1. LNG Prigorodnoye Overview

2. GAS TURBINE COMPRESSOR
LNG TRAIN 1
60 barg
PRESSURE CONTROL
LNG OPERATIONAL OVERVIEW
PRIGORODNOYE
65 – 90 barg
GAS TURBINE COMPRESSOR
65 – 90 barg
PIPELINE
LPG RE-INJECTION
LIQUIFICATION
-COLD END
LIQUIFIED NATURAL GAS
OPF
BOOSTER
METHANE GAS
REFRIGERANT STORAGE
FRACTIONATION
LPG
SCRUB
U-1500
E1402
GAS TREATING –WARM END
CO2 REMOVAL
WATER REMOVAL
Hg REMOVAL
E1401
LNG TRAIN 2
STORAGE & LOADING
STORAGE TANK

3. SEIC LNG Train 1

4. LNG Plant Overview N
Substation
Elec/Inst

5. Unit 1000 Inlet Metering
Feed gas from the OPF enters unit 1000 between 65 to 95 bar at ~20o C.
The gas leaves the unit at 60 bar at temperature of ~0o C.
The feed gas from U1000 is fed to U1100.
Unit 1000 consists of three parallel meter runs, each consisting of a feed
gas mono-cyclone separator (V-1001A/B/C), and a flow/pressure control
station.
This maintains the feed gas supply pressure at 60 bar to the LNG plant.
Each meter run is capable of supplying 33.3% of the overall design gas
Flow for the two LNG trains.

6. U-1000 Gas Inlet and Metering
V1001 A/B/C gas separators with flow & pressure control
Gas Pipeline From OPF

7. Unit 1100 Acid Gas Removal unit.
Purpose of the Acid Gas Removal unit is to remove
CO2 and H2S from the natural gas.
Why?
To prevent freezing and blockages in the liquefaction unit (U1400).
Each train has its own dedicated acid gas removal unit.
The solvent used in the unit is Shell Sulfinol D.
The solvent is made up of the following:
Water 25%.
Di-isopropanolamine (DIPA) 50%.
Tetra-hydrothiophene-dioxide (Sulfolane) 25%.

8. U-1100 Acid Gas Removal Unit
U1100 Sulfinol Treating
Substation
Elec/Inst

9. U-1100 Acid Gas Removal Unit
C-1101 – Absorber
V-1103– Regenerator Overhead Accumulator
C-1102 – Regenerator
V-1101– Feed Gas Knock-out Vessel

10. Transporting C1101 for installation during construction

11. U1100 Principle Operation Absorber Regenerator Lean amine CO2 Out
Treated gas
to driers
Lean amine
CO2 Out
Absorber
Regenerator
CO2 is soaked up by the amine
and removed in the regenerator
To fuelgas
Rich amine
C1101
Raw gas
U1000
C1102
Heat In
GAS SEPARATOR
V1102

12. Purpose of U1300/U1350 Dehydration unit 1300
To remove water present in feed gas from Unit 1100.
Why?
To prevent downstream equipment blockage and damage by ice
and hydrate formation during the gas liquefaction process.
Mercury removal vessel 1350
To remove trace quantities of mercury that could be present in the
feed to liquefaction.
To prevent corrosion in the downstream equipment, and aluminium tube bundles of the MCHE’s.

13. U-1300 Dehydration Unit and U-1350 Mercury Removal
Substation
Elec/Inst

14. U-1300 Dehydration Unit and U-1350 Mercury Removal
C-1351 – Mercury Absorbent Vessel
C-1301 A/B/C – Molsieve Dryer Vessels

15. FAR, Substation and Analyzer House
SS-410
ANC-1

16. Purpose of Unit 1400
In unit 1400, the feedgas is progressively cooled until it condenses at around –158 degrees C and is subcooled to –162 before running down to the storage tanks. This reduces the overall volume around 600 times allowing one LNG tanker able to carry 600 times more than if the natural gas remained in a gaseous state. (135,000m3 LNG = 81,000,000m3! gas)

17. We have not changed this gas in anyway!
REFRIGERATION
PRINCIPLES
Compressing a gas makes its pressure and temperature rise because of the energy we have given it.
Depressuring this gas again would result in the pressure and temperature returning to the same point as we started.
We have not changed this gas in anyway!

