Pipeline Project Description

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Chapter

2 Project Description

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 PA N Y • E N V I R O N M E N TA L I M PA C T A S S E S S M E N T

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Volume 4 Chapter 2 Project Description 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 Oil Booster Stations;

•

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

•

two multiphase pipelines bringing product from Lunskoye landfall to the OPF and and 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 along the pipeline route, as well as pipeline construction camps and lay-down areas that will be utilised during the construction phase of the main pipeline.

A summary of the design details of the onshore pipelines 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 Gas Gas and Condensate MEG Oil

Piltun Landfall to OPF Piltun landfall to OPF (via GDT)

508 (20) 508 (20)

171 171

X65 X65

Lunskoye landfall to OPF (2 pipelines) OPF to Lunskoye landfall OPF to LNG plant (via BS#2 at 319 from OPF) OPF to LNG plant (via BS#2 at 319 from OPF)

762 (30) 114.3 (4.5) 610 (24)

7 7 637

X65 X52 X65

1219 (48)

636

X70

Gas

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

•

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

• •

the Gas Disposition Terminal (GDT); and Booster Station #2 (BS#2) - encompassing the oil booster station and the gas compressor station;

An overview of the onshore pipeline system is included as Figure 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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E N V I R O N M E N TA L R E S O U R C E S M A N A G E M E N T

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Volume 4 Chapter 2 Project Description BS#2 is located 19.5 km to the south-west of Poronaisk, approximately 1.5 km north of the railway station for Gastello township and midway between the OPF and LNG/OET plant. 2.1.1

Role within Sakhalin II Project Pipeline System Oil and gas production will take place from the existing platform (PA-A) and two new platforms (PA-B and Lun-A) off the north-east coast of Sakhalin Island (see Volume II, Chapter 2). As the export facilities for these products are in the far south of the Island, an extensive pipeline transportation system is required to transport the product from the production fields to the export location. The pipeline transportation system consists of both offshore and onshore pipelines as well as some associated onshore facilities. The rationale in having the export facilities in the south of the Island is to allow year round export from the (relatively) ice free Aniva Bay. Industry wide quantitative risk assessments have shown that underground pipelines provide for the safest and most efficient method to transport substances such as oil and gas over long distances. A pipeline is also required to transport monoethylene glycol (MEG) from the Onshore Processing Facility (OPF) to the Lun-A platform where it is injected for hydrate prevention into the multiphase pipelines bringing product to OPF. Telecommunications System The telecommunication system must provide timely, reliable, trustworthy operation of the onshore and the offshore facilities, excluding at the same time unauthorised access to information. A high capacity, digital fibre optic telecommunications transmissions system, will connect all onshore and offshore facilities. The telecommunication system will carry voice, data, video and telemetry traffic between the facilities and offices, as well as provide to public networks. The main component of the telecommunications system considered in this EIA is the installation of the onshore fibre optic cable (FOC). The onshore FOC is used for telecommunication associated with an offshore oil and gas development, oil and gas pipelines and onshore facilities (TEO-C, Volume 3, Book 3.2). Gas Disposition Terminal (GDT) The GDT will be designed to supply gas to the gas pipeline system of the ‘RosneftSakhalinMorneftegaz’ Company (SMNG). It will consist of pressure reduction facilities and associated pipework and instrumentation to allow supply into the existing pipeline network. Booster Station #2 (BS#2) The purpose of BS #2 is to increase the pressure in the main oil pipeline and gas pipeline during the process of pumping the oil and gas so as to compensate for the head pressure losses. The BS#2 is located approximately midway between the OPF and the LNG/OET plant. Note: the first booster/compressor station (BS#1) is located at the OPF site. The area adjacent to the BS#2 site will also serve as a location for storage of pipeline maintenance and emergency response equipment.


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Volume 4 Chapter 2 Project Description Construction Camps, Pipe lay-down and Welding Yards Construction camps will be established along the pipeline route to provide accommodation and supporting facilities to the pipeline construction crews. Ten camp locations, with a capacity of accommodation ranging from 500 to 1000 contractor construction workers and 50 SEIC specialists, have been identified and assessed as part of the project planning to date. At each camp, there will also be a pipe laydown/welding yard. It is here that two pipe lengths will be welded together and prepared for transport to the ROW. Once these double pipe lengths have been transported to the ROW, the remaining welding will take place to form long pipe strings ready for lowering in. Additionally, there will be two other pipe laydown yards which will not serve as welding yards and which are not associated with any camp. Pipe lay-down/welding yards are areas designated and prepared to accept line pipe for temporary storage and for double jointing before transportation to the pipeline corridor for installation. Pipe will be transported via the road and rail network from the port of landing to the lay-down yards, therefore the camp/lay-down yards are typically located adjacent or close to the exiting rail network. Locations are shown in Figure 2.1. 2.1.2

Footprint The footprint of the assets considered in this EIA volume includes the actual area occupied by the assets as well as the area surrounding these assets due the implementation of a Sanitary Protection Zone (SPZ) or Safety Zone. The process of applying for and being granted land for the purposes of the project is an integral part of project approval and is referred to as the Final Land Allocation. Sanitary protection zones are designated areas round industrial facilities separating them from living areas and aimed at protecting the residents. Land allocation for SPZs are not required since these lands are not withdrawn from land users and can be used with restrictions stipulated by relevant legislation. The size of SPZs are determined by the distance from the facility to the boundary where it is considered that the impacts associated with the facility are below permitted levels according to Russian standards. Pipeline System The total length of onshore pipelines is approximately 2 x 808 km, commencing in the far north-east of the Island and terminating in Aniva Bay in the south. The pipeline ROW is in close proximity to the existing transport network on Sakhalin Island, therefore much of the land to be used is within the existing range of human influence. The main exception to this is in the vicinity of the OPF, which is situated in a remote location. The oil and gas pipelines share the same ROW that generally varies in width from 36 to 66 m, however this may be wider at special crossings such as roads or rivers. The width of the ROW is determined by both regulation and by the requirements of the Regional and District authorities. The ROW needs to be wide enough to allow construction of the oil and gas pipelines as well as the fibre-optic cable (FOC), all of which will be in separate trenches.

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Volume 4 Chapter 2 Project Description Figure 2.1

Map showing Construction Spreads, Construction Camps, Pipe lay-down and Welding Yards.


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Volume 4 Chapter 2 Project Description Spacing between oil and gas pipelines varies depending upon the location along the pipeline route, as follows:

•

The 350 mm (14") diameter offshore pipelines from the Piltun-Astokhskoye field will be 30 m apart at the tie-in point with 508 mm (20") onshore pipelines.

•

Segment 1 and 8: The two 508 mm (20") pipelines from the Piltun-Astokhskoye landfall tie-in to the OPF will be 13 m apart.

•

Segment 6 (OPF - KP 19):

• • •

13 m - between 508 mm (20") oil pipeline and 508 mm (20") gas pipeline; 15 m - between 508 mm (20") gas pipeline and 1219 mm (48") gas pipeline; 14 m - between 610 mm (24") oil pipeline and 1219 mm (48") gas pipeline.

•

At Segment 6 (from tie-in point to offshore pipelines from Lunskoye field to OPF) between multi-phase product pipelines, the spacing shall be 13 m. Between multiphase product pipeline and MEG pipeline, the spacing will be 10 m; and

•

KP19 (segment 6) - Prigorodnoye the spacing between 610 mm (24") oil pipeline and 1219 mm (48") gas pipeline shall be as follows:

• •

18 m - on flat ground; minimum 8 m - in highlands (on terraces) where necessary because of topographical limitations (TEO-C Volume 3, Book 3.2).

The Sanitary Protection Zone (SPZ) equals the minimum safety distance from the pipelines to other building and structures as defined in SniP2.05.06-85. The SPZ varies from a minimum of 150 m for the 20" gas line and a minimum of 300 m for the 48" gas line. These distances may be decreased if special measures are provided such as a change in design (safety) factor. For the pipeline, the Protection Zone is specified by Russian regulations and is generally equal to 25 m either side of the pipeline plus the distance between the pipelines. However, at watercourses this widens to 100 m within the watercourse bed either side of the pipeline plus the distance between the pipelines. No work is permitted to be carried out by third parties within the Protection Zone without prior approval from the pipeline operator. The official land take details for the pipeline and associated facilities are further described in the Social Impact Assessment (SIA Chapter 7) report, however the share of the ROW land take per Sakhalin Region Land Category is provided in Table 2.3. Importantly, the pipeline ROW will occupy 3332.9 ha; equivalent to less than 0.04% of the Island’s area, and of this total, 70% of the ROW is located in Forestry Fund Land. In addition to the official land take areas, additional areas that will be affected are:

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• •

access roads;

• •

water supply pipelines for construction camps; and

hydrostatic testing settling pits, the size and location of which are detailed in Table 2.3; areas for communication system infrastructure such as branches of the FOC to Nogliki operations camp and Yuzhno SEIC office and accommodation. The Nogliki operations camp is an existing camp currently used to provide support services to the existing platform.


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Volume 4 Chapter 2 Project Description Table 2.2

ROW Landtake Details per Sakhalin Region Land Category Classification

Forestry Fund Land State Reserve Land Land Used for Industrial Purposes, Transportation, Communication, Radio and TV Broadcasting, Computer Science, Space Research, Military Defence and Other Special Purposes Agricultural land Protected Areas* Land of Settlements Water Fund Land Total area of lands

Total Sakhalin Island Land Classification (01 Jan 2002) ha. %

Pipe-line ROW

% of Total ROW

% of Total Region

ha.

