U.S. patent application number 15/588170 was filed with the patent office on 2017-08-24 for method and apparatus for steering a drill string and reaming well bore surfaces nearer the center of drift.
The applicant listed for this patent is Extreme Technologies, LLC. Invention is credited to Joseph Aschenbrenner, James D. Isenhour, Gilbert Troy Meier, James D. Osterloh, Joshua J. Smith.
Application Number | 20170241207 15/588170 |
Document ID | / |
Family ID | 59629676 |
Filed Date | 2017-08-24 |
United States Patent
Application |
20170241207 |
Kind Code |
A1 |
Meier; Gilbert Troy ; et
al. |
August 24, 2017 |
METHOD AND APPARATUS FOR STEERING A DRILL STRING AND REAMING WELL
BORE SURFACES NEARER THE CENTER OF DRIFT
Abstract
A steerable well bore drilling device and method are disclosed.
The steerable well bore drilling device comprises a drill string, a
bit coupled to the drill string, a drilling motor within the drill
string and driving the bit, and a pair of eccentric reamers coupled
to the drill string and positioned between the bit and the
motor.
Inventors: |
Meier; Gilbert Troy;
(Vernal, UT) ; Osterloh; James D.; (West Richland,
WA) ; Smith; Joshua J.; (Vernal, UT) ;
Aschenbrenner; Joseph; (Blackfoot, ID) ; Isenhour;
James D.; (Windsor, CO) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
Extreme Technologies, LLC |
Vernal |
UT |
US |
|
|
Family ID: |
59629676 |
Appl. No.: |
15/588170 |
Filed: |
May 5, 2017 |
Related U.S. Patent Documents
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Application
Number |
Filing Date |
Patent Number |
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14298484 |
Jun 6, 2014 |
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15588170 |
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|
13442316 |
Apr 9, 2012 |
8752649 |
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14298484 |
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|
13517870 |
Jun 14, 2012 |
8813877 |
|
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14298484 |
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13441230 |
Apr 6, 2012 |
8851205 |
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13517870 |
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13644218 |
Oct 3, 2012 |
9163460 |
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14298484 |
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61473587 |
Apr 8, 2011 |
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61473587 |
Apr 8, 2011 |
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61566079 |
Dec 2, 2011 |
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61542601 |
Oct 3, 2011 |
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Current U.S.
Class: |
1/1 |
Current CPC
Class: |
E21B 7/28 20130101; E21B
7/068 20130101; E21B 10/26 20130101 |
International
Class: |
E21B 7/28 20060101
E21B007/28; E21B 4/02 20060101 E21B004/02; E21B 10/26 20060101
E21B010/26; E21B 47/00 20060101 E21B047/00; E21B 7/06 20060101
E21B007/06 |
Claims
1. A steerable well bore drilling device, comprising: a drill
string; a bit coupled to the drill string; a drilling motor within
the drill string and driving the bit; and a pair of eccentric
reamers coupled to the drill string and positioned between the bit
and the motor.
2. The steerable well bore drilling device of claim 1, wherein the
pair of eccentric reamers are diametrically opposed about the drill
string.
3. The steerable well bore drilling device of claim 2, wherein each
eccentric reamer comprises multiple sets of cutting elements.
4. The steerable well bore drilling device of claim 3, wherein each
set of cutting elements are arranged along a spiral path along the
surface of each eccentric reamer.
5. The steerable well bore drilling device of claim 1, wherein the
eccentric reamers are identical.
6. The steerable well bore drilling device of claim 1, further
comprising a drive shaft coupling the bit to the drilling motor,
wherein the drive shaft passes through the pair of eccentric
reamers.
7. The steerable well bore drilling device of claim 1, further
comprising a measure while drilling device adapted to control the
rotational position of the pair of eccentric reamers about the
drill string to steer the drill string.
8. The steerable well bore drilling device of claim 1, wherein the
pair of eccentric reamers are coupled to the drill string at a
predetermined separation corresponding to a curvature of the well
bore.
9. The steerable well bore drilling device of claim 1, wherein the
pair of eccentric reamers extend from the drill string a
predetermined distance corresponding to a curvature of the well
bore.
10. The steerable well bore drilling device of claim 1, wherein the
pair of eccentric reamers provide a steering force when the drill
string is sliding and condition the well bore when the drill string
is rotating.
