yemen lng operational feedbacks - airproducts.com · yemen lng operational feedbacks ... isrs level...
TRANSCRIPT
Yemen LNGOperational feedbacks
APCI Owners’ Seminar XI – September 2013APCI Owners’ Seminar XI – September 2013
9/3/20131
Yemen LNG - Agendag
1 Yemen LNG general presentation1. Yemen LNG general presentation
2 Feedback on Plant restarts optimization2. Feedback on Plant restarts optimization
3 Other operational feedbacks3. Other operational feedbacks
9/3/20132
YEMEN LNG – GENERAL PRESENTATION Sh h ldShareholders
OPCO / Total Technical Leader (39.6%) OPCO / Total Technical Leader (39.6%)
9/3/20133
YEMEN LNG – GENERAL PRESENTATIONK j t d tKey project data
Yemen largest industrial project 6.9 Mtpa Average 110 LNG cargoes per year
Project Milestones:o 1995: First GDA
2004 FIDo 2004: FIDo 2005: Site construction started Sept.o 2009: Train 1 First LNG on 15 Oct.
Fi t t 7 N 2009
3 Sales Contracts / 20 years
First export on 7 Nov 2009
TOTAL KOGAS GDF SUEZ
9/3/20134
YEMEN LNG – GENERAL PRESENTATION
Transfer lineTransfer line25 km25 km –– 3030””
Upstream Facilities
Gas supply 25 km 25 km 3030
Main line 38’’Main line 38’’320 km320 km
to the LNG plant
LNG Plant: 2 trains & terminal
9/3/20135
YEMEN LNG – GENERAL PRESENTATION38” Pi li fil38” Pipeline profile
PlateauPlateauTransfer Transfer
LineLine 1400 m1400 m1700 m1700 m
0000
DescentDescentAscentAscentSand dunesSand dunes
LineLine
1000 m1000 m
1400 m1400 m
0000
BalHafBalHaf
CPUCPU KPUKPUWadi & sandWadi & sand
Main Main LineLine
BalHafBalHafBasaltBasalt
Plateau Plateau AscentAscent Plateau Plateau DescentDescent
9/3/20136
YEMEN LNG – GENERAL PRESENTATIONM i liMain line
9/3/20137
YEMEN LNG – GENERAL PRESENTATIONP d i tiProcess description
– 2 identical trains design capacity of 6.9 Mtpa (6.7 guaranteed)2 identical trains design capacity of 6.9 Mtpa (6.7 guaranteed)
– Gas Pre-treatment: • AGRU (Amine unit)• Dehydration (molecular sieve)• (Mercury bed)
– APCI C3-MR split processp p
• 2 spool wound type Main Cryogenic Heat exchanger (MCHE) of a guaranteed capacity to produce 428.8 t/h per train (APCI)
• 2 MR and Propane compression packages ( Eliott)
• 4 Frame 7EA turbine packages driving refrigerant compressors (General Electric)
– 2 LNG storage tanks (2 x 140 000 m3)
1 J tt f t 205 000 3 l– 1 Jetty for up to 205,000 m3 vessels
9/3/20138
YEMEN LNG – GENERAL PRESENTATIONF d G C itiFeed Gas Composition
VV Lean V Lean RichComponent (Mol %) (Mol %) (Mol %)
H20 0.000 0.000 0.000H2S 0 000 0 000 0 000H2S 0.000 0.000 0.000N2 0.100 0.090 0.100CO2 0.310 0.170 0.286C1 93 550 93 220 91 920C1 93.550 93.220 91.920C2 5.560 5.090 5.660C3 0.450 1.220 1.482IC4 0.010 0.080 0.128NC4 0.010 0.110 0.239IC5 0.000 0.000 0.040NC5 0.010 0.010 0.047NC6 0.000 0.000 0.015NC7 0.000 0.000 0.083
9/3/20139
HHV 1055.63 (1062.09) 1069.29 (1076.44) 1086.57 (1089.86)
YEMEN LNG – GENERAL PRESENTATIONK FiKey Figures
82% Yemenis in Operations teams82% Yemenis in Operations teamsAverage of 170 expats on site
ISO 17025 certification for Laborator
Indicators Design 1 Jan 31 Jul 2013
ISO 17025 certification for LaboratoryISO 14001 certificationISRS Level 5
Indicators Design 1 Jan- 31 Jul 2013LTIF - 0.54
TRIR - 1.0
RDL Production 445 t/h 465 t/hReliability 99.5% **Availability 95% * 96.0% **Thermal efficiency 90.4% * 90.6% **
9/3/201310
