Note: Descriptions are shown in the official language in which they were submitted.
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SYSTEMS AND METHODS FOR FRACTURING
A MULTIPLE WELL PAD
CROSS REFERENCE TO RELATED APPLICATIONS
[0001] This application claims priority to and the benefit of, co-pending
U.S.
Provisional Application Serial No. 62/314,001, filed March 28, 2016, the full
disclosure of
which is hereby incorporated herein by reference in its entirety for all
purposes. This
application is a continuation-in-part of co-pending U.S. Patent Application
No. 15/343,463,
titled "Systems and Methods for Fracturing a Multiple Well Pad," filed
November 4, 2016,
the full disclosure of which is hereby incorporated by reference in its
entirety for all
purposes.
BACKGROUND
Field of Invention
[0002] This invention relates in general to equipment used in the
hydrocarbon
industry, and in particular, to systems and methods for hydraulic fracturing
operations.
Description of the Prior Art
[0003] Hydraulic fracturing is a technique used to stimulate production
from some
hydrocarbon producing wells. The technique usually involves injecting fluid,
or slurry, into
a wellbore at a pressure sufficient to generate fissures in the formation
surrounding the
wellbore. The fracturing fluid slurry, whose primary component is usually
water, includes
proppant (such as sand or ceramic) that migrate into the fractures with the
fracturing fluid
slurry and remain to prop open the fractures after pressure is no longer
applied to the
wellbore. Typically hydraulic fracturing fleets include a data van unit,
blender unit,
hydration unit, chemical additive unit, hydraulic fracturing pump unit, sand
equipment, and
other equipment.
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[0004] The fluid used to fracture the formation is typically pumped into
the well by
high-powered hydraulic fracturing pumps. The pumps in typical fracing
operations pump
the fluid to a frac pump output header, also known as a missile, which in turn
passes the
fluid to a hydraulic fracturing manifold. The hydraulic fracturing manifold is
located
between the missile and a tree (assortment of valves and controls) located
above the
opening of a well bore. A plurality of dedicated fluid supply lines can
connect the hydraulic
fracturing manifold to a plurality of wells, with one supply line connected to
a tree
corresponding to each well. With this arrangement, an operator can use the
hydraulic
Fracturing manifold to isolate wells as they complete a frac cycle, and to
redirect fluid to a
different well that is ready to begin a new frac cycle. In some instances,
actuated valves
can improve transition time, increasing efficiency. Use of a hydraulic
fracturing manifold
in this manner is known in the industry as "zip" ['racking.
[0005] One disadvantage to typical hydraulic fracturing spreads is that,
when
servicing multiple wells, the hydraulic fracturing, or zipper manifold, is
typically located
near the missile, and some distance from some or all of the wells. Thus,
piping connecting
the manifold to the trees of individual wells can be lengthy, and include many
turns and
bends. Such turns and bends lead to inefficiencies, and often require
couplings and fittings
that add possible failure points to the system.
SUMMARY
[0006] One aspect of the present technology provides a flow system for use
at a
hydraulic fracturing well site. The flow system includes a tree attached to a
wellhead, an
inlet head in fluid communication with at least one hydraulic fracturing pump
at the well
site, and fluid conduit providing fluid communication between the inlet head
and the tree.
The flow system further includes a valve in the fluid conduit and having an
open position
and a closed position, the valve permitting fluid flow through the fluid
conduit when in the
open position, and preventing fluid flow through the fluid conduit when in the
closed
position, at least a portion of the fluid conduit positioned between the valve
and the tree.
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[0007] Another aspect of the present technology provides a flow system for
use at a
hydraulic fracturing well site. The flow system includes a plurality of trees,
each tree
attached to a wellhead, an inlet head in fluid communication with at least one
hydraulic
fracturing pump at the well site, and a fluid conduit providing fluid
communication
between the inlet head and the plurality of trees, and including expandable
conduit
segments joined by connectors. The flow system further includes a plurality of
valves in
the fluid conduit, each valve corresponding to one of the plurality of trees,
each valve
having an open position and a closed position, each valve permitting fluid
flow through the
fluid conduit when in the open position, and preventing fluid flow through the
fluid conduit
when in the closed position, at least a portion of the fluid conduit
positioned between at
least one of the plurality of valves and its corresponding tree.
