tepi - vico capillary string workshop
TRANSCRIPT
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TEPI VICO CAPILLARY STRING WORKSHOP
Sharing the experiences key success for the future !!
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Decreasing gas rate
new well,
high gas rate Well died !!
Liquid loading issue will always occurs in gas wells, just only wait in the
matter of time when it comes !!
At initial stage of production, the gas will
carry produced liquids up to surface as the gasvelocity is high enough.
The energy available to transport theproduced liquids to surface declines due to thedepletion drive of reservoirs.
When the gas produced are below gas
critical rate, the liquids start toaccumulate in the wellboreincreasing hydrostatic pressure, backpressure into formation. As a result,thegas rate will significantly drops and thewell died
Quick overview: liquids loading phenomena in gas wells
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IP of the well is deceasing very fast after offload due to
water production from the reservoirs
Very fast transition (a few days) from steady state (offload)to death
Frequent offloads between repressurization period
Water loading kills the well
Objective of capillary = stabilize the rate
1 32
1- 2 weeks
1- 2months
IP of the well is downgraded because of partial water
loading
The well is able to produce during a long period
Offloads are less frequent
Water loading limits the gas rate
Objective of capillary = enhance the gas rate
Offloads
TIME
GASRATE
2
Targeted wells; 2 types
Offloads
TIME
GAS
RATE
1
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reps. pseudo diedcategory
need special
operating procedure
Below 50% Turner
velocity line
validated in 2011
campaign
50% above Turner
velocity line
validated in 2010
campaign
Turner Velocity
Conclusion: Foaming technology can be applied in all region BUT it will
not work if the well has reservoir pressure issue (som e black w ells)
Test the limit of foaming technology !!
Weak wells
loading mode
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TN-X8was in
Regular offloadcategory
With CS
Sustainable production for 16 months
(No off-load was required)
Qg: 0.8 MM
Surfactant
60 L/D
Qw: 30 bwpd
TN-H5 was in
Regular offload category
With CS
Sustainable production for 12 months
(No off-load was required)
Some good results: Off-loaded wells, critical velocity
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TN-F7was in died
category since 2010
With CS
Intermittent production = 7
MMscfD more than 4 weeks
Unique well (died, even only
shut in for 2 hours)
Very good response if the well has strong inflow (high DEQ) but severe problem in
the outflow
Qg: 5.2 MM
~1 month~1 month
The special one !! good surprise of revival
Well
revivalLong offload
+ testLong offload
+test
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Negative response due to reservoir pressure issue (low deq)
TN-ML5was in died category
Negative response (production
can not be sustained):
Offload 4x
1x intermittent well opening
The died well: negativeresponse !!
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80
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100
0
1
2
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5
17-May-11 6-Jun-11 26-Jun-11 16-Jul-11 5-Aug-11 25-Aug-11 14-Sep-11
WHFP(Bar)
Surfact
antInejctionrate(L/D)
GasRate(MMSCFD)
Production Evolution on Well TN-X8
Gas Rate Surfactant Injection Rate Water Production oil Production WHFP
LP
mode
SI for CS
installation
QG increase After surfactant injection
DP downhole linked to dewatering is > DP linked to LP mode
TN-X8: Dewatering dP downhole evaluation
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DEPTH REACHED (TARGET VS ACTUAL)
Some tolerance to the setting depth
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Highlights from pilot phase Gain obtained 6.84 MMscfd (5 wells put on production).
TN-F7 rePoP after offload (+4.8 MM) ; TN-F5 plugged due to drilling activity. TN-X8 still low after misunderstanding of program.
TN-R23 is SI due to need to replace a part of DH equipment.
Highlights from Industrial phase Gain obtained 8.41 MMscfd (7 wells put on production).
TN-M18 rePoP : +3.7 MM TN-I9 rePoP failed : inject de-mineral then stop injection while waiting rig move out.
TN-I1 is waiting rig move-out for an intervention (gas found in control line)
TN-P23 SI for pressure Build up
TN-Lx41 rePoP : +0.5MM
TN-H12 diedafter switch to MP. SIBU
TN-Dx20 to be rePoP this week.
