US20180355678A1 - A downhole tubular verification and centralizing device, and method - Google Patents
A downhole tubular verification and centralizing device, and method Download PDFInfo
- Publication number
- US20180355678A1 US20180355678A1 US16/061,163 US201616061163A US2018355678A1 US 20180355678 A1 US20180355678 A1 US 20180355678A1 US 201616061163 A US201616061163 A US 201616061163A US 2018355678 A1 US2018355678 A1 US 2018355678A1
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- tubular
- wall
- tools
- bore
- casing
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- 238000000034 method Methods 0.000 title claims description 19
- 238000012795 verification Methods 0.000 title description 3
- 230000035515 penetration Effects 0.000 claims abstract description 33
- 238000006243 chemical reaction Methods 0.000 claims abstract description 3
- 238000003801 milling Methods 0.000 claims description 13
- 238000005755 formation reaction Methods 0.000 description 18
- 230000015572 biosynthetic process Effects 0.000 description 17
- 230000004888 barrier function Effects 0.000 description 9
- 239000004568 cement Substances 0.000 description 7
- 229930195733 hydrocarbon Natural products 0.000 description 5
- 150000002430 hydrocarbons Chemical class 0.000 description 5
- 238000004519 manufacturing process Methods 0.000 description 4
- 238000009434 installation Methods 0.000 description 3
- 239000004215 Carbon black (E152) Substances 0.000 description 2
- 239000004020 conductor Substances 0.000 description 2
- 239000012530 fluid Substances 0.000 description 2
- 239000000463 material Substances 0.000 description 2
- 241000282472 Canis lupus familiaris Species 0.000 description 1
- 241000270295 Serpentes Species 0.000 description 1
- 238000004873 anchoring Methods 0.000 description 1
- 238000005422 blasting Methods 0.000 description 1
- 230000001276 controlling effect Effects 0.000 description 1
- 230000001419 dependent effect Effects 0.000 description 1
- 238000009826 distribution Methods 0.000 description 1
- 238000005553 drilling Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 238000002347 injection Methods 0.000 description 1
- 239000007924 injection Substances 0.000 description 1
- 230000001788 irregular Effects 0.000 description 1
- 230000003287 optical effect Effects 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 238000003825 pressing Methods 0.000 description 1
- 238000005086 pumping Methods 0.000 description 1
- 230000001105 regulatory effect Effects 0.000 description 1
- 238000009877 rendering Methods 0.000 description 1
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
- E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
- E21B17/10—Wear protectors; Centralising devices, e.g. stabilisers
- E21B17/1014—Flexible or expansible centering means, e.g. with pistons pressing against the wall of the well
-
- 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
- E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
- E21B17/10—Wear protectors; Centralising devices, e.g. stabilisers
- E21B17/1078—Stabilisers or centralisers for casing, tubing or drill pipes
-
- 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
-
- 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
- E21B29/002—Cutting, e.g. milling, a pipe with a cutter rotating along the circumference of the pipe
- E21B29/005—Cutting, e.g. milling, a pipe with a cutter rotating along the circumference of the pipe with a radially-expansible cutter rotating inside the pipe, e.g. for cutting an annular window
-
- 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
- E21B33/134—Bridging plugs
-
- 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
- E21B47/00—Survey of boreholes or wells
- E21B47/09—Locating or determining the position of objects in boreholes or wells, e.g. the position of an extending arm; Identifying the free or blocked portions of pipes
-
- 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
- E21B33/14—Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes
Definitions
- the invention concerns a device and method for centralizing a tubular in a bore, as set out by the preambles of claims 1 , 8 and 11 .
- the invention is particularly useful in centralizing a casing, in connection with plugging-and-abandonment operations in subterranean hydrocarbon wells.
- Hydrocarbons e.g. oil and/or gas
- Hydrocarbons are extracted from subterranean formations, often referred to as a reservoirs, by drilling a wellbore into the formations containing hydrocarbons.
- a wellbore When a wellbore has been drilled, the well must be completed before hydrocarbons can be produced from the reservoir.
- a completion normally involves the design, selection, and installation of equipment and materials in or around the wellbore for conveying, pumping, or controlling the production or injection of fluids. After the well has been completed, production testing of the well can begin.
- Hydrocarbon wells normally have an upper and outer conductor, which forms the base of the well, an upper casing arranged into and in extension of the conductor, and further down in the well more casings which are arranged into and overlaps the above casing.
