US20210172289A1 - Downhole tool and uses thereof - Google Patents
Downhole tool and uses thereof Download PDFInfo
- Publication number
- US20210172289A1 US20210172289A1 US16/703,255 US201916703255A US2021172289A1 US 20210172289 A1 US20210172289 A1 US 20210172289A1 US 201916703255 A US201916703255 A US 201916703255A US 2021172289 A1 US2021172289 A1 US 2021172289A1
- Authority
- US
- United States
- Prior art keywords
- tool
- drill bit
- wellbore
- projection
- debris
- 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.)
- Abandoned
Links
- 239000012530 fluid Substances 0.000 claims description 44
- 238000005553 drilling Methods 0.000 claims description 21
- 238000000034 method Methods 0.000 claims description 17
- UONOETXJSWQNOL-UHFFFAOYSA-N tungsten carbide Chemical compound [W+]#[C-] UONOETXJSWQNOL-UHFFFAOYSA-N 0.000 claims description 12
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 10
- 239000004215 Carbon black (E152) Substances 0.000 claims description 4
- 229930195733 hydrocarbon Natural products 0.000 claims description 4
- 150000002430 hydrocarbons Chemical class 0.000 claims description 4
- 229910052751 metal Inorganic materials 0.000 claims description 4
- 239000002184 metal Substances 0.000 claims description 4
- 238000011084 recovery Methods 0.000 claims description 4
- 229910000975 Carbon steel Inorganic materials 0.000 claims description 3
- 239000010962 carbon steel Substances 0.000 claims description 3
- 239000011248 coating agent Substances 0.000 claims description 3
- 238000000576 coating method Methods 0.000 claims description 3
- 239000010935 stainless steel Substances 0.000 claims description 3
- 229910001220 stainless steel Inorganic materials 0.000 claims description 3
- 239000003129 oil well Substances 0.000 description 5
- 230000001419 dependent effect Effects 0.000 description 4
- VTYYLEPIZMXCLO-UHFFFAOYSA-L Calcium carbonate Chemical compound [Ca+2].[O-]C([O-])=O VTYYLEPIZMXCLO-UHFFFAOYSA-L 0.000 description 2
- MBMLMWLHJBBADN-UHFFFAOYSA-N Ferrous sulfide Chemical compound [Fe]=S MBMLMWLHJBBADN-UHFFFAOYSA-N 0.000 description 2
- TZCXTZWJZNENPQ-UHFFFAOYSA-L barium sulfate Chemical compound [Ba+2].[O-]S([O-])(=O)=O TZCXTZWJZNENPQ-UHFFFAOYSA-L 0.000 description 2
- 230000015572 biosynthetic process Effects 0.000 description 2
- OSGAYBCDTDRGGQ-UHFFFAOYSA-L calcium sulfate Chemical compound [Ca+2].[O-]S([O-])(=O)=O OSGAYBCDTDRGGQ-UHFFFAOYSA-L 0.000 description 2
- 238000005552 hardfacing Methods 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 150000003839 salts Chemical class 0.000 description 2
- UBXAKNTVXQMEAG-UHFFFAOYSA-L strontium sulfate Chemical compound [Sr+2].[O-]S([O-])(=O)=O UBXAKNTVXQMEAG-UHFFFAOYSA-L 0.000 description 2
- 229910019142 PO4 Inorganic materials 0.000 description 1
- 230000004075 alteration Effects 0.000 description 1
- 229910000019 calcium carbonate Inorganic materials 0.000 description 1
- 238000005520 cutting process Methods 0.000 description 1
- 230000008021 deposition Effects 0.000 description 1
- 238000002347 injection Methods 0.000 description 1
- 239000007924 injection Substances 0.000 description 1
- 238000003780 insertion Methods 0.000 description 1
- 230000037431 insertion Effects 0.000 description 1
- UQSXHKLRYXJYBZ-UHFFFAOYSA-N iron oxide Inorganic materials [Fe]=O UQSXHKLRYXJYBZ-UHFFFAOYSA-N 0.000 description 1
- 235000013980 iron oxide Nutrition 0.000 description 1
- VBMVTYDPPZVILR-UHFFFAOYSA-N iron(2+);oxygen(2-) Chemical class [O-2].[Fe+2] VBMVTYDPPZVILR-UHFFFAOYSA-N 0.000 description 1
- 238000003754 machining Methods 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- -1 oxides Chemical class 0.000 description 1
- 235000021317 phosphate Nutrition 0.000 description 1
- 150000003013 phosphoric acid derivatives Chemical class 0.000 description 1
- 239000004576 sand Substances 0.000 description 1
- 150000004760 silicates Chemical class 0.000 description 1
Images
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B37/00—Methods or apparatus for cleaning boreholes or wells
- E21B37/02—Scrapers specially adapted therefor
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B10/00—Drill bits
- E21B10/26—Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B10/00—Drill bits
- E21B10/46—Drill bits characterised by wear resisting parts, e.g. diamond inserts
- E21B10/56—Button-type inserts
- E21B10/567—Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
Definitions
- the present disclosure relates generally to well equipment for bore holes. More particularly, the present disclosure relates to a downhole tool and uses thereof.
- Scale can be caused by a deposition of, for example, various salts, oxides, silicates, and/or phosphates onto surfaces within a well, such as an oil well, a gas well, a water well, etc.
- Some specific, non-limiting examples of scale include metal salts and oxides, such as calcium carbonate, calcium sulfate, barium sulfate, strontium sulfate, iron sulfide, iron oxides, etc.
- the downhole tool comprises a drill bit, the drill bit having an outer surface for engaging a wellbore and defining a bit bore therethrough, the drill bit having a first end defining a leading face and a second end adapted to engage a drive pipe; and a projection coupled to the outer surface of the drill bit, the projection being adapted to remove debris from a wellbore.
- the projection comprises a plurality of projections.
- the projection separates or detaches the scale and debris from the wellbore, at least partially breaks up, grinds down or crushes the scale and debris, and the scale and debris are at least partially removed from the wellbore by circulation of fluids, reverse circulation of fluids, or a combination thereof.
- the scale and debris is substantially separated or detached from the wellbore.
- the scale and debris is substantially removed from the wellbore by circulation of fluids, reverse circulation of fluids or a combination thereof, i.e. sequentially.
- the present disclosure provides a downhole tool, including a drill bit, the drill bit having an outer surface for engaging a wellbore and defining a bit bore, the drill bit having a first end defining a leading face and a second end adapted to engage a drive pipe, and a projection coupled to the outer surface of the drill bit, the projection being adapted to remove debris from the wellbore.
- the projection comprises a plurality of projections.
- each of the plurality of projections is circumferentially displaced relative to each other.
- each of the plurality of projections is longitudinally displaced relative to each other.
- each of the plurality of projections are circumferentially and longitudinally displaced relative to each other and spiral along the outer surface of the drill bit.
- the plurality of projections may be oriented in a general “spiral” orientation.
- the outer surface of the drill bit has a substantially frustoconical-shaped section proximal the first end, and a substantially cylinder shaped section.
- the outer surface of the drill bit has a substantially cylinder-shaped section abutting the second end, and a substantially frustoconical-shaped section abutting the substantially cylinder-shaped section and terminating at the first end.
- the projection extends substantially perpendicular from the outer surface of the drill bit.
- the projection extends from the outer surface between about 1 mm and about 10 mm.
- At least one of the plurality of projections extends beyond an outer diameter of the cylinder-shaped section, by an undercut height.
- the undercut height is a maximum of 10 mm.
- the undercut height is between about 2.5 mm and about 10 mm.
- the projection is substantially frustoconical shaped.
- the projection is substantially shaped as a cone tip, a wedge-shape, a wedge-tip, a random clustering or a combination thereof.
- the projection is composed of one or more of substantially tungsten carbide, hardened metal, carbon steel or stainless steel.
- the projection is coupled to the substantially frustoconical-shaped section of the outer surface of the drill bit.
- the projection is integral with the outer surface of the drill bit.
- the projection is pressed into the outer surface of the drill bit.
- leading face comprises a plurality of pegs extending longitudinally from the leading face, adapted to facilitate drilling.
- leading face is substantially a saw tooth face.
- leading face defines an elliptical plane having a pitch greater than 0 degrees.
- the pitch is between about 15 degrees and about 30 degrees.
- the pitch is about 24 degrees.
- At least a portion of the leading face is angled at a face angle.
- the face angle is greater than 0 degrees.
- the face angle is between about 15 degrees and about 30 degrees.
- the face angle is about 24 degrees.
- the projection comprises a tungsten carbide coating providing a plurality of tungsten carbide clusters (clusterite) spaced about the frustoconical-shaped section.
- the frustoconical-shaped section comprises a taper.
- the taper is between about 2 degrees and about 8 degrees.
