in turn enables the heater body walls to be made thinner without risk of them being burned through.
  • the lining may be made from fibre glass, Kevlar ® , or provided as a ceramic layer coated on the inner walls of the tubular heater body.
  • a suitable ceramic material is ZrO 2 .
  • refractory coatings are often used, in the casting industry, in equipment to transfer molten metals. However these are generally used in conjunction with low-melting point alloys such as aluminium or bronze, which have melting points in the range of 500 to 1000 degrees C.
  • Refractory coatings are generally not recommended for use with high-temperature molten materials such as iron or steel. This is relevant because steel is one of the preferred materials used for chemical heater bodies of the present invention. In contrast to aluminium and bronze, iron and steel have melting points of about 1500 and 1400 degrees C, respectively.
  • the aluminium/iron oxide thermite which is commonly used as the chemical reaction heat source in the heaters of the present invention, in further contrast, has a reaction temperature of about 3200 degrees C.
  • refractory coatings are generally only rated to a range of about 1500 to 1800 degrees C. Therefore one would not normally consider a refractory coating as a viable method to protect a steel heater tube from molten thermite.
  • heater body 'burn-throughs' when they do occur, usually happen within less than a minute after the thermite is ignited. In view of this, it has been discovered that if a refractory coating could survive long enough for the heater tube to endure this critical one-minute interval, 'burn-throughs' could be prevented.
  • Zirconium oxide was selected as the coating material for testing based on its relatively high (1800 degrees C) operating temperature rating, and on the fact that its coefficient of thermal expansion (CTE) is closer to that of steel than do most other ceramic materials. This is an advantage because the greater the mismatch in CTE, the more likely a coating is to spall off the heater tube walls at elevated temperatures.
  • zirconium oxide has low thermal conductivity, which can provide some benefit in delaying, or spreading out over time, the heat transfer from the termite reaction products to a steel heater tube, for example. Perhaps more importantly, zirconium oxide does not have a chemical affinity to iron, and thus is less likely to be wetted by the iron by-products from the termite reaction.
  • the downhole tool deployment assembly makes use of the collar to ensure that alloy cannot cool and re-solidify over the separation or break point between the heater and the tubular heat conducting member (sometimes referred to as a mandrel).
  • One such variant takes the form of a two-part heater downhole tool deployment assembly, which, unlike the downhole tool deployment assembly described above, does not employ a tubular heat conducting member (i.e. mandrel).
  • a second aspect of the present invention provides a downhole tool deployment assembly in accordance with claim 4.
  • the role of the collar is again to keep the region of the assembly where separation takes place clear from alloy once the heater has been operated to melt the alloy.
  • keeping the point of weakness of the tubular heater body free of alloy makes the process of separating the up-hole section of the heater body from the downhole section of the heater body. In this way, the up-hole section of the heater body can be retrieved from the well, whilst the downhole section remains in place.
  • the point of weakness of the tubular heater body is located between the lowermost end of the up-hole section and the uppermost end of the downhole section of the tubular heater body.
  • the point of weakness may take the form of region of the heater body tubing that has been partially milled or drilled away to reduce the thickness of the wall.
  • the heater body is formed from a single tubular member that can be broken into two parts by simply pulling on the up-hole section once the weakened region is no longer covered by alloy.
  • the point of weakness may take the form of fixing means that connects the up-hole and downhole sections of the tubular heating body together. It is envisaged that the strength of the fixing means will be configured so as to fail when a predetermined force is applied to the assembly to retrieve the up-hole section of the tubular body.
  • suitable fixings means include: shear pins, a shear ring or a destructible screw thread.
  • the up-hole section can be readily separated from the downhole section of the heater body and retrieved out of the well.
  • the downhole section of the heater body may be blocked so as enable the section to function as a plug.
  • an insulating sleeve may be provided to achieve the heating efficiencies outlined above.
  • a skirt portion may be provided at the leading end of the downhole section of the tubular heating body to help facilitate the cooling of the heated alloy as it flows away from the region of the heater where the heat source is provided.
  • the internal cavity of the tubular heater body may contain a chemical reaction heat source.
  • the chemical reaction heat source may comprise a plurality of stacked blocks (e.g. thermite blocks), wherein the heating characteristics of each block may vary along the stack.
  • the chemical reaction heat source may also be provided as fragmented thermite blocks (i.e. crumble) and/or in powdered form.
  • the inner walls of the tubular heater body may be provided with a layer of a refractory material.
  • a refractory material examples include fibre glass, Kevlar ® and a coating of ceramic material, such as zirconium oxide (ZrO 2 ), aluminium oxide, magnesium oxide.
  • ZrO 2 zirconium oxide
  • the present invention also provides a method of deploying a downhole tool within an oil/gas well, said method comprising: delivering into a target region of an oil/gas well a tool deployment assembly according to the present invention; activating the heater to melt the eutectic/bismuth alloy layer; allowing the alloy to cool and secure the tubular heat conducting member in position within the oil/gas well; extracting at least a section of the heater from within the tubular heat conducting member and retrieving the heater from the oil/gas well.
  • the present invention provides methods of deploying a downhole tool with an oil/gas well that are in accordance with claims 10 and 11.
