CA2191076A1 - Lateral drilling method - Google Patents
Lateral drilling methodInfo
- Publication number
- CA2191076A1 CA2191076A1 CA002191076A CA2191076A CA2191076A1 CA 2191076 A1 CA2191076 A1 CA 2191076A1 CA 002191076 A CA002191076 A CA 002191076A CA 2191076 A CA2191076 A CA 2191076A CA 2191076 A1 CA2191076 A1 CA 2191076A1
- Authority
- CA
- Canada
- Prior art keywords
- aperture
- guide surface
- wellbore
- set forth
- invention set
- 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
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
- E21B41/00—Equipment or details not covered by groups E21B15/00 - E21B40/00
- E21B41/0035—Apparatus or methods for multilateral well technology, e.g. for the completion of or workover on wells with one or more lateral branches
-
- 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
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/30—Specific pattern of wells, e.g. optimizing the spacing of wells
- E21B43/305—Specific pattern of wells, e.g. optimizing the spacing of wells comprising at least one inclined or horizontal well
-
- 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
- E21B7/00—Special methods or apparatus for drilling
- E21B7/04—Directional drilling
- E21B7/06—Deflecting the direction of boreholes
- E21B7/061—Deflecting the direction of boreholes the tool shaft advancing relative to a guide, e.g. a curved tube or a whipstock
Abstract
A method for enhancing the productive capacity of a primary wellbore (2) containing a conduit string (5) such as casing comprising removing at least a partial section (20) of the casing to provide an aperture (21) therein, setting tubing (22) carrying a guide surface (25) in the vicinity of the aperture (21) and drilling a lateral wellbore (34) at an angle to the primary wellbore (2) using a coiled tubing conveyed drilling assembly (30).
Description
wo 95132353 2 1 9 1 0 7 6 P~ IC 17 LATERAL DRILLING METHOD
R 4.CK&ROUND OF 1~ INVFNTION
Heretofore horizontal wellbores, i.e., a wellbore that starts out essentially vertical and then curves into an essentially horizontal ~icrnci~inn have been employed in order to achieve a more productive well.
There are a number of existing primary welibores, both vertical in nature or deviated, whose productive capacity could be enhanced by drilling secondary or lateral wellbores therefrom.
This invention provides a timely and cost efficient melhod for enhancing the productive capacity of a primary wellbore, whether vertical or deviated, by providing a procedure by which one or more secondary wellbores are formed from the primary wellbore at one or more locations along that wellbore.
SUMMARY OF TEIE INVENTION
In accordance with this invention at least one aperture is formed in a conduit string, be it casing or tubing, that lines the wellbore after which a tubing string is set inside the conduit string, the tubing string carrying a guide surface at its dista~ end. Thereafter, a downhole drilling assembly is run into the tubing string by way of coiled tubing to engage with the guide surface and thereby direct the drilling assembly toward the aperture Upon operation of the drilling assembly, a secondary (lateral) wellbore is formed which extends at an angle to the long axis of the primary wellbore.
Accordingly, it is an object of this invention to provide a new and improved method for enhancing the productive capacity of a primary wellbore.
It is another object to provide a new and improved method for forming at least one secondary wellbore from an existing primary wellbore.
Other aspects, objects and advantages of this invention will be apparent to those skilled in the art from this disclosure and the appended claims .
.
w095/32353 ~ 1 9 1 [~76 ~ - 7 l)~S~RTPl'ION OF T~F, DRAWIN~S
Figure 1 shows a cross seaion of an existing primary wellbore.
Figure 2 shows the wellbore of Figure 1 after an aperture has been formed therein and with a tubing-guide surface ~,v~ iol~ being inserted in the primary wellbore.
Figure 3 shows the wellbore of Figure 2 after the 1~
surface . ",.,1, -~;..,. has been set in place and a downhole motor-bit assemblyinserted into the interior of the tubing by way of a coiled tubing string.
Figure 4 shows the wellbore of Figure 3 after a secondary wellbore has been drilled at a angle to the long axis of the primary wellbore and at the start of formation of another secondary wellbore.
Figure 5 shows a top view of a primary wellbore from which five secondary wellbores have been drilled, Figure 6 shows a front view of a guide surface usefrl in this invention.
Figure 7 shows a jet drilling assembly useful in this invention.
Figure 8 shows an alternative guide surface ~ v~
DETAILED DF~SCRTPIION OF T~E INVENTION
Figure 1 shows the earth's surface 1 with a primary wellbore 2 extending essentially vertically thereinto down to subsurface geologic formation 3 from which one or more minerals such as oil, natural gas, carbon dioxide, and the lil~e is plDdDced. The Dpper po lon D~ aellbo~e ~ lined wlth a meml cDddDi W0 95/32353 2 1 9 1 0 7 6 r~ 1047 .
slring 4 mosl commonly referred to as surface casing. The remainder of wellbore ~ is lined with a smaller diameler conduil slring S which can be either metal casing or lubing, but is more ofien casing. The lower end of conduit string 5 is lerminated with a slotted liner 6 through which fluid or fluidized minerals fromformation 3 can flow inlo open inlernal space 7 of conduit string 5 as shown by arrow 8 for production to and recovery at earth's surface 1. Wellbore 2 is capped at earth's surface 1 by a conventional wellhead 10 which carries a valved line 11 for recovery of minerals at the earth's surface. Wellhead 10 is capped by a ~u~ iù--~l crown valve 12. Primary wellbore 2 has a long axis 13 that extends into the earth and that is in alignment and coincides with the long axis of conduit string 5. The long axis of conduit string 5 can, therefore, also be represented by long axis 13. Internal space 7 of conduit string 5 extends along axis 13.