6 950 200 993 400 336 300

79.8% 11.4% 3.9%

2 350 233 9

70.9% 7% 0.3%

0.0270% 0.0027% 0.0001%

177 900 122 300 83 200 46 800 8 710 100

2.0% 1.4% 1.0% 0.5% 100.00%

591 55 95 0 3 333

17.7% 1.7% 2.9% 0.00% 100.00%

0.0066% 0.0006% 0.0011% 0.0000% 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 - Nogliki’ road. 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 East (m)1

UTM North (m)1

Geodetic Latitude (N)1

Geodetic Longitude (E)1

BSL 77 (m)2

KP on pipeline route

GDT

638 897

5 810 253

52 25 29.37

143 02 33.88

+37

41.1 (section 1)

BS#2

640 944

5 440 060

49 05 50.04

142 55 50.85

+34

279 (section 4)

Notes: 1. Universal Transverse Mercator (UTM) co-ordinates and corresponding geodetic positions are in Zone 54N, Central Meridian 141°E. 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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Volume 4 Chapter 2 Project Description 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. Gas Disposition Terminal (GDT) 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:

• •

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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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Volume 4 Chapter 2 Project Description •

implementation of main scope of construction and installation - May-September 2004;

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 PA-A to Shore PA-B to shore Piltun Area Shore Manifold to OPF South: Lunskoye and OPF to LNG Lunskoye to OPF OPF to LNG Lunskoye to OPF OPF to LNG

Design Case (summer and winter) 1.7 (60) 2.6 (92) 3.8 (134) Season Winter Design: 52.3 (1847) Winter Design: 50.1 (1768) Summer Design: 45.8 (1619) Summer design: 40.8 (1440)

(1)

For full description of design assumptions see BOD Rev 5. 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 PA N Y • E N V I R O N M E N TA L I M PA C T A S S E S S M E N T

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Gas Pipeline Pressures and Temperatures (2) Pipeline Section

Normal OP (barg) 1

MOP (barg) 2

MAOP (barg) 3

Temperature Range for Hydraulics (°C)

80 81 94 94 85.5 70 58 96.5 65 95 66

98 98 98 98 98 98 98 98 98 98 98

100 100 100 100 100 100 100 100 100 100 100

20/30 38/60 20 to 45 20 to 45 33 15/20 15/20 40/45 -3/+5 40 -3/+5

PA-A Gas Export PA-B Gas Export Lun-A Multiphase Wet Gas/ condensate/MEG Export to OPF OPF inlet (from Lunskoye) GDT BS#1 Inlet (Piltun area gas and OPF gas) BS#1 Discharge BS#2 Inlet BS#2 Oulet SE gas pipeline outlet to LNG plant 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

Table 2.7

Oil Pipeline System Design Capacity (2) Pipeline Section

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

PA-A oil export PA-B oil export Combined Pa-A and PA-B to OPF OPF to OET OET to TLU

14 309 (90 000) 11 129 (70 000) 23 530 (140 000) 31 003 (195 000) 190.8x103 (1.2x106)

Oil Pipeline System Pressures and Temperatures (2) Pipeline Section

PA-A oil export PA-B oil export OPF Oil BS#1 suction OPF Oil BS#1 outlet BS#2 suction OET inlet TLU inlet

(2)

2-10

Normal OP Operating (barg)

MOP (barg)

MAOP (barg)

Temperature Range for Hydraulics (°C)

88 88 7 70-80 7-11 18-20 Summer 11.29 Winter 12.24

91 91 91 91 91 91 25

100 100 100 100 100 100 60

25/45 38/60 10/20 10/20 -3/+5 -3/+5 -7/+20

For full description of design assumptions see BOD Rev 5.


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Volume 4 Chapter 2 Project Description 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 an emergency 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

Piltun: landfall to Pig launcher/receiver at KP1.2 Piltun: Pig launcher/receiver at KP1.2 to OPF Pipeline from OPF to OET/LNG OPF to Lunskoye landfall

2 25 82

2 8 35

MEG

Multi-phase

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 1 6 6 3 7

350mm (14") pig receiver site from PA-A 350mm (14") pig receiverL/R site from PA-B 508mm (20") pig launcher site to OPF 508mm (20") pig receiver site at OPF 1219mm (48") pig launcher site at OPF 1219mm (48") pig L/R site at BS#2 1219mm (48") pig receiver site at LNG plant

350mm (14") pig receiver site from PA-A 350mm (14") pig receiver site from PA-B 508mm (20") pig launcher site to OPF 508mm (20") pig receiver site at OPF 610mm (24") pig launcher site at OPF 610mm (24") pig L/R site at BS#2 610mm (24") pig receiver site at OET

1.2 1.2 1.2 7 7 278.9 599.54

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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Volume 4 Chapter 2 Project Description • • • • •

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 in Figure 2.2 (TEO-C, Volume 3, Book 2, Section 4, Appendix F). Table 2.10

GDT Design Requirements Element

Detail

Location Main Systems Gas Flow Rates

Near Boatasyn (approx 41 km from Piltun landfall) Gas filtering, pressure reduction and custody transfer metering 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. Gas fuel power generation, 2x100% units (normally both running at 50% capacity) and 1x100% standby unit as standby emergency generator Power generation, primary and back-up Gas Fuel, Process Drains, Vent system.

Power Generation Utilities / Buildings

Booster Station #2 (BS#2) 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 Main systems Gas Compression / Export

Near Gastello (approx 319 km from OPF) Booster / Compressor Station 50.1X106 Sm3 (1755(106 Sft3) of gas per day Estimated fuel gas consumption is 0.3X106 Sm3 (11X106 Sf3) per day 195 000 barrels (31 003 m3) of oil per day Gas Fuel power generation, 3x50% units and Emergency Diesel generator 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

Oil Export Power Generation Utilities/Buildings

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GDT Site Layout


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Volume 4 Chapter 2 Project Description 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 emergency generator and electrical distribution and lighting system;

• •

ground system for lightning control;

• • • • • •

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

• • • •

fire detection and control system;

• • • •

administration building with control room;

fuel measurement, regulation, and distribution systems for both gas fuel and diesel fuel; 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 UPS back-up; civil works, roads, drainage, fencing and foundations; lighted helipad; pipeline maintenance vehicles, light construction equipment, furnishings, tools, consumables; warehouse and maintenance building; 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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BS#2 Layout


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Volume 4 Chapter 2 Project Description Oil boosting Oil is transferred from BS#1 at the OPF to the filters of BS#2 direct by the oil pipeline. In order to protect the rotating equipment from damage, the BS#2 filters act to remove solids that could get into the pipeline during the construction, maintenance and operation. There are two filters at the station: a master and standby, each rated at 1421 m3 h-1. From the mud filters oil is transferred to the trunk pumps of the BS#2. There are two working pumps that operate simultaneously and one standby, the pumps are powered with gas turbine drives. The noise at a distance of 1 m from modular pump facility will not exceed 85 dB. Oil discharged from trunk pumps flows into the trunk pipeline. All the surface parts of above ground trunk pipelines of the BS#2 are heated and insulated. Gas compression The design is for three gas-compression units powered by gas turbine drivers that are sized for 50% of nominal design flow. In normal operation, two compressors are running and the third is used as common spare. Each module includes the following equipment:

• • •

horizontal scrubber; gas-transferring unit powered with turbine; and units of air-cooling of gas.

Gas from trunk pipeline is transferred to the horizontal scrubber in order to separate condensate, dust and solids. Then it flows into centrifugal compressor and is boosted until the pressure equals 94 bar (exc.). The temperature of boosted gas rises up to 20 - 22°C in wintertime and 45°C in summertime. Then gas is transferred to the air-cooling units until air-cooled to the temperature not higher than 40°C (in summertime). Moisture with hydrocarbon contaminants is automatically discharged into closed drainage system. The unit is operational at the temperature of ambient air varying from -55 to +45°C. Gas is discharged from the pipeline into the atmosphere through safety and bleeder valves located in a safe area. Each gas-compression unit with scrubber and air-cooling unit is disconnected from trunk pipeline with the help of isolation valves installed outside the module. Operations can be controlled locally or automatically. The processing facilities are arranged in such a manner to reduce the site area and the length of processing trains and power supply lines. Layout of the facilities ensures their convenient and safe operation and maintenance as well as the ability to take effective arrangements in order to prevent emergencies and localise fires. Reservoirs and units are located in the open areas. Rotating equipment (compressors and drivers) used in processing is installed in shelters, with the exception of ventilator drives. As a rule, all the processing facilities of the units where there is a risk of fires and explosions are placed above the ground level. The layout was developed taking into account the following points:

• • • 2-16

environmental conditions; fire fighting requirements; and ergonomics aspects.


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Volume 4 Chapter 2 Project Description 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;

•

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

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 generators shelter, gas compressor shelter); and

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 arisings 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 during construction 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 I of this EIA.

Table 2.12

Combined Waste Generation Estimate for Pipelines and BS#2. N° FWCC Hazard Waste Type Code Class 1 1.1 353000 1.2

I I

2 2.1 353000

II

2.2 2.3 2.4 2.5 2.6

521000 971000 593000 550000 541000

II II II II II

549000 549000 549000 570000 353000 548000 550000 555000

III III III III III III III

3 3.1 3.2 3.4 3.6 3.7 3.8 3.9

Construction (all period), t

Operations (annual), t y-1

0

0.1 n/a

WASTE OF HAZARD CLASS I Spent mercury light bulbs/tubes Activated carbon contaminated with mercury sulphide Sub-total

0

0.1

WASTE OF HAZARD CLASS II Spent dry-charged batteries (chemical current source) Waste sulphuric acid (electrolyte) Medical wastes Waste chemicals Waste organic solvents Waste lubricating oil Sub-total

1.4

0

17.6 2.2 40 10 786 857.2

0.11 0.01 1 1 3.9 6.02

WASTE OF HAZARD CLASS III Oiled rags Waste oil and air filters Oil contaminated soil including sorbents Spent X-ray films Batteries - lead cell (without electrolyte) Bitumen, tar paper, ruberoid, insulation materials Paints/wood dyes, adhesives

98.4 52 55 45 90 330 30

0.25 0.3 0.3 n/a 0.35 n/a 0.5

700.4

1.7

Sub-total


n/a

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Combined Waste GenerationEstimate for Pipelines and BS#2 Continued N° FWCC Hazard Waste Type Code Class

2.2.3

4 4.1 596000

IV

4.2 943000

IV

4.3 947000

IV

4.4 390000 4.5 399000 4.6 110000

IV IV IV

5 5.1 5.2 5.3 5.4 5.5 5.6

351000 353000 353000 575000 390000 399000

V V V V V V

5.7 5.8 5.9 5.1

570000 173000 170000 187000

V V V V

5.11 581000 5.12 314000 5.13 911000

V V V

Construction (all period), t

WASTE OF HAZARD CLASS IV Spent filter material not contaminated with harmful substances Sludge from a biological wastewater treatment facilities Sludge generated in the course of mechanical treatment of domestic wastewater Waste brake blocks and clutch plates Waste cement Food wastes Sub-total

Operations (annual), t y-1

2

0.1

1927.7

4.11

77.6

0.16

32 71 3968 6078.3

0.3 n/a 8 12.67

WASTES OF HAZARD CLASS V (PRACTICALLY NON-HAZARDOUS) Ferrous metal scrap 2790 150 Non-ferrous metal scrap 174 0.15 Spent welding electrodes 85 1 Tyres with metal cord/textile cord 418.7 10 Waste abrasive materials (abrasive sand) 4000 n/a Waste concrete and reinforced concrete 2200 n/a components Polimer/plastic wastes (industrial) 60 n/a Brush wood 61 855 n/a Construction wood 9500 n/a Uncontaminated waste paper/cardboard; 300 20 paper/cardboard manufacture Waste textile clothes (working clothes) 108.8 0.22 Uncontaminated clear glass/broken glass 100 1.5 Solid domestic wastes 2585 5.2 Sub-total 84 176.5 188.07 TOTAL 91 812.4 208.56

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:

• • • 2-18

mud; mud and stone; alluvial;


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Volume 4 Chapter 2 Project Description • •

water and stone; and water and snow.