  • the method of the present invention does not require that the alloy is deployed downhole with the rest of the platform deployment tool. This is because the benefits of the heater retrieval are achieved by providing a clearance between the heater and the re-solidified alloy. This clearance is achieved regardless of whether the alloy is deployed down-hole with the rest of the tool or separately.
  • the downhole tool deployed by the method of the present invention is suitable to support the deployment of a straddle tool.
  • Straddles are typically used to provide a bypass conduit within an existing region of production tubing.
  • the present invention provides a method of deploying a by-pass conduit, such as a straddle, within an oil/gas well, said method being in accordance with claim 12.
  • the alloy provided on the tubing may be in the form of an annular packer.
  • the length of tubing may comprise a second tool deployment assembly according to the present invention.
  • the tubing may be heated using a heater located within the tubing.
  • the heater may comprise a chemical heat source.
  • heat sources such as electrical, might be used to heat the alloy
  • chemical heat sources are considered preferable due to the technical difficulties of operating electrical heaters reliably at greater distances from the surface.
  • the heater may be retrieved once the alloy has cooled.
  • the central space through the middle of the annular heat conducting member of the platform is exposed to permit the subsequent flow of fluid through the platform to the straddle and beyond.
  • the tubing may further comprise an expandable tubular member that can be expanded to increase its diameter. In this way the flow rate through any by-pass conduit might be increased.
  • the present invention also provides a method of sealing an oil/gas well in accordance with claim 16.
  • the downhole tool deployment assembly of the present invention disclosed herein is considered particularly suitable for use in downhole operations that take place within gas and oil wells.
  • the well tool deployed in accordance with the present invention is considered particularly suitable for use in repair operations involving Open Hole Gravel Packs.
  • OHGP Open Hole Gravel Pack'
  • figure 1 The main components of the downhole tool deployment assembly of the present invention are shown in figure 1 , which provides a partially exposed view of a preferred embodiment of the assembly 1.
  • the assembly 1 is constructed from a heater with a tubular heater body 2, at least a portion of which is received within a tubular heat conducting member 3.
  • the tubular member 3 that is positioned on the outside of the tubular heater body 2 only receives a portion of the heater body. As a result, a significant portion of the heater body is exposed and is not surrounded by the tubular member 3.
  • the assembly of the present invention is particularly suited to chemical heat source based heating, using for example thermite-based heat sources.
  • the chemical heat source material is housed within the internal cavity of the tubular heater body 2.
  • the chemical heat source material is provided in the form of a plurality of thermite blocks 6.
  • This partial covering of the tubular heater body 2 distinguishes the assembly of the present invention from downhole tool deployment assemblies of the past, in which the heaters were either entirely received within an outer tubular member or there was no outer tubular member at all provided.
  • the alloy is provided directly onto the heater body rather than on an intermediate tubular body.
  • the arrangement of the downhole tool deployment assembly of the present invention is such that the weight of the assembly is reduced by essentially removing a significant portion of the tubular member 3, which would have otherwise been present if the entire length of the tubular heater body 2 was to be received.
  • the omission of a portion of the tubular member 3 serves to create more space to accommodate the eutectic/bismuth based alloy, which is provided on the outside of the assembly without necessarily increasing the profile (i.e. external diameter) of the assembly.
  • the shape of the target well can impose a maximum limit on one or more of these dimensions. It is on these occasions that assemblies without an intermediate tubular member (i.e. alloy provided directly on heater) might have been deployed. As detailed above, however, this approach can face difficulties when it is desirable to retrieve the heater from the well after the alloy has cooled and re-solidified due to the heater becoming trapped by the re-solidified alloy.
  • At least 25% of the heater tubular body 2 must be received within the outer tubular member 3. That is to say, up to 75% of the heater tubular body 2 is exposed and in direct contact with the alloy.
  • the extent to which the heater tubular body 2 is received within the outer tubular member 3 will depend on the outer diameter of the tool and/or the inner diameter of the well bore.
  • the dimensions of the tubular heater body 2 are such that it can be slideably received within and retrieved from the outer tubular member 3. To this end, there must be a suitable clearance, preferably around 1 mm, between the outer diameter of the tubular heater body 2 and the inner diameter of the tubular member 3.
  • the tubular heater body 2 is held in place by an outer coating of eutectic/bismuth based alloy 5. This arrangement ensures that the tubular heater body can only be removed from the tubular member 3 once the alloy 5 has been melted.
  • addition temporary fixing means may be provided to supplement and support the connection of the tubular heater body 2 to the outer tubular member 3.
  • additional temporary fixing means may take the form of shear pins or shear rings.
  • the alloy 5 preferably extends along the entire length of the heater body 2. Of course, for at least a portion of that length the alloy 5 is separated from the tubular heater body 2 by the outer tubular member 3.
  • This co-axial arrangement of the alloy 5 and the tubular heater body 2 ensures that the alloy is effectively heated.
  • the presence of the intermediate tubular member 3 may result in an uneven heating of the alloy along the length of the assembly because some of the alloy is in direct contact with the heater and some of the alloy is not.