[0008] Yet another aspect of the present technology provides a method of
providing
pressurized fluid to a plurality of wells at a hydraulic fracturing well site.
The method
includes the steps of pressurizing fluid with at least one hydraulic
fracturing pump,
directing the fluid from the at least one hydraulic fracturing pump to a fluid
conduit through
an inlet head, and selectively directing the fluid into a well via the fluid
conduit by opening
and closing fluid communication between the at least one hydraulic fracturing
pump and
the at least one of the wells using valves positioned in the fluid conduit and
corresponding
to each of the plurality of wells. The method further includes the step of
directing the fluid
into a tree attached to the wellhead by attachment of the fluid conduit to the
tree at a
location adjacent the master service valve of the tree.
BRIEF DESCRIPTION OF THE DRAWINGS
[0009] The present technology will be better understood on reading the
following
detailed description of non-limiting embodiments thereof, and on examining the
accompanying drawings, in which:
[0010] Figure 1 is a schematic environmental view of a hydraulic fracturing
site, in
accordance with an embodiment of the present technology;
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[0011] Figure 2 is a perspective view of a single wellhead fluid delivery
system, in
accordance with an embodiment of the present technology;
[0012] Figure 3 is a side view of a wellhead fluid delivery system, in
accordance with
an embodiment of the present technology;
[0013] Figure 4 is a perspective view of a multiple wellhead fluid delivery
system, in
accordance with an embodiment of the present technology;
[0014] Figure 5 is a perspective view of an alternate embodiment of a
multiple
wellhead fluid delivery system, in accordance with an embodiment of the
present
technology;
[0015] Figure 6 is a perspective view of another alternate embodiment of a
multiple
wellhead fluid delivery system, in accordance with an embodiment of the
present
technology;
[0016] Figure 7 is a side view of a wellhead fluid delivery system, in
accordance with
an alternate embodiment of the present technology;
[0017] Figure 8 is a perspective view of a wellhead fluid delivery system,
in
accordance with an embodiment of the present technology;
[0018] Figure 9 is a side view of a wellhead fluid delivery system, in
accordance with
an embodiment of the present technology;
[0019] Figure 10 is a side view of a wellhead fluid delivery system, in
accordance with
an embodiment of the present technology; and
[0020] Figure 11 is a perspective view of another alternate embodiment of a
multiple
wellhead fluid delivery system, in accordance with an embodiment of the
present
technology.
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DETAILED DESCRIPTION OF THE INVENTION
[0021] The
foregoing aspects, features and advantages of the present technology will
be further appreciated when considered with reference to the following
description of
preferred embodiments and accompanying drawings, wherein like reference
numerals
represent like elements. In describing the preferred embodiments of the
technology
illustrated in the appended drawings, specific terminology will be used for
the sake of
clarity. The invention, however, is not intended to be limited to the specific
terms used,
and it is to be understood that each specific term includes equivalents that
operate in a
similar manner to accomplish a similar purpose.
[0022] Embodiments
of the present disclosure are directed to systems and methods for
coupling manifolds to trees at well sites. Flow systems may include an inlet
head to direct
fluid toward a configuration that is coupled to one or more trees at the well
site. Fluid
conduits are positioned between valves to enable blocking of fluid flow to a
particular tree
of a plurality of trees, but to enable flow to other trees. In this manner,
selective flow to
the trees may be utilized to control, for example, fracturing operations. In
embodiments,
the fluid conduits include "S" spool configurations with rotating flanges to
adjust a position
of the flanges in an x, y, and z-direction, thereby enabling coupling of
components when
certain fittings are not exactly aligned and increasing flexibility at the
well site. Moreover,
the fluid conduits may include expansion joints to adjust a length of the
fluid conduit for a
given operation or line configuration. As such, increased flexibility for
coupling
connections at the well site may be provided.
[0023] Fig. 1
shows a schematic environmental view of equipment used in a hydraulic
fracturing operation. Specifically, there is shown a plurality of pumps 10
mounted to
vehicles 12, such as trailers. The pumps 10 are fluidly connected to trees 14
attached to
wellheads 16 via a missile 18, which is in turn connected to an inlet head 20.
