WO2014149132A2

WO2014149132A2 - Drill bit with replaceable blades, fluid pulse and fluid collision

Info

Publication number: WO2014149132A2
Application number: PCT/US2014/000046
Authority: WO
Inventors: Alan L. Nackerud
Original assignee: Nackerud Alan L
Priority date: 2013-03-19
Filing date: 2014-03-17
Publication date: 2014-09-25
Also published as: WO2014149132A3

Abstract

A drill bit and turbine unit apparatus for drilling a bore which can accept one or more pressures of drilling fluid and/or one or more types of drilling fluid wherein it has two or more distinct and separate fluid paths through said bit which provides the intersection of some paired fluid expulsion points and has a rotating turbine unit for the pulsing of fluid at some of its expulsion points for enhanced hole advancement by increased drilling fluid velocity and cutting force to the material to be cut and has replaceable blades which interlock with each other and have retention means on more than one axis whereby the blades can be easily removed, refurbished and/or replaced.

Description

Patent Application of

Alan L. Nackerud

For

DRILL BIT WITH REPLACEABLE BLADES, FLUID PULSE AND FLUID COLLISION CROSS REFERENCE TO RELATED APPLICATIONS:

This application claims the benefit of provisional patent application Ser. No. US 61/852,692 filed March 19, 2013 by Alan L. Nackerud, which is incorporated by reference herein.

BACKGROUND AND FIELD OF INVENTION:

The present invention relates to a drill bit which can be used in the drilling of earthen well bores or to advance a bore in hard material.

SUMMARY OF THE INVENTION:

The present invention is a drill bit with replaceable blades and pulse turbine unit which provides new and novel features including but not limited to; blades which can be removed and repaired or replaced, a fluid system which can receive one or more fluid types and/or fluids with different pressures, a fluid system which has more than one distinct and separate fluid delivery path through the drill bit, a fluid pulse turbine unit which can provide delivery of one or more pulsed fluids to the rock or cutting interface, a fluid path to direct fluid to provide a collision of two or more flow patterns at or near the rock or cutting interface to increase the velocity of the delivered fluid, a fluid delivery pattern system to kerf or etch the rock with the enhanced fluid delivery, and hardened disc rollers or other hardened cutters to track the kerfs and apply pressure to the rock or material to be cut and thereby crack or break the rock. The present invention can be used with a bottom hole assembly or drill string which can deliver either a normal low pressure fluid or more than one type of fluid or both a low and high pressure fluid to the present invention. An example delivery system and apparatus or assembly which provides a low and high pressure fluid system is contemplated and referred to in Provisional Patent Application of Alan L. Nackerud for High Pressure

Downhole Pump Assembly filed and dated February 26, 2013. With regard to the replaceable blades the present invention also provides new and novel features including but not limited to; replaceable blades which are pinned together which provide greater strength, replaceable blades where each blade is interlocked with the other blade to provide greater strength, placement of multiple attachment pins between the blades and body that align with the drill bit body in more than one direction for added strength, replaceable blades which have small pressure pistons that are positioned between the blades and the bit body to provide better securing and tightening of the blades to the bit body. There are additional features of the present invention that will be described herein, however it is to be understood that the invention is not limited in its application to the details of construction and to the

arrangements of the components set forth in the following description. The invention is capable of other embodiments and of being practiced and carried out in various ways. Also, it is to be understood that the phraseology and terminology herein are for the purpose of description and should not be regarded as limiting. As such, those skilled in the art will appreciate that the conception, upon which this disclosure is based, may readily be utilized as a basis for the designing of other embodiments, structures, methods and systems for carrying out the several purposes of the present invention. The above and other advantages and features of the present invention will become more readily appreciated and understood from a consideration of the following detailed description taken together with the accompanying drawings;

DRAWINGS - FIGURES:

Figure 1 is a side view of drill bit and pulse turbine unit;

Figure 2 is a bottom view of drill bit showing roller discs, large fluid nozzles and hidden blade lateral fluid bores;