- the taper is about 5 degrees.
- the present disclosure provides the use of the tool as disclosed herein with an oil and gas well service rig or an oil and gas drilling rig.
- the tool is used with a tubular.
- the tool is used to remove debris from a wellbore.
- the debris includes or is hard scale.
- the present disclosure provides a method for servicing a well having a defined wellbore restricted by debris, including inserting a clean-out string into the wellbore of the well, the clean-out string having a downhole tool as disclosed herein coupled thereto, and rotating the clean-out string to engage the downhole tool with the debris restricting the wellbore to remove the debris from the wellbore.
- the method further includes circulating or reverse circulating a fluid through the well to carry the debris removed from the wellbore out of the well.
- inserting the clean-out string into the wellbore includes positioning the downhole tool within the wellbore at a point restricted by the debris.
- engaging the downhole tool with the debris restricting the wellbore comprises rotating the downhole tool to engage a projection of the downhole tool with the debris to grind down or break apart the debris within the wellbore.
- the fluid is a drilling fluid or a well servicing fluid.
- the drilling fluid or the well servicing fluid may be water.
- the well is a hydrocarbon recovery well or a water well.
- the debris comprises hard scale or well-bottom debris or both.
- FIG. 1 depicts a plurality of views of a downhole tool in accordance with an embodiment of the present disclosure, showing a plurality of frustoconical-shaped projections on the outer surface of the drill bit.
- FIG. 2 depicts a top plan view of the downhole tool of FIG. 1 , showing the bit bore defined by the drill bit and a plurality of frustoconical-shaped projections on the outer surface of the drill bit.
- FIG. 3 depicts a side-elevation view of the downhole tool of FIG. 2 , showing the bit bore defined by the drill bit (in dashed lines), a plurality of frustoconical-shaped projections on the outer surface of the drill bit, with the first end (typically well bottom) of the drill bit defining a leading face and the second end (typically well top) of the drill bit adapted to engage a drive pipe.
- FIG. 4 depicts of a perspective view of the downhole tool of FIG. 2 , showing the first end of the drill bit defining a leading face comprising a plurality of teeth-like projections adapted to facilitate drilling, in accordance with an embodiment of the present disclosure.
- FIG. 5 depicts a side-elevation view of a downhole tool in accordance with an embodiment of the present disclosure, showing a plurality of wedge-tip projections on the outer surface of the drill bit, with the first end of the drill bit defining a leading face and the second end of the drill bit adapted to engage a drive pipe.
- FIG. 6 depicts a plurality of views of a downhole tool in accordance with an embodiment of the present disclosure, showing a plurality of wedge-tip projections on the outer surface of the drill bit, with a first end of the drill bit defining a leading face and a second end of the drill bit adapted to engage a drive pipe, the leading face having a substantially saw-tooth face.
- FIG. 7 depicts a side-elevation view of the downhole tool of FIG. 6 , showing a plurality of wedge-tip projections on the outer surface of the drill bit, with the first end of the drill bit defining a leading face having a substantially saw-tooth face and the second end of the drill bit adapted to engage a drive pipe.
- FIG. 8 depicts a perspective view of a downhole tool in “Normal Circulation” in accordance with an embodiment of the present disclosure in use in a wellbore.
- FIG. 9 depicts a perspective view of a downhole tool in “Reverse Circulation” in accordance with an embodiment of the present disclosure in use in a wellbore.
- a downhole tool as described herein may be used to break up or grind down and remove scale and debris that has built up within a defined wellbore, including but not limited to cased wellbores, uncased wellbores, and combinations thereof including but not limited to wellbores with barefoot completions, the wellbore being a wellbore of, for example, a hydrocarbon recovery well (e.g. producing one or more of oil, gas and water), a water well, an injection well, or other well.
- a hydrocarbon recovery well e.g. producing one or more of oil, gas and water
- the downhole tool comprises a drill bit, the drill bit having an outer surface for engaging a wellbore and defining a bit bore, the drill bit having a first end defining a leading face and a second end adapted to engage a drive pipe; and a projection coupled to the outer surface of the drill bit, the projection being adapted to remove debris from a wellbore.
- the scale and debris are at least partially removed from the wellbore when broken up or ground down by the downhole tool comprising the projection and carried to the surface through the circulation of drilling fluid.
- the projection comprises a plurality of projections.
- the downhole tool is used on a well servicing tubing string that, generally, is top-driven.
- the downhole tool is used with a mud motor, or down-hole motor.
- the present disclosure is preferably used with drive that allows the use of reverse circulation whereby returning fluids and cleaned out debris are conveyed to the surface through the internal bore of the bit and clean out string.
- FIGS. 1 to 4 show a downhole tool having a drill bit 100 , the drill bit having an outer surface for engaging a wellbore and defining a bit bore 2 .
- the drill bit 100 has a first end 4 defining a leading face and a second end 5 adapted to engage a drive pipe, with the outer surface having a substantially cylinder-shaped section 7 abutting the second end 5 , and a substantially frustoconical-shaped section 6 abutting the substantially cylinder-shaped section 7 and terminating at the first end 4 .
- the first end 4 defines a leading face that comprises a plurality of pegs 9 adapted to facilitate drilling, the pegs 9 extending longitudinally from the leading face. In some examples, the pegs 9 are absent.
- the substantially cylinder-shaped section 7 is proximal the second end 5 . In other examples, the substantially frustoconical-shaped section 6 is proximal the substantially cylinder-shaped section 7 and the first end 4 . In some examples, the substantially cylinder-shaped section 7 of the outer surface acts to centralizing the drill bit 100 in the wellbore. In other examples, the substantially cylinder-shaped section 7 of the outer surface is sized to provide an annular gap within the wellbore. In some examples, the annular gap is from about 10 mm to about 50 mm in size.
- the drill bit 100 has a projection 3 coupled to the substantially frustoconical-shaped section 6 of the outer surface, the projection 3 being adapted to remove (e.g., break up or grind down) debris from a wellbore.
- the projection 3 extends substantially perpendicular from the outer surface 6 , and is substantially frustoconical-shaped. In some examples the projection 3 is a wedge tipped shape, and in others it is cone-shaped. In other cases the projection 3 is made up of randomly clustered cutting surfaces.
- the drill bit 100 may utilize one or more type/shape of projection 3 .
- the projection 3 is composed of tungsten carbide.
- the projection 3 is integral with the outer surface of the drill bit 100 .
- the projection 3 is pressed into the outer surface of the drill bit 100 .
- the projection 3 comprises a plurality of projections, each of the projections being circumferentially and longitudinally displaced relative to each other to spiral along the substantially frustoconical-shaped section 6 of outer surface of the drill bit 100 .
- each of the plurality of projections is circumferentially displaced relative to each other.
- each of the plurality of projections is longitudinally displaced relative to each other.
- the projections are clustered randomly.
- FIG. 5 shows a downhole tool having a drill bit 102 , the drill bit 102 having an outer surface for engaging a wellbore and defining a bit bore (not shown).
- the drill bit 102 has a first end 4 A defining a leading face and a second end 5 A adapted to engage a drive pipe, with the outer surface having a substantially cylinder-shaped section 7 A abutting the second end 5 A, and a substantially frustoconical-shaped section 6 A abutting the substantially cylinder-shaped section 7 A and terminating at the first end 4 A.
- the substantially cylinder-shaped section 7 A is proximal the second end 5 A.
- the substantially frustoconical-shaped section 6 A is proximal the substantially cylinder-shaped section 7 A and the first end 4 A.
- the substantially cylinder-shaped section 7 A of the outer surface acts to centralizing the drill bit 102 in the wellbore.
- the substantially cylinder-shaped section 7 A of the outer surface is sized to provide an annular gap within the wellbore. In some examples, the annular gap is from about 10 mm to about 50 mm in size.
- the drill bit 102 has a projection 10 that is substantially shaped as a wedge-tip.
- the projection 10 extends substantially perpendicular from the substantially frustoconical-shaped section 6 A of the outer surface of the drill bit 102 .
- the projection 10 is composed of tungsten carbide.
- the projection 10 is integral with the outer surface of the drill bit 102 .
- the projection 10 is pressed into the outer surface of the drill bit 102 .
- the projection 10 comprises a plurality of projections, each of the projections being circumferentially and longitudinally displaced relative to each other to spiral along the substantially frustoconical-shaped section 6 A of the outer surface of the drill bit 102 .
- each of the plurality of projections is circumferentially displaced relative to each other.
- each of the plurality of projections is longitudinally displaced relative to each other.
- FIGS. 6 and 7 show a downhole tool having a drill bit 104 , the drill bit having an outer surface for engaging a wellbore and defining a bit bore 2 B.
