Note: Descriptions are shown in the official language in which they were submitted.
CA 02832804 2013-10-09
WO 2012/141691
PCT/US2011/032122
SHALE-GAS SEPARATING AND CLEANOUT SYSTEM
Background of the Invention
[0001] During the drilling phase of well exploration, it is common to hit
pockets of gas and
water. When using an air drilling process in a shale formation, shale
cuttings, dust, gas and
fluid/water create a volatile mixture of hard-to-handle debris; especially
when encountering
previously fractured formations. Drilling operations and debris disposal
account for the
majority of the volatility and fire risk during the drilling process. Without
limitations, these
operations include fluid recovery, gas irrigations and debris disposal.
[0002] As the number of wells drilled in a given area increase, the
possibility of
encountering a fractured formation within an active drilling operation,
increases. This
possibility presents the drilling operator with a problem of removing shale
cuttings, along
with dust, fluid/water and gas. There is no effective way to separate the
shale cuttings, mute
the dust, by-pass the fluid/water encountered, and control/burn the waste gas
in the air portion
of the drilling program.
100031 Air drilling is one method of drilling into shale formations, but it
creates large
volumes of dust. Unfortunately, the dust cannot be discharged into the
environment due to
the many governmental regulations related to dust control for shale-gas
drilling operations.
Thus, such drilling efforts must overcome this problem or face substantial
penalties and fines.
100041 As gas is often encountered during the air drilling operation from a
previously
fractured formation, a combustible gas cloud may be created and linger near
the ground. A
similar gas cloud may exist and linger within and/or around the debris
disposal pits. These
combustible gas clouds create a fire hazard at the drilling site, and downwind
therefrom.
Accordingly, many additional governmental regulations for shale-gas drilling
relate to the
handling and processing of debris from such wells in order to avoid a
volatile, combustible
gas cloud.
CA 02832804 2013-10-09
WO 2012/141691
PCT/US2011/032122
2
100051 The foregoing issues show there is a need for an apparatus to separate
the shale-gas-
water mixture into non-volatile components, and provide environmentally safe
collection and
disposal of the shale debris, fluid and formation gas burned a safe distance
from wellbore.
Summary of the Invention
[0006] In one aspect, the following invention provides for a shale-gas
separator. The
shale-gas separator comprises a vessel and a jet assembly. The vessel has an
intake pipe
defined thereon, where the intake pipe is positioned to tangentially
communicate a shale-gas-
fluid mixture into the vessel. A gas release vent is defined on the vessel,
and positioned to
communicate gas therefrom. The jet assembly has a side opening connected to a
port
positioned on the bottom of the vessel. The jet assembly has a first end and a
second end
defined thereon. A jet is connected to the first end. A jet assembly outlet is
secured to the
second end.
100071 In another aspect, a shale-gas separator and clearing apparatus is
provided. The
shale-gas separator and clearing apparatus comprises a vessel, a jet assembly
and internal
aerated cushion system (IACS) pipe. The vessel has a intake pipe defined
thereon. The
intake pipe provides tangential communication of a shale-gas-fluid mixture
into the vessel.
The vessel has a top and a bottom, where the top and the bottom each have a
port disposed
therethrough. The jet assembly is secured to the bottom. The jet assembly has
a jetted input
and a venturi output. The IACS pipe is centrally disposed within the vessel,
and extends
towards the port in the bottom. The RCS pipe has at least one discharge nozzle
defined
thereon.
[00081 In yet another aspect, a shale-gas separator dust eliminator is
provided. The dust
eliminator comprises a sidewall, an inlet and an outlet. There is at least one
fluid jet disposed
through the sidewall. There are a plurality of baffles positioned within the
housing, where a
first baffle is positioned beneath the fluid jet and oriented to deflect fluid
towards the outlet.
CA 02832804 2013-10-09
WO 2012/141691
PCT/US2011/032122
3
There is a second baffle complementarily positioned within the housing between
the fluid jet
and the outlet, wherein the baffles are positioned to interrupt the flow of
fluid through the
housing.