Figure 3 is a cross section side view of drill bit and pulse turbine unit showing main inner fluid bore, outer bores, blade lateral fluid bores, roller discs and retention pins;

Figure 4 is a bottom view of drill bit showing roller discs, hidden blade lateral fluid bores, large fluid nozzles and hidden retention pins;

Figure 5 is a cross section side view of drill bit and pulse turbine unit rotated 45 degrees clockwise showing main inner fluid bore, outer bores, blade lateral fluid bores, roller discs and retention pins;

Figure 6 is a bottom view of drill bit rotated 45 degrees showing roller discs, hidden blade lateral fluid bores, fluid nozzles and hidden retention pins;

Figure 7 is a cross section side view of drill bit rotated 22.5 degrees showing main inner fluid bore and angle fluid bores;

Figure 8 is a bottom view of drill bit rotated 22.5 degrees showing blade slots, large fluid nozzles and hidden retention pins; Figure 9 is a side view of upper blade showing roller discs, retention holes and pins, hidden bores and small pressure pistons;

Figure 10 is an end view of upper blade showing roller discs, hidden retention pin holes and small pressure pistons;

Figure 11 is a side view of lower blade showing roller discs, retention holes and pins, hidden bores and small pressure pistons;

Figure 12 is an end view of lower blade showing roller discs, hidden retention pin holes, bores and small pressure pistons;

Figure 13 is a side view of drill bit without blades showing main inner fluid bore, outer fluid bores, retention pin holes and blade slots;

Figure 14 is a side view of drill bit without blades rotated 45 degrees showing main inner fluid bore, outer fluid bores, retention pin holes and blade slots;

Figure 15 is a top view of pulse turbine;

Figure 16 is a side view of pulse turbine;

Figure 17 is a top view of drill bit without pulse turbine unit;

Figure 18 is a top view of drill bit with pulse turbine unit;

Figure 19 is a top view of drill bit with pulse turbine unit rotated 22.5 degrees clockwise; Figure 20 is a top view and side view of small ring bearing;

Figure 21 is a top view and side view of large ring bearing; DRAWINGS - REFERENCE NUMERALS:

1. ball bearing to pulse turbine unit

2. large ring bearing

3. spring to pulse turbine ring bearing

4. turbine

5. pulse turbine unit

6. small ring bearing

7. pulse turbine slot

8. ball bearing hole to pulse turbine

9. main inner fluid bore

10. pin connection

11. upper outer fluid bore

12. lower outer fluid bore

13. wrench flat

14. vertical retention pin hole

15. horizontal retention pin hole

16. blade slot

17. vertical retention pin

18. upper replaceable blade

19. blade vertical fluid bore

20. set screw

21. blade lateral fluid bore 22. small roller disc

23. disc bearing

24. large roller disc

25. small fluid nozzle

26. snap ring nozzle retainer

27. small pressure piston

28. angle fluid bore

29. large fluid nozzle

30. inner ball bearing hole to pulse turbine

31. outer ball bearing hole to pulse turbine

32. lower replaceable blade

33. horizontal retention pin

34. horizontal retention pin knock out hole

DETAILED DESCRIPTION:

The drill bit, pulse turbine unit 19 and various parts described herein are illustrated in Figures 1 through 21. The body of the drill bit has a threaded pin connection 10 on top to allow connection to a drill string. One or more wrench flats 13 are located on the outside surface perimeter of the drill bit body to assist in holding the drill bit as it is connected to or unconnected from the drill string. A main inner fluid bore 9 proceeds through the pin connection 10 and into the drill bit body where it connects to angle fluid bores 28, and out the bottom of the drill bit to provide normal fluid circulation out of the drill bit for rock cuttings removal, cooling of the drill bit and drill string and other normal fluid uses in drilling. On top of said drill bit is a pulse turbine unit 5 which is placed on top of the drill bit and inside a recess in a flared sub or pump to be connected above the pulse turbine unit 5 and drill bit. Said pulse turbine unit 5 allows two paths of delivery of fluid through the drill bit; one path provides for fluid delivery down the main inner fluid bore 9 and the other path provides for fluid delivery through numerous outer fluid bores, 11, 12 located axially around the perimeter of the top of the drill bit. Said outer fluid bores 11, 12 direct fluid to blade vertical fluid bores 19 and blade lateral fluid bores 21 which direct fluid to small fluid nozzles 25, some of which are paired and angled toward each other near the bit bottom to provide a concentrated collision of fluid near the rock interface where an increased fluid velocity is achieved and thereby a greater fluid force to cut the rock or material being removed. A kerf line or etch of the rock or material being cut is obtained. The pulse turbine unit 5 located at the top of the drill bit has opposing and alternating pulse turbine slots 7 which when rotated by the passage of fluid through the center turbine 4 provide for additional cutting force via alternating delivery of pulsed fluid to the small fluid nozzles 25. The other path of fluid is through the main inner fluid bore 9 which delivers fluid to angle fluid bores 28 which expels fluid out the bottom of the drill bit for additional fluid volume for cuttings removal, cooling of downhole tools and drill string and other normal uses of fluid circulation in a well bore. The two fluid delivery paths; the angle fluid bore 28 path, and the outer fluid bore 11, 12 path can receive drill string fluid at one pressure or they can each receive a different fluid type or different fluid pressure provided the down hole assembly above the pulse turbine and drill bit has a high pressure downhole pump, drill pipe or other assembly capable of two flow paths to deliver two distinct fluid types or two distinct fluid levels of fluid pressure to the pulse turbine unit 5 and drill bit. The preferred form of the drill bit has roller discs 22, 24 that are located such on the bottom of the drill bit to track or align with the kerf lines of the paired and non-paired small fluid nozzles 25 so that when drill string weight and rotation is applied to the rock or material being removed, the roller discs 22, 24 are able to crack and break the rock at a weakened point between kerf lines below the top of the rock interface. This is a more efficient method of rock removal and provides an increased rate of hole advancement and a larger percentage of rock removal with each rotation of the drill string compared to less efficient methods of conventional drill bit rock removal by typical crushing or shearing of the rock. The preferred form of the drill bit shows roller discs 22, 24 of a hardened material such as tungsten carbide, however tungsten carbide inserts or discs, or polycrystalline diamond compact (PDC) discs or other hardened material cutters could be used. The preferred form of the drill bit has said rollers 22, 24 which are able to rotate or spin on disc bearings 23. Said disc bearings 23 are attached to the drill bit by weld or other common attachment method such as a bearing cover or plate and bolts.

As to the replaceable blades 18, 32, they are affixed to the body by vertical retention pins 17 and horizontal retention pins 33. The drill bit body has blade slots 16 to receive replaceable blades 18, 32. The replaceable blades 18, 32 shown have tungsten carbide roller discs but other hardened material cutters could be used such as tungsten carbide discs or inserts or PDC cutters. The replaceable blades 18, 32 are overlapping and held and aligned with vertical pins 17. The upper replaceable blade 18 is inserted in the body and slotted so that the lower replaceable blade 32 when inserted will fit against and be perpendicular to said upper replaceable blade 18. Vertical retention pins 17 are placed in between the replaceable blades 18, 32 and bit body to further align and hold said replaceable blades 18, 32 to the bit body. The replaceable blades 18, 32 are inserted into blade slots 16 from the bottom and pinned with horizontal retention pins 33 to the body. The horizontal retention pins 33 stay in place with drill string clockwise rotation. The horizontal retention pins 33 can be further retained in place by set screws 20, weld or other attachment method. After drill bit use and when the replaceable blades 18, 32 have become worn, the horizontal retention pins 33 can be knocked out by way of the horizontal retention pin knock out holes 34 on the backside. The replaceable blades 18, 32 can then be removed from the body and refurbished, redressed or replaced. Should additional blade retention strength be needed the replaceable blades 18, 32 can be welded to the body. Another option for replaceable blades 18, 32 retention is the use of small pressure pistons 27 placed between replaceable blades 18, 32 and bit body to tighten the fit in the blade slots 16 especially in tools being reused. When fluid is pumped through the bit the fluid pushes the small pressure pistons 27 slightly outward from the blade and against the bit body. If the replaceable blades 18, 32 have been welded to the body the weld can be ground off and the blades 10, 11 removed to be refurbished, redressed or replaced. Additional blades may be added as part of the drill bit either as insertable blades or integral blades being machined or forged as part of the body. It is therefore to be understood that even though numerous characteristics and advantages of the present embodiment have been set forth in the foregoing description, together with the details of the structure and function of the embodiment, the disclosure is illustrative only, and changes may be made within the principles of the embodiment to the full extent indicated by the broad general meaning of the terms in which the claims are expressed and reasonable equivalents thereof and various forms of the present invention can be applied to numerous drilling and completion tools of well bores.