- the drill bit 104 has a first end 4 B defining a leading face and a second end 5 B adapted to engage a drive pipe, with the outer surface having a substantially cylinder-shaped section 7 B abutting the second end 5 B, and a substantially frustoconical-shaped section 6 B abutting the substantially cylinder-shaped section 7 B and terminating at the first end 4 B.
- the first end 4 B defines a leading face that has a substantially saw-tooth face 8 adapted to facilitate drilling. In some examples, the saw-tooth face 8 is absent.
- the drill bit 104 also has hardfacing strips 11 to provide additional strength to the drill bit 104 . In some examples, the hardfacing strips 11 are absent.
- the substantially cylinder-shaped section 7 B is proximal the second end 5 B. In other examples, the substantially frustoconical-shaped section 6 B is proximal the substantially cylinder-shaped section 7 B and the first end 4 B. In some examples, the substantially cylinder-shaped section 7 B of the outer surface acts to centralizing the drill bit 104 in the wellbore. In other examples, the substantially cylinder-shaped section 7 B of the outer surface is sized to provide an annular gap within the wellbore. In some examples, the annular gap is from about 10 mm to about 50 mm in size.
- the drill bit 104 has a projection 10 B that is substantially shaped as a wedge-tip.
- the projection 10 B extends substantially perpendicular from the substantially frustoconical-shaped section 6 B of the outer surface of the drill bit 104 .
- the projection 10 B is composed of tungsten carbide.
- the projection 10 B is integral with the outer surface of the drill bit 104 .
- the projection 10 B is pressed into the outer surface of the drill bit 104 .
- the projection 10 B comprises a plurality of projections, each of the projections being circumferentially and longitudinally displaced relative to each other to spiral along the substantially frustoconical-shaped section 6 B of the outer surface of the drill bit 104 .
- each of the plurality of projections is circumferentially displaced relative to each other.
- each of the plurality of projections is longitudinally displaced relative to each other.
- drill bit 100 is attached to drive 20 and inserted into a wellbore 30 until above or at debris 40 .
- Rotation 45 e.g. conventionally clockwise looking from above
- drive 20 e.g. from a top drive or rotary drive at surface or a mud motor or downhole motor proximate the drill bit 100
- the drill bit 100 causes the drill bit 100 to grind down or break up at least a portion and preferably substantially the debris 40 .
- Circulation of fluid 50 sweeps or otherwise conveys the ground debris 60 to surface. While FIG.
- FIGS. 8 and 9 illustrate the wellbore 30 as being a substantially vertical portion, the invention may also be applied to wells having slanted, horizontal, lateral, angled, dogleg, and/or radiused sections. While FIGS. 8 and 9 illustrate the wellbore 30 as having a casing 70 , as described herein, the invention may also be applied to uncased wellbores.
- the downhole tool having the drill bit 100 , 102 , 104 is attached in a conventional manner to, for example, a well service drilling rig drive pipe and run into an affected, already defined wellbore (e.g., a wellbore of an oil well, gas well, water well, or other well, etc.) that has a build-up of hard scale or debris.
- a well service drilling rig drive pipe e.g., a wellbore of an oil well, gas well, water well, or other well, etc.
- the downhole tool is used on a well servicing tubing string that is top-driven.
- the downhole tool is used with a mud motor, or down-hole motor.
- the shape of the drill bit 100 , 102 , 104 and projection 3 , 10 , 10 B coupled thereto allow the downhole tool to be used to grind down or break up and remove scale and debris from the wellbore as the drill bit 100 , 102 , 104 is rotated.
- fluids e.g., drilling fluids, well-servicing fluids
- fluids are, for example, circulated down the drive pipe and delivered with a high hydraulic velocity at the leading face defined by the first end 4 , 4 A, 4 B of the drill bit 100 , 102 , 104 due to the single bit bore 2 , 2 B of the drill bit 100 , 102 , 104 .
- the fluids then carry the scale and debris removed from the wellbore by the downhole tool out of the wellbore via an annulus formed between the drive pipe and the wellbore.
- shark-tooth machining of the leading face defined by the first end 4 , 4 A, 4 B of the drill bit 100 , 102 , 104 provides for a more aggressive bite when required (e.g., teeth-like projections 9 of drill bit 100 in FIGS. 1 to 4 , and substantially saw-tooth face 8 of drill bit 104 in FIGS. 6 and 7 ).
- the fluids are reverse circulated down the annulus and then carry the scale and debris out of the wellbore via the internal bore of the drive pipe.
- the downhole tool having the drill bit 100 , 102 , 104 is attached in a conventional manner to, for example, a well service drilling rig drive pipe and run into an affected, already defined wellbore (e.g., a wellbore of an oil well, gas well, water well, etc.) that has a build-up of hard scale or debris.
- the present disclosure is used with a drive that allows the use of reverse circulation whereby returning fluids and cleaned out debris are conveyed to the surface through the internal bore of the bit and clean out string.
- the downhole tool is used on a well servicing tubing string that is top-driven.
- the drill bit 100 , 102 , 104 is rotated in a conventional manner.
- the shape of the drill bit 100 , 102 , 104 and projection 3 , 10 , 10 B coupled thereto allow the downhole tool to be used to grind down or break up and remove scale and debris from the wellbore as the drill bit 100 , 102 , 104 is rotated.
- fluids e.g., drilling fluids, well-servicing fluids
- fluids are, for example, reverse circulated down the annulus formed between the drive pipe and the wellbore and delivered with a high hydraulic velocity at the leading face defined by the first end 4 , 4 A, 4 B of the drill bit 100 , 102 , 104 due to the single bit bore 2 , 2 B of the drill bit 100 , 102 , 104 .
- the fluids then carry the scale and debris removed from the wellbore by the downhole tool out of the wellbore to surface via the drive pipe bore.
- a combination or sequence of circulation, reverse circulation, no circulation may be used.
- a combination or sequence of rotating or non-rotating may be used.
- the downhole tool having the drill bit 100 , 102 , 104 is attached to the bottom of a clean-out string, and run into an affected well with an already defined wellbore to break up or grind out built-up scale and other well-bottom debris. Such debris may then be reverse circulated out of the well during a clean out operation.
- a clean-out string is a string of tubing assembled specifically to clean out a well.
- the well may be, for example, an oil well, gas well, or water well that has its performance restricted by well-bottom debris.
- the clean-out string is generally set up by a service rig attending the wellsite. For example, if in use, a production tubing string is first removed from the affected well and set aside in a suitable manner.
- the downhole tool having the drill bit 100 , 102 , 104 is attached to the bottom of the clean-out string using a make-up torque suitable for the threads of the clean-out string.
- the downhole tool having the drill bit 100 , 102 , 104 may optionally be used with one or more specialized joints in the clean-out string.
- the clean-out string is then inserted into, for example, the casing of the affected well and lowered to the point of debris obstruction. Standard industry well servicing practices may be followed during the insertion of the clean-out string.
- the clean-out string is rotated, and the well is reverse circulated, with well servicing fluid being pumped down to the well-bottom through the annulus between the string and the casing.
- the well servicing fluid is returned to the surface through the single bit bore 2 , 2 B of the drill bit 100 , 102 , 104 and clean-out string.
- the well servicing fluid pump rates need to be sufficient to create a fluid velocity that will carry debris up through the center bore of the clean-out string.
- the clean-out string is rotated to create a grinding action with the downhole tool having the drill bit 100 , 102 , 104 , where common industry practice would determine the rotation rate.
- the projection 3 , 10 , 10 B coupled to the drill bit 100 , 102 , 104 grinds off or breaks up the debris until it is small enough to be lifted by the well servicing fluid.
- the flow of the well servicing fluid then carries the debris to the surface where it is removed from the well servicing fluid in a conventional manner.
- the clean-out string is pulled out of the well bore, and the downhole tool having the drill bit 100 , 102 , 104 is inspected and set aside for use in another well service job.
- the normal service string is then reinserted into the wellbore and well put back into normal service.
- the downhole tool having the drill bit 100 , 102 , 104 may be used with an well service drilling rig, such as an oil well service drilling rig. In other examples, the downhole tool having the drill bit 100 , 102 , 104 may be used with a well service drilling rig drill pipe. In yet other examples, the downhole tool having the drill bit 100 , 102 , 104 may be used with a drill pipe. In other examples, the downhole tool having the drill bit 100 , 102 , 104 may be used to remove debris from a wellbore, wherein the debris may comprise hard scale.
- the downhole tool may be used with tubulars, including but not limited to pipe, drill pipe, tubing, coiled tubing, jointed tubing.
- the downhole tool may be rotated from surface, for example by a top drive or rotary table or may be rotated proximate the downhole tool, for example by a mud motor or downhole-motor.