- a production tubing string is subsequently located in the middle of the well for transporting petroleum from the bottom of the well to the earths surface or to a seabed facility. Annuli are thus formed between the different casings, as well as between the outer casing and the wellbore wall (i.e. the formation).
- cement plugs are normally used to provide a barrier in the well.
- a common procedure during plug-aid-abandonment operations is to place a cement plug inside an inner casing string and a further plug in the annulus between the inner casing string and the outer casing string, and in the annulus between the outer casing and the formation. The plug will then extend across the full section of the well, and extend a predetermined axial distance.
- each penetration tool comprises sensing means configured for sensing the distance travelled by the penetration tool.
- Each penetration tool may comprise sensing means configured for sensing the distance to a wall of the bore.
- the penetration tools may be releasably connected to the motive means.
- Three penetration tools may be arranged at 120° intervals around the body circumference.
- Four penetration tools may be arranged at 90° intervals around the body circumference.
- Five or more penetration tools may be arranged at regular intervals around the body circumference.
- the penetration tool may comprise a milling tool.
- the tool may which impinges on the wall may be extended further, whereby the casing is moved as a reaction.
- the device body may be subsequently be disconnected from the tools and retrieved out of the bore upon completion of the steps.
- a tubular e.g. a casing
- an adjacent wall e.g. wellbore wall
- these operations may be conducted in one downhole trip.
- FIG. 1 is a cross-sectional drawing of an embodiment of the invented device, in an unactuated state, placed in a casing in a formation wellbore;
- FIG. 2 corresponds to FIG. 1 , and shows the invented device in an activated state, with four tools having been extended through the casing wall;
- FIG. 3 corresponds to FIG. 2 , and shows how the tools have shifted the casing in the wellbore, to a more centralized position in the wellbore than previously;
- FIG. 4 corresponds to FIG. 4 , and shows that the invented device has been removed from the casing, while the tools remain in the casing wall;
- FIG. 5 is a schematic illustration of a tool in an extended position
- FIG. 6 is a schematic illustration of an alternative embodiment of a tool
- FIG. 7 is a schematic illustration of an alternative embodiment of the invented device, during a first milling operation
- FIG. 8 illustrates the device of FIG. 7 , during the installation of a first set of wedges in an annulus between a casing and a formation
- FIG. 9 illustrates the device of FIG. 7 , during a second milling operation
- FIG. 10 illustrates the device of FIG. 7 , during the installation of a second set of wedges in an annulus between a casing and a formation
- FIG. 11 shows the first and second sets of wedges installed in an annulus between a casing and a formation, and a cement plug having been placed in a section of the annulus and casing.
- FIG. 1 shows a casing 1 placed in a wellbore 2 having a wall 2 a against a subterranean formation 7 .
- the formation wall 2 a may be of an irregular shape and contain cracks, fissures and unconsolidated regions.
- the casing 1 is not properly centralized in the wellbore 2 , but is in contact with a portion of the wellbore wall 2 a (in the upper, left-hand part, as shown in FIG. 1 ). There is thus no complete is annulus between the casing and the wellbore wall 2 a , or the annulus 3 is insufficiently wide, therefore rendering a cementing procedure impossible at this location.
- FIG. 1 also shows the invented device 4 in place inside the casing 1 .
- the device 4 may be connected to a drillpipe, coiled tubing (not shown), or other known downhole device conveyance means, and powered and controlled from an uphole location, in a manner generally known in the art.
- the device 4 comprises a body 9 and four individually operated tools 5 , which will be described below.
- each individual tool 5 has been extended from the tool body 9 and advanced towards and through the casing wall.
- Each individual tool 5 is extended by individual arms 6 , which may be hydraulically operated telescopic cylinders, known per se in the art.
- Each tool 5 comprises casing penetration means (not shown) for making a hole or other opening in the casing wall. Such casing penetration means may for example be jet blasting nozzles or a milling tool, all of which are generally known in the art.
- Each tool 5 also comprises attachment means (not shown in FIG. 2 ) for attaching the tool to the casing wall, for example dogs, slips, or other anchoring means generally known in the art. With these means (referring to FIG.
- a first tool portion 5 a of the tool 5 may be held in position in the hole made in the casing wall, while a second tool portion 5 b is advancing (e.g. telescoping) towards and into abutment with the wellbore wall 2 a .
