A ESIA Yemen Section 3 Revision 1

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REVISION 1 Date : 10 February 2006

Yemen LNG Company ltd

Yemen LNG Project

Environmental and Social Impact Assessment

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CONTENTS

Section Page Number 3. PROJECT DESCRIPTION............................................................................................ 3-1

3.1. MAIN LINE – TRANSFER LINE ....................................................................................3-1 3.1.1. Project Overview .....................................................................................................3-1 3.1.1.1. Main Line.............................................................................................................3-1 3.1.1.2. Transfer Line .......................................................................................................3-2 3.1.1.3. KPU and CPU facilities .......................................................................................3-2 3.1.1.4. Gas Composition.................................................................................................3-3 3.1.2. Construction, Installation and Commissioning .......................................................3-3 3.1.2.1. Construction Activities .........................................................................................3-3 3.1.2.2. Commissioning Activities ....................................................................................3-4 3.1.2.3. Construction Camp.............................................................................................3-5 3.1.2.4. Specific Construction Techniques ......................................................................3-5 3.1.3. Pipelines Process Operations.................................................................................3-6 3.1.3.1. Maintenance........................................................................................................3-6 3.1.3.2. Control / Inspection .............................................................................................3-6 3.1.3.3. Logistics...............................................................................................................3-6 3.1.4. Decommissioning....................................................................................................3-6

3.2. BALHAF LNG PLANT....................................................................................................3-7 3.2.1. Project Overview .....................................................................................................3-7 3.2.2. Construction, Installation and Commissioning .......................................................3-8 3.2.2.1. LNG Process Unit and Utilities............................................................................3-8 3.2.2.2. Jetty and MOF Construction ...............................................................................3-9 3.2.2.3. Construction Camp...........................................................................................3-10 3.2.3. Process Operations...............................................................................................3-11 3.2.3.1. Flare systems....................................................................................................3-12 3.2.3.2. Liquid Burners and Tank Vents.........................................................................3-12 3.2.3.3. Water Intake and Water Systems.....................................................................3-13 3.2.3.4. Sewer and Wastewater Collection Systems.....................................................3-14 3.2.3.5. Wastewater Treatment Plant ............................................................................3-16 3.2.3.6. Utilities ...............................................................................................................3-17 3.2.3.7. Logistics.............................................................................................................3-18 3.2.3.8. Additional Facilities ...........................................................................................3-18 3.2.4. Decommissioning..................................................................................................3-19 3.2.5. Summary of Wastes and Emissions.....................................................................3-19 3.2.5.1. Atmospheric Emissions .....................................................................................3-19 3.2.5.2. Liquid Emissions ...............................................................................................3-23 3.2.5.3. Wastes...............................................................................................................3-24 3.2.5.4. Summary of Emissions and Waste...................................................................3-26 3.2.6. Indicative Schedule of the LNG Project................................................................3-26

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FIGURES

After page n°

Figure 3-1 Main Line Transfer Line Location Map 3-1

Figure 3-2 Main Line and Transfer Line Profiles 3-1

Figure 3-3 CPU and KPU Facilities in Marib 3-2

Figure 3-4 Pipeline Right-of-Way and Working Area 3-2

Figure 3-5 Main Line Construction Camps and stock piles locations

3-5

Figure 3-6 Balhaf LNG Plant and Camp Location Map 3-7

Figure 3-7 Aerial view of model of Balhaf LNG Plant 3-7

Figure 3-8 Jetty loading berths 3-8

Figure 3-9 Balhaf LNG Plant Overall Site Plot Plan 3-11

Figure 3-10 LNG Treatment Train Block Flow Diagram 3-11

Figure 3-11 Desalination Plant 3-13

Figure 3-12 LNG Plant Simplified Water Discharge Flow Diagram 3-14

Figure 3-13 Main and Transfer Lines – Project Schedule Bar Chart 3-26

Figure 3-14 Level 1 Overall Project Bar Chart Schedule 3-26

TABLES

Table 3-1 Gas composition

Table 3-2 LNG plant feed gas composition

Table 3-3 Flare systems

Table 3-4 Water consumptions

Table 3-5 Sanitary treatment plant standards for discharge

Table 3-6 Consumptions during normal operations

Table 3-7 Consumptions during shutdowns

Table 3-8 Estimated GHG emissions

Table 3-9 Estimated GHG emissions intensities

Table 3-10 Wastewater flows

Table 3-11 LNG plant waste streams

Table 3-12 Summary of Emissions and Wastes

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3. PROJECT DESCRIPTION NOTE: The project description presented here is based on the most recent available design data. This data is subject to further development and the ESIA will be updated as and when required to reflect the updated information.

3.1. MAIN LINE – TRANSFER LINE 3.1.1. Project Overview The YLNG Project comprises connection to the existing oil and gas production facilities of the Marib fields in the block 18, to extract the required gas to feed the projected LNG plant to be located in Balhaf on the Gulf of Aden. Another pipeline, the Spur Line which will connect Ma’bar is not yet fully defined and will be addressed in a separate ESIA. The present ESIA concerns the following two pipelines:

• The Main Line will supply the LNG plant with gas from the Kamil Processing Unit (KPU) located in Marib Province, Yemen to the Balhaf LNG plant;

• The bi-directional Transfer Line will link the KPU and the Central Processing Unit (CPU) at Alif.

Figure 3-1 shows the location of the pipelines and Figure 3-2 shows the profiles of the Main Line and Transfer Line respectively.

3.1.1.1. Main Line

The Main Line will consist of a 325 km long, 930.4 mm constant internal diameter, hereafter referred to as 38-inch diameter pipeline, starting from KPU to Balhaf site. The design flow capacity is 1,280 MMSCFD. This system could eventually be expanded to approximately 1,600 MMSCFD.

The Main Line will take a sidestream off the gas reinjection header from KPU and let the pressure down for transport to Balhaf through the pipeline.

The Main Line starts at Kilometric Point 0 (KP 0) from the KPU, at an elevation of 960 m. The pipeline route travels south-east through the sand dunes and across a flat desert plain for about 134 km, and then ascends to a plateau at an elevation of approximately 1,420 m. On the plateau, the route gradually climbs over a distance of 64 km to an elevation of 1,720 m, before descending to Wadi Salmun. The route then avoids the wadi by taking an east turn. Then it travels across the generally flat coastal desert plain gradually descending to 260 m before reaching the coastal sand dunes and Balhaf at KP 320.

The pipeline (API 5LX70 steel grade) will be buried. The design pressure is between 117 barg and 134.5 barg depending on the location. The pipeline predominantly qualifies as ANSI Class 1 design, with Class 2 design in the last 23 km of the Main Line (Balhaf side) and in the CPU-KPU vicinity, since most of the pipeline route stays well clear of all dwellings. The pipeline route generally remains at least 200 m from any dwellings for safety reasons. To achieve this requirement in the coastal plain to Balhaf, additional relocation has been planned to stay away from the new dwellings and agriculture that have developed in the area

DUNE FIELD

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MAIN LINE - TRANSFER LINE LOCATION MAP

ENVIRONMENTALAND SOCIAL IMPACT ASSESSMENT

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YLNG

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since the performance of the 1997 baseline survey. The current design with two trains at Balhaf plant does not comprise an intermediate compressor station at the foot of the plateau.

The right of way (ROW) for the pipelines will be typically 17 m to 30 m in width depending on the area (Figure 3-4).

