Pipeline Project Description

7/28/2019 Pipeline Project Description

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ProjectDescription

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S A K H A L I N E N E R G Y I N V E S T M E N T C O M P A N Y E N V I R O N M E N T A L I M P A C T A S S E S S M E N T 2-1

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2.1 OVERVIEW

The pipeline system is required to transport oil and gas from the production fields in

the north east of the island to Aniva Bay in the south of the island. Aniva Bay is

relatively ice-free and so will allow year round export of the oil and gas to the

international market. The main gas pipeline has a capacity to transport 50.1 x 106 Sm3

d-1 (1768 x 106 scf d-1) in winter and 40.8 x 106 Sm3 d-1 (1440 x 106 scf d-1) during

summer. The main oil pipeline has a capacity of transporting 31 003m3 d-1 (195 000 b d-1).

This chapter describes the onshore pipeline transportation and associated facilities

section of the Sakhalin II, Phase 2 project. It consists of the following main

components:

main oil pipeline from the Piltun landfall to the Oil Export Terminal via the OilBooster Stations;

mainline gas pipeline from the Piltun Landfall to the LNG Plant via the BoatasynGas Disposition Terminal and Gas Compressor Stations; and

two multiphase pipelines bringing product from Lunskoye landfall to the OPF andand one pipeline transporting monoethylene glycol (MEG) from the OPF to the

Lunskoye landfall.

This section also covers a telecommunications fibre optic cable to be installed alongthe pipeline route, as well as pipeline construction camps and lay-down areas that

will be uti lised during the construction phase of the main pipeline.

A summary of the design details of the onshore pipel ines is provided in Table 2.1

(BOD, Revision 5). Imperial units are given in parentheses.

Table 2.1 Onshore Pipeline Design Details

Product Description Dia. mm (") Length km Steel Grade

Oil Piltun Landfall to OPF 508 (20) 171 X65

Gas Piltun landfall to OPF (via GDT) 508 (20) 171 X65

Gas and

Condensate Lunskoye landfall to OPF (2 pipelines) 762 (30) 7 X65

MEG OPF to Lunskoye landfall 114.3 (4.5) 7 X52

Oil OPF to LNG plant (via BS#2 at 319 610 (24) 637 X65

from OPF)

Gas OPF to LNG plant (via BS#2 at 319 1219 (48) 636 X70

from OPF)

Generally this section is written with reference to the following three components:

the pipeline system (encompassing the oil, gas, and onshore sections of themultiphase and MEG pipelines);

the Gas Disposition Terminal (GDT); and

Booster Station #2 (BS#2) - encompassing the oil booster station and the gascompressor station;

An overview of the onshore pipeline system is included asFigure 1.2 in Chapter 1.

The GDT is located approximately 5 km north of the village of Val, in the north east of

the island.

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Chapter 2 Project Description

2-2 E N V I R O N M E N T A L R E S O U R C E S M A N A G E M E N T


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Figure 2.1 Map showing Construction Spreads, Construction Camps, Pipe lay-down andWelding Yards.

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Table 2.2 ROW Landtake Details per Sakhalin Region Land Category

Classification Total Sakhalin Island Pipe-line % of % of

Land Classificat ion ROW Total Total

(01 Jan 2002) ROW Region

ha. % ha.

Forestry Fund Land 6 950 200 79.8% 2 350 70.9% 0.0270%

State Reserve Land 993 400 11.4% 233 7% 0.0027%

Land Used for Industrial 336 300 3.9% 9 0.3% 0.0001%

Purposes, Transportation,

Communication, Radio and

TV Broadcasting, Computer

Science, Space Research,

Military Defence and

Other Special Purposes

Agricultural land 177 900 2.0% 591 17.7% 0.0066%

Protected Areas* 122 300 1.4% 55 1.7% 0.0006%

Land of Settlements 83 200 1.0% 95 2.9% 0.0011%

Water Fund Land 46 800 0.5% 0 0.00% 0.0000%

Total area of lands 8 710 100 100.00% 3 333 100.00% 0.0383%

* The pipeline runs through the Makarov Nature Reserve (4.9 km * 43 m. wide) and Izubrovij Nature Reserve (8.0 km *

43 m. wide). Pipeline does not go via specially protected zones of these Natural Reserves.

Gas Disposition Terminal (GDT)

The GDT site is rectangular, sized 116 m from north to south and 112 m from east to

west. The area of the site is 1.3 ha comprising 1897 m2 for construction, area of

passages is 3621 m2 and the area of landscape gardening is 7474 m2.Beyond the fence

at a distance of 100 m southwards, there is a gas vent.

A road is planned to connect the GDT to the existing road network. The road is likely

to parallel the existing Okha - Komsomolsk-on-Amur gas pipeline route that adjoins

the Okha - Noglikiroad.

Due to the few and low emissions from the GDT, no sanitary protection zone is required.The main co-ordinates of the GDT and BS#2 are shown in Table 2.3 (BOD, Revision 5).

Table 2.3 Main Co-ordinates for GDT and BS#2

Facility UTM UTM Geodetic Geodetic BSL 7 7 KP onEast North Latitude Longitude (m)2 pipeline

(m)1 (m)1 (N)1 (E)1 route

GDT 638 897 5 810 253 52 25 143 02 +37 41.1

29.37 33.88 (section 1)

BS#2 640 944 5 440 060 49 05 142 55 +34 279

50.04 50.85 (section 4)

Notes: 1. Universal Transverse Mercator (UTM) co-ordinates and corresponding geodetic positions are in Zone 54N,

Central Meridian 141E. UTM locations are in metres and geodetic locations are in degrees, minutes and seconds. All

co-ordiantes relate to the World Geodetic System 1984 (WGS 84) ellipsoid and datum.2. Baltic Sea Level (BSL) 77 is used for all onshore locations

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Booster Station #2 (BS#2)

The permanent sites are:

The site of booster-compressor station proper with the area of 6.7 ha;

helipad 1 ha;

artesian well site 0.2 ha; and intersite roads with roadsides 0.63 ha.

The total area of lands allocated for construction of stationary facilities of BS#2 is

8.33 ha (TEO-C,Volume 3, Book 8.3.1, Section 7).

The Sanitary Protection Zone (SPZ) for BS#2 is represented by a circle with a radius

of 2200 m during normal operations and 2100 m during initial (gas free) operations

(TEO-C,Volume 3, Book 8.3.1, Appendix E.1).

The size of the BS#2 construction camp is approximately 250 m x 155 m, making an

area of approximately 3.8 ha (TEO-C,Volume 3, Book 7, Section 3,Appendix H).

Construction Camps, Pipe Welding yards and Lay-down areas

The actual size of construction camps and lay-down areas will vary, however as an

indicator of size, the Val camp/Pipeline Welding Yard and Workshop Area has a land

allocation of 25 ha.

The two additional laydown yards not associated with a camp are approximately 3 ha

each in size. These laydown yards do not serve as welding yards.

2.1.3 Construction, Commissioning and Operation Schedule

The master schedule for the project is included in Volume I.The current overall pipeline construction has the following main milestones:

Commence camp set up Q1 2003

Commence construction Q3 2003

Commission pipelines to GDT Q4 2004

Commission entire pipeline route Q4 2005

These milestones are subject to adjustment depending upon changes in the overall

project schedule. The most foreseeable changes are likely to lead to commissioning

of the pipelines to GDT occurring in Q4 2005, with entire commissioning in Q4 2006.