- Other tool advancing means such as a threaded, rotational configuration, are also envisaged.
- Each tool 5 may comprise distance-sensing means (not shown), by which the distance travelled by the tool may be monitored. Alternatively, such sensing means may be integrated in the individual arm 6 . It should be understood that the distance-sensing means may comprise generally known devices, including optical, acoustic and electromechanical means. The distance-sensing means will enable the device operator to determine the distance between the casing and the adjacent wellbore wall 2 a , thus being able to evaluate whether or not a sufficient clearance between casing and wellbore wall exists.
- the tools 5 have been advanced further through their respective casing penetrations, towards the wellbore wall 2 a .
- the casing is pushed away from the wellbore wall 2 a when the tool is abutting the formation.
- FIG. 3 this is seen as the casing 1 has been pushed away from the wellbore wall by the tool 5 ′ (towards the right in the figure).
- the distance-sensing means are also in effect casing verification means, inasmuch as they will communicate the extended distance for each tool, and hence the minimum distance between the casing and the wellbore wall.
- FIG. 6 illustrates an alternative embodiment of the tool, being a deformable plug 5 c , pressing against the formation wall.
- FIG. 4 shows the casing 1 centralized in the wellbore and thus forming an annulus 3 with the wellbore (formation) wall 2 a .
- the tools 5 have been disconnected from their individual arm, and the device has been retrieved to an uphole location.
- the tools thus function as permanent casing centralizers, and cement (or other barrier element) 8 is placed into the annulus 3 .
- Each tool 5 is disconnectable from its individual arm by means that are known per se.
- the invention it is possible to verify the distance between the casing and the adjacent wellbore wall, and, if necessary, move the casing laterally in order to centralize the casing and establish sufficient distance between the casing and the wall. These operations may be conducted in one downhole trip.
- the device and tools may be integrated with an additional tool (not shown), whereby a well barrier placement operation may be performed following the verification and centralization procedure.
- FIG. 7 illustrates another embodiment of the invented device 41 , having a tool section 41 a and a milling section 41 b .
- the device is conveyed into the casing 1 and controlled via a drill string 10 (or coiled tubing, or similar).
- the tool section 41 a carries a first (upper) wedge set 52 and a second (lower) wedge set 53 .
- the milling section 41 b which is rotatably connected to the tool section, carries a set of milling arms 51 . It should be understood that each set comprises a plurality of wedges and milling arms, respectively.
- FIG. 7 illustrates another embodiment of the invented device 41 , having a tool section 41 a and a milling section 41 b .
- the device is conveyed into the casing 1 and controlled via a drill string 10 (or coiled tubing, or similar).
- the tool section 41 a carries a first (upper) wedge set 52 and a second (lower) wedge set 53 .
- the milling section 41 b is rotated (as indicated by arrow R) with milling arms 51 in a deployed position, in a manner well known in the art, thus generating a first (upper) circumferential casing window 54 (see FIG. 8 ).
- FIG. 8 the device has been lowered further into the casing 1 , and the second wedge set 53 has been entered (rammed or pushed) into the annulus 3 , through the first casing window 54 .
- the connection between the first wedge set 53 and the tool section 41 is severed (e.g. sheared), and the device is being moved further into the casing, to a position shown in FIG. 9 .
- the milling section 41 b is once again rotated (as indicated by arrow R) with milling arms 51 in a deployed position, to generate a second (lower) circumferential casing window 55 (see FIG. 10 ).
- the device has been lowered further into the casing 1 , and the first wedge set 52 has been entered (rammed or pushed) into the annulus 3 , through the second casing window 55 .
- the connection between the first wedge set 53 and the tool section 41 is severed (e.g. sheared), and the device may be retrieved from the casing, e.g. to an uphole location.
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- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Mechanical Engineering (AREA)
- Geophysics (AREA)
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Abstract
Description
- The invention concerns a device and method for centralizing a tubular in a bore, as set out by the preambles of
claims 1, 8 and 11. The invention is particularly useful in centralizing a casing, in connection with plugging-and-abandonment operations in subterranean hydrocarbon wells. - Hydrocarbons (e.g. oil and/or gas) are extracted from subterranean formations, often referred to as a reservoirs, by drilling a wellbore into the formations containing hydrocarbons. When a wellbore has been drilled, the well must be completed before hydrocarbons can be produced from the reservoir. A completion normally involves the design, selection, and installation of equipment and materials in or around the wellbore for conveying, pumping, or controlling the production or injection of fluids. After the well has been completed, production testing of the well can begin.