Sectional valves will allow the Main Line to be isolated by section.

3.1.1.2. Transfer Line

The transfer Line will connect KPU to CPU. It will consist of a 25 km long, 30-inch diameter pipeline, which will be constructed parallel to two other existing 12” and 6“ diameter pipelines of Yemen HOC (YHOC). The Transfer Line is located in a flat desert region of low sand dunes approximately 75 km northeast of the City of Marib between KPU and CPU. It will be buried.

3.1.1.3. KPU and CPU facilities

The existing gas processing plants in the Marib area (Figure 3-3), which have been in operation for about 12 years, extract pentanes and heavier for export, LPG for domestic consumption, and return the residue gas for re-injection into the oil fields. They are concentrated in two main gas processing facilities at Alif (CPU) and Kamil (KPU), located 22 kilometers apart:

• The KPU facility comprises two 420 MMCFD cryogenic gas plants and four compressor trains which process over 1 billon cubic feet of gas per day. At KPU facilities, gas is compressed to 220 bar and cooled to a maximum of 15ºC above ambient temperature or 60°C maximum for re-injection into the field.

• The CPU facilities include two cryogenic plants: a 500 MMCFD lean oil plant and a 420 MMCFD cryogenic plant, with their six re-injection compressors, which process over 1.2 billon cubic feet of gas per day.

For the YLNG Project, the following upgrade will be implemented, in compliance with the World Bank standards, at these two facilities:

To ensure adequate LNG feed gas supply, the three existing cryogenic plants will be utilized with minor modifications, and one new additional cryogenic plant will be constructed, as the lean oil plant at the CPU cannot supply gas to the required specification. The new CPU cryogenic plant will be designed to process 420 MMSCFD. New compression and power generation facilities will also be part of these new facilities.

Modifications to existing plants will include flow control / pressure letdown stations from the compressors, vent stacks to handle blowdown and PSV discharge gases, in addition to the necessary tie-ins to the 30” transfer line between CPU and KPU and to the 38” feed gas pipeline to Balhaf.

The combination of these four gas treatment plants will provide sufficient feed gas availability to the LNG plant, three plants being normally needed to meet the peak flow rate requirement.

The design of the upstream facility expansion and upgrade related to the YLNG Project (CPU-KPU) is currently in the conceptual stage. Preliminary and final design phases have not yet begun. Accordingly, details regarding the construction and operation of upstream facilities related to the YLNG Project are not yet available

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YEMEN LNG


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3.1.1.4. Gas Composition

The gas composition in the Main Line, which feeds the LNG plant, can be summarized in Table 3-1 as follows:

Table 3-1 Gas composition Dry Concentration (mole %)

Composition Very Lean Case Rich Case1.

Nitrogen 0.09 0.175

Methane 93.22 89.893

Ethane 5.09 5.204

Propane 1.22 3.088

i-Butane 0.08 0.452

n-Butane 0.11 0.819

n-Pentane 0.01 0.036

i-Pentane 0.01 0.034

Dimethyl-pentane - 0.008

Trimethyl-pentane - 0.003

n-Hexane - 0.008

n-Heptane - 0.027

Carbon dioxide 0.17 0.253 1. The gas composition for the rich case was used as the basis for this ESIA report. These values only relate to this ESIA report.

3.1.2. Construction, Installation and Commissioning

3.1.2.1. Construction Activities

Construction will use standard cut-and-fill techniques for most of the pipeline length (Figure 3-4). The construction activities outlined below are indicative only and typical for pipelines, and include seven major activities:

• Clearing and grading: it involves removing bushes, trees and any other obstructions from the pipeline ROW and grading the ground surface as much as practical to reduce the need for bends in the pipe; bulldozers and graders are typically used;

• Stringing and bending: the joints, with a single joint length of approximately 12 m, will be placed end to end along the open trench by side-boom tractors; a bending crew will place cold bends in the pipe using other side-booms and bending machines;

• Line-up and welding: the line up crew fits joints of pipe together using either an internal or external alignment clamp and applies the initial weld called the

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stringer or root weld, thanks to side-booms and tack rig tractors; welds are complete by individual welding rigs;

• Trenching: the main sections of the pipe trench are typically excavated using either trenching machines, backhoes or excavators, or combinations of both;

• Tie-in and lowering in: long sections of welded pipe are welded together (tied in) and lowered into the trench with side-booms or backhoes; then instrumentation controls (fiber optic cable) will be positioned in the pipeline trench or in adjacent trench;

• Backfill and cleanup: if the remaining trench spoil is free of large rocks, it will be placed back directly over the pipe, otherwise, fine material such as sand or sifted earth will be placed over the pipe to a shallow depth; the trench will then be filled to existing ground level with the excavated spoil and infill materials; any excess spoil will remain along the pipeline within the limits of the ROW; the trench is backfilled to an approximate depth of 1 m to the top of the pipe;

• Clean-up and restoration: the ROW and temporary work spaces will be cleaned-up as soon as the pipe is laid and backfilled; all debris, scrap and other waste material will be collected and properly disposed of or eliminated according to construction contractor procedures approved by YLNG (landfill or incineration, depending on the waste characteristics) ; rock will not be windrowed or distributed along the ROW in areas where topsoil replacement has occurred; where the line runs through permanently irrigated and cultivated land, the trench backfill shall be appropriately compacted so as to permit normal irrigation and cultivation.

3.1.2.2. Commissioning Activities

After backfill and clean-up, the pipe will be hydrostatically pressure-tested by sections and commissioned at the end of the construction.

Each pipeline section will be filled with water. The origin of the water, sourced from three or four deep wells located along the pipeline route, will be in accordance with groundwater protection regulation in Yemen. To prevent corrosion, the water will be treated with a number of chemicals including biocides, oxygen scavengers and corrosion inhibitors. Chlorine will be at a concentration lower than 50 ppm in all cases. These chemicals will be generally selected for their effectiveness and low toxicity, and will be biodegradable.

For the hydrotest, water will be brought to the specified test pressure and be held at this pressure for a specified period of 24 hours. During this period, pressure and temperature of the water inside the pipeline are measured at regular intervals. Hydrostatic test water will be recycled between test sections to minimize the quantity of water required. The volume of water required for each test section is estimated to be approximately 20 000 m3 (the exact amount of water required for the test is still under assessment). However, the total volume required for the pipeline hydrostatic testing is expected to be at least 40 000 m3 (20 000 m3 for Main line and 20 000 m3 for Transfer Line). The hydrostatic test water discharge location is not decided yet and needs to be detailed in specific studies. However, it is expected that the hydrostatic test water may be discharged into lined evaporation ponds located along the pipeline route.

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After the hydrostatic test of the pipe, scrapping operations will be done to remove rust deposit and potential solid wastes left in the pipe. These wastes will be recovered in Balhaf LNG plant and will be disposed of or eliminated according to construction contractor procedures approved by YLNG (landfill or incineration, depending on the waste characteristics).

3.1.2.3. Construction Camp

Two camps will be installed for the construction of the pipelines: one at KP 110 at the end of the desert area and one at KP 283 in the coastal plain (Figure 3-5). The camps will also have an equipment and pipe yard. There will be three other intermediate pipe yards (KP 0 at KPU, KP 70 in the desert, KP 240 in the upper coastal plain and along the pipeline route. These pipe yards will be guarded. The overall size of each camp is expected to be approximately 250 x 350 m in width but will vary depending on terrain conditions.