Construction is planned to commence simultaneously on each of the five construction

spreads.


Duration of GDT construction is estimated to take 50 weeks based on a 10-h working

day and 6-day working week.

Taking into account the condition of roads in the Okha - Nogliki region from the end

of April to the beginning of June, it is recommended that construction follow the

outlined schedule below:

begin the construction in October 2003 (camp construction); transportation of main cargoes (soil, sand, rip-rap, reinforced concrete) - December

2003-March 2004; and

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implementation of main scope of construction and installation - May-September2004;

This allows a 1-2 months reserve with regards to scheduled completeness (Gas supply

to GDT) - November 2004. As noted in the overall schedule above, that indicates

dates are likely to be postponed by up to 1 year, the GDT schedule may also be

postponed depending upon shifts in the overall project schedule.

The recommended time of beginning the construction will enable fulfilment of the

main scope of construction and start-up works that can be carried out in the open air

during summer and autumn, which will minimise the downtime due to the

unfavourable weather conditions (TEO-C,Volume 3, Book 7, Part 4).

Booster Station # 2 (BS#2)

BS#2 is only needed when the oil flow rate exceeds approximately 140 000 Barrels of

Oil Per Day (BOPD) or when the second LNG train is in operation (currently planned

for 2008), whichever is first.

Construction is planned to commence in the third quarter of 2006 and be completed

by the first quarter of 2008. Thus, BS-2 construction will take 21 months.

2.2 PROCESS

2.2.1 Process Flow

Pipeline

Gas

The primary export route for gas is to the LNG plant at Prigorodnoye. The GDT will

allow for the flow of SEIC gas into the existing domestic gas infrastrucure, which is

currently limited to a network of pipelines in the north of the island operated by

Sakhalinmorneftegaz (SMNG), as shown in Volume I, Figure 5.3. The daily gas

production will need to respond to changing and predominantly seasonal demands

from the LNG plant and domestic gas users.

The gas pipeline volume requirements are shown in Table 2.4 and the pressures and

temperatures in Table 2.5. These tables are based on BOD Revision 5, however exclude

detailed design notes.

Table 2.4 Gas Pipeline Volume Requirements (1)

Pipeline Section Design Capacity 106Sm3 d-1 (106scf d-1)

North: Associated Gas Only to OPF Design Case (summer and winter)

PA-A to Shore 1.7 (60)

PA-B to shore 2.6 (92)

Piltun Area Shore Manifold to OPF 3.8 (134)

South: Lunskoye and OPF to LNG Season

Lunskoye to OPF Winter Design: 52.3 (1847)

OPF to LNG Winter Design: 50.1 (1768)

Lunskoye to OPF Summer Design: 45.8 (1619)OPF to LNG Summer design: 40.8 (1440)

(1) For full description of design assumptions see BOD Rev 5.

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Table 2.5 Gas Pipeline Pressures and Temperatures (2)

Pipeline Section Normal OP MOP MAOP Temperature Range

(barg) 1 (barg) 2 (barg) 3 for Hydraulics (C)

PA-A Gas Export 80 98 100 20/30PA-B Gas Export 81 98 100 38/60

Lun-A Multiphase Wet Gas/ 94 98 100 20 to 45

condensate/MEG Export to OPF 94 98 100 20 to 45

OPF inlet (from Lunskoye) 85.5 98 100 33

GDT 70 98 100 15/20

BS#1 Inlet (Piltun area gas and OPF gas) 58 98 100 15/20

BS#1 Discharge 96.5 98 100 40/45

BS#2 Inlet 65 98 100 -3/+5

BS#2 Oulet 95 98 100 40

SE gas pipeline outlet to LNG plant 66 98 100 -3/+5

1. Normal OP - Normal or typical operating pressures are indicative only and will be further evaluated during detailed

engineering,

2. MOP - Maximum operating pressure.

3. MAOP - Maximum allowable operating pressure, maximum pressure based on design code and materials.

Oil

Oil will be produced from the Piltun-Astokhskoye field and from the condensate/oil

rim from the Lunskoye field.

The oil pipeline system design capacity is summarised in Table 2.6 and pressure and

temperatures in Table 2.7. These tables are based on BOD Revision 5, however exclude

detailed design notes.

Table 2.6 Oil Pipeline System Design Capacity (2)

Pipeline Section Design capacity m3 d-1 (b d-1)

PA-A oil export 14 309 (90 000)

PA-B oil export 11 129 (70 000)

Combined Pa-A and PA-B to OPF 23 530 (140 000)

OPF to OET 31 003 (195 000)

OET to TLU 190.8x103 (1.2x106)

Table 2.7 Oil Pipeline System Pressures and Temperatures (2)

Pipeline Section Normal OP MOP MAOP Temperature Range

Operating (barg) (barg) (barg) for Hydraulics (C)

PA-A oil export 88 91 100 25/45

PA-B oil export 88 91 100 38/60

OPF Oil BS#1 suction 7 91 100 10/20

OPF Oil BS#1 outlet 70-80 91 100 10/20

BS#2 suction 7-11 91 100 -3/+5

OET inlet 18-20 91 100 -3/+5

TLU inlet Summer 11.29 25 60 -7/+20

Winter 12.24

(2) For full description of design assumptions see BOD Rev 5.

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Additional design features include AGIs (Above Ground Installations) such as block

valves and pigging stations.

Block Valves

Block valves are located at least every 30 km along the pipeline and more frequently

where there are additional features such as major rivers or seismic faults. Block valves

are installed in order to be able to isolate pipeline sections in the event of anemergency or pipeline failure. The number of block valves is shown in Table 2.15.

All block valves are buried.

Table 2.8 Number of Oil, Gas, Multiphase and MEG Block Valves.

Section Oil Gas MEG Multi-phase

Piltun: landfall to Pig launcher/receiver at KP1.2 2 2

Piltun: Pig launcher/receiver at KP1.2 to OPF 25 8

Pipeline from OPF to OET/LNG 82 35OPF to Lunskoye landfall 1 4

Pigging Stations

Pig launchers/receivers are designed to allow for removal of internal scale (mud,

paraffins etc) and any liquid holdup, as well as for intelligent pigging whilst

maintaining the full pipeline capacity during the pigging operation.The pig launching

and receiving stations on the pipeline route are shown in Table 2.9.

Table 2.9 Pig Launching and Receiving Stations.

Segment KP Gas Pipeline Oil Pipeline

1 1.2 350mm (14") pig receiver site from PA-A 350mm (14") pig receiver site from PA-A

1 1.2 350mm (14") pig receiverL/R site from PA-B 350mm (14") pig receiver site from PA-B

1 1.2 508mm (20") pig launcher s ite to OPF 508mm (20") pig launcher s ite to OPF

6 7 508mm (20") pig receiver s ite at OPF 508mm (20") pig rece iver s ite a t OPF

6 7 1219mm (48") pig launcher s ite a t OPF 610mm (24") pig launcher s ite at OPF

3 278.9 1219mm (48") pig L/R site at BS#2 610mm (24") pig L/R site at BS#2

7 599.54 1219mm (48") pig receiver site at LNG plant 610mm (24") pig receiver site at OET

Gas Disposition Terminal (GDT)The GDT serves as a pressure regulating and metering station for the transfer of gas

into the existing SMNG gas distribution network on Sakhalin Island. It consists of the

following systems and utilities:

gas filters;

gas pressure regulating skid;

gas custody transfer metering;

emergency Shut Down system with relief header and vent pipe ;

GDT mainline inlet, outlet and bypass piping and valves;

power generation with emergency back-up system; grounding system for lightning control;

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primary and back-up gas fuel measurement, regulation, and distribution systems;

process drain system;

telecommunications, SCADA and system control equipment;

fire detection and control system; and

civil works, roads, drainage, fencing and foundations.The GDT is designed to be Not Normally Manned (NNM) and shall be fully

automated with systems interface for remote monitoring and control from the Central

Control Room at the OPF.