- Hydrocarbon wells normally have an upper and outer conductor, which forms the base of the well, an upper casing arranged into and in extension of the conductor, and further down in the well more casings which are arranged into and overlaps the above casing. A production tubing string is subsequently located in the middle of the well for transporting petroleum from the bottom of the well to the earths surface or to a seabed facility. Annuli are thus formed between the different casings, as well as between the outer casing and the wellbore wall (i.e. the formation).
- Before the well is permanently abandoned, it must be securely plugged, in a manner that is in compliance with regulatory requirements. Cement plugs are normally used to provide a barrier in the well. A common procedure during plug-aid-abandonment operations is to place a cement plug inside an inner casing string and a further plug in the annulus between the inner casing string and the outer casing string, and in the annulus between the outer casing and the formation. The plug will then extend across the full section of the well, and extend a predetermined axial distance.
- One commonly used method to install such plug, is to snake holes in the casing wall and force cement from within the central casing, through the casing wall holes and into the annulus. This procedure, and various variants, are well known in the art.
- In order to ensure that the dimensions and integrity of a plug are within acceptable tolerances, there must be a minimum distance between the casing and the wellbore wall (i.e. the formation), allowing the cement (or other barrier element) to form a barrier of a predetermined minimum thickness and density. This is because the structural integrity of the wellbore wall is not always known. Devices and methods for determining the distance between the casing and the formation exist. For example, an acoustic logging tool may be lowered to the desired location and activated to determine the distribution of material outside the casing. Sometimes, the casing-to-formation clearance is found to be too small or non-existing, due to casing movement during several years of production or formation instabilities. The casing is thus too close to the wellbore wall. Such regions of casing are normally unsuitable for plugging, because it is impossible to establish a complete annular barrier in the annulus between the casing and wellbore wall. It is therefore a need for a device and method whereby the above problems may be mitigated.
- The invention is set forth and characterized in the main claim, while the dependent claims describe other characteristics of the invention.
- It is thus provided a device for centralizing a tubular in a bore, characterized by
-
- a body configured for being positioned at a predetermined location inside the tubular;
- a plurality of penetration tools movably connected to the body via respective motive means and configured for extension from the body and through the tubular wall; and
- wall-abutment means configured for generating a force between the tubular and the bore in order to at least partly shift the tubular inside the bore.
- In one embodiment, each penetration tool comprises sensing means configured for sensing the distance travelled by the penetration tool. Each penetration tool may comprise sensing means configured for sensing the distance to a wall of the bore.
- The penetration tools may be releasably connected to the motive means. Three penetration tools may be arranged at 120° intervals around the body circumference. Four penetration tools may be arranged at 90° intervals around the body circumference. Five or more penetration tools may be arranged at regular intervals around the body circumference. The penetration tool may comprise a milling tool.
- It is also provided a method of centralizing a tubular in a bore, characterized by
- a) arranging the invented device a predetermined location inside the tubular;
- b) extending a plurality of penetration tools radially from the device body and make an opening in respective portions of the tubular while securing at least a portion of the tool to the tubular; and
- c) extending at least a portion of the tool a predetermined distance towards a wall of the bore, or until at least one of the tools impinges on the wall.
- Following step c), the tool may which impinges on the wall may be extended further, whereby the casing is moved as a reaction.
- The device body may be subsequently be disconnected from the tools and retrieved out of the bore upon completion of the steps.
- It is also provided a method of centralizing at least a portion of a tubular in a bore, characterized by
- a) arranging a device according to the invention at a predetermined first location inside the tubular;
- b) extending penetration tools from the device body to make a first circumferential window in the tubular;
- c) installing at least one force member, through the first window, between the tubular outer wall and the bore;
- d) relocating said device to a predetermined second location inside the tubular;
- e) extending penetration tools from the device body to make a second circumferential window in the tubular; and
- f) installing at least one force member, through the second window, between the tubular outer wall and the bore.
- With the invention, it is possible to verify sufficient distance between a tubular (e.g. a casing) and an adjacent wall (e.g. wellbore wall), and, if necessary, move the casing laterally in order to establish sufficient distance between the tubular and the wall. With the invented device and method, these operations may be conducted in one downhole trip.
