U.S. patent application number 15/678528 was filed with the patent office on 2017-12-28 for method and apparatus for reaming well bore surfaces nearer the center of drift.
The applicant listed for this patent is Extreme Technologies, LLC. Invention is credited to James D. Isenhour.
Application Number | 20170370157 15/678528 |
Document ID | / |
Family ID | 46965235 |
Filed Date | 2017-12-28 |
United States Patent
Application |
20170370157 |
Kind Code |
A1 |
Isenhour; James D. |
December 28, 2017 |
METHOD AND APPARATUS FOR REAMING WELL BORE SURFACES NEARER THE
CENTER OF DRIFT
Abstract
A well bore reaming device and method are disclosed. The device
includes a drill string, a bottom eccentric reamer coupled to the
drill string, and a top eccentric reamer coupled to the drill
string, wherein the bottom and top eccentric reamers have a
prearranged spacing and orientation.
Inventors: |
Isenhour; James D.;
(Windsor, CO) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
Extreme Technologies, LLC |
Vernal |
UT |
US |
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|
Family ID: |
46965235 |
Appl. No.: |
15/678528 |
Filed: |
August 16, 2017 |
Related U.S. Patent Documents
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Application
Number |
Filing Date |
Patent Number |
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14298484 |
Jun 6, 2014 |
9739092 |
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15678528 |
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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 10/42 20130101;
E21B 10/26 20130101; E21B 7/28 20130101 |
International
Class: |
E21B 7/28 20060101
E21B007/28; E21B 10/42 20060101 E21B010/42; E21B 10/26 20060101
E21B010/26 |
Claims
1. A well bore reaming device, comprising: a drill string; a bit
coupled to the drill string; a bottom hole assembly coupled to the
drill string; a bottom eccentric reamer coupled to the drill
string; and a top eccentric reamer coupled to the drill string;
wherein the bottom and top eccentric reamers are diametrically
opposed on the drill string.
2. The well bore reaming device of claim 1, further comprising
cutting elements coupled to the top eccentric reamer and to the
bottom eccentric reamer.
3. The well bore reaming device of claim 2, wherein the cutting
elements of the bottom eccentric reamer have a prearranged
orientation with respect to the orientation of the cutting elements
coupled to the top eccentric reamer.
4. The well bore reaming device of claim 2, wherein each eccentric
reamer comprises multiple sets of cutting elements.
5. The well bore reaming device of claim 4, wherein each set of
cutting elements are arranged along a spiral path along the surface
of each eccentric reamer.
6. The well bore reaming device of claim 4, further comprising a
flow area adjacent to each set of cutting elements.
7. The well bore reaming device of claim 1, wherein the bottom
eccentric reamer and the top eccentric reamer are spaced at a
prearranged position.
8. The well bore reaming device of claim 1, wherein the outermost
radius of the bottom and top eccentric reamers is less than the
innermost radius of the well bore and casing.
9. The well bore reaming device of claim 1, wherein the bottom
eccentric reamer is identical to the top eccentric reamer.
10. A method of reaming a well bore, comprising: providing a drill
string; providing drill bit coupled to the drill string; providing
a bottom hole assembly coupled to the drill string; providing
bottom eccentric reamer coupled to the drill string; providing top
eccentric reamer coupled to the drill string; positioning the top
and bottom eccentric reamers at diametrically opposed positions on
the drill string; and rotating the drill string in the well
bore.
11. The method of claim 10, further comprising coupling cutting
elements to the top eccentric reamer and to the bottom eccentric
reamer.
12. The method of claim 11, wherein the cutting elements coupled to
the bottom eccentric reamer have a prearranged orientation with
respect to the orientation of the cutting elements coupled to the
top eccentric reamer.
13. The method of claim 11, further comprising providing each
eccentric reamer with multiple sets of cutting elements.
14. The method of claim 13, further comprising arranging each set
of cutting elements along a spiral path along the surface of each
eccentric reamer.
15. The method of claim 13, further comprising providing a flow
area adjacent to each set of cutting elements.
16. The method of claim 10, further comprising spacing the bottom
eccentric reamer and the top eccentric reamer at a prearranged
spacing and orientation.
17. The method of claim 10, wherein the outermost radius of the
bottom and top eccentric reamers is less than the innermost radius
of the well bore and casing.
18. The method of claim 10, wherein the first eccentric reamer is
identical to the second eccentric reamer.