The work force will vary depending on the different activities involved at each construction step. The camps will be designed for a maximum capacity of 1,000 persons for durations of 4 to 6 months at each camp location. The Main Line and Transfer Line installation is expected to last approximately 2 years.

All camps will be equipped to satisfy adequate sanitary and waste treatment, depending of the number of people involved. Treated wastewater may be reused for dust control and garden watering. The sewage sludge will be dried, stabilized for appropriate disposal.

3.1.2.4. Specific Construction Techniques Special construction techniques will be required for some areas, including the following:

• Construction of pipeline in large dunes: The sand will be cleared over a width of 33 m and piled on each side of the ROW. The trench will have a width of 15 m at the top and 7 m at the bottom depth of 2 m;

• Ascent and descent of the plateau: The ROW width will be reduced to approximately 17 m and the trench width will be 10 m. The ROW on the ascent and descent of the plateau will be used for equipment and supply transport to the plateau. For slopes greater than 25° the equipment will be secured by a winch cable. These accesses to the plateau will be maintained at the end of the construction for pipeline maintenance operations;

• Shallow wadi crossings: standard trenching will be used in construction with concrete coating of the pipe for additional stability and minimum cover of 1.70 m;

• Blasting: the trench will be excavated in hard rock using drilling and blasting; • Topsoil Separation: in agricultural and pasture land the topsoil will be saved

and stockpiled separately from the subsoil; after pipe laying, topsoil will be replaced as the upper surface of the ROW;

• Minimum Cover: the normal ditch will normally be excavated to provide a minimum cover of 1 m; however, certain soil or terrain conditions would require depths of cover as follows:

0 25 50 75 100 Km

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YEMEN LNG


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- consolidated rock: 0.60 m;

- agricultural land: 1.20 m; - wadi crossing: 1.70 m.

3.1.3. Pipelines Process Operations

The pipelines will be operated dry, i.e. free of liquid hydrocarbons and water.

Operational activities will mainly consist of pipeline scraper trapping and monitoring. A maintenance track will follow the pipeline ROW.

3.1.3.1. Maintenance

Scraper traps will be constructed at both ends of the Transfer Line and Main Line to allow scraping operations for cleaning and inspection. The scraper will be sent from KPU to Balhaf.

Corrosion protection will be provided by 3 layers of polyethylene coating plus an impressed current cathodic protection system using thermoelectric generators.

3.1.3.2. Control / Inspection The pipeline will be regularly inspected and the process monitored. This will take several forms, as described below:

• Pipeline pressure, flow rate and block valves will be continuously monitored by a Supervisory Control And Data Acquisition (SCADA) system from a Central Control Room in the LNG plant. Block valves are located approximately every 32 km along the pipeline. Joints and gaskets which could initiate leaks are limited to block valves. The rest of the pipeline is welded and pressure tested. A fiber optic cable will be installed in parallel with the pipeline for communication links;

• Control and maintenance patrols will drive regularly the route of the pipeline using the access road adjacent to the pipeline; this will check for third party surface disturbance or other potential activities or risks to pipeline integrity.

3.1.3.3. Logistics

During operation of the pipeline, only monitoring and maintenance personnel are required. They will be based at the permanent camps in Balhaf and CPU/KPU.

3.1.4. Decommissioning

At the end of the lifetime of the Project, the pipeline will be decommissioned. After flushing the pipeline will be left in place, appropriately sealed and identified.

Above ground structures such as wadi crossing, sectional valves, detection and data transmission will be dismantled and removed.

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3.2. BALHAF LNG PLANT 3.2.1. Project Overview

The LNG plant will process natural gas transported via pipeline from the KPU facility. The site is located near Balhaf on the south coast of Yemen, approximately 140 km west of the port city of Al Mukalla and 380 km east of Aden. Coordinates are as follows: 13°59’00” N, 48°10’50” E.

The 1 km2 LNG plant included in about 10 km2 fenced site is located in an area of extinct volcanic craters and basalt flows to the east and a sandy coastal plain to the west. Two isolated hills known as Black Barn and North Rock lie immediately to the north-west of the site. A location plan of the site and ancillary facilities and camps is presented in Figure 3-6. An aerial photograph of a scale model of the LNG plant and MOF is shown on Figure 3-7.

The LNG plant will comprise two processing trains of 3.45 Million Ton per annum (Mtpa) each, thus a design production capacity of 6.9 Mtpa. In the initial phase, the facilities will be delivering a guaranteed capacity of 6.7 Mtpa of LNG. Finished product will be stored and then shipped out by sea in 135,000 m3 average LNG carriers every 3 or 4 days.

The quality of the LNG plant feed gas is presented in the following Table 3-2:

Table 3-2 LNG plant feed gas composition Dry Concentration (mole %)

Composition Very Lean Case

Rich Case

Nitrogen 0.09 0.175

Methane 93.22 89.893

Ethane 5.09 5.204

Propane 1.22 3.088

i-Butane 0.08 0.452

n-Butane 0.11 0.819

n-Pentane 0.01 0.036

i-Pentane 0.01 0.034

Dimethyl-pentane - 0.008

Trimethyl-pentane - 0.003

n-Hexane - 0.008

n-Heptane - 0.027

Carbon dioxide 0.17 0.253

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YEMEN

YEMEN LNG


BALHAF LNG PLANT AND CAMP LOCATION MAP

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Aerial view of Balhaf site (Baseline Survey, 1997)

Aerial view of model Showing future LNG plant

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YEMEN LNG


AERIAL VIEW OF MODEL OF BALHAF LNG PLANT

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The Project will include the following principal components:

• Feed pipeline (Main Line described in Section 3.1);

• LNG plant and ancillary facilities;

• Jetty for LNG Carriers loading and shipping (Figure 3-8);

• MOF for tug boat mooring;

• Administrative facilities;

• An air strip;

• A construction camp;

• A permanent camp.

3.2.2. Construction, Installation and Commissioning

The LNG plant will require the construction of numerous facilities; the description of the main construction activities is described for the following operations:

• LNG process units, utilities and additional facilities (air strip, other);

• Jetty and Material Offloading Facility (MOF);

• Construction camp.

3.2.2.1. LNG Process Unit and Utilities

Construction will occur in several phases, including site preparation activities, earth moving and grading, establishment of temporary works, and construction and installation of process units and other facilities.

Site Preparation, Earth Moving, Grading and Temporary Works The site will be constructed in an undeveloped area with the exception of several uninhabited houses at Balhaf. Site preparation will result in demolition of the uninhabited houses as well as moving significant quantities of soil and rock. Blasting will also be required in areas where basalt rock must be removed to achieve projected grades. Process units, structures and utilities will be supported on concrete slabs. The concrete will be mixed at concrete batching plants on site and delivered to the foundations in trucks.

Earth moving will be performed with conventional equipment such as scrapers, graders, bulldozers, dump trucks, and backhoes.

Construction and Installation of Process Units Many of the process units and other components will be fabricated off-site at vendor’s shops and delivered to the site for installation. Other equipment such as piping, instruments and conduit will be partially assembled in sections prior to delivery to the site. Steel structures used to support the process unit piping and other components will be assembled on-site using prefabricated structural members supplied to the plant by off-site vendors. In addition to the process and utility units, administrative buildings, service building, warehouses, repair and maintenance shops will be constructed.