In accordance with this invention, as shown in Figure 2, at least a partial radial section 20 is removed from conduil string 5 to form an aperture 21 therein. The G",l~o~l;,., ; of Figure 2 totally separates lower portion 35 of conduit string 5 from the remaining upper portion of same, although total separation is not required in this invention. For example, aperture 21 can be just a window milledin conduit string 21 which Icaves conduit string 5 in tact from top to bottom since a window would encompass substantially less than the 360 degree radius J by aperture 21 of Figure 2. Aperture 21 or a narrower window can extend any desired length along the long axis of conduit string S and can radlially encompass less than the entire ..il~ul..r~ ...e of conduit string S in lieu of the full or entire cil- ul~r~ c of conduit string S as shown in Figure ~. Formation of aperture 21 provides substantially greater access to formation 3 for the subsequent production of greater quantities of mineral values into internal space 7.
After formation of aperture 21 a ull~ .-liulldl tubing string 22 (jointed or coiled) is inserted into internal space 7 from earth's surface 1, tubing string 2'2 having a long axis 23 and an open internal space 24 along axis 23.
Tubing string 22 carries at its distal end a guide surface 25, an optional centralizer 26, and optional packer 27. Pacl:~r 27 is expandable upon actuation .
W0 95/32353 ~ i q t 0 7 6 r~ 0 ~7 (m~rh:~nir~lly, electrically, or ~ O expand and seal with the interior surface 28 of conduit string 5. This integral tubing ~ ~-guide surface 25 ~ ..",1",.-l;.." is lowered through intemal space 7 as shown by arrow 29 until guide surface 25 is in the vicinity of aperture 21.
Normally guide surface ~S will be essen~ially adjacent to aperture 21 as shown in Figures 3 and 7. Guide surface 25 is oriented toward a portion ofaperture 21 through which a secondary wellbore is desirably drilled. The orientation of guide surface 25 can be ~. ~..,.,1,1;~1,. ;1 at any time. For example, the orientation can be established at the earth's surface before tubing string 22 isinserted into internal space 7. However, guide surface 25 can be oriented by simple rotation of tubing string 22 from the earth's surface while lubing 22 is passing du..llw~ldly (arrow 29) or after tubing 2'2 is se~ in place in intemal space 7. Altematively, tubing string 22 can carry a u u~ Liol~dl indexing tool near guide surface 25, as explained in greater detail hereinafter with reference to Figure 4, for rotating the guide surface by way of operation of the indexing tool downhole without rotating tubing string 22. Any approach well known in the art for orienting guide surface 25 can be employed in this invention essentially to point guide r,urface 25 toward the portion of aperture 21 where a secondary wellbore is to be formed.
Figure 3 shows tubing string 22 set in place by means of expanded packer 27 in internal space 7 of conduit string S with guide surface ~ in the vicinity of aperture 21. Guide surface 25 in Figure 3 is essentially adjacent toaperture 21 but in the practice of the invention guide surface 25 can be set further along the length 20 of aperture 21 so that it is clearly adjacent to aperture 21.
Tubing string 22 can be set so that guide surface 25 is anywhere along the length of aperture 21 so long as the desired secondary wellbore can be drilled without impinging on the lower portion of 35 of conduit string S.
Coiled tubing 30 carrying at its distal end a downhole motor 31-drill bit 32 I ~ l ;l lll is inserted into inter al space 24 of tubing string 22. Coiled .
W0 95/32353 . 2 1 q 1 'J 7 ~ 17 .
tubing 30 has a long axis 33 which is shown for sake of clarity in Figure 3 as displaced from axis q3 of tubing string 2q, but which can coincide with axis 23 in the same manner that the long axis of wellbore 2 coincides with the long axis ofconduit string 5.
The downhole motor-bit, ' nn is lowered by way of coiled tubing 30 until bit 32 engages guide surface 25 whereupon bit 32 is directed at an angle to axis 13 toward aperture 21. When downhole motor 31 is operated it causes bit 32 to form a secondary wellbore 34 which extends at an angle to long axis 13 of primary wellbore 2 and conduit string 5. Thus, it can be seen that bythe method of this invention a secondary wellbore 34 can be drilled a substantial distance out into producing formation 3 thereby increasing substantially the access of internal space 7 to the interior of formation 3 separately from and in addition to the access provided by slotted liner 6.
