U.S. patent application number 14/137344 was filed with the patent office on 2014-06-12 for nozzle selective perforating jet assembly.
This patent application is currently assigned to SCHLUMBERGER TECHNOLOGY CORPORATION. The applicant listed for this patent is SCHLUMBERGER TECHNOLOGY CORPORATION. Invention is credited to VICTOR LYASHKOV, MARK C. OETTLI.
Application Number | 20140158357 14/137344 |
Document ID | / |
Family ID | 50879699 |
Filed Date | 2014-06-12 |
United States Patent
Application |
20140158357 |
Kind Code |
A1 |
LYASHKOV; VICTOR ; et
al. |
June 12, 2014 |
NOZZLE SELECTIVE PERFORATING JET ASSEMBLY
Abstract
A downhole hydraulic tool employing multiple nozzles in a
selectable fashion from an oilfield surface. At least one of the
nozzles of the tool is equipped with a burst disk such that fluid
pressure directed from the surface may be utilized in activating
the nozzle. The pressure may be driven to exceed a predetermined
level for sake of the activating by way of sealing off access to
other nozzle(s) therebelow, for example, by way of standard ball
drop techniques. Thus, nozzle selectivity may be taken advantage of
when a first nozzle wears out without requiring time consuming
removal of the tool from the well for sake of remedial repairs or
replacement.
Inventors: |
LYASHKOV; VICTOR; (KATY,
TX) ; OETTLI; MARK C.; (RICHMOND, TX) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
SCHLUMBERGER TECHNOLOGY CORPORATION |
Sugar Land |
TX |
US |
|
|
Assignee: |
SCHLUMBERGER TECHNOLOGY
CORPORATION
Sugar Land
TX
|
Family ID: |
50879699 |
Appl. No.: |
14/137344 |
Filed: |
December 20, 2013 |
Related U.S. Patent Documents
|
|
|
|
|
|
Application
Number |
Filing Date |
Patent Number |
|
|
13667244 |
Nov 2, 2012 |
|
|
|
14137344 |
|
|
|
|
Current U.S.
Class: |
166/297 ;
166/308.1; 166/311; 166/373; 166/55; 175/424 |
Current CPC
Class: |
E21B 43/114 20130101;
E21B 34/063 20130101; E21B 7/18 20130101; E21B 43/26 20130101 |
Class at
Publication: |
166/297 ; 166/55;
166/373; 166/308.1; 166/311; 175/424 |
International
Class: |
E21B 43/114 20060101
E21B043/114; E21B 37/00 20060101 E21B037/00; E21B 7/18 20060101
E21B007/18; E21B 43/26 20060101 E21B043/26 |
Claims
1. A nozzle selective jetting tool comprising: a first jetting
nozzle at a first location of the tool for a first perforating
application; and a second jetting nozzle at a second location of
the tool for a subsequent perforating application, the second
jetting nozzle inoperable in a first configuration and operable in
a second configuration.
2. The tool of claim 1, further comprising a sealing location in
the central channel and between said nozzles for sealably
accommodating a projectile to close channel access to said first
nozzle and thereby configuring the second jetting nozzle in the
second configuration.
3. The tool of claim 2, wherein said sealing location is a valve
seat and the projectile is a ball.
4. The tool of claim 1, wherein the first perforating application
takes place at a pressure below that of the subsequent perforating
application.
5. The tool of claim 1, wherein said first nozzle is located
downhole of said second nozzle when the tool is positioned in a
well for the perforating applications.
6. The tool of claim 1, wherein said first configuration comprises
a burst disk coupled to said second nozzle for occluding access
thereto when pressure in a central channel of the tool is below a
predetermined level and said second configuration comprises a
ruptured burst disk when the pressure is above the predetermined
level.
7. A hydraulic bottom hole tool assembly for disposal in a well,
the assembly comprising: a jetting tool accommodating first and
second selectively employable nozzles, at least one of the nozzles
having selective hydraulic access thereto via a central channel of
the tool, wherein the selective access comprises one of a burst
disk and a soluble plug selectively occluding a flow path of the
nozzle; and a hydraulic line conveyance in fluid communication with
the central channel for directing an application through the other
nozzle when channel pressure therein is below the predetermined
level.
8. The assembly of claim 7, wherein the predetermined level is a
first predetermined level, the assembly further comprising a third
nozzle of said tool having another burst disk for allowing
hydraulic access thereto via the central channel when pressure
therein exceeds a second predetermined level greater than the first
predetermined level.
