Note : Les descriptions sont présentées dans la langue officielle dans laquelle elles ont été soumises.
CA 02816458 2013-05-23
WELL COMPLETION USING A PUMPABLE SEAT ASSEMBLY
INVENTORS: TSCHETTER, Sam and JAHANGIRI, Armin
ASSIGNEE: ENCANA CORPORATION
Field of the Invention
100011 The present invention relates generally to the field of vertical and
horizontal well
completion, and, more particularly, to a process for fracturing, stimulating
and producing a
wellbore without having to mill out and remove fracturing/bridge plugs and to
a pumpable seat
assembly for use with said process.
Background of the Invention
[0002] Oil and gas well are drilled to a depth in order to intersect a series
of formations or
zones which produce hydrocarbons. Often the drilled wells are cased with steel
casing pipe and
cemented to secure the casing in place. Hence, it is necessary to create a
flow path from these
cased producing zones to the surface of the wellbore. This is generally
accomplished by
stimulation processes such as fracturing using water, various chemicals and/or
proppants.
However, the steel and cement barrier needs to be first perforated with shaped
explosive charges
prior to fracturing the surrounding oil or gas reservoir.
100031 Depending on the number of producing zones in a particular reservoir,
usually several
elevation levels and/or lateral intervals will need to be fractured. Thus, it
is common in the
industry to use a temporary well completion plug which is generally set in the
bore of the steel
well casing with a setting tool just below the level or interval where the
perforation of the steel
and cement barrier and fracturing occurs. It is understood that these bridge
or "frac plugs" can
also be pumped down the well on an electric wireline, either by itself or in
combination with the
perforating gun assemblies. When the barrier is perforated, "frac fluids"
and/or sand are pumped
down to the perforations and into the reservoir to stimulate movement of the
oil or gas. Use of
the temporary plug prevents contamination of the already fractured levels
below.
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[0004] Interval isolation and fracturing or stimulation can be performed on
both vertical and
horizontal wells with multiple planned intervals, often with multiple
intervals and sometimes
greater than 25 intervals per well at varying depths including sometimes
greater than 6000
Meters Below Kelly Bushing (MKB). Bridge/frac plug technology for interval
isolation for frac
stimulation purposes is proven, effective, predictable and repeatable.
[00051 Unfortunately, once all of the zones have been stimulated, these
temporary plugs may
prevent the flow of oil or gas to the surface. Thus, traditionally, these
plugs need to be milled or
drilled out using a drill bit using jointed pipe or coiled tubing. However,
there are operational
risks associated with this process and, further, this is a time consuming and
costly procedure.
Furthermore, it has been found that frac plugs having even a minimal amount of
steel are
difficult to drill during removal and can damage the drill bit.
[0006] Coil tubing or jointed pipe intervention to mill out and remove the
plugs on extended
reach wells, e.g. lateral length exceeding 2500 m, is extremely costly,
unpredictable and
sometimes impossible due to metal to metal friction encountered sliding in the
casing, creating
what is known as coil tubing lock-up. In some cases, frac plugs that are not
reachable due to
friction lock up issues are left in the well (i.e., not milled out) and
intervals left behind these frac
plugs are expected to flow through a % inch hole in the center of the frac
plugs. Flow can
sometimes be restricted by the number of frac plugs which were not accessible
for mill-out due
to the friction lock encountered. In some cases operations are exposed to such
risks as sticking
the coil tubing or bottom-hole assembly (BHA) in the well, resulting in
fishing operations for
pipe recovery. Fishing operations can cost an operating company millions of
dollars depending
on difficulty and risk, in extreme cases wellbore have been lost due to
fishing operations and
associated costs.
[0007] Accordingly, there is a need in the art for a well completion process
and plug which
will allow the plug to behave like a frac plug for a temporary period of time
and then allow the
flow of gas and or oil from the reservoir up to the well head without the need
for drilling the plug
out.
Summary of the Invention
[00081 The present invention relates generally to a process and apparatus for
multiple interval
isolation of a horizontal or vertical well, where intervention such as
drilling out frac plugs is not
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necessary for well completions. Generally, pumpable seat assembly is provided,
which is a seat
and slip assembly that would be applicable to more than 80% of vertical and
horizontal
completions activity within the industry and that can be configured to fit all
casing sizes and
casing weights. In one embodiment, the pumpable seat assembly would be
deployed or pumped
on electric wireline down the well by itself or in combination with the
perforating guns to a
desired depth within the well. A standard setting tool would set the pumpable
seat assembly in
the casing and the wireline would then log on depth the guns and perforate the
interval at desired
depth and pull to surface.