18. We can graph this and see exactly what has happened.
REFRIGERATION
PRINCIPLES
We can graph this and see exactly what has happened.
HOT
HIGH
Temperature
Pressure
COLD
LOW
Compression 0% 0%
100%

19. REFRIGERATION PRINCIPLES
This time, after compressing the gas we will cool it to remove the heat energy we gave it.
HOT
HIGH
Temperature
Pressure
COLD
LOW
Compression 0% 0%
100%

20. This time when we depressure the gas the temperature becomes very low!
REFRIGERATION
PRINCIPLES
This time when we depressure the gas the temperature becomes very low!
HOT
HIGH
Temperature
Pressure
Additional
temperature
drop
COLD
LOW
Compression 0% 0%
100%

21. LNG PLANT PRINCIPLES -80 -180 TREATED FEEDGAS PMR MR LIQUIFIEDHP LP
LIQUID
GAS
-80
TREATED
FEEDGAS
LIQUIFIED
NATURAL GAS
-162
+10 MR LP HP
-180

22. Purpose of Unit 1400
Treated feed gas from the mercury removal unit (U1350) is cooled
against low pressure PMR in E-1402 and fed to the scrub columns.
The scrub columns, C-1401 & C-1402, remove heavy hydrocarbons
(C5+) and the LPG’s from the natural gas stream for 2 reasons.
These gases will condense too early in the fractionation section
The LPG’s are used as the refrigerant in U1400 cooling circuits.
The bottom product of the scrub columns is fed to the fractionation unit
(U1500).

23. Purpose of Unit 1400 (Cold End)
Substation
Elec/Inst

24. LNG PLANT
DETAILS

25. U-1400 Liquefaction Unit C-1402– Upper Scrub Column
E-1412– LP Pre-cool Exchanger
E-1411– HP Pre-cool Exchanger
C-1401– Lower Scrub Column

26. Main Cryogenic Heat Exchangers
U-1400 Liquefaction Unit
Main Cryogenic Heat Exchangers
Substation
Elec/Inst

27. U-1400 Liquefaction Unit E-1415A – Main Cryogenic Heat Exchanger
E-1415B – Main Cryogenic Heat Exchanger

28. Internals of the Main Cryogenic Heat Exchanger
U-1400 Liquefaction Unit
Internals of the Main Cryogenic Heat Exchanger

29. U-1400 Liquefaction Unit
Substation
Elec/Inst

30. E-1430 – Light MR/Endflash Exchanger
U-1400 Liquefaction Unit
V-1420 – LP MR Suction Drum
V-1430 – Endflash Vessel
V-1425 – HP/MR Separator
E-1430 – Light MR/Endflash Exchanger

31. Process Description - PMR
The PMR (pre-mixed refrigerant) system utilizes pressurized PMR,
a mixture of ethane and propane, evaporating at two pressures.
This supplies refrigeration to the NG feed circuit, the MR circuit and
the fractionation unit.
The PMR is compressed by gas turbine driven PMR compressor
K1440, power assisted by PMR compressor helper motor/generator
(KM-1440).

32. Process Description - PMR
Substation
Elec/Inst

33. K-1440 PMR Compressor
HELPER MOTOR
CENTRIFUGAL COMP
GAS TURBINE

34. Process Description - MR
MR – Mixed Refrigerant
The refrigeration to fully liquefy the feed gas is provided by MR (mixed refrigerant).
This is a mixture of nitrogen, methane, ethane and propane.
The MR system is a closed loop refrigeration system utilizing two
compressors in series, K1420/30. They share a single shaft and are gas
turbine driven.
The LP MR compressor (K-1420) is a single stage axial machine and the
HP MR Compressor (K‑1430) is a two stage centrifugal machine.
The MR compressor starter/helper motor (KM‑1420) is used for starting
the compressor, and also to provide additional shaft power to maximize
LNG production.

35. Process Description - MR
Substation
Elec/Inst

36. 80 MW's of power!!! K-1420/K-1430 MR Compressor HELPER MOTOR
MAN
HELPER MOTOR
CENTRIFUGAL COMP
AXIAL COMP
GAS TURBINE
80 MW's of power!!!

37. Process Description - End Flash System
Nitrogen in the LNG stream leaving the MCHE’s is removed in the end
flash vessel.
The nitrogen and some light hydrocarbons leave the top of the end
flash vessel and exchange cooling in the light MR/end flash gas
exchanger.
The gas is then compressed by the end flash gas compressor (K-1450)
and routed via the end flash compressor after-cooler to the HP fuel gas
system.

38. K-1450 End Flash Compressor

39. U1500 Process Description Purpose of Unit 1500:
To remove heavy components from the feed gas
To extract refrigerant components, and make up ethane and propane for storage.
Also to produce stabilized condensate for re-injection in the crude oil.
Any LPG’s not used in the refrigerant circuit are re-injected back into the liquefaction section as part of the LNG rundown.