11. A method of drilling a well bore, comprising: coupling a bit to
a drill string; coupling a drilling motor positioned within the
drill string to the bit; coupling a pair of eccentric reamers to
the drill string, wherein the pair of eccentric reamers are
positioned between the bit and the motor; drilling the well bore;
steering the bit by sliding the drill string within the well bore;
and reaming the well bore by rotating the drill string.
12. The method of claim 11, wherein the pair of eccentric reamers
are diametrically opposed about the drill string.
13. The method of claim 12, wherein each eccentric reamer comprises
multiple sets of cutting elements.
14. The method of claim 13, wherein each set of cutting elements
are arranged along a spiral path along the surface of each
eccentric reamer.
15. The method of claim 11, wherein the eccentric reamers are
identical.
16. The method of claim 11, wherein the bit is coupled to the
drilling motor by a drive shaft that passes through the pair of
eccentric reamers.
17. The method of claim 11, further comprising controlling the
rotational position of the pair of eccentric reamers about the
drill string to steer the drill string with a measure while
drilling device.
18. The method of claim 11, further comprising separating the pair
of eccentric reamers along the drill string at a predetermined
distance corresponding to a curvature of the well bore.
19. The method of claim 11, wherein the pair of eccentric reamers
extend from the drill string a predetermined distance corresponding
to a curvature of the well bore.
20. The method of claim 11, wherein steering step and the reaming
step occur at separate times.
Description
REFERENCE TO RELATED APPLICATIONS
[0001] This application is a continuation-in-part of U.S.
non-provisional application Ser. No. 14/298,484, filed Jun. 6,
2014, entitled "METHOD AND APPARATUS FOR REAMING WELL BORE SURFACES
NEARER THE CENTER OF DRIFT, which is a continuation of U.S.
non-provisional application Ser. No. 13/442,316, filed Apr. 9,
2012, entitled "METHOD AND APPARATUS FOR REAMING WELL BORE SURFACES
NEARER THE CENTER OF DRIFT," which claims priority to U.S.
provisional application Ser. No. 61/473,587, filed Apr. 8, 2011,
entitled "METHOD AND APPARATUS FOR REAMING WELL BORE SURFACES
NEARER THE CENTER OF DRIFT." U.S. non-provisional application Ser.
No. 14/298,484 is also a continuation of U.S. non-provisional
application Ser. No. 13/517870, filed Jun. 14, 2012, entitled
"METHOD AND APPARATUS FOR REAMING WELL BORE SURFACES NEARER THE
CENTER OF DRIFT," which is a continuation of U.S. non-provisional
application Ser. No. 13/441230, filed Apr. 6, 2012, entitled
"METHOD AND APPARATUS FOR REAMING WELL BORE SURFACES NEARER THE
CENTER OF DRIFT," which claims priority to U.S. provisional
application Ser. No. 61/473,587, filed Apr. 8, 2011, entitled
"METHOD AND APPARATUS FOR REAMING WELL BORE SURFACES NEARER THE
CENTER OF DRIFT." U.S. non-provisional application Ser. No.
14/298,484 is also a continuation of U.S. non-provisional
application Ser. No. 13/644218, filed Oct. 3, 2012, entitled
"WELLBORE CONDITIONING SYSTEM," which claims priority to U.S.
provisional application Ser. Nos. 61/566,079, filed Dec. 3, 2011,
and 61/542601, filed Oct. 3, 2011, both entitled "WELLBORE
CONDITIONING SYSTEM." All of which are hereby specifically and
entirely incorporated by reference.
BACKGROUND
[0002] 1. Field of the Invention
[0003] The invention is directed to methods and devices for
drilling well bores, specifically, the invention is directed to
methods and devices for increasing the drift diameter and improving
the quality of a well bore.
[0004] 2. Background of the Invention
[0005] Horizontal, directional, S curve, and most vertical wells
are drilled with a bit driven by a bent housing downhole mud/air
motor, which can be orientated to build or drop angle and can turn
right or left. The drill string is orientated to point the bent
housing mud/air motor in the desired direction. This is commonly
called "sliding". Sliding forces the drill bit to navigate along
the desired path, with the rest of the drill string to
following.