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Hydrostatic Testing Sea water will be used for hydrostatic testing of the tanks (approximately 145,000 m3 of water). The other equipment and lines may be hydrotested using desalinized water.

The hydrotest water will be transferred from one piece of equipment to another to minimize the quantity of water to be discharged after the test. The hydrostatic test water will be either re-used or be discharged to the sea after quality control through the water outfall. However, detailed hydrotest water handling is still under assessment.

3.2.2.2. Jetty and MOF Construction

Jetty The loading jetty head and jetty trestle will be constructed based on the international codes and standards (refer to section 2.3) already included in the Project Design. The jetty consists of the following construction activities (Figure 3-8):

• Piles construction;

• Driving and drilling (if on rock) for piles to support the deck and mooring appurtenances;

• Erection of steelwork frame and concrete slab deck;

• Laying of pipelines for loading;

• Installation of loading arms and support facilities (control room, etc.);

• Additional foundations or pile clusters at intervals along the jetty to protect it from lateral LNG carriers loads and provide mooring structures.

After foundation construction (piles), skeletal steel framework is erected and discontinuous reinforced concrete slabs installed. Steel work sections are fabricated off-site, transported to the site, lifted into place using cranes, and welded and bolted together. The pipelines will be assembled on-site using pre-fabricated pipe sections.

MOF The MOF facility will be constructed for material unloading only and will not function as a harbour. The wharf will be constructed as a concrete paved area, laid on top of rock fill and basalt blocks (from blasting and excavation). Construction will typically consist of the following general steps:

• Dredging (see below);

• Placement of rock fill, obtained partly from general site levelling;

• Driving of pile clusters to protect the MOF and provide mooring for off loading ships;

• Pouring in place of concrete slabs;

• Placement of precast concrete type Accropodes along the sea side of the wharf.

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Dredging Dredging requirement for the MOF construction will be minimized. It may include the removal and relocation of bottom sediments to increase the depth of the navigable water. Dredging will be carried out to a depth of 8.5 m below LAT (lowest astronomical tide) over a surface of roughly 10 000 m2 in the area of the main off-loading dock and in the tug wharf area. Approximate volume to be dredged is estimated about 5 000 m3 (to be confirmed during the detailed engineering phase).

Dredging will also be required for the trenches of the sea water intake pipe and of the water outfall pipe.

The material to be dredged is expected to be some marine sand on top of basalt rock, and therefore may require rock excavation means.

Dredged materials will be disposed in the sea in a dedicated area at depth of 150 m, selected to avoid possible future redeposit in sensitive zones. Further investigation is still in process for the exact location of the dredged material disposal area.

Sea water intake The construction activities associated with the installation of the sea water intake pipe include:

• Dredging of a trench (see above);

• Grab trimming of the trench bottom;

• Welding of pipe sections into 36 m long sections on the pipework crane barge;

• Installation of pipe sections and in-situ connection of pipe sections;

• Backfilling of trench with excavated and dredged materials;

• Placing of armoured rock on top of the backfill materials;

• Connection of the intake pipes into the onshore pumping pit structure;

• Shore protection reinstated over the completed pipelines.

Water outfall The construction activities associated with the water outfall are the same basic procedures as those outlined above for the sea water intake. The laying of the pipelines will commence at the onshore outfall chamber and the water discharge outfall will extend 680 m from shore and 20 m depth into the Gulf of Aden.

3.2.2.3. Construction Camp

The total workforce required for construction of the LNG plant and associated facilities will vary depending on the construction phase. The first pioneer’s camp of 100 people will grow to a Construction Camp with an estimated peak of 7,000 to 10,000 workers. The duration of construction is estimated to be approximately 32 months. The approximate surface of the construction camp and construction facility area will be approximately 800, 000 m2.

During construction, trucks will transport concrete, steelwork, piping and other materials to the site.

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The construction camp will be arranged to satisfy adequate sanitary and waste treatment. Utilities will be provided by temporary equipments, such as:

• Diesel engine generators for electrical power supply;

• Temporary desalination units for potable water supply and fire water demand;

• Sewage effluent from the construction camp will be treated through a treatment plant using activated sludge with a capacity of 2000 m3/d and the treated wastewater may be reused for dust control and garden watering. A part of these equipments will be left and retained to serve for disposal of excess treated water from the permanent sewage treatment unit (see 3.2.3.5)

• Domestic waste incinerator and landfill;

• Telecommunications;

• Fire and gas detection.

3.2.3. Process Operations

The LNG plant will be designed as two parallel treatment trains operating as an average 335 days per year. Figure 3-9 presents an overall site plot plan and Figure 3-10 presents a block diagram of the LNG treatment train. The treatment process includes the following principal process steps:

Reception facilities: receive the gas feed from the pipeline, ensure a coarse filtration before distribution and control its pressure at the LNG trains inlet.

Pretreatment of acid gas removal (carbon dioxide, less than 0.6%): absorption using activated methyldiethanol amine (MDEA) as the sour gas passes through the amine column, carbonates and bicarbonates are formed.

Water wash: removal of residual amines.

Drying: reduction of water content to less than 1 ppm for cryogenic liquefaction.

Mercury removal with sulfur-impregnated carbon bed unit: this unit is designed for the removal of 50 nanograms/Nm3 of mercury to less than 10 nanograms/Nm3; the bed will be removed and replaced every few years, as required. However, no mercury is expected.

Feed gas precooling is achieved through propane evaporators with a scub column, to enable heavies/aromatics removal and liquid separation to extract ethane and propane required for refrigerant make-up. The heavy products are disposed of as liquid fuel in the steam boilers; each fractionation unit (one per train) comprises three distillation columns (deethaniser, depropaniser, debutaniser) and a re-injection/recycle system into LNG.

Liquefaction of products: the liquefaction unit will be based on the APCI process, the most widely used, which will supply the Main Cryogenic Heat Exchangers (MCHE);

Refrigeration: it is based on the use of two gas turbines drivers for each train. The refrigeration system consists of two refrigerant loops:

• The propane refrigeration loop based on a three pressure levels system;

• Mixed Refrigerant (MR) compression loop is achieved in a three casing design: the Low Pressure (LP) MR compressor, the Medium Pressure (MP) MR compressor and the High Pressure (HP) MR compressor.

Title

Location

Client

YEMEN

YEMEN LNG


BALHAF LNG PLANT OVERALL SITE PLOT PLAN

70 m 60 m 50 m 40 m 30 m

60 m

50 m

40 m

30 m

20 m

10 m

5 m

70 m

10 m

20 m

14°00'00" N

1549000 N

1548000 N

194

00

0E

48°1

0'0

0"

E

195

00

0E

1 547 000 N

48°1

1'0

0"

E

196

00

0E

1550000 N

0

SCALE

100 200 300 400 500 m

N

NORT

H

150100

50

CALM362

SUP TO 9 BFTS

7 & 8 BFTS5 & 6 BFTS3 & 4 BFTS1 & 2 BFTS

CIRCLES NUMBERS OF OBSERVATIONS PER THOUSAND(NOT TO SCALE)

25.0 m

12.5 m

D=

750M

UTILITIES

EFFLUENTTREATMENT

ADMINISTRATIONBUILDING

TRAIN 2

TRAIN 1

WATEROUTFALL

CAP RAS AL ASID

SANDBEACH

TURNINGCIRCLE FOR

GENERAL CARGO

TURNINGBASIN

LNG CARRIER

LIQUIDSBURNER

PIP

ELIN

EFR

OM

KPU

PLANT FENCE

BASALTROCK

LAGOON

BEACH

FLATPLA

IN

GULF OF ADEN

LOWSAND

DUNES

BOIL OFF

ACCESS ROAD

L N GPLANT

TURNINGBASIN

LNG JETTY

LNGSTORAGE

SEA WATERINTAKE

WORKSHOPWAREHOUSE

TO WATEROUTFALL

PO

WE

RG

EN

.