40. U1500 Fractionation C1 C2 + C3+ C4 + C5 + C1501 C1502 C1503 C1504
E1415
C1401
V1504
V1503
V1502
U1500 Fractionation
C2 Make up
U1600
C2 NGL
C3 Make up
C3 NGL
27barg
14barg
9barg
3barg
E1502
E1504
E1506
E1513
NGL
OET
E1508
P1505
P1504
P1501
P1502
P1503
E1501
E1503
E1505
E1507
E1510
C4 NGL
-50degC
-10degC
35degC
40degC
109degC
-30degC
85degC
99degC
86degC
67degC
V1425
Re-process
NGL re-injection
PMR
HTF C4 C2 C3
103degC
Stabilised
condensate
7degC
-13degC
-15degC
33degC
38degC
Vapour
Make up C1
C5 +
C4 +
C3+
C2 +

41. U1500 Process Description
Substation
Elec/Inst

42. U-1500 Fractionation Unit C-1501– Demethanizer Column
C-1502– Deethanizer Column
C-1503– Depropanizer Column
C-1504– Debutanizer Column
V-4201– Tempered Water Expansion Vessel

43. U1600 Process Description
The ethane and propane/PMR storage systems are common to both LNG Trains and are used primarily to supply start-up refrigerant for the PMR and MR cycles in the Liquefaction Unit, U-1400.
The purpose of Unit 1600 is to provide storage for refrigerant grade ethane and propane produced in Unit 1500 De-ethaniser and the De-propaniser.

44. U-1600 Refrigerant Storage
T-1601 – Ethane Storage
T-1602 – PMR Storage

45. LNG Storage Tanks
T-3102 LNG Tank No. 2
T-3101 LNG Tank No. 1

46. LNG Storage Tanks / Boil Off Gas
To store and load Liquefied Natural Gas and to collect and compress the vapor generated from the process of filling the tanks.
This is known as BOG (boil off gas) Vapor created when loading LNG ships (ship vapor return) is used used as fuel gas

47. LNG Storage Tanks / Boil Off Gas
There are two LNG Storage tanks each with a capacity of 100,000m3
Eight loading pumps each with a discharge capacity of 1250 m3/Hr
One boil off compressor with a capacity of 730T/D
There are Four loading arms, Two for LNG liquid, One vapour return arm & a spare for either liquid or vapour service allow ship loading to be carried out based on a 24 hour turn around.

48. FLARE K3401 Boil off gas Fuel gas system End Flash compressor V3401PC
Boil off gas header
End Flash compressor TC
V3401
Vapour Arm LC
Loading Arm
T3100
LNG Loading line

49. Liquid disposal burners and Ops flare
Emergency Flare stack
Unit 6200 Flare system
Liquid disposal burners and Ops flare

50. Unit 6200 Flare system FLARE Why do we have a Flare System?
The flare system is used to collect and dispose vapour and liquid in a safe manner. (Safe disposal of Hydrocarbons, the first system online and the last system shut down)
Flare Systems
Emergency operational system for cold, light, dry streams, liquid and vapour.
Emergency operational system for warm, heavy, streams, liquid and vapour.
Emergency operational system for LNG storage and loading, vapour.
Operational flare system, vapour.
LNG disposal system, liquid and vapour (start-up).
Spare flare can be used for cold and warm service.
FLARE

51. Unit 6200 Flare system Warm Flare System (FWW)
All the warm vapours are collected into a single 48” header which slopes to the liquid knock-out drum V The header is continuously purged with LP fuel gas at sufficient flow rate to keep velocity at the tip of flare stack. Nitrogen connection is also given as back-up purge source.
Warm Liquid Disposal System (DHC)
The warm liquids from manual drains are collected in a 4” header and routed to V Light components are flashed-off and burned in A-6201 (FWW) The accumulated liquid in V-6201 is pumped and transferred to warm liquid burner A-6204 by P-6201A/B via 6” line.

52. Unit 6200 Flare system Cold Flare System (FCD)
Cold dry and light hydrocarbon vapours from unit 1400, 1500 and 1600 are collected into a 48” header which slopes to the cold flare KO drum V-6202.The header is continuously purged with LP fuel gas. Nitrogen connection is also given as back-up purge source.Vapour from the cold flare KO drum is directed to the cold flare (A‑6202) through a 56” line.
HP fuel gas is used as atomising gas to flare stack A-6202
Cold Liquid Disposal System (DLH)
All the cold liquids are collected into two 12” headers that are routed to the cold flare KO Drum (V‑6202). flashed vapours are removed and burned in A-6202.
Operational Flare System (FOP)
Any operationally initiated release is vented to a separate 16” FOP header.
The vented gas is routed to V-6203 and burned in operational flare (A-6211)

53. Unit 6200 Flare system

54. Unit 6200 Flare system