Abstract
The Smart Reamer Tool, Apparatus or Method is used to underream an oil or natural gas well and deliver a desired wellbore diameter without the need to unnecessarily stop drilling or trip out of the hole.
Claims
1. A bottom hole assembly for use in a wellbore comprising a fixed diameter bit wherein a plurality of cutters extend from a central location to the outer ends of the bit to form a first diameter; and an expandable reamer wherein a further plurality of cutters are placed on an extendable cutter block in at least two substantially parallel substantially helical rows, each substantially helical row having at least tour cutters, wherein at least three of the cutters on one of the substantially helical rows align with three of the cutters on the other of the substantially helical rows along the longitudinal axis to form at least three longitudinal rows of cutters extending along the longitudinal axis of the expandable reamer.
2. The bottom hole assembly of claim 1 further comprising a directional control system.
3. The bottom hole assembly of claim 2 wherein the directional control system is a rotary steerable.
4. The bottom hole assembly of claim 1 wherein cutter placement is optimised to reduce vibration around the bottom hole assembly.
5. The bottom hole assembly of claim 1 further comprising position sensing means.
6. The bottom hole assembly of claim 1 further comprising borehole diameter sensing means.
7. The bottom hole assembly of claim 1 wherein the cutters are hard faced.
8. A method of engaging at least 7 cutters with a wellbore in at least 7 different radial locations by placing cutter elements on one or more extendable cutting blocks in arcuate and longitudinal locations wherein at least eight cutter elements are set in a substantially helical pattern on the extendable cutter block of an expandable reamer and wherein said pattern is repeated in at least two substantially parallel substantially helical rows, wherein each substantially helical row has at least four cutter elements, wherein at least three of the cutter elements on one of the substantially helical rows align with three of the cutter elements on the other of the substantially helical rows along the longitudinal axis to form at least three longitudinal rows of cutters extending along the longitudinal axis of the expandable reamer.
9. The method of claim 8 further comprising a flowpath directly to a reamer cutter face wherein the at least one flowpath is located on the face or middle of a cutter block and radiates flow directly across at least one cutter element.
10. The method of claim 8 further comprising a flowpath directly to a reamer cutter face wherein the at least one flowpath is located on the side of a cutter block and radiates flow directly across at least one cutter element.
11. The method of claim 9 wherein the flow path opens flow between two rows of cutters.
12. The method of claim 8 comprising a rotary steerable.
13. The method of claim 8 comprising a position sensing means.
14. The method of claim 8 comprising a wellbore caliper.
15. An array of cutter elements for drilling an earthen wellbore, wherein at least eight cutter elements are set in a substantially helical pattern on an extendable cutter block of an expandable reamer and wherein said pattern is repeated in at least two substantially parallel substantially helical rows, wherein each substantially helical row has at least four cutter elements, wherein at least three of the cutter elements on one of the substantially helical rows align with three of the cutter elements on the other of the substantially helical rows along the longitudinal axis to form at least three longitudinal rows of cutters extending along the longitudinal axis of the expandable reamer.
16. The array of cutter elements as claimed in claim 15 wherein said cutter elements are set in an expandable cutter block, and preferably set in a plurality of expandable cutter blocks distributed uniformly around the body of a reamer wherein cutter elements form a helix oriented in the direction of reaming.
17. An array of cutter elements as claimed in claim 16 located substantially in rows extending diagonally across the face of the cutter block and helically in respect of the wellbore.
18. An array of cutters as claimed in claim 17 wherein the helix is oriented in the direction of upward reaming.
19. An array of cutters as claimed in claim 16 wherein the helix forms a continuation of outer ends of drill bit teeth.
20. An array of cutters as claimed in claim 16 wherein the helix engages the wellbore in at least 7 different circumferential points.