FIRE TRAININGAREA

SEA WATERPUMP

ENTRANCE

WHARF

RECEIVINGAREA

FLARE

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Date

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MOF

Title

Location

Client

YEMEN

YEMEN LNG


LNG TREATMENT TRAINBLOCK FLOW DIAGRAM

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Storage: finished LNG product will be stored in two cryogenic storage tanks (140,000 m3 each) at a temperature of -162°C; these are above ground full containment tanks with a concrete shell and free standing inner tank.

LNG loading: into LNG carriers moored 900 m from shore via a pipe jetty; re-circulation, vapour return and boil-off lines will be provided.

The cryogenic storage Tanks and LNG Terminal will be built following Standards and Rules from BSI, API,ASTM,AWS (American Welding Society),DOT, AISI, FIP, ASME and SIGTTO (Society of International Gas Tankers and Terminals Operators).

3.2.3.1. Flare systems

Relief valve gases and vent gases will be collected and sent to the flare system with normally no flow except purging of the headers for safety reasons. The flare system to be installed is described in the table below. Pilot gas isolation valving and the ignition panel will be located far from the flares; the system will be maintained in positive pressure to prevent ingress of air and the resulting risk of explosion.

The loading LNG system will be connected to a dedicated marine flare (normally no flow).

Table 3-3 Flare systems

Flare Design flow (kg/hr)

Estimated flow (kg/hr)

1 marine flare, 96,806 40,081

1 wet flare (continuous) 650,000 243,000

1 high pressure dry flare (discontinuous)

1,840,000 1,000,000

1 low pressure dry flare 980,000 260,000

1 spare flare - backup for low pressure dry flare or wet flare

1,840,000 not applicable

3.2.3.2. Liquid Burners and Tank Vents

Two liquid burners will be provided for emergency disposal of waste oils, oily liquids, and start-up “off-specs” product:

• One wet liquid burner – design flow rate of 12,000 kg/h, water content: 5 to 100%;

• One dry liquid burner – design flow rate of 160,000 kg/h (at start-up).

However, waste lube oil and oily liquid waste will be burnt in an incinerator to make up the calorific values of wet domestic wastes.

Most of the major tank vents will be sent to flares. Some miscellaneous tank vents not included in the flare system will generate minor emissions. This includes 2 x 150 m3 diesel fuel tanks for the emergency generator.

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It should be noted that the tank for the liquid fuel system used to feed the steam boilers will be vented to the flare system.

3.2.3.3. Water Intake and Water Systems Seawater Intake

Sea water will be pumped for different processes of the plant. Water consumption by process can be summarized as follow:

Table 3-4 Water consumptions Process Water consumption

m3/h

Process trains 60,000 primarily for single pass cooling-off

Boiler plant 7

Electro-chlorination 130 (described below)

Desalination plant 1,200 (described below)

Screened marine life debris will be collected in a removable basket from the rotating band screen.

Electrochlorination

Sodium hypochlorite will be produced electrolytically for sanitary use (50 g/h as Cl2) and for the cooling water system (190 kg/h as Cl2).

Desalination and Potable Water System

The flow diagram of the desalination plant is shown on Figure 3-11. Sea water will be pumped for treatment in desalinization units to produce fresh water. Desalinization will be conducted using a thermo-compression unit. The unit itself will be heated by steam.

The units will produce a total of 58 t/h of desalinated water and discharge 550 t/h of mixture of brine and sea water to the sea. Prior to discharge, this brine will be mixed with effluent from other treatment processes as well as cooling water.

The following additives will be incorporated into the process:

• Dechlorination agent - added to raw sea water prior to the thermo compression unit;

• Anti-scale and anti-foam agents - added to treated water;

• Acid cleaning - for periodic cleaning of the unit.

Treated water will flow into two separate storage systems, each consisting of two storage tanks:

Title

Location

Client

YEMEN

YEMEN LNG


DESALINATION PLANT

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• Potable water tanks (sodium bicarbonate and calcium chloride are added): 38.6 t/h broken down as follows:

- 35 t/h is pretreated for Plant and Camp potable use (chlorination, with hypochlorite generated by the electro-chlorination unit);

- 2.5 t/h service water;

- 1.1 t/h fire water (biocide and corrosion inhibitor added).

• Other tanks:

- 22 m3/h boiler feed;

- 1 m3/h periodic turbine cleaning water and amine wash unit make up, pretreated using activated carbon and mixed bed ion exchange.

3.2.3.4. Sewer and Wastewater Collection Systems

In order to achieve an economical, functional and reliable drainage and primary water treatment facility for the LNG complex, incorporating proper segregation and controlled discharge of effluents and cooling water, the following systems have been developed:

• Non-contaminated sewer system (NW);

• Oily water sewer system (OW);

• Chemical sewer system (CW);

• Amine drainage system (DA);

• Domestic sewer system (DW);

• Brine system (desalinization);

• Cooling water discharge system;

• Peripheral rain water ditches.

A simplified diagram of the water discharges is shown on Figure 3-12.

At each outlet of the sewer and wastewater treatment, a sampling facility and volumetric device will be installed to ensure that the effluent quality is met before discharge to the sea through the outfall.

Non-Contaminated Sewer System (NW) This system will consist of open ditches and will collect:

• Rain water run off from all plant areas (except contained areas);

• Fire fighting water run off from all plant areas (except contained areas);

• Non-contaminated process waste effluent from process and utilities areas.

The non-contaminated sewer with sealed inlets will be discharged by gravity into the sea via an observation pit. However, for process areas where liquid hydrocarbon leaks could occur, the areas will be drained separately and connected to independent impoundment basins.

The system is designed to handle flows of up to 1,000 m3/hour, but under normal conditions, flows are expected to be between 0 and 100 m3/hour.

Title

Location

Client

YEMEN

YEMEN LNG


LNG PLANT SIMPLIFIED WATER DISCHARGE FLOW DIAGRAM

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February 2006

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43683552 Figure 3-12

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60 000 m³/h

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Oily Water Sewer System (OW) This system will collect wastewater which is continuously oil contaminated or accidentally contaminated through spillage during normal operations. This includes the following:

• Purges and drains from equipment in process and utilities areas;

• Lubricating oil spillage from areas such as pump plinths;

• Accidental spillage associated with specific equipment (contained areas);

• Accidental spillage from the diesel discharge station;

• The liquid fuel tanks retention basin (in case of spillage);

• This system will also collect rainwater runoff, firewater or washdown from contained areas in process and utilities areas.

The collected oily wastewater will be routed via a weir box to the oily Corrugated Plate Interceptor (CPI) separator. It will consist of gravity separation using a corrugated plate interceptor. Oily surface layer will flow from the CPI to a holding basin then be pumped periodically and will be burned in an incinerator. Flows are not expected to exceed 2 tons/hr. Sludge will be collected in a sump for periodic removal by vacuum truck for proper disposal.

