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Gas Well Deliquification Workshop
Sheraton Hotel, Denver, Colorado
February 17 – 20, 2013
Packer-Type Gas Separator with Seating Nipple
Lynn Rowlan, Dieter Becker, Ken Skinner
Echometer Company
Tony Podio - University of Texas – Austin
Jim McCoy Jim@echometer.com
Packer Type Gas Separators
A new type of Packer Type Separator is described.
A comparison in separator performance between
different Packer Type Separators is given.
A comparison between Packer Type Separators and
Natural Gas Separators is shown.
Special uses and features of the new Packer Type
Separator are described.
2 2013 Gas Well Deliquification Workshop
Denver, Colorado
Feb. 17 – 20, 2013
Gas Separator
Liquid Capacity
is Based on the
Following
Principle:
1/4 INCH DIAMETER GAS BUBBLES FLOW UPWARD IN OIL OR WATER AT A
RATE OF APPROXIMATELY 6 INCHES PER SECOND. THUS, GAS BUBBLES
WILL BE RELEASED FROM A LIQUID COLUMN IF THE DOWNWARD LIQUID
VELOCITY IS LESS THAN 6 INCHES PER SECOND.
A LIQUID COLUMN HAVING AN AREA OF 1 SQUARE INCH TRAVELLING AT
6 INCHES PER SECOND IS A FLOW RATE OF 50 BPD.
Downhole Gas Separator
Principle of Operation
Feb. 17 – 20, 2013 3
2013 Gas Well Deliquification Workshop
Denver, Colorado
The outer pipe can be
the casing or the outer
barrel of a gas
separator. The inner
tube is the inlet to the
pump.
Natural Gas Separator
The most efficient downhole gas separators locate the pump intake below the lowest gas entry point.
Gas is not pulled down to the pump perforations unless the liquid velocity is greater than 6 inches per second downward.
Maximum capacity is obtained using casing annulus.
4
Concentric Packer Type Gas Separator
A concentric packer type gas separator
offers additional liquid and gas capacities
over Poor Boy type gas separator.
Note that the seating nipple is located
immediately above the packer in this
separator system so a dip tube is not
needed.
Some packer type separators use a dip
tube in the inner portion of the separator
and locate the pump above the
separator. Page Oil Tools 1957
5 2013 Gas Well Deliquification Workshop
Denver, Colorado
Echometer Gas Separator Top
Collar
Bottom
Collar Formation
Fluids
Formation
Fluid Outlet
Pump
Seating Nipple
Pump Inlets
Fluids from the formation flow
upward to the gas separator and
then flow through a concentric
annulus to an outlet at the top of
the separator which discharges
on one side into the casing
annulus.
The gas rises and the liquid falls
in the casing annulus.
Pump inlet is located at bottom
of the gas separator causing the
pressure drop from the liquid at
the bottom of the separator to
the pump inlet to be negligible.
Diverter Cups or a packer or tail
pipe with packer is located below
the Separator to force formation
fluids into the separator.
Casing
Diverter cups
or Packer or
Stinger 6
2013 Gas Well Deliquification Workshop
Denver, Colorado
Pump is Above Separator
Differences:
The pump is located above the 39 feet
long separator.
The liquid that is in the casing annulus
surrounding the separator flows from
the casing annulus upward 40 feet to
the pump inlet. The liquid flow rate
varies from 0 in/sec during the pump
downstroke to approximately 3 times
the plunger velocity or about 240
in/sec during the mid portion of the
upstroke.
The Ported Coupling has 7 3/16 inch
flow paths for the formation fluids. 7
Pump is Above 40 foot Separator
Differences:
The pump is located above the
separator.
The liquid that is in the casing
annulus surrounding the separator
flows from the casing annulus
upward 40 feet to the pump inlet.
Baffles are located in the separator
annulus to cause turbulence and a
pressure drop which causes
additional solution gas to be
released from the oil.
2013 Gas Well Deliquification Workshop
Denver, Colorado 8
Data on 27 Wells – 66 tests Cobra Oil and Gas - Thanks
Feb. 17 – 20, 2013
Important Analysis Factors
Cobra Oil and Gas
Packer Type Separator
10
Feb. 17 – 20, 2013
Important Analysis Factors
Cobra
Packer Type Separator
11
Pump Fillage Data
Acceptable
Questionable
12
Average
of all data
Pump Above Separator Vs.