The GDT design requirements are shown in Table 2.10 (BOD, Revision 5) and the site

layout is shown inFigure 2.2 (TEO-C,Volume 3, Book 2, Section 4, Appendix F).

Table 2.10 GDT Design Requirements

Element Detail

Location Near Boatasyn (approx 41 km from Piltun landfall)

Main Systems Gas f iltering,pressure reduction and custody transfer metering

Gas Flow Rates Design flow rates:

8.496105 Sm3/d (30x106scf/d) to 3.398x106 Sm3/d (120x106 scf/d)

Required delivery pressure to SMNG is 70 barg. Maximum is 75 barg.

Power Generation Gas fuel power generation, 2x100% units (normally both running at 50%

capacity) and 1x100% standby unit as standby emergency generator

Utilities / Buildings Power generation, primary and back-up Gas Fuel, Process Drains,Vent system.


Design Requirements of BS#2 are shown in Table 2.11 (BOD, Rev 5).

Table 2.11 Design Requirements for BS#2

Element Detail

Location Near Gastello (approx 319 km from OPF)

Main systems Booster / Compressor Station

Gas Compression / Export 50.1X106 Sm3 (1755(106 Sft3) of gas per day

Estimated fuel gas consumption is 0.3X106 Sm3 (11X106 Sf3) per day

Oil Export 195 000 barrels (31 003 m3) of oil per dayPower Generation Gas Fuel power generation, 3x50% units and Emergency Diesel generator

Utilities/Buildings Power Generation,Potable Water, Service Water, Diesel and Gas Fuel,

Instrument and Utility Air, Process Drains, Sewage,Vent, Facility Heating,

Helipad, Administration Buildings, Warehouse and Maintenance Building,

Fire Post Building

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Figure 2.2 GDT Site Layout

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Oil Booster Station components:

gas turbine driven centrifugal crude oil booster pumps;

Emergency Shut Down (ESD) control system;

station mainline crude oil inlet, mud filter, outlet and bypass piping and valves;

High Integrity Pressure Protection System (HIPPS), piping and controls;

oil pipeline pig launcher and receiver.Gas Compressor Station components:

gas turbine driven centrifugal compressor;

compressor ESD control system with discharge header and vent pipe;

station mainline gas inlet, outlet and bypass piping and valves; and

gas pipeline pig launcher and receiver.

Common elements:

gas turbine driven electric power generators, with back-up diesel fuelled emergencygenerator and electrical distribution and lighting system;

ground system for lightning control;

fuel measurement, regulation, and distribution systems for both gas fuel and dieselfuel;

water well, treatment, and distribution systems for domestic and fire water service;

utility and instrument air supply system;

sanitary waste treatment and disposal system;

oily water drainage, treatment and disposal system;

diesel fuel storage tank;

telecommunication, SCADA and system control equipment with battery UPSback-up;

fire detection and control system;

civil works, roads, drainage, fencing and foundations;

lighted helipad;

pipeline maintenance vehicles, light construction equipment, furnishings, tools,consumables;

administration building with control room;

warehouse and maintenance bui lding; boiler house and hot water heating system; and

Fire Post Building.

The general layout and the equipment layout is given in Figure 2.3 (TEO-C,Volume 3,

Book 3, Section 3, Appendix E).

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Figure 2.3 BS#2 Layout

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Operation of the oil boosting and gas compression units will be noisy. The design

guidelines for the station dictate that sound pressure levels shall not exceed:

85 dB(A) within BS#2 station boundaries;

65 dB(A ) for the external work area noise in front of administration building walls;

95 dB(A) inside noisy buildings (crude booster pumps shelter, power generatorsshelter, gas compressor shelter); and

45 dB(A) at 700 m from BS#2 station near Gastello residential area.

There is an absolute sound pressure level of 115 dB(A) in any situation, including

emergencies such as blowing of safety/relief valves. The impulse noise level shall not

exceed 135 dB(A).

2.2.2 Waste Streams

An estimate of waste aris ings has been completed as part of the Solid Waste

Management Plan (SWMP) that considers wastes from the pipeline system, GDT and

BS#2 (Table 2.12). As can be seen the total amount of waste generated duringconstruction is estimated to be approximately 90 000t, as opposed to approximately

210t per year during operations. Waste management is discussed in detail in the

SWMP, for further information refer to Volume Iof this EIA.

Table 2.12 Combined Waste Generation Estimate for Pipelines and BS#2.

N FWCC Hazard Waste Type Construction Operations

Code Class (all period), t (annual), t y-1

1 WASTE OF HAZARD CLASS I

1.1 353000 I Spent mercury light bulbs/tubes 0 0.11.2 I Activated carbon contaminated with n/a n/a

mercury sulphide

Sub-total 0 0.1

2 WASTE OF HAZARD CLASS II

2.1 353000 II Spent dry-charged batteries (chemical 1.4 0

current source)

2.2 521000 II Waste sulphuric acid (electrolyte) 17.6 0.11

2.3 971000 II Medical wastes 2.2 0.01

2.4 593000 II Waste chemicals 40 1

2.5 550000 II Waste organic solvents 10 1

2.6 541000 II Waste lubricating oil 786 3.9

Sub-total 857.2 6.02

3 WASTE OF HAZARD CLASS III

3.1 549000 III Oiled rags 98.4 0.25

3.2 549000 III Waste oil and air filters 52 0.3

3.4 549000 III Oil contaminated soil including sorbents 55 0.3

3.6 570000 III Spent X-ray films 45 n/a

3.7 353000 III Batteries - lead cell (without electrolyte) 90 0.35

3.8 548000 III Bitumen, tar paper, ruberoid, insulation materials 330 n/a

3.9 550000 III Paints/wood dyes, adhesives 30 0.5

555000

Sub-total 700.4 1.7



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Table 2.12 Combined Waste GenerationEstimate for Pipelines and BS#2 Continued

N FWCC Hazard Waste Type Construction Operations

Code Class (all period), t (annual), t y-1

4 WASTE OF HAZARD CLASS IV

4.1 596000 IV Spent filter material not contaminated 2 0.1

with harmful substances

4.2 943000 IV Sludge from a biological wastewater 1927.7 4.11

treatment facilities

4.3 947000 IV Sludge generated in the course of mechanical 77.6 0.16

treatment of domestic wastewater

4.4 390000 IV Waste brake blocks and clutch plates 32 0.3

4.5 399000 IV Waste cement 71 n/a

4.6 110000 IV Food wastes 3968 8

Sub-total 6078.3 12.67

5 WASTES OF HAZARD CLASS V (PRACTICALLY NON-HAZARDOUS)

5.1 351000 V Ferrous metal scrap 2790 150

5.2 353000 V Non-ferrous metal scrap 174 0.155.3 353000 V Spent welding electrodes 85 1

5.4 575000 V Tyres with metal cord/textile cord 418.7 10

5.5 390000 V Waste abrasive materials (abrasive sand) 4000 n/a

5.6 399000 V Waste concrete and reinforced concrete 2200 n/a

components

5.7 570000 V Polimer/plastic wastes (industrial) 60 n/a

5.8 173000 V Brush wood 61 855 n/a

5.9 170000 V Construction wood 9500 n/a

5.1 187000 V Uncontaminated waste paper/cardboard; 300 20

paper/cardboard manufacture

5.11 581000 V Waste textile clothes (working clothes) 108.8 0.22

5.12 314000 V Uncontaminated clear glass/broken glass 100 1.5

5.13 911000 V Solid domestic wastes 2585 5.2

Sub-total 84 176.5 188.07

TOTAL 91 812.4 208.56

2.2.3 Engineering Considerations of Natural Hazards

The GDT and BS#2 have been sited to avoid high-risk areas in terms of natural

hazards. Their design will incorporate all standard oil and gas industry practise

measure to ensure safe operations under the expected conditions.