Collected water (prior to treatment) is expected in normal conditions to contain a maximum of 100 mg/l of suspended solids (maximum of 500 mg/l of oil), with an expected flow of 10 m3/h (possible increase to 60 m3/h in the event of a fire). If the oily water flow exceeds 15 m3/h, the additional flow will spill over the weir into a holding basin, which allows water to be inspected, tested and treated further, if required, prior to discharge to the sea.

Treated effluents from the oily sewer system will be mixed with treated effluent from the chemical and domestic sewer systems and with cooling water, prior to being discharged to the sea in accordance with the appropriate water quality discharge requirements (see Section 3.2.5.2).

Chemical Sewer Systems (CW) Chemical effluents will be collected from:

• Acid cleaning effluents from desalination and electro-chlorination plants;

• Chemicals from:

- specific equipment drains in process and utilities areas;

- rainwater run off, firewater and washdown in contained areas around specific equipment in process and utilities areas;

- laboratory waste.

Average flow rate is expected to be 0.5 m3/h (possible peaks of 4 m3/h). The collected effluent will flow into one of two neutralization sumps. Neutralization will be conducted automatically using caustic soda and/or hydrochloric acid.

Treated effluents from the chemical sewer system will be mixed with treated effluent from the oily and domestic sewer systems and with cooling water prior to being discharged to the sea in accordance with the appropriate water quality discharge requirements (see Section 2.4).

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Amine Drainage System (DA) The amine drainage system will consist of the following:

• Amine contaminated water system (DA) from amine plant equipment will be drained by closed pressurized drain system to the buried amine sump drum;

• Rainwater runoff, firewater and washdown in the contained area of the amine unit will be drained to a sump within the contained area and emptied by vacuum truck for proper disposal;

• Rainwater runoff, firewater and washdown to paved areas in the amine unit area will be collected in an independent drainage channel and connected by sealed inlet to the oily water sewer system.

Average flow rate is expected to be 12 m3/day.

Domestic Sewer System (DW) The domestic sewer system will receive all domestic wastewater from the plant buildings and the permanent operation camp, including sanitary and kitchen wastes after degreasing which will be directed to the wastewater treatment plant (Section 3.2.3.5).

Treated effluents from the domestic sewer system will be mixed with treated effluent from the oily and chemical sewer systems and with cooling water prior to being discharged to the sea in accordance with the appropriate water quality discharge requirements (see Section 2.4).

Brine Systems The concentrated brine discharge system from the sea water desalination plant will be pumped via a dedicated pipe line to the sea water outfall channel.

Average flow rate is expected to be 550 m3/h.

Cooling Water Discharge The outfall is designed for an average flow rate of cooling water discharge of 60,000 m3/h.

Peripheral Rain Water Ditches Peripheral ditches installed on the east and south sides of the plant site will collect clean surface water from the surrounding hills and discharge this water to existing wadi(s) or to the sea. These ditches, located inside of the perimeter security fence, may, in some cases, also collect non-contaminated water from unconstructed areas, roads and building roofs.

3.2.3.5. Wastewater Treatment Plant

Domestic sewer wastes will be treated using an aerobic biological treatment plant, comprised of buffer tanks with aeration system, activated sludge reactor, clarifier, and chlorination dosing system. The sludge will be dried and stabilized for appropriate disposal. Treated effluent will be mixed with treated wastewater from the chemical and oily sewer as well as cooling water prior to being discharged to the sea.

The design flow rate is expected to be 333 m3/h on average for the temporary camp (during construction) and 30 m3/h average for permanent camp (during operation phase).

The sanitary treatment plant will meet the following quality standards for discharge (both normal and peak flows):

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Table 3-5 Sanitary treatment plant standards for discharge Parameter Concentration

BOD 20 mg/l

Total Suspended Solids 30 mg/l

Residual chlorine < 0.1 mg/l

pH 6 - 9

3.2.3.6. Utilities

Fuel gas system A fuel gas system will be provided to condition the fuel gas required by the gas turbines (process and power generation) and the boilers.

Power generation Power demand for the complete facilities is totally produced by onsite power generation. There is neither public nor other electrical tie in available. The power generation facility includes 4 gas turbine generators, located in the Utility Area, producing 27 MW each (11,000 V, 3 phase, 50 Hz power). Parallel gas turbine trains will be installed. Average gas flow rate to the system (total for all trains is expected to be approximately 16 t/h.

Gas turbines for power generation are equipped with reduced NOx emission burners.

Emergency power generation and black start system consist of two diesel generators producing 2,500 kW (6.6 kV, 3 phases, 50 Hz power).

Steam generation Three parallel boilers will be installed to provide process steam to the LNG plant (at least one for maintenance, two remaining in full production plus 100% utilities load). Each boiler will run at 50 to 66% capacity in normal operation (fed with liquid fuel condensate and/or fuel gas – dual system). The characteristics are being subject to final design.

Compressors Four gas turbines (two per train) will be installed for providing power directly to high consumption process units, as follows:

• Propane compressors: 84 MW (ISO) turbine from a maximum fuel demand of approximately 260 MW (one per train);

• MR compressors: 84 MW (ISO) turbine from a maximum fuel demand of approximately 260 MW (one per train).

Regeneration furnace One regeneration gas heater will be installed per train. The design duty of these two heaters is 8.3 MW.

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Cooling medium The seawater cooling system will be a once-through intake / outfall arrangement, and will be treated using electrochlorination to prevent marine growth in the circuit. The overall rise temperature between inlet and outlet of the seawater circuit shall be 10°C maximum.

Other utilities The following supporting services will be available on the LNG plant:

• Diesel fuel will be supplied by truck or barges from an outside source to diesel fuel storage tanks.

• Compressed air system for instrument air, plant service air and feed air supply to the nitrogen plant. The system will include 3 x 50% electric driven air compressors, wet air receivers, instrument air dryers and receivers.

• Nitrogen generation system: two cryogenic air separation units.

• Fire fighting water system: fixed equipments (fire hydrants, elevated monitors, water spray systems, powder units and foam generators) and mobile equipments (hand held extinguishers, water monitors and wheeled powder units) will be available, using treated fresh water or sea water. A fire brigade with its mobile equipment: fire trucks, powder and foam trucks, ladders and hoses will also be available.

• Refrigerant storage (ethane and propane) will be sized to hold approximately twice of one LNG train.

• Chemicals will be set on areas provided with retention.

Control The LNG plant at Balhaf will be monitored and controlled from an Integrated Plant Control System (IPCS): the control equipment intelligence shall be distributed into instrument technical rooms, located close to the process areas they serve, while the operator interface shall be from Distributed Control System (DCS) operator consoles installed in the CCR and located in a “safe” area.

The CCR will include the terminal station of the SCADA of the Main pipeline (see Section 3.1.3.2).

3.2.3.7. Logistics

All support buildings and facilities necessary for plant administration, operation, maintenance, safety and training will be provided. A permanent camp will be located adjacent to the plant facilities to house personnel required for normal conduct of operations.

3.2.3.8. Additional Facilities

Jetty The jetty will serve as the main LNG loading point to LNG carriers ranging from 70,000 to 205,000 m3. The jetty will be equipped with mooring appurtenances (dolphins), loading arms that connect the LNG carrier manifolds to pipelines on the jetty, strainers, circulation pumps, drain pumps and a drain drum. At Balhaf, the jetty will extend westward from the LNG plant approximately 900 m into the Gulf of Aden.