  • Heating uniformity can be achieved by making the outer tubular member 3 from a heat conducting material, such as Aluminium.
  • a heat conducting material such as Aluminium.
  • Other examples include steel alloys. In this way the heat from the heater can readily pass through the intermediate tubing to the alloy.
  • uniform heating of the alloy might also be achieved by using a predetermined arrangement of chemical heat source material blocks 6 with varying heat generation characteristics.
  • the applicant earlier International PCT filing Pub. No. WO 2014/096857 ) deals with the provision of chemical heat sources that can be tailored to create specific heating patterns by stacking blocks with differing mixtures of thermite and damping agent.
  • the heating blocks located in the exposed portion of the tubular heater body might include an increased proportion of damping agent when compared to the blocks located in the portion of the heater body that is received within the outer tubular member.
  • the exposed heater portion can be configured to emit less heat than the received portion, thereby providing a more uniform heat along the entire length of the alloy.
  • the tubular heater body 2 is provided with ignition means 11 at the trailing end thereof (i.e. the end that enters the well hole last).
  • the ignition means 11 are inserted into the open end of the tubular heater body 2 and secured in position, preferably using a screw thread arrangement - although other fixing arrangements may be employed.
  • the ignition means 11 is configured to enable the heater, and as a result the assembly 1 as a whole, to a running tool 10.
  • the running tool 10 together with above-ground delivery tools, facilitates the delivery of the assembly 2 down the well hole.
  • the tubular heater body 2 is closed at the leading end, which is the end opposite where the ignition means 11 is received. This enables the heat source material 6 to be received and housed within the heater tubular body 2.
  • the tubular member 3 is provided with an end plate 7, which is secured onto the leading end of thereof.
  • the end plate 7 is preferably secured in position by welding; however alternative attachment methods will be appreciated.
  • the tubular member 3 may be blocked by a burst disk that is held in position by 'O' rings or a metal sealing ring.
  • the provision of a burst disk means that the tubular member 3 can be quickly unblocked at a later date to suit the needs of a particular well.
  • the end plate 7 serves to close off the end of the tubular member 3 such that, once deployed, the combination of the tubular member and the re-solidified alloy form a downhole tool that plugs the well hole.
  • the end plate 7 is a preferred feature of the tubular member 3. In view of this it is envisaged that in some assemblies, where a plug is not required (i.e. by-pass conduits), the end plate 7 need not be present.
  • the tubular member 3 is also provided with a skirt portion 8.
  • the skirt portion may be secured to the leading end of the tubular member 3 by a screw thread or by welding. Other attachment mechanisms may also be employed without departing from the general concept of the present invention.
  • the skirt portion is preferably made of high strength steel, although other suitable materials will be envisaged by the skilled person upon consideration of the described invention.
  • skirt portion 8 may be formed as part of the tubular member 3. In this arrangement the length of the skirt portion would be determined by the location of the end plate 7 within the tubular member 3.
  • the role of the skirt portion is to provide a cooler region adjacent the heater where the molten alloy can start to cool and solidify. Cooling is achieved by allowing downhole fluids to get inside the skirt portion 8, whereby the heat energy present in the skirt portion due to the heater can be more quickly transferred away by the downhole fluids.
  • This cooling of the skirt portion 8 relative to the directly heated region of the tubular member 3 helps to begin the alloy re-solidification process, which helps prevent molten alloy simply dripping off the end of the assembly 1 and falling down the well.
  • the eutectic/bismuth based alloy 5 coats a large portion of the assembly, covering most of the exposed heater tubular body 2, the tubular member 3 and the collar 4.
  • the thickness of the alloy 5 coating varies along the length of the assembly 1 to take advantage of the additional space provided by the omission of the tubular member 3 towards the trailing end of the assembly 1.
  • the alloy coating is such that the outer diameter of the assembly remains consistent along the length of the assembly, whilst retaining more alloy that would have been possible if the tubular member 3 extended the entire length of the assembly.
  • the assembly is also provided with an anti-crush member 9.
  • the anti-crush member 9 which is formed from a material with greater mechanical strength than the alloy 5 (e.g. steel), is located at the trailing end of the assembly 1 adjacent to open end of the tubular member 3 in to which the ignition means 11 are inserted.
  • the anti-crush member 9 provides the upper region of the assembly with increased structural strength that enables the assembly to gripped and manoeuvred by mechanical handling equipment above ground without being damaged or deformed.
  • the anti-crush member 9 is configured to ensure that the consistent outer diameter of the assembly is maintained. To this end, a reduced thickness of alloy (or possibly no alloy) is provided in the region of the anti-crush member 9.
  • the assembly 1 may further be provided with an outer insulating layer or covering that completely encloses the alloy.
  • the insulating layer/covering is preferably provided with openings or weakened regions so as to provide specific egress points for the alloy as it melts. The benefits of providing the outer insulating layer are described above.
  • the ignition means 11 is attached to the assembly 1 and then attached to the running tool 10.
  • the running tool 10 which is engaged with a delivery tool (not shown) is then used to deliver the assembly 1 to a downhole target region within a well casing/tubing 12.
  • the ignition means 11 are activated and the chemical reaction of the chemical heat source (e.g. thermite based heat source) is started.