As shown,
the vehicles 12 can be positioned near enough to the missile 18 to connect
fracturing fluid
lines 22 between the pumps 10 and the missile 18.
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[00241 Fig. 1 also shows equipment for transporting and combining the
components
of the hydraulic fracturing fluid or slurry used in the system of the present
technology. In
many wells, the fracturing fluid contains a mixture of water, sand or other
proppant, acid,
and other chemicals. A non-exclusive list of possible examples of fracturing
fluid
components includes acid, anti-bacterial agents, clay stabilizers, corrosion
inhibitors,
friction reducers, gelling agents, iron control agents, pH adjusting agents,
scale inhibitors,
and surfactants. Historically, diesel fuel has at times been used as a
substitute for water in
cold environments, or where a formation to be fractured is water sensitive,
such as, for
example, slay. The use of diesel, however, has been phased out over time
because of price,
and the development of newer, better technologies.
[0025] In Fig. 1, there are specifically shown sand transporting containers
24, an acid
transporting vehicle 26, vehicles for transporting other chemicals 28, and a
vehicle carrying
a hydration unit 30. Also shown is a fracturing fluid blender 32, which can be
configured
to mix and blend the components of the hydraulic fracturing fluid, and to
supply the
hydraulic fracturing fluid to the pumps 10. In the case of liquid components,
such as water,
acids, and at least some chemicals, the components can be supplied to the
blender 32 via
fluid lines (not shown) from the respective components vehicles, or from the
hydration unit
30. In the case of solid components, such as sand, the components can be
delivered to the
blender 32 by conveyors 34. The water can be supplied to the hydration unit 30
from, for
example, water tanks 36 onsite. Alternately, water can be provided directly
from the water
tanks 36 to the blender 32, without first passing through the hydration unit
30.
[0026] Monitoring equipment 38 can be mounted on a control vehicle 40, and
connected to, e.g., the pumps 10, blender 32, the trees 14, and other downhole
sensors and
tools (not shown) to provide information to an operator, and to allow the
operator to control
different parameters of the fracturing operation. Other hydraulic fracturing
well site
equipment shown in figure 1 can include a greasing unit 42, a flushing unit
44, and RFOC
46, accumulators 48, Wireline 50, a test unit 52, trunk lines 54, and fluid
conduit 56. The
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system may also include a crane 58, and flow back equipment 60, such as a
choke manifold,
plug catcher, desander, separator, and flares.
[0027] Referring now to Fig. 2, there is shown more specifically the
portion of the
hydraulic fracturing system that delivers fluid from the hydraulic fracturing
pumps 10 to
each wellhead 16. In particular, Fig. 2 shows the missile 18, the inlet head
20, and the fluid
line connecting the missile 18 to the inlet head 20. Fig. 2 also shows the
tree 14 and fluid
conduit 56 connecting the inlet head 20 to the tree 14. One aspect of the
present technology
shown and described herein is the flow system 64, which includes the fluid
conduit 56
between the inlet head 20 and the tree 14. In the embodiment of Fig. 2, as
well as other
embodiments described herein and shown in the drawings, both the fluid line
connecting
the missile 18 to the inlet head 20, the inlet head 20 itself, and the fluid
conduit 56
connecting the inlet head 20 to each well is large enough to carry the entire
fluid volume
and flow required to fracture a well. Moreover, in the embodiments shown and
described,
only one conduit is required per well to provide the fluid needed to fracture
the well.
[0028] Fig. 3 shows an enlarged side view of the flow system 64 according
to one
embodiment of the present technology, including inlet head 20, tree 14, and
fluid conduit
56. Fluid conduit 56 connects, and provides a fluid conduit, between the inlet
head 20 and
the tree 14. Fluid conduit 56 also includes at least one valve 66 capable of
regulating fluid
flow through the fluid conduit 56 between the inlet head 20 and the tree 14.