[0006] Repeated correcting of the direction of the well bore causes
micro-ledging and "doglegs," inducing friction and drag between the
well bore and the bottom hole assembly and drill string. This
undesired friction causes several negatives on the drilling
process, including but not limited to: increasing torque and drag,
ineffective weighting on bit transfer, eccentric wearing on the
drill string and bottom hole assembly (BHA), increasing the number
of days to drill the well, drill string failures, limiting the
distance the well bore can be extended, and issues related to
inserting the production string into the well bore.
[0007] When a dogleg, spiraled path, or tortuous path is cut by a
drill bit, the relatively unobstructed passageway following the
center of the well bore may yield a smaller diameter than the well
bore itself. This relatively unobstructed passageway is sometimes
referred to as the "drift" and the nominal diameter of the
passageway is sometimes referred to as the "drift diameter". The
"drift" of a passageway is generally formed by well bore surfaces
forming the inside radii of curves along the path of the well bore.
Passage of pipe or tools through the relatively unobstructed drift
of the well bore is sometimes referred to as "drift" or
"drifting".
[0008] In general, to address these difficulties the drift diameter
has been enlarged with conventional reaming techniques by enlarging
the diameter of the entire well bore. Such reaming has been
completed as an additional step, after drilling of the well bore is
completed. Doing so has been necessary to avoid unacceptable
increases in torque and drag during drilling. Such additional
reaming runs add considerable expense and time to completion of the
well. Moreover, conventional reaming techniques frequently do not
improve the well bore, but instead simply enlarge certain areas of
the well bore.
[0009] During directional drilling of well bores, existing steering
methods include a physical bend or elbow in the drill string,
requiring a flex-shaft or jointed shaft, and do not condition the
bore. Additionally, one of the problems in steerable drilling is
that the elbow of current bent-motors moves around impacting the
well bore when drilling straight. These vibrations negatively
impact the drill bit and various electronic sensors in the BHA.
Rotational vibrations also come from the bit due to stick-slip
behavior.
[0010] Accordingly, a need exists for a reamer that reduces the
torque and drag on the drill string and produces closer to drift
well bore. A need also exists for a reamer capable of enlarging the
diameter of the well bore drift passageway, without needing to
enlarge the diameter of the entire well bore. Additionally, there
is a need for a method of steering a BHA during drilling that
eliminates vibrations.
SUMMARY OF THE INVENTION
[0011] The present invention overcomes the problems and
disadvantages associated with current strategies, designs and
provides new tools and methods of drilling well bores.
[0012] One embodiment of the invention is directed to a steerable
well bore drilling device. The device comprises a drill string, a
bit coupled to the drill string, a drilling motor within the drill
string and driving the bit, and a pair of eccentric reamers coupled
to the drill string and positioned between the bit and the
motor.
[0013] Preferably, the pair of eccentric reamers are diametrically
opposed about the drill string. In a preferred embodiment, each
eccentric reamer comprises multiple sets of cutting elements.
Preferably, each set of cutting elements are arranged along a
spiral path along the surface of each eccentric reamer. The
eccentric reamers are preferably identical. The drilling device
preferably further comprises a drive shaft coupling the bit to the
drilling motor, wherein the drive shaft passes through the pair of
eccentric reamers.
[0014] In a preferred embodiment, the drilling device further
comprises a measure while drilling device adapted to control the
rotational position of the pair of eccentric reamers about the
drill string to steer the drill string. Preferably, the pair of
eccentric reamers are coupled to the drill string at a
predetermined separation corresponding to a curvature of the well
bore. Preferably, the pair of eccentric reamers extend from the
drill string a predetermined distance corresponding to a curvature
of the well bore. The pair of eccentric reamers preferably provide
a steering force when the drill string is sliding and condition the
well bore when the drill string is rotating.
[0015] Another embodiment of the invention is directed to a method
of drilling a well bore. The method comprises the steps of coupling
a bit to a drill string, coupling a drilling motor positioned
within the drill string to the bit, coupling a pair of eccentric
reamers to the drill string, wherein the pair of eccentric reamers
are positioned between the bit and the motor, drilling the well
bore, steering the bit by sliding the drill string within the well
bore, and reaming the well bore by rotating the drill string.