Measures to protect the pipelines against the effect of all types of mud flows include:

•

deepening of pipelines 0.5 m below the line of maximum wash-out, 5 % of provision for mud flow;

• • • • •

avoiding dangerous mud flow areas where feasible;

•

making support walls on dangerous mud flow sections coinciding with landslide sections more than 2.0 m thick.

flattening of slopes, water protective facilities and support walls; restoration of landscapes for soil stability on slopes; protection of soil embankment over the pipeline against wash-out by alluvial flows; additional deepening of pipelines on dangerous mud flow sections coinciding with landslide sections, up to 2.0 m thick; and

Landslides According to engineering surveys along the route, 25 zones susceptible to landslide processes have been identified. As shown in Figure 1.10 (map of geological hazards) in Chapter 1, the recent sedimentary deposits and the poorly lithified strata along Segments 3 and 4, through the Poronaysk and Makarov regions, present the greatest risk of impact by landslides. These are commonly initiated by tectonic events or heavy rainfall/snowmelt and aggravated by increased loading of slopes or the reduction/removal of natural footings, which may be associated with the construction of a pipeline. The risk from mudflows associated with recent deposits is most apparent along Segment 4, between the settlements of Makarov and Vzomvye, where 36 mudflow basins have been identified. Records show that small flows occur once every three years, with large mass flows occurring once every 12 years. The origin of large ‘mass flows’ may occur some way from the proposed route yet they remain a risk due to their capacity to flow long distances. The most reliable method to protect the pipeline against damage is by avoiding the landslide zone. In 2001, work was done to reroute the pipeline around some of the landslide zones, as a result of that rerouting the landslides at KP 325, 331, and 391 were bypassed. Before the beginning of construction, measures will be taken to stabilise landslides in those areas where there is highest risk. The main anti-landslide measure for all landslide sections of the route is the control of surface drainage in order to exclude or significantly reduce humidification of soil with rain or thawing water. Where landslide zones have to be crossed, measures will be taken to relieve underground water flows by installing additional drainage measures to facilitate water discharge. Other measures include the installation of supporting walls and flattening slopes to further reduce the likely landslide risks. SEIC has developed various Environmental Design Guidelines for the project, one of which addresses soil erosion control. This is further discussed in Section 2.3.7.


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Volume 4 Chapter 2 Project Description Meliorative Systems Land reclamation systems of Sakhalin Island are primarily involved in the discharge of spring thaw waters. Crossing of meliorated fields takes place at the following sections of the pipeline route:

• • • • • • • • •

77 km - 86.5 km; 220 3 km - 222.3 km; 297 km - 298.2 km; 308.4-309.5 km; 493.5 km -495 km; 503.8 km - 506.2 km; 517 km - 519.3 km; 535.8 km - 540 km; and 554.5 km - 563.7 km.

The total length of the pipeline route crossing land reclamation canals is about 33.4 km. The average depth of canals is 1.5 - 2.0 m. The depth of the pipelines when crossing the canals is 1.1 m (from channel bottom to the top of pipe). Shut off valves are planned on the oil pipeline at KP79.5, 87.5, 222.3, 519.5, and 570 to minimise spill risks in the vicinity of meliorative systems. When pipelines cross the canals, clay coffer-dams (screens) will be installed to exclude the penetration of water into the ditch and its spread along the pipeline. Reinforced concrete ring weights will be applied to the pipelines to eliminate buoyancy and potential pipeline damage during canal cleaning (TEO-C, Volume 3, Book 3.2). Snow Slides/Avalanches Sakhalin Island has a high risk of potential snow slide hazards to population and economic facilities. The length of snow slide areas along the pipeline route is 232 km; the number of zones, in which damage to subsurface pipeline is possible is 17. Intensive snowfalls accompanied by snowstorms are the main factors contributing to avalanche frequency (TEO-C, Volume 3, Book 8.2.1, Section 4). Snowflows present greater risk than mudflows as they travel faster, further and disturb a greater thickness of the surface soils. The potential occurrence of snowflows along the route is widespread and is closely associated with those stretches at the foot of mountain ranges, particularly in the south of the island. Seventeen snowflow zones have been identified along the pipeline route. Measures to protect the pipelines against the effect of avalanches include:

• • • • •

discharge of flows away from the pipeline route; building avalanche breaking structures, earth banks, and discharging dikes; terracing slopes of more than 10 m in height; strengthening of steep bluff slopes; and restoration (TEO-C, Volume 3, Book 8.2.1, Section 2).

Liquifaction and Soil Thinning Liquifaction and soil thinning are typically activated by tectonic activity and can result in the complete loss of bearing pressure, slope stability and/or apparent subsidence of

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Volume 4 Chapter 2 Project Description areas of land that are underlain by either saturated or dry unlithified soils. Liquifaction and soil thinning occur in relation to very specific soil types, climatic conditions and activation mechanisms. Given the highly porous and permeable nature of the sedimentary deposits and strata that directly underlie much of the proposed route, localised sections of the pipeline may be at risk from such impacts during both the construction and operational phases. Liquefaction surveys have been undertaken (Geovision, 2001) using speciflais equipment to determine the density of the soils at specific points. Areas where liquefaction could occur have been taken into account in the pipeline design by ensuring the pipeline will be buried below the area of potential liquefaction impact. Alluvial and Coastal Erosion Alluvial erosion in relation to climatic flooding events will present a risk along the majority of the proposed route. During flooding at river crossings or along river valleys the very loose or weak nature of the recent deposits and of many of the strata that directly underlie the route will result in a risk of erosional impacts ie undermining, upon structures associated with the pipeline (bridges, revetments and embankments. Similarly, undermining of slopes or faces may initiate landslides, mudflows or snowflows that could result in impact upon the pipeline even if it is some distance from the original event. It is reported that coastal erosion is most pronounced around the settlements of Vladimirovo and Odoptu on the northern shores of Terpeniya Bay, where retreat of up to 20 m a year is occurring. Along sections of Segments 4 and 5, where the proposed route occasionally follows the coastline very closely, coastal erosion may present a risk to the integrity of the pipeline over the long term. However as the pipeline is inland of the existing road and railway, it is therefore protected by these existing structures. Seismic Areas As described in Section 1.3.4 (Volume IV, Section 1) faults on Sakhalin and along the pipeline route have been identified by geological, geophysical and geomorphic surveys. There are 24 crossings of tectonic faults along the pipeline route where the risk of exposure to seismic events will be higher. The segments of the pipeline have been attributed the following status by earlier reports with regard to the potential risk from fault movement:

•

Segment 1, along the north eastern coastline is described as generally hazardous as illustrated by the recent Neftegorsk earthquake;

•

Segments 8 and 9, to the east of Nysh are described as generally hazardous as illustrated by the recent Neftegorsk earthquake.

• •

illustrated by the recent Neftegorsk earthquake;

•

Segment 3, through the lower reaches of the Tym - Poronaysk lowlands, is considered less favourable particularly with regard to the existence of the active Zmeinogorsky Fault;

• • •

Segment 4, along the coast of the Makarov region is described as favourable;

Segment 2, through the upper reaches of the Tym - Poronaysk lowlands, is considered generally favourable;

Segment 5, through the Dolinsk Region, is also described as favourable; Segment 7, up onto the Korsakov Plateau to the LNG and OET is described as favourable despite the existence of the Mereisky Fault zone.


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Volume 4 Chapter 2 Project Description The most effective way to decrease the effect of seismic loads on pipelines at fault crossings is to design the trench geometry, backfill material and angle of approach of the fault crossing so that in case of seismic event, the pipeline would accommodate the displacement caused by the movement. Table 2.13 shows the solutions adopted for such crossings. Table 2.13

Pipeline Backfill Material at Seismic Crossings Trench type

Backfill type

Standard Standard Total

Sand Foam with geotextile material

# per gas pipeline

# per oil pipeline

1 23 24

1 23 24

Shutdown valves are also planned to be located on both sides of selected faults or group of faults to allow control of pipeline flow in the event of increased seismic load or event. Additionally, seven river crossing have been selected for the installation of seismometric stations, for monitoring the pipelines and soil vibrations. Details are shown in Table 2.14 (TEO-C, Volume 3, Book 3.2). Table 2.14

2.2.4

River Seismometric Station Locations (river and seismic fault identification) #

River River Name Crossing KP

River

Name and location of fault, km Class

1 2 3 4 5 6 7

152.8 195.7 205.25 324.53 371 538.1 549.8

III III III III III III I

Central-Sakhalin fault area (Onor town), 154.0 Central-Sakhalin fault area (Pobedino), 192.3-196.7 Central-Sakhalin fault area (Gastello town), 207.4 Makarovsky, 326.1 Zagrobka stream break, 367.9 Aprelovsky, 539.4 Aprelovsky, (Yuzhno-Sakhalinsk) 550.0

Onor Pobedinka Orlovka Gornaya Lazovaya Susuya Mayakovskogo

Safety Risk Analysis The risk analysis for the pipeline transportation system (PTS) has been carried out by Starstroi and was presented as Volume 3, Book 9 of the TEO-C. It considers the risk to both workers and the population of Sakhalin Island from releases of gas and oil. The focus of this document is the effect on people, and it specifically states that incidents leading to pollution are not considered. This section is presented in the form of a synopsis of the TEO-C Volume 3, Book 9 document. Work Carried Out The assessment considers all pipelines (onshore and offshore), the booster station and gas disposition terminal, and aims to provide a QRA for the hazards associated with the transportation of oil and gas through these pipelines. The report includes preparation of initial data with regards to the location and description of the PTS, identification of risks, description of initiation of events and their possible consequences and evaluation of the overall risks calculated. The risk assessment has

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Volume 4 Chapter 2 Project Description 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 company and 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 activity 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;

• • • • • • • • • • • • • • • • • •

high corrosion due to soil type and salt water;

residual stresses; deterioration due to thermal strain; internal/external corrosion and/or vibration due to seasonal temperature fluctuations; 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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Volume 4 Chapter 2 Project Description • • • • • • • • •

changes in operating conditions; changes in thermal loads; gravity loads; hydrodynamic loads caused by waves and streams; soil loads from ground subsidence or landslides; ice loads; loads from fire, explosion, sail failure or landslides; dropped objects; and earthquakes.