Natural Separator
13 Wells with Packer Type Separators 17 Variables were Studied
13 Feb. 17 – 20, 2013 2013 Gas Well Deliquification Workshop
Denver, Colorado
2013 Gas Well Deliquification Workshop
Denver, Colorado
% liquid Surrounding Separator Vs. % Pump Fillage
14
Packer Type Separators with Pump above Separator
Natural Gas Separators
Vs.
Packer-Type Separators
Separation
Principles are
Different
Packer-Type Separator:
• Wellbore Oil is decreasing in
pressure releasing very small
gas bubbles
Natural Gas Separator:
• Wellbore Oil is increasing in
pressure and small gas bubbles
are dissolved into the oil
Packer Type Natural
2013 Gas Well Deliquification Workshop
Denver, Colorado 15 Feb. 17 – 20, 2013
Typical Plunger Position and Velocity and Rate
Velocity Position Maximum plunger velocity is
80 inches/second and the
maximum displacement rate
is 1258 BPD (for a 1 ½ inch
plunger).
Withdrawing liquid at a high
rate from the casing annulus
to a pump located 40 feet
above may cause
considerable pressure drop in
the liquid that will release gas
and produce foam.
16 Feb. 17 – 20, 2013
5 Seconds
10 Seconds
15 Seconds
20 Seconds
Start
The problem of gas in the liquid as the liquid enters the pump may be the
creation of small gas bubbles from the pressure drop of liquid in the dip
tube as the oil travels from the casing to the pump inlet.
17
Other Pump Fillage Factors
• Variable Diameter Pump Barrel
• Hole/Holes in Pump Barrel
• High Clearance Plunger
These conditions will fill the pump chamber
but generally lower the total production rate
18 2013 Gas Well Deliquification Workshop
Denver, Colorado
Feb. 17 – 20, 2013
Pump Analysis and Surface Production
19
Seating Nipple Separator Performance
Seating Nipple Separators
Feb. 17 – 20, 2013 2013 Gas Well Deliquification Workshop
Denver, Colorado
20
Packer-Type Separator Configurations
All of the formation fluid must be directed into the bottom
of the separator to pass through the separator and be
discharged out of the top of the separator. Then the
discharged liquid in the casing annulus falls to the pump
inlet and the gas flows upward.
The flow can be directed through the separator using a:
• Packer
• Diverter Cups
• Tail Pipe with packer
All installations must have one of the diverter devices to
force the formation fluids upward through the separator
and out of the top of the separator.
21 2013 Gas Well Deliquification Workshop
Denver, Colorado
Feb. 17 – 20, 2013
Separator with Packer
Casing
Tubing
Gas Separator
Packer
Tail Pipe
The Packer can contain a
casing locking device or a
tubing anchor can be used
below the packer.
22 2013 Gas Well Deliquification Workshop
Denver, Colorado
Feb. 17 – 20, 2013
Tail Pipe With Packer
Casing
Tubing
Gas Separator
Packer
Tail Pipe
The tail pipe with packer
configuration is very
effective and will increase
production in a well when
the pump is set a
considerable distance
above the formation. The
tail pipe reduces the
pressure required to push
the formation fluids to the
pump so a lower PBHP
exists.
23 2013 Gas Well Deliquification Workshop
Denver, Colorado
Feb. 17 – 20, 2013
Oil 75 BPD Water 75 BPD Gas 200 MSCFPD
0
500
1000
1500
2000
2500
3000
0 200 400 600 800 1000 1200
Pressure, psi
Ve
rtic
al
Dis
tan
ce
Be
low
Pu
mp
, ft
2-3/8 in 2-7/8 in 4-1/2 in 5-1/2 in 7 in
Tail Pipe Reduces Producing Bottom Hole Pressure
24
PIP = 100 psi
Horizontal wells can cause problems with Artificial Lift
due to the nature of the flow. These wells tend to head a
lot when placed on artificial lift. Back in the 80s when
we were Gas Lifting the Austin Chalk wells we noticed
that if we ran tail pipe around the corner of a horizontal
well below the packer, we could even out the flow of
these wells. Using this technique, you should have no
problems no matter the type of Artificial Lift you use.
Jay.miller@bakerhughes.com
2/5/2013
Feb. 17 – 20, 2013 2013 Gas Well Deliquification Workshop
Denver, Colorado
25
Packer with Check Valve
Casing
Tubing
Gas Separator
Packer
Check Valve
A check valve can be used with
wells that tend to flow in slugs to
increase production and separator
performance. The portion of fluid
in the slug that flows above the
check valve will be caught above
the check valve. This will result in
a lower PBHP and additional
separation time for well fluids
which will improve separator
performance.
