Eia lucky electric power company 660 mw coal power project

Final Report

660 MW COAL FIRED POWER PLANT

Environmental Impact Assessment (EIA) Study

Disclaimer:

This report has Attorney – Client Privilege. EMC Pakistan Pvt. Ltd has prepared this report in accordance

with the instructions of (Project Proponent) Lucky Electric Power Company Limited for their sole and

specific use. Any other person(s) who use any information contained herein do so at their own risk. This

report cannot be used in the court of law for any negotiation or standardization.

© EMC Pakistan Pvt. Ltd. 2015

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Environmental Impact Assessment for 660 MW Coal Power Project (Final Report)

EXECUTIVE SUMMARY

Pakistan faces a number of critical challenges in energy sector such as energy and power resource

deficit, power shortages, and a greater dependency on imported oil to meet the energy demand-

supply gap. The demand for electricity currently outstrips supply. Inadequate generation, transmission,

and distribution, as well as the inefficient use of electricity, lead to shortages of 12-20 hours, particularly

at peak times. Realizing these challenges, the governments of Sindh & Pakistan are focusing on the

huge potential of developing indigenous coal resources on fast-track basis and put coal based power

as a major portion in overall energy mix.

The National Energy Policy 2013 requires development of strategy to i) ensure the generation of

inexpensive and affordable electricity for domestic, commercial, and industrial use by using indigenous

resources such as coal (Thar coal) and hydel power, ii) address the key challenges of the power sector

in order to provide much needed relief to the citizens of Pakistan, and iii) shift Pakistan’s energy mix

towards cheaper fuel and conservation of gas for power.

In order to contribute towards meeting Pakistan’s growing electricity demand, Lucky Electric Power

Company Limited (LEPCL) proposes constructing a 1 x 660 MW coal based power station near Port

Qasim Karachi. LEPCL has acquired 250 acres of land from the Sindh Board of Revenue for the

establishment of the proposed power plant. Coal for the power plant will be imported from Indonesia,

South Africa, and/or Australia. The preferred option for imported coal is the under-construction

Pakistan International Bulk Terminal (PIBT) at Port Qasim. The terminal is expected to be operational

by 2016.

Figure EX-1: Location of LECPP Site

This Environmental Impact Assessment (EIA) serves as useful tool in prediction of potential impacts on

the surrounding environment due to developmental project. It will help the project proponent, impact

assessment authorities, regulatory agencies and other stakeholders in understanding the project and

mitigation measures, environmental impact and establishing emission requirements and other

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measures early in the project cycle. This report describes the project location, baseline environmental

scenario, potential impacts of the project on the environment and proposed measures for effective

environment management (EMaP & EMoP) during the project cycle.

The basic design parameters for these are listed in Table EX-1:

Table EX-1: Basic Design Parameters of LECPP

Parameter Value

Thermal Cycle Information - Gross Capacity 660 MW (approximately) at annual average conditions with turbine max. continuous rating (TMCR)

Thermal Cycle Information - Net Capacity 607.2 MW (target) at annual average conditions TMCR

Net Plant Heat Rate 2,224 kcal/kWh at annual average conditions TMCR

Main Steam Flow 1,993,500 kg/h, 4,394,918 lb/hr

Main Steam Pressure 242 bar, 3,509 psi

Main Steam Temperature 566°C, 1,050 °F

Hot Reheat Flow 1,623,420 kg/h, 3,597,031 lb/hr

Hot Reheat Pressure 42.63 bar, 618 psi

Hot Reheat Temperature 566°C, 1,050°F

Cold Reheat Flow 1,623,420 kg/h, 3,597,031 lb/hr

Cold Reheat Pressure 47.36 bar, 686.7 psi

Cold Reheat Temperature 325.8°C, 618°F

Feedwater Pressure 291.1 bar, 4,221 psi at pump discharge

Coal Burn Rate 269 t/h for the design coal, 100% load

Water Flow to the Plant 82,000 m3/h

Circulating Water Flow 78,000 m3/h to condenser and closed cooling

Circulating Water Temperature Rise in Condenser

8.5°C, 15.3°F

Circulating Water Temperature Rise Total Condenser and Seawater FGD

9°C at 34% scrubbing

Sea Water Flow to Desalination System 600 m3/h

Waste Water Flow 12 m3/h

Potable Water Supply to Plant & Colony 15 m3/h

The boiler is a supercritical, balanced draft, outdoor, coal-fired design, and Low NOx burner, pulverized

coal with front or rear or tilting tangential firing design suitable for operation at the super-critical steam

conditions. The boiler will be equipped with regenerative type air heaters, 2x50% adjustable moving-

blade axial-flow PA fans for FD and 2x50% adjustable stationary-blade axial-flow fans for ID. The design

of the air heaters, fans and associated boiler auxiliaries will be provided with adequate margins to avoid

limiting the capability of the Plant to achieve full rated output throughout the design life of the Facility.

Steam soot blowers will be provided to support the cleaning operation of the boiler to allow continuous

full load operation with the worst case fuel characteristics. The furnace will be equipped with wall soot

blowers and long retractable soot blowers for the superheater, reheater and economizer areas. The

air heaters will have fixed lance type soot blower units. The boiler maximum continuous rating will be

designed with the inclusion of auxiliary steam flow. The boiler will have a suitable number of duty

medium speed coal mill groups which allows the firing of performance coal at BMCR conditions, with

one spare mill group acts as standby. The boiler exit flue gas will pass through an electrostatic

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precipitator and the SWFGD plant prior to entry into the stack, but the electrostatic precipitator and

SWFGD plant will have bypass system in order for emergency condition.

There are currently over 400 supercritical units in operation in the United States, Europe, Korea, and

Japan and a few in the developing countries. The European, Japanese, and, recently, the Chinese

suppliers have standardized on supercritical designs for units larger than 600 MW. Due to renewed

interest in large coal-fired plants in the United States, the American suppliers have revived the debate

over subcritical versus supercritical steam cycles. Most recent coal plants now under design and

construction are supercritical.

The coastal meteorology and hydrography of Karachi is controlled by the seasonal change in the north

Arabian Sea viz. monsoon system. The data collected for a number of studies along the Karachi coast

show the influence of NE and SW monsoon winds. The meteorological conditions in the area around

Port Qasim are characterized by generally hot and relatively humid conditions especially in the

summers (April to October) when the prevailing wind is from the south west. The south west monsoon

brings humid air in from the sea, but the rainfall is generally very low with nearly 80% of the 265mm of

rain falling from July to September. Rainfall, when it does come is often torrential causing problems of

drainage and erosion of the light and sparsely vegetated land.

The winters are short and mild from December to mid-February with the prevailing wind coming from

the northeast with very little rainfall. The most important characteristics of the prevailing

meteorological conditions are the generally high dusty conditions as a result of the aridity of the

surrounding area; dust storms occur especially during the summer as well as winter monsoons. The

higher winds during the south west monsoon tend to carry any air-borne contaminant inland during

the summer months. In winter the winds tend to be light to moderate in intensity.

The proposed CPP site located in the coastal zone has a relatively mild climate, characterized by dry, hot

and humid conditions. There is minor seasonal intervention of a mild winter from mid-December to

mid-February into a long hot and humid summer extending from April to mid-September.

Sea water samples collected from Lath Basti had lower SAR~65 but TDS ~38700 at 26 and 28oC, pH

7.44 and 7.58, and DO~4.0 showing dilution with wastewater discharges from the surrounding. The

samples from boreholes show characteristics of groundwater having higher proportions of sodium and

chloride ions. The water supply samples with SAR above 1.2 show characteristics of fresh water

contamination with groundwater.

Wastewater samples collected from Korangi Industrial Area which is the outfall region of Malir River,

had SAR values ranging from 2.79 to 5.56; TDS ranging from 1228 to 4310; low DO 0.39 to 0.62 and the

high BOD and COD values in the samples; they are characterized as industrial wastewater mixed with

sewage. The sewage is in higher proportion upstream while industrial effluent is dominant as the river

enters its delta area. Seawater intrusion was noted at Malir River/Korangi Industrial Area during high

tide. It was noted that the sample collected from here had SAR 57.68, TDS 22300, DO 0.82 and quite

high BOD and COD, and is characterized as seawater contaminated with sewage and industrial effluent.

The quality of water samples collected from the Kadiro Creek in front of the proposed site during the

current EIA study is presented in Table 5.5. Here again it is noted that the Seawater TDS in both samples

is at least 10,000 mg/L lower than what is normal for open seas and much lower than that observed at

the creeks. The BOD5 is much lower than COD values suggesting that the seawater has been

http://www.answers.com/topic/climate

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contaminated by chemical oxidants or industrial effluents and that the channel is least exposed to

sewage or biological contaminants.

EMC acquired the services of SUPARCO to study the pollutants concentration levels in ambient air in the microenvironment of project site. The results show that ambient air concentration of all parameters i.e., SO2, NO2, NO, CO, PM10, PM2.5, SPM and Lead in the area meets Sindh Ambient Air quality Standards.

The mangrove trees growing 200-300 m away from the creek (seawater) in the land ward direction showed an overall decline in the height of the mangrove plantations.

The density of mangrove vegetation was randomly evaluated in an area of 100m2. The trees were characterized (visual observations) according to the arbitrary height of the plants.

The height of mangrove seedling were characterized as <0.5 m Mangrove sapling height 0.5 -1.0 m Short mangroves trees were characterized as having 1-2 m height. Medium height mangroves trees had were characterized as having 2-3 m height. High mangroves trees had were characterized as having more than 3 m height.

The Shannon Weiner biodiversity Index was undertaken. Both the species diversity and the species

richness is relatively poor. The species diversity ranges from 0.69 to 0.90 (normal range is 3.0) whereas the species richness i.e. number of species in each of the community measured between 0.07 at sample 3 to 0.188 at station 1 (species richness ranges from 0.01 (low) to (1.0) high. It is not unusual, since the creeks are generally a disturbed area.

The ecology of the two UCs viz. Ibrahim Haidery and Rehri, which are the main constituencies of the

macroenvironment of the proposed project site, has completely changed by having grown from

villages dominated mainly by fishermen until the late 1950s with hardly 250 huts each scattered along

the coast to attain the category of towns with population estimated by the local residents to exceed

50,000. Both of them are now the headquarters for Union Council Administration. Lath Basti and

Chashma Goth have also grown from villages to small towns; they are both part of Rehri Union Council.

Residents of Ibrahim Haidery and Rehri were traditional fishermen involved in fishing business since

the last few centuries. They have been joined by scores of migrants from coastal villages and towns like

Shah Bunder and Keti Bunder on the east and west of Indus Delta respectively and also the

Bangladeshis and Burmese who appeared here as cheap labor. Lath Basti on the other hand is home

for the Jat tribe, who were traditionally engaged in cattle and camel farming. The Jat tribe had migrated

from the interior of Sindh and has been residing at the present site of Lath Basti for the last seven or

eight decades. Juma Goth with its Railway Station and a large plot of land, designated to house the KCR

displaced population, lies between Cattle Colony and Port Qasim Employees Residential area.