- These and other characteristics of the invention will become clear from the following description of preferential embodiments, given as non-restrictive examples, with reference to the attached schematic drawings, wherein:
-
FIG. 1 is a cross-sectional drawing of an embodiment of the invented device, in an unactuated state, placed in a casing in a formation wellbore; -
FIG. 2 corresponds toFIG. 1 , and shows the invented device in an activated state, with four tools having been extended through the casing wall; -
FIG. 3 corresponds toFIG. 2 , and shows how the tools have shifted the casing in the wellbore, to a more centralized position in the wellbore than previously; -
FIG. 4 corresponds toFIG. 4 , and shows that the invented device has been removed from the casing, while the tools remain in the casing wall; -
FIG. 5 is a schematic illustration of a tool in an extended position; -
FIG. 6 is a schematic illustration of an alternative embodiment of a tool; -
FIG. 7 is a schematic illustration of an alternative embodiment of the invented device, during a first milling operation; -
FIG. 8 illustrates the device ofFIG. 7 , during the installation of a first set of wedges in an annulus between a casing and a formation; -
FIG. 9 illustrates the device ofFIG. 7 , during a second milling operation; -
FIG. 10 illustrates the device ofFIG. 7 , during the installation of a second set of wedges in an annulus between a casing and a formation; and -
FIG. 11 shows the first and second sets of wedges installed in an annulus between a casing and a formation, and a cement plug having been placed in a section of the annulus and casing. - The following description may use terms such as “horizontal”, “vertical”, “lateral”, “back and forth”, “up and down”, “upper”, “lower”, etc. These terms generally refer to the views and orientations as shown in the drawings and that are associated with the illustrated use of the invention. The terms are used for the reader's convenience only and shall not be limiting.
-
FIG. 1 shows acasing 1 placed in awellbore 2 having awall 2 a against asubterranean formation 7. As the jagged lines indicate, theformation wall 2 a may be of an irregular shape and contain cracks, fissures and unconsolidated regions. Thecasing 1 is not properly centralized in thewellbore 2, but is in contact with a portion of thewellbore wall 2 a (in the upper, left-hand part, as shown inFIG. 1 ). There is thus no complete is annulus between the casing and thewellbore wall 2 a, or theannulus 3 is insufficiently wide, therefore rendering a cementing procedure impossible at this location. -
FIG. 1 also shows the inventeddevice 4 in place inside thecasing 1. Thedevice 4 may be connected to a drillpipe, coiled tubing (not shown), or other known downhole device conveyance means, and powered and controlled from an uphole location, in a manner generally known in the art. In the illustrated embodiment, thedevice 4 comprises abody 9 and four individually operatedtools 5, which will be described below. - In
FIG. 2 , thetools 5 have been extended from thetool body 9 and advanced towards and through the casing wall. Eachindividual tool 5 is extended byindividual arms 6, which may be hydraulically operated telescopic cylinders, known per se in the art. Eachtool 5 comprises casing penetration means (not shown) for making a hole or other opening in the casing wall. Such casing penetration means may for example be jet blasting nozzles or a milling tool, all of which are generally known in the art. Eachtool 5 also comprises attachment means (not shown inFIG. 2 ) for attaching the tool to the casing wall, for example dogs, slips, or other anchoring means generally known in the art. With these means (referring toFIG. 5 ) afirst tool portion 5 a of thetool 5 may be held in position in the hole made in the casing wall, while asecond tool portion 5 b is advancing (e.g. telescoping) towards and into abutment with thewellbore wall 2 a. Other tool advancing means, such as a threaded, rotational configuration, are also envisaged. - Each
tool 5 may comprise distance-sensing means (not shown), by which the distance travelled by the tool may be monitored. Alternatively, such sensing means may be integrated in theindividual arm 6. It should be understood that the distance-sensing means may comprise generally known devices, including optical, acoustic and electromechanical means. The distance-sensing means will enable the device operator to determine the distance between the casing and theadjacent wellbore wall 2 a, thus being able to evaluate whether or not a sufficient clearance between casing and wellbore wall exists. - In