  • the heat given off by the chemical heat source melts the alloy 5 directly, and indirectly via the tubular member 3, causing the alloy to flow.
  • the alloy 5 flows it is immediately subjected to the cooling influences of the surrounding downhole environment (i.e. downhole fluids), which typically have a temperature range of around 20 to 170 °C
  • the alloy 5 flows away from the heat being generated by the chemical heat source it starts to cool and, as it does, re-solidify.
  • This cooling process is further assisted by the provision of the skirt portion 8 at the leading end of the assembly.
  • the skirt portion 8 allows the downhole fluids to cool the alloy from both outside and inside the assembly 1.
  • the alloy flows away from the exposed portion of the tubular heater body 2 cooling as it flows until it forms any annular alloy seal 5a between the tubular member 3 and the surrounding well casing/tubing 12.
  • the flow of the alloy is such that clearance is achieved between the alloy seal 5a and the exposed portion of the tubular heater body 2.
  • the alloy flow also provides clearance between the collar 4 and the annular alloy seal 5a.
  • the running tool 10 can be used to extract the tubular heater body 2 from within the tubular member 3 and then retrieve it from the downhole environment.
  • annular alloy seal 5a serves to lock the tubular member 3 in position within the well casing, thereby completing the deployment of the downhole tool.
  • the tubular heater body 2 is no longer held securely within the tubular member 3 due to the relocation of the alloy that previously held the tubular heater body 2 and the tubular member 3 together.
  • additional fixing means e.g. shear pins/rings
  • shear pins/rings such will be configured with a break point that is lower than the expected failure level of the alloy plugs, such that the fixing means fail when the heater is retrieved using the delivery tool.
  • the provision of the collar 4 ensures that no alloy can flow into the gap between the tubular heater body 2 and the outer tubular member 3 and cool, which, it will be appreciated, could seal the tubular heater body 2 and the outer tubular member 3 together and prevent them being readily pulled apart.
  • the downhole tool might instead be used as a platform to support the deployment of a straddle or other by-pass conduit within a target region of a well.
  • Figure 3 shows a diagrammatic representation of the key stages of deploying a straddle within an Open Hole Gravel Pack (OHGP) of a well.
  • OHGP Open Hole Gravel Pack
  • An open hole 100 is formed in an underground formation so as to access an underground oil/gas reservoir.
  • the oil/gas is extracted from the reservoir via the production tubing 101, which in the region of the reservoir comprises a screen with a plurality of slots or apertures designed to allow the free flow of downhole fluids, including oil, into the tubing and ultimately out of the well.
  • a proppant 102 is provided between the tubing 101 and the surrounding formation 100.
  • the present invention utilises the distinctive characteristics of eutectic/bismuth based alloys to form plugs in this environment without the need to carry out any perforation processes.
  • the first stream 103 and the third stream 105 represent a fluid with an acceptable proportion of oil to water.
  • the second stream 104 represents a fluid with a much higher proportion of water, which is undesirable.
  • the streams 103, 105 and 104 combine within the production tubing 101 they produce a combined fluid with a much less commercially acceptable oil to water ratio.
  • the first fluid stream 103 and the third fluid stream 105 can be isolated from the second fluid stream 104.
  • the positioning of the second fluid stream source between the first and third fluid stream sources makes it difficult to do this.
  • the downhole tool deployment assembly of the present invention enables the deployment of a by-pass conduit, such as a straddle, within the production tubing 101 to isolate the non-oil producing fluid stream 104 from the other neighbouring oil producing streams 103 and 105.
  • a by-pass conduit such as a straddle
  • the straddle tool is not shown in detail in Figure 3 , it should be understood that the straddle is preferably formed from a pair of tool components that are each set in place using the downhole tool deployment assembly of the present invention In the second key stage shown in Figure 3 a downhole tool deployment assembly 110 of the present invention is run into the well bore 100 using a wire line 111.
  • the assembly 110 comprises a heater body 2 that is partially received within the outer tubular member 3. Unlike in the embodiment shown in Figures 1 and 2 , however, in this arrangement the outer tubular member is not provided with an end plate. This ensures that the outer tubular member 3 can perform its function as part of the by-pass conduit.
  • the heater body 2 which it will be appreciated preferably houses a chemical heat source (not shown), is provided with a collar 4.
  • a eutectic/bismuth based alloy 5 covers the heater body 2, outer tubular member 3 and the collar 4. It is appreciated that the alloy may preferably be at least partially enclosed within an insulating sleeve. However the sleeve has not been included in Figure 3 to avoid overcomplicating the diagrammatic representation.
  • the heater is activated, preferably using a signal transmitted via the wire line 111, and the alloy 5 is melted. As the molten alloy flows away from the heater it begins to cool and re-solidify, thereby causing the formation of an alloy plug 5a within the well bore 100.
  • the heater body 2 and the attached collar 5 can be retrieved from the well using the wire line 111. This stage is shown in the third key stage of Figure 3 . It will be appreciated that the second and third key stages of Figure 3 proceed in accordance with the stages shown in Figure 2 , as described above.
  • a second downhole tool deployment assembly 114 can be run down the well into the target region just above the plug 5a. This is shown in the fourth key stage of Figure 3 .
  • the second downhole tool deployment assembly 114 is similar to the first assembly 110, however it is preferably provided with a length of tubing 115 that extends from the leading end of the outer tubular member 3. It is envisaged that the tubing may be formed as part of the outer tubular member or it may simply be attached to it by standard connection means (i.e. screw threaded engagement).