[0016] In a preferred embodiment, the pair of eccentric reamers are
diametrically opposed about the drill string. Preferably, each
eccentric reamer comprises multiple sets of cutting elements. Each
set of cutting elements are preferably arranged along a spiral path
along the surface of each eccentric reamer. Preferably, the
eccentric reamers are identical. In a preferred embodiment, the bit
is coupled to the drilling motor by a drive shaft that passes
through the pair of eccentric reamers.
[0017] Preferably, the method further comprises controlling the
rotational position of the pair of eccentric reamers about the
drill string to steer the drill string with a measure while
drilling device. In a preferred embodiment, the method further
comprises separating the pair of eccentric reamers along the drill
string at a predetermined distance corresponding to a curvature of
the well bore. Preferably, the pair of eccentric reamers extend
from the drill string a predetermined distance corresponding to a
curvature of the well bore. Preferably, the steering step and the
reaming step occur at separate times.
[0018] Other embodiments and advantages of the invention are set
forth in part in the description, which follows, and in part, may
be obvious from this description, or may be learned from the
practice of the invention.
DESCRIPTION OF THE DRAWINGS
[0019] The invention is described in greater detail by way of
example only and with reference to the attached drawing, in
which:
[0020] FIG. 1 is a cross-section elevation of a horizontal well
bore.
[0021] FIG. 2 is a magnification of the down-hole portion of a top
reamer.
[0022] FIG. 3 illustrates the layout of cutting elements along a
down-hole portion of the bottom reamer.
[0023] FIGS. 4 and 5 illustrate the location and arrangement of
cutting elements on another embodiment of a reamer.
[0024] FIG. 6 is an embodiment of a reamer having four sets of
cutting elements.
[0025] FIG. 7 illustrates the arrangement of cutting elements on
each of four blades.
[0026] FIG. 8 illustrates the eccentricities of a reamer.
[0027] FIG. 9A-B illustrate an embodiment of the placement of the
reamers to steer a drill bit.
DESCRIPTION OF THE INVENTION
[0028] As embodied and broadly described, the disclosures herein
provide detailed embodiments of the invention. However, the
disclosed embodiments are merely exemplary of the invention that
may be embodied in various and alternative forms. Therefore, there
is no intent that specific structural and functional details should
be limiting, but rather the intention is that they provide a basis
for the claims and as a representative basis for teaching one
skilled in the art to variously employ the present invention.
[0029] A problem in the art capable of being solved by the
embodiments of the present invention is increasing the drift
diameter of a well bore. It has been surprisingly discovered that
providing diametrically opposed reamers allows for improved reaming
of well bores compared to conventional reamers. This is
accomplished, in one embodiment, by cutting away material primarily
forming surfaces nearer the center of the drift. Doing so reduces
applied power, applied torque and resulting drag compared to
conventional reamers that cut into all surfaces of the well
bore.
[0030] FIG. 1 depicts a cross-sectional view of a horizontal well
bore containing a reamer. The reamer has a bottom eccentric reamer
and a top eccentric reamer. The top and bottom eccentric reamers
are preferably of a similar construction and are preferably
diametrically opposed (i.e. at an angular displacement of
approximately 180.degree.)on the drill string. However other
angular displacements can be used, for example, 120.degree.,
150.degree., 210.degree., or 240.degree.. The diametrically opposed
positioning causes the cutting elements of each of the top and
bottom reamers to face approximately opposite directions. The
reamers are spaced apart and positioned to run behind the bottom
hole assembly (BHA). In one embodiment, for example, the eccentric
reamers are positioned within a range of approximately 100 to 150
feet from the BHA. Although two reamers are shown, a single reamer
or a larger number of reamers could be used in the alternative.
[0031] As shown, the drill string advances to the left as the well
is drilled. Each of the reamers preferably has an outermost radius,
generally in the area of its cutting elements, less than the inner
radius of the well bore. However, the outermost radius of each
reamer is preferably greater than the distance of the nearer
surfaces from the center of drift. The top and bottom reamers
preferably comprise a number of carbide or diamond cutting
elements, with each cutting element preferably having a circular
face generally facing the path of movement of the cutting element
relative to the well bore as the pipe string rotates and advances
down hole.
