EXTENDED REACH DRILLING APPARATUS & METHOD
A method for drilling a well in a formation including inserting a thruster, a first conduit, and a drill bit into a wellbore lined with a previous casing and applying a force to the first conduit with the thruster so that the thruster grips onto the previous casing.
The present application claims the benefit of pending U.S. Provisional Patent Application Ser. No. 60/731,988 filed Oct. 27, 2005 the entire disclosure of which is hereby incorporated by reference.
FIELD OF INVENTION The present invention relates to an apparatus and method for drilling an extended reach well in a formation. BACKGROUNDIn the production of hydrocarbon fluid from an earth formation, wellbores are drilled to provide a conduit for hydrocarbon fluid to flow from a subterranean reservoir to a production facility at the surface. The ability to drill longer and deeper wells at inclined angles (referred to as extended reach drilling or ERD) is becoming increasingly important to the oil and gas industry. An ERD well is generally defined as a well with a throw ratio of approximately 2:1 where the throw ratio is the ratio of horizontal depth to true vertical depth (TVD). Some extended reach wells (characterized as ultra ERD wells) may have throw ratios as high as 6:1.
Traditionally wellbores are formed in two phases. In the first phase, a drill string (or drill pipe) with a drill bit attached to the lower end is rotated by a kelly or rotary table located at the surface. As the drill bit creates a hole in the earth, drilling mud is circulated through the annular space between the drill string and the wellbore wall to cool the bit and transport cuttings (rock chips from drilling) to the surface. In the next phase, the drill string and bit are removed and the wellbore is lined with a string of steel pipe known as casing. The casing serves to stabilize the newly formed wellbore and facilitate the isolation of certain areas of the wellbore adjacent to the hydrocarbon bearing formations. Once the casing is cemented in the wellbore, a smaller bit is inserted through the casing and used to drill deeper into the earth. This process is then repeated and numerous sections of casing are installed until the desired depth is reached. When the well is complete, the entire string of casing resembles an extended, inverted telescope.
To reduce costs and drilling time, a process known as “drilling with casing” is often employed. This process involves attaching the drill bit to the same string of tubulars that will be used to line the wellbore. Because the same string is used, both phases of the wellbore formation can be completed in a single trip. However, the traditional nested arrangement of casing in a well causes the available diameter for the production of hydrocarbon fluid to decrease with depth in a stepwise fashion. This becomes a technical and economic problem for deep wells with many separate casings because drilling a small diameter deep hole becomes very challenging. To overcome this problem, the oil and gas industry has begun to experiment with new drilling and casing techniques that involve radially expanding individual casing strings as they are installed in the well in order to maximize the available diameter. One such technique is described in WO 2004/097168 A1, which is herein incorporated by reference. This technique known as “expandable” technology, eliminates the aforementioned telescoping effect, and may enable the drilling of a “monodiameter well,” a well in which every joint of casing used to line the wellbore has the same diameter.
Another recent development is the replacement of conventional drill pipe with “coiled tubing.” Whereas conventional drill pipe is assembled from relatively short rigid lengths of pipe, coiled tubing is a single strand of flexible pipe that is capable of handling a drilling assembly. A downhole drilling motor is used to create the mechanical energy necessary to rotate the drill bit and a tractor device that grips onto the interior of the wellbore maintains the proper amount of weight on bit and holds the reactive torque from the motor.
Even with these recent advancements in drilling technology, operators still encounter challenges drilling and running completions in extended reach wells. One major limitation is overcoming the friction incurred by the drill string rotating and sliding on the casing or formation. Frictional losses can reduce the weight on bit so much that it is impossible to drill with a reasonable penetration rate. Sufficient weight on bit is required to force the drill bit into the formation. Thus, the maximum drilling depth for an ERD well is often limited by the weight on bit, torque, or resistance of the drill string.
In addition to the frictional problem, disposal of cuttings and steering also limit drilling of ERD wells. Because ERD wells are so deep and long, cleaning the cuttings from the drill out of the hole poses a challenge. The need to steer the drill bit through three dimensional rock formations is also costly and time-consuming because the operator is often required to trip out of the hole multiple times to replace or change equipment.
US Pat. No. 6,467,557 B1 discloses a means to overcome the challenges associated with extended reach drilling using a rotary long reach drilling assembly. The tool described comprises an elongated conduit extending through a bore, a drill bit for being rotated to drill the bore, a 3D steering tool on the conduit for steering the bit, and a tractor on the conduit for applying force to the bit. The tractor includes a gripper which can assume a first position that engages an inner surface of the bore and limits movement of the gripper relative to the inner surface. The gripper can also assume a second position that permits substantially free relative movement between the gripper and the inner surface of the bore. A propulsion assembly moves the tractor with respect to the gripper while the gripper position is in the first position.