Full circle aperture 21 can be formed by any ~u~ ..iiu~
equipment know in the art for removing a section of conduit string such as well known casing cutters, ~ , and the like. Similarly, secondary wellbore 34 can be drilled in any known manner. For exa~nple, instead of using a drill bit 32, secondary wellbore 34 can be drilled using high pressure jet nozle drilling equipment conveyed to guide surface 25 and aperture 21 by way of coiled tubing 30 as shown in Figure 7. Also, .Il.~lb~L.l,.~J drilling can be used in which case gas lift ports 36 are employed on tubing string 2_ and a temporary plug 37 emplaced at the top of slotted liner 6 to stop the flow of fluids by way of arrow 8. Plug 37 can be a removable mechanical plug, cement plug, gel plug, or the like. Similarly, any ~ul.~ Liull~l coiled tubing unit can be used to deploy coiled tubing 30, a suitable coiled tubing unit being fully and completely disclosed inU.S. Patent 5,287,921 to Blount et al, the disclosure of which is ~ r~
herein by reference. Coiled tubing 30 can also be used to dispose a liner or other ~UII~ liiUllal well completion equipment into secondary wellbore 34 after its drilling has been completed. Guide surface 25 as shown in Figures 2 through 4, and 6 is integral with and internal to tubing string 22. A suitable guide surface s WO 95/32353 ~ ~ ~ t 0 7 6 PCrIG~95101047 can also be provided by carrying a ,GII~ ~IlLiolldl or modified whipstock at the end of tubing string 22 as shown in Figure 8. The norma~ly slanted surface 7~ of thewhipstock serves as guide surface 25.
After secondary wellbore 34 is drilled, coiled tubing 30 can be removed from internal space 24 of tubing string 22 or at least pulled sufficiently up into internal space 24 so that guide surface 25 can be reoriented for the drilling of another secondary wellbore through the same aperture ~1. As noted above of guide surface 25 can be ~ d by rotation of all or part of tubing string Z at or below the earth's surface 1 or by rotating essentially only the guide surface portion of string '22 as described hereinaher with respect to Figure 4.
Figure 4 shows tubing string 24 carrying a u u~ iull.,l indexing tool 40 below packer 27 and above guide surface 25. Tool 40 can be actuated m~-~h~ ly, electrically, or the like from the earth's surface to cause the portion of tubing string 22 below indexing tool 40 and containing guide surface 25 to rotate a ~ number of degrees to reorient guide surface 25 towards a new portion of aperture 21 for drilling another secondary wellbore. The few degree rotation can be repeated as many times as necessary to achieve a proper orientation. In the case of Figure 4, guide surface 25 has been rotated 18û degrees although this is not required. Indexing tool 40 is a ~o~ .lLi.,ll~l piece of apparatus well known in the art, one of which is disclosed under the term "orienting tool" in U.S. Patent 5,215,151 to Smith et al, the disclosure of which is ill~u~l u~dlc;d herein by reference.
Once guide surface 25 is rotated the desired number of degrees, downhole motor 31-drill bit 32 ..,, ~ i."- is redeployed by way of coiled tubing 30 in the manner described h~ Luve with reference to Figure 3. Thus, another secondary wellbore 41 is drilled at an angle to long axis 13 but in a totally differeM interior portion of formation 3. This further increases the access of intornal space 7 to the interior of formation 3. This procedure can be repeated as = y ~im~s as is re~son~ble fol a sb glc apermre. ~h~l is why ~ 360 de3~et radi d Wo 95132353 2 I q I 0 7 6 r~l . s .:17 aperture 21 is shown.
As noted above, an aperture useful in this invention can be a window in conduit string 5 that radially r~ less tharL even substantially less than, the entire 360 degree ~il-ulllrclcll-c of conduit string 5. If less than the entire ~il.ul.lrtlcll.c of the conduit string is desired for the aperture of this invention, a window can be milled in the conduit string using various milling practices. For example, tubing string 22 with guide surface 25 can be used to direct a downhole motor-mill ~ulllbill~lliùll to the inner surface 28 of conduit string S so that the mill can form an apenure (window) of only a few degrees of radius instead of the 360 degree radius of aperture 21. Thereafter a secondary wellbore, e.g., wellbore 34 of Figure 3, can be drilled through this narrow window in the same manner disclosed in Figure 3 above. Other window milling equipment can be employed such as that described in U.S. Patent 5,277,251 to Blount et al, thedisclosure of which is hereby i"l Ill~ by reference.
If additional secondary wellbores are desired along the length of wellbore 7 and conduit string ~, a second spaced apan aperture 42 can be milled or cut in conduit string S after which 1 or more secondary wellbores 43 can be drilled Li,~,lcLIlluu~;ll in the manner disclosed with reference to Figure 3 h~"cilldl/uvc. Thus, more than 1 apenure can be formed along the long axis 13 of conduit string 5 so that secondary wellbores can be formed spaced apan along the lenglh of conduit string 5 at as many locations as desired and reasonable.Thus, the productive capacity of wellbore 7 can be enhanced not only from formation 3 but also from other formations along the length of wellbore 7 that are removed from and not connected with formation 3.