Screening process has been adopted to identify significant environmental and social aspects during the

pre-construction, construction and operation stages of proposed 1 x 660 MW CPP Project. Based on

the environmental aspects identified for the different stages and during the stakeholder meetings,

mitigation measures have been proposed. Mitigation Measures will have to be adopted in order to

reduce, minimize or compensate for the negative impact as far as possible.

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The power plant building structure(s) would be reinforced concrete (recommended by UNDP for

Tsunami affected areas). This responds to the Tsunami hazard that has been identified recently.

The near shore environment of the project site is characterized by long and narrow creeks, mud flats

and the mangroves forest ecosystems. However, it has been committed by LEPCL that for any

mangrove tree / plant destroyed due to Project activities, five mangrove seedlings / species will be

planted in another part of the coast/project site in presence of independent observers such as IUCN-P,

WWF-P and LEPCL shall be responsible to provide necessary care until they reach maturity.

To avoid adverse impact of the construction activities on the environment, following measures are

proposed:

The construction contractor will develop a specific Construction Management Plan (CMP) based

on the CMP included in the EMP. The CMP will be submitted to the LEPCL for approval.

The CMP will clearly identify all areas that will be utilized during construction for various purposes.

For example, on a plot plan of the construction site the following will be shown:

o Areas used for camp

o Storage areas for raw material and equipment

o Waste yard

o Location of any potentially hazardous material such as oil

o Parking area

o Loading and unloading of material

o Septic tanks

o Safe distance from water front

Other key mitigation measures are as follows:

The new equipment will be stored in properly demarcated and identified areas;

Lifting equipment (cranes) used for the equipment will follow the prescribed safety specification;

Material Safety Data Sheet (MSDS) for chemicals, if any, will accompany the consignment. A copy

of the MSDS will be available near the storage area at all times;

Appropriate PPEs will be provided to the workers and it will be ensured that the PPEs are used;

The staff will be provided with training in use of PPE;

Proper scaffolding platforms will be provided for all work areas located more than 1 m above floor

level;

First Aid facilities and fire protection devices will be placed in areas where activates will be

performed;

Ear protection will be used if the noise level is above 85dB(A);

All confined spaces will be identified;

The temperature of the confined space will be in the human tolerance range;

Artificial and intrinsically safe lighting will be provided in the confined spaces;

If there is a risk of gases or fumes in the confined space the provisions for ventilation will be made.

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During operation of a thermal power project, the soils within the deposition zone of pollutants may

undergo physico-chemical changes due to deposition of SPM (ash particles) and washout of gases (SOx

and NOx) during the rains. However, the impacts of these are likely to be marginal, as the impacts on

soil due to gaseous emissions from operation of LECPP, are likely to be negligible as the maximum

incremental PM and SO2 levels are in the range of 1.3 and 15.1 µg/m3 respectively.

The effluents from the plant include the boiler blow down, cooling water and waste water from the

plant. A water treatment plant will be constructed at the plant site which will ensure the effluents meet

the SEQS limits.

The main mode of air pollution from a thermal power plant is point emission –emissions from the boiler

and the combustion of fuel (HSFO, natural gas and coal) results in the emission of various types of

pollutants from the plant stack. The main pollutants are Particulate Matter, Oxides of Nitrogen (NOx),

and Sulphur Dioxide (SO2).

The modeling for the proposed LECPP Project was carried out using the US EPA ISCST3 Model. The

model is capable of handling multiple sources, including point, volume, area and open pit source types.

However, in the present scope the model was used for point emission (chimney) source type. The

worst incremental 24 hourly average GLC value of SO2, NOx, PM10 and PM2.5 from the project at full

operating load with 200 m high stack will be 15.1 μg/m3, 40 μg/m3, 1.3 μg/m3 and 0.85 μg/m3

respectively in the downwind ENE direction (at 2.0 km distance). The worst incremental annual average

GLC vale of SO2, NOx, PM10 and PM2.5 from the project at full operating load will be 3.6 μg/m3, 9.5

μg/m3, 0.4 μg/m3 and 0.2 μg/m3 respectively in the downwind ENE direction (at 1.0 km distance). The

maximum incremental GLC is superimposed over the maximum baseline ambient air level and the

resultant values are shown in Table EX-2 (24 -hour average in μg/m3). The 200 m tall stack heights with

high momentum and buoyancy takes the plume above the highest mixing height. 99.98%. PM

emissions are controlled using ESP, SO2 by FGD and NOx by Low NOx burners. This results in lowest

ground level concentration of air pollutants in the study area.

Table EX-2: Incremental GLC due to LECPP

Parameter Incremental GLC (max) Background Level Superimposed Value Sindh EQS

SO2 15.1 μg/m3 12.06 μg/m3 27.16 μg/m3 120 μg/m3

NOx 40 μg/m3 7.89 μg/m3 47.39 μg/m3 80 μg/m3

PM10 1.3 μg/m3 70 μg/m3 71.3 μg/m3 150 μg/m3

PM2.5 0.9 μg/m3 19.25 μg/m3 19.2 μg/m3 75 μg/m3

The impact on the terrestrial ecosystem due to operation of the thermal power project may occur from

deposition and absorption of air pollutants on flora and soil surfaces. Deposition of fly ash on leaves

may interrupt gaseous exchange through stomatal clogging, thereby affecting plant growth However,

the impact due to operation of the project is envisaged to be negligible, as incremental ground level

concentration ofPM10 due to emissions from the project is predicted to be 1.3 µg/m3 only. The

predicted maximum incremental ground level concentration of SO2 due to operation of project is 15.1

µg/m3 and maximum ground level concentration of SO2 after operation of the project is predicted as

27.16 µg/m3. This is well within the Sindh Ambient Air Quality Standards.

A 100 meter wide green belt shall be developed all around the project and extensive afforestation shall

be undertaken within main plant, township and ash disposal areas. Such activities would help

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ameliorating the impact and improving the environmental quality of the surrounding area. It is

envisaged that the plantation in and around the project site would act as sink to pollutants.

The marine ecological resources including the mangrove plants, MBI, fish, crabs and shrimps may also

suffer harm from the coal dust and ash dust generated as a result of project activities. Leakage from

the prospective ash disposal site due to seepage or an accident may release toxic or hazardous

materials into the creek water, negatively impacting marine biodiversity.

Good practice measures will be adopted including:

Waste management measures outlined in the Waste Management Plan.

Monitoring of liquid effluents from Project to ensure they meet the SEQS.

Monitoring of gaseous emissions including coal and ash dust

Monitoring to ensure that there is no leakage from the ash disposal site.

Fly ash, bottom ash, and boiler slag are other areas of concern in case of coal fired boiler. Recycling of

ash will be the preferred option for ash disposal. The quantity of ash production from the proposed

Project will depend on the quantity of coal and its ash content. For 5-10% ash content, the ash

production is estimated at 250,000 to 500,000 tonnes/year.

A review of the utilization of fly ash produced in the coal powered plants in India shows that on an

average the utilization of fly ash produced by the coal fired power plants is over 50%, with a number of

plants achieving 100% utilization. In China, the nearly 70% of the fly ash produced is recycled.

The fly ash collection and disposal system will transfer particulate collected from the boiler flue gas to

a fly storage silo for unloading into trucks for disposal (transported to lucky cement Karachi). Fly ash

entrained in the boiler flue gas will be collected using a baghouse or electrostatic precipitator. Fly ash

will also be collected throughout the flue gas system by means of ash hoppers at other locations such

as the air heaters. The bottom ash handling system will collect, store, and transport bottom ash from

the boiler furnace, economizer hoppers and mill reject hoppers. The system will include a submerged

scraper conveyor (SSC) for collecting, cooling and transporting the bottom ash, a flight conveyor system

to convey economizer ash to the SSC, and a sluice system to convey mill rejects to the SSC. The bottom

ash, mill rejects and economizer ash will be transported to a concrete bunker for removal by trucks.

The objectives of Environmental Management and Monitoring Plan are to provide consistent

information and guidance for implementing the management and monitoring measures which will

help achieve compliance with recommendations and conditions specified through the EIA process as

well as to ensure continuous improvement of environmental performance, reduction of negative

impacts and enhancement of positive effects during the construction, operation and decommissioning

of the facility.

The aims of this EMMP are to:

Ensure that all relevant legislations (including national, provincial and local) are complied with

during all the phases;

Identify entities that will be responsible for the implementation of the measures and outlines the

functions and responsibilities;

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To propose mechanisms for monitoring compliance & prevent long-term or permanent

environmental degradation;

Ensure that the best management/ industry practices and best available techniques are

incorporated and implemented to minimize potential environmental and social impacts during

each phase;

Ensure that the project operation does not result in undue or reasonably avoidable adverse

environmental impacts, and that any potential environmental benefits are enhanced;

Enforce the company policies through training, supervision, regular reviews and consultation;

Adhere to high standards of safety and care for the protection of the Employees and public.

Screening of potential environmental impacts at the different stages of the Project namely siting,

construction and operation of the proposed 1 x 600 MW Coal Power Plant by Lucky Electric Power

Company Limited (LEPCL) leads to the following conclusion:

Environmental impacts of the proposed Project are localized to the microenvironment of the

activity area and consequently are rated as minor or insignificant.

Severity of impact of the activities is of small order.

Implementation of recommended mitigation measures and strictly following the environmental

management plan shall minimize the impact of proposed activities.

The proposed project will create enormous potentiality of economic and social development of the

region. The present electricity crisis and rising electricity demand urge installation of new power plant.

It will offer large number of job opportunity during its life time where the local people will get priority.

The potential benefits of the project will compensate the negative impact if the prescribed EMP is

implemented with honesty. The proposed Project would, on adoption of mitigation measures, have

no significant impact on the microenvironment and macroenvironment of the project area.

This EIA Study finds that the proposed project would fulfil the requirements of sustainable

development by being socially equitable, and economically viable in improving the quality of life for all

citizens of Pakistan, without altering the balance in the resources of the ecosystem of the region.

The Study therefore recommends that the EIA report should be approved with the provision that the

suggested mitigation measures will be adopted and the Environmental Management & Monitoring

Plans shall be followed in letter and spirit.