- the present disclosure is preferably used with drive that allows the use of reverse circulation whereby returning fluids and cleaned out debris are conveyed to the surface through the internal bore of the bit and clean out string.
- the supply of well servicing fluid, and circulation or reverse circulation, as the case may be, as well as the removal of debris from the well servicing fluid, is provided from/at surface.
- hard scale is loose debris that may originate from one or more sources within or associated with the wellbore. It may be hard debris that originates from within the completed formation or from formation fluids. Occasionally, hard scale or well bottom debris could result from mechanical debris from wellbore components. Hard scale or well bottom debris could also result from scale, consolidated or unconsolidated sand, iron sulfides, wax or a combination of one or more of the above. When the material is hard, the disclosed tool and methods break it up.
- Embodiment 1 A downhole tool, comprising: a drill bit, the drill bit having an outer surface for engaging a wellbore and defining a bit bore, the drill bit having a first end defining a leading face and a second end adapted to engage a drive pipe; and a projection coupled to the outer surface of the drill bit, the projection being adapted to remove debris from the wellbore.
- Embodiment 2 The tool of embodiment 1, wherein the projection comprises a plurality of projections.
- Embodiment 3 The tool of embodiment 2, wherein each of the plurality of projections is circumferentially displaced relative to each other.
- Embodiment 4 The tool of embodiment 2 or 3, wherein each of the plurality of projections is longitudinally displaced relative to each other.
- Embodiment 5 The tool of any one of embodiments 2 to 4, wherein each of the plurality of projections are circumferentially and longitudinally displaced relative to each other and spiral along the outer surface of the drill bit.
- Embodiment 6 The tool of any one of embodiments 1 to 5, wherein the outer surface of the drill bit has a substantially frustoconical-shaped section proximal the first end, and a substantially cylinder-shaped section.
- Embodiment 7 The tool of any one of embodiments 1 to 6, wherein the outer surface of the drill bit has a substantially cylinder-shaped section abutting the second end, and a substantially frustoconical-shaped section abutting the substantially cylinder-shaped section and terminating at the first end.
- Embodiment 8 The tool of any one of embodiments 1 to 7, wherein the projection extends substantially perpendicular from the outer surface of the drill bit.
- Embodiment 9 The tool of embodiment 8, wherein the projection extends from the outer surface between about 1 mm and about 10 mm.
- Embodiment 10 The tool of any one of embodiments 7 to 9 when dependent on embodiment 2, wherein at least one of the plurality of projections extends beyond an outer diameter of the cylinder-shaped section, by an undercut height.
- Embodiment 11 The tool of embodiment 10, wherein the undercut height is a maximum of 10 mm.
- Embodiment 12 The tool of embodiment 11, wherein the undercut height is between about 2.5 mm and about 10 mm.
- Embodiment 13 The tool of any one of embodiments 1 to 12, wherein the projection is substantially frustoconical-shaped.
- Embodiment 14 The tool of any one of embodiments 1 to 12, wherein the projection is substantially shaped as a cone tip, a wedge-shape, a wedge-tip, a random clustering or a combination thereof.
- Embodiment 15 The tool of any one of embodiments 1 to 14, wherein the projection is composed of one or more of substantially tungsten carbide, hardened metal, carbon steel or stainless steel.
- Embodiment 16 The tool of embodiment 6 or 7, or any one of embodiments 8 to 15 when dependent on embodiment 6 or 7, wherein the projection is coupled to the substantially frustoconical-shaped section of the outer surface of the drill bit.
- Embodiment 17 The tool of any one of embodiments 1 to 16, wherein the projection is integral with the outer surface of the drill bit.
- Embodiment 18 The tool of any one of embodiments 1 to 16, wherein the projection is pressed into the outer surface of the drill bit.
- Embodiment 19 The tool of any one of embodiments 1 to 18, wherein the leading face comprises a plurality of pegs extending longitudinally from the leading face, adapted to facilitate drilling.
- Embodiment 20 The tool of any one of embodiments 1 to 18, wherein the leading face is substantially a saw-tooth face.
- Embodiment 21 The tool of any one of embodiments 1 to 20, wherein the leading face defines an elliptical plane having a pitch greater than 0 degrees.
- Embodiment 22 The tool of embodiment 21, wherein the pitch is between about 15 degrees and about 30 degrees.
- Embodiment 23 The tool of embodiment 22, wherein the pitch is about 24 degrees.
- Embodiment 24 The tool of any one of embodiment 1 to 20, wherein at least a portion of the leading face is angled at a face angle.
- Embodiment 25 The tool of embodiment 24, wherein the face angle is greater than 0 degrees.
- Embodiment 26 The tool of embodiment 25, wherein the face angle is between about 15 degrees and about 30 degrees.
- Embodiment 27 The tool of embodiment 26, wherein the face angle is about 24 degrees.
- Embodiment 28 The tool of any one of embodiments 6 or 7 to 27 when dependent on embodiment 6, wherein the projection comprises a tungsten carbide coating providing a plurality of tungsten carbide clusters (clusterite) spaced about the frustoconical-shaped section.
- Embodiment 29 The tool of any one of embodiments 6 or 7 to 28 when dependent on embodiment 6, wherein the frustoconical-shaped section comprises a taper.
- Embodiment 30 The tool of embodiment 29, wherein the taper is between about 2 degrees and about 8 degrees.
- Embodiment 31 The tool of embodiment 30, wherein the taper is about 5 degrees.
- Embodiment 32 Use of the tool of any one of embodiments 1 to 31 with an oil and gas well service rig or an oil and gas drilling rig.
- Embodiment 33 Use of the tool of any one of embodiments 1 to 31 with a tubular.
- Embodiment 34 Use of the tool of any one of embodiments 1 to 31 to remove debris from a wellbore.
- Embodiment 35 The use of embodiment 34, wherein the debris comprises hard scale.
- Embodiment 36 A method for servicing a well having a defined wellbore restricted by debris, comprising: inserting a clean-out string into the wellbore of the well, the clean-out string having a downhole tool of any one of embodiments 1 to 31 coupled thereto; and rotating the clean-out string to engage the downhole tool with the debris restricting the wellbore to remove the debris from the wellbore.
- Embodiment 37 The method of embodiment 36, further comprising circulating or reverse circulating a fluid through the well to carry the debris removed from the wellbore out of the well.
- Embodiment 38 The method of embodiment 36 or 37, wherein inserting the clean-out string into the wellbore comprises positioning the downhole tool within the wellbore at a point restricted by the debris.
- Embodiment 39 The method of any one of embodiments 36 to 38, wherein engaging the downhole tool with the debris restricting the wellbore comprises rotating the downhole tool to engage a projection of the downhole tool with the debris to grind down or break apart the debris within the wellbore.
- Embodiment 40 The method of any one of embodiment 36 to 39, wherein the fluid is a drilling fluid or a well-servicing fluid.
- Embodiment 41 The method of any one of embodiments 36 to 40, wherein the well is a hydrocarbon recovery well or a water well.
- Embodiment 42 The method of any one of embodiments 36 to 41, wherein the debris comprises hard scale or well-bottom debris or both.
Abstract
There is provided a downhole tool that can be used to grind down and remove scale and debris that has built up within a wellbore. The downhole tool has a drill bit that has an outer surface for engaging a wellbore and defines a bit bore. The drill bit has a first end defining a bit face and a second end adapted to engage a drive pipe. The drill bit also has a projection coupled to the outer surface of the drill bit, the projection being adapted to remove debris from a wellbore. In some cases, the projection comprises a plurality of projections. Generally, the scale and debris are at least partially removed from the wellbore when ground down by the downhole tool comprising the projection.
Description
- The present disclosure relates generally to well equipment for bore holes. More particularly, the present disclosure relates to a downhole tool and uses thereof.
- Wellbores in, for example, the oil and gas industry can build up scale and other debris. Scale can be caused by a deposition of, for example, various salts, oxides, silicates, and/or phosphates onto surfaces within a well, such as an oil well, a gas well, a water well, etc. Some specific, non-limiting examples of scale include metal salts and oxides, such as calcium carbonate, calcium sulfate, barium sulfate, strontium sulfate, iron sulfide, iron oxides, etc. When wellbores accumulate a considerable build-up of hard scale and debris they can become subject to clogging and the scale and debris must be removed, for example by a well service rig. On occasion, well bore debris may also result from mechanical sources within the well bore. There remains a need for equipment that facilitates removal of a build-up of scale and debris from all sources within wellbores.
- Herein described is a downhole tool that can be used to grind down and remove scale and debris that has built up within a defined wellbore, including but not limited to cased wellbores, uncased wellbores, and combinations thereof including but not limited to wellbores with barefoot completions. The downhole tool comprises a drill bit, the drill bit having an outer surface for engaging a wellbore and defining a bit bore therethrough, the drill bit having a first end defining a leading face and a second end adapted to engage a drive pipe; and a projection coupled to the outer surface of the drill bit, the projection being adapted to remove debris from a wellbore. In some embodiments, the projection comprises a plurality of projections.