Figure 5 shows a top view of wellbore 2 wherein, in addition to secondary wellbores 34 and 41 of Figures 3 and 4 ll~,lc;,l~uvc, additional spaced apan secondary wellbores 50, 51, and 52 are shown to have been drilled from apenure 21. Any number of spaced apart secondary wellbores radially around wellbore 2 and, by way of additional spaced apart apenures, at various locationsalong the length of wellbore 2 can be a~ieved by this invention.
wo 95132353 2 1 9 ~ 7 ~ P
Figure 6 shows what the wellbore 34 portion of aperture ~1 would see of guide surface 25 before drilling wellbore 34. Figure 6 shows guide su}face 25 to be a flat surface contained within the interior walls of tubing string '2 and facing an elongate opening 53 which will allow bit 32 followed by downhole motor31 and coiled tubing 30 to exit from internal space 24 of tubing 2' to meet and drill the portion of formation 3 that faces guide surface 25. As noted above, instead of the apparatus of Figure 6, a L(lll~ iU~ whipstock such as that shown in U.S. Patent 5,277,251 to Blount et al, can be used.
Figure 7 shows conduit string S having a narrow window (aperture) 60 of substantially less than the 360 degree radius of aperture 21, but still wide enough to pass a drilling assembly Lh..cillluu~;ll to form a secondary wellbore 61.
In this case, instead of using a motor-bit assembly, a high pressure jet drilling no2zle 62 is employed at the distal end of coiled tubing 30, wellbore 61 being formed by high pressure fluid 63 being supplied from the earth's surface throughthe interior of tubing 30 and emitted by nozle 62 at a high velocity and pressure.
Figure 8 shows tubing string 22 carrying at its distal end whipstock 70 whose normal guide surface 72 can serve as a substitute for guide surface 25.As an exarnple, a primary wellbore essentially as shown in Figure 1 is completed with 9 5/~" diameter steel casing for conduit string 5 and a 6 5/8`' diameter slotted steel liner for liner 6 and produces 100 barrels of oil per day and 50 barrels of water per day by way of arrow 8. The casing is sectioned as shown in Figure 3 using an u,.l. llc~ l and cernent for temporary plug 37. A string ofjointed 4 1/2" diameter steel tubing is used for tubing string 22. Two inch diameter coiled tubing is employed for coiled tubing 30 using a ,UII~ iUII~II
whipstock to provide guide surface 25. The 4112" tubing string is rotated with u ull~ iu~.~l equipment at the earth's surface to reorient the whipstock after the first, lateral well 34 is drilled.
Reasonable variations and mn-lifi~ n~ are possible within the scope of this disclosure without departing from the spirit and scope of this iDvcnlion
R 4.CK&ROUND OF 1~ INVFNTION
Heretofore horizontal wellbores, i.e., a wellbore that starts out essentially vertical and then curves into an essentially horizontal ~icrnci~inn have been employed in order to achieve a more productive well.
There are a number of existing primary welibores, both vertical in nature or deviated, whose productive capacity could be enhanced by drilling secondary or lateral wellbores therefrom.
This invention provides a timely and cost efficient melhod for enhancing the productive capacity of a primary wellbore, whether vertical or deviated, by providing a procedure by which one or more secondary wellbores are formed from the primary wellbore at one or more locations along that wellbore.
SUMMARY OF TEIE INVENTION
In accordance with this invention at least one aperture is formed in a conduit string, be it casing or tubing, that lines the wellbore after which a tubing string is set inside the conduit string, the tubing string carrying a guide surface at its dista~ end. Thereafter, a downhole drilling assembly is run into the tubing string by way of coiled tubing to engage with the guide surface and thereby direct the drilling assembly toward the aperture Upon operation of the drilling assembly, a secondary (lateral) wellbore is formed which extends at an angle to the long axis of the primary wellbore.
Accordingly, it is an object of this invention to provide a new and improved method for enhancing the productive capacity of a primary wellbore.
It is another object to provide a new and improved method for forming at least one secondary wellbore from an existing primary wellbore.
Other aspects, objects and advantages of this invention will be apparent to those skilled in the art from this disclosure and the appended claims .
.
w095/32353 ~ 1 9 1 [~76 ~ - 7 l)~S~RTPl'ION OF T~F, DRAWIN~S
Figure 1 shows a cross seaion of an existing primary wellbore.
Figure 2 shows the wellbore of Figure 1 after an aperture has been formed therein and with a tubing-guide surface ~,v~ iol~ being inserted in the primary wellbore.
Figure 3 shows the wellbore of Figure 2 after the 1~
surface . ",.,1, -~;..,. has been set in place and a downhole motor-bit assemblyinserted into the interior of the tubing by way of a coiled tubing string.
Figure 4 shows the wellbore of Figure 3 after a secondary wellbore has been drilled at a angle to the long axis of the primary wellbore and at the start of formation of another secondary wellbore.