9. The assembly of claim 7, wherein said hydraulic line conveyance
is selected from a group consisting of coiled tubing and drill
pipe.
10. The assembly of claim 7, wherein the jetting tool is a
perforating tool for perforating a wall of the well.
11. The assembly of claim 10, wherein the wall is selected from a
group consisting of a casing, a liner and an open-hole
formation.
12. The assembly of claim 10, further comprising: an anchor
segment; and a reverse circulation segment.
13. The assembly of claim 12, wherein said anchor segment includes
a compression set anchor for anchoring the assembly in advance of
perforating.
14. The assembly of claim 10, further comprising a segment selected
from a group consisting of a swivel, an eccentric weight and an
isolation device.
15. A method of selectively employing jetting nozzles of a tool
disposed in a well at an oilfield, the method comprising:
performing a hydraulic application through a first nozzle at a
first location of the tool; hydraulically closing off access to the
first nozzle; opening a second nozzle at a second location of the
tool; and performing a second hydraulic application through the
second nozzle.
16. The method of claim 15, wherein opening comprises initiating a
ball drop technique from a surface of the oilfield to initiate said
closing and initiating a one of rupturing a burst disk and
dissolving a soluble plug.
17. The method of claim 15, wherein performing comprises performing
a perforating application directed at a wall of the well.
18. The method of claim 15, wherein at least one of the
applications is directed at a contingent emergent circumstance.
19. The method of claim 15, further comprising performing a
fracturing application through an assembly accommodating the tool
while the tool remains in the well.
20. The method of claim 15, further comprising performing a
cleanout application through an assembly accommodating the tool
while the tool remains in the well.
Description
CROSS-REFERENCE TO RELATED APPLICATION
[0001] The present application is a continuation-in-part which
claims priority under 35 U.S.C. .sctn.120 to U.S. patent
application Ser. No. 13/667,244 entitled Nozzle Selective
Perforating Jet Assembly, filed Nov. 2, 2012, the disclosure of
which is incorporated herein by reference in its entirety.
BACKGROUND
[0002] Exploring, drilling and completing hydrocarbon wells are
generally complicated, time consuming and ultimately very expensive
endeavors. As a result, over the years, well architecture has
become more sophisticated where appropriate in order to help
enhance access to underground hydrocarbon reserves. For example, as
opposed to wells of limited depth, it is not uncommon to find
hydrocarbon wells exceeding 30,000 feet in depth. Furthermore,
today's hydrocarbon wells often include deviated or horizontal
sections aimed at targeting particular underground reserves.
Indeed, at targeted formation locations, it is quite common for a
host of lateral legs and perforations to stem from the main
wellbore of the well toward a hydrocarbon reservoir into the
surrounding formation.
[0003] The above described perforations are formed and effectively
completed by a series of applications that begin with perforating
the well wall. So, for example, a casing defining the well may be
perforated by a series of projectiles directed at a targeted
location by way of a perforating gun. The gun itself may be
equipped with conventional charges for powering the projectiles,
with the application itself directed over standard wireline running
from the oilfield surface.
[0004] Perforating in this manner generally takes place in a zone
by zone fashion. That is, for sake of effective management,
production regions are divided into 20 to 40 or more zones, often
ranging from 3 feet to 50 feet or so apiece. Thus, over the course
of perforating a well, one zone is generally perforated, followed
by another, and so on. Once more, fully developing perforations,
for sake of enhancing recovery, require more than the initial
perforating via the perforating gun. Rather, follow-on fracturing,
or "fracing," and cleanout applications are also employed. The
fracturing involves pumping a fracturing fluid with solid proppant
particulate to the perforated locations to provide a degree of
channel stabilization. Subsequently, a cleanout application may be
employed to remove excess debris and particulate following the
perforating and fracturing.
[0005] Unfortunately, the step by step process of perforating,
fracturing and cleanout is performed on a zone by zone basis. So,
for example, following the perforating, the gun may be removed and
other fracturing and cleanout equipment lowered into position for
these subsequent applications. Afterwards, the entire process of
delivering and removing the various pieces of equipment may be
repeated for each and every zone. In fact, each zone may even be
isolated in advance of perforating and fracturing, thus adding
further layers of complexity and time to the overall process.
[0006] In order to streamline the above described process of
perforating and fracturing various downhole zones, coiled tubing
perforating equipment may be utilized. More specifically, a
hydraulically driven coiled tubing assembly may be outfitted with a
jetting tool and other features capable of performing each of the
various perforating, fracturing and cleanout functions. That is,
the coiled tubing may be advanced to the downhole perforating
location and the jetting tool employed to create the above
described perforations. However, rather than remove the coiled
tubing, it may be left in place as a fluid-based fracturing
application is directed through the coiled tubing to the recently
perforated zone. Indeed, the coiled tubing may remain in place to
serve as the platform for a subsequent circulating cleanout
application.