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Table of Contents

1.0 INTRODUCTION ........................................................................................................... 1

1.1 PROJECT PROPONENT ......................................................................................................................... 1 1.2 EIA CONSULTANT................................................................................................................................. 3 1.3 THE PROJECT ....................................................................................................................................... 4 1.4 PROJECT BACKGROUND ...................................................................................................................... 7 1.4.1 ENERGY RESOURCES IN PAKISTAN ...................................................................................................... 7 1.4.2 CURRENT ENERGY MIX ........................................................................................................................ 7 1.4.3 TARGET ENERGY MIX ........................................................................................................................... 8 1.4.4 PROFILE OF CURRENT ENERGY CONSUMPTION .................................................................................. 8 1.4.5 CURRENT POWER SUPPLY ................................................................................................................... 9 1.4.5.1 ELECTRICITY GENERATION ................................................................................................................... 9 1.4.5.2 K-ELECTRIC (FORMERLY KESC) ........................................................................................................... 10 1.4.5.3 NUCLEAR ........................................................................................................................................... 10 1.4.6 GOVERNMENT OF PAKISTAN POLICY, THE REGULATORY FRAMEWORK, AND THE ENERGY SECTOR

.......................................................................................................................................................... 11 1.4.7 ELECTRICAL POWER SUPPLY IN PAKISTAN ........................................................................................ 14 1.4.7.1 FUTURE DEMAND FOR POWER ......................................................................................................... 14 1.4.7.2 DEMAND FORECAST .......................................................................................................................... 14 1.4.7.3 FUTURE SUPPLY ................................................................................................................................. 15 1.4.7.4 THE ROLE OF IMPORTED COAL .......................................................................................................... 16 1.4.7.5 NUCLEAR ENERGY.............................................................................................................................. 16 1.4.8 TRANSMISSION NETWORK ................................................................................................................ 17 1.5 OBJECTIVES OF PROJECT ................................................................................................................... 18 1.6 NEED FOR EIA .................................................................................................................................... 19 1.7 OBJECTIVES OF EIA ............................................................................................................................ 19 1.8 CATEGORIZATION OF PROJECT.......................................................................................................... 20 1.9 METHODOLOGY................................................................................................................................. 20 1.9.1 SCOPING ............................................................................................................................................ 20 1.9.2 BASELINE DATA COLLECTION ............................................................................................................ 21 1.9.3 IDENTIFICATION OF ASPECTS ............................................................................................................ 21 1.9.4 IMPACT ASSESSMENT & EMP ............................................................................................................ 21 1.9.5 DOCUMENTATION & REVIEW ........................................................................................................... 22 1.10 STRUCTURE OF THE EIA REPORT ....................................................................................................... 22

2.0 POLICY, LEGAL & REGULATORY FRAMEWORK ............................................................ 23

2.1 NATIONAL POLICY FRAMEWORK ....................................................................................................... 23 2.1.1 NATIONAL CONSERVATION STRATEGY .............................................................................................. 23 2.1.2 BIODIVERSITY ACTION PLAN.............................................................................................................. 23 2.1.3 NATIONAL POWER POLICY 2013 ....................................................................................................... 23 2.1.4 NATIONAL FOREST POLICY 2010 ....................................................................................................... 24 2.1.5 NATIONAL ENVIRONMENTAL POLICY 2005 ....................................................................................... 24 2.1.6 NATIONAL CLIMATE CHANGE POLICY ............................................................................................... 25 2.1.7 NATIONAL STRATEGY AND ACTION PLAN FOR MANGROVES FOR THE FUTURE (2010) ................... 25 2.1.8 NATIONAL DRINKING WATER POLICY ................................................................................................ 26 2.2 THE 18TH AMENDMENT IN CONSTITUTION OF PAKISTAN ............................................................... 26 2.2.1 SINDH ENVIRONMENTAL PROTECTION AGENCY............................................................................... 26 2.2.2 SINDH ENVIRONMENTAL PROTECTION ACT 2014 ............................................................................. 27 2.3 SINDH WILDLIFE PROTECTION ORDINANCE 1972 AND AMENDMENTS 2001 ................................... 28 2.4 SINDH FISHERIES ORDINANCE 1980 .................................................................................................. 29 2.5 SINDH FOREST ACT 1927 ................................................................................................................... 29 2.6 THE FACTORIES ACT 1934 .................................................................................................................. 29 2.7 LAND ACQUISITION ACT (LAA) 1984.................................................................................................. 30 2.8 PORT QASIM AUTHORITY ACT 1973 (AMENDMENTS 2002) ............................................................. 31



2.9 PAKISTAN PENAL CODE ..................................................................................................................... 31 2.10 SINDH ANTIQUITIES ACT 1974 ........................................................................................................... 32 2.11 SINDH CULTURAL HERITAGE (PRESERVATION) ACT 1994 ................................................................. 32 2.12 THE BOILER ACT 1923 ........................................................................................................................ 32 2.13 THE MOTOR VEHICLES ORDINANCE 1965 AND RULES 1969 ............................................................. 32 2.14 ENVIRONMENTAL REGULATIONS & GUIDELINES .............................................................................. 32 2.14.1 SINDH EPA REVIEW OF IEE AND EIA REGULATIONS 2014 ................................................................. 32 2.14.2 ENVIRONMENTAL ASSESSMENT PROCEDURES ................................................................................. 34 2.14.3 SINDH ENVIRONMENTAL QUALITY STANDARDS ............................................................................... 37 2.14.4 SELF-MONITORING AND REPORTING BY INDUSTRY RULES 2014 ...................................................... 40 2.14.5 THE HAZARDOUS SUBSTANCES RULES 2014 ..................................................................................... 41 2.14.6 GUIDELINES FOR SENSITIVE AND CRITICAL AREAS ............................................................................ 41 2.14.7 GUIDELINES FOR PUBLIC CONSULTATION ......................................................................................... 41 2.14.8 GUIDELINES FOR COAL FIRED THERMAL POWER PLANTS – NIAP (2014) .......................................... 43 2.14.9 IFC GUIDELINES FOR THERMAL POWER PLANTS ............................................................................... 43 2.14.10 IFC GENERAL EHS GUIDELINES .......................................................................................................... 44 2.14.11 IFC PERFORMANCE STANDARDS 2012 .............................................................................................. 45 2.15 INTERNATIONAL CONVENTIONS AND TREATIES ............................................................................... 47 2.15.1 CONVENTION ON CONSERVATION OF MIGRATORY SPECIES, 1979 .................................................. 48 2.15.2 CONVENTION OF INTERNATIONAL TRADE IN ENDANGERED SPECIES (CITES) 1973 ......................... 48 2.15.3 CONVENTION ON WETLANDS OF INTERNATIONAL IMPORTANCE; RAMSAR CONVENTION 1971.... 48 2.15.4 IUCN RED LIST .................................................................................................................................... 49 2.15.5 INTERNATIONAL CONVENTION ON BIODIVERSITY 1992 ................................................................... 49 2.15.6 KYOTO PROTOCOL (1992) AND UNITED NATION’S CLIMATE CHANGE CONVENTION ...................... 49

3.0 DESCRIPTION OF PROJECT ......................................................................................... 51

3.1 THERMAL POWER GENERATION PROCESS ........................................................................................ 51 3.2 BOILER SYSTEM ................................................................................................................................. 54 3.2.1 FURNACE ........................................................................................................................................... 55 3.2.2 SUPERHEATERS AND REHEATERS ...................................................................................................... 55 3.2.3 REHEAT STEAM PIPES ........................................................................................................................ 56 3.2.4 ECONOMIZER .................................................................................................................................... 56 3.2.5 STARTUP SYSTEM .............................................................................................................................. 56 3.2.6 AIR PREHEATER ................................................................................................................................. 56 3.2.7 SOOT BLOWERS ................................................................................................................................. 57 3.2.8 PULVERIZER ....................................................................................................................................... 57 3.2.9 BURNERS ........................................................................................................................................... 58 3.2.10 SYSTEM OPERATION .......................................................................................................................... 58 3.3 TURBINE GENERATOR ....................................................................................................................... 58 3.3.1 HIGH-PRESSURE TURBINE ................................................................................................................. 59 3.3.2 INTERMEDIATE-PRESSURE TURBINE ................................................................................................. 59 3.3.3 LOW-PRESSURE TURBINE .................................................................................................................. 59 3.3.4 LUBRICATING OIL SYSTEM ................................................................................................................. 59 3.3.5 ELECTROHYDRAULIC CONTROL OIL SYSTEM ..................................................................................... 60 3.3.6 GENERATOR ....................................................................................................................................... 60 3.3.7 HYDROGEN SEAL OIL SYSTEM............................................................................................................ 60 3.3.8 STATIC EXCITER .................................................................................................................................. 60 3.3.9 CONTROL SYSTEM ............................................................................................................................. 60 3.3.10 SYSTEM OPERATION .......................................................................................................................... 60 3.4 MAIN STEAM AND REHEAT PIPING ................................................................................................... 61 3.4.1 FUNCTION.......................................................................................................................................... 61 3.4.2 MAIN STEAM ..................................................................................................................................... 61 3.4.3 COLD REHEAT .................................................................................................................................... 61 3.4.4 HOT REHEAT ...................................................................................................................................... 61 3.4.5 EXTRACTION STEAM .......................................................................................................................... 61 3.4.6 SYSTEM OPERATION .......................................................................................................................... 62 3.5 CONDENSATE .................................................................................................................................... 62



3.5.1 FUNCTION.......................................................................................................................................... 62 3.5.2 DESIGN BASIS .................................................................................................................................... 62 3.5.3 SYSTEM OPERATION .......................................................................................................................... 63 3.6 FEED WATER ...................................................................................................................................... 63 3.6.1 FUNCTION.......................................................................................................................................... 63 3.6.2 DESIGN BASIS .................................................................................................................................... 63 3.6.3 SYSTEM OPERATION .......................................................................................................................... 64 3.7.1 FUNCTION.......................................................................................................................................... 64 3.7.2 DESIGN BASIS .................................................................................................................................... 64 3.7.3 SYSTEM OPERATION .......................................................................................................................... 65 3.8 CLOSED COOLING WATER SYSTEM .................................................................................................... 65 3.8.1 FUNCTION.......................................................................................................................................... 65 3.8.2 DESIGN BASIS .................................................................................................................................... 66 3.8.3 SYSTEM OPERATION .......................................................................................................................... 66 3.9 HYPOCHLORITE GENERATOR ............................................................................................................. 67 3.9.1 FUNCTION.......................................................................................................................................... 67 3.9.2 DESIGN BASES.................................................................................................................................... 67 3.9.3 DESCRIPTION ..................................................................................................................................... 67 3.9.4 NORMAL OPERATION ........................................................................................................................ 67 3.9.5 ABNORMAL OPERATION ................................................................................................................... 68 3.10 DESALINATION ................................................................................................................................... 68 3.10.1 FUNCTION.......................................................................................................................................... 68 3.10.2 DESIGN BASIS .................................................................................................................................... 68 3.10.3 DESCRIPTION ..................................................................................................................................... 68 3.10.4 NORMAL OPERATION ........................................................................................................................ 69 3.10.5 ABNORMAL OPERATION ................................................................................................................... 69 3.11 DEMINERALIZATION .......................................................................................................................... 69 3.11.1 FUNCTION.......................................................................................................................................... 69 3.11.2 DESIGN BASES.................................................................................................................................... 70 3.11.3 DESCRIPTION ..................................................................................................................................... 70 3.11.4 NORMAL OPERATION ........................................................................................................................ 70 3.11.5 ABNORMAL OPERATION ................................................................................................................... 71 3.12 CONDENSATE POLISHING .................................................................................................................. 71 3.12.1 FUNCTION.......................................................................................................................................... 71 3.12.2 DESIGN BASES.................................................................................................................................... 71 3.12.3 DESCRIPTION ..................................................................................................................................... 71 3.12.4 NORMAL OPERATION ........................................................................................................................ 71 3.12.5 ABNORMAL OPERATION ................................................................................................................... 72 3.13 WASTEWATER SYSTEM ...................................................................................................................... 72 3.13.1 FUNCTION.......................................................................................................................................... 72 3.13.2 DESIGN BASIS .................................................................................................................................... 72 3.13.3 INDUSTRIAL WASTEWATER TREATMENT .......................................................................................... 73 3.13.4 SANITARY WASTEWATER TREATMENT SYSTEM ................................................................................ 73 3.13.5 NORMAL OPERATION ........................................................................................................................ 74 3.13.6 ABNORMAL OPERATION ................................................................................................................... 74 3.14 EMISSION CONTROLS ........................................................................................................................ 74 3.14.1 LOW NOx BURNERS ........................................................................................................................... 74 3.14.1.1 FUNCTION.......................................................................................................................................... 74 3.14.1.2 DESIGN BASIS .................................................................................................................................... 75 3.14.1.3 SYSTEM OPERATION .......................................................................................................................... 75 3.14.2.1 FUNCTION.......................................................................................................................................... 75 3.14.2.2 DESIGN BASIS .................................................................................................................................... 75 3.14.2.3 SYSTEM OPERATION .......................................................................................................................... 75 3.14.3 BAGHOUSE/ELECTROSTATIC PRECIPITATOR/SCRUBBER SYSTEM ..................................................... 76 3.14.3.1 FUNCTION.......................................................................................................................................... 76 3.14.3.2 DESIGN BASIS .................................................................................................................................... 76 3.14.3.3 SYSTEM OPERATION .......................................................................................................................... 76