Claims

CLAIMS: I claim:

1. A drill bit and pulse turbine unit apparatus which can receive drilling fluid from a preceding high pressure downhole pump or preceding drill string and provides that said drilling fluid travel through the drill bit in two or more distinct and separate paths of two or more internal fluid bores and subsequent distinct and separate discharge ports to the rock or material being cut comprising:

(a) a drill bit with a threaded pin connection on top with a centered main inner bore intersected by several distinct and separate inner angle fluid bores which deliver fluid to the drill bit leading edge, and

(b) wherein numerous distinct and separate outer angle fluid bores are located radially near the outside perimeter at the top of said threaded pin connection which intersect subsequent radial lateral fluid bores which intersect subsequent small fluid nozzle bores which then deliver fluid to the drill bit leading edge, and

(c) wherein on top of the drill bit threaded pin connection a pulse turbine unit is placed which has an inner bore with angled turbine blades whereby when fluid passes through said turbine blades said pulse turbine unit rotates, and

(d) wherein said pulse turbine unit has two or more outer perimeter slots that align with the outer angle fluid bores in the drill bit threaded pin connection whereby when said pulse turbine unit rotates the fluid is altematingly delivered and pulsed to one or more of said drill bit outer angle fluid bores and subsequent intersecting radial lateral fluid bores and subsequent small fluid nozzle bores for delivery to the drill bit leading edge, and (e) wherein said drill bit has one radially oriented slot opening onto the bottom exterior wherein a replaceable cutter blade is inserted into said slot and affixed to said body by one or more vertical pins and one or more horizontal pins or similar retention devices and wherein a second cutter blade can be placed over said first cutter blade in a slot position perpendicular to and interlocking said first cutter blade and affixed to said body by one or more vertical pins and one or more horizontal pins or similar retention devices.

2. In an apparatus according to claim 1 wherein said pulse turbine unit on its bottom has a small diameter circular groove and a larger diameter circular groove to match the location of ball bearings or similar rotational bearings located on the top of the drill bit threaded pin connection, and wherein said pulse turbine unit on its top has a small diameter deep circular groove and a larger diameter deep circular groove wherein respectively a small ring bearing and large ring bearing are placed in said groove on top of small springs which provide a rotatable bearing which is movable vertically to provide a tight fit or seal against the preceding high pressure downhole pump or other downhole equipment, and

3. In an apparatus according to claim 1 wherein the bottom face of the drill bit has roller discs or a similar cutting structure of hardened material welded, brazed or otherwise attached to said bottom face aligned and coinciding with the kerf line location or rotational circular line of the fluid nozzle bores to assist in cleaning and kerfing the rock or material to be cut, and

4. In an apparatus according to claim 1 wherein some of the small fluid nozzle bores are paired and angled toward each other at their discharge points to provide drilling fluid to intersect outside and near the bottom face of the drill bit, and

5. In an apparatus according to claim 1 wherein one or more small pressure pistons within the replaceable blades pushes against the drill bit body when fluid is forced through the blade lateral fluid bore whereby the blade is more tightly maintained in its blade slot against the drill bit body, and