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The LNG carriers will be subject to the MARPOL convention. During their approach and mooring at the Balhaf jetty, no bunkering, refuelling or ballasting will be carried out. ISPS (International Ship and Port Facility Security) code (IMO) will be applied.

MOF (Material Offloading Facility) The MOF, located approximately 300 m south of the jetty, will be used for general supply off-loading and mooring of tugs and will not function as a harbour. The area will include lighted beacons, a material off-loading dock and a tug wharf.

Air strip An air strip will be constructed in the area approximately 3 km to the north-west of the LNG plant. The air strip will consist of a single runway approximately 950 m long and 45 m wide. Access will be from the plant access road via a new access road. The airstrip will be operated on day-time only for domestic flights and will be compliant with International Civil Aviation Organisation Exhibit 14 vol. 1. It will be used for personnel transportation during rotation and for emergency situations (MEDEVACs).

Camps During operation a permanent camp will be constructed for 700 to 1,000 people. A refurbished part of the construction camp will house 1,000 persons every 18 months for maintenance periods. The location of the camps is shown on Figure 3-5.

All camp facilities such as potable water system and sewage treatment will be designed for these peak periods. The permanent camp will have a waste incinerator fuelled by natural gas for the combustion of domestic solid waste.

3.2.4. Decommissioning

At the end of the lifetime of the Project (25 years), the LNG plant will be decommissioned. Above ground structures of the LNG plant will be dismantled and removed. Specific studies will be conducted for the plan decommissioning.

3.2.5. Summary of Wastes and Emissions

Wastes and emissions generated by this Project include atmospheric emissions, construction wastes, wastewater, hazardous wastes and non-hazardous wastes. These emissions and waste streams are quantified, during construction and operations, in the following sub-sections.

3.2.5.1. Atmospheric Emissions

Pipeline construction atmospheric emissions Combustion contaminants from heavy duty vehicles are estimated based on the anticipated level of vehicle activity. For pipeline sections constructed in open areas consisting of uncovered ground and dirt roads (rural spread), the rate of progress can move rapidly. Rural spreads generally use a 22 m construction zone. Construction equipment in a spread would include machinery such as trenchers, welding machines, tracked side booms and support vehicles. Based on emissions for the installation of a pipeline (Aspen Environmental Group, 1996) constructed in open areas, the table below presents estimated vehicle emissions as a function of distance. These values are based on a semi-arid region and a typical depth of 1.2 meters for the pipeline trench. Estimated construction emissions using these factors are also presented in this table:

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AIR EMISSION FROM VEHICLES DURING PIPELINE CONSTRUCTION

Pollutant : NOx Sox CO VOC

Emission Factor (kg/km) 288 11 779 55

Emissions (kg) 92,220 3,625 249,299 17,782

Pipeline operation atmospheric emissions. The pipeline operation does not produce atmospheric emissions since compression is installed and already operating for gas reinjection in the Upstream Fields. There is no intermediate compressor station along the pipeline, thus there is not atmospheric emission during routine operation.

LNG plant atmospheric emissions The emissions generated during construction of the LNG plant have not been quantified.

Two modes of operation have been identified for the Yemen LNG Project:

• Normal operations for which fuel gas is available for both electrical generation and turbo compression, assumed to be 345 days per year;

• Shutdown mode (processes shutdowns or maintenance operations), during which the field will run with reduced power consumption (diesel) and without gas production; it will occur about 20 days per year.

The first train of the plant is scheduled to start in December 2008, and the second train in March 2009. Then the consumptions are defined “pro rata temporis”, assuming one month functioning in 2008 (train 1), 22 months functioning in 2009 (12 for train 1 and 10 for train 2).

The atmospheric emission sources expected from the YLNG Project during normal operations are discussed below.

Fuel gas combustion

The fuel gas consumption is defined as follows:

• Compression 31.48 t/h per train;

• Regeneration heater 0.764 t/h per train ;

• Steam generation: 4.1 t/h – 2 trains;

• Power generation: 21.6 t/h – 2 trains.

The trains are assumed to run at 60% capacity during the first month, due to start-up period.

Diesel consumption

In normal operations, the diesel consumption is reduced to the regular emergency safety equipment testing and other miscellaneous equipment, and is estimated to be approximately 500 t/y.

During the shutdown mode, there is no hydrocarbon production. Essential power is generated from diesel and is assumed to be equivalent to the nominal power of the Emergency Diesel Generator, i.e. 2 500 kW (30% efficiency).

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Flaring

No flaring is expected on Yemen LNG plant, except for safety reasons. Two flares are planned for the Balhaf plant with the following characteristics:

• Marine flare: Pilot gas: 240 kg/h or 2102.4 t/y

Purge gas: 450 kg/h or 3942 t/y

Flared gas: 50 t/h during 2 hours (only when the boil off compressor is down)

• Main flare: Pilot gas: 240 kg/h or 2102.4 t/y

Purge gas: 450 kg/h or 3942 t/y

Compressor seal gas: 300 kg/d or 109.5 t/y during 2 hours

Two depressurizations are assumed of 500 tons per train per normal operating year. Additional depressurizations are expected during the first two years of operation.

Venting

The amine regeneration unit will be the only one unit which will be vented. Approximately 23.09 MSm3/y of acid gas will be vented in normal operations.

Fugitive emissions

The two gas production facilities and the four compression units of the Yemen LNG plant, LNG loading/unloading facilities, PSVs, atmospheric pressure installations are considered to estimate the fugitive emissions.

Logistics and transport

Two tug boats are assumed to be permanently in operation in the MOF, each consuming 5 t/d of diesel.

As no precise information is available at this stage of the Project, atmospheric emissions are not estimated here for the construction phase and the decommissioning of the plant.

The following Tables 3-6 and 3-7 summarize the input information for the GHG emissions calculation for the operation of the plant.

Table 3-6 Consumptions during normal operations

Year Fuel gas (MSm3/y)

Diesel (kton/y)

Flaring (MSm3/y)

Acid gas vent

(MSm3/y)

Fugitive emissions (Gas nb*)

Fugitive emissions (Comp nb*)

Logistics (kton/y)

2008 27.1 0.02 4.1 1.0 2 4 0.2

2009 974.0 0.46 7.1 21.2 2 4 3.3

2010 to

2034 1082.3 0.50 19.6 23.1 2 4 3.7

*: number of processing facilities

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Table 3-7 Consumptions during shutdowns

Year Diesel (kton/y)

Logistics (kton/y)

2008 0.3 0.2

2009 5.7 3.3

2010 to 2034 6.3 3.7

GHG emissions calculation The Green House Gases (GHG) emissions from the LNG plant project can be compared with similar projects, in terms of emission intensities. Quantities from each source are estimated using the methodology adopted by International Association of Oil and Gas Producers (OGP). The emission estimation comprises multiplying the mass of hydrocarbon (diesel, gas) combusted by corresponding emission factors of each compound. The compounds that are released into the atmosphere include:

• Carbon dioxide (CO2);

• Carbon monoxide (CO);

• Nitrous oxide (N2O);

• Methane (CH4);

• Sulfur dioxide (SO2);

• Volatile Organic Compounds (VOC);

• Nitrogen oxides (NOx).

The following tables 3-8 and 3-9 summarize the GHG emissions, including 345 d/y of normal operations and 20 d/y of shutdowns, compared to the Net Utilized Production of the plant (NUP, it correspond s to the sum of exported energy and fuel gas used by the plant).