3.14.3.4 THERMAL DISCHARGE ....................................................................................................................... 78 3.14.3.5 NOISE ................................................................................................................................................. 78 3.14.3.6 ASH .................................................................................................................................................... 78 3.14.3.7 AIRBORNE DUST FORM ASH STORAGE YARD .................................................................................... 78 3.14.3.8 WASTEWATER DISCHARGE ................................................................................................................ 78 3.15 HVAC .................................................................................................................................................. 79 3.15.1 FUNCTION.......................................................................................................................................... 79 3.15.2 DESIGN BASIS .................................................................................................................................... 79 3.15.3 AIR CONDITIONING ........................................................................................................................... 79 3.15.4 BATTERY ROOM ................................................................................................................................. 79 3.16 COAL DUST COLLECTORS ................................................................................................................... 80 3.17 DRY PIPE DELUGE TYPE SPRINKLER SYSTEM...................................................................................... 81 3.18 DUST SUPPRESSION ........................................................................................................................... 82 3.18.1 SYSTEM OPERATION .......................................................................................................................... 82 3.18.2 WET CENTRIFUGAL DUST COLLECTOR .............................................................................................. 82 3.19 COMPRESSED AIR .............................................................................................................................. 83 3.19.1 FUNCTION.......................................................................................................................................... 83 3.19.2 DESIGN BASIS .................................................................................................................................... 83 3.19.3 SYSTEM OPERATION .......................................................................................................................... 83 3.20 FIRE PROTECTION .............................................................................................................................. 83 3.20.1 FUNCTION.......................................................................................................................................... 83 3.20.2 DESIGN BASIS .................................................................................................................................... 83 3.20.3 FIRE PROTECTION MASTER PLAN ...................................................................................................... 85 3.20.4 BUILDING AND FIRE CODES & LIFE SAFETY COMPLIANCE REVIEW ................................................... 85 3.20.5 FIRE RISK EVALUATION ...................................................................................................................... 86 3.20.6 HAZARDOUS AREA CLASSIFICATION EVALUATION ............................................................................ 86 3.20.7 SYSTEM OPERATION .......................................................................................................................... 86 3.21 FUEL OIL STORAGE AND TRANSFER ................................................................................................... 87 3.21.1 FUNCTION.......................................................................................................................................... 87 3.21.2 DESIGN BASIS .................................................................................................................................... 87 3.21.3 SYSTEM OPERATION .......................................................................................................................... 88 3.22 COAL UNLOADING AND HANDLING SYSTEM ..................................................................................... 88 3.22.1 FUNCTION.......................................................................................................................................... 88 3.22.2 DESIGN BASIS .................................................................................................................................... 88 3.22.3 DESCRIPTION ..................................................................................................................................... 89 3.22.4 SYSTEM OPERATION .......................................................................................................................... 90 3.23 ASH HANDLING AND DISPOSAL ......................................................................................................... 90 3.23.1 FUNCTION.......................................................................................................................................... 90 3.23.2 DESIGN BASIS .................................................................................................................................... 90 3.23.2.1 FLY ASH HANDLING SYSTEM .............................................................................................................. 90 3.23.2.2 BOTTOM ASH HANDLING SYSTEM .................................................................................................... 90 3.23.2.3 MILL REJECTS HANDLING SYSTEM ..................................................................................................... 90 3.23.2.4 ECONOMIZER ASH HANDLING SYSTEM ............................................................................................. 91 3.23.3 DESCRIPTION ..................................................................................................................................... 91 3.23.3.1 FLY ASH HANDLING SYSTEM .............................................................................................................. 91 3.23.3.2 BOTTOM ASH AND PYRITE HANDLING .............................................................................................. 91 3.23.3.3 SYSTEM OPERATION .......................................................................................................................... 92 3.24 ELECTRICAL ........................................................................................................................................ 92 3.24.1 FUNCTION.......................................................................................................................................... 92 3.24.2 DESIGN BASES.................................................................................................................................... 92 3.24.3 SYSTEM CONFIGURATION ................................................................................................................. 93 3.24.4 SYSTEM OPERATION .......................................................................................................................... 93 3.25 STATION TRANSFORMER SYSTEM ..................................................................................................... 95 3.25.1 FUNCTION.......................................................................................................................................... 95 3.25.2 DESIGN BASIS .................................................................................................................................... 95 3.25.3 SYSTEM CONFIGURATION ................................................................................................................. 95 3.25.4 SYSTEM OPERATION .......................................................................................................................... 95



3.26 11-KV UPPER MEDIUM VOLTAGE SYSTEM ........................................................................................ 96 3.26.1 FUNCTION.......................................................................................................................................... 96 3.26.2 DESIGN BASIS .................................................................................................................................... 96 3.26.3 SYSTEM CONFIGURATION ................................................................................................................. 96 3.26.4 SYSTEM OPERATION .......................................................................................................................... 96 3.27 3.3-KV LOWER MEDIUM VOLTAGE SYSTEM ...................................................................................... 96 3.27.1 FUNCTION.......................................................................................................................................... 96 3.27.2 DESIGN BASIS .................................................................................................................................... 96 3.27.3 SYSTEM CONFIGURATION ................................................................................................................. 97 3.27.4 SYSTEM OPERATION .......................................................................................................................... 97 3.28 400-VOLT LOW-VOLTAGE AUXILIARY SYSTEM .................................................................................. 97 3.28.1 FUNCTION.......................................................................................................................................... 97 3.28.2 DESIGN BASIS .................................................................................................................................... 97 3.28.3 SYSTEM CONFIGURATION ................................................................................................................. 98 3.28.4 SYSTEM OPERATION .......................................................................................................................... 98 3.29 DC SYSTEMS ....................................................................................................................................... 98 3.29.1 FUNCTION.......................................................................................................................................... 98 3.29.2 DESIGN BASIS .................................................................................................................................... 99 3.29.3 SYSTEM CONFIGURATION ................................................................................................................. 99 3.29.4 SYSTEM OPERATION .......................................................................................................................... 99 3.30 UNINTERRUPTIBLE POWER SUPPLY SYSTEM ................................................................................... 100 3.30.1 FUNCTION........................................................................................................................................ 100 3.30.2 DESIGN BASIS .................................................................................................................................. 100 3.30.3 SYSTEM CONFIGURATION ............................................................................................................... 100 3.30.4 SYSTEM OPERATION ........................................................................................................................ 100 3.31 EMERGENCY DIESEL GENERATOR SYSTEM ...................................................................................... 100 3.31.1 FUNCTION........................................................................................................................................ 100 3.31.2 DESIGN CRITERIA ............................................................................................................................. 100 3.31.3 SYSTEM CONFIGURATION ............................................................................................................... 101 3.31.4 SYSTEM OPERATION ........................................................................................................................ 101 3.32 SWITCHYARD ................................................................................................................................... 101 3.32.1 FUNCTION........................................................................................................................................ 101 3.32.2 DESIGN BASIS .................................................................................................................................. 101 3.32.3 SYSTEM CONFIGURATION ............................................................................................................... 101 3.32.4 SYSTEM OPERATION ........................................................................................................................ 102 3.33 INSTRUMENTATION AND CONTROLS .............................................................................................. 102 3.34 DISTRIBUTED CONTROLS AND MONITORING SYSTEMS .................................................................. 103 3.35 OPERATOR CONSOLE ....................................................................................................................... 104 3.36 BOILER CONTROL SYSTEM ............................................................................................................... 105 3.36.1 GENERAL .......................................................................................................................................... 105 3.36.2 SYSTEM DESCRIPTION ..................................................................................................................... 105 3.37 BURNER CONTROL AND FURNACE SAFETY SYSTEM ........................................................................ 106 3.37.1 SYSTEM DESCRIPTION ..................................................................................................................... 107 3.37.2 FLAME SCANNERS ........................................................................................................................... 107 3.38 TURBINE CONTROL SYSTEM ............................................................................................................ 107 3.38.1 GENERAL .......................................................................................................................................... 107 3.38.2 SYSTEM DESCRIPTION ..................................................................................................................... 107 3.38.3 TURBINE SUPERVISORY INSTRUMENTS ........................................................................................... 108 3.39 VIBRATION MONITORING ............................................................................................................... 108 3.40 CONTINUOUS EMISSION MONITORING SYSTEM ............................................................................ 109 3.41 PROPOSED COAL RECEIVAL ............................................................................................................. 109

4.0 SCREENING OF ALTERNATIVES ................................................................................. 111

4.1 NO PROJECT ALTERNATIVE .............................................................................................................. 111 4.2 TECHNOLOGY SELECTION ................................................................................................................ 112 4.2.1 THE BOILER ...................................................................................................................................... 112 4.2.2 UNIT SIZE SELECTION ....................................................................................................................... 112