[0007] In theory, routing each of the various applications through
the same bottom hole assembly (BHA) at the end of the coiled tubing
would save a tremendous amount of time in terms of trips into the
well. That is, after one zone is finished, the coiled tubing may be
moved to the next zone and the same applications repeated through
the same BHA without the need to return to the oilfield
surface.
[0008] Unfortunately, the ability to fully take advantage of the
coiled tubing BHA for the different applications noted above is
limited by the nozzles of the jetting tool. As noted above, the BHA
is outfitted with a jetting tool which utilizes nozzles in
achieving the perforating at each zone. However, even the most
robust of nozzles is likely to be effective for no more than about
5 to 10 perforating applications. This is due to the naturally
occurring erosion which tends to enlarge the diameter of the
nozzles over repeated use. As a result, after perforating and
fracturing 5 to 10 zones or so, the entire coiled tubing is removed
from the well so that the nozzles and/or the entire jetting tool of
the BHA may be replaced. The assembly is then re-deployed for use
in subsequent zones, with this process repeated until all of the
perhaps 40 or more zones are fully perforated, fractured and
cleaned out. Thus, the ability to attain the full advantage leaving
the coiled tubing downhole throughout the perforating and
fracturing of the entire well remains elusive.
[0009] In some circumstances, efforts may be undertaken to extend
the effective life of the nozzle without removing the BHA. For
example, as later zones are perforated, operators at the oilfield
surface may increase pressure and flow rates in an attempt to
compensate for increasing diameter of the eroding nozzles. However,
such efforts are unlikely to extend nozzle life beyond an
additional perforating application or two. Thus, as a practical
matter, the operator is still likely to remove the entire BHA on
multiple occasions, adding significant time and expense to overall
perforating and fracturing operations.
SUMMARY
[0010] A nozzle selective perforating jet assembly is provided with
multiple nozzles. A first jetting nozzle may be situated at a given
location of the assembly for directing a first perforating
application. Further, another nozzle may be positioned at another
location for a subsequent perforating application. Once more, a
degradable member, a dissolvable member, a soluble member, and/or a
burst disk may be incorporated into the other nozzle for the
subsequent application so as to occlude fluid access thereto until
activation is desired for the other nozzle, such as when pressure
in the assembly is below a predetermined level.
BRIEF DESCRIPTION OF THE DRAWINGS
[0011] FIG. 1 is a front view of an embodiment of a nozzle
selective perforating jet assembly.
[0012] FIG. 2 is an overview of an oilfield having a well with the
nozzle selective perforating jet assembly of FIG. 1 disposed
therein.
[0013] FIG. 3A is an enlarged view of a jetting tool of the
assembly of FIG. 1 utilizing burst disk nozzles to form
perforations in the well of FIG. 2.
[0014] FIG. 3B is an enlarged view of a perforation of FIG. 3A
following a fracturing application with the assembly.
[0015] FIG. 3C is an enlarged view of the assembly of FIG. 3A
during a cleanout application in the well.
[0016] FIG. 4A is a perspective view of a first burst disk nozzle
of the jetting tool following significant perforating application
wear.
[0017] FIG. 4B is a perspective view of a second burst disk nozzle
of the jetting tool prior to use in a perforating application.
[0018] FIG. 4C is a cross sectional perspective view of an
embodiment of a nozzle used in abrasive jet perforating.
[0019] FIG. 4D is a cross sectional perspective view of the nozzle
of FIG. 4C with an embodiment of a soluble plug installed
therein.
[0020] FIG. 5A is a side cross-sectional view of the jetting tool
at the outset of downhole perforating applications.
[0021] FIG. 5B is a side cross-sectional view of the tool of FIG.
5A employing subsequent burst disk nozzle selection following
wear-out of prior nozzles.
[0022] FIG. 6 is a flow-chart summarizing an embodiment of
employing a nozzle selective perforating jet assembly in a
well.