The major hazards that have been considered during pipeline design are:

mud flows;

landslides;

meliorative systems;

snow slides and avalanches; and

seismic faults.

Mud Flows and Avalanches

Along the pipeline route, there are five types of mud flows possible:

mud;

mud and stone;

alluvial;




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been carried out in accordance with the current Russian legislation (GOST), and takes

into account the best domestic and international practices.

Initiating events considered are leaks of varying sizes as well as catastrophic failure,

and event frequencies have been obtained from various literature sources. For the PTS,

the frequency data has been obtained from the European Gas Pipeline Incident Data

Group (EGIG), the State Safety Inspectorate of Russia, Transneft joint-stock companyand Gazprom joint-stock company.The frequency data for the equipment in the

booster station/GD terminal has been obtained from Sooby & Tolchard (1993), Smith

and Warwick (1991), E&P Forum (1992) and F. P. Lees (1980 & 1996).

Also taken into consideration are the seismic activi ty of the area, and the possibility of

tsunami generation. Event trees have been produced to identify the probabilities of

each scenario occurring.

Numerous causes of failure for both the PTS and booster/GD stations have been

identified and considered in this study, including:

mechanical wear, corrosion and physical damage associated with normal operation;

residual stresses;

deterioration due to thermal strain;

internal/external corrosion and/or vibration due to seasonal temperaturefluctuations;

high corrosion due to soil type and salt water;

corrosion due to defective insulation on pipes;

corrosion due to unreliable cathodic protection;

presence of hydrates in the process fluid;

external mechanical impact; operator error;

loss of power supply to booster station/GD terminal;

hydraulic shocks;

over/under pressure of system;

earthquakes and landslides;

washout of soil under pipelines;

forest fires;

ingress of foreign objects;

accidents at adjacent facilities;

terrorism;

lightning;

wind; and

ice loads on marine pipelines.

Design of PTS, GDT and BS#2

The design of the system includes numerous safety measures, and a number

of possible causes of hazards have been considered and accounted for.

The pipeline scheme has been designed to withstand a certain level of increased

loads and a number of factors have been considered.




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Figure 2.4 Typical Spread Construction Technique

installation by cutting and filling to the proper profile and cross slope (depending

on the season). Wherever possible, topsoil will be stripped and stockpiled separately,

which will be replaced upon completion of construction to promote successful

reinstatement. Erosion control measures will be installed (eg embankments, brush

piles or silt fencing) where required (see Section 2.3.7).

The double-jointed lengths of pipe are transported to the working width where they

are laid out on wooden supports parallel to the proposed trench. Gaps are left where

access across the working width is required. The sections of pipe are then welded into

continuous lengths between features such as roads, rivers, services etc using either

automatic or manual welding. Automatic welding is used primarily for three reasons:

ensure weld quality;

increase/sustain a high daily production rate; and/or

reduce the overall manpower requirements.

Manual welding is used where:

a supply of experienced welders is readily available;

difficult terrain, weather and site conditions exist;

special sections and areas with a high proportion of tie-ins; and/or

high production rates cannot be achieved.

Once welded, the joints are then x-rayed and a protective coating is applied

to the weld joints.



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Figure 2.5 Installation of FOC by Cable Layer


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installation of Distribution Control System (DCS), Emergency Shutdown system(ESD), Fire and Gas Detection and Protection System (F&G) control cabinets and

telecommunications equipment shelter;

installation of instruments and low voltage equipment; and

start-up & adjustment operations (TEO-C,Volume 3, Book 7.4).


Provision has been made for a 6 day working week (26 working days per month) and

a 10 hour working day. Construction is planned for two phases, preparatory and the

main.The following activities are planned for the preparatory period, which should

be completed within six months of commencement:

engineering preparation of a site territory for construction works (deforestation,topsoil removing, levelling, drainage, soil stock piling and roads);

camps construction to accommodate construction crew;

work-shops and layout yards;

construction of temporal water/power/heat supply; delivery of construction material, structures and equipment to a site; and

delivery of construction machinery and equipment.

The main construction period is further broken into two parts. The first part is the

general construction works that include:

earthworks (trenching, foundation and basement pit excavation);

construction of concrete foundations;

underground utilities (water-supply, sewerage, heating systems);

main line pump stations, gas section sites and other buildings and cable racks; erection of steel tanks of 100, 300 and 1000 m3volume, metal flood-lighting towers,lightning-rods, ladders, platforms and other facilities to serve valves and other

process facilities;

construction of inner site roads and yards;

footpaths, fencing; and

landscaping.

The second part of the main construction period is installation, involving the:

mounting of main-line pump stations, gas section block-containers, poser pack

(block-containers) and supporting process equipment with piping; and assembly of auxiliary facilities, fitting of separately located structures.

The main construction period should be accomplished within 21 months.

2.3.3 Workforce

Construction workforce numbers are summarised in Table 2.16.


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Table 2.16 Construction Workforce

Component Number Accommodation Arrangements

Pipeline 3-6000 10 construction camps along ROW

GDT 50-100 Construction camp near site

BS#2 200 (however construction camp will have Construction camp near sitecapacity for 400 people)

2.3.4 Temporary Infrastructure

Pipeline

Temporary infrastructure required to facilitate pipeline construction includes:

construction camps;

pipe welding yards;

lay-down areas ; and temporary access roads - for more information refer to Volume VIof this EIA.

There are 10 construction camp and laydown/welding yards and two additional

laydown yards, as shown inFigure 2.1. In general, they are close to major

transportation routes but also within 200 m to 5 km of the pipeline route itself.

The distances between construction camps varies from 30 to 80 km.

Site selection criteria for the construction camps included the following:

land type, suitable terrain, size, and configuration; and

existing environmental sensitivities (eg rivers);

scope of work for clearing the site;

easy reach of ROW;

round trip distance the contractor would have to travel to work that would becovered by the spread;

potential for using stretches of ROW for truck traffic to minimise the effect on localcommunities and not to overload local roads;

brown field site preference;

distance to main road, power supply and water source;

access to existing or potentially new railway sidings;

physical barriers between camp and local communities; and

subsequent benefits for the community (adapted from SIA draft).

The sites proposed as construction camp and laydown/welding yards are detailed in

Table 2.17and shown inFigure 2.1.