Description
BRIEF DESCRIPTION OF THE DRAWINGS
(1) Embodiments of the invention are illustrated by way of non-limiting examples in the accompanying drawings, in which:
(2) FIG. 1 is a general diagrammatic view of an oil or gas well showing surface structures and the underground wellbore, with a tool in accordance with the invention as part of a bottomhole assembly;
(3) FIG. 2A is a side elevation, part cut away to show the expansion elements in a deactivated state, of the tool of FIG. 1;
(4) FIG. 2B is a side elevation corresponding to FIG. 2a showing the expansion elements in an activated state;
(5) FIG. 3 is a diagrammatic cross section through an underreaming and caliper tool in accordance with the invention similar to that shown in the previous Figures, but having an additional stabiliser section at the trailing uphole end;
(6) FIG. 4 is an enlargement of part of FIG. 2 showing an expansion block;
(7) FIG. 5 is a view corresponding to FIG. 4 showing an alternative construction;
(8) FIG. 6 is a diagram showing cutting elements of the tool positioned in a borehole, the tool being in a deactivated condition;
(9) FIG. 7 is a diagram corresponding to FIG. 6 but showing the same elements of the tool when the tool is in an activated condition;
(10) FIG. 8 is a diagram corresponding to FIG. 7 showing the disposition of cutting elements in a notional corresponding prior art approach;
(11) FIG. 9A is a top view and FIG. 9B is a front view of the outer face of a traditional cutter block for underreaming without nozzles and using a vertical arrangement of cutter elements, of the kind illustrated in FIG. 8;
(12) FIG. 10 is a front view corresponding to FIG. 9B showing the placement of a traditional cutting fluid delivery nozzle;
(13) FIGS. 11A and 11B are views of a cutter block in accordance with the invention, corresponding to the views in FIGS. 9A and 9B respectively, showing the tool's cutter block outer face using a helical pattern optimized for underreaming while drilling;
(14) FIG. 12 corresponds to FIG. 10 and shows cutting fluid delivery nozzles located in the cutter block in accordance with the invention;
DETAILED DESCRIPTION OF THE INVENTION
(15) As shown in FIG. 1, an exemplary exploration or production rig comprises a surface structure 10 at the wellhead, a wellbore 20, and a drill string 30 in the wellbore with a bottom-hole assembly 40 at its lower end. The bottom-hole assembly includes an underreamer 50 in accordance with the invention, and a drill-bit (not shown).
(16) The underreamer 50 is illustrated in FIGS. 2A and 2B, and comprises a tubular steel body 52 provided with a drilling collar 54 at its downhole end and a mud-pulser 56 at its other end, which is adapted to be engaged by a further drill collar (not shown) to connect it other elements of the bottom-hole assembly 40, and then to the drill string 30.
(17) The tool body also carries an acoustic caliper 58 and an expansion element assembly 60 between the acoustic caliper and the drill collar 54. The expansion element assembly 60 comprises a number of expansion blocks 62 disposed symmetrically, radially around the tool body 52, and in the deactivated condition shown in FIG. 2A the blocks are withdrawn into the tool body, but in the activated condition shown in FIG. 2B the blocks are extended beyond the tool body against the wellbore 20.
(18) FIG. 3 illustrates diagrammatically the aforementioned elements of the tool 50, together with a stabiliser section 61.
(19) FIG. 3 also shows an alternative location for a caliper, in housing 76 connected to wiring in keyway 74 and further wiring 78 to alternative processor location 68 and motor 80 for activation of expansion block 62, as will be further described in relation to FIGS. 4 and 5. FIG. 3 also shows a central axial through passage 90 for the flow of drilling fluid through the whole bottom-hole assembly 40.
(20) A mechanical caliper 122 may be located within the cutter block among the most radially extended cutter elements 92, or on the block surface in the case where the expansion block is not an underreamer with cutting teeth or inserts, but a device for expanding a tubular by deformation.
(21) Housing 76 may also be used for other types of sensor, especially a wellbore vibration sensor to detect a stick-slip condition.
(22) The tool body 52 is a cylindrical high grade steel housing adapted to form part of a bottom-hole assembly (BHA) 40. FIG. 3 shows an internal connection 82 joining two parts of tool body 52. At the leading downhole end of the tool is a section housing the cutter blocks 62. Connection 82 joins this to a central section housing measurement and control functions.