6. In an apparatus according to claim 4 wherein said pulse turbine unit on its bottom has a small diameter circular groove and a larger diameter circular groove to match the location of ball bearings or similar rotational bearings located on the top of the drill bit threaded pin connection, and wherein said pulse turbine unit on its top has a small diameter deep circular groove and a larger diameter deep circular groove wherein respectively a small ring bearing and large ring bearing are placed in said groove on top of small springs which provide a rotatable bearing which is movable vertically to provide a tight fit or seal against the preceding high pressure downhole pump or preceding drill string, and

7. In an apparatus according to claim 4 wherein the bottom face of the drill bit has roller discs or a similar cutting structure of hardened material welded, brazed or otherwise attached to said bottom face aligned and coinciding with the kerf line location or rotational circular line of the fluid nozzle bores to assist in cleaning and kerfing the rock or material to be cut, and

8. In an apparatus according to claim 4 wherein one or more small pressure pistons within the replaceable blades pushes against the drill bit body when fluid is forced through the blade lateral fluid bore whereby the blade is more tightly maintained in its blade slot against the drill bit body, and

9. A drill bit and pulse turbine unit apparatus which can receive drilling fluids from a preceding high pressure downhole pump or preceding drill string at two or more distinct and separate pressures and provides that said drilling fluids travel through the drill bit in two or more distinct and separate paths of two or more internal fluid bores and subsequent distinct and separate discharge ports to the rock or material being cut comprising:

(d) wherein said pulse turbine unit has two or more outer perimeter slots that align with the outer angle fluid bores in the drill bit threaded pin connection whereby when said pulse turbine unit rotates the fluid is altematingly delivered and pulsed to one or more of said drill bit outer angle fluid bores and subsequent intersecting radial lateral fluid bores and subsequent small fluid nozzle bores for delivery to the drill bit leading edge, and

subsequent small fluid nozzle bores for delivery to the drill bit leading edge, and (e) wherein said drill bit has one radially oriented slot opening onto the bottom exterior wherein a replaceable cutter blade is inserted into said slot and affixed to said body by one or more vertical pins and one or more horizontal pins or similar retention devices and wherein a second cutter blade can be placed over said first cutter blade in a slot position perpendicular to and interlocking said first cutter blade and affixed to said body by one or more vertical pins and one or more horizontal pins or similar retention devices.

10. In an apparatus according to claim 9 wherein said pulse turbine unit on its bottom has a small diameter circular groove and a larger diameter circular groove to match the location of ball bearings or similar rotational bearings located on the top of the drill bit pin connection, and wherein said pulse turbine unit on its top has a small diameter deep circular groove and a larger diameter deep circular groove wherein respectively a small ring bearing and large ring bearing are placed in said groove on top of small springs which provide a rotatable bearing which is movable vertically to provide a tight fit or seal against the preceding high pressure downhole pump, or preceding drill string, and

11. In an apparatus according to claim 9 wherein the bottom face of the drill bit has roller discs or a similar cutting structure of hardened material welded, brazed or otherwise attached to said bottom face aligned and coinciding with the kerf line location or rotational circular line of the fluid nozzle bores to assist in cleaning and kerfing the rock or material to be cut, and

12. In an apparatus according to claim 9 wherein some of the small fluid nozzle bores are paired and angled toward each other at their discharge points to provide drilling fluid to intersect outside and near the bottom face of the drill bit, and

13. In an apparatus according to claim 9 wherein one or more small pressure pistons within the replaceable blades pushes against the drill bit body when fluid is forced through the blade lateral fluid bore whereby the blade is more tightly maintained in its blade slot against the drill bit body, and