* Target for 2013** Up to 31st July 2013
FEEDBACK ON PLANT RESTARTSSh td tShutdown events
Plant restart duration
17 20
40
8
9MCHE bottom temperature before restart (average 2 trains)
‐52
‐23
7
31
1
‐20
0
6
7
re (d
egC)
‐31
‐60
‐40
4
5
m te
mpe
ratur
mbe
r of d
ays
1.2 days saved
ted)
120
‐100
‐80
2
3
MCH
E bo
ttom
Num
(feed
gas
lim
i
‐160
‐140
‐120
0
1
M
Estim
atio
n
9/3/201311
16001 2 3 4 5 6 7
Note: Plant restart duration is from Pipeline pressurization to the 2 trains at full production
FEEDBACK ON PLANT RESTARTST i l t tTypical start-up sequence
• Restart sequence ≈ 5 days• Restart sequence ≈ 5 days– Pipeline re-pressurization– Trains restart
8h 12h 12h 24 to 36h
1st TrainWarm end restart=> Gas on‐spec
ready for cold end
Pre‐cooldown=> MCHE @‐30 C
ready to start MR circulation
Final cooldown=> 1st LNG drop(MCHE @‐144 C)
Ramp‐up=> maximum sustainable production
(optimized process conditions)
nd
– Train 2 ramp up can be slow down due to Ethane shortage
2nd Train
p p g
9/3/201312
FEEDBACK ON PLANT RESTARTSO ti i ti f th t tOptimization of the restart sequence
Main challenges:- Pipeline re-pressurization - Restart sequence: Not possible to restart 2 trains at the same time (flare design)- Lean gas composition and Ethane inventory limitations
Several axis of progress:
Warm end restart Pre‐cooldown Final cooldown Ramp‐up
Optimization of the “inter-steps”–Pipeline pressurization and warm end restart almost in parallelAnticipation of the restart:
preparation d ring sh tdo nFeedback tools
p–Anticipation of next step
O ti i ti f h St
preparation during shutdown…
9/3/201313
Optimization of each Step
FEEDBACK ON PLANT RESTARTSP t t d I t tPre-restart and Inter-steps
• Reduction of the gap between 2 steps
• Coordination / planning
• PR and MR compressors restart anticipated
• Lessons learnt: Feedback before & after restart
Good improvement : No gap between 2 consecutive steps
G i th ll l i 2 hGain on the overall planning = 2 hours
• Pressurization
• Pressure optimization in the upstream sections < 70 barg
• From upstream and downstream sections at the same time
Improvement = re-pressurization duration reduced by 10 hours
9/3/201314
FEEDBACK ON PLANT RESTARTSMCHE ldMCHE pre-cooldown
MCHE pre-cooldown to -30 degC MCHE pre-cooldown to -30 degC
Optimization of the cool down flow: Flow through MCHE is restricted by PV on shell side
LNG
g y Optimization done by early opening of the JTs and drains Increased feed gas flow Homogeneous cooldown of the MCHE
MCHE
HP MR separator and lines up to MCHE– Early cooldown recommended
FEED GAS
Early cooldown recommended– Done during pre-cooldown – to be ready for final cooldown
Gain on the overall planning = 10 hoursNGL
REINJECTION
HP MR sep
9/3/201315
FEEDBACK ON PLANT RESTARTSMCHE fi l ldMCHE final-cooldown
C iti l t 30 144 d C Critical step: -30 -144 degC Not possible to decrease the duration Nevertheless some optimizations done
VMR
Control of the cooldown rate Material constraint = 28 deg/h maximum Temperature control difficult when the MR
Monitoring with the VMR & LMR
PDI
Temperature control difficult when the MR starts condensing coils PDIs
LMR PDI
Feed Gas flow adjustment
9/3/201316
FEEDBACK ON PLANT RESTARTSEth tEthane management