(23) A further section 61 at the uphole end, joined by connection 65, houses stabiliser blocks 63 which are constructed and housed substantially identically to the underreamer components generally designated 60, except that in place of cutter elements on cutter blocks there is at least one surface which is hard faced or coated with a hard abrasion-resistant material. A similar construction can be used to expand a deformable bore, such as a steel tubular. The means for attaching the tool body to a drill string or coiled tubing comprises a screw thread (not shown) provided on the tool body which is engageable with a drill collar (not shown).
(24) In this alternative configuration the tool is configured, in addition to underreaming capacity, with the underreaming tool body incorporating hard facing cutter blocks to act as a stabiliser. The hard facing acts to prevent cutter abrasion while reaming or stabilising the underreamed hole. This eliminates some of the problems associated with loss of directional control due to the undergauge stabiliser above the underreamer.
(25) The stabiliser may be directly or indirectly connected to the underreamer and hard-wired accordingly so as to ensure the mud-pulser may transmit data to surface.
(26) The tool normally comprises a plurality of such cutter blocks 62, arranged symmetrically around the tool. Two cutter blocks are on opposite sides of the tool, three blocks are separated by 120 degrees, four by ninety degrees, and six by sixty degrees. In operation, the underreaming tool 50 is typically rotated on the drill string as well as being moved axially along the wellbore.
(27) FIGS. 4 and 5 show side elevations of cutter blocks (62) with cutter elements or inserts generally designated as 92.
(28) FIG. 4 shows cutter block 62 with internal duct 110 leading to an opening (112) such as a nozzle among cutter elements 92. The nozzle can be located below cutters or recessed as seen by 112 in FIG. 4.
(29) FIG. 5 shows caliper 122 among cutter elements 92.
(30) FIGS. 4 and 5 side views of cutter blocks 62 further correspond to the top view FIG. 11A and frontal view 11B which describe in more detail below cutter patterns, nozzles and caliper location on cutter blocks 62.
(31) FIG. 6 illustrates diagrammatically the relationship of the cutter blocks 62 and their cutter elements (inserts 92) with the wellbore 20, before underreaming, and the layout of the teeth on the drill bit.
(32) FIG. 6 superimposes ten curved rows of drill bit teeth 44, as seen from below the BHA looking back up the wellbore, over the cutter block locations. A central drilling fluid outlet 46 indicates where drilling fluid is delivered to the drill bit, having passed through passage 90 in the tool body 52.
(33) Whereas FIG. 6 illustrates the tool in its deactivated condition, its activated condition with cutter blocks 62 extended and underreaming wellbore 20 is illustrated in FIG. 7. Arrows 124 indicate the sense in which the whole BHA 40, including the curved rows of drill bit teeth 44 and cutter blocks 62, rotate. As the drill deepens the wellbore, so the tool advances towards the viewer, as represented in FIGS. 6 and 7.
(34) FIG. 8 illustrates a similar operation to that shown in FIG. 7, but with a traditional arrangement of cutting elements (inserts 126) on the cutter blocks. The significance of this will be explained in relation to FIGS. 9A, 9B and 10.
(35) FIG. 9A is a downhole, or equally uphole, profile of a cutter block 62 with a traditional arrangement of cutter elements 126, in two parallel straight lines extending parallel to the bore axis (FIG. 9B). When there are three cutter blocks 62, as in FIG. 8, the underreaming takes place along six parallel lines down the wellbore 20 at any instant.
(36) FIG. 10 shows the cutter block face of FIG. 9B together with the traditionally placed drilling fluid nozzle 116; and lines 128 radiating from nozzle 116 indicate the distribution of drilling fluid emerging from the nozzle to lubricate and wash the cutter elements 126.
(37) FIGS. 11A and 11B illustrate the improved placement of cutter inserts 92 over the face of each cutter block 62, in accordance with a specific aspect of this invention, and the location of drilling fluid nozzles 112 over the face of the cutter block in accordance with a further specific aspect of this invention. FIGS. 11A and 11B shows the nozzles 112 beside, between, below and adjacent to cutters 92.