Both the GDT and BS#2 have been laid out in order to maximise the distance between probable sites of release and ignition sources, with easy access to the site and pipelines for emergency crews. Drainage systems have been designed, which are intended to remove any spillages of liquid hydrocarbons, therefore minimising any impact and reducing the risk of an incident occurring. Should a fire or explosion occur, plant siting arrangements ensure that other equipment is to be placed at a distance that minimises the probability of it becoming involved in the incident. A fire and gas detection system has been designed with fire exits and a clear escape route from both the GDT and BS#2. There are no other industrial facilities within 3 km of the PTS, aside from those considered in the study. The areas surrounding the GDT and BS#2 are uninhabited for a radius of 1 km, with information available about people living within a 5 km radius of the PTS. There is a vessel operation exclusion zone of 500 m around the offshore pipelines, and a minimum buffer zone of 25 m for the onshore pipelines. For the marine pipelines, the number of flanged joints in the subsurface system has been minimised, and cathodic protection has been included. They are further protected with the inclusion of shut off valves and HIPPS systems. For onshore pipelines, wall thickness and pipe selection has been carefully considered for sections that cross rail, road, water, pipelines and electrical lines. The block valves are installed in accordance with Russian regulatory Project Specific Technical Specifications (PSTSs). The distance between block valves will not be any more than 30 km, with valves installed on both banks of water areas, at water crossings (of a certain size) and both sides of a fault crossing. They will also be installed where the pipelines are in close proximity to communities and the pipeline is at an elevation above the communities. Results Mathematical modelling using Riskplot Graphic was used to calculate the risks from fire and explosion hazards, and determine the overall area affected by any incidents. Full details of the risk calculations, and contour plots are available within the report. The most common causes of failure in oil and gas pipelines are due to construction and installation defects, and the most common cause of failure in offshore pipelines is impact from other objects (eg anchors). When determining the areas affected by incidents, a number of assumptions have been made. For flash fires, the hazardous zone is defined by the lower flammability limit of the material released. It is assumed that there will be 100% fatalities within this zone when ignition occurs. The effect zone determined for jet and pool fires has 2-24


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Volume 4 Chapter 2 Project Description been defined by a radiation value of 35 kW m-2, which would give 100% fatality after 10 seconds of exposure. For explosions, 100% fatality occurs at 0.1 bar overpressure for conventional buildings, and at design pressure for specifically constructed buildings such as control rooms. Persons that are not in buildings are considered to be at negligible risk from explosion hazards. Information for the GDT and BS#2 states that a jet fire would give rise to the largest hazard, affecting the largest areas in comparison to the other possible incidents (explosions, flash fires and pool fires). No information of this nature is available for the PTS. It is determined that the hazardous zone around the GDT and BS#2 sites would be a maximum of 50 m, which is well within site limits. The maximum onsite risks calculated are 5.5 E-4 y-1 for the booster station, 5.9 E-5 y-1 for the GDT. The maximum offsite risk is 1.2 E-6 y-1, however there is no population within 1 km of the site and the risk to this population is lower than 1 E-8 y-1, which is well within the standards defined in GOST. The individual risk to personnel onsite depends on the type of job a person does, and is explained fully within the report, but the report concludes that the requirements have been met for the best worldwide practice in the oil and gas industry. The risk calculations carried out for the pipeline system have concluded that there is a slight risk to inhabitants within 1 km of the pipeline, where 1-2 persons may be fatally injured when considering maximum affected areas. There is also a small risk of fatalities where the pipeline intersects with the road, but this risk is greatly reduced when the frequency of traffic is considered. One area of the pipeline has been identified from the risk assessment results as requiring additional safety provisions. The section of the pipeline between KP 537 - 569 where it passes an inhabited area of 183 000 people at a distance between 0.45 and 4.5 km, and steps must be taken to further reduce the risks to people within this area of the pipeline. This is to be carried out at the next stage of engineering design. Risk Conclusion The report concludes that the PTS, BS#2 and GDT meets both Russian and international standards, and that the proposed pipeline route is suitable on safety grounds, provided that one section of pipeline has further safety measures included.

2.3

CONSTRUCTION

2.3.1

Pipeline Routing Careful selection of a pipeline route is of prime importance in eliminating or minimising any adverse environmental effects associated with the construction and operation of a pipeline. Thus it is important to adopt a systematic route selection process for pipelines in which environmental factors are considered throughout. The constraints and environmental features considered important at the routing stage include:

•

Environmental and social issues - including flora, fauna, hydrogeology, landscape, livelihoods, cultural heritage, protected areas, reinstatement potential and requirements, land use, places of habitation;


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Terrain evaluation and natural hazards - including mudflows, landslides, slow slides, avalanches and seismic faults;

•

Constructability and long-term integrity - including access and logistics assessments, reinstatement, river, gorge and gully crossings;

• •

Security - including terrorism, sabotage, civil unrest; and Safety and health - to ensure the safety and health of construction works and long-term safe operation.

Where possible the route selection process identifies the least sensitive route from an environmental and social impact point of view within the engineering constraints presented by terrain, natural hazards and the requirement to maintain the long-term integrity of the pipeline. In practical terms, the issues listed above translate into:

2.3.2

• • •

avoidance of the main areas of population density;

• •

avoidance of high-risk locations for natural hazards; and

avoidance or minimisation of construction in sensitive environmental locations; selection of optimum locations for major crossings to minimise the length of crossing and maximise reinstatement potential; where avoidance is not possible, development of specific design solutions and mitigation.

Construction Methodology The contract for the pipeline construction has been tendered by SEIC. SEIC will appoint the most suitable Engineering, Procurement and Construction (EPC) contractor from these tenderers, who will subsequently be responsible for the detailed engineering, procurement of materials, construction and commissioning of the pipeline. While there are standard pipeline construction techniques and equipment, the final details with regards to how pipeline construction will be planned and implemented are flexible and will remain so. Having this flexibility allows the EPC contractor and SEIC to implement the optimal solution to ensure that overall, the pipeline is constructed in the most effective manner with due regard to legislative, shareholder and community requirements. The discussion in this section is based on current SEIC planning. Pipeline The onshore construction schedule is divided into two construction periods: preparatory works and main construction activities. The preparatory period includes the following works:

2-26

•

preparation of construction sites for camps and workshop yards (deforestation, topsoil removal, levelling, drainage system);

• • • • •

camp establishment to accommodate construction workers; access roads construction (to the ROW, camps, laydown yards) ROW deforestation and stripping of fertile soil; track roads over swamps; terracing works on the mountain sections with cross slope exceeding 8°;


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subcontractor mobilisation;

•

double jointing at laydown/welding yards.

delivery of pipes, construction machinery and materials to the lay-down/ welding yards; and

The main works of onshore pipeline construction include:

• • • • • • • •

pipe welding on the ROW;

• • • • •

pipeline tie-in;

•

ROW re-instatement.

trenching; field joint coating and lowering-in; pipeline ballasting in swampy and waterlogged sections; trench back-filling; installation of pipelines across watercourses; installation of pipelines across roads and railways; installation of block valves, including power generation units and housing for electrical and instrumentation/telecommunication equipment and cathodic protection; pipe cleaning and testing; pipeline dewatering, drying and commissioning; Fiber Optic Cable construction (FOC); access road construction to block valves. Access road construction is going to be at the same time as pipeline construction; and

Construction of the onshore pipelines is planned to be undertaken during two winter and two summer seasons. The standard method for construction of onshore pipelines is the 'spread' technique. A spread is defined as the manpower and equipment necessary to carry out construction from surveying the route at the start of construction through to restoration works at the end of construction. Typical spread construction is shown in Figure 2.4. The work is conducted on a moving assembly line basis with each sequential activity maintaining a constant rate of progress. The rate at which the spread advances is determined by the nature of the terrain, the frequency of special sections, such as natural (for example river crossings) and man made obstacles and other factors. In addition to the main spread teams, other teams may be mobilised to undertake special activities such as road and river crossings, which require some variation in standard methods. In sections of particularly sensitive environment, modifications may be made to standard spread techniques and to the timing of construction with a view to mitigating environmental impacts. All construction activities are undertaken within a strip referred to as the working strip or right of way (ROW). In this case the width will range from 36 m to 66 m depending on the pipeline diameters and it may be increased adjacent to crossings. The ROW will be cleared of trees, shrubs, and brush that will be disposed of according to approved procedures. The grading operation will prepare the ROW for trenching and pipeline


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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. 2-28


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Volume 4 Chapter 2 Project Description In order that the pipeline can follow the contours of the land and achieve the required line and level, bends are formed in the sections of pipe. Bends are either formed hot or cold; hot pre-formed or forged bends, which are manufactured off-site in a factory, can achieve a greater curvature than cold bends which are formed in the field. If the pipe can be bent to follow the lie of the land as far as possible, this can limit unnecessary excavation and the requirement for additional backfill. The trench is excavated to the requisite depth by standard trenching equipment (eg wheeled/tracked trenchers/backhoes) depending on the season. In some areas, the trench will require battered sides for stability purposes. The excavated subsoil is placed adjacent to the trench. To prevent erosion processes of unstable soils, the time lag between excavation and backfilling will be minimised. Any existing pipelines or services will be manually exposed prior to trenching. The welded pipeline is then lowered into the prepared trench using side boom tractors or equivalent plant ensuring that the pipeline and its protective coating are not damaged in the process. The trench is then carefully backfilled and prior to replacement the excavated subsoil is graded to remove large stones that could potentially damage the coating. In rocky soils, the pipeline coating will be protected against damage by padding with 10 cm of soft soil along the bottom of the trench and 20 cm on top of the pipeline as well as using additional protective measures in locations where suitable backfill materials are not available (TEO-C, Volume 3, Book 7.2). The installation of two pipelines within the same trench can be carried out in a number of ways, most commonly either concurrently proceeding in the same direction or sequentially as two separate operations. Installing the pipelines concurrently in the same direction involves carrying out the trenching and pipe-laying activities at around a 100 m apart for each pipeline. After installation of the more ‘advanced’ pipeline, the pipe trench would be backfilled and a construction mat placed over the pipeline. This allows the area to be used as a running track for the plant excavating the trench and installing the second pipeline. As this takes place, trenching and pipe installation for the first pipeline continues. An advantage of this method is that it minimises the extent of the working width required and may allow optimal use of plant and machinery. It can also limit construction time in any one area, which is particularly important within sensitive environments. However, it does involve construction plant traffic over sections of newly laid pipeline. In sequential construction the pipelines are installed as two separate activities. This method of installation has a longer construction period and the combined working width of the two separate pipelines is likely to be larger than with the concurrent method. The pipeline ROW has been nominally split into five construction spreads as detailed in Table 2.15 (TEO-C, Volume 3, Book 7.2). Construction will commence simultaneously on all five spreads. While some activities are common to both the oil and gas pipeline construction (such as ROW clearing and grading), in general separate crews will be assigned to oil and gas pipelines. There will always be some distance between the oil and gas pipeline construction crews, just as there is always a gap between the different construction activities themselves. Separate special-crossing crews are anticipated for crossings of major rivers, rail or road. The intention of such crews is to install both the oil and gas pipelines at the same time to ensure that time of disturbance at these typically sensitive sites is minimised.