A check valve can be used if the
operator wants to insure that the
packer is set. Liquid can be
pumped down the casing annulus
to check packer seal. 26 2013 Gas Well Deliquification Workshop
Denver, Colorado
Feb. 17 – 20, 2013
Tail Pipe With Packer or Stinger
Casing
Tubing
Gas Separator
Stinger Assembly
Liner
Tail Pipe
When a liner is used
in the portion of the
well that is curved
and horizontal, a
stinger with or
without a tail pipe can
be run into the liner
so a packer would not
be needed.
27 2013 Gas Well Deliquification Workshop
Denver, Colorado
Feb. 17 – 20, 2013
Packer with Sand Screen
Casing
Tubing
Gas Separator
Packer
Sand screen
Many wells produce
some sand and debris.
Sand screens below
the packer can be used
to prevent sand from
getting above the
packer. The screen can
be back-washed by
pumping liquid down
the casing annulus
from the surface.
28 2013 Gas Well Deliquification Workshop
Denver, Colorado
Feb. 17 – 20, 2013
Diverter Cup Assembly
Upper Male connection
8 Diverter Cups
Cups are loose fit to freely slide
on mandrel
Lower Male Connection 29 2013 Gas Well Deliquification Workshop
Denver, Colorado
Feb. 17 – 20, 2013
Top Hold-down Pump
Casing
Rods
Tubing
Seating nipple
Pump
Gas Separator
Packer
The bottom of the pump
should be located near the
liquid inlet holes at the
bottom of the separator.
Therefore, the pump
seating assembly must be
located above the
separator. The pump
actually extends into the
gas separator so the
pump inlet is near the
liquid inlet holes in the
separator.
30 2013 Gas Well Deliquification Workshop
Denver, Colorado
Feb. 17 – 20, 2013
Acoustic Test – Echometer Separator 11/26/12
Dynamometer Test – Echometer Separator 11/26/2012
Gas Separator and Seating Nipple
Top Collar
Inner and Outer barrels
Larger Outer barrel over seating nipple
Seating Nipple, conventional or mechanical
Two Large Holes for liquid flow into pump inlet
Lower Collar and mating assembly
35 2013 Gas Well Deliquification Workshop
Denver, Colorado
Final Slide
jim@echometer.com
36 2013 Gas Well Deliquification Workshop
Denver, Colorado Feb. 17 – 20, 2013
Feb. 17 – 20, 2013 2013 Gas Well Deliquification Workshop
Denver, Colorado
37
Copyright
Rights to this presentation are owned by the company(ies) and/or author(s) listed on the title page. By submitting this presentation to the Gas Well Deliquification Workshop, they grant to the Workshop, the Artificial Lift Research and Development Council (ALRDC), and the Southwestern Petroleum Short Course (SWPSC), rights to:
– Display the presentation at the Workshop.
– Place it on the www.alrdc.com web site, with access to the site to be as directed by the Workshop Steering Committee.
– Place it on a CD for distribution and/or sale as directed by the Workshop Steering Committee.
Other use of this presentation is prohibited without the expressed written permission of the author(s). The owner company(ies) and/or author(s) may publish this material in other journals or magazines if they refer to the Gas Well Deliquification Workshop where it was first presented.
Feb. 17 – 20, 2013 2013 Gas Well Deliquification Workshop
Denver, Colorado
38
Disclaimer
The following disclaimer shall be included as the last page of a Technical Presentation or Continuing Education Course. A similar disclaimer is included on the front page of the Gas Well Deliquification Web Site.
The Artificial Lift Research and Development Council and its officers and trustees, and the Gas Well Deliquification Workshop Steering Committee members, and their supporting organizations and companies (here-in-after referred to as the Sponsoring Organizations), and the author(s) of this Technical Presentation or Continuing Education Training Course and their company(ies), provide this presentation and/or training material at the Gas Well Deliquification Workshop "as is" without any warranty of any kind, express or implied, as to the accuracy of the information or the products or services referred to by any presenter (in so far as such warranties may be excluded under any relevant law) and these members and their companies will not be liable for unlawful actions and any losses or damage that may result from use of any presentation as a consequence of any inaccuracies in, or any omission from, the information which therein may be contained.
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