(38) FIGS. 6 and 7 respectively show retracted and extended cutter elements (92) placed at different radial angles from a central axial passage (46).
(39) FIG. 11A as viewed from right to left, shows the location of three cutter elements (three lines to circles marked 92) with different radial angles and circumferential points shown as positions (R1, R2 and R3) on the cutter block 62 relative to the central axial passage (46 of FIGS. 6 and 7).
(40) FIG. 11A viewed further from right to left shows three central cutters each placed at differing radial angles (R4, R5 and R6) to the central axis (46) shown in FIG. 7.
(41) FIG. 11B shows rows of cutters 92 across cutter block 62 distributed in circumferential arcs or radial positions shown in FIG. 11A. Each of the three radially central positions of FIG. 11A (R6, R5 and R4) align with at least one cutter element (any of L3, L2 and L1 or 6,5 and 4) which is located at different longitudinal positions as shown in FIG. 11B. FIG. 11B shows two cutter elements located in different longitudinal positions, element (4) and element (L1). FIG. 11B shows cutter elements placed in two longitudinally distant positions yet having the same radial position relative to a central axis (L1 and 4, L2 and 5, L3 and 6). Cutters 92 may be positioned at different or unequal radial positions (R10, R3, R9, R1, R2) or may form circumferential arcs of differing or unequal lengths (L7 and 3, L6 and 1 or 2).
(42) In accordance with the aspect that concerns cutter element placement, it can be seen that these are located in rows extending diagonally across the face of the cutter block, and helically in respect of the wellbore. The helix is oriented in a sense which, as can be seen from consideration of FIGS. 7 and 11 together, corresponds to the path of a screw advancing down the wellbore, although by no means at a corresponding screw pitch and due to the cutter elements may be used to underream upward.
(43) The helix is also in alignment and considered synchronised with the extended outer ends of the rows of teeth 44 on the drill bit, if notionally wrapped in continuation of that alignment around the outside of the BHA 40 extending back as far as the tool body 52.
(44) This provides the advantage that, as can be seen when viewed along the wellbore, the cutter inserts 92 engage the wellbore over a much better circumferentially distributed arc than the six parallel lines of the traditional arrangements, with consequent benefits to equalization of forces around the tool and therefore around the BHA, of which the tool is a part.
(45) In the aspect of cutters contacting the wellbore, FIGS. 6 and 7 show 7 or more points contacting the wellbore, the three cutter blocks (62) show each cutter element (92) is placed at different radial positions (R1-R10) from a central axis or bore (46 which is connected to central axial through passage 90 in the tool).
(46) As will be detailed below FIGS. 11A and 11B show 3 or more points where cutter elements (92) contact the wellbore considering a single expandable block (62).
(47) In the aspect of cutter patterns extending across the face of a cutter block contacting the wellbore with different circumferential arcs or radial positions but the same longitudinal positions, FIG. 11B shows a first cutter (L7) placed in a first radial position (R10 of FIG. 11A) and a second cutter (3) placed in a second radial position (R3 of FIG. 11A) but with the same longitudinal position along the length of the cutter block face; FIG. 11B shows a second cutter (L6) placed at a third radial position (R9 of FIG. 11A) and a fourth cutter (1) placed at a fourth radial position (R1 of FIG. 11A) that is unequally radially spaced with respect to cutters (L7, 3 or L6). FIG. 11B shows that L6 and 1 are placed at the same longitudinal position along the length of the block face. It can be appreciated from FIG. 11B that the radial positions of L7 and 3 form a circumferential arc length that is different and unequal to the circumferential arc length between L6 and 1. FIG. 11B shows cutters with unique radial and longitudinal positions (2, L5 and L4).
(48) In the aspect of cutter patterns extending across the face of a cutter block contacting the wellbore with different longitudinal positions but the same circumferential or radial positions, FIG. 11B shows two cutters (6 and L3) contacting the wellbore at two points having a first circumferential or radial position (6 and L3 correspond to radial position R6 in FIG. 11A). FIG. 11B shows a line drawn between 6 and L3 showing their different longitudinal positions.