- Generally, the projection separates or detaches the scale and debris from the wellbore, at least partially breaks up, grinds down or crushes the scale and debris, and the scale and debris are at least partially removed from the wellbore by circulation of fluids, reverse circulation of fluids, or a combination thereof. In an embodiment disclosed, the scale and debris is substantially separated or detached from the wellbore. In an embodiment disclosed, the scale and debris is substantially removed from the wellbore by circulation of fluids, reverse circulation of fluids or a combination thereof, i.e. sequentially.
- In a first aspect, the present disclosure provides a downhole tool, including a drill bit, the drill bit having an outer surface for engaging a wellbore and defining a bit bore, the drill bit having a first end defining a leading face and a second end adapted to engage a drive pipe, and a projection coupled to the outer surface of the drill bit, the projection being adapted to remove debris from the wellbore.
- In an embodiment disclosed the projection comprises a plurality of projections.
- In an embodiment disclosed each of the plurality of projections is circumferentially displaced relative to each other.
- In an embodiment disclosed each of the plurality of projections is longitudinally displaced relative to each other.
- In an embodiment disclosed each of the plurality of projections are circumferentially and longitudinally displaced relative to each other and spiral along the outer surface of the drill bit. The plurality of projections may be oriented in a general “spiral” orientation.
- In an embodiment disclosed the outer surface of the drill bit has a substantially frustoconical-shaped section proximal the first end, and a substantially cylinder shaped section.
- In an embodiment disclosed the outer surface of the drill bit has a substantially cylinder-shaped section abutting the second end, and a substantially frustoconical-shaped section abutting the substantially cylinder-shaped section and terminating at the first end.
- In an embodiment disclosed the projection extends substantially perpendicular from the outer surface of the drill bit.
- In an embodiment disclosed the projection extends from the outer surface between about 1 mm and about 10 mm.
- In an embodiment disclosed at least one of the plurality of projections extends beyond an outer diameter of the cylinder-shaped section, by an undercut height.
- In an embodiment disclosed the undercut height is a maximum of 10 mm.
- In an embodiment disclosed the undercut height is between about 2.5 mm and about 10 mm.
- In an embodiment disclosed the projection is substantially frustoconical shaped.
- In an embodiment disclosed the projection is substantially shaped as a cone tip, a wedge-shape, a wedge-tip, a random clustering or a combination thereof.
- In an embodiment disclosed the projection is composed of one or more of substantially tungsten carbide, hardened metal, carbon steel or stainless steel.
- In an embodiment disclosed the projection is coupled to the substantially frustoconical-shaped section of the outer surface of the drill bit.
- In an embodiment disclosed the projection is integral with the outer surface of the drill bit.
- In an embodiment disclosed the projection is pressed into the outer surface of the drill bit.
- In an embodiment disclosed the leading face comprises a plurality of pegs extending longitudinally from the leading face, adapted to facilitate drilling.
- In an embodiment disclosed the leading face is substantially a saw tooth face.
- In an embodiment disclosed the leading face defines an elliptical plane having a pitch greater than 0 degrees.
- In an embodiment disclosed the pitch is between about 15 degrees and about 30 degrees.
- In an embodiment disclosed the pitch is about 24 degrees.
- In an embodiment disclosed at least a portion of the leading face is angled at a face angle.
- In an embodiment disclosed the face angle is greater than 0 degrees.
- In an embodiment disclosed the face angle is between about 15 degrees and about 30 degrees.
- In an embodiment disclosed the face angle is about 24 degrees.
- In an embodiment disclosed the projection comprises a tungsten carbide coating providing a plurality of tungsten carbide clusters (clusterite) spaced about the frustoconical-shaped section.
- In an embodiment disclosed the frustoconical-shaped section comprises a taper.
- In an embodiment disclosed the taper is between about 2 degrees and about 8 degrees.
- In an embodiment disclosed the taper is about 5 degrees.
- In a further aspect, the present disclosure provides the use of the tool as disclosed herein with an oil and gas well service rig or an oil and gas drilling rig.
- In an embodiment disclosed the tool is used with a tubular.
- In an embodiment disclosed the tool is used to remove debris from a wellbore.
- In an embodiment disclosed the debris includes or is hard scale.
- In a further aspect, the present disclosure provides a method for servicing a well having a defined wellbore restricted by debris, including inserting a clean-out string into the wellbore of the well, the clean-out string having a downhole tool as disclosed herein coupled thereto, and rotating the clean-out string to engage the downhole tool with the debris restricting the wellbore to remove the debris from the wellbore.
- In an embodiment disclosed the method further includes circulating or reverse circulating a fluid through the well to carry the debris removed from the wellbore out of the well.
- In an embodiment disclosed, inserting the clean-out string into the wellbore includes positioning the downhole tool within the wellbore at a point restricted by the debris.
- In an embodiment disclosed, engaging the downhole tool with the debris restricting the wellbore comprises rotating the downhole tool to engage a projection of the downhole tool with the debris to grind down or break apart the debris within the wellbore.
- In an embodiment disclosed the fluid is a drilling fluid or a well servicing fluid. In an embodiment, the drilling fluid or the well servicing fluid may be water.
- In an embodiment disclosed the well is a hydrocarbon recovery well or a water well.
- In an embodiment disclosed the debris comprises hard scale or well-bottom debris or both.
- Embodiments of the present disclosure will now be described, by way of example only, with reference to the attached Figures.
-
FIG. 1 depicts a plurality of views of a downhole tool in accordance with an embodiment of the present disclosure, showing a plurality of frustoconical-shaped projections on the outer surface of the drill bit. -
FIG. 2 depicts a top plan view of the downhole tool ofFIG. 1 , showing the bit bore defined by the drill bit and a plurality of frustoconical-shaped projections on the outer surface of the drill bit. -
FIG. 3 depicts a side-elevation view of the downhole tool ofFIG. 2 , showing the bit bore defined by the drill bit (in dashed lines), a plurality of frustoconical-shaped projections on the outer surface of the drill bit, with the first end (typically well bottom) of the drill bit defining a leading face and the second end (typically well top) of the drill bit adapted to engage a drive pipe. -
FIG. 4 depicts of a perspective view of the downhole tool ofFIG. 2 , showing the first end of the drill bit defining a leading face comprising a plurality of teeth-like projections adapted to facilitate drilling, in accordance with an embodiment of the present disclosure. -
FIG. 5 depicts a side-elevation view of a downhole tool in accordance with an embodiment of the present disclosure, showing a plurality of wedge-tip projections on the outer surface of the drill bit, with the first end of the drill bit defining a leading face and the second end of the drill bit adapted to engage a drive pipe. -
FIG. 6 depicts a plurality of views of a downhole tool in accordance with an embodiment of the present disclosure, showing a plurality of wedge-tip projections on the outer surface of the drill bit, with a first end of the drill bit defining a leading face and a second end of the drill bit adapted to engage a drive pipe, the leading face having a substantially saw-tooth face. -
FIG. 7 depicts a side-elevation view of the downhole tool ofFIG. 6 , showing a plurality of wedge-tip projections on the outer surface of the drill bit, with the first end of the drill bit defining a leading face having a substantially saw-tooth face and the second end of the drill bit adapted to engage a drive pipe. -
FIG. 8 depicts a perspective view of a downhole tool in “Normal Circulation” in accordance with an embodiment of the present disclosure in use in a wellbore. -
FIG. 9 depicts a perspective view of a downhole tool in “Reverse Circulation” in accordance with an embodiment of the present disclosure in use in a wellbore. - A downhole tool as described herein may be used to break up or grind down and remove scale and debris that has built up within a defined wellbore, including but not limited to cased wellbores, uncased wellbores, and combinations thereof including but not limited to wellbores with barefoot completions, the wellbore being a wellbore of, for example, a hydrocarbon recovery well (e.g. producing one or more of oil, gas and water), a water well, an injection well, or other well. Generally, the downhole tool comprises a drill bit, the drill bit having an outer surface for engaging a wellbore and defining a bit bore, the drill bit having a first end defining a leading face and a second end adapted to engage a drive pipe; and a projection coupled to the outer surface of the drill bit, the projection being adapted to remove debris from a wellbore. The scale and debris are at least partially removed from the wellbore when broken up or ground down by the downhole tool comprising the projection and carried to the surface through the circulation of drilling fluid. In some examples, the projection comprises a plurality of projections. In some examples, the downhole tool is used on a well servicing tubing string that, generally, is top-driven. In other examples, the downhole tool is used with a mud motor, or down-hole motor. In a preferred embodiment, the present disclosure is preferably used with drive that allows the use of reverse circulation whereby returning fluids and cleaned out debris are conveyed to the surface through the internal bore of the bit and clean out string.