100091 Numerous objects and advantages of the invention will become apparent
as the
following detailed description of the preferred embodiments is read in
conjunction with the
drawings, which illustrate such embodiments.
Brief Description of the Drawings
[0010] FIG. I depicts a simplified schematic elevational view of a wellsite in
fluid
communication with a shale-gas separator.
10011j FIG. 2 depicts a simplified schematic plan view of a wellsite in fluid
communication with a shale-gas separator.
[0012] FIG. 3 depicts a lower left perspective view of a shale-gas separator.
100131 FIG. 4 depicts right side elevational view of a shale-gas separator.
100141 FIG. 5 depicts a left side elevational view of a shale-gas separator.
[0015] FIG. 6 depicts a front elevational view of a shale-gas separator.
[0016] FIG. 7 depicts a rear side elevational view of a shale-gas separator.
100171 FIG. 8 is plan view of a shale-gas separator.
100181 FIG. 9 is a sectional detail view taken from FIG. 4 along line 9-9, and
illustrates a
debris shield.
[0019] FIG. 10 is a sectional detail view taken from FIG. 4 along line 10-10,
and illustrates
an intake pipe having a tangential input and a wear plate.
[0020] FIG. 11
is sectional view taken from FIG. 6, long line 11-11, and illustrates an
internal aerated cushion system (IACS) pipe.
10021] FIG. 12 depicts a side view of a jet assembly.
[0022] FIG. 13A depicts a side view of a dust eliminator having spiraling
baffles.
CA 02832804 2013-10-09
WO 2012/141691
PCT/US2011/032122
4
[0023] FIG. 13B is a sectional view taken from FIG. 13A along line 13B-13B,
and
illustrates one of the spiraling baffles.
[0024] FIG. 13C is a sectional view taken from FIG. 13A along line 13C-13C,
and
illustrates another of the spiraling baffles.
100251 FIG. 13D is an elevational end view of a dust eliminator having
spiraling baffles.
[0026] FIG. I4A is a bottom view schematic of slotted outlet muffler with the
slot on one
side.
[0027] FIG. 1413 is a bottom view schematic of an outlet muffler having holes
on one side,
[0028] FIG. 15A is a side view schematic of a slotted outlet muffler disposed
within a
housing.
[0029] FIG. 15B is a sectional view of a slotted outlet muffler disposed
within a housing
taken from FIG. 15A along lines 15B-15B.
[00301 FIG. 15C depicts a perspective view of an alternative configuration of
the collection
bin, slotted outlet muffler without a housing and fluid overflow bypass line.
100311 FIG. 16 depicts a perspective view of a jet assembly and pressurized
fluid input
lines, and optional valve.
[0032] FIG. 17 depicts a detail view of the vessel and fluid overflow bypass
line.
Detailed Description
[0033] Referring to FIGS. 1-3, the inventive shale-gas separator is
illustrated and generally
designated by the numeral 10. As shown by the drawings and understood by those
skilled in
the art, shale-gas separator 10 and components thereof are designed to be
associated with a
well 12. As discussed herein, shale-gas separator 10 is associated with well
12, shale
formations 14 and drilling strategies. The drilling strategies include air
drilling in shale
formations. However, the invention is applicable to multiple drilling
techniques with
CA 02832804 2013-10-09
WO 2012/141691
PCT/US2011/032122
cuttings, dust, debris, gas and fluid from wells 12 other than those
associated with shale
formations 14.
[0034] Shale-gas separator 10 is in air/fluid communication with well 12.
FIGS. 1 and 2
illustrate shale debris, dust, gas and fluid being communicated to shale-gas
separator 10 in
pipe 16. The fluid is typically water, mist, foam, detergent or aerated mud.
Shale-gas
separator 10 receives the shale-gas-fluid mixture at intake pipe 18. Intake
pipe 18 is secured
to and protrudes through wall 20 of vessel 22. Optional dust eliminator 24 is
illustrated as
being directly connected to intake pipe 18. However, dust eliminator 24 may
also be
positioned in-line with pipe 16.
