plunger lift assist presentation -...
TRANSCRIPT
Primary
Separator
155 psi
Sales Line
150 psi
Sales Line
150 psi
Well Opens, Plunger rises
When the well opens up, initial gas volume and pressure will bypass the
compressor and go into the gathering system. As pressure declines, the
compressor will assume control and pull the static line pressure down
that the well is working against to raise the plunger.
Initial Flow bypasses
the compressor
160 psig
Control
valve
set to
open
below
50 psig
Primary
Separator
40 psi
Sales Line
150 psi
Sales Line
150 psi
After Flow Period
As the WH pressure declines the PLC will sense
and the compressor will turn on helping the
plunger reach the surface. After plunger arrival an
“after flow” period begins and the compressor
continues to pull the wellhead pressure down.
35 psi
As well pressure declines,
compressor takes over and
pulls well down to near
suction pressure
45 psig
155 psi
Primary
Separator
30 psi
Sales Line
150 psi
Sales Line
150 psi
Well closes, Plunger falls
After the plunger falls and the WH valve shuts, the FX
compressor will go into recycle mode until the next plunger
cycle on the PAD
In the event of a well or PAD SI, the compressor will sense
loss of suction pressure over extended period and shut
itself down.
5 psig
Primary
Separator
30 psi
Sales Line
150 psi
Sales Line
150 psi
Advantages
The cycle is repeated and provides:
• Less differential pressure needed between Csg and Tbg to
cycle plunger
• Thereby reducing backpressure on formation allowing more
fluid entry
• More plunger cycles per day are achieved
• Increased production of Oil and Gas
Well SI to build
pressure
Increased Frequency of Plunger Cycles over 2 Hour Period for a Niobrara well
1111
2222
3333 44 55
CP480CP480
CP300CP300TP300TP300
TP230TP230Static130
Static80
– Logix PLC uses algorithm to respond to plunger control box signals
– Using well’s flowing pressure to determine when to utilize or bypass compression
– Higher frequency of plunger cycles by reducing differential pressure needed between Tbg and Csg
– Compressor lowers upstream static pressure and holds it constant to allow stable plunger velocity
– Compressor will alarm and shutdown upon well or sales line shut-in condition
� Compressor stays in auto mode and pulls down sales line pressure as wells cycle their plungers.
� Between plungers the FX compressor goes into recycle.
� It will shut down if suction pressure falls below set point.
� Allows one compressor to control multiple wells on PADs
- Picture of Flogistix compressor doing Multistream plunger assist in DJ Basin
� Niobrara formation well in Weld Co., CO
� Plunger assist WH compression installed
� $433,000 PV10 added
� 161 MBO oil and 1.3 BCF gas reserves added
Plunger Assist Compressor Installed
$45 oil/$3.40 gas assumed. 100%/80% WI/NRI.
� Niobrara formation well in Weld Co., CO
� Plunger assist WH compression installed
� $414,000 PV10 added
� 155 MBO oil and 1.6 BCF gas reserves added
Plunger Assist Compressor Installed
$45 oil/$3 gas assumed. 100%/80% WI/NRI.
Douglass formation well in Hemphill Co. TX
� Well struggling on plunger against line pressure
� $283K PV10 From Aug 2015 forward with strip pricing at $2.75/mcf and $4,300 LOE/month
� Assumed 100% WI, 80% NRI
Plunger Assist Compressor InstalledPlunger Assist Compressor Installed
Example Well Occurrence – Buffalo Wallow Field
Production Avg. 190 MCFD & 6 Bbl condensate
� Compressor down 3 days in Jan. 2016
3 Days of Lost Production Cost:
3*190*$2 + 3*$35*6 = $1,770
� Well was loaded for another week
3 Days of loaded production cost:
3*190*$2 +3*$35*6 = $1,770
� Pumper hours burdened to handle well
3 Hours 1st day, 1Hr on 2nd & 3rd day,
3Hr kicking well off on 4th day
Fully Burdened hour = $100
Pumper cost of 8Hrs * $100 = $800
Total Downtime Cost $4,340
100% Runtime
Well Name $/mcf Cost PV10 Remaining Gas Reserves, MMcf
Haney 3 well PAD 0.59 $199,857 330.4
Haney 2 well PAD 0.74 $86,676 200.6
Totals $286,533 531.0
Well Name $/mcf Cost PV10 Remaining Gas Reserves, MMcf
Haney 3 well PAD 0.69 $113,295 255.8
Haney 2 well PAD 0.90 $16,947 142.8
Totals $130,242 398.6
95% Runtime
Well Name $/mcf Cost PV10 Remaining Gas Reserves, MMcf
Haney 3 well PAD 0.83 $27,375 180.5
Haney 2 well PAD 1.14 -$52,329 84.1
Totals -$24,954 264.6
90% Runtime
Complete Transparency through
Telemetry on every unit
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Note: FLUX is included with cost of rental unit
30 Day Mechanical Availability
FLOGISTIX
� Compressor package w/ Logix PLC advanced control (Included)
� FLUX Automation
� Regularly scheduled Maintenance (Included in monthly rental charge)
� Service Call (Included in monthly rental charge)
� Optimization of unit (One time optimization charge)
� Engine Oil (Included in monthly rental charge)
� Compressor Oil (Included in monthly rental charge)
� 98% runtime guaranteed (Audit by FLUX)
COMPETITOR
� Skid package w/ Murphy control panel (Included)
� On/Off surveillance only
� Maintenance call (Charge per event)
� Service call (Charge per event)
� Optimization of unit (Charge per event)
� Engine Oil (Charge on use)
� Compressor Oil (Charge on use)
� 95 - 98% runtime guaranteed (Take their word for it)
� #1 in transparent WH Compression runtime
� Only WH compression package with LOGIX PLC that allows for pinpoint wellhead optimization
� Only WH Compressor company with FLUX telemetry that enables customer surveillance at no additional cost
� Multi-StreamTM capability with LOGIX PLC that allows one machine to manage multiple services; Vapor Recovery, Plunger Assist, Csg Drawdown, WH compression
� Highly Motivated customer service to ensure operator is fully satisfied
� Design Engineering team that optimizes standard units to fit most needs
� In-house Petroleum Engineering team to identify proper application