The at least
one valve 66, or combination of valves 66, can alternate between an open
position, a closed
position, and a partially open position. When in the open position, fluid flow
through the
fluid conduit 56 is unrestricted. When in the closed position, fluid flow
through the fluid
conduit 56 is prevented by the valve 66. When in the partially open position,
fluid flow
through the fluid conduit 56 is restricted, but not wholly prevented. The
valves 66 can be
controlled manually or remotely.
[0029] The tree 14 shown in Fig. 3 includes multiple parts, including a
series of tree
valves. Such tree valves may include, but are not limited to, a master valve
68, wing valves
70, and a swab valve 72. Although a single master valve 68 is shown in Fig. 3,
some trees
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14 may include both upper and lower master valves. Similarly, although details
of the wing
valves 70 are not shown in Fig. 3, there may be multiple wing valves,
including, for
example, a kill wing valve and a production wing valve.
[0030] The flow system 64 of the present technology includes fluid conduit
56 and
valves 66 that are separate and distinct from the tree 14 and tree valves 68,
70, and 72. In
fact, in many embodiments, at least a portion of the fluid conduit 56a is
positioned between
at least one of the valves 66 and the tree 14. One advantage to this
arrangement is that fluid
flow through the fluid conduit 56 can be controlled and/or stopped, as desired
by an
operator, independent of the tree 14 before the flow reaches the tree 14. This
feature is
especially advantageous at a wellsite containing multiple wells, as shown in
Fig. 4.
Coupling 73 connects the fluid conduit 56a to the tree 14, and can have the
ability to rotate
to allow rotation of the tree 14 relative to the well and the fluid conduit 56
as needed or
desired by an operator. This allows the operator to adjust the radial
alignment of the trees
so that the planes of the flange faces are coincident or parallel to each
other.
[0031] Fig. 4 depicts a flow system 64 that includes an inlet head 20, and
fluid conduit
connecting the inlet head 20 to multiple trees 14, each associated with a
well. The particular
portion of the fluid conduit 56 between the inlet head 20 and each tree 14
includes at least
one valve 66 capable of regulating flow through the fluid conduit 56 between
the inlet head
20 and that particular tree 14. Similar to the embodiment shown in Fig. 3 and
discussed
above, the at least one valve 66, or combination of valves 66, associated with
each tree 14
can alternate between an open position, a closed position, and a partially
open position.
When in the open position, fluid flow through the fluid conduit 56 is
unrestricted, and will
enter the well, as desired by the operator. When in the closed position, fluid
flow through
the fluid conduit 56 is prevented by the valve 66. When in the partially open
position, fluid
flow through the fluid conduit 56 is restricted, but not wholly prevented.
[0032] The flow system 64 includes valves 66 that are separate and distinct
from the
trees 14 and from all valves associated with and/or attached to the trees 14.
In fact, in many
embodiments, at least a portion of the fluid conduit 56a is positioned between
at least one
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of the valves 66 and the corresponding tree 14 to that valve 66 or series of
valves 66. One
advantage to this arrangement is that fluid flow through the fluid conduit 56
can be
controlled and/or stopped, as desired by an operator, independent of the tree
14 before the
flow reaches the tree 14.
[0033] One reason the ability to allow or prevent flow before the flow
reaches a
particular tree 14 is advantageous is because it allows an operator to easily
direct flow
between wells at a multi-well site as needed in the course of operations. For
example,
different wells might operate on different cycles in a hydraulic fracturing
operation. Thus,
it may be desirable to provide pressurized fluid to a particular well at a
particular time or
place in the frac cycle, while simultaneously stopping the flow of fluid into
another well
that is in a different place in the frac cycle. With the flow system 64 of the
present
technology it is possible direct flow between wells continuously simply by
opening or
closing the valves 66 associated with individual wells. Thus, the flow of
pressurized fluid
into wells can be managed efficiently. In addition, while flow to a tree 14 is
stopped, due
to the closing of the corresponding valve 66, valves on the tree can be
operated to allow
the operator to insert a line, frac isolation ball, etc. as needed.