[00091 In one aspect, a dissolvable member is provided. In one embodiment, the
dissolvable
member is a dissolvable ball which would be dropped by the service provider
into the well from
surface and then pumped downhole until the dissolvable ball lands on the
pumpable seat
assembly and provides isolation from the previous interval for frac
stimulation purposes. The
process can then be repeated a multiple number of times in the same wellbore
using additional
pumpable seat assemblies and dissolvable balls. Once the frac or stimulation
services are
completed, the dissolvable ball will dissolve and the well can be flowed on
production, or
equipped with production tubing, all without any wellbore intervention. It is
understood that the
term "dissolvable ball" includes any degradable or biodegradable ball.
[00010j In another embodiment, the dissolvable member is a dissolvable
valve (e.g.,
dissolvable poppet valve or dissolvable flapper/check valve) or a solid
dissolvable plug, which is
installed in the pumpable seat assembly and therefore the dissolvable member
would be would
be deployed or pumped downhole together with the pumpable valve assembly.
[00011] In another aspect, a pumpable seat assembly is provided having a
non-dissolvable
isolation device such as a non-dissolvable poppet valve or non-dissolvable
flapper.
[00012] In one aspect, the pumpable seat assembly has an inner diameter
that is equal to or
greater than about 1 inch. In one embodiment, the assembly has an inner
diameter of about 2
inches or larger. In another embodiment, the pumpable seat assembly has an
inner diameter that
is between about 1 inch to about 2 inches in diameter. By having a larger
inner diameter than
conventional frac plugs, once the dissolvable member has dissolved, the flow
would not be
restricted.
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1000131 In one aspect, the invention comprises a process for fracturing,
stimulating and
producing a wellbore having a plurality of oil or gas producing zones,
comprising:
introducing into the well a pumpable seat assembly comprising a generally
cylindrical
tube having an outer diameter and an inner diameter with an upper end forming
a ball seat;
setting the pumpable seat assembly below an oil or gas producing zone to be
produced;
introducing a dissolvable ball into the well, said dissolvable ball having a
sufficiently
large enough outer circumference so that it can sit on the ball seat and
temporarily restrict a flow
of fluids to the portion of the wellbore located below the pumpable seat
assembly;
fracturing the oil and gas producing zone to stimulate oil or gas production;
whereby the dissolvable ball is configured to dissolve within a predetermined
period of time so
that when it dissolves any oil or gas produced from zones below the pumpable
seat assembly can
flow through the cylindrical tube.
1000141 In one embodiment, the inner diameter of the cylindrical tube is
sufficient to
allow relatively unrestricted flow of oil or gas there through. In one
embodiment, the inner
diameter is equal to or greater than about 1 inch. In one embodiment, the
inner diameter is about
2 inches or larger. In another embodiment, the pumpable seat assembly has an
inner diameter
that is between about 1 inch to about 2 inches in diameter.
[00015] In another aspect, the pumpable seat assembly is provided for
temporarily sealing
a well casing, the pumpable seat assembly comprising:
a generally cylindrical tube having an outer diameter and an inner diameter
with an upper
end forming a ball seat;
a upper slip assembly and a lower slip assembly mounted on such cylindrical
tube and
adapted to selectively engage the well casing to anchor the pumpable seat
assembly;
an elastomeric packing element mounted on said cylindrical tube between the
upper slip
assembly and the lower slip assembly; and
a dissolvable ball having a sufficiently large enough outer circumference so
that it can sit
on the ball seat and temporarily restrict a flow of fluids to the portion of
the wellbore located
below the pumpable seat assembly.
[00016] In one embodiment, the inner diameter of the cylindrical tube is
equal to or
greater than I inch. In another embodiment, the pumpable seat assembly has an
inner diameter
that is between about 1 inch to about 2 inches in diameter. In another
embodiment, the
pumpable seat assembly has an inner diameter that is about 2 inches in
diameter or larger. In one
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embodiment, the cylindrical tube has at least one flow port located at a lower
end of the
cylindrical tube.
[00017] In another aspect, the pumpable seat assembly is provided for
temporarily sealing
a well casing, the pumpable seat assembly comprising:
a generally cylindrical tube having an outer diameter and an inner diameter;
a upper slip assembly and a lower slip assembly mounted on such cylindrical
tube and
adapted to selectively engage the well casing to anchor the pumpable seat
assembly;
an elastomeric packing element mounted on said cylindrical tube between the
upper slip
assembly and the lower slip assembly; and
a dissolvable member positioned within the generally cylindrical tube for
temporarily
restricting a flow of fluids to the portion of the wellbore located below the
pumpable seat
assembly.