4.2.3 PARTICULATE MATTER EMISSION CONTROLS ................................................................................. 114 4.2.4 ASH HANDLING AND DISPOSAL ....................................................................................................... 115 4.3 COAL SOURCE AND PRICING ........................................................................................................... 116 4.3.1 SUPPLY ............................................................................................................................................. 116 4.3.2 WORLD PRODUCTION: THE WORLD SEABORNE THERMAL COAL MARKET .................................... 116 4.3.3 POTENTIAL COAL SUPPLY SOURCES ................................................................................................ 117 4.3.3.1 AUSTRALIA - NEW SOUTH WALES ................................................................................................... 119 4.3.3.2 AUSTRALIA - QUEENSLAND ............................................................................................................. 120 4.3.3.3 INDONESIA ...................................................................................................................................... 120 4.3.3.4 BUMI RESOURCES ............................................................................................................................ 122 4.3.3.5 PT ADARO INDONESIA ..................................................................................................................... 122 4.3.3.6 BANPU PUBLIC COMPANY LTD. ....................................................................................................... 123 4.3.3.7 PT KIDECO JAYA AGUNG .................................................................................................................. 123 4.3.3.8 OTHER LARGE INDONESIAN STEAM COAL PRODUCERS .................................................................. 123 4.3.3.9 PAKISTAN ......................................................................................................................................... 123 4.3.3.10 SOUTH AFRICA ................................................................................................................................. 124 4.3.3.11 BHP BILLITON................................................................................................................................... 125 4.3.3.12 ANGLO COAL ................................................................................................................................... 125 4.3.3.13 XSTRATA .......................................................................................................................................... 125 4.3.3.14 OTHER MAJOR STEAM COAL EXPORTERS ....................................................................................... 125 4.3.3.15 MOATIZE MINE ................................................................................................................................ 125 4.3.4 COAL QUALITIES .............................................................................................................................. 126 4.3.4.1 SIZE OF SHIPS AND AVAILABILITY OF COAL CARRIERS ..................................................................... 128 4.3.4.2 HANDLING CAPACITY OF COAL LOADING PORTS ............................................................................ 128 4.3.4.3 VOYAGE DISTANCE AND FREQUENCY OF TRANSPORTATION ......................................................... 129 4.3.4.4 INDIGENOUS COAL .......................................................................................................................... 129 4.4 COAL SHIPPING AND RECEIVAL ....................................................................................................... 129 4.4.1 TRANSPORTATION TECHNOLOGIES ................................................................................................. 129 4.5 AVAILABILITY OF APPROPRIATE ENERGY SOURCE .......................................................................... 132 4.5.1 SINDH PROVINCE ............................................................................................................................. 132 4.5.1.1 THAR ................................................................................................................................................ 132 4.5.1.2 LAKHRA ............................................................................................................................................ 133 4.5.1.3 SONDA-JHERRUCK ........................................................................................................................... 134 4.5.2 BALOCHISTAN .................................................................................................................................. 135 4.5.2.1 SOR-RANGE, DEGARI, SINJIDI .......................................................................................................... 135 4.5.3 PUNJAB ............................................................................................................................................ 135 4.5.3.1 SALT RANGE ..................................................................................................................................... 135 4.5.3.2 MAKERWAL/GULLAKHEL ................................................................................................................. 135 4.5.4 COAL RESOURCES SUMMARY .......................................................................................................... 136 4.5.5 COAL PRODUCTION ......................................................................................................................... 136 4.5.6 COAL MINING AND TRANSPORTATION ........................................................................................... 136 4.5.6.1 COAL MINING .................................................................................................................................. 136 4.5.6.2 TRANSPORTATION ........................................................................................................................... 137 4.5.7 PAKISTAN COAL FOR LEPCL ............................................................................................................. 137

5.0 ENVIRONMENTAL & SOCIAL BASELINE ..................................................................... 138

5.1 METHODOLOGY OF BASELINE SURVEY ........................................................................................... 138 5.2 DESCRIPTION OF MICRO AND MACRO ENVIRONMENT .................................................................. 138 5.3 PHYSICAL ENVIRONMENT................................................................................................................ 140 5.3.1 TOPOGRAPHY .................................................................................................................................. 140 5.3.2 GEOLOGY, GEOMORPHOLOGY & SOIL ............................................................................................ 140 5.3.2.1 SUB-RECENT AND RECENT DEPOSITS .............................................................................................. 141 5.3.3 SEISMIC CONDITIONS ...................................................................................................................... 143 5.3.4 TSUNAMIS ....................................................................................................................................... 143 5.3.5 HYDROLOGY .................................................................................................................................... 144 5.3.6 WAVES ............................................................................................................................................. 147 5.3.7 TIDES & SURGES .............................................................................................................................. 148



5.3.8 SEAWATER CURRENTS ..................................................................................................................... 149 5.3.9 CLIMATE .......................................................................................................................................... 149 5.3.9.1 TEMPERATURE ................................................................................................................................ 150 5.3.9.2 PRECIPITATION ................................................................................................................................ 151 5.3.9.3 HUMIDITY ........................................................................................................................................ 153 5.3.9.4 WIND DIRECTION AND SPEED ......................................................................................................... 153 5.3.10 AMBIENT AIR & NOISE QUALITY ...................................................................................................... 154 5.3.10.1 DATA ACQUISITION CRITERIA .......................................................................................................... 154 5.3.10.2 AMBIENT AIR QUALITY MONITORING METHODS & AMBIENT AIR QUALITY STANDARDS .............. 155 5.3.10.3 RESULTS ........................................................................................................................................... 156 5.4 ECOLOGY ......................................................................................................................................... 161 5.4.1 FLORA .............................................................................................................................................. 161 5.4.2 FAUNA ............................................................................................................................................. 163 5.4.2.1 METHODOLOGY............................................................................................................................... 163 5.4.2.2 SURVEY RESULTS ............................................................................................................................. 164 5.5 SOCIOECONOMIC ENVIRONMENT .................................................................................................. 170 5.5.1 DEMOGRAPHY ................................................................................................................................. 170 5.5.2 EMPLOYMENT AND LIVING CONDITIONS ........................................................................................ 170 5.5.3 DEPENDENCE ON MANGROVES ...................................................................................................... 171 5.5.4 EDUCATION ..................................................................................................................................... 171 5.5.5 HEALTH ............................................................................................................................................ 172 5.5.6 LANDSCAPING ................................................................................................................................. 172 5.5.7 ARCHAEOLOGICAL AND HISTORICAL SITES ..................................................................................... 172

6.0 SCREENING OF POTENTIAL ENVIRONMENTAL IMPACTS AND PROPOSED MITIGATION MEASURES .............................................................................................................. 175

6.1 IMPACT ON LANDUSE ...................................................................................................................... 175 6.2 IMPACT OF CONSTRUCTION ACTIVITIES ......................................................................................... 175 6.3 SOIL DISTURBANCE .......................................................................................................................... 178 6.4 STABILITY OF STRUCTURES .............................................................................................................. 178 6.5 SOIL & WATER CONTAMINATION ................................................................................................... 179 6.6 IMPACT ON AIR QUALITY................................................................................................................. 183 6.7 COAL DUST CONTROL ...................................................................................................................... 198 6.8 IMPACT DUE TO NOISE .................................................................................................................... 198 6.9 IMPACT ON TERRESTRIAL ECOLOGY ................................................................................................ 206 6.10 IMPACT ON AQUATIC ECOLOGY ...................................................................................................... 206 6.11 DISPOSAL OF WASTE ....................................................................................................................... 207 6.12 ASH HANDLING AND UTILIZATION .................................................................................................. 208 6.13 GREENBELT DEVELOPMENT ............................................................................................................ 209 6.14 EXPLOSION RISK AND PREVENTION ................................................................................................ 209 6.15 SOCIOECONOMIC IMPACT .............................................................................................................. 210 6.16 SAFETY & OCCUPATIONAL HEALTH ................................................................................................. 210

7.0 CONSULTATION & INFORMATION DISCLOSURE ........................................................ 212

7.1 OBJECTIVES ...................................................................................................................................... 212 7.2 CONSULTATION FRAMEWORK ........................................................................................................ 212 7.3 CONSULTATION PROCESS ................................................................................................................ 213 7.4 COMMUNITY ENGAGEMENT RESPONSIBILITIES ............................................................................. 219 7.5 TRAINING ON COMMUNITY RELATIONS ......................................................................................... 221 7.6 STAKEHOLDER ENGAGEMENT PLAN FRAMEWORK......................................................................... 221 7.6.1 OBJECTIVES AND PRINCIPLES .......................................................................................................... 221 7.6.2 PRINCIPLES OF STAKEHOLDER ENGAGEMENT ................................................................................ 222 7.6.3 IMPLEMENTATION PLAN ................................................................................................................. 222 7.6.4 GRIEVANCE MANAGEMENT ............................................................................................................ 223 7.6.5 COMMITMENT REGISTER ................................................................................................................ 224 7.6.6 ROLES AND RESPONSIBILITIES ......................................................................................................... 224 7.6.7 COMMUNITY DEVELOPMENT .......................................................................................................... 225



7.6.8 MONITORING AND EVALUATION .................................................................................................... 225 7.6.9 PERFORMANCE INDICATORS ........................................................................................................... 226

8.0 ENVIRONMENTAL MANAGEMENT & MONITORING PLAN ......................................... 227

8.1 INTRODUCTION ............................................................................................................................... 227 8.2 SCOPE OF EMMP ............................................................................................................................. 227 8.3 OBJECTIVES OF EMMP ..................................................................................................................... 228 8.3.1 PROJECT ........................................................................................................................................... 228 8.4 EMMP PROCESS............................................................................................................................... 228 8.5 PRE-CONSTRUCTION (DESIGN) PHASE ............................................................................................ 229 8.5.1 RESPONSIBILITIES OF LEPCL............................................................................................................. 229 8.5.2 RESPONSIBILITIES OF EPC CONTRACTOR ........................................................................................ 230 8.5.3 CONSTRUCTION PHASE ................................................................................................................... 230 8.5.4 ROLES AND RESPONSIBILITIES DURING CONSTRUCTION ................................................................ 231 8.6 OPERATIONS PHASE ........................................................................................................................ 235 8.6.1 EXPECTED HSE ORGANIZATIONAL STRUCTURE ............................................................................... 235 8.6.2 ROLES AND RESPONSIBILITIES DURING OPERATIONS PHASE ......................................................... 236 8.7 CLOSURE AND DECOMMISSIONING PHASE .................................................................................... 238 8.8 MITIGATION PLAN ........................................................................................................................... 238 8.9 MONITORING PLAN ......................................................................................................................... 256 8.9.1 OBJECTIVES OF MONITORING PLAN ................................................................................................ 256 8.10 WASTE MANAGEMENT PLAN .......................................................................................................... 260 8.11 SPILL MANAGEMENT ....................................................................................................................... 261 8.11.1 AVOIDING SPILLS ............................................................................................................................. 261 8.11.2 SPILL KITS ......................................................................................................................................... 262 8.11.3 RESPONDING TO SPILLS ................................................................................................................... 262 8.12 COAL DUST MANAGEMENT PLAN ................................................................................................... 262 8.13 TRAINING PROGRAM ....................................................................................................................... 263 8.14 CONSTRUCTION MANAGEMENT PLAN............................................................................................ 264 8.15 CHANGE MANAGEMENT ................................................................................................................. 270 8.15.1 FIRST-ORDER CHANGE ..................................................................................................................... 270 8.15.2 SECOND-ORDER CHANGE ................................................................................................................ 270 8.15.3 THIRD-ORDER CHANGE ................................................................................................................... 271 8.15.4 CHANGES TO THE EMMP ................................................................................................................. 272

8.16 EMERGENCY RESPONSE PLAN............................................................................................... 272

9.0 CONCLUSION........................................................................................................... 275

ANNEXURES

Annex –I : Sindh Environmental Protection Act 2014

Annex – II : Sindh EPA (Review of IEE and EIA) Regulations 2014

Annex – III : National Environmental Quality Standards (NEQS)



1.0 INTRODUCTION

Pakistan faces a number of critical challenges in energy sector such as energy and power resource

deficit, power shortages, and a greater dependency on imported oil to meet the energy demand-

supply gap. The demand for electricity currently outstrips supply. Inadequate generation, transmission,

and distribution, as well as the inefficient use of electricity, lead to shortages of 12-18 hours, particularly

at peak times. Realizing these challenges, the governments of Sindh & Pakistan are focusing on the

huge potential of developing indigenous coal resources on fast-track basis and put coal based power

as a major portion in overall energy mix.


inexpensive and affordable electricity for domestic, commercial, and industrial use by using indigenous

resources such as coal (Thar coal) and hydel power, ii) address the key challenges of the power sector

in order to provide much needed relief to the citizens of Pakistan, and iii) shift Pakistan’s energy mix

towards cheaper fuel and conservation of gas for power.