[0035] Shale-
gas separator 10, illustrated in FIGS. 1-7 illustrates vessel 22 in fluid
communication with intake pipe 18. As illustrated in FIG. 3, intake pipe 18
flows into
tangential input 26 through the siclewall 20 of vessel 22and opens within
vessel 22, thereby
defining the tangential flow and initiating the cyclonic effect with vessel
22.
[00361 Vessel 22 is generally circumferential with domed top 28 and conical
bottom 30.
Domed top 28 has a port disposed therethrough. The port in domed top 28
functions as gas
release vent 32, which is in fluid communication with flare stack feedline 34
and is capable
of communicating gas from vessel 22 to a flare (not shown) placed sufficiently
far enough
from the well to mitigate any threat of accidental ignition of gas. Although
not shown, gas
release vent 32 optionally includes one-way valves, splash-guards, and/or back-
flow
preventers placed in flare stack feedline 34 prior to igniting the flare.
Conical bottom 30 has
port 36 disposed therethrough. Port 36 is in fluid communication with jet
assembly 38.
[0037] Interiorly disposed between tangential input 26 and gas release vent 32
is debris
shield 40. Debris shield 40 interiorly extends outward from wall 20 and covers
about 40
percent to about 75 percent of the inner diameter of vessel 22. As illustrated
in FIGS. 4-9,
debris shield extends across the inner diameter of vessel 22 about 4 feet
(about 1.2 meters).
CA 02832804 2013-10-09
WO 2012/141691
PCT/US2011/032122
6
Additionally, FIGS. 4 and 5 illustrate debris shield 40 as having downward
angle 42 and
being oriented towards conical bottom 30. Downward angle 42 is between about -
5 and
about - 600 below the horizon, and is illustrated in FIGS. 4 and 5 as having
an angle of about
-15 below the horizon. Downward angle 42 provides for the downward deflection
of shale
debris and fluid, while allowing the separated gas to escape towards gas
release vent 32.
Debris shield 40 has gas vents 44 penetrating therethrough along edges 46 to
facilitate gas
release,
10038] In operation, debris shield 40 receives the shale-gas-fluid mixture
from intake pipe
18, and working in concert with the cyclonic effect communicated by intake
pipe 18 and
tangential input 26, causes the gas to separate from the shale-gas-fluid
mixture. The
separated gas rises towards gas release vent 32 where it is communicated from
vessel 22.
The shale debris and fluid fall towards conical bottom 30, where it is
received by jet
assembly 38.
[00391 FIG, 10 illustrates wear plate 48 secured to wall 20 and positioned to
receive shale-
gas-fluid mixture from intake pipe 18 and tangential input 26. Wear plate 48
may be
permanently affixed to wall 20, or it may be removably affixed. As
illustrated, wear plate 48
is interiorly welded to wall 20. In the alternative, not shown, wear plate 48
is bolted, or
otherwise secured to wall 20. As illustrated, wear plate 48 is between about
18 inches to
about 24 inches wide (about 0.46 meters to about 0.61 meters) and covers about
one-half of
the circumferential interior of wall 20. As illustrated, wear plate 48 is
about 0.5 inches (about
1.3 centimeters) thick. Wear plate 48 begins where tangential input 26 ends
within vessel 22.
The longitudinal centerline (not shown) of wear plate 48 is centered on
tangential input 26,
Preferably, wear plate 48 and tangential input 26 are blended together to
prevent any edges
for input flow to impinge upon.
CA 02832804 2013-10-09
WO 2012/141691
PCT/US2011/032122
7
[9040] As illustrated in FIGS. 1, 3-8, 12 and 16, jet assembly 38 connects to
port 36 of
conical bottom 30 at a side opening thereon, also referred to as side receiver
50. Side
receiver 50 has a shape facilitating the flow of debris and fluid into jet
assembly 38. Side
receiver 50 surrounds port 36, thereby providing for unimpeded flow into jet
assembly 38.