[0034] Another advantage to the flow system 64 of the present technology is
a
reduction in the amount of piping and other iron needed to manage flow between
the
hydraulic fracturing pumps 10 and multiple wells. For example, at conventional
hydraulic
fracturing drilling sites, separate piping may be run all the way from the
missile 18 to each
individual well. Depending on the size of the operation and the number of
wells at the site,
this conventional arrangement can lead to a great quantity of piping, and each
pipe may
contain many bends, turns, and connections to accommodate an indirect path
between the
pumps 10 and a well.
[0035] In stark contrast, the flow system 64 of the present technology
provides an inlet
head 20 that can be connected to the missile 18 by a single pipe, and that can
be located
proximate a group of wells. The fluid conduit 56 of the flow system 64 is then
required to
connect the inlet head 20 and the individual trees 14 over a relatively short
distance, and
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with a relatively low number of bends, turns, and connections. Although the
corners of the
fluid flow lines are shown in the figures as a single segment with an
approximate 90 degree
angle, bends in the fluid flow lines can be formed with single segments at
angles other than
90 degrees, or can be made up of multiple segments that together form a bend
or corner.
This arrangement accordingly provides a decrease in set up time, as well as
fewer
maintenance issues.
[0036] Also shown in the flow system 64 of Fig. 4 is a fresh water inlet 74
and a flush
port 76. Such fresh water inlet 74 and flush port 76 can be located proximate
to the valves
66 and the inlet head 20. With the valves 66 closed and no pressurized fluid
being delivered
to the fluid conduit 56 from the inlet head 20, fresh water can be injected
through the fresh
water inlet 74, flow through the fluid conduit 56, and exit at the flush
port76. This process
will replace the contents of the fluid conduit 56 with fresh water, flushing
any sand and
other solids and fluids from the fluid conduit 56. In some alternate
embodiments, the
positions of the fresh water inlet 74 and the flush port 76 can be switched.
[0037] Referring now to Fig. 5, there is shown an embodiment of the present
technology where the flow system 64 includes multiple trees 14 attached to
individual
wells. As in embodiments described above, fluid conduit 56 connects the inlet
head 20 with
each tree 14, and valves 66 are positioned to isolate or connect each tree 14
to pressurized
fluid in the fluid conduit 56 as desired by an operator.
[0038] Fig. 5 also shows the versatility of the present technology in
servicing well
sites having any formation. For example, the fluid conduit 56 may be tailored
to any
configuration necessary to connect the inlet head 20 to the trees 14. The
fluid conduit 56
may include expandable or telescoping segments 56b, capable of length
adjustment to
accommodate variable distances between trees 14 and between the inlet head 20
and trees
14. The expandable joints can have a maximum length and minimum length and can
be set
at any of an infinite number of lengths between the maximum length and the
minimum
length. In addition, the fluid conduit 56 may include "S" spools 78 with
rotating flanges 80
to accommodate height adjustments. Furthermore, in certain embodiments, the
ends of the
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"S" spools 78 may not be flanged and could include quick connect fittings, for
example.
This feature may be useful when wells associated with a common flow system 64
are
positioned at different elevations. Thus, the combination of telescoping
segments 56b and
"S" spools 78 with rotating flanges 80 compensates for variances between a
site plan and
actual spacing between the wells. In addition, these features add
adjustability, modularity,
and scalability to the system. Support structure, such as struts and braces,
can be spaced at
various locations along each of the fluid flow lines and used to support the
fluid flow lines.
Additional structure can be added to provide fall protection around the
location of each of
the wells.
[0039] Additional advantageous features of the flow system 64 include
couplings and
positioning of the inlet head 20 relative to the trees 14. For example, the
couplings 82
between fluid conduit 56 segments can consist of any appropriate type of
connector, and
are not required to be flange connectors. In some embodiments, the couplings
82 may be
quick connect-type clamp connectors, thereby allowing for quick assembly and
disassembly of the flow system 64. In addition, in the embodiments shown in
Figs. 5 and
6, the inlet head 20 is not linearly aligned with individual trees 14.
Specifically, the inlet
head 20 is attached to individual fluid conduit sections that run
perpendicular to the
longitudinal axis of the inlet head 20, so that the fluid within the fluid
conduit 56 changes
direction upon flow into the fluid conduit 56 from the inlet head 20. This
feature is useful
to reduce or prevent packing in the conduits adjacent the valves 66 and trees
14.