In order to contribute towards meeting Pakistan’s growing electricity demand, Lucky Electric Power

Company Limited (LEPCL) proposes constructing a 1 x 660 MW coal based power station near Port

Qasim Karachi. LEPCL has acquired 250 acres of land from the Sindh Board of Revenue for the

establishment of the proposed power plant. Coal for the power plant will be imported from Indonesia,

South Africa, and/or Australia. The preferred option for imported coal is the under-construction

Pakistan International Bulk Terminal (PIBT) at Port Qasim. The terminal is expected to be operational

by 2016.

This Environmental Impact Assessment (EIA) serves as useful tool in prediction of potential impacts on

the surrounding environment due to developmental project. It will help the project proponent, impact

assessment authorities, regulatory agencies and other stakeholders in understanding the project and

mitigation measures, environmental impact and establishing emission requirements and other

measures early in the project cycle. This report describes the project location, baseline environmental

scenario, potential impacts of the project on the environment and proposed measures for effective

environment management (EMaP & EMoP) during the project cycle.

1.1 PROJECT PROPONENT

The project company Lucky Electric Power Company Limited (LEPCL) is wholly owned

subsidiary or Lucky Holdings Limited (LHL), which is also an indirect subsidiary of Lucky

Cement Limited.

Lucky Cement Limited was founded in 1996 by Tabba Memons. The company initially

started with factories in the Pezu district of the North West Frontier Province (N.W.F.P). It now, also,

owns a factory in Karachi. Lucky Cement Limited has been sponsored by one of the largest business

groups in Pakistan, the Yunus Brothers Group based in Karachi. Over the years, the Company has grown

substantially and is expanding its business operations with production facilities at strategic locations in

Karachi to cater to the Southern regions and Pezu, Khyber Pakhtunkhwa to furnish the Northern areas

of the country. Lucky Cement has a network of over 200 dealers which enables it to dominate the local

market and is Pakistan’s first company to export sizeable quantities of loose cement and is the only

cement manufacturer to have its own loading and storage terminal at Karachi Port.



In 2013, LCL imported 1 million ton of thermal coal. In the thermal coal market in Japan, LCL has been

the largest coal importer for many years. The stable supply of coal from many countries, including

Australia, Canada, China, Indonesia, and Russia, supports consistent power supply in Japan.

The company is producing enough electricity to not only fulfil its own requirements but has also started

supplying electricity to Hyderabad Electric Supply Corporation and is now in the process of providing

electricity to Peshawar Electric Supply Corporation which is a noteworthy achievement in the area of

energy generation.

It also has Largest, lowest cost and most efficient cement manufacturer in Pakistan with captive power

generation capacity of 200 MW. Similarly it produces 7.75 million tons of cement per annum

production capacity with production lines at different strategic locations from coverage perspective

within Pakistan. The 2013 Turnover of USD 375 million with USD 127 million exports to Africa, GCC

countries, India, Iraq, Sri Lanka and Afghanistan. It is also the Largest exported of cement from Pakistan.

The group has around 29,000 employees. Yunus brother group is also a proud sponsor of 9 different

firms including Lucky Cement Limited. The firms include textile mills, building materials and others.

Almost all generate their own electricity. Following are the companies generating their own electricity:

Lucky Cement Limited (Pezu) - 75 MW

Lucky Cement Limited (Karachi) - 80 MW

Lucky Cement Limited – WHR Pezu – 20 MW

Lucky Cement Limited – WHR Karachi – 25 MW

ICI Pakistan Limited – 37 MW

Gadoon Textile Mills Limited – 50 MW

Yunus Textile Mills Limited – 14 MW

Lucky Energy (Pvt) Limited – 16.52 MW

Al- Mabrooka Cement (Iraq) – 8 MW

Yunus Energy Limited – 50 MW (2015- E)

Total In-house power capacity – 375.52 MW

Some key strengths of the group are:

7.75 million tons per annum state of the art cement manufacturing plant in Pakistan which continues to be a Cash cow for the group

300,000 spindles with 1,050 weaving looms along with significant processing, stitching and finishing capacity within the textile sector in Pakistan

Captive power generation of 316 MW to support industrial units and under construction 50 MW wind power generation plant and 10 MW through waste heat recovery from Lucky Cement operations

Recent acquisition of ICI Pakistan Limited which is (i) a renowned brand in the local market, (ii) 2nd largest Polyester Staple Fibre producer and (iii) market leader in Soda Ash production and Life Sciences business



The use of expertise gained via Lucky Cement Limited in the Cement Manufacturing sector evident from the new planned investments in Africa and Iraq.

A special purpose company (LEPCL) has been established by Lucky Cement, bringing together a team

of highly professional people in all areas like, technical, commercial, and legal specialists with the

capability to construct, develop, operate, finance and maintain the Project. Following figure shows the

project company organization which is guided by a Board of Directors.

Figure 1.1 — Project Company Organization

All applicable national and provincial regulations will be followed by the LEPCL (Project Company) and

it will be organized and managed under an agreement that outlines reporting and budgeting

requirements and the limits of authority for its various members. The Project Company will own

finance, construct, design, and operate the facility. Development of a world class facility in terms of

safety, customer satisfaction, employee development, regulatory relations, environmental

compliance, and cost effectiveness is the project company’s governing philosophy.

The management component of the Project Company will comprised of individuals with direct

experience in development of power projects in developing countries, leading the Project through

each phase of development will be their responsibility. There will be a date-certain, lump-sum, turnkey

basis EPC Contract. It is envisioned at this time that a single EPC Contractor will be responsible for the

power plant facilities, colony, and any other facilities necessary for the generation of power.

An Operation & Maintenance (O&M) organization will be established by the Project Company for the

efficient operation and maintenance of the Project upon commissioning. The Project Company may

form this O&M organization or assigned to a third-party company. Operations including compliance to

the PPA, fuel delivery, permit, & environmental laws will be the responsibilities of O&M organization.

1.2 EIA CONSULTANT

LEPCL appointed EMC Pakistan Private Limited for conducting the Environmental Impact

Assessment (EIA) study of the Proposed Project to assess the likely environmental and social

impacts that may result from Project activities and to identify measures to mitigate negative

impacts, if any.



EMC formulated the following team of officials and experts for conducting the EIA study and preparing

the report:

Table 1.1: List of EIA Team

S. No. Name Position in Project

1 Syed Nadeem Arif Project Director

2 Saquib Ejaz Hussain ESIA Specialist / Expert on Environmental Modeling

3 Dr. Mirza Arshad Ali Beg Senior Environmentalist / Team Leader

4 Dr. Shahid Amjad Marine Biologist

5 Dr. Syed Ali Ghalib Expert on Fauna

6 Mr. Khurram Shams Khan Social Development Specialist

7 Ms. Zulekha Soorma Health & Safety Specialist

8 Ashar H. Lodi Transportation Specialist

9 Mr. S.M. Zaman Geologist

1.3 THE PROJECT

The proposed [1 x 660 MW] Lucky Electric Coal Power Project (LECPP] will be established over an area

of 250 acres of land acquired from Sindh BoR in Deh Ghangiaro, Bin Qasim Town, Karachi.

On the east, the LECPP site faces Pakistan International Bulk Terminal [PIBT] in PQA which is being set-

up for handling Coal, Cement and Clinker. On the South, the Kadiro Creek flows into Arabian Sea. The

Lath Basti is located in the west while the Bhains Colony is located at about 1 km in the North.

Figure 1.2 (a) shows the location of the proposed power plant site and Figure 1.2 (b) shows the view of

the project site.

The boiler technology shall be based on super critical boiler parameters having higher thermal

efficiency as compared to conventional pulverized coal fired units. The increase in efficiency results in

lower coal consumption as well as lower generation of ash and gaseous emissions. Coal for the power

plant will be made available through Indonesia, South Africa or Australia.

The main components of the proposed project include:

Coal Handling System including Dust Extraction and Suppression System

Steam Generator, Turbine Generator and Auxiliary Units

Cooling water system

Water & Effluent Treatment System

Fire Protection System

Air Conditioning & Ventilation System

Electrostatic Precipitators, Low Nox Burners, FGD

A 200 meters high stack

Ash Handling System with Dry Ash Extraction & Temporary Storage Facilities.

Electrical Systems: Generator Bus Duct, Transformers, Switchgears, Switch Yard etc.



Figure 1.2 (a) — Map showing LECPP Site

LECPP Site

Lath basti

Bhains

Colony

Landhi

Ind. Area

Bin

Qasim

PIBT

Port

Qasim



Figure 1.2 (b) — Pictorial view of Project Site



1.4 PROJECT BACKGROUND

1.4.1 ENERGY RESOURCES IN PAKISTAN

The economy has taken a turnaround on account of following serious economic agenda and striving

sincerely to implement it. Early positive results, particularly stabilizing foreign exchange reserves,

appreciation of exchange rate, stability in prices despite heavy adjustments, remarkable industrial

growth on account of improved energy supply, considering the strong correlation between economic

growth and energy demand growth, there is an imperative need for sustained increases in energy supply

not only to sustain the growth momentum but to protect the economy from disruptions caused by

energy deficits reflected in demand management, popularly known as load shedding.

With the commissioning of private sector Independent Power Projects (IPPs) the demand and supply of

electricity was balanced in 1997, IPPs were established under the Private Power Policy, 1994. Generation

capacity has increased since 1997, and it was expected that demand and supply would remain in

equilibrium through 2014. However, demand of electricity has been increasing due to faster economic

activity, rising disposable income, higher availability of consumer finance, double-digit growth of large-

scale manufacturing, and higher agricultural production. Therefore, the government has encouraged

the private sector to meet this additional demand.

1.4.2 CURRENT ENERGY MIX

Pakistan is producing around 36 percent from oil, 29 percent each from gas and hydroelectric and five

percent from nuclear to meet its requirements. Unlike the global practice of producing electricity

through cheapest energy sources, Pakistan is fulfilling its energy needs through expensive oil and gas-

based power plants.