Description
REFERENCE TO RELATED APPLICATIONS
[0001] This application is a continuation 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. 13/517,870, 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. 13/441,230, 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. 13/644,218, filed Oct. 3, 2012, entitled
"WELLBORE CONDITIONING SYSTEM," which claims priority to U.S.
provisional application Ser. No. 61/566,079, filed Dec. 3, 2011,
and 61/542,601, filed Oct. 3, 2011, both entitled "WELLBORE
CONDITIONING SYSTEM." All of which are hereby specifically and
entirely incorporated by reference.
BACKGROUND
1. Field of the Invention
[0002] 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.
2. Background of the Invention
[0003] 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.
[0004] 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 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.
[0005] 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".
[0006] 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.
[0007] Accordingly, a need exists for a reamer that reduces the
torque and drag on the drill string and produces closer to drift
well bore.
[0008] 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.
SUMMARY OF THE INVENTION
[0009] The present invention overcomes the problems and
disadvantages associated with current strategies, designs and
provides new tools and methods of drilling well bores.
[0010] One embodiment of the invention is directed to a well bore
reaming device. The device comprises a drill string, a bit coupled
to the drill string, a bottom hole assembly coupled to the drill
string, a bottom eccentric reamer coupled to the drill string, and
a top eccentric reamer coupled to the drill string. The bottom and
top eccentric reamers are diametrically opposed on the drill
string.
[0011] In a preferred embodiment, the device further comprises
cutting elements coupled to the top eccentric reamer and to the
bottom eccentric reamer. Preferably, the cutting elements of the
bottom eccentric reamer have a prearranged orientation with respect
to the orientation of the cutting elements coupled to the top
eccentric reamer. Each eccentric reamer preferably comprises
multiple sets of cutting elements. In the preferred embodiment,
each set of cutting elements are arranged along a spiral path along
the surface of each eccentric reamer. In the preferred embodiment,
the device further comprises a flow area adjacent to each set of
cutting elements.
[0012] Preferably, the bottom eccentric reamer and the top
eccentric reamer are spaced at a prearranged position. The
outermost radius of the bottom and top eccentric reamers is
preferably less than the innermost radius of the well bore and
casing. In the preferred embodiment, the bottom eccentric reamer is
identical to the top eccentric reamer.
[0013] Another embodiment of the invention is directed to a method
of reaming a well bore. The method comprises providing a drill
string, providing drill bit coupled to the drill string, providing
a bottom hole assembly coupled to the drill string, providing
bottom eccentric reamer coupled to the drill string, providing top
eccentric reamer coupled to the drill string, positioning the top
and bottom eccentric reamers at diametrically opposed positions on
the drill string, and rotating the drill string in the well
bore.
[0014] The method preferably further comprises coupling cutting
elements to the top eccentric reamer and to the bottom eccentric
reamer. The cutting elements coupled to the bottom eccentric reamer
preferably have a prearranged orientation with respect to the
orientation of the cutting elements coupled to the top eccentric
reamer. Preferably, the method further comprises providing each
eccentric reamer with multiple sets of cutting elements.
[0015] In a preferred embodiment, the method further comprises
arranging each set of cutting elements along a spiral path along
the surface of each eccentric reamer. Preferably, the method
further comprises providing a flow area adjacent to each set of
cutting elements. The method, preferably, further comprises spacing
the bottom eccentric reamer and the top eccentric reamer at a
prearranged spacing and orientation. Preferably the outermost
radius of the bottom and top eccentric reamers is less than the
innermost radius of the well bore and casing. The first eccentric
reamer is preferably identical to the second eccentric reamer.
[0016] 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 DRAWING
[0017] The invention is described in greater detail by way of
example only and with reference to the attached drawing, in
which:
[0018] FIG. 1 is a cross-section elevation of a horizontal well
bore.
[0019] FIG. 2 is a magnification of the down-hole portion of a top
reamer.
[0020] FIG. 3 illustrates the layout of cutting elements along a
down-hole portion of the bottom reamer.
[0021] FIGS. 4 and 5 illustrate the location and arrangement of
cutting elements on another embodiment of a reamer.
[0022] FIG. 6 is an embodiment of a reamer having four sets of
cutting elements.
[0023] FIG. 7 illustrates the arrangement of cutting elements on
each of four blades.
[0024] FIG. 8 illustrates the eccentricities of a reamer.
DESCRIPTION OF THE INVENTION
[0025] 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.
[0026] 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.
[0027] 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.
[0028] 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.
[0029] 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.
[0030] 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.
[0031] 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.
[0032] 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.
[0033] 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.
[0034] 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.
[0035] 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.
[0036] 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.
[0037] 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.
[0038] 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."
* * * * *