Result of current FAL project (per W1 Dec 12) No. Well Site Phase Date Gas Rate Surf. Inj.Rate (L/D) WHFP (bar) WHFT(deg C)1 TN-T6 SPU
Pilot
2-Dec 0.54 MMSCFD 20 14.5 36
2 TN-X8 SPU 2-Dec 0.38 MMSCFD 60 11 33
3 TN-H5 SPU 2-Dec 0.82 MMSCFD 60 12 35
4 TN-H3 SPU 2-Dec 0.35 MMSCFD 30 12 33
5 TN-F5 SPU 2-Dec 0.00 MMSCFD 5 0 0
6 TN-F7 SPU 2-Dec 4.76 MMSCFD 150 23 57
7 TN-R23 SPU 2-Dec 0.00 MMSCFD 0 60 0
8 TN-K11 NPU
Industria
l
2-Dec 0.40 MMSCFD 126 9 36.6
9 TN-P14 NPU 2-Dec 1.79 MMSCFD 50 12 41.7
10 TN-P23 NPU 2-Dec 0.00 MMSCFD 15 11 30
11 TN-H12 SPU 2-Dec 0.00 MMSCFD 15 10.5 3112 TN-I9 NPU 2-Dec 0.00 MMSCFD 5 9.4 0
13 TN-Kx23 NPU 2-Dec 0.25 MMSCFD 40 7.9 35
14 TN-TMx30 SPU 2-Dec 1.20 MMSCFD 80 13 46
15 TN-Dx20 SPU 2-Dec 0.00 MMSCFD 100 107 0
16 TN-M18 NPU 2-Dec 3.69 MMSCFD 60 10 50
17 TN-I1 NPU 2-Dec 0.00 MMSCFD 0 10 0
18 TN-F11 SPU 2-Dec 0.55 MMSCFD 100 26 57
19 TN-Lx41 NPU 2-Dec 0.52 MMSCFD 40 12 33
TOTAL (12) ells flowing 15.25 MMSCFD 956 L/D
1.27 MMSCFD/ Well flowingin Network Total
SPU 8.60 MMSCFD 500 L/D 620 L/DNPU 6.65 MMSCFD 316 L/D 336 L/D
Pilot Phase 6.84 MMSCFD 325 L/D
Indus. Phase 8.41 MMSCFD 631 L/D
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7 wells are still shut in due to DHSV packing leaking, work over, plug due to rig activity and
pressure build up
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DESIGN FEATURES
To keep down-hole safety valve installation
To reach target injection depth (3000 ~ 5000 m)
To avoid gas through inside capillary string
To be able to inject 150 L/D whilst maintaining DHSV
open
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INSTALLATION PROCEDURE
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WIRELINE PREPARATION:
RIH Dummy CS Hanger
RIH Memory P/T Survey
CAPILLARY STRING:
RIH Capillary String with Bottom Injection
valve to target depth
Cut Capillary String at surface
WIRELINE/BRAIDED LINE:
Connect CS with Hanger
Deploy CS with Hanger using Braided line
Function test the CS Installation
DOWNHOLE EQUIPMENT SCHEMATIC
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Pressure up Control lineSTART OPEN DHSV AT 2000 PSICRACK TOP INJECTION VALVE AT
3200 PSI
CRACK BOTTOM INJECTION
VALVE AT 4000 PSI
2.81 DHSV Inside CS
Hanger. Opening
pressure 2000 psi
Top Injection Valveinside CS Hanger.
Crack pressure 3200
psi
Bottom Injection
Valve
3/8 CS
Max 4800 lbs
TEPI CAPILLARY STRING COMPLETION
INDUSTRIALIZATION PHASE
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CHALLENGES
Down-hole equipment reliability
To simplify installation process
Running use CS Unit & deploy still
utilizes Braided line
Reduce crane dependency
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Surfactant Injection Surface Facility
Overview and Design Basis
Well Location
- Scattered Location Around Tunu Area
- Instrument Gas is The Main Motive/Control Fluid
- Limited Electrical Power (in some area is not available at all)
Design Basis
- Injection Pressure : 159332 Barg
- Injection Flowrate : 10150 LPD
- Positive Displacement Pump (Pneumatic Driven) Selection Based on API-675
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Surfactant Injection Surface Facility
Injection Package - Simplified Block Diagram
Safety Equipment
(Surfactant Injection
Isolation Valve)
Safety Equipment
(Pressure Protection)Safety Equipment
(Instrument Gas Supply
Isolation Valve)
Pump, Regulator
and Filter
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Surface facilities package
Surface facilities package will be
removable. Once the capillarywell is finished, the package will be
used for the other well
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Surfactant Injection Surface Facility
Challenges
Modification on Existing Infrastructure/Facilities
- Various Type of Structure and Configuration
- Portable Injection Facilities (Structure/Platform, Tank and Injection Package)
Surfactant Liquid Compatibility
- Corrosion Issues
- Instrument Seal vs Surfactant Liquid Compatibility
- Surfactant as Safety Valves (DHSV) Motive Fluid
Engineering and Design Condition
- Required Injection Pressure and Flowrate (Sensitive to Wells Characteristic)
- Instrument Gas Issues (Low Pressure, Condensation)
Alternative Solution : Gas Amplifier ?, Local Gas Scrubber ?, Electric Driven Pump (by
Solar Panel + Battery)?
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D l f f b h
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Development of surfactant test bench
Sign of chemical
degradation
If chemical
degrade, end of
story !!
Onsite
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FOAMING & EMULSION ISSUE
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NMP3 SC
M M M
FLOTATOR
M
TO FOSTTO DISPOSAL
TUBE
DEFOAMER
INJECTION LINE
SAMPLING POINT
REVERSE
DEMULSIFIER
INJECTION
SURFACTANT
INJECTION
7.9 7.8 8.2 8.3 8.7 7.9 7.1 7.3 7.8 7.2 8.6 8.1 7.8 7.9 9.3 9.1
32.9
19.6 17.29.1 9.0
0 0 0 0 0 0
80 80
50
100
40
240
260
1 40 1 40
230
3 80 3 80
330
230
9910
10433
10219
8965
9259
96459426
8939
5318
6334
7013
8029
4162
3386
2972
3243 3190 31442922
6782
0
2000
4000
6000
8000
10000
12000
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20-Sep-12
21-Sep-12
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1-Oct-12
2-Oct-12
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5-Oct-12
6-Oct-12
7-Oct-12
8-Oct-12
9-Oct-12
10-Oct-12
ProducedWater(bbl/d)
Water Oil Content (ppm)
SurfactantInjec tion (L/d)
Defoamer Injection (L/d)
Produced Water (bbl/d)
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Conclusions & Way forward
The Capillary String project is profitable. The additional gas production is obtained and
can sustain/prolong the life of liquids loaded wells.
Foaming & emulsions issue shall be solved asap to maintain project delivery.
Continue learning process to get comprehensive understanding about capillary foaming
technology.
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