WO9909290 discloses an extended reach drilling system for drilling a borehole in an underground formation. The ERD system comprises a drill bit, a motor for driving the drill bit, a drill-pipe to surface, a hydraulic cylinder/piston arrangement for providing the required weight on bit, the drill-pipe being coupled to a selected one of the cylinder and the piston of said cylinder/piston arrangement by swivel means allowing rotation of the drill pipe relative to one of the cylinder or the piston, the drill bit being coupled to the other one of the cylinder and the piston, and locking means for locking said selected one of the cylinder and the piston against the borehole wall, the locking means being operable between an engaged and a disengaged position.
WO9708418 discloses a method and apparatus for propelling a tool having a body through a passage. The tool includes a gripper including at least a gripper portion, which can assume a first position that engages an inner surface of the passage and limits relative movement of the gripper portion relative to the inner surface. The gripper portion can also assume a second position that permits substantially free relative movement between the gripper portion and the inner surface of the passage. The tool includes a propulsion assembly for selectively continuously moving the body of the tool with respect to the gripper portion while the gripper portion is in the first position.
There are several opportunities for improving existing drilling systems to overcome the challenges associated with extended reach wells. First, there is an opportunity to overcome the problems associated with frictional losses and maintaining weight on bit. Known systems may encounter difficulty achieving the penetration rate necessary to drill extended reach wells. Although tractors and other gripping devices apply some additional force to the drill bit, a tractor's grip on the inner surface of the bore may be insufficient to overcome the frictional losses especially if a rotary system is used. In addition to the problem associated with frictional loss, there is also an opportunity to address the telescoping problem posed by conventional casing methods. Generally, the ability to drill a deep well is limited by the available diameter in the deepest segment of the nested casing. Maximizing the diameter of this segment of casing would enable the operator to drill deeper extended reach wells.
SUMMARY OF THE INVENTIONThe present inventions include a method for drilling a well in a formation comprising inserting a thruster, a first conduit, and a drill bit into a wellbore lined with a previous casing and applying a force to the first conduit with the thruster wherein the thruster grips onto the previous casing.
The present inventions include an apparatus for drilling a well in a formation through a wellbore lined with a previous casing comprising a drilling assembly and a thruster connectable to the drilling assembly; wherein the thruster is capable of gripping onto the previous casing and providing a force to the drilling assembly.
The present inventions include a method for drilling a well in a formation comprising providing a wellbore lined with a previous casing, inserting a first drilling assembly comprising a drill bit at a distal end, a first conduit connectable to the drill bit, and a thruster connectable to first conduit, gripping the previous casing with the thruster, and drilling a well.
BRIEF DESCRIPTION OF THE DRAWINGSThe present invention is better understood by reading the following description of non-limitative embodiments with reference to the attached drawings, wherein like parts of each of the figures are identified by the same reference characters, and which are briefly described as follows:
Referring to
In operation, the drilling assembly (comprising first conduit 104, drill bit 105, and thruster 106) is inserted into wellbore 101. In the embodiment shown, drill pipe 107 is used to perform this function; however, other oilfield equipment (e.g. coiled tubing) may be used instead. After the drilling assembly is inserted, thruster 106 applies a force to first conduit 104 causing drill bit 105 to drill a hole and extend wellbore 101. Thruster 106 provides the necessary weight on bit for penetration by gripping onto previous casing 103. The torque required to rotate drill bit 105 may be transferred by first conduit 104. Although it is shown as a liner in this embodiment, first conduit 104 may also be drilling casing or other oilfield equipment. It is also possible to insert a drill pipe inside the liner to transmit the torque to drill bit 105.
Once wellbore 101 is extended, first conduit 104 is removed from the drilling assembly and hung against previous casing 103. First conduit 104 is optionally secured in place by expansion, cementing, or any other method. Drill pipe 107 is then used to remove the drilling assembly. A new drilling assembly is lowered into wellbore 101 comprising drill bit 105, thruster 106, and second conduit (not shown). The steps are then repeated until the desired depth is reached.
Turning to
In operation, after drilling assembly 204 is inserted into wellbore 201, the torque required to drive drill bit 208 is provided by drill motor 211. The torque is transferred via the liner or via drill pipe or coiled tubing inserted in the liner. Thruster 205 applies a force to liner 206 causing drill bit 208 to drill a hole and extend wellbore 201 and holds the reactive torque from the drill motor. Thruster 205 provides the necessary weight on bit for penetration by gripping onto previous casing 203.
Once wellbore 201 is extended, drilling casing 206 is removed from the drilling assembly and hung against previous casing 203. Drilling casing 206 is then expanded using expander 212. Optionally drilling casing 206 may be expanded against formation 202. Drilling casing 206 may also be expanded to be the same diameter as previous casing 203; it may also be expanded so that it has a smaller diameter. Preferably drilling casing 206 is expanded so that its outer diameter is substantially equal to the inner diameter of previous casing 203. Expander 212 may be a pig, cone, rotary expansion device, cyclic expansion device or any other expansion device. After expansion, drilling casing 206 is then optionally cemented in place. A new drilling assembly is lowered into wellbore 201 the steps are then repeated until the desired depth is reached. The subsequent drilling casings may each be expanded so that the wellbore is monodiameter.