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FIGS. 1 to 4 show a downhole tool having adrill bit 100, the drill bit having an outer surface for engaging a wellbore and defining abit bore 2. Thedrill bit 100 has afirst end 4 defining a leading face and asecond end 5 adapted to engage a drive pipe, with the outer surface having a substantially cylinder-shapedsection 7 abutting thesecond end 5, and a substantially frustoconical-shapedsection 6 abutting the substantially cylinder-shapedsection 7 and terminating at thefirst end 4. Thefirst end 4 defines a leading face that comprises a plurality ofpegs 9 adapted to facilitate drilling, thepegs 9 extending longitudinally from the leading face. In some examples, thepegs 9 are absent. In some examples, the substantially cylinder-shapedsection 7 is proximal thesecond end 5. In other examples, the substantially frustoconical-shapedsection 6 is proximal the substantially cylinder-shapedsection 7 and thefirst end 4. In some examples, the substantially cylinder-shapedsection 7 of the outer surface acts to centralizing thedrill bit 100 in the wellbore. In other examples, the substantially cylinder-shapedsection 7 of the outer surface is sized to provide an annular gap within the wellbore. In some examples, the annular gap is from about 10 mm to about 50 mm in size. - The
drill bit 100 has aprojection 3 coupled to the substantially frustoconical-shapedsection 6 of the outer surface, theprojection 3 being adapted to remove (e.g., break up or grind down) debris from a wellbore. Theprojection 3 extends substantially perpendicular from theouter surface 6, and is substantially frustoconical-shaped. In some examples theprojection 3 is a wedge tipped shape, and in others it is cone-shaped. In other cases theprojection 3 is made up of randomly clustered cutting surfaces. Thedrill bit 100 may utilize one or more type/shape ofprojection 3. In some examples, theprojection 3 is composed of tungsten carbide. In some examples, theprojection 3 is integral with the outer surface of thedrill bit 100. In other examples, theprojection 3 is pressed into the outer surface of thedrill bit 100. Theprojection 3 comprises a plurality of projections, each of the projections being circumferentially and longitudinally displaced relative to each other to spiral along the substantially frustoconical-shapedsection 6 of outer surface of thedrill bit 100. In some examples, each of the plurality of projections is circumferentially displaced relative to each other. In other examples, each of the plurality of projections is longitudinally displaced relative to each other. In other examples the projections are clustered randomly. -
FIG. 5 shows a downhole tool having adrill bit 102, thedrill bit 102 having an outer surface for engaging a wellbore and defining a bit bore (not shown). Thedrill bit 102 has afirst end 4A defining a leading face and asecond end 5A adapted to engage a drive pipe, with the outer surface having a substantially cylinder-shapedsection 7A abutting thesecond end 5A, and a substantially frustoconical-shapedsection 6A abutting the substantially cylinder-shapedsection 7A and terminating at thefirst end 4A. In some examples, the substantially cylinder-shapedsection 7A is proximal thesecond end 5A. In other examples, the substantially frustoconical-shapedsection 6A is proximal the substantially cylinder-shapedsection 7A and thefirst end 4A. In some examples, the substantially cylinder-shapedsection 7A of the outer surface acts to centralizing thedrill bit 102 in the wellbore. In other examples, the substantially cylinder-shapedsection 7A of the outer surface is sized to provide an annular gap within the wellbore. In some examples, the annular gap is from about 10 mm to about 50 mm in size. - The
drill bit 102 has aprojection 10 that is substantially shaped as a wedge-tip. Theprojection 10 extends substantially perpendicular from the substantially frustoconical-shapedsection 6A of the outer surface of thedrill bit 102. In some examples, theprojection 10 is composed of tungsten carbide. In some examples, theprojection 10 is integral with the outer surface of thedrill bit 102. In other examples, theprojection 10 is pressed into the outer surface of thedrill bit 102. Theprojection 10 comprises a plurality of projections, each of the projections being circumferentially and longitudinally displaced relative to each other to spiral along the substantially frustoconical-shapedsection 6A of the outer surface of thedrill bit 102. In some examples, each of the plurality of projections is circumferentially displaced relative to each other. In other examples, each of the plurality of projections is longitudinally displaced relative to each other. -
FIGS. 6 and 7 show a downhole tool having adrill bit 104, the drill bit having an outer surface for engaging a wellbore and defining a bit bore 2B. Thedrill bit 104 has afirst end 4B defining a leading face and asecond end 5B adapted to engage a drive pipe, with the outer surface having a substantially cylinder-shapedsection 7B abutting thesecond end 5B, and a substantially frustoconical-shapedsection 6B abutting the substantially cylinder-shapedsection 7B and terminating at thefirst end 4B. Thefirst end 4B defines a leading face that has a substantially saw-tooth face 8 adapted to facilitate drilling. In some examples, the saw-tooth face 8 is absent. Thedrill bit 104 also has hardfacing strips 11 to provide additional strength to thedrill bit 104. In some examples, the hardfacing strips 11 are absent. - In some examples, the substantially cylinder-shaped
section 7B is proximal thesecond end 5B. In other examples, the substantially frustoconical-shapedsection 6B is proximal the substantially cylinder-shapedsection 7B and thefirst end 4B. In some examples, the substantially cylinder-shapedsection 7B of the outer surface acts to centralizing thedrill bit 104 in the wellbore. In other examples, the substantially cylinder-shapedsection 7B of the outer surface is sized to provide an annular gap within the wellbore. In some examples, the annular gap is from about 10 mm to about 50 mm in size. - The
drill bit 104 has aprojection 10B that is substantially shaped as a wedge-tip. Theprojection 10B extends substantially perpendicular from the substantially frustoconical-shapedsection 6B of the outer surface of thedrill bit 104. In some examples, theprojection 10B is composed of tungsten carbide. In some examples, theprojection 10B is integral with the outer surface of thedrill bit 104. In other examples, theprojection 10B is pressed into the outer surface of thedrill bit 104. Theprojection 10B comprises a plurality of projections, each of the projections being circumferentially and longitudinally displaced relative to each other to spiral along the substantially frustoconical-shapedsection 6B of the outer surface of thedrill bit 104. In some examples, each of the plurality of projections is circumferentially displaced relative to each other. In other examples, each of the plurality of projections is longitudinally displaced relative to each other. - Referring to
FIG. 8 ,drill bit 100 is attached to drive 20 and inserted into awellbore 30 until above or atdebris 40. Rotation 45 (e.g. conventionally clockwise looking from above) of thedrill bit 100 viadrive 20, e.g. from a top drive or rotary drive at surface or a mud motor or downhole motor proximate thedrill bit 100, causes thedrill bit 100 to grind down or break up at least a portion and preferably substantially thedebris 40. Circulation offluid 50 sweeps or otherwise conveys theground debris 60 to surface. WhileFIG. 8 illustrates normal circulation (being the fluid 50 conveyed down the pipe bore and up the annulus), as described herein, the invention may also utilize reverse circulation (being the fluid 50 conveyed down the annulus and up the pipe bore), seeFIG. 9 . WhileFIGS. 8 and 9 illustrate thewellbore 30 as being a substantially vertical portion, the invention may also be applied to wells having slanted, horizontal, lateral, angled, dogleg, and/or radiused sections. WhileFIGS. 8 and 9 illustrate thewellbore 30 as having acasing 70, as described herein, the invention may also be applied to uncased wellbores. - In an example, in use, the downhole tool having the
drill bit drill bit drill bit projection drill bit drill bit first end drill bit drill bit first end drill bit like projections 9 ofdrill bit 100 inFIGS. 1 to 4 , and substantially saw-tooth face 8 ofdrill bit 104 inFIGS. 6 and 7 ). - Referring to
FIG. 9 , the fluids are reverse circulated down the annulus and then carry the scale and debris out of the wellbore via the internal bore of the drive pipe. In an example, in use, the downhole tool having thedrill bit drill bit drill bit projection drill bit drill bit first end drill bit drill bit - A combination or sequence of circulation, reverse circulation, no circulation may be used. Similarly, a combination or sequence of rotating or non-rotating may be used.