[00018] In one embodiment, the inner diameter of the cylindrical tube is
equal to or
greater than I inch. In one embodiment, the inner diameter is about 2 inches
or larger. In
another embodiment, the pumpable seat assembly has an inner diameter that is
between about 1
inch to about 2 inches in diameter. In one embodiment, the cylindrical tube
has at least one flow
port located at a lower end of the cylindrical tube. In one embodiment, the
dissolvable member
is selected from the group consisting of a dissolvable poppet valve, a
dissolvable flapper/check
valve and a solid dissolvable plug.
[00019] In one embodiment, the dissolvable member comprises a polymer that
is
dissolvable by water, pH, enzymes and the like.
[00020] Additional aspects and advantages of the present invention will be
apparent in
view of the description, which follows. It should be understood, however, that
the detailed
description and the specific examples, while indicating preferred embodiments
of the invention,
are given by way of illustration only, since various changes and modifications
within the spirit
and scope of the invention will become apparent to those skilled in the art
from this detailed
description.
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Brief Description of the Drawings
[000211 The invention will now be described by way of an exemplary
embodiment with
reference to the accompanying simplified, diagrammatic, not-to-scale drawings:
[00022] Figure 1 is a cross-sectional view of an exemplary embodiment of
the pumpable
seat assembly having a dissolvable ball.
[00023] Figure 2 is a partial cross-sectional perspective of a plurality
of pumpable seat
assemblies as shown in Figure 1 set within a length of well casings.
[000241 Figure 3 is a cross-sectional view of an exemplary embodiment of
the pumpable
seat assembly having a dissolvable plug or valve member.
Detailed Description of Preferred Embodiments
[00025] The detailed description set forth below in connection with the
appended
drawings is intended as a description of various embodiments of the present
invention and is not
intended to represent the only embodiments contemplated by the inventor. The
detailed
description includes specific details for the purpose of providing a
comprehensive understanding
of the present invention. However, it will be apparent to those skilled in the
art that the present
invention may be practised without these specific details.
[00026] The present invention relates generally to a process for
fracturing, stimulating and
producing a wellbore without having to mill out and remove fracturing/bridge
plugs and to a
pumpable seat assembly for use therein.
[00027] Figure 1 shows one embodiment of a pumpable seat assembly (10)
useful in the
present invention, which assembly (10) is shown being set within a wellbore
casing (12).
Pumpable seat assembly (10) comprises a generally cylindrical tube (14) having
an upper end
(15) and a lower end (17). Situated near the first end (15) of cylindrical
tube (14) is an upper slip
assembly (18) and situated near the lower end (17) of cylindrical tube (14) is
a lower slip
assembly (22). Both the upper and lower slip assemblies generally include a
plurality of
serrations (23) which engage the casing (12) and prevent longitudinal movement
of the slips (18)
and (22) once set.
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[00028] An elastomeric packer element (20) is mounted on the cylindrical
tube (14)
between the upper slip ((18) and the lower slip (22). The packing element (20)
is adapted to be
deformed into sealing engagement with the casing (12) upon compression of
setting components
(not shown). Although the packing element (20) is shown and described as being
one-piece it is
to be understood that a packing element having multiple members is
contemplated under the
present invention. In either case, the packing element (20) is adapted to
provide a fluid-tight seal
between the cylindrical tube (14) and the casing (12).
[00029] The lower end (17) of the cylindrical tube (14) can further
comprise one or more
flow ports (24). The flow ports (24) facilitate the flow of oil or gas from
the region below the
pumpable seat assembly (10) through the cylindrical tube (14) to the wellhead
(not shown). The
upper end (15) further comprises a time-dissolvable ball (28), which ball (28)
is sized to
generally sit into and cover the seat (16) formed in the upper portion (15) of
the cylindrical tube
(14) to prevent the flow of fluids such as those used for fracturing,
stimulating and the like from
flowing through the cylindrical tube (14) to the formation below the pumpable
seat assembly
(10). The ball (28), however, is dissolvable within a predetermined passage of
time to then allow
the flow of oil and gas from the formation below to the surface. Thus, the
dissolvable ball (28)
functions to temporarily restrict the flow through the cylindrical tube (14)
until it is desirable to
do so. The inner diameter (ID) of the cylindrical tube must be large enough so
that unrestricted
flow can occur therethrough. In one embodiment, the ID is about 2 inches or
larger. This is due
to the varying casing sizes that the tools are run in.
[00030] An example of biodegradable balls that may be used in the present
invention is
BioBallsTM, which are soluble ball sealers that are completely soluble in all
aqueous fluids such
as fresh water, brine and acid. The solubility rate is time and temperature
dependent and works
in static or agitation fluids. BioBallsTM are available from Santrol. It is
understood that there are
many service providers that can supply dissolvable products. Generally,
dissolvable balls can
include biodegradable balls that can degrade over a period of hours or days
when exposed to a
set of predetermined environmental conditions. For example, the environmental
conditions can
include normal wellbore operating conditions of temperature and pressure at a
particular depth or
elevation in the wellbore, as well as the normal chemistry for drilling mud or
pumping/frac fluids
used during completion operations.