  • the leading end of the tubing 115 is provided with means for engaging the trailing end of the outer tubular member 3 of the tool deployed by the first downhole tool deployment assembly 110. It is envisaged that any arrangement that facilitates the alignment of the central cavities of the tubing 115 with the outer tubular member 3 of the tool deployed by the first downhole tool deployment assembly 110 is considered suitable.
  • the engagement formed between the tubing 115 and the outer tubular member 3 of the tool deployed by the first downhole tool deployment assembly 110 is fluid tight to ensure that fluid entering the by-pass conduit is transported the full length of the conduit and does not escape via the joint between the two components.
  • the heater of the second assembly 114 is activated and its associated alloy melted.
  • the molten alloy will flow away from the heater and cool to form a plug 116 within the well bore.
  • the two plugs 5a and 116 serve to both hold the two tool components of the by-pass conduit together and prevent fluids flowing around the plugs via the proppant 102.
  • the final stage of Figure 3 shows the by-pass conduit being held in position by the upper alloy plug 116 and the lower alloy plug 5a. Once in position, the by-pass conduit facilitates the flow of the first 103 and third 105 fluid streams out of the well via the production tubing 101, whilst at the same time isolating the second, undesirable fluid stream 104.
  • tubing 115 of the by-pass conduit shown in Figure 3 may comprise an expandable tubular member that, in use, is located between the two alloy plugs 5a and 116. In this way, once the plugs have been set within the well, the diameter of the tubing can be expanded to allow for an increased flow rate through the by-pass conduit.
  • tubing 115 may be provided with at least one eutectic/bismuth based alloy annular packer. In this way the annular packer could be activated at a later stage if a leak were to develop.
  • the second aspect of the present invention relates to an assembly with a two-part heater body system, wherein part of the heater is configured to be retrievable once the alloy has been melted.
  • an open hole 100 is formed in an underground formation so as to access an underground oil/gas reservoir.
  • the oil/gas is extracted from the reservoir via the production tubing 101, which in the region of the reservoir comprises a screen with a plurality of slots or apertures designed to allow the free flow of downhole fluids, including oil, into the tubing and ultimately out of the well.
  • a proppant 102 is provided between the tubing 101 and the surrounding formation 100.
  • the assembly 200 is deployed downhole via the tubing 101 using delivery means 206.
  • the assembly 200 comprises an up-hole tubular section 201 and a downhole tubular section 202. Both sections align to create a central cavity within which a heat source (e.g. chemical heat source) is received.
  • a heat source e.g. chemical heat source
  • the heat source has been omitted from figure 4 purely for the sake of clarity.
  • the up-hole section 201 of the assembly is so described because in use it is located closest to ground level.
  • the downhole section 202 of the assembly is so described because in use it is located further down hole than the up-hole section.
  • a point of weakness 204 is located at the point where the up-hole and downhole tubular sections of the assembly meet.
  • the point of weakness may take the form of a weakened region of a single tubular body which is configure to break under a predetermined force to realise the up-hole and downhole sections of the assembly.
  • the point of weakness may comprise fixing means that hold the up-hole and downhole sections together.
  • These fixing means which may be in the form of a sheer pin, a shear ring or a destructible screw thread, are configures to fail when a predetermined force is applied to the assembly 200.
  • the point of weakness 204 is shielded by a collar 203, which is shown extending away from the lower end of the up-hole section 201 of the assembly. It is appreciated that in an alternative embodiment the collar may extend from the top end of the downhole section 202 in addition to or instead of the collar on the up-hole section.
  • the collar 203 serves to prevent molten alloy from cooling and re-solidifying over the separation point between the different sections of the assembly, which in the case of the assembly shown in figure 4 are the up-hole 201 and downhole sections 202.
  • An alloy coating 205 is provided on the outside of the assembly so as to cover the collar 203 and at least part of both the up-hole 201 and downhole 202 sections thereof.
  • the alloy 205 is a eutectic alloy, which may be bismuth based.
  • the alloy coating 205 serves to reinforce the connection between the up-hole and downhole sections of the assembly so that the assembly retains a monolithic structure until the alloy is melted.
  • the assembly 200 is delivered downhole to a target region within the well. Once in position, the heat source is activated and the alloy 205 is melted.
  • the collar 203 serves to direct the alloy 205 away from the point of weakness and thereby prevent molten alloy flowing into direct contact with the region at which the two sections of the assembly would be separated from one another.
  • the alloy 205 flows it starts to cool and re-solidify into a plug 205a.
  • the alloy can flow through the perforations into the surrounding annulus, thereby forming an alloy seal that extends across the entire cross-section of the wellbore 100.
  • the delivery means 206 can be operated in reverse to pull the assembly out of the well.
  • the pulling force of the delivery means works again the anchoring force of the plug 205a to impart a force separating force that exceeds the predetermined force required to break point of weakness so that the two sections of the assembly can be separated from one another.
  • the plug 205a is shown in situ within the well. It should be noted that the length of the downhole section has been exaggerated for the purposes of clearly demonstrating the operation of the assembly. The actual length may be considerably less so as to ensure that, if necessary, the plug can be drilled/milled out relatively quickly.