Figure 5 shows a top view of a primary wellbore from which five secondary wellbores have been drilled, Figure 6 shows a front view of a guide surface usefrl in this invention.
Figure 7 shows a jet drilling assembly useful in this invention.
Figure 8 shows an alternative guide surface ~ v~
DETAILED DF~SCRTPIION OF T~E INVENTION
Figure 1 shows the earth's surface 1 with a primary wellbore 2 extending essentially vertically thereinto down to subsurface geologic formation 3 from which one or more minerals such as oil, natural gas, carbon dioxide, and the lil~e is plDdDced. The Dpper po lon D~ aellbo~e ~ lined wlth a meml cDddDi W0 95/32353 2 1 9 1 0 7 6 r~ 1047 .
slring 4 mosl commonly referred to as surface casing. The remainder of wellbore ~ is lined with a smaller diameler conduil slring S which can be either metal casing or lubing, but is more ofien casing. The lower end of conduit string 5 is lerminated with a slotted liner 6 through which fluid or fluidized minerals fromformation 3 can flow inlo open inlernal space 7 of conduit string 5 as shown by arrow 8 for production to and recovery at earth's surface 1. Wellbore 2 is capped at earth's surface 1 by a conventional wellhead 10 which carries a valved line 11 for recovery of minerals at the earth's surface. Wellhead 10 is capped by a ~u~ iù--~l crown valve 12. Primary wellbore 2 has a long axis 13 that extends into the earth and that is in alignment and coincides with the long axis of conduit string 5. The long axis of conduit string 5 can, therefore, also be represented by long axis 13. Internal space 7 of conduit string 5 extends along axis 13.
In accordance with this invention, as shown in Figure 2, at least a partial radial section 20 is removed from conduil string 5 to form an aperture 21 therein. The G",l~o~l;,., ; of Figure 2 totally separates lower portion 35 of conduit string 5 from the remaining upper portion of same, although total separation is not required in this invention. For example, aperture 21 can be just a window milledin conduit string 21 which Icaves conduit string 5 in tact from top to bottom since a window would encompass substantially less than the 360 degree radius J by aperture 21 of Figure 2. Aperture 21 or a narrower window can extend any desired length along the long axis of conduit string S and can radlially encompass less than the entire ..il~ul..r~ ...e of conduit string S in lieu of the full or entire cil- ul~r~ c of conduit string S as shown in Figure ~. Formation of aperture 21 provides substantially greater access to formation 3 for the subsequent production of greater quantities of mineral values into internal space 7.
After formation of aperture 21 a ull~ .-liulldl tubing string 22 (jointed or coiled) is inserted into internal space 7 from earth's surface 1, tubing string 2'2 having a long axis 23 and an open internal space 24 along axis 23.
Tubing string 22 carries at its distal end a guide surface 25, an optional centralizer 26, and optional packer 27. Pacl:~r 27 is expandable upon actuation .
W0 95/32353 ~ i q t 0 7 6 r~ 0 ~7 (m~rh:~nir~lly, electrically, or ~ O expand and seal with the interior surface 28 of conduit string 5. This integral tubing ~ ~-guide surface 25 ~ ..",1",.-l;.." is lowered through intemal space 7 as shown by arrow 29 until guide surface 25 is in the vicinity of aperture 21.
Normally guide surface ~S will be essen~ially adjacent to aperture 21 as shown in Figures 3 and 7. Guide surface 25 is oriented toward a portion ofaperture 21 through which a secondary wellbore is desirably drilled. The orientation of guide surface 25 can be ~. ~..,.,1,1;~1,. ;1 at any time. For example, the orientation can be established at the earth's surface before tubing string 22 isinserted into internal space 7. However, guide surface 25 can be oriented by simple rotation of tubing string 22 from the earth's surface while lubing 22 is passing du..llw~ldly (arrow 29) or after tubing 2'2 is se~ in place in intemal space 7. Altematively, tubing string 22 can carry a u u~ Liol~dl indexing tool near guide surface 25, as explained in greater detail hereinafter with reference to Figure 4, for rotating the guide surface by way of operation of the indexing tool downhole without rotating tubing string 22. Any approach well known in the art for orienting guide surface 25 can be employed in this invention essentially to point guide r,urface 25 toward the portion of aperture 21 where a secondary wellbore is to be formed.
Figure 3 shows tubing string 22 set in place by means of expanded packer 27 in internal space 7 of conduit string S with guide surface ~ in the vicinity of aperture 21. Guide surface 25 in Figure 3 is essentially adjacent toaperture 21 but in the practice of the invention guide surface 25 can be set further along the length 20 of aperture 21 so that it is clearly adjacent to aperture 21.
Tubing string 22 can be set so that guide surface 25 is anywhere along the length of aperture 21 so long as the desired secondary wellbore can be drilled without impinging on the lower portion of 35 of conduit string S.
Coiled tubing 30 carrying at its distal end a downhole motor 31-drill bit 32 I ~ l ;l lll is inserted into inter al space 24 of tubing string 22. Coiled .