Table 3-8 Estimated GHG emissions

Year NUP (Mboe/y)

CO2 (kton/y)

CO (kton/y)

N2O (kton/y)

CH4 (kton/y)

GHG (kton/y) SO2

(kton/y) VOC

(kton/y) NOx

(kton/y)

2008 1.72 61.3 0.08 0.00 0.34 69.9 0.00 0.05 0.14

2009 61.78 1 950.1 2.01 0.15 2.31 2 048.4 0.03 0.40 4.74

2010 to

2034 68.64 2 146.5 2.17 0.17 2.39 2 251.5 0.03 0.42 5.25

Total 1 780 55 673 56.23 4.31 62 58 406 0.8 11.0 136.0

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The GHG emission intensity value is obtained dividing the total GHG emissions (in kilo tons per year) by the total energy production i.e. the gas production expressed in million barrels of oil equivalent per year. This calculation leads to the following estimations:

Table 3-9 Estimated GHG emissions intensities

Year CO2 (Kt/Mboe)

CO (Kt/Mboe)

N2O (Kt/Mboe)

CH4 (Kt/Mboe)

GHG (Kt/Mboe) SO2

(Kt/Mboe) VOC

(Kt/Mboe) NOx

(Kt/Mboe)

2008 35.72 0.04 0.00 0.20 40.72 0.00 0.03 0.08

2009 31.57 0.03 0.00 0.04 33.16 0.00 0.01 0.08

2010 to

2034 31.27 0.03 0.00 0.03 32.80 0.00 0.01 0.08

The total GHG emissions during the LNG plant project are 58 406 kt CO2 eq., which corresponds to an average emission intensity of 32.8 kt/Mboe. This intensity is calculated with the Net Utilised Production which includes the fuel gas required to run the plant.

The use of only the exported energy (total of 1 700 Mboe) leads to an average emission intensity of 34.3 kt/Mboe.

3.2.5.2. Liquid Emissions Non-contaminated sewer: it will be discharged by gravity into the sea via an observation pit with an expected flow between 0 and 100 m3/h.

Wastewater flows: The following wastewater flows will be combined in a common outfall pipe with a discharge to the ocean, 680 m from shore at 20 m depth:

Table 3-10 Wastewater flows

Source Design

Average Flow

(m3/h)

Design Peak Flow

(m3/h)

Treated oily wastewater 10 60

Treated chemical wastewater

0.5 4

Treated sanitary wastewater

11.7 16.7

Desalination discharge (brine water)

550 -

Amine drain effluent 0.5 1

Cooling water from utility 310 342

Cooling water 60,000 65,000

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The combined discharge will meet quality requirements adopted for the YLNG Project (see Section 2.4).

Inhibited water from pipelines and plant hydro-testing: The pipeline and plant equipments hydro-test water contains chemicals necessary to prevent corrosion and/or biological growth. This water is flushed out of equipments during pre-commissioning and is discharged to the sea after the test. The water hydrostatic test water from the plant will be discharged to sea after meeting the criteria and the hydrostatic test water from the pipelines may be discharged to lined evaporation ponds located along the pipeline route. However, the method of handling hydrotest water used for commissioning is still under assessment.

3.2.5.3. Wastes

During the construction period, the following volumes are expected to be disposed of:

• Burnable wastes: max. 130 t/month;

• Unburnable wastes: max. 150 t/month;

• Slop oils: max. 20 t/month;

• Medical wastes: max. 0.2 t/month.

Anticipated domestic waste generated per person per day is maximum 1.2 kg.

A Waste Management Program will be developed for this Project setting out the ground rules conforming with the local regulations and the YLNG specifications as applicable for waste disposal and waste management (see Section 7.0).

Domestic solid wastes that cannot be recycled or reused will be incinerated in a waste incinerator located in proximity to the permanent camp.

Wastes generated by the LNG facility are presented in the following Table 3-11.

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Table 3-11 LNG plant waste streams Waste Frequency of Generation

Kitchen waste - food waste, packaging Daily

Office waste - paper etc. Daily

Molecular sieves Intermittent - maintenance and shut-downs only every 3-4 years

Mercury removal catalyst None expected - maintenance and shut-downs only every 3-4 years

Activated carbon Intermittent - at 3-6 month intervals

Gas filters Intermittent - 1 week

Liquid filters for amine Intermittent - at 3-6 month intervals

Boiler cleaning wastes Intermittent - maintenance and shut-downs only every 3-4 years

Heat exchanger wastes Intermittent - maintenance and shut-downs only every 3-4 years

Digested sanitary sewage sludge Intermittent - at 1-2 month intervals

Inorganic sludge from ETP Intermittent - at 6 month intervals

Oily sludge from ETP Intermittent - at 6 month intervals

Oily waste - rags, paper Small amounts daily

Clinical waste Small amounts weekly

Air intake filters from gas turbines Intermittent - depending on weather conditions

Laboratory wastes - acids, alkalis, solvents Small amounts daily

Waste oils - equipment and vehicle maintenance

Small amounts daily - more during shutdowns

Transformer oils Intermittent - maintenance and shut-downs only every 3-4 years

Scrap metal Intermittent

Waste paints and paint tins Intermittent

Waste concrete, rubble, brick Intermittent

Gardening wastes Intermittent

Spent mercury absorbent None expected

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3.2.5.4. Summary of Emissions and Waste

The following Table provides a summary of the LNG plant emissions and wastes.

Table 3-12 Summary of Emissions and Wastes

Waste Category Source Basis for estimation of quantities /

comments Estimated waste

quantity

Atmospheric emissions

LNG plant production operations

Gas and diesel combustion, flaring, venting, fugitive emissions.

58 406 tonnes of equivalent CO2 per

year

Pipelines Construction

Generated by approximately 300 people living in the pipeline construction camps. ~ 4,000 m3/month

LNG plant Construction

Generated by approximately 7,000 people living in the LNG plant construction camp. ~ 84,000 m3/month

LNG plant permanent camp

Generated by approximately 1,000 people living in the LNG plant permanent camp ~ 12,000 m3/month


Generated by processes. ~ 61,000 m3/h

Construction: Hydro-testing treated water from pipelines

For pressure testing and chemical treatment of the pipelines.

~ 40,000 m3(to be

confirmed)

Liquid emissions

Construction: Hydro-testing treated water from LNG plant equipments

For pressure testing and chemical treatment of the LNG plant equipments. ~ 145,000 m3

Pipelines Construction

Chemical waste (batteries, used solvents, transformers…), garbage and inert solid waste

~ 300 t/month

LNG plant Construction


~ 300 t/month Solid wastes emissions



~ 0.5 m3/d per person

3.2.6. Indicative Schedule of the LNG Project

The indicative construction schedules for the pipeline and of the Balhaf LNG plant are shown in Figures 3-13 and 3-14.

Title

Location

Client

YEMEN

YEMEN LNG


MAIN AND TRANSFER LINES - PROJECT SCHEDULE BAR CHART

App’d

Date

Drawn

Scale

Project No.

Ref.

No barscale

LYO

February 2006

JLL

43683552 Figure 3-13

Format

A4

Title

Location

Client

YEMEN

YEMEN LNG


OVERALL PROJECT BAR CHART SCHEDULE

App’d

Date

Drawn

Scale

Project No.

Ref.

No barscale

LYO

February 2006

JLL

43683552 Figure 3-14

Format

A3

A ESIA Yemen Section 3 Revision 1

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