DETAILED DESCRIPTION
[0023] Embodiments are described with reference to certain downhole
applications conveyed by way of coiled tubing. For example, coiled
tubing driven perforating, fracturing and cleanout operations are
detailed within a cased well. However, other types of applications,
tools and environments may be applicable. For example, embodiments
of jetting tools directed at open hole environments or liners of
lateral legs may be applicable. Additionally, conveyance for sake
of perforating may be achieved by way of drill pipe or other
tubular deployment. Regardless, the jetting tool includes multiple
nozzles which may be selectively actuated via burst disk mechanics
depending upon internal sealing and hydraulic pressure directed
through the tool.
[0024] Referring now to FIG. 1, a front view of an embodiment of a
nozzle selective perforating jet assembly 100 is shown. The
assembly 100 includes a jetting tool 101 outfitted with pairs of
nozzles 120, 140. With reference to a given nozzle set (e.g., 140),
the nozzles thereof appear roughly opposite one another at a
particular radial depth location of the tool 101. However, in other
embodiments such nozzles 140 may be staggered relative one another
in terms of depth location or even located at different radial
positions of the tool 101 other than 180.degree. directly opposite
one another.
[0025] The nozzles 120, 140 of the jetting tool 101 are configured
to guide perforating as detailed hereinbelow (see FIG. 3A). This
application involves driving an abrasive silica or sand-based
slurry through coiled tubing 110 of the assembly 100 and ultimately
directed through the nozzles 120, 140. More specifically regarding
the embodiments depicted, however, the nozzles 120, 140 may be
selectively employed through the use of burst disks 400 (see FIG.
4B). So, for example, with added reference to FIG. 4, in one
embodiment, the uphole nozzles 140 may be outfitted with burst
disks 400 to prevent jetting therethrough until a predetermined
pressure has been attained. That is, an operator may initially
direct perforating through the downhole nozzles 120 for a period of
uses. However, once a determination is made that such nozzles 120
may be damaged, for example, through natural wear, they may be
hydraulically shut off by way of a conventional ball drop or other
suitable technique. As such, pressure within the tool 100 may then
be driven up until burst disks 400 of the uphole nozzles 140 are
ruptured, at which time, these nozzles 140 may then be utilized for
subsequent perforating.
[0026] In an embodiment, the jetting tool 101 may be configured
with nozzles 142 having a soluble, dissolvable or degradable plug
402 disposed in a flow path 404 of the nozzle 142, such as by an
interference fit or the like (see FIGS. 4C and 4D). In such an
embodiment, instead of driving up pressure to burst disks 400, a
solvent or suitable liquid or gas capable of dissolving or
otherwise degrading the plug 402 may be pumped from the oilfield
surface through the coiled tubing 110 so that these nozzles 142 may
then be utilized for subsequent perforating.
[0027] The above described technique of nozzle selective
perforating allows the operator to use different sets of nozzles
120, 140 or 142 in succession. Indeed, in other embodiments,
nozzles at more than two depth locations may be successively
employed through the use of burst disks 400 as shown in FIG. 4B.
Thus, with added reference to FIG. 2, an operator at an oilfield
200 need not pull the entire assembly 100 out of the well 280 each
time a nozzle or nozzle set 120 wears out. Rather, the operator may
simply shut off the worn out nozzles 120 and move to the next
uphole set via burst disk actuation or via the pumping of a solvent
or other suitable liquid or gas as noted above and detailed further
below.
[0028] Continuing with reference to FIG. 1, the assembly 100
depicted includes a variety of additional features useful in
operating a perforating jetting tool 101. For example, an anchor
segment 175 may be provided for setting the assembly 100 in advance
of performing tasks such as the noted perforating via the tool 101.
In the embodiment shown, a compression set anchor is utilized,
though other setting mechanisms may be employed. Furthermore, where
oriented perforating is desired, such as within a lateral well
section, swivel 155 and eccentric weighted 160 segments may be
provided. Additionally, in the embodiment shown, a reverse
circulation segment 150 is depicted which may be utilized in
follow-on clean-out applications as detailed hereinbelow.
[0029] In addition to the above noted features, multi-cycle,
coupling, isolation and other standard bottom hole assembly
features may be incorporated into the assembly 100. Once more, the
features may be provided in multiple and rearranged configurations.
For example, multiple isolation devices may be utilized both above
and below the jetting tool 101 or alternatively a single isolation
device positioned above or below the tool 101.