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Pipeline Construction Spreads #

Description

1 2 3 4

Piltun Landfall to OPF, including Lunskoye multiphase and MEG lines OPF to Taulan River (KP124) Taulan River to crossing of Yuzhno-Sakhalinsk - Nogliki Railway (KP 264) From Yuzhno-Sakhalinsk - Nogliki Railway crossing to southern Yuzhno-Sakhalinsk - Nogliki Railway crossing (KP 424) Yuzhno-Sakhalinsk - Nogliki Railway crossing to OET/LNG

5

Length (km) 178.1 160.1 140 160 173

These possible pipeline construction spreads are shown in Figure 2.15. According to the SEIC Sakhalin II Onshore Pipelines Project Specific Technical Specification (PSTS), minimum depth of pipeline laying is at least:

•

0.8 m - to top of pipe when nominal diameter is 100 mm, 500 mm, 600 mm, 700 mm; 1.0 m - to top of pipe when nominal diameter is 1200mm;

•

1.1 m - to top of pipe at swamps and crossings of irrigation / drainage channels (from the bottom);

• •

1.0m - to top of pipe in irrigated lands

•

2 m from rail to top of pipe or casing at railway crossings, and at least 1.5 m - to top of pipe from bottom of embankment or drainage ditch; and

• •

1.4 m - from road surface to top of pipe at road crossings; and

0.5 m - at river crossings from level of expected washout to top of pipe, but no less than 1m from the natural river bottom marks;

at least 0.4 m - to top of pipe from bottom of embankment or drainage ditch (TEO-C, Volume 3, Book 3.2).

Following backfill, the pipeline undergoes hydrostatic testing to ensure it’s integrity. Hydrostatic testing is discussed in Chapter 2.4. Following hydrostatic testing the pipeline is dewatered and dried. Comprehensive operating procedures will be put in place to ensure clear and effective operating instructions and emergency procedures, a system for monitoring, recording and continually updating the state of the pipelines and auxiliary equipment, a schedule for regular inspection and maintenance of pressure regulating equipment and effective corrosion control and condition monitoring. Two anti-corrosion methods will be used to ensure the integrity of the pipelines. Firstly, the pipes are coated in the factory with a fusion-bonded epoxy coating system. After testing, the bare welds are field-coated to an equivalent standard. The second anti-corrosion protection method is achieved by the use of an impressed current system. This system, known as cathodic protection, reverses corrosion currents present in the soil by creation of a pipe to soil negative potential. In addition to the installation of the cathodic protection system, other associated pipeline components will also be constructed. These include block valves and pigging stations. These AGI’s are typically constructed by a separate construction crew from the main pipeline construction crews. Pigging stations are typically co-located at valve sites. All AGIs result in a permanent land take as the sites are required to be securely fenced. 2-30


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Volume 4 Chapter 2 Project Description Fibre Optic Cable (FOC) The fibre optic cable can be installed in three main ways:

•

directly into the ground (by a cable layer, or into a manually or mechanically excavated trench);

• •

in high density polyethylene (HDPE) conduits installed into the ground; and hung from power line poles.

The application of Option 2 is limited because of the potential for deformation of polyethylene tubes under frozen-earth conditions. As the FOC route goes through deep forest areas, above ground installation such as Option 3 is not appropriate as the integrity of the FOC can be compromised by fire or falling tree branches. Following the application of Option 1 there are two ways of work executing:

• •

cable laying together with the pipeline; and cable laying separately from the pipeline.

A comparative analysis of the ways of FOC installation showed that cable laying in a separate trench is preferable (TEO-C, Volume 3, Book 3.2, Section 8). A schematic showing installation of a FOC by a cable layer is shown in Figure 2.5. Construction of the FOC will typically occur following the installation of the pipelines, however where special crossings occur at rivers deeper than 6 m or where the pipeline is installed by means of Horizontal Directional Drilling (HDD) method or at railroads and categorised roads, a conduit for the FOC is going to be installed at the same time as the pipeline installation. Gas Disposition Terminal (GDT) Provision is made for a 6-day working week and for a 10-h working day. The following civil preparatory activities shall be completed before the main construction- installation works:

• • • •

to clean up the GDT Construction Site of low trees and bushes;

•

to set up the field communication system.

to set up temporary site storage facilities for materials and equipment; to prepare temporary production facilities; to construct the temporary camp, which shall ensure appropriate living accommodation, sanitary and recreation conditions for personnel; and

The Main Period includes the following construction- installation activities relating to the GDT construction:

• • • • • •

construction of the foundations for above ground facilities (racks, supports, etc); installation of gas filters, inlet/outlet valves and bypass shelter; installation of the Gas Flow Regulator and Metering Shelter; installation of the Drain Tank; installation of skid mounted equipment and connection piping; installation of power supply system (generators) Shelter;


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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).

Booster Station #2 (BS#2) 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 m3 volume, 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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2.3.4

Construction Workforce Component

Number

Accommodation Arrangements

Pipeline GDT BS#2

3-6000 50-100 200 (however construction camp will have capacity for 400 people)

10 construction camps along ROW Construction camp near site Construction camp near site

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 VI of this EIA.

There are 10 construction camp and laydown/welding yards and two additional laydown yards, as shown in Figure 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

•

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

• • • • •

brown field site preference;

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 be covered by the spread;

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 2.17 and shown in Figure 2.1.

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Proposed Camp and Laydown /Pipe Welding Yard Locations Name

Nearest Kilometre Post

Distance from ROW (m)

Construction Spread

52.90

3980

1

113.90 5.40 171.80 6.30 102.60 103.40 154.40 261.90 262.70 262.20 278.90 316.80 348.40 377.80 398.70 400.80 484.10 484.20 570.20 571.00 597.10

3375 390 155 16 085 3750 1590 4870 2195 1920 12 225 415 1595 6865 6660 215 1165 1765 2200 625 1160 1720

1 1 1 2 2 2 3 3 3 4 4 4 4 4 4 4 5 5 5 5 5

Val Camp/Laydown Yard Nogliki operations camp Nogliki Laydown Yard 1 Nysh Camp/Laydown OPF Site SAR Camp* Yasnoye Camp Yasnoye Laydown Onor Camp/Laydown Leonidovo Camp Leonidovo Laydown Poronaysk IUP Camp* Booster Station 2 Tumanovo Camp/Laydown Porechy Laydown Zaozernoye Laydown Pugachevo Laydown Pugachevo Camp Sovetskoye Camp Sovetskoye Laydown Mitsulevka Laydown Mitsulevka Camp Prigorodnoye LNG/OET * Refer to Volume VI

A typical construction camp and PWY layout is included as Figure 2.6. Further information about the site selection process and description of the construction camp locations can be found in the SIA (Chapter 7). Gas Disposition Terminal (GDT) 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.

Booster Station #2 (BS#2) Temporary infrastructure associated with the construction of the BS#2 includes the construction camp and production base, both of which are briefly described below.


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Plot Plan of Camp and PWY at Val


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Volume 4 Chapter 2 Project Description 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 the production 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 instrumentation and anodes);

• • • • • • •

welding materials (electrodes, wire, fuel); varied fill 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).


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Volume 4 Chapter 2 Project Description 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. Crushed Stone Requirement (m3)

Location Val Nogliki Nysh Yasnoye Onor Leonidovo Tumanovo Pugachevo Sovetskoye Mitsulevka BS#2 Camp GDT Camp Total

Table 2.19

30 300 30 300 30 300 30 300 10 100 10 100 30 300 30 300 30 300 30 300 700 200 263 500

Sand Requirement (m3) 10 500 10 500 10 500 10 500 3500 3500 10 500 10 500 10 500 10 500 40 000 1000 13 200

Sand Requirements for Pipeline Construction per Segment. Pipeline Segment (refer to Figure 1.3 in chapter 1)

Sand for pipeline padding in heaving soils with soil substitution (m3)

Sand for trench fill in fault areas (m3)

31 2562 99 570 247 115 903 817 355 854 604 194 2 523 112

3000

1&8 6 9&2 3 4 5, 7 TOTAL GRAND TOTAL

24 970 6607 17 193 51 770 4 247 587

Sand for pipeline padding in rocky or frozen areas (m3)

116 985 506 976 506 976 270 884 270 884 1 672 705

Electricity An estimation of electricity needs for the pipeline 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).

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Estimate of Electric Power Consumption for Pipeline Construction Construction spread

1 2 3 4 5 Total

Production plants Installed Power capacity consumption 300 590 590 590 590 2660

Consumption amount, kW Living camps Installed Power capacity consumption

240 470 470 470 470 2120

1341 1341 1341 1341 1341 6705

1205 1205 1205 1205 1205 6025

Total Installed capacity

Power consumption

1641 1931 1931 1931 1931 9365

1445 1675 1675 1675 1675 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 will 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 spread Production plants For For production household and needs, technical drinking needs and hygienic needs 1 2 3 4 5 Total

14 20 20 20 20 94

16 18 18 18 18 88

Consumption amount, m3/day Living camps For For production household and needs, technical drinking needs and hygienic needs 162 162 162 162 162 820

155 155 155 155 155 775

Total For production and technical needs

For household needs, drinking and hygienic needs

176 182 182 182 182 904

171 173 173 173 173 863

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;


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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

Electric power need (installed capacity kWt) Water consumption (m3/day)

Construction Site

Construction Camp

70 2.9

136 15

Booster Station #2 (BS#2) It’s 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#2 site 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-gravel mixture;

• •

quarry Vakhrushevo up to BS#2 - 20 km, crushed stone; and railway station Gastello up to BS#2 - 3.5 km, reinforced concrete structures and timber.

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

Electric power need (installed capacity kWt) Water consumption (m3/day)

2.3.6

Workshop Yard Requirements

Camp

Construction

494.0 42.42

641.4 109.74

329.0 3.75

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 will have to comply with permitted levels.

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Typical Discharges from Construction Camps and Construction Activities. Discharges

Construction camp

Construction activities

Yes Yes

Yes

Site runoff Treated wastewaters Trench dewatering Hydrostatic test water runoff (see Section 2.4)

Table 2.25

Yes Yes

Typical Emission Sources from Construction Camps and Construction Activities. Emission sources

Construction camp

Construction activities

Yes Yes

Yes Yes Yes

Vehicles Generators Welding operations (ROW) Machinery repair activities Welding operations (from PWY)

Yes 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

2.3.7

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

Code of material

Hazard class

Tonnes for the construction period Pipeline GDT BS#2

Nitrogen dioxide Nitrogen oxide Sulphur dioxide Carbon oxide Particulates (Dust)

301 304 330 337 2902

2 3 3 4 3

755.822 49.793 356.861 53.246

21.222 22.396 2.335 12.061 0.351

137.4 21.07 142.69 0.697

Management of Potential Impacts Overview This 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.


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Volume 4 Chapter 2 Project Description A separate section is presented to address the presence of unexploded ordinance that 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 Licences for Use of Sub-soil Gosstroy Licence for Construction and Installation Permit to use sand from ‘borrows’ Permit for Construction commencement

MNR - Ministry of Natural Resources MNR - Ministry of Natural Resources FLC - Gosstroy Federal Licensing Centre MNR - Ministry of Natural Resources 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:

2-42

•

Selecting pipeline route, facility locations, access roads, transport routes and associated 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 climate and terrain.