Landscapes

  • 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)
  • Resistance Heating (AREA)

Claims (16)

  1. Bohrloch-Werkzeugverwendungsbaugruppe (1), wobei die Baugruppe umfasst:
    Ein Heizgerät mit einem rohrförmigen Heizkörper (2), der einen Innenhohlraum aufweist, welcher ausgelegt ist, eine Heizquelle aufzunehmen;
    ein rohrförmiges Wärmeleitelement (3), welches ausgelegt ist, den rohrförmigen Heizkörper (2), unter Hinterlassen eines ringförmigen Spalts, zu umgebe, wobei sich das rohrförmige Wärmeleitelement nicht entlang der ganzen Länge des rohrförmigen Heizkörpers erstreckt;
    einen Bund (4), der angrenzend an den Bereich der Baugruppe montiert ist, wo das rohrförmige Wärmeleitelement (3) endet, wobei der Bund ausgelegt ist, Zugang zum ringförmigen Spalt zwischen dem Wärmeleitelement und dem rohrförmigen Heizkörper (2) zu verhindern; und
    sich ein eutektischer auf Bismut basierender (5) Legierungsbelag über den Bund (4) und wenigstens einen Teil des rohrförmigen Heizkörpers (2) und das rohrförmige Wärmeleitelement (3) erstreckt, und wodurch die Legierung das Heizgerät und das rohrförmige Wärmeleitelement zusammenhält, bis die Legierung geschmolzen ist; und
    Gekennzeichnet durch einen Schürzenabschnitt (8), der sich am Ende des rohrförmigen Wärmeleitelements (3) fern vom Bund befindet, wobei der Schürzenabschnitt (8) das Kühlen der geschmolzenen Legierung erleichtert, während sie die Baugruppe hinunterfließt, indem Bohrlochflüssigkeiten ermöglicht wird, sich innerhalb des offenen Endes der Schürze zu sammeln.
  2. Baugruppe nach Anspruch 1, wobei der Bund (4) am rohrförmigen Heizkörper (2) montiert ist.
  3. Baugruppe nach irgendeinem der vorhergehenden Ansprüche, wobei das rohrförmige Wärmeleitelement (3) aus Aluminium gebildet ist.
  4. Bohrloch-Werkzeugverwendungsbaugruppe (200), wobei die Baugruppe umfasst:
    Ein Heizgerät mit einem rohrförmigen Heizkörper, der einen Innenhohlraum aufweist, welcher ausgelegt ist, eine Heizquelle aufzunehmen, wobei der rohrförmige Heizkörper einen Oberlochabschnitt (201) und einen Bohrlochabschnitt (202) umfasst, die durch eine Schwachstelle (204) getrennt sind;
    ein auf Eutektikum und/oder auf Bismut basierender Legierungsbelag (205), der sich über den Bund (203) und wenigstens einen Teil sowohl des Oberlochabschnitts (201) als auch des Bohrlochabschnitts des rohrförmigen Heizkörpers erstreckt, und wodurch die Legierung die Oberloch- und Bohrlochhabschnitte des rohrförmigen Heizkörpers zusammenhält, bis die Legierung geschmolzen ist; und
    gekennzeichnet durch einen Bund (203), der angrenzend an die Schwachstelle (204) montiert ist, wobei der Bund ausgelegt ist, die Schwachstelle zu bedecken.
  5. Baugruppe nach irgendeinem der vorhergehenden Ansprüche, wobei sich der Bund (4, 203) von einem ersten Durchmesser an einem ersten Ende davon zu einem zweiten, größeren Durchmesser an einem zweiten Ende davon erstreckt.
  6. Baugruppe nach irgendeinem der vorhergehenden Ansprüche, wobei die Legierung (5, 205) wenigstens teilweise innerhalb einer isolierenden Muffe eingeschlossen ist; und wobei die isolierende Muffe vorzugsweise entweder:
    Eine oder mehrere Öffnungen in einem Bereich angrenzend an den Bund; oder
    eine oder mehrere Schwachstellen im Bereich angrenzend an den Bund umfasst; wobei die geschwächten Stellen ausgelegt sind, vor dem Rest der isolierenden Muffe, zu versagen.
  7. Baugruppe nach irgendeinem der Ansprüche 4 bis 6, die ferner einen Schürzenabschnitt (8) umfasst, der sich am Ende des rohrförmigen Bohrlochabschnitts (202) fern vom Bund (4) befindet.
  8. Baugruppe nach irgendeinem der vorhergehenden Ansprüche, ferner umfassend:
    Eine Endplatte (7), die sich am Ende des rohrförmigen Wärmeleitelements (3) fern vom Bund (4) befindet; und/oder