(49) FIG. 11B shows a further third and fourth cutter (5 and L2) contacting the wellbore at a further third and fourth point having a second radial position (R5 in FIG. 11A). The line drawn between 5 and L2 shows a different longitudinal position to the first two cutters.
(50) FIG. 11B shows a fifth cutter (either of 4 or L1) contacting the wellbore at a fifth point and placed in a third radial position (R4 in FIG. 11A). The line drawn between 4 and L1 shows either of 4 and L1 are in different longitudinal positions in relation to any the first four cutters (L3, 6, 5 and L2). Each of the radial positions of the pairs of cutters (L1 and 4, L2 and 5, L3 and 6) have different circumferential or radial positions (R4, R5 and R6) respectively.
(51) Further FIG. 11B shows cutters with unique radial and longitudinal positions (2, L5 and L4).
(52) In the aspect of cutter patterns extending across the face of a cutter block with the same radial position but different longitudinal positions, FIG. 11B shows a first pair of cutters (6 and L3) placed in a first radial position (R6 in FIG. 11A) and separated by a longitudinal distance shown by the line between 6 and L3; a second pair of cutters (5 and L2) placed at second radial position (R5 in FIG. 11A) longitudinally offset to the first pair of cutters and a third pair of cutters (4 and L1) placed in a third radial position (R4 in FIG. 11A) longitudinally offset in relation to the first or second pair of cutters (L3 and 6 or 5 and L2).
(53) In a further aspect of cutter patterns extending across the face of a cutter block with a pair of cutters having the same longitudinal position but having different or unequal radial positions, FIG. 11B shows a first row or pair of cutters (L7 and 3) placed at the same longitudinal position and separated by a radial distance (shown as R10 and R3 in FIG. 11A); a second pair of cutters (L6 and 1) placed at different radial positions (shown as R9 and R1 in FIG. 11A) and longitudinally offset relative to the first pair of cutters; and wherein at least one pair of cutters are unequally spaced (FIG. 11A shows either of R10 and R3 or R9 and R1 as unequally spaced) from a central axis or bore (shown as 46 in FIG. 7).
(54) In a related aspect, FIG. 11B shows a first row or pair of cutters (L7 and 3) placed at the same longitudinal position but having different or unequal circumferential arc lengths (the radial distance between R10 and R3 in FIG. 11A defines a circumferential arc) and a second pair of cutters (L6 and 1) placed at different longitudinal positions wherein at least one cutter is spaced at an unequal circumferential arc length (R9 and R1 in FIG. 11A define a different or unequal arc length) relative to a central axis or bore (46).
(55) In a further aspect FIG. 11B shows 3 rows or 3 pairs of radially offset cutters (6 and L3, 5 and L2, 4 and L1) with one or more cutters (L5, L4 or 2) placed in unique radial and longitudinal positions.
(56) In yet a further related aspect FIG. 11B shows swept cutters (L1-L7, 1-6) corresponding to a screw advancing down the wellbore but not a screw pitch. Further cutters (L1-L7 or 1-6) may not be symmetric as viewed along the length and breadth of the cutter block
(57) FIG. 11B also shows the placement of the optional mechanical or acoustic caliper 122 on a flat part of the cutter block face between the helical rows of cutter elements 92.
(58) FIGS. 11B and 12 show the nozzle 112 distribution over the cutter block face. A plurality of nozzles may be provided, and radiating lines 128 again show the drilling fluid distribution, which is now more accurately, usefully and uniformly achieved than in the traditional arrangement of FIG. 10.
(59) Those skilled in the art will appreciate that the examples of the invention given by the specific illustrated and described embodiments show a novel underreaming tool and system and method for underreaming, with numerous variations being possible. These embodiments are not intended to be limiting with respect to the scope of the invention. Substitutions, alterations and modifications not limited to the variations suggested herein may be made to the disclosed embodiments while remaining within the ambit of the invention.