[00031] Figure 2 shows an embodiment of a well completion process of the
present
invention using a plurality of pumpable seat assemblies (10) of the present
invention. In Figure
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2, a horizontal portion of a well is shown which has been cased in with casing
(12), such as steel
pipe casing. The casing (12) may be cemented in place in the well. The
horizontal well portion
in Figure 2 comprises five separate producing zones, zone A, zone B, zone C,
zone D and zone
E. The end of the casing (12) is shown as element (130). The first zone to be
fractured/stimulated would be the zone closest to the casing end (130),
namely, zone A. A
perforating apparatus (not shown) can be used to form perforations 132 in the
casing (12) and
fracing/stimulating fluids can then be pumped down to complete the
fracing/stimulating process.
1000321 The next producing zone to be perforated/fractured/stimulated
would now be zone
B. However, it is desirable that any fracing/stimulating fluids that are used
to stimulate zone B
do not reach zone A to prevent re-stimulating or re-fracturing of an already
stimulated/fractured
zone/interval. Thus, pumpable seat assembly (10a) is pumped downhole and set
just below zone
B but above zone A. Dissolvable ball (28a) is then pumped down to cover the
open seat of
pumpable seat assembly (10a). This will then prevent any fracing/stimulating
fluid from
reaching zone A. After zone B is stimulated, the next zone to be
perforated/fractured/stimulated
is zone C, using a second pumpable seat assembly (10b)which is pumped down the
wellbore
casing (12) followed by a second dissolvable ball (28b). After zone C is
stimulated, zone D is
the next producing zone to be perforated/fractured/stimulated using pumpable
seat assembly
(10c) and dissolvable ball (10c). Finally, pumpable seat assembly (10d) and
dissolvable ball
(10d) is used when zone E is perforated/fractured/stimulated.
[00033/ Figure 3 shows another embodiment of a pumpable seat assembly
(310) useful in
the present invention, which assembly (310) is shown being set within a
wellbore casing (312).
Pumpable seat assembly (310) comprises a generally cylindrical tube (314)
having an upper end
(315) and a lower end (317). Situated near the first end (315) of cylindrical
tube (314) is an
upper slip assembly (318) and situated near the lower end (317) of cylindrical
tube (314) is a
lower slip assembly (322). Both the upper and lower slip assemblies generally
include a
plurality of serrations (323) which engage the casing (312) and prevent
longitudinal movement
of the slips (318) and (322) once set.
[000341 An elastomeric packer element (320) is mounted on the cylindrical
tube (314)
between the upper slip (318) and the lower slip (322). The packing element
(320) is adapted to
be deformed into sealing engagement with the casing (312) upon compression of
setting
components (not shown). Although the packing element (320) is shown and
described as being
one-piece it is to be understood that a packing element having multiple
members is contemplated
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under the present invention. In either case, the packing element (320) is
adapted to provide a
fluid-tight seal between the cylindrical tube (314) and the casing (312).
[00035] The lower end (317) of the cylindrical tube (314) can further
comprise one or
more flow ports (324). The flow ports (324) facilitate the flow of oil or gas
from the region
below the pumpable seat assembly (310) through the cylindrical tube (314) to
the wellhead (not
shown). The upper end (315) further comprises a dissolvable member (346), such
as a
dissolvable valve or plug, which prevents the flow of fluids such as those
used for fracturing,
stimulating and the like from flowing through the cylindrical tube (314) to
the formation below
the pumpable seat assembly (310). The dissolvable member (346), however, is
dissolvable
within a predetermined passage of time to then allow the flow of oil and gas
from the formation
below to the surface. Thus, the dissolvable member (346) functions to
temporarily restrict the
flow through the cylindrical tube (314) until it is desirable to do so. The
inner diameter (ID) of
the cylindrical tube must be large enough so that unrestricted flow can occur
therethrough. In
one embodiment, the ID is about 2 inches or larger, due to the varying casing
sizes that the tools
are run in.
[00036] While the invention has been illustrated and described in detail
in the drawings
and foregoing description, the same is to be considered as illustrative and
not restrictive in
character, it being understood that only the preferred embodiments have been
shown and
described. The scope of the claims should not be limited by the preferred
embodiments set forth
in the examples, but should be given the broadest interpretation consistent
with the description as
a whole. In addition, all references cited herein are indicative of the level
of skill in the art.
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