LNG Prigorodnoye Overview

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

SEIC LNG Train 1

LNG Plant Overview N Substation Elec/Inst

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.

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

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%.

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

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

Transporting C1101 for installation during construction

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

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.

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

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

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

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)

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!

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%

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%

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%

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

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).

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

LNG PLANT DETAILS

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

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

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

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

U-1400 Liquefaction Unit Substation Elec/Inst

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

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).

Process Description - PMR Substation Elec/Inst

K-1440 PMR Compressor HELPER MOTOR CENTRIFUGAL COMP GAS TURBINE

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.

Process Description - MR Substation Elec/Inst

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!!!

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.

K-1450 End Flash Compressor

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.

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 +

U1500 Process Description Substation Elec/Inst

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

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.

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

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

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

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.

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

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

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

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-6201. 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-6201. 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.

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)

Unit 6200 Flare system

Unit 6200 Flare system