[0030] Referring now to FIG. 2, an overview of an oilfield 200 is
depicted with a well 280 accommodating the nozzle selective
perforating jet assembly 100 of FIG. 1 therein. In this depiction,
the assembly 100 is shown advancing into a well 280 and traversing
various formation layers 290, 295 prior to perforation. For
example, as detailed further below with respect to FIGS. 3A-3C, the
tool 101 of the assembly 100 may be positioned adjacent casing 285
at one depth or another for sake of perforating and other
stimulation efforts. Indeed, the well 280 may be sectioned off into
various 3-50 foot or so `zones` adjacent the different layers 290,
295, with each zone slated to undergo a series of applications as
detailed with reference to FIGS. 3A-3C. Once more, the ability to
leave the assembly 100 and tool 101 downhole for a maximum of
different perforating applications at different zones may be of
significant advantage. More specifically, with reference to FIG. 2,
the tool 101 need not be pulled out of the well 280 and
disassembled past various equipment described below each time a set
of nozzles wears out. Rather, shut off of worn out nozzles and
burst disk activation of unused nozzles may be utilized as detailed
above to significant cost and time saving advantage.
[0031] In the embodiment of FIG. 2, the assembly 100 is conveyed by
way of coiled tubing 110 drawn from a reel 230 at the oilfield
surface 200. More specifically, a coiled tubing truck 220 is
positioned adjacent the well 280 for sake of providing the reel 230
along with a pump 225, control unit 227, mobile rig 240 and other
equipment. The rig 240 supports the transition of coiled tubing 110
from the reel 230 and through a gooseneck injector 250 and standard
pressure control equipment 275 at the well head 260. A variety of
hydraulic conveyances may be utilized in positioning the assembly
100 and jetting tool 101 in light of the hydraulic influx of
jetting fluids into the well 280 and subsequent cleanout. However,
the forcible injective advancement of coiled tubing 110 may be
particularly useful in circumstances where the well 280 is of
extended reach or includes horizontal or other tortuous
sections.
[0032] Referring now to FIGS. 3A-3C, enlarged views of the jetting
tool 101, and/or perforations 300 formed thereby into the adjacent
formation 290, are depicted. More specifically, FIG. 3A shows the
tool 101 of FIG. 1 utilizing nozzles 120 to form the noted
perforations 300 in the well 280 of FIG. 2. Subsequently, the
results of a fracturing application, with proppant supported
fibrous network 350, are depicted at the enlarged view of the
perforation 300 of FIG. 3B. Finally, a cleanout application
directed through the reverse circulation segment 150 of the tool
101 is shown at FIG. 3C. Notably, each of the referenced
applications regarding FIGS. 3A-3C may be run through the tool 101
without the need for its intervening removal to the oilfield
surface 200 (see FIG. 2).
[0033] Referring specifically now to FIG. 3A, the tool 101 may be
positioned as indicated. With position confirmation via the control
unit 227 of FIG. 2, the assembly 100 may be directed to anchor in
place utilizing the anchor segment 175 of FIG. 1. In one
embodiment, anchoring may be hydraulically achieved with a
monitored pressure indicative of achieving an anchored setting. By
the same token, in embodiments where zonal isolation is to be
employed, isolating devices at either side of the tool 101 may also
be hydraulically actuated. In either case, abrasive jetting through
the initial set of nozzles 120 may now ensue so as to form the
depicted perforations 300. Depending on the pressures utilized and
a host of other factors, the perforations 300 may reach between a
couple of inches to a foot or more into the formation 290.
[0034] In one embodiment, even the initial set of nozzles 120 are
of a burst disk variety. Thus, pressure utilized in the jetting
application depicted is sufficient for bursting disks incorporated
into these nozzles 120 so as to initiate perforating. For example,
in one embodiment, a 2,000-3,000 PSI differential is utilized in
jetting through these nozzles 120. As such, where they are equipped
with burst disks, a pressure rating of below about 2,000 PSI may be
utilized for these particular disks. Further, in circumstances
where the burst disk for one of the pair of nozzles 120 breaks but
the other does not, flow rate may be increased so as to overrun the
jetting of the open nozzle 120 and allow the other disk to break
for opening of the other nozzle 120. So long as pressure is kept
below the higher pressure rating of disks associated with uphole
nozzles 140, this technique may be utilized to ensure that both
downhole nozzles 120 are opened. Of course, as noted above and
detailed further below, the backup or uphole nozzles 140 are also
made available once the initial downhole nozzles 120 begin to show
wear from the initial described perforating.
[0035] Referring specifically now to FIG. 3B, an enlarged view of a
perforation 300 of FIG. 3A is shown following a fracturing
application with the assembly 100 of FIGS. 1 and 2. More
specifically, a proppant supported fibrous matrix 350 is shown
disbursed throughout the perforation 300 so as to support
subsequent hydrocarbon recovery therefrom. The fracturing
application may be similar to the noted perforating. However, the
fracturing fluid may be delivered at lower pressures and higher
volumes, with the fluid emerging from ports other than the nozzles
120, 140. Regardless, following perforating and fracture fluid
delivery, debris 375 in the area may then be cleaned out as
depicted in FIG. 3C. More specifically, a conventional cleanout may
be run through the reverse circulation segment 150 as noted above.