- In another example, in use, the downhole tool having the
drill bit - The clean-out string is generally set up by a service rig attending the wellsite. For example, if in use, a production tubing string is first removed from the affected well and set aside in a suitable manner. The downhole tool having the
drill bit drill bit - The clean-out string is then inserted into, for example, the casing of the affected well and lowered to the point of debris obstruction. Standard industry well servicing practices may be followed during the insertion of the clean-out string. Once the downhole tool having the
drill bit drill bit - As would be understood by a person skilled in the art, the well servicing fluid pump rates need to be sufficient to create a fluid velocity that will carry debris up through the center bore of the clean-out string. At the same time that the well is being reverse circulated, the clean-out string is rotated to create a grinding action with the downhole tool having the
drill bit - As the clean-out string is rotated, the
projection drill bit - Upon completion of the clean out, the clean-out string is pulled out of the well bore, and the downhole tool having the
drill bit - In examples, the downhole tool having the
drill bit drill bit drill bit drill bit - Generally, the downhole tool may be used with tubulars, including but not limited to pipe, drill pipe, tubing, coiled tubing, jointed tubing. Generally, the downhole tool may be rotated from surface, for example by a top drive or rotary table or may be rotated proximate the downhole tool, for example by a mud motor or downhole-motor. In a preferred embodiment, the present disclosure is preferably used with drive that allows the use of reverse circulation whereby returning fluids and cleaned out debris are conveyed to the surface through the internal bore of the bit and clean out string. The supply of well servicing fluid, and circulation or reverse circulation, as the case may be, as well as the removal of debris from the well servicing fluid, is provided from/at surface.
- Apart from hard scale, well bottom debris is loose debris that may originate from one or more sources within or associated with the wellbore. It may be hard debris that originates from within the completed formation or from formation fluids. Occasionally, hard scale or well bottom debris could result from mechanical debris from wellbore components. Hard scale or well bottom debris could also result from scale, consolidated or unconsolidated sand, iron sulfides, wax or a combination of one or more of the above. When the material is hard, the disclosed tool and methods break it up.
- Embodiment 1. A downhole tool, comprising: a drill bit, the drill bit having an outer surface for engaging a wellbore and defining a bit bore, the drill bit having a first end defining a leading face and a second end adapted to engage a drive pipe; and a projection coupled to the outer surface of the drill bit, the projection being adapted to remove debris from the wellbore.
-
Embodiment 2. The tool of embodiment 1, wherein the projection comprises a plurality of projections. -
Embodiment 3. The tool ofembodiment 2, wherein each of the plurality of projections is circumferentially displaced relative to each other. -
Embodiment 4. The tool ofembodiment -
Embodiment 5. The tool of any one ofembodiments 2 to 4, wherein each of the plurality of projections are circumferentially and longitudinally displaced relative to each other and spiral along the outer surface of the drill bit. -
Embodiment 6. The tool of any one of embodiments 1 to 5, wherein the outer surface of the drill bit has a substantially frustoconical-shaped section proximal the first end, and a substantially cylinder-shaped section. -
Embodiment 7. The tool of any one of embodiments 1 to 6, wherein the outer surface of the drill bit has a substantially cylinder-shaped section abutting the second end, and a substantially frustoconical-shaped section abutting the substantially cylinder-shaped section and terminating at the first end. -
Embodiment 8. The tool of any one of embodiments 1 to 7, wherein the projection extends substantially perpendicular from the outer surface of the drill bit. -
Embodiment 9. The tool ofembodiment 8, wherein the projection extends from the outer surface between about 1 mm and about 10 mm. -
Embodiment 10. The tool of any one ofembodiments 7 to 9 when dependent onembodiment 2, wherein at least one of the plurality of projections extends beyond an outer diameter of the cylinder-shaped section, by an undercut height. -
Embodiment 11. The tool ofembodiment 10, wherein the undercut height is a maximum of 10 mm. - Embodiment 12. The tool of
embodiment 11, wherein the undercut height is between about 2.5 mm and about 10 mm. - Embodiment 13. The tool of any one of embodiments 1 to 12, wherein the projection is substantially frustoconical-shaped.
- Embodiment 14. The tool of any one of embodiments 1 to 12, wherein the projection is substantially shaped as a cone tip, a wedge-shape, a wedge-tip, a random clustering or a combination thereof.
- Embodiment 15. The tool of any one of embodiments 1 to 14, wherein the projection is composed of one or more of substantially tungsten carbide, hardened metal, carbon steel or stainless steel.
- Embodiment 16. The tool of
embodiment embodiments 8 to 15 when dependent onembodiment - Embodiment 17. The tool of any one of embodiments 1 to 16, wherein the projection is integral with the outer surface of the drill bit.
- Embodiment 18. The tool of any one of embodiments 1 to 16, wherein the projection is pressed into the outer surface of the drill bit.
- Embodiment 19. The tool of any one of embodiments 1 to 18, wherein the leading face comprises a plurality of pegs extending longitudinally from the leading face, adapted to facilitate drilling.
-
Embodiment 20. The tool of any one of embodiments 1 to 18, wherein the leading face is substantially a saw-tooth face. - Embodiment 21. The tool of any one of embodiments 1 to 20, wherein the leading face defines an elliptical plane having a pitch greater than 0 degrees.
- Embodiment 22. The tool of embodiment 21, wherein the pitch is between about 15 degrees and about 30 degrees.
- Embodiment 23. The tool of embodiment 22, wherein the pitch is about 24 degrees.
- Embodiment 24. The tool of any one of embodiment 1 to 20, wherein at least a portion of the leading face is angled at a face angle.
- Embodiment 25. The tool of embodiment 24, wherein the face angle is greater than 0 degrees.
- Embodiment 26. The tool of embodiment 25, wherein the face angle is between about 15 degrees and about 30 degrees.
- Embodiment 27. The tool of embodiment 26, wherein the face angle is about 24 degrees.
- Embodiment 28. The tool of any one of
embodiments embodiment 6, wherein the projection comprises a tungsten carbide coating providing a plurality of tungsten carbide clusters (clusterite) spaced about the frustoconical-shaped section. - Embodiment 29. The tool of any one of
embodiments embodiment 6, wherein the frustoconical-shaped section comprises a taper. -
Embodiment 30. The tool of embodiment 29, wherein the taper is between about 2 degrees and about 8 degrees. - Embodiment 31. The tool of
embodiment 30, wherein the taper is about 5 degrees. - Embodiment 32. Use of the tool of any one of embodiments 1 to 31 with an oil and gas well service rig or an oil and gas drilling rig.
- Embodiment 33. Use of the tool of any one of embodiments 1 to 31 with a tubular.
- Embodiment 34. Use of the tool of any one of embodiments 1 to 31 to remove debris from a wellbore.
- Embodiment 35. The use of embodiment 34, wherein the debris comprises hard scale.
- Embodiment 36. A method for servicing a well having a defined wellbore restricted by debris, comprising: inserting a clean-out string into the wellbore of the well, the clean-out string having a downhole tool of any one of embodiments 1 to 31 coupled thereto; and rotating the clean-out string to engage the downhole tool with the debris restricting the wellbore to remove the debris from the wellbore.
- Embodiment 37. The method of embodiment 36, further comprising circulating or reverse circulating a fluid through the well to carry the debris removed from the wellbore out of the well.
- Embodiment 38. The method of embodiment 36 or 37, wherein inserting the clean-out string into the wellbore comprises positioning the downhole tool within the wellbore at a point restricted by the debris.
- Embodiment 39. The method of any one of embodiments 36 to 38, wherein engaging the downhole tool with the debris restricting the wellbore comprises rotating the downhole tool to engage a projection of the downhole tool with the debris to grind down or break apart the debris within the wellbore.
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Embodiment 40. The method of any one of embodiment 36 to 39, wherein the fluid is a drilling fluid or a well-servicing fluid. - Embodiment 41. The method of any one of embodiments 36 to 40, wherein the well is a hydrocarbon recovery well or a water well.
- Embodiment 42. The method of any one of embodiments 36 to 41, wherein the debris comprises hard scale or well-bottom debris or both.
- The embodiments described herein are intended to be examples only. Alterations, modifications and variations can be effected to the particular embodiments by those of skill in the art. The scope of the claims should not be limited by the particular embodiments set forth herein, but should be construed in a manner consistent with the specification as a whole.
- The invention being thus described, it will be obvious that the same may be varied in many ways. Such variations are not to be regarded as a departure from the spirit and scope of the invention, and all such modification as would be obvious to one skilled in the art are intended to be included within the scope of the following claims.
Claims (45)
1. A downhole tool, comprising:
a drill bit,
the drill bit having an outer surface for engaging a wellbore and defining a bit bore,
the drill bit having a first end defining a leading face and a second end adapted to engage a drive pipe; and
a projection coupled to the outer surface of the drill bit, the projection being adapted to remove debris from the wellbore.
2. The tool of claim 1 , wherein the projection comprises a plurality of projections.
3. The tool of claim 2 , wherein each of the plurality of projections is circumferentially displaced relative to each other.
4. The tool of claim 3 , wherein each of the plurality of projections is longitudinally displaced relative to each other.
5. The tool of claim 4 , wherein each of the plurality of projections are circumferentially and longitudinally displaced relative to each other and spiral along the outer surface of the drill bit.