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Table 2.17 Proposed Camp and Laydown /Pipe Welding Yard Locations

Name Nearest Kilometre Distance from Construction

Post ROW (m) Spread

Val Camp/Laydown Yard 52.90 3980 1

Nogliki operations campNogliki Laydown Yard 1 113.90 3375 1

Nysh Camp/Laydown 5.40 390 1

OPF Site 171.80 155 1

SAR Camp* 6.30 16 085 2

Yasnoye Camp 102.60 3750 2

Yasnoye Laydown 103.40 1590 2

Onor Camp/Laydown 154.40 4870 3

Leonidovo Camp 261.90 2195 3

Leonidovo Laydown 262.70 1920 3

Poronaysk IUP Camp* 262.20 12 225 4

Booster Station 2 278.90 415 4

Tumanovo Camp/Laydown 316.80 1595 4Porechy Laydown 348.40 6865 4

Zaozernoye Laydown 377.80 6660 4

Pugachevo Laydown 398.70 215 4

Pugachevo Camp 400.80 1165 4

Sovetskoye Camp 484.10 1765 5

Sovetskoye Laydown 484.20 2200 5

Mitsulevka Laydown 570.20 625 5

Mitsulevka Camp 571.00 1160 5

Prigorodnoye LNG/OET 597.10 1720 5

* Refer to Volume VI

A typical construction camp and PWY layout is included asFigure 2.6.

Further information about the site selection process and description of the

construction camp locations can be found in the SIA (Chapter 7).


The temporary construction facilities required for the GDT will be built on the GDT

site during the preparatory construction phase. Such facilities include, but are not

limited to:

temporary buildings and structures at the construction site;

temporary construction camp; temporary access road;

temporary power supply network; and

lay-down yards for construction materials and structures.


Temporary infrastructure associated with the construction of the BS#2 includes the

construction camp and production base, both of which are briefly described below.


Fi 2 6 Pl t Pl f C d PWY t V l

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Figure 2.6 Plot Plan of Camp and PWY at Val


Construction Camp

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Construction Camp

The workers will be accommodated in a specially constructed camp and taken to the

site every day.The camp will be approximately 1 km away from the BS#2 construction

site. Both the construction site and the temporary construction camp will only be

operated within the BS#2 construction period.

The estimated camp area with temporary buildings and facilities is 3.84 ha (TEO-C,Volume 3, Book 7.3). It will provide accommodation for up to 400 people.

Production Base

The temporary production site will accommodate:

materials and equipment storage facilities;

maintenance and assembly workshops;

a fuels, lubes and greases storage facility

a garage and an open parking area for vehicles and mechanisms;

a washing-down facility; a boiler-house;

a diesel power plant; and

living quarters to accommodate 30 workers during the construction of theproduction site within the period of 3 months (preliminary work).

The yards and bins for temporary storage of solid production waste will be placed in

the same area (TEO-C,Volume 3, Book 3.2, Section 2).

2.3.5 Resource Usage

Pipeline

Construction Materials

The type of materials required for pipeline construction include:

pipeline materials (pipes, valves, pig launchers and receivers, CP instrumentationand anodes);

welding materials (electrodes, wire, fuel);

varied fil l requirements (sand, gravels, stone);

culverts, cement, concrete slabs;

tapes and wrapping; oils, chemicals, paints;

wires, cables, FOC; and

instrumentation and pressure control equipment.

Fuel and Lubrication Materials

It is estimated that approximately 77 400 000 litres of diesel and 1 300 000 litres of

petrol will be consumed during pipeline construction. Fuel will supplied from two

storage areas in Nevelsk or Kholmsk and Nogliki or Nysh or Kaigon and delivered

to camps by rail and motor tankers where it will be stored in bunded 300 m3 tanks

(TEO-C,Volume 3, Book 7.2).


Inert Materials

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Inert Materials

Construction materials (crushed stone, sand, gravel) will be sourced from local

quarries. Information regarding quarries is presented in Volume VI of this EIA.

The amount of crushed stone and sand required for the establishment of construction

camps/PWYs is shown in Table 2.18, the amount of sand required for pipeline

construction is shown in Table 2.19. In total, these materials represent over 4 500 000

m3. In addition to these raw materials, it is estimated that 140 000 m3 of concrete will

be required for ballasting of the pipeline.

Table 2.18 Crushed Stone and Sand Requirements for Construction Camps / PWYs.

Location Crushed Stone Requirement (m3) Sand Requirement (m3)

Val 30 300 10 500

Nogliki 30 300 10 500

Nysh 30 300 10 500

Yasnoye 30 300 10 500Onor 10 100 3500

Leonidovo 10 100 3500

Tumanovo 30 300 10 500

Pugachevo 30 300 10 500

Sovetskoye 30 300 10 500

Mitsulevka 30 300 10 500

BS#2 Camp 700 40 000

GDT Camp 200 1000

Total 263 500 13 200

Table 2.19 Sand Requirements for Pipeline Construction per Segment.

Pipeline Sand for pipeline Sand for trench fill Sand for pipeline

Segment (refer padding in heaving in fault areas (m3) padding in rocky or

to Figure 1.3 in soils with soil frozen areas (m3)

chapter 1) substitution (m3)

1 & 8 31 2562 3000

6 99 570 116 985

9 & 2 247 115 506 976

3 903 817 24 970 506 976

4 355 854 6607 270 8845, 7 604 194 17 193 270 884

TOTAL 2 523 112 51 770 1 672 705

GRAND TOTAL 4 247 587

Electricity

An estimation of electricity needs for the pipel ine construction has been undertaken.

The results of this are shown in Table 2.20. This electricity will be supplied by diesel

powered generators (TEO-C,Volume 3, Book 7.2).


Table 2.20 Estimate of Electric Power Consumption for Pipeline Construction

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f p f p

Construction Consumption amount, kW

spread Production plants Living camps Total

Installed Power Installed Power Installed Power

capacity consumption capacity consumption capacity consumption

1 300 240 1341 1205 1641 1445

2 590 470 1341 1205 1931 1675

3 590 470 1341 1205 1931 1675

4 590 470 1341 1205 1931 1675

5 590 470 1341 1205 1931 1675

Total 2660 2120 6705 6025 9365 8145

Water

Water consumption estimates are summarised in Table 2.21 (TEO-C,Volume 3, Book

7.2). For the pipeline construction camps, water is planned to be sourced from nearby

wells. An abstraction license wil l be applied for prior to construction. More details

about the water use licences are provided in Chapter 2.3.7.

Table 2.21 Estimate of Water Consumption for Pipelines Construction

Construction Consumption amount, m3/day

spread Production plants Living camps Total

For For For For For Forproduction household production household production household

and needs, and needs, and needs,technical drinking technical drinking technical drinking

needs and needs and needs andhygienic hygienic hygienic

needs needs needs

1 14 16 162 155 176 171

2 20 18 162 155 182 173

3 20 18 162 155 182 173

4 20 18 162 155 182 173

5 20 18 162 155 182 173

Total 94 88 820 775 904 863

Gas Disposition Terminal (GDT)The materials, equipment, structures and goods required for the construction of the

GDT include materials such as:

precast concrete slabs;

supports;

inert building materials (sand, gravel, crushed stone);

reinforced steel;

metal piping and fittings;


valves, instrumentation and telecommunications equipment; and

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valves, instrumentation and telecommunications equipment; and

paints and coatings.

Electrical and water requirements are shown in Table 2.22.

Table 2.22 Electrical and Water Requirements for GDT Construction

Construction Site Construction Camp

Electric power need (installed capacity kWt) 70 136

Water consumption (m3/day) 2.9 15


Its intended to have a Marshalling Yard at one of the far Eastern Russian ports

(Vostochny and Vanino). The Yard will enable optimisation of loads to Sakhalin Island.