Thus, the assembly 100 may be repositioned with a subsequent well
zone undergoing a similar set of perforating, fracturing and
cleanout procedures.
[0036] Referring now to FIGS. 4A and 4B, with added reference to
FIG. 1, perspective views of nozzles 120, 140 are depicted. More
specifically, the downhole nozzle 120 is depicted following a
series of perforation applications which have inflicted a certain
natural degree of damage 401. The uphole nozzle 140, on the other
hand, remains in-tact and in an unused condition as detailed
further below. Such nozzles 120, 140 include a channel 410,
generally ranging between about 0.10 and 0.25 inches in diameter.
Further, both nozzles 120, 140 are equipped with an exposed cover
420 that transitions into a main body 475 and seal 450 coupled to a
cylinder housing 430 that surrounds the nozzle channel 410.
However, the uphole nozzle 140 is also outfitted with a burst disk
400 as detailed further below and uphole nozzle 140b may be
outfitted with a soluble plug 400b as detailed further below.
[0037] Continuing with specific reference to FIG. 4A, as sand-based
perforating fluids are jetted out of the nozzle channel 410,
erosion begins to take place at defining surfaces of this channel
410 and the nozzle cover 420. Indeed, even where durable
carbide-based materials are utilized, such erosion may be expected
after some period of use. Further, once begun, the degree of
erosion may increase exponentially with each successive perforating
application via the nozzle 120. Ultimately, the effectiveness of
the nozzle 120 for sake of perforating may be negligible. However,
as noted above, the unused uphole nozzle 140 remains incorporated
with the tool 101 (e.g., of FIG. 1).
[0038] Referring now to FIG. 4B, the downhole nozzle 140 is
equipped with a burst disk 400 as noted above and/or nozzle 142 is
equipped with a soluble plug 402, best seen in FIG. 4D. So, for
example, the interior of this nozzle 140 or 142 is not exposed to
jetting fluids. Thus, perforating-based wear at its interior
channel or flow path 404 or cover surface 420 is unseen as in the
case of the downhole nozzle 120 (e.g., at 401). By the same token,
however, this nozzle 140 or 142 is unavailable for use in abrasive
jetting for sake of perforating as detailed hereinabove.
Nevertheless, as detailed below, once the downhole nozzle 120 is
rendered ineffective as shown in FIG. 4A, it may be closed off and
the burst disk 400 of the uphole nozzle 140 ruptured, or the
soluble plug 402 of nozzle 142 may be dissolved or degraded such
that a new nozzle 140 or 142 is available for operations. More
specifically, the disk 400 may be of a predetermined pressure
rating. Therefore, rupturing of the disk 400 in this manner may be
a matter of applying a correspondingly predetermined pressure
through the tool 101 of FIG. 1. As such, the need to remove the
entire assembly 100 of FIGS. 1 and 2 in order to redress an
inoperable nozzle is obviated, thereby saving considerable downhole
time and expense.
[0039] Referring now to FIGS. 5A and 5B, side cross-sectional views
of the jetting tool 101 of FIGS. 1 and 2 are depicted. More
specifically, FIG. 5A is a view of the tool 101 at the outset of
perforating applications where fluid access to downhole nozzles 420
is available for sake of abrasive jetting. FIG. 5B, on the other
hand reveals closed off fluid access to these nozzles 420 via a
pressure technique that also results in the burst disk opening of
the uphole nozzles 420.
[0040] With more direct reference to FIG. 5A, the tool 101 includes
a central tool channel 580 that is in fluid communication with
coiled tubing 110 as depicted in FIGS. 1 and 2. In the embodiment
shown, a ball projectile 570 may be introduced to the channel 580
and pumped to an initial valve seat 567 as a conventional manner by
which to initiate perforating through initial nozzles 515 at an
initial depth 510. By the same token, depending on pressure through
the channel 580 perforating at the downhole depth 520 via downhole
nozzles 120 may also ensue.