The world is producing approximately 41 percent of electricity through coal, whereas Pakistan is

producing approximately seven percent electricity through coal. We produce 36 percent electricity

through the most expensive source of energy, which is oil, adding that 29 percent of electricity is

produced through gas while 29 percent is produced through hydroelectric sources.

Figure 1.3 – Primary Energy Supply by Source



1.4.3 TARGET ENERGY MIX

Government of Pakistan aims to achieve power generation mix through development of indigenous

energy resources particularly hydel and coal. The government is committed to arrange timely finances

for these projects and monitor their development regularly in order to complete them as per schedule.

It is expected that 16, 564 MW power generation will be added in the nation al grid system through

various resources by completing the new projects which will reduce/eliminate load shedding during

next four years. The detail of the project is given below:

Table 1.1 — Power Generation Plan

Year Name of Project Capacity Agency Fuel

2014

GUDDU-1 (243 MW) GENCOs Gas

Nandipur Power Project (425 MW) GENCOs Oil

Guddu-2 (243 MW) GENCOs Gas

Quaid-e-Azam Solar Park (Phase-I) (100 MW) PPDB Solar

Quaid-e-Azam Solar Park (Phase-II) (300 MW) PPDB Solar

Guddu Steam (3) (261 MW) GENCOs Gas

2015 Quaid-e-Azam Solar Park (Phase-III) (600 MW) PPDB Solar

Neelum Jhelum Hydel (969 MW) WAPDA Hydel

2016 Golen Gol (106 MW) WAPDA Hydel

Patrind HPP (147 MW) PPDB Hydel

2017 Terbela 4th Extension (1410 MW) WAPDA Hydel

Coal Plant at Sahiwal (1200 MW) PPDB COAL

2018

Coal Plant at Jamshoro (1320 MW) GENCOs COAL

Thar Coal Plant (1320 MW) GENCOs COAL

Gaddani Power Park (6600 MW) Public + Pvt COAL

Upto 2018 Total Generation Addition 16564 MW

Source: Pakistan Electric Power Company Ltd

1.4.4 PROFILE OF CURRENT ENERGY CONSUMPTION

The 6-year summary presented in Figure 1.4 reveals that there has been a decline in the use of coal

concurrent with an increase in gas, electricity and petroleum product. This structural change in the

energy consumption pattern is also assisted by the government administered price differential between

petroleum products and gas. The apparent reversal, recently, wherever there is an increase in

petroleum products usage, is most probably because of lack of alternative fuel, load shedding of gas etc,

and higher consumption of oil in agriculture sector. The is coal consumption in Pakistan also because of

its higher usage in brick kilns, a function of growing demand in the housing and other infrastructure and

conversion of about 80% of the cement industry from heavy oil to coal, but as far as power generation

is concerned it has not been used properly uptil now.



Figure 1.4 — Annual Energy Consumption by Source

The breakdown of power consumption over a 20-year period (Figure 1.5), reveals that households

continue to be the largest power consumer sector. All the other sectors have maintained their relative

share over recent years except for agriculture, which has seen its relative share decline.

Figure 1.5 — Electricity Consumption by Economic Groups (% Share)

1.4.5 CURRENT POWER SUPPLY

1.4.5.1 ELECTRICITY GENERATION

Electricity is a secondary energy source which is obtained by converting primary sources like gas, oil,

coal, nuclear power and other natural sources. There was decline in s hare of electricity in energy supply

as it declined from 15.5 percent in 1995 to 12.9 percent in 2013. The installed capacity in the PEPCO

system is 22,812 M W as of June 2013; with hydro 6,773 MW, thermal 1 5,289 MW and nuclear 750

MW. Thus the hydro power capacity accounts for 29.7 percent, thermal 67.0 percent and nuclear 3.3



percent. Of this 11,493 MW is owned by WAPDA and ex -WAPDA GENCOs, 2, 216 MW by K-Electric,

750 by PAEC, and rest by IPP s. However, one critical issue is that electricity generated is almost fifty

percent of installed capacity due to inefficient recovery system, lack of wear and tear of plants and

inappropriate fuel mix. A comparison of electricity generation during July-April for current year and last

year is shown in Figure 1.6:

Figure 1.6 – Comparative Data of Electricity Generation July-April

1.4.5.2 K-ELECTRIC (FORMERLY KESC)

The installed capacity of K-Electric various generating stations remained at 2,341 MW, compared to the

maximum demand of 2,222 MW.

In addition to the restoration of lost capacity, K-Electric plans to bring new generating plants online in

two phases. Phase I consists of the installation of a 220 MW combined-cycle power plant at Korangi, for

which K-Electric has already entered into a contract. In Phase II, K-Electric will install a combined-cycle

power plant of approximately 560 MW at the Bin Qasim Station.

K-Electric will lease Bin Qasim Power Station 1, units 3 and 4 under long-term lease agreement to K-

Energy for proposed Coal Conversion Project. K-Energy will function as an Independent Power Producer

(IPP) and will sell power to K-Electric. EPC Agreement has been signed with Harbin Electric International.

Similarly, Karachi Biogas Karachi Organic Energy Limited (KOEL) incorporated to establish a Biogas Power

Plant at Landhi Cattle Colony. The plant will utilize cattle manure and organic food waste as feedstock to

produce 22 MW of electricity in two phases (11 MW each). On the transmission and distribution side, K-

Electric will continue to implement network expansion and rehabilitation of the existing network with a

comprehensive loss-reduction program.

1.4.5.3 NUCLEAR

Pakistan Atomic Energy Commission (PAEC) is responsible for planning, construction and operation of

nuclear power plants in the country. PAEC is currently operating three nuclear power plants Karachi

Nuclear Power Plant (KANUPP), Chashma Nuclear Power Plant Unit-1 (C-1) and Unit-2 (C-2). The

construction of two more units C-3 and C-4 of 340 MW each is in progress. The second and third nuclear

power plants i.e. (C-1 and C-2) are performing very well.



The construction of fourth and fifth nuclear plants, Chashma Nuclear Power Plant unit 3 & 4 (C-3 and C-

4) at Chashma site, is ahead of the schedule. The Domes on containment buildings of C-3 and C-4 were

placed on the 6th March, 2013 and 2nd January, 2014, respectively.

Table 1.2 — Pakistan Total Installed Generation Capacity

Name of Producer Installed Capacity (MW)

2013 - 2014 Derated/Dependable Capacity

MW

Hydro (Wapda) 6,902 6,902

Hydro (IPPS) 195 195

GENCOs 4,829 3,580

IPPs 8,678 7,955

Nuclear 665 615

Wind 106 106

Total 21,375 19,353

Source: Wapda System Account

1.4.6 GOVERNMENT OF PAKISTAN POLICY, THE REGULATORY FRAMEWORK, AND THE

ENERGY SECTOR

The four main public sector organizations involved in power generation and/or transmission, and

distribution of electricity in Pakistan, WAPDA and K-Electric along with their respective IPPs, KANUPP

and CHASNUPP-controlled by the Pakistan Atomic Energy commission (PAEC). The total capacity of

Wapda is 21375 MW whereas the dependable capacity is 19353 MW in 2013 - 2014, which accounts

for 58% of the country’s total installed capacity. For WAPDA alone, hydro power accounts for 56.9% or

6,463 MW and thermal accounts for 43.1% or 4,900 MW. The total installed capacity of IPPs is 5,859

MW (30.1%), K-Electrics is 2,341 MW (10%), and nuclear power is 462 MW (2.4%) of the country’s total

installed capacity.

The private sector was allowed to enter into power generation under the 1994 Power Policy, whereby

14 IPPs were inducted into the system, in addition to the pre-1994 plants; Hubco and Kot Addu Power

Co. (Kapco), which was created through privatization.

Table 1.3 summarizes the IPPs currently in Pakistan.

Table 1.3 — List of Existing IPPs - WAPDA Only

S.# Name of Project

Technology Fuel Commercial

Operation Date

Gross Capacity

(MW)

Net Capacity

(MW)

1 KAPCO GTs, Combined

cycle, Steam Turbine

LSFO/gas/diesel 27.06.1996 1,638 1,345

2 Hubco Steam Turbines Fuel Oil 31.03.1997 1,292 1,207

3 Kohinoor

Energy Ltd Engines Fuel Oil 20.06.1997 131 124

4 AES Lalpir Steam Turbine Fuel Oil 06.11.1997 362 351

5 AES Pakgen Steam Turbine Fuel Oil 01.02.1998 365 351

6 Southern

Electric Power Engines Fuel Oil 10.03.1999 117 104

7 Habibullah

Coastal Power Combined cycle Pipeline Quality Gas 11.09.1999 140 129



Table 1.3 — List of Existing IPPs - WAPDA Only

S.# Name of Project

Technology Fuel Commercial

Operation Date

Gross Capacity

(MW)

Net Capacity

(MW)

8 Fauji Kabirwala

Power Combined cycle

Pipeline Quality and Low Btu Gas

21.10.1999 157 151

9 Rousch

(Pakistan) Power

Combined cycle Converted to Pipeline

Quality Gas 11.12.1999 450 395

10 Saba Power Steam turbine Fuel Oil 31.12.1999 134 126

11 Japan Power Generation

Engine Fuel Oil 14.03.2000 135 107

12 Uch Power Combined cycle Low Btu gas 18.10.2000 586 551

13 Altern Energy Engine Flare Gas 06.06.2001 11 5

14 Liberty Power Combined cycle Pipeline Quality Gas 10.09.2001 235 210

15 CHASNUPP Nuclear Nuclear Fuel 325 300

Total 6,078 5,456

To purchase power from IPPs WAPDA and K-Electric have entered into long-term power purchase

agreements (PPAs) with them. The PPAs are for up to 30 years from the corresponding commercial

operation dates (CODs). The PPAs are on a Build, Own, and Operate (BOO) basis or a Build, Own,

Operate, and Transfer (BOOT) basis.

WAPDA’s thermal power generation is divided into four generating companies (GENCOs). The power

plants under each GENCO are listed in Table 1.4 along with their installed and present capacities.

WAPDA’s hydro units and their installed capacities are listed in Table 1.5.