    lösbare Befestigungsmittel, um den Zusammenhalt des Heizgeräts und des rohrförmigen Wärmeleitelements (2) von Anspruch 1 oder der Oberloch- (201) und Bohrlochabschnitte (202) des rohrförmigen Heizgeräts von Anspruch 4 zu ergänzen, bis die Legierung geschmolzen ist.
  9. Baugruppe nach irgendeinem der vorhergehenden Ansprüche, wobei der Innenhohlraum des rohrförmigen Heizkörpers eine Wärmequelle (6) chemischer Reaktion enthält; und/oder die Innenwände des rohrförmigen Heizgeräts oder die Innenwände der Oberloch- und Bohrlochabschnitte des rohrförmigen Heizkörpers Körpers mit einer Schicht aus feuerfestem Material versehen sind.
  10. Verfahren zur Verwendung eines Bohrlochwerkzeugs innerhalb einer Öl-/Gasquelle, wobei das Verfahren umfasst:
    Lieferung in einen Zielbereich einer Öl-/Gasquelle einer Werkzeugverwendungsbaugruppe nach Anspruch 1 oder irgendeinem der Ansprüche 2, 3, 5-9, wenn direkt oder indirekt von Anspruch 1 abhängig;
    Aktivieren des Heizgeräts, um die Eutektikum-/Bismut-Schicht zu schmelzen;
    Kühlen der Legierung zu erlauben und Sichern des rohrförmigen Wärmeleitelements in Position innerhalb der ÖL-/Gasquelle, um das Bohrlochwerkzeug zu bilden; Herausholen des Heizgeräts aus der ÖL-/Gasquelle.
  11. Verfahren zur Verwendung eines Bohrlochwerkzeugs innerhalb einer Öl-/Gasquelle, wobei das Verfahren umfasst:
    Lieferung in einen Zielbereich einer Öl-/Gasquelle einer Werkzeugverwendungsbaugruppe nach Anspruch 4 oder irgendeinem der Ansprüche 5 bis 9, wenn direkt oder indirekt von Anspruch 4 abhängig;
    Aktivieren des Heizgeräts, um die Eutektikum-/Bismut-Schicht zu schmelzen;
    Kühlen der Legierung zu erlauben und Sichern des rohrförmigen Heizkörpers in Position innerhalb der ÖL-/Gasquelle, um das Bohrlochwerkzeug zu bilden;
    Herausholen des Oberlochabschnitts des rohrförmigen Heizkörpers aus der Öl-/Gasquelle.
  12. Verfahren zur Verwendung einer Bypass-Leitung, wie beispielsweise eine Überbrückung, innerhalb einer ÖL-/Gasquelle, wobei das Verfahren umfasst:
    Verwenden eines Bohrlochwerkzeugs innerhalb einer Öl-/Gasquelle, unter Verwendung des Verfahrens Anspruch 10 oder 11; Bereitstellen einer Länge von Rohr auf einer Legierung aus Eutektikum/Bismut beruhend, die an die Außenwand der Rohrleitung montiert ist;
    Lieferung der Rohrleitung auf das Bohrlochwerkzeug;
    Erhitzen der Rohrleitung, um die Legierung zu schmelzen; und
    Kühlung der auf Eutektikum/Bismut basierenden Legierung zu erlauben und Sichern der Rohrleitung in Position, um eine Bypass-Leitung innerhalb der Öl-/Gasquelle zu bilden.
  13. Verfahren nach Anspruch 12, wobei die auf der Rohrleitung bereitgestellte Legierung ein ringförmiger Packer ist; und wobei die Länge von Rohr vorzugsweise eine zweite Werkzeugverwendungsbaugruppe nach irgendeinem der Ansprüche 1 bis 9 umfasst.
  14. Verfahren nach Anspruch 12, wobei die Rohrleitung unter Verwendung eines innerhalb der Rohrleitung befindlichen Heizgeräts erhitzt wird; und wobei das Heizgerät vorzugsweise eine chemische Wärmequelle umfasst.
  15. Verfahren nach irgendeinem der Ansprüche 12 bis 14, wobei das Heizgerät herausgeholt wird, sobald sich die Legierung abgekühlt hat.
  16. Verfahren zur Versiegelung einer Öl-/Gasquelle, wobei das Verfahren umfasst:
    Lieferung in einen Zielbereich einer Öl-/Gasquelle einer Werkzeugverwendungsbaugruppe nach Anspruch 4 oder irgendeinem der Ansprüche 5 bis 9, wenn direkt oder indirekt von Anspruch 4 abhängig;
    Aktivieren des Heizgeräts, um die Schicht aus Eutektikum/Bismut zu schmelzen; Kühlen der Legierung zu erlauben und sichern des Bohrlochabschnitts des rohrförmigen Heizkörpers in Position innerhalb der ÖL-/Gasquelle, um eine Dichtung innerhalb des Zielbereichs zu bilden;
    Herausholen des Oberlochabschnitts des rohrförmigen Heizkörpers aus der Öl-/Gasquelle.
EP18728449.2A 2017-05-24 2018-05-24 Bohrlochwerkzeugeinsetzanordnung mit verbesserter heizerentfernbarkeit und verfahren zur anwendung davon Active EP3631150B1 (de)