[0041] Continuing with reference to FIG. 5A, uphole 140 or 142 and
further uphole 555 nozzles may remain sealed off via burst disks
400 or plug 402 as described hereinabove at FIGS. 4B and 4D,
respectively. For example, these uphole nozzles 140, 555 may be
outfitted with disks 400 having a rating that exceeds 3,000 PSI
whereas the perforating application taking place through the
downhole 120 and initial 515 nozzles occurs at a differential of
below about 2,500 PSI. In an embodiment, the upper nozzles 142 may
only be accessed after a solvent capable of dissolving or otherwise
degrading plug 402 to clear the flow path 404 has been added to the
environment where the plug 402 resides.
[0042] With specific reference now to FIG. 5B, the above noted
downhole 120 and initial 515 nozzles may wear out over the course
of successive perforating applications as detailed above.
Therefore, a subsequent projectile ball 575 of greater diameter
than the first 570 may be introduced into the channel 580. As
shown, the ball 575 is sized to sealably encounter a sealing
location of a subsequent valve seat 565 located between the uphole
140 and downhole 120 nozzles. Thus, once sealingly engaged with the
seat 565 damaged valves 120, 515 therebelow are effectively shut
off Once more, flow may be directed through the channel 580 such
that a pressure exceeding the predetermined amount, 3,000 PSI in
the example noted above, may be produced. As such, the uphole valve
140 may be burst open and utilized in continuing perforating
operations. In this manner, a new nozzle 140 is made available to
the tool 101 without the need for tool removal from the well 280
during ongoing operations (see FIG. 2). Once more, the providing of
a new nozzle 140 is done in a manner that does not require movement
or shifting of downhole tool components. This may be of particular
advantage where more abrasive perforating fluids are utilized which
may tend to inflict wear and sticking on such components. Referring
now to FIGS. 4C and 4D, the above noted downhole 120 and initial
515 nozzles may wear out over the course of successive perforating
applications as detailed above. Therefore, a solvent or other
suitable liquid or gas may be pumped through the worn out nozzles
120 or 515 that will leave sufficient solvent in the region of the
uphole nozzles 142 and plug 402 to dissolve the plug 402. After the
solvent has been pumped, a subsequent projectile ball 575 of
greater diameter than the first 570 may be introduced into the
channel 580. As shown, the ball 575 is sized to sealably encounter
a sealing location of a subsequent valve seat 565 located between
the uphole 142 and downhole 120 nozzles. Thus, once sealingly
engaged with the seat 565, the damaged tool 515 and nozzle 120
therebelow are effectively shut off. As such, the uphole valve 142
with the soluble plugs 402 now dissolved or degraded such that the
flow path 404 is clear may be utilized in continuing perforating
operations. In this manner, a new nozzle 142 is made available to
the tool 101 without the need for tool removal from the well 280
during ongoing operations (see FIG. 2). Once more, the providing of
a new nozzle 142 is done in a manner that does not require movement
or shifting of downhole tool components. This may be of particular
advantage where more abrasive perforating fluids are utilized which
may tend to inflict wear and sticking on such components.
[0043] The above detailed technique for equipping and utilizing
successive sets of nozzles 120, 140 may be continued to any
practical number of depths 510, 520, 540, 550. For example, as
shown in FIGS. 5A and 5B, a further uphole nozzle 555 is shown
which may be burst disk protected to a pressure of more than about
4,000 PSI. Furthermore, where multiple burst disk nozzles 140 are
positioned at roughly the same depth location for simultaneous use,
the bursting of multiple disks 400 may be operator ensured by
increasing flow rate through the channel 580 as necessary. For
example, where pressure feedback at surface is indicative of a
single burst where multiple bursts are called for at a given
location, flow rate may be increased as a manner of overrunning
burst capacity of the other nozzle's disk.
[0044] Referring now to FIG. 6, a flow-chart is depicted
summarizing an embodiment of employing a nozzle selective
perforating jet assembly in a well. More specifically upon
deployment into the well as indicated at 605, an initial series of
perforating applications may be run as indicated at 620. However,
upon wear at initial nozzles, they may be hydraulically sealed off
(see 635). Indeed, in embodiments hereinabove, the same techniques
for closing off the initial nozzle(s) may support increasing
pressure to burst a disk as noted at 650 or degrade or dissolve a
plug 402. Thus, subsequent nozzle(s) may be exposed for subsequent
perforating as indicated at 665. In addition to leaving the tool in
the well during the transition from a worn set of nozzles to a
fresh set, as indicated at 680 and 695, fracturing, cleanout and
other applications may also ensue via the same assembly
accommodating the tool without requirement of its removal from the
well.