W0 95/32353 . 2 1 q 1 'J 7 ~ 17 .
tubing 30 has a long axis 33 which is shown for sake of clarity in Figure 3 as displaced from axis q3 of tubing string 2q, but which can coincide with axis 23 in the same manner that the long axis of wellbore 2 coincides with the long axis ofconduit string 5.
The downhole motor-bit, ' nn is lowered by way of coiled tubing 30 until bit 32 engages guide surface 25 whereupon bit 32 is directed at an angle to axis 13 toward aperture 21. When downhole motor 31 is operated it causes bit 32 to form a secondary wellbore 34 which extends at an angle to long axis 13 of primary wellbore 2 and conduit string 5. Thus, it can be seen that bythe method of this invention a secondary wellbore 34 can be drilled a substantial distance out into producing formation 3 thereby increasing substantially the access of internal space 7 to the interior of formation 3 separately from and in addition to the access provided by slotted liner 6.
Full circle aperture 21 can be formed by any ~u~ ..iiu~
equipment know in the art for removing a section of conduit string such as well known casing cutters, ~ , and the like. Similarly, secondary wellbore 34 can be drilled in any known manner. For exa~nple, instead of using a drill bit 32, secondary wellbore 34 can be drilled using high pressure jet nozle drilling equipment conveyed to guide surface 25 and aperture 21 by way of coiled tubing 30 as shown in Figure 7. Also, .Il.~lb~L.l,.~J drilling can be used in which case gas lift ports 36 are employed on tubing string 2_ and a temporary plug 37 emplaced at the top of slotted liner 6 to stop the flow of fluids by way of arrow 8. Plug 37 can be a removable mechanical plug, cement plug, gel plug, or the like. Similarly, any ~ul.~ Liull~l coiled tubing unit can be used to deploy coiled tubing 30, a suitable coiled tubing unit being fully and completely disclosed inU.S. Patent 5,287,921 to Blount et al, the disclosure of which is ~ r~
herein by reference. Coiled tubing 30 can also be used to dispose a liner or other ~UII~ liiUllal well completion equipment into secondary wellbore 34 after its drilling has been completed. Guide surface 25 as shown in Figures 2 through 4, and 6 is integral with and internal to tubing string 22. A suitable guide surface s WO 95/32353 ~ ~ ~ t 0 7 6 PCrIG~95101047 can also be provided by carrying a ,GII~ ~IlLiolldl or modified whipstock at the end of tubing string 22 as shown in Figure 8. The norma~ly slanted surface 7~ of thewhipstock serves as guide surface 25.
After secondary wellbore 34 is drilled, coiled tubing 30 can be removed from internal space 24 of tubing string 22 or at least pulled sufficiently up into internal space 24 so that guide surface 25 can be reoriented for the drilling of another secondary wellbore through the same aperture ~1. As noted above of guide surface 25 can be ~ d by rotation of all or part of tubing string Z at or below the earth's surface 1 or by rotating essentially only the guide surface portion of string '22 as described hereinaher with respect to Figure 4.
Figure 4 shows tubing string 24 carrying a u u~ iull.,l indexing tool 40 below packer 27 and above guide surface 25. Tool 40 can be actuated m~-~h~ ly, electrically, or the like from the earth's surface to cause the portion of tubing string 22 below indexing tool 40 and containing guide surface 25 to rotate a ~ number of degrees to reorient guide surface 25 towards a new portion of aperture 21 for drilling another secondary wellbore. The few degree rotation can be repeated as many times as necessary to achieve a proper orientation. In the case of Figure 4, guide surface 25 has been rotated 18û degrees although this is not required. Indexing tool 40 is a ~o~ .lLi.,ll~l piece of apparatus well known in the art, one of which is disclosed under the term "orienting tool" in U.S. Patent 5,215,151 to Smith et al, the disclosure of which is ill~u~l u~dlc;d herein by reference.
Once guide surface 25 is rotated the desired number of degrees, downhole motor 31-drill bit 32 ..,, ~ i."- is redeployed by way of coiled tubing 30 in the manner described h~ Luve with reference to Figure 3. Thus, another secondary wellbore 41 is drilled at an angle to long axis 13 but in a totally differeM interior portion of formation 3. This further increases the access of intornal space 7 to the interior of formation 3. This procedure can be repeated as = y ~im~s as is re~son~ble fol a sb glc apermre. ~h~l is why ~ 360 de3~et radi d Wo 95132353 2 I q I 0 7 6 r~l . s .:17 aperture 21 is shown.