•

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


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Construction Phase Industry Standard Environmental Protection Measures. Receptor

Environmental management measures

Generic to all receptors

• Construct pipeline and facilities in accordance with regulations, industry standards and permits. • Scheduling construction activities to reflect the most efficient use of resources and minimal period of time between commencement and completion of construction. • Implement and follow HSE management system requirements. • Implement and follow issue specific management plans as relevant (eg plans for the management of wastes, emergencies, oil spills). • Implement and follow a stakeholder engagement plan to communicate and inform stakeholders about construction activities. • Compensation payments for modelled damage are calculated, approved by relevant authorities and paid as required. • Minimise blasting activities. • Ensure the safe transport, storage and usage of fuels, oils and chemicals including the provision of bunding. As for geology above plus: • Implement appropriate soil and erosion controls (see section below for examples). • Restrict vehicular access along the ROW. • Regularly inspect ROW for subsidence and erosion and repair as required.. • Where appropriate, stockpile and backfill topsoil separately from subsoils to avoid the mixing of soil types. • Minimise the width of the ROW. • Wherever possible use existing tracks and roads. • Reuse cut vegetation during restoration to promote soil stability and reduce erosion potential of the otherwise bare ground. As for geology and soils above plus: • Ensure the safe transport, storage and usage of fuels, oils and chemicals. • Backfill trench and reinstate ROW as quickly as possible. As for geology, soils, and groundwater above plus: • Minimise the construction time through watercourses • Control discharges and site runoff. • Maintain construction equipment (vehicles, machinery etc) in good working order. • Implement dust control strategies such as minimising vehicle movements and using water for dust suppression. • Minimise vegetation clearance. • Leaving vegetation screens in place wherever possible. • Reinstate ROW to allow previous landuse to continue (within operational conditions). As for landscape above plus: • Inspect ROW for invasive species and formulate appropriate mitigation measures wherever required. • Discourage illegal/increased access to previously inaccessible areas (further discussed in SIA Chapter 12). As above plus: • Inspect trench in sensitive locations for trapped fauna. • Restrict the access of livestock to open trench. • Discourage illegal/increased hunting (further discussed in SIA Chapter 12). As above plus: • Discourage illegal/increased gathering (further discussed in SIA Chapter 12). • Wherever possible, vegetation originally cleared for construction will be reused on the ROW or recycled. • As for landscape above. • Maintain construction equipment and vehicles in good working order. • When working within close proximity to people, schedule most noisy activities for daytime periods. • Select less noise producing equipment. • Refer to Air (above)

Geology

Soils

Ground water

Surface water

Air

Landscape

Habitats

Fauna

Flora

Human - visual Human - noise

Humans - air


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Volume 4 Chapter 2 Project Description Watercourse Crossings The management of potential impacts due to watercourse crossings is the subject of the SEIC River Crossing Position Paper. This section has been taken from that Position Paper (Gamble (SEIC), 2002). Various construction methods were considered for river crossings including open trenching, elevated crossings and horizontal directional drilling (HDD). Whilst some of the sections of the pipelines could cross the streams or marshy areas with elevated crossings using single or multiple span beams, guy with pylons, anchors etc. SEIC prefers that due to security and public safety reasons overhead construction methods are not be used. This is important to ensure that there is no opportunity to allow third parties to damage (particularly) the oil pipeline and thereby cause a significant public safety and environmental issue. In terms of environmental impact during construction, elevated crossings have a lesser impact than open trenching and more impact than HDD. With regard to the rivers on Sakhalin, however, due to extensive flood plains, possibility of liquefaction and potential scouring, this type of crossing would require significant foundation construction to support the pipelines. This type of crossings also carries additional maintenance requirements over and above the routine maintenance for buried pipelines. Particularly with the oil pipeline, the exposure to the extreme air temperatures would lead to the requirement for insulation which in its self adds to the maintenance requirements as this can lead to enhanced corrosion probabilities. Compared to open trenching, the construction for elevated crossings requires additional time and hence a longer period of impact. The preference against overhead crossings has also been expressed by TSUREN (Central Department for Fisheries Expertise and Norms for Protection and Reproduction of Fish Stock) as a condition for approval of the crossing methodology based on their experiences with the Kamchatka Gas Pipeline Project. In view of the above, the Project discounted the use of overhead crossings for rivers with the design of the pipeline system. Proposed Crossing Construction Methods The construction methods for crossings have been engineered in accordance with applicable company standards, Russian Codes and Regulations. The main physical parameters that determine the crossing construction method are the watercourse width and depth. Table 2.29 shows the possible construction methods in relation to the watercourse width and depth.

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Watercourse Crossing Construction Methods

Width

Trench ≤0.5 m firm ground

Lay ≤0.5 m firm ground

Trench ≤0.5 m loose ground

Depth Lay Trench ≤0.5 m 0.5loose 1.5 m ground

Lay 0.51.5 m

Trench >1.5 m

Lay >1.5 m

≤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 in Figure 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.


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


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


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Typical Horizontal Directional Drill Schematic


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Volume 4 Chapter 2 Project Description 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. Table 2.30

Crossing Excavation versus Soil Type Trench excavation in Bed

SNiP Soil group

Soil Type

Hydraulic dredge

2-4 easy up to heavy for single bucket excavator

Sandy loam, clay, sand, gravel to weak siltstone

Rope-scraper with ground loosened by blasting

5-7 single bucket excavator after ripping

Siltstone, gravel-pebble, slates up to harder conglomerate and shale

HDD limit

2, 3, 4 drilling in higher soil group is not recommended

Loam, clay, gravel, gravel pebble, weak siltstone

A description of the River Classification System was included in Chapter 1, Section 1.3.4. An economic evaluation of the types of available crossing was undertaken. In general for crossings of streams smaller than 10 m wide, a single elevated span was the cheapest. There are very few Group III crossings of this type, however, as in the vast majority of cases the flood plain is much greater than 10 m. In line with the reasons above elevated crossings were therefore ruled out. For all other crossings, open trenching was evaluated as the lowest cost alternative. In consultation with Sakhalinrybrod, all Group II and Group III crossings were evaluated for impact of construction throughout the year. In the majority of cases, Sakhalinrybrod have stipulated that work within the flood plain can only be undertaken outside the migration and spawning seasons, limiting construction to between the months of October and March. These months also coincide with the winter freeze. This is important as it is the time when water levels are the lowest, when the flood plain is frozen to depths of 1 m and when streams and rivers freeze (some completely). The freezing effect will significantly reduce the potential for sediment transportation downstream and hence effects on spawning areas. It also allows rapid excavation of trenches and minimization of water ingress to the trenches in the flood plains. The use of ice roads and specialised swamp roads will reduce the effects on the non-excavated ground from heavy equipment.


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Volume 4 Chapter 2 Project Description Sakhalinrybrod has permitted work on some crossings during July, however it is the intention of SEIC to avoid any crossing work on Group II and III crossings outside the October - March period, with the exception of those crossings where HDD is selected as the crossing technique. Sakhalin Energy, in consultation with Sakhalinrybrod, have specified that all Group II and Group III crossings greater than 50 m wide shall be constructed by HDD. These rivers are Val, Tym (first crossing), Naiba, Nabil and Vazi. In addition, any Group II or Group III watercourses that have fish farms downstream of the crossing location will also be constructed using HDD. Similarly, Sakhalinrybrod have further identified rivers requiring HDD. These rivers are Tym (second crossing), Buyuklinka and Firsovka. As such, a total of eight watercourses will be crossed using HDD. This will reduce the impact of construction work on these watercourses. Where HDD is undertaken, pontoons may be used to move personnel and equipment from one bank to the other, however the main equipment will be moved via access roads. Crossing Construction Work Sequence Description Regardless of the crossing method to be used, the pre-installation activities are very similar. Silt fencing will be installed along both banks of the stream, and along the limits of ROW for a minimum distance of 20 m from the stream banks, to minimise the effects of wash out of excavated spoil. After that, clearing and grubbing, and installation of equipment crossing facility will be completed. On completion of welding of the two pipeline sections to be installed under the stream they will be placed on wooden skids on one side of the stream. These two sections of pipeline (pipe strings) will be prepared for installation prior to any in-stream activities. During the designated installation period, these two pipe strings will be installed using either the wet or dry ditch method. Prior to any work within the stream all equipment, labour and materials shall be on site for uninterrupted excavation, pipe laying and backfilling. When the crossing is to be made using the wet ditch method, the ditches are excavated by one of the techniques listed in Table 3.1. In the case of very wide shallow streams with low flow, the excavation equipment may work for a short period in the middle of the stream, using equipment mats if required. The excavated material (spoils) will be loaded to a soil barge, or trucks working and moving simultaneously with the excavator. When using the wet ditch method the crossing is made without impeding the stream flow. The wet stream method is usually completed in a matter of hours, thus minimizing the duration of high turbidity. However, where the wet ditch method is used, turbidity curtains will be installed downstream of the crossing area to impede the release of any sediments from the excavated or disturbed site. When the main pipeline spread cannot lay the crossing without interruption, the crossing will be prefabricated and left on skids near the crossing site. The mainline spread will start laying the pipeline from the far bank. A separate crossing crew will excavate the trench across the stream and install the crossing. By utilising additional resources for this separate team, the crossing duration will be kept to a minimum thereby reducing the potential impacts on both the physical and biological components of the watercourse.

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Volume 4 Chapter 2 Project Description Immediately following completion of the trench excavation the pipe strings are installed and backfilled including restoration of the riverbed as close as possible to its original conditions. The zone of most environmental impact at crossing sites is judged to be 25 m upstream and downstream from the crossing. The zone of impact can, however, reach up to 1000 m downstream, depending on the watercourse characteristics. The zone of influence at the crossing location is being modelled, as part of the TEO-C EPB’s and will form the basis of the Fish Damage Compensation estimate. Table 2.31 provides a summary of the fishery impact versus construction cost comparison. Table 2.31

Construction Methods Cost Versus Degree of Environmental Impact Construction Method

Open trench excavation by backhoe from banks

Open trench excavation by backhoe from pontoon

Open trench excavation from dredge ship

Single or multiple span beam w/or w/out support

Guy crossing

Horizontal Directional Drilling (HDD)

Fishery Impact

Significant unless construction between Oct. and March



Minor (excludes flood plain impact)

Minor (excludes flood plain impact)

None (within flood plain)

Construct. Cost

Low

Low

Low to moderate

Moderate

Moderate

High

Applicable for

For all waterway

For all waterway

For all waterway

For small stream

For stream from 10m50m

Medium to large waterway

Based upon evaluation of the available data discussions with regulatory Federal and State agencies the following approach has been adopted during the Front End Engineering Design (FEED) and TEO-C preparation for watercourse crossings:

•

all 995 watercourses in Group I are proposed be crossed using wet open cut trenching (underground pipe laying);

•

45 watercourses in Group II are proposed be crossed using wet open cut trenching (underground pipe laying). One watercourse, however, (Small Irkir) will be further investigated for suitability for HDD;

•

55 watercourses in Group III are proposed be crossed using wet open cut trenching (underground pipe laying). 36 watercourses, however, will be further investigated for suitability for HDD; and

•

eight watercourses in Group III are proposed for HDD.