[0032] In FIG. 1, the bottom reamer begins to engage and cut a
surface nearer the center of drift off the well bore shown. As will
be appreciated, the bottom reamer, when rotated, cuts away portions
of the nearer surface of the well bore, while cutting substantially
less or none of the surface farther from the center of drift,
generally on the opposite side of the well. The top reamer performs
a similar function, reamer nearer the center of drift as the drill
string advances. Each reamer is preferably spaced from the BHA and
any other reamer to allow the centerline of the pipe string
adjacent the reamer to be offset from the center of the well bore
toward the center of drift or aligned with the center of drift.
[0033] FIG. 2 is a magnification of the down-hole portion of the
top reamer as the reamer advances to begin contact with a surface
of the well bore nearer the center of drift. As the reamer advances
and rotates, the existing hole is widened along the surface nearer
the center of drift, thereby widening the drift diameter of the
hole. It will be appreciated that the drill string and reamer
advance through the well bore along a path generally following the
center of drift and displaced from the center of the existing
hole.
[0034] FIG. 3 illustrates the layout of cutting structure along a
down-hole portion of the bottom reamer illustrated in FIG. 1. Four
sets of cutting elements, Sets A, B, C and D, are angularly
separated about the exterior of the bottom reamer. FIG. 3 shows the
position of the cutting elements of each Set as they pass the
bottom-most position shown in FIG. 1 when the bottom reamer
rotates. As the reamer rotates, Sets A, B, C and D pass the
bottom-most position in succession. The Sets of cutting elements
are arranged on a substantially circular surface having a center
eccentrically displaced from the center of rotation of the drill
string.
[0035] Each of the Sets of cutting elements are preferably arranged
along a spiral path along the surface of the bottom reamer, with
the down-hole cutting element leading as the reamer rotates (e.g.,
see FIG. 6). Sets A and B of the reamer cutting elements are
positioned to have outermost reamers forming a 61/8 inch diameter
path when the pipe string is rotated. The cutting elements of Set B
are preferably positioned to be rotated through the bottom-most
point of the bottom reamer between the rotational path of the
cutting elements of Set A. The cutting elements of Set C are
positioned to have outermost cutting faces forming a six inch
diameter when rotated, and are preferably positioned to be rotated
through the bottom-most point of the bottom reamer between the
rotational path of the cutting elements of Set B. The cutting
elements of Set D are positioned to have outermost reamers forming
a 57/8 inch diameter when rotated, and are preferably positioned to
be rotated through the bottom-most point of the bottom reamer
between the rotational path of the cutting elements of Set C.
[0036] FIGS. 4 and 5 illustrate the location and arrangement of
Sets 1, 2, 3 and 4 of cutting elements on another reamer
embodiment. Sets 1, 2, 3 and 4 of cutting elements are each
arranged to form a path of rotation having respective diameters of
55/8 inches, 6 inches, 61/8 inches and 61/8 inches. FIG. 5
illustrates the relative position of each of Sets 1, 2, 3 and 4 of
cutting elements. The cutting elements of Set 2 are preferably
positioned to be rotated through the bottom-most point of the
reamer between the rotational path of the cutting elements of Set
1. The cutting elements of Set 3 are preferably positioned to be
rotated through the bottom-most point of the reamer between the
rotational path of the cutting elements of Set 2. The cutting
elements of Set 4 are preferably positioned to be rotated through
the bottom-most point of the reamer between the rotational path of
the cutting elements of Set 3.
[0037] FIG. 6 is a photograph illustrating an embodiment of a
reamer having four sets of cutting element, with each set arranged
in a spiral orientation along a curved surface having a center
eccentric with respect to the drill pipe on which the reamer is
mounted. Adjacent and in front of each set of cutting elements is a
flow area formed in the surface of the reamer. The flow area allow
fluids, such as drilling mud for example, and cuttings to flow past
the reamer and exit away from the reamer's cutting structure during
operation.
[0038] The positioning and arrangement of Sets of cutting elements
may be rearranged to suit particular applications. For example, the
alignment of the Sets of cutting elements relative to the
centerline of the drill string, and the distance between the bottom
eccentric face and the top eccentric face along with the outer
diameter of the reamer body can be adjusted to each
application.