As noted above, an aperture useful in this invention can be a window in conduit string 5 that radially r~ less tharL even substantially less than, the entire 360 degree ~il-ulllrclcll-c of conduit string 5. If less than the entire ~il.ul.lrtlcll.c of the conduit string is desired for the aperture of this invention, a window can be milled in the conduit string using various milling practices. For example, tubing string 22 with guide surface 25 can be used to direct a downhole motor-mill ~ulllbill~lliùll to the inner surface 28 of conduit string S so that the mill can form an apenure (window) of only a few degrees of radius instead of the 360 degree radius of aperture 21. Thereafter a secondary wellbore, e.g., wellbore 34 of Figure 3, can be drilled through this narrow window in the same manner disclosed in Figure 3 above. Other window milling equipment can be employed such as that described in U.S. Patent 5,277,251 to Blount et al, thedisclosure of which is hereby i"l Ill~ by reference.
If additional secondary wellbores are desired along the length of wellbore 7 and conduit string ~, a second spaced apan aperture 42 can be milled or cut in conduit string S after which 1 or more secondary wellbores 43 can be drilled Li,~,lcLIlluu~;ll in the manner disclosed with reference to Figure 3 h~"cilldl/uvc. Thus, more than 1 apenure can be formed along the long axis 13 of conduit string 5 so that secondary wellbores can be formed spaced apan along the lenglh of conduit string 5 at as many locations as desired and reasonable.Thus, the productive capacity of wellbore 7 can be enhanced not only from formation 3 but also from other formations along the length of wellbore 7 that are removed from and not connected with formation 3.
Figure 5 shows a top view of wellbore 2 wherein, in addition to secondary wellbores 34 and 41 of Figures 3 and 4 ll~,lc;,l~uvc, additional spaced apan secondary wellbores 50, 51, and 52 are shown to have been drilled from apenure 21. Any number of spaced apart secondary wellbores radially around wellbore 2 and, by way of additional spaced apart apenures, at various locationsalong the length of wellbore 2 can be a~ieved by this invention.
wo 95132353 2 1 9 ~ 7 ~ P
Figure 6 shows what the wellbore 34 portion of aperture ~1 would see of guide surface 25 before drilling wellbore 34. Figure 6 shows guide su}face 25 to be a flat surface contained within the interior walls of tubing string '2 and facing an elongate opening 53 which will allow bit 32 followed by downhole motor31 and coiled tubing 30 to exit from internal space 24 of tubing 2' to meet and drill the portion of formation 3 that faces guide surface 25. As noted above, instead of the apparatus of Figure 6, a L(lll~ iU~ whipstock such as that shown in U.S. Patent 5,277,251 to Blount et al, can be used.
Figure 7 shows conduit string S having a narrow window (aperture) 60 of substantially less than the 360 degree radius of aperture 21, but still wide enough to pass a drilling assembly Lh..cillluu~;ll to form a secondary wellbore 61.
In this case, instead of using a motor-bit assembly, a high pressure jet drilling no2zle 62 is employed at the distal end of coiled tubing 30, wellbore 61 being formed by high pressure fluid 63 being supplied from the earth's surface throughthe interior of tubing 30 and emitted by nozle 62 at a high velocity and pressure.
Figure 8 shows tubing string 22 carrying at its distal end whipstock 70 whose normal guide surface 72 can serve as a substitute for guide surface 25.As an exarnple, a primary wellbore essentially as shown in Figure 1 is completed with 9 5/~" diameter steel casing for conduit string 5 and a 6 5/8`' diameter slotted steel liner for liner 6 and produces 100 barrels of oil per day and 50 barrels of water per day by way of arrow 8. The casing is sectioned as shown in Figure 3 using an u,.l. llc~ l and cernent for temporary plug 37. A string ofjointed 4 1/2" diameter steel tubing is used for tubing string 22. Two inch diameter coiled tubing is employed for coiled tubing 30 using a ,UII~ iUII~II
whipstock to provide guide surface 25. The 4112" tubing string is rotated with u ull~ iu~.~l equipment at the earth's surface to reorient the whipstock after the first, lateral well 34 is drilled.
Reasonable variations and mn-lifi~ n~ are possible within the scope of this disclosure without departing from the spirit and scope of this iDvcnlion
Claims (15)
1. In a method for enhancing the productive capacity of a primary wellbore, said wellbore having a long axis and extending into the earth along said long axis, said wellbore containingat least one conduit string which has a long axis essentially in alignment with the long axis of said wellbore, said conduit string having an internal space along its long axis, the improvement comprising removing at least a partial radial sectionof said conduit string to provide an aperture therein, providing a tubing stringhaving a long axis and an internal space along said long axis, said tubing string carrying a guide surface on its distal end, setting said tubing string in the internal space of said conduit string so that said guide surface is in the vicinity of said aperture and oriented toward a portion of said aperture, providing coiled tubinghaving a drilling assembly on the distal end thereof, passing said coiled tubing and drilling assembly through the internal space of said tubing string to engage said drilling assembly with said guide surface and direct said drilling assembly toward said aperture portion at an angle to the long axis of said wellbore, and operating said drilling assembly to form a secondary wellbore which extends at an angle tothe long axis of said primary wellbore.
2. The invention set forth in Claim 1 wherein:
- said aperture radially encompasses less than the entire circumference of said conduit string.
- said aperture radially encompasses less than the entire circumference of said conduit string.