[0040] The embodiments of Figs. 3-5 depict flow systems 64 having multiple
valves
66 for each tree 14, wherein the valves 66 are positioned in series on a
common horizontal
plane. Moreover, in each of these embodiments, the fluid conduit 56 is shown
to intersect
the tree 14 at a relatively low position, adjacent the lower master valve 68.
This
configuration is beneficial because it slows easier access to the valves 66
for adjustment
and management of the overall flow system 64. For example, with the valves 66
located
adjacent the lower master valve 68 of each tree 14, an operator standing on
the ground can
typically access the valves 66 to make adjustments and to open and close
valves. This
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allows operation of the flow system 66 without the need for scaffoldings or
other platforms,
thereby eliminating a safety risk to the operators. Additional embodiments of
the present
technology, however, contemplate alternative fluid conduit and valve
arrangements.
[0041] For example, the flow system 64 of Fig. 6 includes valves 66
associated with
each tree 14 that are not located on the same horizontal plane, but that are
stacked one
above another. As a result, the portion of the fluid conduit 56a positioned
between the
valves 66 and each tree 14 connects to the tree14 at a position above the wing
valves 70,
adjacent the swab valve 72. Such a configuration may be desirable depending on
the
specific layout and/or geography of a well site. As discussed above with
respect to alternate
embodiments, the embodiment of Fig. 6 can include fluid conduit 56 having "S"
spools 78
with rotating flanges 80 to accommodate height adjustments. This feature may
be useful
when wells associated with a common flow system 64 are positioned at different
elevations.
"S" spools 78 can also be used, for example, between the valves 66 and their
respective
trees 14, to account for height differences between the a tree 14 and the
uppermost valve
66, as will be described below.
[0042] Figs. 7 and 8 show yet another embodiment of the flow system 64 of
the present
technology. In this embodiment, the valves 66 are positioned in series 66 on
the same
horizontal plane, but the portion of the fluid conduit 56a between the valves
66 and the tree
14 is dogged upward so that it intersects the tree above the wing valves 70
adjacent the
swab valve 72. This embodiment may be advantageous where there is a need for
the inlet
of the fluid conduit 56 into the tree 14 to be positioned high, adjacent the
swab valve 72,
but the valves 66 are desired to be located low, so they can be accessed by an
operator
without use of a scaffolding or platform. Also shown in Figs. 7 and 8 is an
optional skid 84
to support the flow system 64. Such a skid 84 may be used in the flow systems
64 of any
embodiment described herein, and may be useful to solidify the footing of the
flow system
64 at a well site.
[0043] Fig. 9 illustrates another embodiment of the fluid conduit 56a
arranged
between a vertical fracturing manifold including a pair of valves 66. However,
it should
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be appreciated that the vertical fracturing manifold may include a single
valve 66 or
multiple valves, and may also include additional auxiliary components, such as
tie ins for
instrumentation, bleeder valves, and the like. The fluid conduit 58a includes
the "S" spool
78 having the rotating flanges 80. In embodiments where the inlet to the tree
14 is at a
vertical position higher than the outlet to the vertical fracturing manifold,
the rotating
flanges 80 of the "S" spool 78 may be used to adjust the connection between
the vertical
fracturing manifold and the tree 14. For example, if the inlet to the tree 14
is at a lower
position, the flanges 80 may be rotated to reduce the vertical elevation of
the "S" spool 78,
relative to a ground plane, to enable coupling of the fluid conduit 56a
between the vertical
fracturing manifold and the tree 14. As described above, in certain
embodiments the fluid
conduit 56a may include expandable joint segments 56b describe above.
Accordingly, the
connection between the vertical fracturing manifold and the tree 14 may be
adjusted in
each of the x, y, and z directions in order to facilitate coupling of the
fluid conduit 56a.
[0044] FIG. 10
illustrates another embodiment of the fluid conduit 56a connecting the
vertical fracturing manifold to the tree 14, when the vertical fracturing
manifold is arranged
on the skid 84. In the embodiment illustrated in FIG. 10, the skid 84 is an
adjustable skid.