Jet assembly 38 has first end 52 and second end 54. First end 52 has jet 56
connected thereto.
Referring to FIG. 12, jet 56 extends into jet assembly 38 along a center axis
of jet assembly
38, and terininates between side receiver 50 and second end 54. Vacuum gauge
58 is
illustrated in FIG. 12 as being positioned on side receiver 50 within jet
assembly 38 to
measure the drop in pressure or amount of vacuum pulled in inches or
kilopascals. In
practice, the amount of vacuum pulled by jet assembly 38 is about -10 inches
of mercury to
about -15 inches of mercury (about -34 kilopascals to about -51 kilopascals).
100411 Jet 56 is capable of receiving fluid, either liquid or air, which in
turn provides the
motive force to the shale debris and fluid to exit through second end 54.
Preferably, jet 56 is
able to use compressed air, compressed inert gas, pressurized water,
pressurized hydraulic
fluid, or combinations thereof. Jet assembly 38 also has pressure gauge 60.
Pressure gauge
60 provides feedback on the pressure of air/fluid flowing into jet assembly 38
through jet 56
and to internal aerated cushion system (IACS) pipe 62.
[00421 Second end 54 communicates the debris and fluid to outlet muffler 64.
FIG. 12
depicts second end 54 as venturi 66. Jet assembly outlet 68, illustrated in
FIGS. 4-6, 8, 12
and 16, communicates the debris and fluid from second end 54 to collection bin
70 via
discharge line 72. In an alternative embodiment, venturi 66 is part of jet
assembly outlet 68
that is secured to second end 54.
10043] Jet assembly outlet 66 is secured to discharge line 72, which is in
communication
with outlet muffler 64. As illustrated in FIGS. 2 and 15C, outlet muffler 64
is positioned to
discharge shale debris and fluid into collection bin 70. Outlet muffler 64 has
at least one
CA 02832804 2013-10-09
WO 2012/141691
PCT/US2011/032122
8
discharge port 74. As illustrated in FIGS. 2, 11A-12C, outlet muffler 64 has
one to six
discharge ports 74, but any number will provide the desired discharge. FIGS.
2, 14A, and
15A-15C illustrate discharge port 74 being a slot. FIG. 14B illustrates three
discharge ports
74 as holes. Other shapes and sizes of discharge port 74 are understood to be
included, For
example, discharge port 74 can be elliptical or square. It is also anticipated
that discharge
line 72 can directly discharge the shale debris and fluid without outlet
muffler 64,
10044] FIGS. 15A and I5B depict outlet muffler 64 with housing 76 surrounding
it and
being secured thereto. Housing 76 tapers outwardly from top 78 to bottom 80,
as illustrated
in FIGS. 2, 3, 15A and 15B. Also illustrated in FIGS. 2, 15A and 15B, is
outlet muffler 64
with discharge port 74 oriented towards bottom 80. FIG. 15A shows one
embodiment of
outlet muffler 50 secured to housing 76. Additionally, outlet muffler cap 82
is illustrated as
extending externally to wall 84 of housing 76. In this embodiment, discharge
port 74 is a slot
extending across a substantial depth 86 of housing 76.
[0045] Outlet muffler cap 82 provides impact baffling for debris discharging
through outlet
muffler 64. Alternatively, internal baffles (not shown) may be used to divert
and slow the
debris within outlet muffler 64. Another alternative is to not use outlet
muffler 64 and secure
housing 76 directly to elbow 88. This alternative has internal baffles or wear
plates on wall
84.
[0046] FIG.
15A illustrates housing 76 with sniffer port 89 thereon. Sniffer port 89
provides access for a gas sniffer (not shown) to sample the output from outlet
muffler 64 for
the presence of gas. In this context, the gas sniffer includes the capability
to detect one or
more of the gaseous chemicals found in well 12, In the absence of housing 76,
sniffer port 89
is positioned on outlet muffler 64.