[0045] An embodiment of a nozzle selective jetting tool comprises a
first jetting nozzle at a first location of the tool for a first
perforating application, a second jetting nozzle at a second
location of the tool for a subsequent perforating application, the
second jetting nozzle inoperable in a first configuration and
operable in a second configuration. In an embodiment, the tool
further comprises a sealing location in the central channel and
between the nozzles for sealably accommodating a projectile to
close channel access to the first nozzle and thereby configuring
the second jetting nozzle in the second configuration. The sealing
location may be a valve seat and the projectile may be a ball. In
an embodiment, the first perforating application takes place at a
pressure below that of the subsequent perforating application. In
an embodiment, the first nozzle is located downhole of the second
nozzle when the tool is positioned in a well for the perforating
applications.
[0046] The tool of claim 1 wherein the first configuration
comprises a burst disk coupled to the second nozzle for occluding
access thereto when pressure in a central channel of the tool is
below a predetermined level and the second configuration comprises
a ruptured burst disk when the pressure is above the predetermined
level.
[0047] An embodiment of a hydraulic bottom hole tool assembly for
disposal in a well, the assembly comprises a jetting tool
accommodating first and second selectively employable nozzles, at
least one of the nozzles having selective hydraulic access thereto
via a central channel of the tool, wherein the selective access
comprises one of a burst disk and a soluble plug selectively
occluding a flow path of the nozzle, and a hydraulic line
conveyance in fluid communication with the central channel for
directing an application through the other nozzle when channel
pressure therein is below the predetermined level. In an
embodiment, the predetermined level is a first predetermined level,
the assembly further comprising a third nozzle of the tool having
another burst disk for allowing hydraulic access thereto via the
central channel when pressure therein exceeds a second
predetermined level greater than the first predetermined level. In
an embodiment, the hydraulic line conveyance is selected from a
group consisting of coiled tubing and drill pipe. In an embodiment,
the jetting tool is a perforating tool for perforating a wall of
the well. The wall may be a casing, a liner or an open-hole
formation. In an embodiment, the assembly further comprises an
anchor segment and a reverse circulation segment. The anchor
segment may comprise a compression set anchor for anchoring the
assembly in advance of perforating. In an embodiment, the assembly
further comprises a segment selected from a group consisting of a
swivel, an eccentric weight and an isolation device.
[0048] In an embodiment, a method of selectively employing jetting
nozzles of a tool disposed in a well at an oilfield comprises
performing a hydraulic application through a first nozzle at a
first location of the tool, hydraulically closing off access to the
first nozzle, opening a second nozzle at a second location of the
tool, and performing a second hydraulic application through the
second nozzle. In an embodiment, opening may comprise initiating a
ball drop technique from a surface of the oilfield to initiate the
closing and initiating a one of rupturing a burst disk and
dissolving a soluble plug. In an embodiment, the applications are
perforating applications directed at a wall of the well. In an
embodiment, at least one of the applications is directed at a
contingent emergent circumstance. In an embodiment, the method
further comprises performing a fracturing application through an
assembly accommodating the tool while the tool remains in the well.
In an embodiment, the method further comprises performing a
cleanout application through an assembly accommodating the tool
while the tool remains in the well.
[0049] Embodiments described hereinabove allow for jetting tool
perforating applications in a manner that substantially extends the
life of the tool. More specifically, the tool need not be removed
and repaired after every 5 to 10 jetting perforating applications.
Indeed, any practical number of perforating applications may be
directed through the same jetting tool without requirement of
intervening remedial action. Such is limited only by the design
constraints employed such as varying burst pressure ratings, tool
channel and projectile ball diameters and other factors.
Regardless, operators need not attempt to ineffectively drive
pressures up to extend the nozzle life but rather are provided with
a viable technique for leaving the tool downhole while moving on
from a worn nozzle to a fresh one for subsequent perforating.
[0050] The preceding description has been presented with reference
to presently preferred embodiments. Persons skilled in the art and
technology to which these embodiments pertain will appreciate that
alterations and changes in the described structures and methods of
operation may be practiced without meaningfully departing from the
principle, and scope of these embodiments. For example, the burst
disk concepts and/or soluble plug concepts described herein may be
employed in a contingency fashion so as to allow operator directed
nozzle use in circumstances apart from perforating. These
circumstances may include unsticking a tool, introducing annular
circulation or dealing with a variety of other emergent
circumstances. Furthermore, the foregoing description should not be
read as pertaining only to the precise structures described and
shown in the accompanying drawings, but rather should be read as
consistent with and as support for the following claims, which are
to have their fullest and fairest scope.
* * * * *