3. The invention set forth in Claim 1 wherein:
said aperture radially encompasses the full circumference of said conduit string.
said aperture radially encompasses the full circumference of said conduit string.
4. The invention set forth in Claim 1 wherein:
said guide surface is carried internally of said tubing string.
said guide surface is carried internally of said tubing string.
5. The invention set forth in Claim 1 wherein:
said guide surface is carried by a whipstock and said whipstock is carried by said tubing string.
said guide surface is carried by a whipstock and said whipstock is carried by said tubing string.
6. The invention set forth in Claim 1 wherein:
said tubing string is set in said conduit string so that said guide surface is essentially adjacent to said aperture.
said tubing string is set in said conduit string so that said guide surface is essentially adjacent to said aperture.
7. The invention set forth in Claim 1 wherein:
said tubing string is rotated to orient said guide surface.
said tubing string is rotated to orient said guide surface.
8. The invention set forth in Claim 7 wherein:
said tubing string is rotated at the earth's surface.
said tubing string is rotated at the earth's surface.
9. The invention set forth in Claim 1 wherein:
said tubing string carries an indexing tool near said guide surface, and said guide surface is rotated for orientation by operation of said indexing tool.
said tubing string carries an indexing tool near said guide surface, and said guide surface is rotated for orientation by operation of said indexing tool.
10. The invention set forth in Claim 1 wherein:
more than one secondary wellbore is drilled through said aperture.
more than one secondary wellbore is drilled through said aperture.
11. The invention set forth in Claim 1 wherein:
a plurality of spaced apart secondary wellbores are drilled through at least one aperture.
a plurality of spaced apart secondary wellbores are drilled through at least one aperture.
12. The invention set forth in Claim 1 wherein:
more than one aperture is formed along the long axis of said conduit string so that secondary wellbores can be formed spaced apart along said long axis.
more than one aperture is formed along the long axis of said conduit string so that secondary wellbores can be formed spaced apart along said long axis.
13. The invention set forth in Claim 1 wherein:
said aperture is formed using said tubing string carrying a guide surface on its distal end.
said aperture is formed using said tubing string carrying a guide surface on its distal end.
14. The invention set forth in Claim 1 wherein:
said drilling assembly is a downhole motor and drill bit combination.
said drilling assembly is a downhole motor and drill bit combination.
15. The invention set forth in Claim 1 wherein:
said drilling assembly is a jet drilling device.
said drilling assembly is a jet drilling device.
Applications Claiming Priority (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US08248972 US5435400B1 (en) | 1994-05-25 | 1994-05-25 | Lateral well drilling |
| US08/248,972 | 1994-05-25 |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CA2191076A1 true CA2191076A1 (en) | 1995-11-30 |
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ID=22941491
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA002191076A Abandoned CA2191076A1 (en) | 1994-05-25 | 1995-05-10 | Lateral drilling method |
Country Status (6)
| Country | Link |
|---|---|
| US (1) | US5435400B1 (en) |
| EP (1) | EP0760895B1 (en) |
| CA (1) | CA2191076A1 (en) |
| DE (1) | DE69505523T2 (en) |
| NO (1) | NO964942D0 (en) |
| WO (1) | WO1995032353A1 (en) |
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| US5277251A (en) * | 1992-10-09 | 1994-01-11 | Blount Curtis G | Method for forming a window in a subsurface well conduit |
| AU5408294A (en) * | 1992-10-19 | 1994-05-09 | Baker Hughes Incorporated | Retrievable whipstock system |
| US5287921A (en) * | 1993-01-11 | 1994-02-22 | Blount Curtis G | Method and apparatus for setting a whipstock |
| US5413184A (en) * | 1993-10-01 | 1995-05-09 | Landers; Carl | Method of and apparatus for horizontal well drilling |
-
1994
- 1994-05-25 US US08248972 patent/US5435400B1/en not_active Expired - Fee Related
-
1995
- 1995-05-10 DE DE69505523T patent/DE69505523T2/en not_active Expired - Fee Related
- 1995-05-10 WO PCT/GB1995/001047 patent/WO1995032353A1/en active IP Right Grant
- 1995-05-10 CA CA002191076A patent/CA2191076A1/en not_active Abandoned
- 1995-05-10 EP EP95918072A patent/EP0760895B1/en not_active Expired - Lifetime
-
1996
- 1996-11-21 NO NO964942A patent/NO964942D0/en not_active Application Discontinuation
Also Published As
| Publication number | Publication date |
|---|---|
| WO1995032353A1 (en) | 1995-11-30 |
| EP0760895B1 (en) | 1998-10-21 |
| NO964942L (en) | 1996-11-21 |
| US5435400A (en) | 1995-07-25 |
| US5435400B1 (en) | 1999-06-01 |
| DE69505523D1 (en) | 1998-11-26 |
| NO964942D0 (en) | 1996-11-21 |
| DE69505523T2 (en) | 1999-05-20 |
| EP0760895A1 (en) | 1997-03-12 |
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| Date | Code | Title | Description |
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| FZDE | Dead |