[0039] FIG. 7 depicts the blades of an embodiment of a reamer. The
reamer is designed to side-ream the "near" side of a directionally
near horizontal well bore that is crooked to straighten the crooks.
As the 5.25'' body of the reamer is pulled into the "near" side of
the crook the cut of the rotating reamer will be forced to rotate
about the body's threaded center and cut an increasingly larger
radius into just the "near" side of the crook without cutting the
opposite side. This cutting action will act to straighten the
crooked hole without following the original bore hole path.
[0040] FIG. 8 depicts the radial layout of an embodiment of a
reamer. The tops of the PDC cutters in each of the two eccentrics
of the reamer rotate about the threaded center of the tool and are
placed at increasing radii starting with the No. 1 cutter at
2.750'' R. The cutters' radii increase 0.018'' ever 5 degrees
through cutter No. 17, where the radii become constant at the
maximum of 3.062'' which is the 6.125'' maximum diameter of the
tool.
[0041] FIGS. 9A-B depict a preferred placement of the reamers 505A
and 505B within a drill string 500 that allows reamers 505A-B to
steer the drill bit 510 as well as condition the well bore. In a
preferred embodiment of the instant invention, reamers 505A-B are
positioned between drill bit 510 and drilling motor 515. However,
in other embodiments, one or both of reamers 505A-B may be
positioned on motor 515. Drilling motor 515 is preferably housed
within drill string 500 with a straight drive 525 shaft running
through reamers 505A-B and coupling drill bit 510 to motor 515,
thereby allowing the drill bit 510 to rotate without the reamers
505A-B turning.
[0042] Preferably, reamers 505A-B are positioned in front of the
drilling motor 515 to steer the bit 510 during a slide, or when the
drill string 500 is not rotating. Lateral forces on reamers 505A-B
during a slide preferably results in a lateral force on bit 510,
causing the assembly to turn as it drills forward (i.e. to the
right in the figures) and creating a curved bore hole. Preferably
the spacing between reamer 505A and 505B as well as the distance
reamers 505A-B are positioned behind drill bit 510 are matched to
the bit size and the desired turn build rate. For example, larger
reamers 505A-B will create a smaller diameter curve than smaller
reamers 505A-B. With larger reamers 505A-B, a larger drill bit 510
will be necessary accommodate the larger reamers. Additionally, by
placing the reamers further apart, a larger diameter curve can be
cut.
[0043] The rotational positioning of reamers 505A-B is preferably
monitored by a Measure While Drilling (MWD) device 520 positioned
behind reamers 505A-B within drill string 500. MWD 520 may have GPS
sensors, magnometers, thermometers, rotation sensors,
accelerometers, and/or other sensors to determine at least one of
the rotational speed of the drillstring, the smoothness of that
rotation, the type and severity of any vibration downhole, downhole
temperatures, torque and weight on bit, and mud flow volume. With
the data from MWD 520 reamers 505A-B can be rotated to provide the
proper direction of curvature for drilling the well bore.
Additionally, the path of the well bore may be corrected, adjusted,
and/or maintained based on data received from MWD 520. In other
embodiments, the positioning of the drill string may be determined
by calculating the twist in the drill string.
[0044] Preferably, once the slide is complete and the drill string
begins rotating, reamers 505A and 505B continue to ream and
condition the bore hole as described herein. Preferably, the bore
conditioning action benefits all of the drill string components
that follow reamers 505A-B by clearing rough spots and tight spots
in the well bore. Additionally, the cutting structures on reamers
505A-B preferably take rotational vibrations that come from the bit
and motor and transmit them to the well bore as cutting action. The
drill string between reamers 505A-B and the surface is preferably
protected from those vibrations. By putting the steering reamers
505A-B between the motor and bit, vibrations from both bent-motors
and the drill bit are addressed and the greatest possible amount of
the drill string is protected.
[0045] Other embodiments and uses of the invention will be apparent
to those skilled in the art from consideration of the specification
and practice of the invention disclosed herein. All references
cited herein, including all publications, U.S. and foreign patents
and patent applications, are specifically and entirely incorporated
by reference. It is intended that the specification and examples be
considered exemplary only with the true scope and spirit of the
invention indicated by the following claims. Furthermore, the term
"comprising of" includes the terms "consisting of" and "consisting
essentially of."
* * * * *