From this Marshalling Yard equipment and construction materials for BS#2 will be

shipped to Kholmsk or Nevelsk. From there the materials will be delivered to the BS#2site by roads or rails (TEO-C,Volume 3, Book 7.3).

Other construction equipment will be transported to site by road from the following

locations:

near route quarry (highway 279 km) up to BS#2 - 8 km, delivery of sand-gravelmixture;

quarry Vakhrushevo up to BS#2 - 20 km, crushed stone; and

railway station Gastello up to BS#2 - 3.5 km, reinforced concrete structures andtimber.

The materials, equipment, structures and goods required for the construction of BS#2

includes the same type of equipment for the GDT, plus additional instrumentation

and fittings pertinent to the BS#2 functioning. For example: heat radiators, process

equipment, ventilating equipment and air conduits.

Electrical and water requirements for construction are shown in Table 2.23 (TEO-C,

Volume 3, Book 7.3). Electricity requirements will be provided by onsite generators.

Water will be sourced from a local water well.

Table 2.23 Electrical and Water Requirements for BS#2 Construction

Workshop Yard Camp Construction

Requirements

Electric power need (installed capacity kWt) 494.0 641.4 329.0

Water consumption (m3/day) 42.42 109.74 3.75

2.3.6 Emissions & Discharges

Typical emissions sources and discharges from construction activities and construction

camps are included in Table 2.24 and Table 2.25. The treated wastewater discharges willhave to comply with permitted levels.


Table 2.24 Typical Discharges from Construction Camps and Construction Activities.

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Discharges Construction camp Construction activities

Site runoff Yes Yes

Treated wastewaters Yes

Trench dewatering YesHydrostatic test water runoff (see Section 2.4) Yes

Table 2.25 Typical Emission Sources from Construction Camps and Construction Activities.

Emission sources Construction camp Construction activities

Vehicles Yes Yes

Generators Yes Yes

Welding operations (ROW) Yes

Machinery repair activities YesWelding operations (from PWY) Yes

The general characteristics of contaminants discharged into the air during construction

of the pipeline, GDT and BS#2 are shown in Table 2.26 (TEO-C,Volume 3, Book 8.2.1,

8.3.1, 8.4.1, Exhibits 6.1).

Table 2.26 Characteristics of Contaminants Discharge into the Air during Construction, Pipeline,GDT & BS#2 Construction

Name of material Code of Hazard Tonnes for the construction periodmaterial class Pipeline GDT BS#2

Nitrogen dioxide 301 2 755.822 21.222 137.4

Nitrogen oxide 304 3 - 22.396

Sulphur dioxide 330 3 49.793 2.335 21.07

Carbon oxide 337 4 356.861 12.061 142.69

Particulates (Dust) 2902 3 53.246 0.351 0.697

2.3.7 Management of Potential Impacts

OverviewThis section presents the accepted mitigation measures that contribute to the

management of the potential impacts associated with construction activities.

It is divided into five main areas, as follows:

general permits;

generic mitigation measures;

watercourse crossings;

erosion control; and

sediment control.


A separate section is presented to address the presence of unexploded ordinance that

k b S kh l

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are known to be present on Sakhalin.

General Permits

The relevant major approvals that will be obtained prior to construction commencing

are included in Table 2.27.

Table 2.27 Major Construction Approvals

Approval Relevant authority

Water Use Licence MNR - Ministry of Natural Resources

Licences for Use of Sub-soil MNR - Ministry of Natural Resources

Gosstroy Licence for Construction and Installation FLC - Gosstroy Federal Licensing Centre

Permit to use sand from borrows MNR - Ministry of Natural Resources

Permit for Construction commencement GASN - Gosarchstroynadzor (State Oversight

Committee for Architecture and Construction

Inspection)

While not all of the approvals mentioned above are concerned solely with the

protection of the environment, the application and approvals process stipulated by the

Russian legislation typically addresses environmental concerns at the same time as

other issues of interest. SEIC and its contractors will identify and obtain all relevant

permits required for the construction of the pipeline, FOC, GDT and BS#2 and their

associated components such as camps and laydown areas. Permit conditions will

automatically become contractual commitments and as such will be complied with.

Generic Mitigation Measures

There are many mitigation measures that are a standard part of pipeline or facility

construction activities. These measures represent industry best practice and will be

implemented by SEIC and its various contractors. The main measures are detailed in

Table 2.28. It is important to remember that mitigation is firstly considered during

project planning and design. It is assumed that in planning and designing the pipeline

and facilities, many environmental considerations have already been taken into

account.These considerations include:

Selecting pipeline route, facility locations, access roads, transport routes andassociated logistical requirements that avoid environmental sensitivities (including

potable water intake points) as far as practicable.

Selecting materials and techniques that reflect the requirements of the climateand terrain.

Designing the pipeline and facilities to minimise resource requirements, emissions(by flare/vent) and discharges.



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Table 2.29 Watercourse Crossing Construction Methods

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Depth

Width Trench Lay Trench Lay Trench Lay Trench Lay

0.5 m 0.5 m 0.5 m 0.5 m 0.5- 0.5- >1.5 m >1.5 m

firm firm loose loose 1.5 m 1.5 m

ground ground ground ground

10m I A II, III A III B III B

10-15m I A III A III B IV B

15-30m I A IV A IV C IV C

>30m I A IV A V C VI,VII,VIII C, D

The following details are given for types of construction:

Trench: I backhoe travelling on river bottom

II backhoe travelling on river bottom on mats

III backhoe from both banks

IV dragline excavator from both banks

V rope scraper

VI dredger

VII backhoe from pontoon

VIII HDD

Lay: A from trench side using sidebooms

B from banks by cranes

C bottom pulling

D Horizontal Directional Drilling (HDD)

Diagrams of different trenching and pipe laying methods are presented inFigure 2.7,

Figure 2.8, Figure 2.9.

Another criteria impacting the selection of the crossing construction method and

hence the cost of the work is the soil type (excavation difficulties). The soil type

classification with regard to ease of excavation was determined out in accordance with

SNiP 4.02-91 and 4.05-91 Code of construction operations estimation norms and

rates, code I Earthworks.The soil and bedrock type is divided between type 1 to

type 10 (1 being sandy loam, and 10 is being hard rock like granite). The presence of

hard soils and rock in the drilling trajectory may prevent the use of HDD. In open

trenching, blasting may be required to loosen ground prior to excavation as indicated

in Table 2.30.

It should be noted that no geological data has been obtained deeper than 10 m at

crossing locations. It is not possible to verify therefore if HDD is possible at any of

the crossing locations, however based on the shallow bores that are available there

is nothing to suggest that the soil is unsuitable.


Figure 2.7 River Trench Excavation with Backhoe (river depth up to 0.5 m) & Pipe Laying from Trench.

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Figure 2.8 River Trench Excavation with Backhoe (river depth up to 1.5 m) & River TrenchExcavation with Dragline Excavator (river depth 1.5-3 m).