A map illustrating the location of the Group III was included in Chapter 1. A summary of the construction method by watercourse group and width is included in Table 2.32.


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Construction Method by Watercourse Group and Width Group

Width < 10 m

Width 10-15m

Width 15- 30m

Width >30m

Total

I

973 all open trench

9 all open trench

7 all open trench

6

995

II

39 all open trench 1 possible HDD: Small Irkir

4 all open trench

2 all open trench

0

45

III

32 All open trench 19 possible HDD: Small Garomay Big Garomay Tomi Bauri Khuma Vosie Daldaganka North Khandasa South Khandasa Borisovka Pobedinka Matrosovka Zamislatovaya Gornaya Zheleznyak Lazovaya Tikhaya Small Takoy Big Takoy 1044

12 11 open trench 1 HDD: Buyuklinka 8 possible HDD: Nituy Malakhitovka Askasay Onor Small Tym Ai Evay Goryanka

11 10 open trench 1 HDD: Firsovka 8 possible HDD: Leodinovka Lesnaya (2x) Orlovka Gastellovka Big Veni Pugachevka Manuy

8 2 open trench 6 HDD: Val Tym 1st crossing Naiba Tym 2nd crossing Nabil Vazi 1 possible HDD: Makarova

63

25

20

14

1103

Total

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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Description of Main Physical Structures used for Soil Erosion Control. Physical Description and application Structures Slope Breakers

A berm of soil constructed across the ROW to prevent water from collecting and flowing down the right of way. Spacing typically depends on angle of slope and soil type. Temporary slope breakers installed during construction and permanent ones are installed during final restoration

Terraces

Terracing is done to reduce the portion of the ROW with very steep slopes - typically used in mountainous areas.

Trench Breakers

Made from stabilised sand, sand filled bags or high density foam, trench breakers are placed within the trench to interrupt the flow of water along the bottom of the backfilled trench. Trench breakers are placed close enough together to pond water from one to another - the water eventually drains by percolation through the surrounding ground rather than by eroding the backfill.

Trench plugs

Similar to trench breakers, except trench plugs are temporary measures installed before the pipeline is placed in the trench. Used where the trench intersects streams, wetlands or ground water and where site conditions might result in drainage of water from the intersected body of water along the trench. A trench plug may also consist of a short section of unexcavated trench.

Energy Used for areas where water flow is concentrated and may have a high velocity such as the dissipaters outlets of culverts, downstream ends of slope breakers or discharge points for pipeline hydrostatic test water. An energy dissipater is essentially a device to promote water turbulence and spreading to decrease the velocity within a nonerodible area. Often made of a pool or channel lined with rocks or a mat of rocks or brush. Can also include a splash plate, which breaks the momentum of the water flow. Riprap/ concrete mats

Usually composed of various sizes of loose rock or other suitable material placed along a river bank along the pipeline crossing and to vulnerable sections upstream and downstream of the river crossing itself. The size and thickness of the riprap is governed by the velocity and angle of attack of the water flowing against the bank.

Gabions

Stone filled wire baskets used in lieu of rip rap- typically used where a vertical bank is required to be reconstructed.

Culverts

Temporary installations used to cross rivers, streams and small watercourses. Culverts reduce instream turbidity and waterway bank erosion and the carrying of soil into the stream caused by construction equipment, pipe trucks and other traffic. They are removed at the end of construction to allow restoration of the waterway to take place.

Seepage Drains

Used wherever subsurface drainage problems interfere with pipeline construction and/ or operations. Design varies according to local conditions however usually consists of a layer of pervious granular fill wrapped in a filter fabric or similar such structure. For severe seepage problems collector pipes are also installed to further divert water away from the site.

Stone Paving or Mats

Typically used at streams whose flows are too small to have defined courses but have low flows for periods long enough to impact the revegetated ground cover.


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Description of Main Vegetative Techniques used for Soil Erosion Control Vegetative technique

Description and application

Reseeding

Reseeding of the ROW using various mixtures of seeds, line, fertiliser and mulch will begin as soon as appropriate after clean-up, restoration and the installation of permanent erosion and sediment control devices.

Reseeding with Mats

Reseeding with the use of mats, loosely woven netting of jute twine or wood excelsior will be employed on steep slopes that are susceptible to erosion. Plastic netting may also be used in areas where the jute mesh will deteriorate faster than the time required for the area to stabilise - typically one to two seasons.

Sod

Sod may be used in areas requiring immediate protection such as a very steep erodible slope, a grassed waterway or a highly scenic and /or public area. However its application is restricted due to the need for extensive bed preparation, hand setting and watering requirements during establishment.

Screens of Natural Vegetation

Leaving screens of natural vegetation eliminates the erosion potential of the slope and also acts as sedimentation control by filtering sediments through the exiting vegetation. These natural screens have the same function as undisturbed areas on wither side of the ROW onto which water is diverted to prevent concentrated flows along the ROW. Screens have an added aesthetic advantage in that they may block the view along the ROW, effectively concealing its presence. Due to the construction methodology, the ability to use screens of natural vegetation are limited but may be able to be applied in some locations

Planting of Seedlings

A longer term erosion control technique for those rivers and streams deemed both large and sensitive enough or highly susceptible to bank erosion potential. When the seedlings are established, their root system holds the oil in place and the plant body slows the riparian currents thereby further reducing the erosion potential.

Areas Not The two areas that will not normally be re-vegetated are bare rock slopes and wetlands. Re-vegetated The re-vegetation of these areas is typically more successful if the areas are left to natural processes. This is due to the fact that plant species in these areas are more adept at recolonising themselves than any commercially available seed mix.

Sediment Control Measures Sediment control begins with limiting erosion using the physical and vegetative techniques outlined above. Nevertheless, erosion cannot be entirely eliminated and it is therefore necessary to control sedimentation. The standard sediment control measures and their application are summarised in Table 2.35 (Environmental Design Guideline - Stream Crossings).

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Description of the Main Sedimentation Control Techniques and their Application Sedimentation control technique

Description and application

Straw berms

Straw berms are used to intercept sediment carried by sheet flow from graded slopes, spoil piles or other exposed areas. They consist of rows of straw bales installed along the contour, imbedded in the soil and anchored by stakes.

Sediment Trap/ Energy Dissipator

Used when the naturally occurring vegetation is not sufficient to filter the water flow when an excavation is dewatered. Refer Table 2.33 for description.

Silt Fences

Perform the same function as straw berms but have the advantage of the ease of installation, versatility that comes from consisting of lightwight materials. The fabric can be either woven or non-woven and may be natural burlap or from a commercially produced fabric. The filter fabric is installed along the contour, perpendicular to the potential water flow and is usually used in conjunction with vegetated strips.

Filter Strips

Strips of vegetation between the cleared ROW and nearby critical or manmade features such as streams, wetlands, buildings, roads etc in the downslope direction. Vegetation strips are useful in filtering sediment carried off the ROW prior to revegetation and also serve to conceal the pipeline. They will be left as often as possible.

Sediment ponds

Essentially a dam to impound sediment-laden water wherever there is a slope that cannot be controlled by erosion methods and revegetation activities.

Unexploded Ordinance It has been recognised that since the end of WWII, many areas on Sakhalin Island have a risk of containing UXOs. This is considered to be primarily a personnel safety issue however there may be environmental consequences of the discovery/ accidental detonation of UXOs as a result of construction activities. In co-ordination with Sakhalin authorities, SEIC has had a system in place for the identification of UXO areas and their subsequent clearance. While it is expected that construction areas will be cleared prior to activities commencing, it is assumed that this system will continue to be in place to assure the safety of both personnel and the environment. As such the potential environmental risk associated with UXOs is adequately mitigated.

2.4

COMMISSIONING ACTIVITIES

2.4.1

Key Issues Pipeline - Hydrostatic Testing Pressure testing is typically undertaken following backfill activities. Pressure testing involves pressure testing the pipeline (usually with water in which case the testing is called hydrostatic testing or hydrotesting) for pipeline leak and weakness detection. Prior to hydrotesting the pipeline is pre-cleaned and gauged. Following hydrotesting the pipeline is cleaned and dried - this is achieved by using air pressure to push cleaning and drying pigs through the pipeline to remove residual water, welding slag and sediment (APIA, 2000).


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Volume 4 Chapter 2 Project Description The list of major steps associated with hydrotesting are:

• •

prepare to flush pipeline;

•

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

• •

prepare to test;

• • • • •

build up pressure to reach testing pressure value;

run a pig under air pressure, with water slug of 300 m3 run before the pig, drain used water into settling pits after cleaning;

fill pipeline with water, running a separation device and injecting water before separation device in the volume constituting 10% of cavity volume of the segment being tested. Drain used water into settling pits after fill-up; 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 confirmation that 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 pipeline 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/ water inlet

water source water inlet water inlet water source water inlet water source water inlet water source K water inlet water source

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Name of watercourse, (location on the pipeline route - KP of the route); depth in the area of crossing during low water flow.

r. Val (49,5); 2,6 m Okhotsk sea (landfall from PA) r. Bauri (92,6); 1,0 m r. Tym (123,3); 3,3 m Okhotsk sea (landfall from LUN) r. Parkata (38,3); 0,7 m r. Pilenga (44,9); 0,3 m r. Malaya Tym (79); 1.0 m r. Taulan (124); 0.3 m r. Onor (153); 0.8 m


Water intake Total Water volume, discharge m3 during water intake, intake,

44 150

Total water volume for hydraulic tests for strength/ tightness, discharged without treatment, m3 (discharge rate 0,3 m3s-1).

Total water volume for flushing, discharged after settling in storage pits, M3 (discharge rate 0,3 m3 m3s-1).

19 460

2 846

31 880

4 988

66 080

8 408

118 410

13 641

104 180

12 218

0 25

40 520

03

127 442

0 25-0 3

113 170

0 25-0 3

112 384

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Total Volumes of Water Intake and Discharges for Hydrostatic testing Continued Water source/ water inlet

Name of watercourse, (location on the pipeline route - KP of the route); depth in the area of crossing during low water flow.

water inlet

r. Pobedinka (195.5); 0.3 m r. Matrosovka (Kamenka) (239.5); 0.2 m r. Bolshaya Tikhmenevka (266.4); 0.3 m r. Nitui (307); 0.1 m r. Pugachevka (400.2); 2 m

water source water inlet water source water source/ water inlet water source/ water inlet water source/ water inlet water inlet

r. Firsovka; 0.5 m

Water intake Total Water volume, discharge m3 during water intake, intake,

Total water volume for hydraulic tests for strength/ tightness, discharged without treatment, m3 (discharge rate 0,3 m3s-1).

Total water volume for flushing, discharged after settling in storage pits, M3 (discharge rate 0,3 m3 m3s-1).