6. The tool of claim 5 , wherein the outer surface of the drill bit has a substantially frustoconical-shaped section proximal the first end, and a substantially cylinder-shaped section.
7. The tool of claim 6 , wherein the outer surface of the drill bit has a substantially cylinder-shaped section abutting the second end, and a substantially frustoconical-shaped section abutting the substantially cylinder-shaped section and terminating at the first end.
8. The tool of claim 7 , wherein the projection extends substantially perpendicular from the outer surface of the drill bit.
9. The tool of claim 8 , wherein the projection extends from the outer surface between about 1 mm and about 10 mm.
10. The tool of claim 9 , wherein at least one of the plurality of projections extends beyond an outer diameter of the cylinder-shaped section, by an undercut height.
11. The tool of claim 10 , wherein the undercut height is a maximum of 10 mm.
12. The tool of claim 11 , wherein the undercut height is between about 2.5 mm and about 10 mm.
13. The tool of claim 1 , wherein the projection is substantially frustoconical-shaped.
14. The tool of claim 1 , wherein the projection is substantially shaped as a cone tip, a wedge-shape, a wedge-tip, a random clustering or a combination thereof.
15. The tool of claim 1 , wherein the projection is composed of one or more of substantially tungsten carbide, hardened metal, carbon steel or stainless steel.
16. The tool of claim 6 , wherein the projection is coupled to the substantially frustoconical-shaped section of the outer surface of the drill bit.
17. The tool of claim 7 , wherein the projection is coupled to the substantially frustoconical-shaped section of the outer surface of the drill bit.
18. The tool of claim 1 , wherein the projection is integral with the outer surface of the drill bit.
19. The tool of claim 1 , wherein the projection is pressed into the outer surface of the drill bit.
20. The tool of claim 1 , wherein the leading face comprises a plurality of pegs extending longitudinally from the leading face, adapted to facilitate drilling.
21. The tool of claim 1 , wherein the leading face is substantially a saw-tooth face.
22. The tool of claim 20 , wherein the leading face defines an elliptical plane having a pitch greater than 0 degrees.
23. The tool of claim 21 , wherein the leading face defines an elliptical plane having a pitch greater than 0 degrees.
24. The tool of claim 22 , wherein the pitch is between about 15 degrees and about 30 degrees.
25. The tool of claim 24 , wherein the pitch is about 24 degrees.
26. The tool of claim 20 , wherein at least a portion of the leading face is angled at a face angle.
27. The tool of claim 21 , wherein at least a portion of the leading face is angled at a face angle.
28. The tool of claim 26 , wherein the face angle is greater than 0 degrees.
29. The tool of claim 28 , wherein the face angle is between about 15 degrees and about 30 degrees.
30. The tool of claim 29 , wherein the face angle is about 24 degrees.
31. The tool of claim 6 , wherein the projection comprises a tungsten carbide coating providing a plurality of tungsten carbide clusters (clusterite) spaced about the frustoconical-shaped section.
32. The tool of claim 6 , wherein the frustoconical-shaped section comprises a taper.
33. The tool of claim 32 , wherein the taper is between about 2 degrees and about 8 degrees.
34. The tool of claim 33 , wherein the taper is about 5 degrees.
35. In a downhole tool, comprising:
a drill bit,
the drill bit having an outer surface for engaging a wellbore and defining a bit bore,
the drill bit having a first end defining a leading face and a second end adapted to engage a drive pipe; and
a projection coupled to the outer surface of the drill bit, the projection being adapted to remove debris from the wellbore, the use of the tool with an oil and gas well service rig or an oil and gas drilling rig.
36. In a downhole tool, comprising:
a drill bit,
the drill bit having an outer surface for engaging a wellbore and defining a bit bore,
the drill bit having a first end defining a leading face and a second end adapted to engage a drive pipe; and
a projection coupled to the outer surface of the drill bit, the projection being adapted to remove debris from the wellbore, the use of the tool with a tubular.
37. In a downhole tool, comprising:
a drill bit,
the drill bit having an outer surface for engaging a wellbore and defining a bit bore,
the drill bit having a first end defining a leading face and a second end adapted to engage a drive pipe; and
a projection coupled to the outer surface of the drill bit, the projection being adapted to remove debris from the wellbore, the use of the tool to remove debris from a wellbore.
38. The use of claim 37 , wherein the debris comprises hard scale.
39. A method for servicing a well having a defined wellbore restricted by debris, comprising:
inserting a clean-out string into the wellbore of the well, the clean-out string having a downhole tool coupled thereto the downhole tool, comprising:
a drill bit,
the drill bit having an outer surface for engaging a wellbore and defining a bit bore,
the drill bit having a first end defining a leading face and a second end adapted to engage a drive pipe;
a projection coupled to the outer surface of the drill bit, the projection being adapted to remove debris from the wellbore, the use of the tool; and
rotating the clean-out string to engage the downhole tool with the debris restricting the wellbore to remove the debris from the wellbore.
40. The method of claim 39 , further comprising circulating or reverse circulating a fluid through the well to carry the debris removed from the wellbore out of the well.
41. The method of claim 39 , wherein inserting the clean-out string into the wellbore comprises positioning the downhole tool within the wellbore at a point restricted by the debris.
42. The method of claim 39 , wherein engaging the downhole tool with the debris restricting the wellbore comprises rotating the downhole tool to engage a projection of the downhole tool with the debris to grind down or break apart the debris within the wellbore.
43. The method of claim 40 , wherein the fluid is a drilling fluid or a well-servicing fluid.
44. The method of claim 39 , wherein the well is a hydrocarbon recovery well or a water well.
45. The method of claim 39 , wherein the debris comprises hard scale or well-bottom debris or both.
Priority Applications (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US16/703,255 US20210172289A1 (en) | 2019-12-04 | 2019-12-04 | Downhole tool and uses thereof |
CA3063883A CA3063883A1 (en) | 2019-12-04 | 2019-12-05 | A downhole tool and uses thereof |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
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US16/703,255 US20210172289A1 (en) | 2019-12-04 | 2019-12-04 | Downhole tool and uses thereof |
Publications (1)
Publication Number | Publication Date |
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US20210172289A1 true US20210172289A1 (en) | 2021-06-10 |
Family
ID=76206833
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
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US16/703,255 Abandoned US20210172289A1 (en) | 2019-12-04 | 2019-12-04 | Downhole tool and uses thereof |
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US (1) | US20210172289A1 (en) |
CA (1) | CA3063883A1 (en) |
Citations (6)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US1627909A (en) * | 1926-04-26 | 1927-05-10 | Warren J Kirby | Rock-drill bit |
US3885638A (en) * | 1973-10-10 | 1975-05-27 | Sam C Skidmore | Combination rotary and percussion drill bit |
US4823892A (en) * | 1984-07-19 | 1989-04-25 | Nl Petroleum Products Limited | Rotary drill bits |
US6193001B1 (en) * | 1998-03-25 | 2001-02-27 | Smith International, Inc. | Method for forming a non-uniform interface adjacent ultra hard material |
US20160017667A1 (en) * | 2009-07-02 | 2016-01-21 | Baker Hughes Incorporated | Earth-boring tools, drill bits, and diamond-impregnated rotary drill bits including crushed polycrystalline diamond material |
US20170234112A1 (en) * | 2015-09-29 | 2017-08-17 | Halliburton Energy Services, Inc. | Wellbore Reverse Circulation with Flow-Activated Motor |
-
2019
- 2019-12-04 US US16/703,255 patent/US20210172289A1/en not_active Abandoned
- 2019-12-05 CA CA3063883A patent/CA3063883A1/en not_active Abandoned
Patent Citations (6)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US1627909A (en) * | 1926-04-26 | 1927-05-10 | Warren J Kirby | Rock-drill bit |
US3885638A (en) * | 1973-10-10 | 1975-05-27 | Sam C Skidmore | Combination rotary and percussion drill bit |
US4823892A (en) * | 1984-07-19 | 1989-04-25 | Nl Petroleum Products Limited | Rotary drill bits |
US6193001B1 (en) * | 1998-03-25 | 2001-02-27 | Smith International, Inc. | Method for forming a non-uniform interface adjacent ultra hard material |
US20160017667A1 (en) * | 2009-07-02 | 2016-01-21 | Baker Hughes Incorporated | Earth-boring tools, drill bits, and diamond-impregnated rotary drill bits including crushed polycrystalline diamond material |
US20170234112A1 (en) * | 2015-09-29 | 2017-08-17 | Halliburton Energy Services, Inc. | Wellbore Reverse Circulation with Flow-Activated Motor |
Also Published As
Publication number | Publication date |
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CA3063883A1 (en) | 2021-06-04 |
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