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Figure 2.9 Typical Horizontal Directional Drill Schematic

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Table 2.32 Construction Method by Watercourse Group and Width

Group Width < 10 m Width 10-15m Width 15- 30m Width >30m Total

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Group Width < 10 m Width 10-15m Width 15- 30m Width >30m Total

I 973 9 7 6 995

all open trench all open trench all open trench

II 39 4 2 0 45all open trench all open trench all open trench

1 possible HDD:

Small Irkir

III 32 12 11 8 63

All open trench 11 open trench 10 open trench 2 open trench

19 possible HDD: 1 HDD: 1 HDD: 6 HDD:

Small Garomay Buyuklinka Firsovka Val

Big Garomay 8 possible HDD: 8 possible HDD: Tym 1st crossing

Tomi Nituy Leodinovka Naiba

Bauri Malakhitovka Lesnaya (2x) Tym 2nd crossing

Khuma Askasay Orlovka Nabil

Vosie Onor Gastellovka VaziDaldaganka Small Tym Big Veni 1 possible HDD:

North Khandasa Ai Pugachevka Makarova

South Khandasa Evay Manuy

Borisovka Goryanka

Pobedinka

Matrosovka

Zamislatovaya

Gornaya

Zheleznyak

Lazovaya

Tikhaya

Small TakoyBig Takoy

Total 1044 25 20 14 1103

Soil Erosion Control

Erosion control is typically best achieved using a combination of physical structures

and vegetative techniques. The main examples of these are shown in Table 2.33 and

Table 2.34. The application of these techniques will be determined during construction

depending upon the prevailing environmental conditions.

The Pipeline, GDT and BS#2 EPC contractors will be responsible for developing

a project Soil Remediation and Erosion Prevention Plan that will specify where,

when and how the following generic soil erosion and sediment control techniques

will be used.



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The list of major steps associated with hydrotesting are:

prepare to flush pipeline;

run a pig under air pressure, with water slug of 300 m3 run before the pig, drain

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p g p , g p g,

used water into settling pits after cleaning;

run gauge under air pressure, with water slug of 150 m3 run before the gauge. Drainused water into settling pits;

prepare to test;

fill pipeline with water, running a separation device and injecting water beforeseparation device in the volume constituting 10% of cavity volume of the segment

being tested. Drain used water into settling pits after fill-up;

build up pressure to reach testing pressure value;

run strength test;

bleed pressure off to equal the level of leak test pressure;

leak test; and

dewater and discharge into a waterbody after filtration and sample confirmationthat the water can be discharged.

It is currently planned that no chemicals will be added to the hydrotest water.

The hydrotesting will be done in short pipeline sections, the lengths of these sections

will depend on the safety class of the pipel ine and terrain profile. Water for the testing

is expected to be drawn from watercourses along the pipeline route. Details regarding

the water intake and discharge locations and volumes are provided in Table 2.36.

Table 2.36 Total Volumes of Water Intake and Discharges for Hydrostatic Testing

Water source/ Name of watercourse, Water intake Total water Total waterwater inlet (location on the Total Water volume for volume for

pipeline route - KP volume, discharge hydraulic tests flushing,

of the route); depth in m3 during for strength/ discharged

the area of crossing water tightness, after settling

during low intake, discharged in storage

water flow. intake, without pits, M3

treatment, m3 (discharge

(discharge rate rate

0,3 m3s-1). 0,3 m3 m3s-1).

water source r.Val (49,5); 2,6 m 44 150 0 25

water inlet Okhotsk sea 19 460 2 846

(landfall from PA)

water inlet r. Bauri (92,6); 1,0 m 31 880 4 988

water source r.Tym (123,3); 3,3 m 40 520 0 3

water inlet Okhotsk sea

(landfall from LUN) 66 080 8 408

water source r. Parkata (38,3); 0,7 m 127 442 0 25-0 3

water inlet r. Pilenga (44,9); 0,3 m 118 410 13 641

water source K r. Malaya Tym (79);

1.0 m 113 170 0 25-0 3

water inlet r.Taulan (124); 0.3 m 104 180 12 218

water source r. Onor (153); 0.8 m 112 384 0.25-0.3


Table 2.36 Total Volumes of Water Intake and Discharges for Hydrostatic testing Continued

Water source/ Name of watercourse, Water intake Total water Total water

water inlet (location on the Total Water volume for volume for

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water inlet (location on the Total Water volume for volume for

pipeline route - KP volume, discharge hydraulic tests flushing,

of the route); depth in m3 during for strength/ discharged

the area of crossing water tightness, after settling

during low intake, discharged in storagewater flow. intake, without pits, M3

treatment, m3 (discharge

(discharge rate rate

0,3 m3s-1). 0,3 m3 m3s-1).

water inlet r. Pobedinka (195.5);0.3 m 125 330 13 333

water source r. Matrosovka (Kamenka)

(239.5); 0.2 m 111 692 0.15-0.2

water inlet r. Bolshaya Tikhmenevka(266.4); 0.3 m 93 060 11 106

water source r. Nitui (307); 0.1 m 201 748 0.25-0.3

water source/ r. Pugachevka (400.2); 2 m 108 678 0.25-0.3 122 060 13 106water inletwater source/ r. Firsovka; 0.5 m 99 306 0.25-0.3 97 980 10 698

water inlet

water source/ r. Bolshaya Takoi (532); 0.2 m 101 726 0.05 89 460 9 846

water inletwater inlet r. Mereya (565); 2 m 91 660 10 066

Note: Total water volume for each sectio n is formed from flushing volumes for test for strength/tightness. Water

volumes taken and discharged for each section are different since water intake and discharge are performed during

different watercourses.

Table 2.37 Location and Description of Settling Pits for Hydrotest Water

Watercourse/location Volume Area

m3 m2

Okhotskoe sea shore near outlet from PA 1423 475

r. Bauri 1402 468

Okhotskoe sea shore near outlet from LUN 3907 1300r. Pilenga 6025 2010

r. Taulan 5468 1825

r. Pobedinka 5691 1900

r. Bolshaya Tikhmenevka 5133 1710

r. Pugachevka 14400 4800r. Firsocka 8178 2730

r. Bolshaya Takoi 7506 2500r. Mereya 7698 2570

Note. In case of excess of discharged water volumes of settling tanks volumes, water discharge to settling tanks will be

performed by stages. Actual dimensions of settling tanks will be defined during detail design taking into account

profile conditions.

During commissioning of gas pipelines it is typically necessary to purge the pipeline of

air to avoid that the hydrocarbon gas does not form an explosive mixture with air.

Often a slug of inert gas such as nitrogen is used for this. The air emissions during

commissioning therefore include the air and nitrogen mix, as well as any emissionsassociated with venting and flaring at AGIs.



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2.5.1 Workforce

The operational workforce is detailed in Table 2.39.

T bl 2 39 O ti l W kf N b d A d ti A t f th Pi li

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Table 2.39 Operational Workforce Numbers and Accommodation Arrangements for the Pipeline,GDT and BS#2.

Workforce number On site accommodation?

Pipeline 50-100 No

GDT To be serviced by pipeline workers No

BS#2 Between 6 and 16 Yes for 16 people

2.5.2 Resource Usage

Various resources will be used during pipeline, GDT and BS#2 operations. The most

obvious resources include water, power (typically gas fired generators on site), fuels,

oils, lubricants and other minor consumables like filters, batteries and rags.Pipeline

Pipeline operations consume very few materials apart from fuel during pipeline

inspections, and other materials for the maintenance of AGIs such as oils, lubricants

and paints. In maintaining the ROW, it may be necessary to clear vegetation either

by hand, using herbicides or mechanical means - such activities require very

few resources.


As the GDT is unmanned the amount of resources used during operations will be

minimal. Water usage will be limited to only those periods that personnel are on site.


Water is required for the fol lowing needs:

domestic and drinking needs of the attending personnel;

preparation of de-mineralised water;

production needs of boiler room;

own needs of potable water preparation installation;

washing of floors;

watering of plantations; and watering of areas and roads with hard pavement.