Those of skill in the art will appreciate that many modifications and variations are possible in terms of the disclosed embodiments, configurations, materials, and methods without departing from their spirit and scope. Accordingly, the scope of the claims appended hereafter and their functional equivalents should not be limited by particular embodiments described and illustrated herein, as these are merely exemplary in nature.
Claims
1. A method for drilling a well in a formation comprising:
- inserting a thruster, a first conduit, and a drill bit into a wellbore lined with a previous casing; and
- applying a force to the first conduit with the thruster wherein the thruster grips onto the previous casing.
2. The method of claim 1 further comprising forming a hole in the formation;
- wherein the diameter of the hole is larger than the diameter of the first drilling casing.
3. The method of claim 2 further comprising:
- hanging the first conduit against the previous casing;
- expanding at least a portion of the first conduit into contact with an interior surface of the previous casing;
- securing the first conduit; and
- removing the thruster and the drill bit from the wellbore.
4. The method of claim 3 further comprising:
- inserting the thruster, a second conduit, and the drill bit into the wellbore through the first conduit; and
- applying a force to the second first conduit with the thruster wherein the thruster grips onto the first conduit.
5. The method of claim 4 further comprising forming a hole in the formation;
- wherein the diameter of the hole is larger than the diameter of the second conduit.
6. The method of claim 5 further comprising:
- hanging the second conduit against the first conduit;
- expanding at least a portion of the second conduit into contact with an interior surface of the first conduit;
- securing the second conduit; and
- removing the thruster and the drill bit from the wellbore.
7. The method of claim 6 wherein the expanding is performed by a tool selected from the group consisting of pigs, cones, rotary expansion devices, and cyclic expansion devices.
8. The method of claim 7 wherein the securing is performed by cement.
9. The method of claim 8 wherein the first conduit is selected from the group consisting of drilling casing, liner, coiled tubing, and coiled tubing inserted in liner.
10. The method of claim 9 wherein the inserting and removing are performed by coiled tubing.
11. The method of claim 9 wherein the inserting and removing are performed by drill pipe.
12. The method of claim 9 wherein the inserting and removing are performed by liner.
13. An apparatus for drilling a well in a formation through a wellbore lined with a previous casing comprising a drilling assembly and a thruster connectable to the drilling assembly; wherein the thruster is capable of gripping onto the previous casing and providing a force to the drilling assembly.
14. The apparatus of claim 13 further comprising a conduit connecting the thruster to the drilling assembly.
15. The apparatus of claim 14 wherein the drilling assembly comprises:
- a drill bit,
- a mud pump;
- a motor;
- a steering assembly; and
- an expander means.
16. The apparatus of claim 15 wherein the conduit is selected from the group consisting of drilling casing, liner, coiled tubing and coiled tubing inserted in liner.
17. The apparatus of claim 16 further comprising coiled tubing capable of inserting the drilling assembly and the thruster into the wellbore.
18. The apparatus of claim 16 further comprising drill pipe capable of inserting the drilling assembly and the thruster into the wellbore.
19. The apparatus of claim 16 further comprising liner capable of inserting the drilling assembly and the thruster into the wellbore.
20. A method for drilling a well in a formation comprising:
- providing a wellbore lined with a previous casing;
- inserting a first drilling assembly comprising a drill bit at a distal end, a first conduit connectable to the drill bit, and a thruster connectable to first conduit;
- gripping the previous casing with the thruster; and
- drilling a well.
21. The method of claim 20 further comprising:
- providing a force to the first conduit with the thruster; and
- forming a hole with the drill bit.
22. The method of claim 21 further comprising:
- hanging the first conduit against the hole; and
- expanding the first conduit.
23. The method of claim 22 further comprising:
- inserting a second drilling assembly comprising the drill bit at a distal end,
- a second conduit connectable to the drill bit, and a thruster connectable to second conduit; and
- gripping the first conduit with the thruster.
24. The method of claim 23 further comprising:
- providing a force to the second conduit with the thruster; and
- forming a second hole with the drill bit.
25. The method of claim 24 further comprising:
- hanging the second conduit against the second hole; and
- expanding the second conduit.
26. The method of claim 25 wherein the first conduit and the second conduit are expanded to substantially the same diameter.
27. The method of claim 25 wherein the second conduit is expanded to a diameter smaller than the diameter of the first conduit.
28. The method of claim 25 wherein the second conduit is expanded so that an outer diameter of the second conduit is substantially equal to an inner diameter of the first conduit.
29. The method of claim 26 further comprising producing oil with the well.
30. The method of claim 27 further comprising producing oil with the well.
31. The method of claim 28 further comprising producing oil with the well.
Type: Application
Filed: Oct 25, 2006
Publication Date: May 17, 2007
Inventors: Andrei Fillipov (Houston, TX), Fu Hou (Missouri City, TX)
Application Number: 11/552,731
International Classification: E21B 7/00 (20060101);