FIG. 3 , thetools 5 have been advanced further through their respective casing penetrations, towards thewellbore wall 2 a. By virtue of the individual tools' attachment to the casing wall, the casing is pushed away from thewellbore wall 2 a when the tool is abutting the formation. InFIG. 3 , this is seen as thecasing 1 has been pushed away from the wellbore wall by thetool 5′ (towards the right in the figure). Thereby, acomplete annulus 3, with a satisfactory casing-to-wall gap, has been established. The distance-sensing means are also in effect casing verification means, inasmuch as they will communicate the extended distance for each tool, and hence the minimum distance between the casing and the wellbore wall. -
FIG. 6 illustrates an alternative embodiment of the tool, being adeformable plug 5 c, pressing against the formation wall. -
FIG. 4 shows thecasing 1 centralized in the wellbore and thus forming anannulus 3 with the wellbore (formation)wall 2 a. Thetools 5 have been disconnected from their individual arm, and the device has been retrieved to an uphole location. The tools thus function as permanent casing centralizers, and cement (or other barrier element) 8 is placed into theannulus 3. Eachtool 5 is disconnectable from its individual arm by means that are known per se. - With the invention, it is possible to verify the distance between the casing and the adjacent wellbore wall, and, if necessary, move the casing laterally in order to centralize the casing and establish sufficient distance between the casing and the wall. These operations may be conducted in one downhole trip. The device and tools may be integrated with an additional tool (not shown), whereby a well barrier placement operation may be performed following the verification and centralization procedure.
- Although the invention has been described with reference to a casing and an adjacent wellbore (formation) wall, it should be understood that the invention is equally applicable for verifying and centralizing an inner casing in an outer casing.
-
FIG. 7 illustrates another embodiment of the inventeddevice 41, having atool section 41 a and amilling section 41 b. The device is conveyed into thecasing 1 and controlled via a drill string 10 (or coiled tubing, or similar). Thetool section 41 a carries a first (upper) wedge set 52 and a second (lower) wedge set 53. Themilling section 41 b, which is rotatably connected to the tool section, carries a set of millingarms 51. It should be understood that each set comprises a plurality of wedges and milling arms, respectively. InFIG. 7 , themilling section 41 b is rotated (as indicated by arrow R) with millingarms 51 in a deployed position, in a manner well known in the art, thus generating a first (upper) circumferential casing window 54 (seeFIG. 8 ). - In
FIG. 8 , the device has been lowered further into thecasing 1, and the second wedge set 53 has been entered (rammed or pushed) into theannulus 3, through thefirst casing window 54. At this stage, the connection between the first wedge set 53 and thetool section 41 is severed (e.g. sheared), and the device is being moved further into the casing, to a position shown inFIG. 9 . In the position shown inFIG. 9 , themilling section 41 b is once again rotated (as indicated by arrow R) with millingarms 51 in a deployed position, to generate a second (lower) circumferential casing window 55 (seeFIG. 10 ). - In
FIG. 10 , the device has been lowered further into thecasing 1, and the first wedge set 52 has been entered (rammed or pushed) into theannulus 3, through thesecond casing window 55. Upon completion of this step, the connection between the first wedge set 53 and thetool section 41 is severed (e.g. sheared), and the device may be retrieved from the casing, e.g. to an uphole location. - The action of forcing the sets of
wedges annulus 3 between thecasing 1 andwellbore 7 wall, serves to move (se M inFIG. 11 ) and centralize the casing portion between the first andsecond casing window annulus 3 where the wall-to-wall distance d is above a predetermined value considered safe for placing a well barrier element. This is illustrated inFIG. 11 , also showing how a plug of well barrier element (e.g. cement) 8 (or other barrier fluid) is placed in the region between the casing windows. - Although the description above with reference to
FIGS. 7 to 10 describe a procedure in which the upper (first) casingwindow 54 is milled before the lower (second) casingwindow 55, and the sets of wedges are installed in a corresponding sequence, it should be understood that the tool is equally applicable for a reversed method. In such method, thelower casing window 55 is milled first. Then, a lower wedge set 53 is installed through the lower casing window, whereupon the device is pulled to a location above the lower casing window. Here, theupper casing window 54 is milled and the corresponding upper wedge set 52 is installed. - Although the invention has been described with reference to casings, it should be understood that the invention is equally applicable to other tubulars. Although the invention has been described with reference to a plug-and-abandon operation, it should be understood that the invention is applicable to any centralization of tubulars.