The general required consumption of water for BS #2 is as follows:

in summer - 41 m3 d-1; and

in winter - 27 m3 d-1.

Including drinking quality water:

in summer - 18 m3 d-1; and

in winter - 27 m3 d-1y.


The approximate location of the water intake well is a distance of 300 m from the BS

#2 site. There are projected two water supply systems:

technical water supply system; and

potable water supply system

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potable water supply system.

Technical water from the water intake to the BS #2 site is supplied through two water

conduit lines, and is delivered to:

technical water reservoirs; and

by-pass line, by-passing the potable water preparation installation, immediately tothe users.

For potable water, the technical water is purified up to the level of requirements of

sanitary standards and stored in potable water reservoirs. The volume of these

reservoirs ensures the following stock of potable water:

in summer, for 3.5 days; and

in winter, for 2.5 days (TEO-C,Volume 3, Book 8.3.1, Appendix D.1).

2.5.3 Emissions & Discharges

The main types of emissions and discharges from the pipeline, GDT and BS#2 are

provided in Table 2.40.

Table 2.40 Main Types of Emissions and Discharges from Pipeline, GDT and BS#2 Operations.

Air Water Solids

Pipeline Fugitive emissions ROW runoff (uncontrolled) Pigging wastes, U sed oils etc

GDT Venting, emissions from Site runoff Used oils etcgenerator drivers

BS#2 Venting, e missions from Sanitary wastewater Used oils etc

generator, compressor and Site runoff

booster pump drivers

Pipeline

Pipeline wastes are minimal, however there will be wastes associated with pigging

operations such as pipeline scale and other residues.

Gas Disposition Terminal and Booster Station #2Air emissions from the GDT and BS#2 during normal operations have been

summarised in Table 2.41 (TEO-C,Volume 3, Book 8.3 & 8.4, Appendices E.1).The

pipelines are effectively individually sealed systems, with no significant emissions.

Some fugitive emissions may result from some of the AGIs such as valves, however

these are considered to be negligible.


Table 2.41 Emissions from the GDT and BS#2 During Normal Operations

Pollutant Description of Pollutant Formula Hazard t/yr

code Class (1) GDT BS#2

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2902 Particulates (dust) 0.007

301 Nitrogen dioxide NO2 2 8.47 37.697

304 Nitrogen oxide NO 3 1.376 190.412328 Carbon black C 3 1.64

330 Sulphurous anhydride; SO2 3 0.392 24.452

sulphur dioxide

337 Carbon oxide CO 4 14.16 2 020.862

CO2 9 761.416 30 3933.1

Hazard classes: 1-very hazardous, 2- highly hazardous, 3 - hazardous, 4 - moderately hazardous

(Note: Figures taken from TEO-C GDT and BS#2 MPE reports)

Discharges

Open and closed water drainage systems are planned as follows: closed system for collecting waste waters containing oil products, storage in an on-

site tank and subsequent transport to the OPF for treatment and disposal -

estimated to be 15.2 m3 d-1; and

open system for conditionally clean waste waters disposal off site via drains andgutters (TEO-C,Volume 3, Book 8.4,Appendix D1).

BS#2

The following waste streams have been identified for BS#2:

domestic waste waters from the administration building, mechanical workshop and

fire post; production waste waters discharged from the technological areas when washing the

turbines and air coolers;

salt-containing waste waters from boiler room;

wastewaters after washing the fi lters of the potable water preparation installation;

conventionally clean waste waters (safe) coming from the potable water preparationinstallation;

wastewaters as a result of watering the technological areas; and

rainfall and snow melt wastewaters from the technological areas of BS #2.

The maximum volume of wastewaters forwarded for discharge will be 3346 m3 peryear, including:

domestic wastewaters after purification works - 1825 m3y-1;

salt-containing wastewaters - 51 m3y-1;

oil-containing wastewaters - 375 m3y-1; and

conventionally clean wastewater - 1 095 m3y-1.

Upon purification and disinfection, domestic wastewaters are mixed with purified oil-

containing, conventionally clean and salt-containing wastewaters into a single flow

forwarded for discharge.


The indices of combined flow of wastewaters should comply with the MPC

requirements for water basins of fishery importance (Table 2.42).

Table 2.42 Wastewater Criteria and MPC for Water Basins of Fishery Importance

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Indices Purified run-offs for discharge MPC

Suspended substances, mg l-1 3 3

Dry, calcined, mg l-1 1000 1000

Calcium, mg l-1 180 180

Sulfates, mg l-1 100 100

Chlorides, mg l-1 300 300

OBR, mg l-1 3 3

CBR, mg l-1* 30 30

Ammonium nitrogen, mg l-1 0.39 0.39

Nitrite nitrogen, mg l-1 0.02 0.02

Nitrate nitrogen, mg l-1 9.1 9.1

Common iron, mg l-1 0.1 0.1

Copper, mg l-1 0.001 0.001

Zinc, mg l-1 0.01 0.01

Oil products, mg l-1 0.05 0.05

Phenols, mg l-1 0.001 0.001

Phosphates mg l-1 0.2 0.2

Benzene mg l-1 0.5 0.5

2.5.4 Management of Potential Impacts

Environmental management is always an integral part of pipeline and facility

operations. Environmental protection is typically a by-product of effective

management, as protecting the asset requires protection of its surroundingenvironment, this is particularly the case for pipelines but is equally applicable

to AGIs.

Industry standard and accepted mitigation measures are outlined in Table 2.43. SEIC

will operate their pipelines and facilities in accordance with all applicable industry

standard mitigation measures.

Many operational impacts are mitigated through technical and environmental

monitoring activities. These are not included in this chapter but are discussed in

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2.5.5 Episodic Events

Episodic events are considered to include the following:

third party interference;

oil and/or gas pipeline rupture;

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oil and/or gas pipeline rupture;

natural hazards (earthquakes, landslides etc); and

serious operator error resulting in equipment failure.The design of the pipeline and facilities has incorporated all feasible scenarios with

regards to episodic events. The various components of the project have undergone

HAZOP studies that will be reviewed and built upon during detailed engineering.

design, construction and operations also have to be in accordance with relevant

industry standards and best practice guidelines.

Volume Iincluded a short description of the Crisis and Emergency Response

Procedures (ERP). In the event of an episodic event, the ERP will be implemented.

The environmental impact that may result from an episodic event will depend on

many factors including:

location, timing and nature of the event;

environmental sensitivity of the receiving environment; and

scale and effectiveness of the response.

2.6 DECOMMISSIONING

At the conclusion of the design life , the pipelines will be abandoned and the design of

facilities will allow them to be dismantled and removed. In specific cases, the Russian

Party or a local governmental organisation may wish to use a facility.The social

impacts of abandonment will be considered prior to removal of any facility. Actualabandonment procedures will address industry best practices and Russian regulations

in place at the time of abandonment (SEIC Abandonment Strategy).

The following steps have been identified for decommissioning of the onshore

pipelines:

depressurise pipelines;

purge pipelines;

clean pipelines;

leave in place;

conduct environmental survey to determine if any reclamation is needed; and at shore crossings, determine if pipelines need to be removed (after environmental

survey is conducted).

The following steps have been identified for decommissioning of the booster station

and valve stations (if removal is desired):

decommission equipment;

remove equipment and dispose elsewhere (recycle if possible);

remove gravel, fence, etc and level site, if needed; and

conduct environmental survey to determine extent of reclamation needed; and

restore site.


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Documents

Pipeline Project Description