Major impact on the restart sequence: – Very difficult to start LNG production without C2 in the MR loopVery difficult to start LNG production without C2 in the MR loop– Ramp-up strongly impacted by C2 shortage
Lean feed gas composition– Long time to build C2 inventory Minimum level to be kept in the C2 bullet at any time
Recommendation during restart
C2 make up t di tl f d C2 t MR lsent directly from de-C2 to MR loop
C2 from C2 bullet: Priority for the 1st TrainPriority for the 1 Train To be be re-started as early as possible To produce C2 for the 2nd Train
9/3/201317
FEEDBACK ON PLANT RESTARTSE d fl h it t tEnd flash gas unit re-start
B d i b f th EFG it By design, no by pass of the EFG unit
At least 4 hours required to cooldown the LNG pumps and End Flash drum
Anticipation:– During plant ramp-down:
• maximize the level in the EFG drum– During plant shutdown:
• Monitor level in the EFG drum If required “re filling” operations by reverse flow from the RDL• If required re-filling” operations by reverse flow from the RDL
Gain on the overall planning = 4 hours
9/3/201318
FEEDBACK ON PLANT RESTARTSPl t d d h tdPlant ramp down and shutdown
Pipeline de-pressurization and plant ramp down check list including:
1 train immediately stopped
1 train producing until pressure at CRF is 50 bara 1 train producing until pressure at CRF is 50 bara Minimum to operate the train Ease to PPL re-pressurization
C2 i i i d d i d C2 inventory maximized during ramp-down
Driers sequence stopped at the end of cycle 1 fresh drier ready for restart
Plant shutdown – Amine unit Amine circulation stopped to avoid gas losses through amine flash drum Filtration is kept runningFiltration is kept running
9/3/201319
FEEDBACK ON PLANT RESTARTSR t t ti i ti C l iRestarts optimization - Conclusion
7 t t f b th T i 7 restarts for both Trains Good improvement of the restart sequence, reduced by 1.2 days High level of experience of operators on restart operations
Way forward: Keep the knowledge for next restarts Reduction of the flaring during re-start
MR composition adjustment due to MCHE leak PV at the top of MCHE shell connected to the fuel gas network
Not used because mainly N2 is vented To reduce C1 content in MR loop:
HP MR separator is used Modification on-going to re-route this line to the fuel gas network
(instead of flare)
9/3/201320
OTHER OPERATIONAL FEEDBACKST i 2 l d SD i M 2014Train 2 planned SD in May 2014
The biggest planned shutdown ever planned
• All the initial scope completed (Main: turbines HGPI*)
• 2 days ahead the schedule (6th May to 17th May 2013)
• Zero accident
• Frame 7 Hot Gas Path Inspection: turbines in very good condition
48 V l F d H t h i t d ( j• 48 Vessels, Furnaces and Heat exchangers inspected (no major
issue)
• Inlet orifice replaced on Train 2
• Driers beds changed out
• ESDV-47001 downgraded situation rectified
• Elliot Compressors: replacement of 6 conical start up strainers by
spacers
* HGPI: Hot Gas Path Inspection
9/3/201321
OTHER OPERATIONAL FEEDBACKST i 2 I l t ti f t iTrain 2 – Implementation of new venturi
Benefits of reducing pressure drop:I th i li it• Increase the pipeline capacity
• Bigger buffer effect (packing/depacking)• Fuel gas savings at Upstream
Design flow rate
D i DP
9/3/201322
Design DP
Yemen LNGOperational feedbacks
THANK YOUTHANK YOU
APCI conference – September 2013APCI conference – September 2013
9/3/201323