The skid 84 includes legs 86 that are positioned on the ground plane to enable
vertical
adjustment of a top portion 88 of the skid 84. In other words, the legs 86 may
be telescopic
and expand and contract relative to the top portion 88. In certain
embodiments, the skid
86 includes an elevation adjustment device, such as a motor in the form of a
linear actuator.
Additionally, the legs 86 may include pins and apertures to enable individual
adjustment
of the top portion 88. That is, the legs 86 may be arranged within a sleeve
that includes a
series of apertures at different relative elevations. In certain embodiments,
the legs 86
include one or more corresponding apertures to align with the apertures on the
sleeve such
that a pin can be inserted through the apertures to lock the legs 86 in place.
Also, in certain
embodiments, the legs 86 may include the pin as a spring-loaded device that
drives
outwardly through the apertures when aligned with the apertures of the sleeve.
As such,
the vertical position of the outlet of the fracturing manifold may be adjusted
to facilitate
connection to the tree 14.
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[0045] FIG. 11 illustrates an embodiment of the flow system 64 including
the wireline
unit 50. Certain features have been omitted for clarity, but in operation the
wireline unit
50 may include a packoff/line wiper, grease head, head catcher, lubricator,
and the like to
direct the wireline into the wellhead 16. In operation, hydraulic fracturing
may be
performed in several stages. A wire 90 may be introduced into the wellhead 16.
The wire
90 may be a braided wire that includes an electrical cable to enable
transmission of
information into and out of the wellbore. The wire 90 may be introduced into
the wellhead
16 along with a plug. The wire 90 directs the plug to a specified location in
the wellbore
and then activates the plug to form a seal between other portions of the
wellbore. Fracturing
fluid may be introduced into the well and a ball or other mechanism may be
dropped to
block flow of the fracturing fluid past the plug. Thereafter, the high
pressure fracturing
fluid may fracture the well to provide improved flow characteristics and
enable recovery
of hard to reach or unconventional hydrocarbons. The wire 90 is removed from
the
wellbore after the plug or multiple plugs are in position. In certain
embodiments, personnel
are not positioned near the wellhead 16 when the fracturing operation is
underway due to
potential safety concerns. As such, operations at the well site may be slowed
when several
trees 14 are arranged adjacent one another, as operations are halted on
adjacent trees 14
when one well is undergoing fracturing operations.
[0046] In the illustrated embodiment, the plurality of trees 14 include a
wireline
controller 92. The wireline controller 92 enables remote operation of the
wireline unit 50.
In the illustrated embodiment, the wireline controller 92 is positioned on
each of the trees
14. Accordingly, the wire 90 may be moved between adjacent trees 14 via the
wireline
controller 90. It should be appreciated that in certain embodiments each tree
14 of the
plurality of trees may have a separate wireline controller 92. Advantageously,
fracturing
operations at one well can be performed while plugging operations are done in
an adjacent
well, via the wireline controller 92. Moreover, because the wireline
controller 90 may be
controlled remotely, personnel will not be on site while the fracturing
operations are being
performed.
14
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312897
[0047] In embodiments, the wireline controller 90 may include a quick
connect to
couple at least a portion of the wireline unit to the wellhead. Moreover, in
embodiments,
the wireline controller 90 may also include a quick connect adapter. The quick
connect
and/or quick connect adapter may be coupled to the plurality of trees 14.
Additionally, the
quick connect may enable remote connection and disconnection of at least a
portion of the
wireline unit 50 from the quick connect adapter to enable movement of the
wireline unit
50 to an adjacent tree 14 of the plurality of trees 14. In embodiments, the
quick connect
adapter includes a means to pressure test a portion of the wireline unit, such
as a portable
pressure testing unit, and to drain hydraulic fluids from at least a portion
of the wireline
unit.
[0048] Although the technology herein has been described with reference to
particular
embodiments, it is to be understood that these embodiments are merely
illustrative of the
principles and applications of the present technology. It is therefore to be
understood that
numerous modifications may be made to the illustrative embodiments and that
other
arrangements may be devised without departing from the spirit and scope of the
present
technology as defined by the appended claims.