- Although the invention has been described with reference to figures showing a vertically oriented wellbore and casing, the invention shall not be limited to such orientations, but are equally applicable wellbores having to horizontal or inclined orientations.
- Although the invention has been described with reference to a device having four tools, the invention shall not be limited to this number. A device having fewer or more tools shall be considered to be within the scope of this invention. For practical purposes, however, three tools, evenly spaced around the tool perimeter, is considered a minimum number. Five tools have been found to be a suitable number.
Claims (11)
Applications Claiming Priority (3)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
NO20151694 | 2015-12-09 | ||
NO20151694 | 2015-12-09 | ||
PCT/NO2016/050239 WO2017099604A1 (en) | 2015-12-09 | 2016-11-24 | A downhole tubular verification and centralizing device, and method |
Publications (1)
Publication Number | Publication Date |
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US20180355678A1 true US20180355678A1 (en) | 2018-12-13 |
Family
ID=59012850
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US16/061,163 Abandoned US20180355678A1 (en) | 2015-12-09 | 2016-11-24 | A downhole tubular verification and centralizing device, and method |
Country Status (6)
Country | Link |
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US (1) | US20180355678A1 (en) |
AU (1) | AU2016366956A1 (en) |
BR (1) | BR112018011565A2 (en) |
GB (1) | GB2562649A (en) |
NO (1) | NO20180950A1 (en) |
WO (1) | WO2017099604A1 (en) |
Citations (4)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20060054358A1 (en) * | 2003-01-22 | 2006-03-16 | Schlumberger Technology Corporation | Coring bit with uncoupled sleeve |
US7530407B2 (en) * | 2005-08-30 | 2009-05-12 | Baker Hughes Incorporated | Rotary coring device and method for acquiring a sidewall core from an earth formation |
US7958936B2 (en) * | 2004-03-04 | 2011-06-14 | Halliburton Energy Services, Inc. | Downhole formation sampling |
US20170030157A1 (en) * | 2014-05-16 | 2017-02-02 | Aarbakke Innovation A.S. | Multifunction wellbore tubular penetration tool |
Family Cites Families (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US5346016A (en) * | 1991-09-16 | 1994-09-13 | Conoco Inc. | Apparatus and method for centralizing pipe in a wellbore |
WO1995009967A1 (en) * | 1993-10-07 | 1995-04-13 | Conoco Inc. | Downhole activated process and apparatus for completing a wellbore |
US7422069B2 (en) * | 2002-10-25 | 2008-09-09 | Baker Hughes Incorporated | Telescoping centralizers for expandable tubulars |
-
2016
- 2016-11-24 US US16/061,163 patent/US20180355678A1/en not_active Abandoned
- 2016-11-24 WO PCT/NO2016/050239 patent/WO2017099604A1/en active Application Filing
- 2016-11-24 GB GB1811127.8A patent/GB2562649A/en not_active Withdrawn
- 2016-11-24 AU AU2016366956A patent/AU2016366956A1/en not_active Abandoned
- 2016-11-24 BR BR112018011565A patent/BR112018011565A2/en not_active Application Discontinuation
-
2018
- 2018-07-06 NO NO20180950A patent/NO20180950A1/en not_active Application Discontinuation
Patent Citations (4)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20060054358A1 (en) * | 2003-01-22 | 2006-03-16 | Schlumberger Technology Corporation | Coring bit with uncoupled sleeve |
US7958936B2 (en) * | 2004-03-04 | 2011-06-14 | Halliburton Energy Services, Inc. | Downhole formation sampling |
US7530407B2 (en) * | 2005-08-30 | 2009-05-12 | Baker Hughes Incorporated | Rotary coring device and method for acquiring a sidewall core from an earth formation |
US20170030157A1 (en) * | 2014-05-16 | 2017-02-02 | Aarbakke Innovation A.S. | Multifunction wellbore tubular penetration tool |
Also Published As
Publication number | Publication date |
---|---|
WO2017099604A1 (en) | 2017-06-15 |
BR112018011565A2 (en) | 2018-11-27 |
GB2562649A (en) | 2018-11-21 |
GB2562649A8 (en) | 2018-12-05 |
NO20180950A1 (en) | 2018-07-06 |
AU2016366956A1 (en) | 2018-06-07 |
GB201811127D0 (en) | 2018-08-22 |
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