Applications Claiming Priority (3)

Application Number Priority Date Filing Date Title
PCT/GB2017/051458 WO2017203248A1 (en) 2016-05-24 2017-05-24 Combined well plug/chemical heater assemblies for use in down-hole operations and associated heater cartridges
GB1713517.9A GB2562811B (en) 2016-05-24 2017-08-23 A downhole tool deployment assembly with improved heater removability and methods of employing such
PCT/GB2018/051425 WO2018215786A1 (en) 2017-05-24 2018-05-24 A downhole tool deployment assembly with improved heater removability and methods of employing such

Publications (2)

Publication Number Publication Date
EP3631150A1 EP3631150A1 (de) 2020-04-08
EP3631150B1 true EP3631150B1 (de) 2023-11-15

Family

ID=64427260

Family Applications (1)

Application Number Title Priority Date Filing Date
EP18728449.2A Active EP3631150B1 (de) 2017-05-24 2018-05-24 Bohrlochwerkzeugeinsetzanordnung mit verbesserter heizerentfernbarkeit und verfahren zur anwendung davon

Country Status (4)

Country Link
EP (1) EP3631150B1 (de)
CA (1) CA3100822A1 (de)
DK (1) DK3631150T3 (de)
WO (1) WO2018215786A1 (de)

Families Citing this family (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
NO346976B1 (en) * 2021-06-25 2023-03-20 Interwell Norway As Downhole well tool for permanently sealing a downhole well
GB2611583A (en) * 2021-10-11 2023-04-12 Bisn Tec Ltd Retrievable downhole heater

Family Cites Families (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2076308A (en) * 1936-02-15 1937-04-06 Technicraft Engineering Corp Well heating device and method
US3208530A (en) * 1964-09-14 1965-09-28 Exxon Production Research Co Apparatus for setting bridge plugs
US20060144591A1 (en) * 2004-12-30 2006-07-06 Chevron U.S.A. Inc. Method and apparatus for repair of wells utilizing meltable repair materials and exothermic reactants as heating agents
GB201414565D0 (en) * 2014-08-15 2014-10-01 Bisn Oil Tools Ltd Methods and apparatus for use in oil and gas well completion

Also Published As

Publication number Publication date
DK3631150T3 (da) 2024-02-12
WO2018215786A1 (en) 2018-11-29
CA3100822A1 (en) 2018-11-29
EP3631150A1 (de) 2020-04-08

Similar Documents

Publication Publication Date Title
US11536111B2 (en) Downhole tool deployment assembly with improved heater removability and methods of employing such
US11480026B2 (en) Nano-thermite well plug
US20240060385A1 (en) An expandable eutectic alloy based downhole tool and methods of deploying such
EP3578749B1 (de) Bohrlochspreizwerkzeuge
US7455104B2 (en) Expandable elements
US7775286B2 (en) Convertible downhole devices and method of performing downhole operations using convertible downhole devices
EP3604732A1 (de) Verfahren und vorrichtung zur verwendung in der brunnenauflassung
US11098553B2 (en) Method for sealing a region of open hole gravel pack
WO2018063829A1 (en) Tool for metal plugging or sealing of casing
EP3500722B1 (de) Bohrlochoperationen im zusammenhang mit unverrohrten kiespackungen und werkzeuge zur verwendung darin
EP3631150B1 (de) Bohrlochwerkzeugeinsetzanordnung mit verbesserter heizerentfernbarkeit und verfahren zur anwendung davon
US20230160277A1 (en) Method and apparatus for plugging
EP3940195B1 (de) Umkehrbares abdichtverfahren und vorrichtung
GB2608269A (en) An expandable eutectic alloy based downhole tool and methods of deploying such
US20230371454A1 (en) Nano-thermite Well Plug
NO347280B1 (en) Downhole millable permanent plug

Legal Events

Date Code Title Description
STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: UNKNOWN

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: THE INTERNATIONAL PUBLICATION HAS BEEN MADE

PUAI Public reference made under article 153(3) epc to a published international application that has entered the european phase

Free format text: ORIGINAL CODE: 0009012

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: REQUEST FOR EXAMINATION WAS MADE

17P Request for examination filed

Effective date: 20191202

AK Designated contracting states

Kind code of ref document: A1

Designated state(s): AL AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HR HU IE IS IT LI LT LU LV MC MK MT NL NO PL PT RO RS SE SI SK SM TR

AX Request for extension of the european patent

Extension state: BA ME

DAV Request for validation of the european patent (deleted)
DAX Request for extension of the european patent (deleted)
STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: EXAMINATION IS IN PROGRESS

17Q First examination report despatched

Effective date: 20221109

GRAP Despatch of communication of intention to grant a patent

Free format text: ORIGINAL CODE: EPIDOSNIGR1

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: GRANT OF PATENT IS INTENDED

INTG Intention to grant announced

Effective date: 20230613

GRAS Grant fee paid

Free format text: ORIGINAL CODE: EPIDOSNIGR3

GRAA (expected) grant

Free format text: ORIGINAL CODE: 0009210

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: THE PATENT HAS BEEN GRANTED

AK Designated contracting states

Kind code of ref document: B1

Designated state(s): AL AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HR HU IE IS IT LI LT LU LV MC MK MT NL NO PL PT RO RS SE SI SK SM TR

REG Reference to a national code

Ref country code: CH

Ref legal event code: EP

Ref country code: GB

Ref legal event code: FG4D

REG Reference to a national code

Ref country code: DE

Ref legal event code: R096

Ref document number: 602018061096

Country of ref document: DE

REG Reference to a national code

Ref country code: IE

Ref legal event code: FG4D

REG Reference to a national code

Ref country code: DK

Ref legal event code: T3

Effective date: 20240209

REG Reference to a national code

Ref country code: NL

Ref legal event code: FP

REG Reference to a national code

Ref country code: LT

Ref legal event code: MG9D

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: GR

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20240216

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: IS

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20240315

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: LT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20231115

REG Reference to a national code

Ref country code: AT

Ref legal event code: MK05

Ref document number: 1631951

Country of ref document: AT

Kind code of ref document: T

Effective date: 20231115

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: AT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20231115

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: ES

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20231115

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: LT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20231115

Ref country code: IS

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20240315

Ref country code: GR

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20240216

Ref country code: ES

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20231115

Ref country code: BG

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20240215

Ref country code: AT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20231115

Ref country code: PT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20240315