[0047] Vessel 22 also includes lACS pipe 62. As illustrated in FIGS. 4-8 and
11, IACS
pipe 62 is elongated and positioned within vessel 22. IACS pipe 62 is
centrally positioned
CA 02832804 2013-10-09
WO 2012/141691
PCT/US2011/032122
9
within conical bottom 30 of vessel 22, and located above port 36. IACS pipe 62
has at least
one nozzle 66 defined thereon. IACS pipe 62 is positioned within vessel 22 to
provide
pressurized fluid to remove any debris buildup on wall 20 of conical bottom 30
down to port
36, In use, IACS pipe 62 provides a fluid cushion to mitigate the buildup of
gas in jet
assembly 38 and vessel 22.
[00481 The non-limiting example in FIG. 11 depicts IACS pipe 62 having three
to five sets
of nozzles 90 positioned along longitudinal portion 92 of IACS pipe 62.
Additionally, the
non-limiting example depicts another three cleanout nozzles 90 secured to IACS
pipe end 94,
and are downwardly oriented. By way of another non-limiting example, if
longitudinal
portion 92 of lACS pipe 62 is about three (3) feet (about I meter) in length,
nozzles 90 are
spaced along longitudinal portion 92 with spacing of about six (6) inches to
about 18 inches
(about 0.15 meters to about 0,5 meters). The spacing between cleanout nozzles
90 is
determined by the size of vessel 22. As shown in FIG. 11, the spacing between
nozzles 90 is
about twelve (12) inches (about 0.3 meters). There may be a plurality of
nozzles 90
circumferentially positioned along longitudinal portion 92 at each spacing.
Alternatively,
there may be a plurality of nozzles 90 circumferentially and offsettingly
positioned along
longitudinal portion 92 at operator desired spacing.
[00491 Referring to FIGS. 4-8 and 11, IACS pipe 62 is secured to and through
wall 20,
Although IACS pipe 62 is illustrated as a single line, it may be formed out of
several pipe
sections. IACS pipe 62 is in fluid communication with pressurized fluid line
96 with line 98
at t-joint 100. Line 98 has valve 102 disposed between pressurized fluid line
96 and IACS
pipe 62. Valve 102 provides control of the fluid communicated to IACS pipe 62,
and is
illustrated as a manually operated valve. However, automating valve 102 is
understood to be
within the skill of one knowledgeable of the art.
CA 02832804 2013-10-09
WO 2012/141691
PCT/US2011/032122
[0050] As illustrated in FIG. 16, pressurized fluid line 96 communicates
pressurized fluid
to jet 56 and to IACS pipe 62 through line 98. Valve 104 is positioned
upstream from t-joint
100 and pressure gauge 60, and controls the fluid communicated to jet 56.
Valve 104 may
also be manually or automatically operated. Although, using the same fluid for
both jet 56
and IACS pipe 62 is preferred, an alternative is to use separate types of
fluid communicated
through separate supply lines (not shown). For example, compressed air is
communicated to
jet assembly 38 and pressurized water is communicated to IACS pipe 62.
Compressed air
will be the most common fluid communicated through pressurized fluid line 96
and line 98
due to its availability at the wellsite.
100511 FIG. 16 also illustrates pressure gauge 60 and vacuum gauge 58 as
described above.
Preferably, valve 104 is adjusted to set a minimum vacuum condition in jet
assembly 38.
One embodiment facilitates achieving the above-mentioned desired vacuum range
of about -
10 inches of mercury to about -15 inches of mercury (about -34 kilopascals to
about -Si
kilopaseals). In this embodiment, jet 56 operates using fluid having a
pressure in the range of
about 75 pounds per square inch to about 200 pounds per square inch (about 517
Kilopascals
to about 1,379 Kilopascals). Valve 104 is adjustable until vacuum gauge 58
indicates the
vacuum is within desired range.
[0052] FIGS. 4-
8 illustrate fluid overflow bypass line 106, or overflow line 106. Overflow
line 106 communicates any excess fluid buildup within vessel 22 away from
vessel 22. As
illustrated, intake port 108 is oriented towards conical bottom 30, is
centrally positioned
within vessel 22 and below than intake pipe 18. Preferably, intake port 108 is
also positioned
above IACS pipe 62.