125 330

13 333

111 692

0.15-0.2 93 060

11 106

201 748 108 678

0.25-0.3 0.25-0.3

122 060

13 106

99 306

0.25-0.3

97 980

10 698

0.05

89 460

9 846

91 660

10 066

r. Bolshaya Takoi (532); 0.2 m 101 726 r. Mereya (565); 2 m

Note: Total water volume for each section 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

Okhotskoe sea shore near outlet from PA r. Bauri Okhotskoe sea shore near outlet from LUN r. Pilenga r. Taulan r. Pobedinka r. Bolshaya Tikhmenevka r. Pugachevka r. Firsocka r. Bolshaya Takoi r. Mereya

Volume m3

Area m2

1423 1402 3907 6025 5468 5691 5133 14400 8178 7506 7698

475 468 1300 2010 1825 1900 1710 4800 2730 2500 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 emissions associated with venting and flaring at AGIs. 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 PA N Y • E N V I R O N M E N TA L I M PA C T A S S E S S M E N T

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Volume 4 Chapter 2 Project Description GDT and BS#2 Commissioning There will be air emissions during commissioning of both the GDT and BS#2. During commissioning of BS#2, some of the emissions from the site will exceed the concentrations allowed by Russian regulations. The Russian air modelling that has been completed for the site is not easily comparable to common western models, however it is widely accepted that Russian air modelling is very conservative. Despite the modelling results it is not considered appropriate to implement any additional measures to further mitigate the emissions during this short period of time. 2.4.2

Management of Potential Impacts Hydrostatic Testing Management of potential impacts from hydrotesting includes the following mitigation measures:

•

Water intake pits will be located at the sites as remote from the channel flow as possible, where the number of drifting fry is the lowest.

•

Hydrotest water flow rates (during fill-up and discharge) will not represent more than 10-15% of the natural watercourse flow at the time of operation.

•

A water filter will be installed at the water intake inlet to prevent silt and suspended particles from getting into the water intake pipe.

•

In order to prevent the fry from being sucked into the water intake inlet, the same intake be furnished with fish protection device. The device will be selected depending on the fish species and size composition in the water intake area, river water flow rates and the design water intake flow rate but is expected to be a fish protection strainer with mesh size of 2mm.

•

Following pipeline cavity cleaning, water will be drained into settling pits, filtered through filter dams.

•

Since clean up schedules vary for different pipeline segments, and also for gas versus oil pipeline, each watercourse where water is to be discharged after pipeline clean-up will be provided with one settling pit, the pit will be sized for the maximum discharge volume expected from the gas pipeline as this has a larger diameter than the oil pipeline.

•

The duration of water settlement in pits may be up to four days. Once the water has been drained, the residual water will be hauled to waste accumulation sites, and the settling pits will be reclaimed or if permitted, the residual water will be buried directly in the settling pits.

•

Should the use of settling pits become impractical (eg in mountain areas), water shall be discharged through sand and pebble filters at the valley bottom.

The water discharge will contain mostly non-toxic litter, the bulk of which would be soil, small amounts of welding scale and some chemical residue at a very low concentration. Water treatment efficiency for settling pits is around 90% in terms of solid particles recovery, and about 10% in terms of chemicals recovery, it is therefore not considered that the discharge water will cause any harm to the environment. Hydrotesting will be undertaken during the summer months as detailed in Table 2.38.

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Schedule of Water Intake for Pipelines Cleaning and Hydraulic Test Watercourse

Cleaning

Hydraulic test

r. Val r. Tym r. Parkata

May, July (2004) May, June, August (2004) July, August, September, October (2004); May (2005) June, July, August, September (2004); May, June (2005) June, July, August, October, November (2004); May, June (2005) May, August, September, October (2004); June (2005) June, July, August, October (2004 r); May (2005) June, July (2004); June (2005) August, September (2004); May (2005) August, September (2004 r); June (2005)

August (2004), May (2005) May, June (2005) June, July, August (2005)

r. Malaya Tym r. Onor r. Matrosovka r. Nitui r. Pugachevka r. Firsovka r. Bolshaya Takoi

July, August (2005) June, July, August (2005) May, June, July, August (2005) May, June, July (2005) May, August (2005) May, June, July, August (2005) May, July, August (2005)

Note. Schedule of cleaning and hydraulic test are different due to using different watercourses and different time of performing activities on pipeline sections.

2.5

OPERATION The pipelines will be operated remotely from a control room located at the OPF site. A second control room at the LNG site will be a back up in case of any problems at the OPF. Each of the valves along the pipelines have instrumentation and monitoring equipment that collects data regarding parameters such as pressure, flow rate, and temperature. All data is collated and managed by a SCADA system (Supervisory Control and Data Acquisition System) that records and presents the data to the pipeline operators in located in the control room. From this control room, the operators are able to make adjustments to ensure the continued safe and efficient operation of the pipelines. Leak detection systems and emergency shut down capabilities further enhance the ability of the pipeline operator to monitor and respond to any changes or events that could otherwise alter the pipeline’s functioning. In addition to the central control room where the pipeline can be operated remotely, physical inspections of the pipeline ROW and valve sites via helicopter and vehicle (where road access exists) are undertaken regularly. The ROW as well as all AGIs are constantly monitored and maintained by pipeline crews to ensure they remain fit for purpose and safe. Maintenance and servicing is carried out as a part of normal pipeline operations in order to minimise any risks associated with equipment failure. Inspections will include the following tasks:

• • •

ROW inspection;

• •

CP, ESD and Leak Detection System verification and testing; and

River and other special crossings inspections; Equipment and instrumentation checks in accordance with manufacturers and operators requirements; Third party activities in the vicinity of the pipeline and AGIs.


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Volume 4 Chapter 2 Project Description 2.5.1

Workforce The operational workforce is detailed in Table 2.39.

Table 2.39

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

Pipeline GDT BS#2

2.5.2

Workforce number

On site accommodation?

50-100 To be serviced by pipeline workers Between 6 and 16

No No Yes for 16 people

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. Gas Disposition Terminal (GDT) 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. Booster Station #2 (BS#2) Water is required for the following 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:

• •

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in summer - 18 m3 d-1; and in winter - 27 m3 d-1y.


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Volume 4 Chapter 2 Project Description 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.

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 to the 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:

• • 2.5.3

in summer, for 3.5 days; and in winter, for 2.5 days (TEO-C, Volume 3, Book 8.3.1, Appendix D.1).

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, Used oils etc

GDT

Venting, emissions from generator drivers

Site runoff

Used oils etc

BS#2

Venting, emissions from generator, compressor and booster pump drivers

Sanitary wastewater Site runoff

Used oils etc

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 #2 Air 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.


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Emissions from the GDT and BS#2 During Normal Operations Pollutant code

Description of Pollutant

2902 301 304 328 330

Particulates (dust) Nitrogen dioxide Nitrogen oxide Carbon black Sulphurous anhydride; sulphur dioxide Carbon oxide CO2

337

Formula

Hazard Class (1)

t/yr GDT

NO2 NO C SO2

2 3 3 3

8.47 1.376

CO

4

BS#2

0.392

0.007 37.697 190.412 1.64 24.452

14.16 9 761.416

2 020.862 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 onsite 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 and gutters (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 as a result of watering the technological areas; and

wastewaters after washing the filters of the potable water preparation installation; conventionally clean waste waters (safe) coming from the potable water preparation installation; rainfall and snow melt wastewaters from the technological areas of BS #2.

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

• • • •

domestic wastewaters after purification works - 1825 m3 y-1; salt-containing wastewaters - 51 m3 y-1; oil-containing wastewaters - 375 m3 y-1; and conventionally clean wastewater - 1 095 m3 y-1.

Upon purification and disinfection, domestic wastewaters are mixed with purified oilcontaining, conventionally clean and salt-containing wastewaters into a single flow forwarded for discharge.

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Volume 4 Chapter 2 Project Description 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 Indices Suspended substances, mg l-1 Dry, calcined, mg l-1 Calcium, mg l-1 Sulfates, mg l-1 Chlorides, mg l-1 OBR, mg l-1 CBR, mg l-1* Ammonium nitrogen, mg l-1 Nitrite nitrogen, mg l-1 Nitrate nitrogen, mg l-1 Common iron, mg l-1 Copper, mg l-1 Zinc, mg l-1 Oil products, mg l-1 Phenols, mg l-1 Phosphates mg l-1 Benzene mg l-1

2.5.4

Purified run-offs for discharge

MPC

3 1000 180 100 300 3 30 0.39 0.02 9.1 0.1 0.001 0.01 0.05 0.001 0.2 0.5

3 1000 180 100 300 3 30 0.39 0.02 9.1 0.1 0.001 0.01 0.05 0.001 0.2 0.5

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 surrounding environment, 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 Section 3.


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Operations Phase Industry Standard Environmental Protection Measures. Receptor

Environmental management measures

Generic to all receptors

• Maintain pipeline and facilities in accordance with regulations, industry standards and permits. • Implement and follow HSE management system requirements. • Implement and follow issue specific management plans (eg plans for the management of wastes, emergencies, oil spills). • Implement and follow a stakeholder engagement plan to communicate and inform stakeholders about operational activities. • Compensation payments are calculated, approved by relevant authorities and paid as required.

Geology

• Adequately maintain the ROW. • Ensure the safe transport, storage and usage of fuels, oils and chemicals.

Soils

As for geology above plus: • Restrict vehicular access along the ROW. • Regularly inspect ROW for subsidence and erosion and repair as required.

Ground water

• Ensure the safe transport, storage and usage of fuels, oils and chemicals.

Surface water

• Inspect river banks for evidence of erosion, repair as required. • Maintain water intake, treatment and discharge facilities.

Air

• Maintain equipment (AGIs, vehicles, machinery etc) in good working order. • Wherever possible, minimise the release of gases to the atmosphere, if releases can be controlled, give preference to flaring the gas rather than venting. • Develop and implement a Greenhouse gas reduction strategy. • Implement dust control strategies such as minimising vehicle movements and revegetating disturbed areas.

Landscape

• Monitor success of restoration / reseeding, where necessary take actions to further promote vegetation cover. • Undertake appropriate landscaping at AGI sites.

Protected areas • Operate pipeline in accordance with any special requirements stipulated by relevant authority responsible for the management of the protected area. Habitats

• Make provision for adequate fire protection measures. • Promote appropriate revegetation of the ROW then adequately maintain the ROW. • Inspect ROW for invasive species and formulate appropriate mitigation measures wherever required. • Monitor adjacent landuse activities. • Discourage illegal access to previously inaccessible areas.

Fauna

• As above

Flora

• As for habitats above

Human - visual • Promote appropriate re-vegetation of the ROW. • Undertake appropriate landscaping at AGI sites. Human - noise • Maintain equipment in good working order. Humans - air

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• Refer to Air (above).


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Volume 4 Chapter 2 Project Description 2.5.5

Episodic Events Episodic events are considered to include the following:

• • • •

third party interference; 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 I included 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:

• • • 2.6

location, timing and nature of the event; environmental sensitivity of the receiving environment; and scale and effectiveness of the response.

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. Actual abandonment 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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Volume 4 Chapter 2 Project Description

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Pipeline Project Description

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