14. In an apparatus according to claim 12 wherein said pulse turbine unit on its bottom has a small diameter circular groove and a larger diameter circular groove to match the location of ball bearings or similar rotational bearings located on the top of the drill bit pin connection, and wherein said pulse turbine unit on its top has a small diameter deep circular groove and a larger diameter deep circular groove wherein respectively a small ring bearing and large ring bearing are placed in said groove on top of small springs which provide a rotatable bearing which is movable vertically to provide a tight fit or seal against the preceding high pressure downhole pump or preceding drill string, and

15. In an apparatus according to claim 12 wherein the bottom face of the drill bit has roller discs or a similar cutting structure of hardened material welded, brazed or otherwise attached to said bottom face aligned and coinciding with the kerf line location or rotational circular line of the fluid nozzle bores to assist in cleaning and kerfing the rock or material to be cut, and

16. In an apparatus according to claim 12 wherein one or more small pressure pistons within the replaceable blades pushes against the drill bit body when fluid is forced through the blade lateral fluid bore whereby the blade is more tightly maintained in its blade slot against the drill bit body, and

17. A drill bit and pulse turbine unit apparatus which can receive from a preceding high pressure downhole pump or preceding drill string, two or more different types of drilling fluid such as a light weight drilling fluid and a heavy weight drilling fluid or a drilling fluid with laden abrasives and a drilling fluid with no laden abrasives whereby said different types of drilling fluids travel through the drill bit in two or more distinct and separate paths of two or more internal fluid bores to be delivered at subsequent distinct and separate discharge ports to the rock or material being cut comprising:

(c) wherein on the top of the drill bit threaded pin connection a pulse turbine unit is placed on top of the drill bit pin connection which has an inner bore with angled turbine blades whereby when fluid passes through said turbine blades said pulse turbine unit rotates, and

18. In an apparatus according to claim 17 wherein said pulse turbine unit on its bottom has a small diameter circular groove and a larger diameter circular groove to match the location of ball bearings or similar rotational bearings located on the top of the drill bit pin connection, and wherein said pulse turbine unit on its top has a small diameter deep circular groove and a larger diameter deep circular groove wherein respectively a small ring bearing and large ring bearing are placed in said groove on top of small springs which provide a rotatable bearing which is movable vertically to provide a tight fit or seal against the preceding high pressure downhole pump or preceding drill string, and

19. In an apparatus according to claim 17 wherein the bottom face of the drill bit has roller discs or a similar cutting structure of hardened material welded, brazed or otherwise attached to said bottom face aligned and coinciding with the kerf line location or rotational circular line of the fluid nozzle bores to assist in cleaning and kerfing the rock or material to be cut.

20. In an apparatus according to claim 17 wherein some of the small fluid nozzle bores are paired and angled toward each other at their discharge points to provide drilling fluid to intersect outside and near the bottom face of the drill bit, and

21. In an apparatus according to claim 17 wherein one or more small pressure pistons within the replaceable blades pushes against the drill bit body when fluid is forced through the blade lateral fluid bore whereby the blade is more tightly maintained in its blade slot against the drill bit body, and

22. In an apparatus according to claim 20 wherein said pulse turbine unit on its bottom has a small diameter circular groove and a larger diameter circular groove to match the location of ball bearings or similar rotational bearings located on the top of the drill bit pin connection, and wherein said pulse turbine unit on its top has a small diameter deep circular groove and a larger diameter deep circular groove wherein respectively a small ring bearing and large ring bearing are placed in said groove on top of small springs which provide a rotatable bearing which is movable vertically to provide a tight fit or seal against the preceding high pressure downhole pump or preceding drill string, and

23. In an apparatus according to claim 20 wherein the bottom face of the drill bit has roller discs or a similar cutting structure of hardened material welded, brazed or otherwise attached to said bottom face aligned and coinciding with the kerf line location or rotational circular line of the fluid nozzle bores to assist in cleaning and kerfing the rock or material to be cut.

24. In an apparatus according to claim 20 wherein one or more small pressure pistons within the replaceable blades pushes against the drill bit body when fluid is forced through the blade lateral fluid bore whereby the blade is more tightly maintained in its blade slot against the drill bit body.