[0053] Overflow line 106 is secured to and through wall 20 at point 110.
Preferably, point
110 is below intake pipe 18. Overflow line 106 is connected to fluid bypass
discharge line
112, or bypass line 112. Bypass line 112 discharges to any receptacle capable
of receiving
CA 02832804 2013-10-09
WO 2012/141691
PCT/US2011/032122
11
the fluid, with one example shown in FIG. 15C. Preferably, bypass line 112
discharges to
another device (not shown) capable of separating any gas from the fluid.
[0054] To provide additional access to vessel 22, at least one manway 114 and
at least one
cleanout/observation hatch 116 are utilized and disposed through wall 36.
Manway 114 is
disposed through wall 20 above conical bottom 30. Cleanout/observation hatch
116 is
disposed through wall 20 of conical bottom 30. Manway 114 and
cleanout/observation hatch
116 are sized to provide complete or partial access to the interior of vessel
22. As shown,
rnanway 114 is about 24 inches (about 0.6 meters), and cleanout/observation
hatch 116 is
about 10 inches (about 0,25 meters).
[0055] As
illustrated in FIGS. 1-8, 10 and 13A-D dust eliminator 24 has inlet 118,
outlet
120, fluid jet 122, and a plurality of baffles. As illustrated, the plurality
of baffles include
first spiral baffle 124 and second spiral baffle 126. Fluid jet 122 is
disposed through sidewall
128 of dust eliminator 24 near inlet 118. First spiral baffle 124 and second
spiral baffle 126
are positioned from about inlet 118 to about outlet 120. Second spiral baffle
126 is
complementarily positioned within dust eliminator relative to first spiral
baffle 124. Fluid jet
94 is positioned near inlet 118 above first spiral baffle 124 and second
spiral baffle 126. First
spiral baffle 124 and second spiral baffle 126 deflect the fluid, typically
water, being
propelled from fluid jet 122 towards outlet 120. First spiral baffle 124 and
second spiral
baffle 126 interrupt an axial flow of fluid and debris through the dust
eliminator, thereby
inducing a spiraling flow of the fluid and debris through dust eliminator 24.
This spiraling
flow action causes the dust and fluid to mix, thereby reducing dust.
100561 An alternative for first spiral baffle 124 and second spiral baffle 126
is to use off-
setting baffles (not shown) that are alternating and obliquely positioned. In
this case, the first
baffle will be obliquely positioned below fluid jet 122 and capable of
deflecting the fluid
towards outlet 120. The subsequent baffles alternate and provide points of
impact for the
CA 02832804 2013-10-09
WO 2012/141691
PCT/US2011/032122
12
fluid arid the debris of shale-gas. The fluid impacts interrupt flow of fluid
through the dust
eliminator 24. In this setup, there are at least two baffles and preferably
three or more
baffles.
100571 Referring to FIGS. 1-8, shale-gas separator 10 is shown as being
carried by skid
130. Preferably, skid 130 is transportable across a standard U.S. highway.
100581 In an embodiment illustrating the use of shale-gas separator 10, a
typical well 12
using shale-gas separator 10 discharges the shale-gas debris through pipe 16
to the optional
dust eliminator 24, where a fluid, such as water, is injected therein and
encounters the debris,
thereby reducing and/or eliminating any dust. The shale-gas debris may be
shale-gas-fluid
debris. Exiting from the optional dust eliminator 24, the debris is
communicated to vessel 22
where it is cyclonically communicated therein through intake pipe 18 and
tangential input 26.
100591 The debris cyclonically spins around within vessel 22. In a non-
limiting example,
vessel 22 has a diameter of about 72 inches (about 1.83 meters). In this same
non-limiting
example, debris shield 40 has 15-degree downward angle 42 and covers about 66
percent of
the interior of vessel 22, which is about four (4) feet (about 1.2 meters).
Debris shield 40
restricts and deflects solids and fluid downwardly, away from gas release vent
32. The
released gas is communicated upwardly to gas release vent 32, whereby it is
further
communicated to flare stack feedline 34 and burned at a flare positioned a
safe distance from
the well 12.
100601 The solid debris and fluid fall downwardly into conical bottom 30 and
through port
36 where the solids and fluid enter jet assembly 38. Jet 56, using air or
fluid, propels the
solids and fluid through jet assembly 38 to venturi 66. As the solids and
fluid flow through
venturi 66, they are propelled to outlet muffler 64. Outlet muffler 64
discharges the solids
and fluid into collection bin 70.
CA 02832804 2013-10-09
WO 2012/141691
PCT/US2011/032122
13
[0061] If jet assembly is blocked or clogged, IACS pipe 62 is positioned to
provide high-
pressure fluid that is expelled through cleanout nozzles 90 within conical
bottom 30. The
high-pressure fluid is commonly air due to the availability at wellsites. The
high-pressure
fluid creates a cushion or barrier to keep gas from being communicated to jet
assembly 38.
The placement of RCS pipe 62 provides for maximum or additional force of
pressurized
fluid to further motivate the solids out of conical bottom 30 of vessel 22.
Additionally, IACS
pipe 62 provides fluid to remove debris build up on the interior of wall 20 of
vessel 22. For
this non-limiting example, the supply of fluid is from the same source of
fluid provided to jet
56. However, separate sources of fluid for IACS pipe 62 and jet 56 are equally
acceptable as
is the same source. Additionally, for this non-limiting example IACS pipe 62
is about 2
inches (about 5 centimeters) in diameter.
100621 Jet assembly 38 has an additional clean out port, or cleanout plug 131.
Clean out
plug is illustrated in FIG. 16 as being oppositely positioned side receiver
50. In the event jet
assembly 38 becomes to clogged to clean it out with pressurized air or fluid,
plug 131 can be
removed for manual cleaning.
[00631 Referring to FIG. 16, valve 132 is illustrated as being positioned
between second
end 54 and outlet muffler 64. Valve 132 is optional and provides a means to
prevent all flow
from vessel 22 through jet assembly 38. In this instance, all flow can be
forced through
overflow line 106. As illustrated in FIG, 16, valve 132 is a knife valve, but
any valve capable
of preventing flow will work. In one embodiment, valve 132 is air actuated. As
shown in
FIGS. 3 and 16, valve 132 is manually operated.
[0641 Overflow line 106, functioning as a bypass, provides for a means to
passively
remove excess fluid, which is typically water, accumulating within vessel 22.
As the fluid
accumulates, it begins to enter intake port 108 until it reaches first turn
134. At that time, the
fluid begins to flow out of overflow line 106 and into discharge line 112,
where it is
CA 02832804 2013-10-09
WO 2012/141691
PCT/US2011/032122
14
deposited into an approved receptacle. As described in this non-limiting
example, overflow
line 106 and discharge line 112 are each about 6 inches (about 0.15 meters) in
diameter.
ID0651 Referring to FIGS. 2-8 and 17, external valve 136 is utilized to open
and close
overflow line 106 to control fluid communication from overflow line 106 to
bypass line 112.
External valve 136 may be automated, or it may be manual. The manual system of
external
valve 136 is illustrated with handle 138 to open and close it. In the manual
mode, an internal
indicator float (not shown) and float signal 140, as shown in FIG. 17, are
used to notify an
operator to open the external valve 136. The same float and signal 140 are
automatically
integrated with an automated system. Signal 140 can be audible, visual,
electronic, or a
combination thereof.
100661 FIG. 17 depicts optional vessel pressure gauge 142. Vessel pressure
gauge 142
provides the operator with feedback on the current pressure within vessel 22.
100671 Other embodiments of the current invention will be apparent to those
skilled in the
art from a consideration of this specification or practice of the invention
disclosed herein.
Thus, the foregoing specification is considered merely exemplary of the
current invention
with the true scope thereof being defined by the following claims.