Table 1.4 — WAPDA Thermal Power Plants in each GENCO

Name of Plant Installed Capacity (MW) Present Capacity (MW)

GENCO-1 (JPCL)

TPS Jamshoro 850 649

GTPS Kotri 174 106.5

GENCO-2 (CPGCL)

TPS Guddu 1,655 1,155

TPS Quetta 35 25

GENCO-3 (NPGCL)

TPS Muzaffargarh 1,350 1,130

NGPS Multan 130 60

GTPS Faisalabad 244 210

SPS Faisalabad 132 110

GTPS Shahdra 44 30

GENCO-4 (LPGCL)

FBC Lakhra 150 120

Total 4,764 3,680 Source: WAPDA’s official Web Site *JPCL = Jamshoro Power Company Limited TPS = Thermal Power Station GTPS = Gas Turbine Power Station CPGCL = Central Power Generation Company limited NPGCL = Northern Power Generation Company Limited NGPS = Natural Gas Power Station GTPS = Gas Turbine Power Station SPS = Steam Power Station LPGCL = Lakhra Power Generation Company Limited FBC = Fluidized Bed Combustion



Table 1.5 — WAPDA Hydroelectric Power Plants

S. No. Name of Project Installed Capacity (MW)

1 Tarbela 3,478.0

2 Ghazi Barotha 1,450.0

3 Mangla 1,000.0

4 Warsak 240.0

5 Chashma 184.0

6 Malakand 20.0

7 Dargai 20.0

8 Rasul 22.0

9 Shadiwal 14.0

10 Chichoki Malian 13.0

11 Nandipur 14.0

12 Kurram Gari 4.0

13 Reshun 3.0

14 Renala 1.0

15 Chitral 1.0

16 Jagran-I 30.0

17 Kathai 2.0

18 Kundal Shahi 2.0

19 Leepa 2.0

20 Northern Area 94.0

21 Small / Micro Hydro Station 3.0

Total 6,596.0

The 1,260 MW Bin Qasim Thermal Power Plant and the 316 MW Korangi Thermal Power Station

comprises of K-Electric major generation. Whereas the shortfall is provided by the Karachi Nuclear

Power Plant, the two IPPs (Gul Ahmad Energy, Tapal Energy) and WAPDA, by diverting part of the

generation from the Hub Power Station located in the vicinity of Karachi.

The Government of Pakistan (GoP) prepared the regulatory framework under which the National

Electric Power Regulatory Authority (NEPRA) was formed in 1997 to assist the PPIB and regulate the

increasing role of the private sector in power generation. Following from the initial success of the 1994

Policy, and after settling the subsequent issues.

Especially after the amendments to the Power Policy 2002, the GoP’s focus on an increased role for the

private sector in power generation has been well received by the private sector. The private sector has

shown its interest in projects, in response to the GoP initiatives, covering the full range of power

generation technologies: gas, heavy oils, hydropower, and coal.

The GoP has decided, in principle, to leave power generation to the private sector exclusively and

withdraw from the business of power generation. WAPDA has changed its stance and is now working

on two projects as mentioned earlier, although the private sector is again taking a lead in power

generation in the hydro and coal sectors.



1.4.7 ELECTRICAL POWER SUPPLY IN PAKISTAN

1.4.7.1 FUTURE DEMAND FOR POWER

There was equilibrium between the demand and supply until about 1997, and it was assumed then that

the planned supply would meet demand until year 2014 with the arrival of the 1994 Policy IPPs. For a

variety of reasons, including rising levels of disposable income, better-than-expected economic growth,

and availability of consumer finance, the demand started to outpace supply. As of November 2013,

demand growth and other factors have resulted in some parts of Pakistan now being subjected to up to

9 hours of load shedding daily, which greatly disrupts the social and economic fabric of the society.

Due lack of investment in the power sector the Pakistani economy has been bearing the cost of demand

suppression. The GoP, through its Ministry of Water and Power (MoW&P) and the PPIB had forecasted

a demand supply gap increase to 5000 MW in 2014 up from 3500 MW from previous year. The scenario

for the years beyond also indicates a serious gap between the forecasted demand and firm supply; see

Figure 1-6. The shortfall in firm supply, which started in the 2006 with about 400 MW, was managed by

selective load shedding. The gap in 2014, which was expected to increase to about 5000 MW, actually

turned out to be around 7,000 MW because of a variety of other factors.

1.4.7.2 DEMAND FORECAST

Based on a conservative analysis and restricted electrification of non-productive sectors the projected

increase in demand is about 15% per year. Pakistan has added limited supply to the national grid in the

last 8 to 9 years. Since demand suppression is currently so acute, with practically no reserves and with

the results of power conservation measures being negligible, practically the entire burden of meeting

the gap falls on policy instruments and their appeal to investors for fresh addition to power generation

capacity. The following graph from PPIB denotes the gap that needs to be filled.

Figure 1.7 – Disparity between Firm Supply and Demand

Many plants have been inaugurated in early 2014 and are under process. Especially the imported coal-

fired plants which will be set up near the coast because of bulk import of coal.



1.4.7.3 FUTURE SUPPLY

Gas and Oil: Pakistan has exhausted more than half of the original domestic recoverable oil reserves. On

June 30, 2013, original recoverable reserves were 1,102.6 million barrels with 731.5 million barrels (68

percent) cumulative production of oil and 371.0 million barrel (32 percent) balance recoverable

reserves. Further a huge amount is paid on account of import of crude oil. The import of crude oil

remained 44.9 million barrel during July-March FY 14 compared to 40.9 million barrels in corresponding

period last year posting a growth of 11 percent while local crude extraction posted a growth of 12

percent as it stood at 23.0 million barrels in July-March FY 14 compared to 20.5 million barrels in

corresponding period last year. Pakistan has not had a major discovery of fossil fuels for quite some time.

Pending such a strike, therefore, it has to look elsewhere for feedstock.

The high price of oil also makes it an expensive feedstock for power generation. As a result of the recent

severe power shortages, however, the GoP has agreed to several heavy-fuel-oil-fired, engine based,

combined-cycle IPPs, in the size class of 200 MW, which can at best be interpreted as a stopgap measure

(because it will further deteriorate the cost structure of the off taker in the years to come). Clearly, the

system needs cheaper and, perhaps, renewable energy sources to balance out the cost of operating

aging gas- and oil-fired units as base load plants. That leaves hydropower and coal as the only serious

candidates. Although wind and solar energy could also figure prominently in the energy mix, wind- or

solar-generated power has yet to be delivered.

Hydropower: Pakistan has a huge potential of hydropower compared to the known hydrocarbon

resources, excluding coal. It is estimated that Pakistan has the potential to generate 41,000 MW from

its hydro endowment. However, the large projects are costly, have long gestation periods, and need

huge environmental and political groundwork done.

Pakistan is an agro-based country and majority of its population lives off agriculture and the rivers cross

over from one province into another, thus complicating the issues related to water rights and its usage.

There are two existing multipurpose dams, Tarbela and Mangla, whose primary aim is to store excess

summer flows for winter crops, leaving little potential for power generation during low-water-use

months in winter, which complicates the supply situation during those months. Ghazi Barotha is a Run

of the River hydel project downstream of Tarbela Dam and as such is totally dependent on water

releases from Tarbela. Pakistan have to face two major issues in winter months one is the natural gas;

because of a surge in domestic demand for heating, is less available for power generation, and low water

releases drive down hydro power generation drastically. This drop in supply is currently large enough,

despite the decrease in electricity demand, to cause load shedding.

WAPDA has entered into an agreement with a Chinese firm to build Neelum Jhelum Dam on River

Neelum in Azad Jammu and Kashmir to generate around 969 MW at a cost of about USD 2.1 billion.

Work has already begun and the project is expected to come online in about few years. Similarly Golen

Gol Hydropower Project which will contribute 106 MW and will be completed by 2015, the Patrind

hydro power plant in Muzaffarabad Azad Kashmir will produce 150 MW and is to be completed by 2016,

the major project up till now is the Diamer Basha dam and is to be completed in 12 years.

Coal: GoP has now taken major steps to open up the coal sector for power generation to bridge the

demand and supply gap and to address the long-term consequences of depending on costly imports.

The strategy aims at dramatically increasing coal use with import-based, coal-fired plants in tandem with

a few local plants. The current share of coal in the energy mix is 7% which GoP has planned to increase



to about 19% by generating about 20,000 MW and more beyond 2030. This increased use will, in large

part, be achieved by exploiting Thar coal reserves.

Coal resources estimated at Thar coalfield in the Sindh province is estimated to be 175 billion tonnes.

Approximately 80% of cement industry has also switched over from furnace oil to indigenous coal. The

demand for coal has increased from 2.5 to 3.0 million tonnes per year due to conversion of the cement

industry from furnace oil to coal.

Due to existing mining and transportation capabilities to coastal based coal-based power plants the coal

sector currently is not in a position to supply large quantities of coal. Sizeable amounts of capital

investment are needed before coal mining operations can become credible partners to coal-fired plants.

In fact, the Pakistan coal sector currently has virtually no mechanized mining.

However, the government decided to begin processing proposals submitted by private companies to

set up 10 coal-based power projects having a total capacity of 4,250 MW in different provinces.

1.4.7.4 THE ROLE OF IMPORTED COAL

To utilize the coal at Thar field has been the main consideration of GoP since several years. However,

past plans to implement these projects have not materialized. The cost to set up a coal mine in Thar for

feeding a 1,000 MW plant is reportedly quoted at about USD 1 billion. There have been water availability

issues for which solutions are being investigated.

These issues are still being evaluated and a political consensus and method of operation are developed

among the various arms of the governmental structure in Pakistan. However, Engro Power Gen Limited

completed a feasibility study of a coal mining project that aims to supply coal to a 1,200 MW Power

Plant at Thar field, similarly the Sindh Engro Coal Mining Company is expected to commence commercial

operations by the year 2016. But still need for power continues to become more severe. The economy

cannot wait for a resolution of all these issues. As a result, the decision was made to proceed with coal-

fired power plants using imported coal. The other option would be more RFO-fired plants, which uses

higher-cost fuel. Imported coal-based power plants will introduce the scale and technology of modern

coal plants and will provide a basis for the next wave of coal-based plants.

Furthermore, imported coal-based plants may be able to support local coal mines by means of blending

their product with imported coal.

1.4.7.5 NUCLEAR ENERGY

The implementation of Pakistan’s nuclear power program is the responsibility of PAEC. Two nuclear

power plants—KANUPP and CHASNUPP Unit 1 are in operation presently, and a third plant, CHASNUPP

Unit 2, is under construction. The designed life of KANUPP has been completed which was 30 years and

now it is operating on extended life. CHASNUPP 1, with a gross capacity of 325 MW, will be augmented

with the under-construction CHASNUPP 2, with a gross capacity of 330 MW. GoP has set a target of

8,800 MW nuclear power capacity by the year 2030, with increasing share of indigenization. Similarly,

Pakistan is in the process of selecting eight sites for the installation of 32 nuclear power plants, which

will generate a total of 40,000 MW electricity, according to Pakistan Atomic Energy Commission (PAEC).



Table 1.6 – Performance of the Operating Nuclear Plants in Pakistan

Plants Gross Capacity (MW) Grid Connection Data

KANUPP 100 18-Oct-71

C-1 325 13-Jun-00

C-2 330 14-Mar-11

Source: Pakistan Atomic Energy Commission

Table 1.7 – Status of Under Construction Nuclear Power Plant

Plants Gross Capacity (MW) First Concrete Pour Date Target Commercial Operation Date

C-1 340 4-Mar-11 30-Apr-16

C-2 340 18-Dec-11 31-Dec-16

Source: Pakistan Atomic Energy Commission

1.4.8 TRANSMISSION NETWORK

The entity responsible for carrying out the design, construction, maintenance, and operation of the grid

system, consisting of transmission lines and grid stations throughout the country, except for the KESC

area is National Transmission & Dispatch Company (NTDC). NTDC’s creates one of the world's largest

contiguous grid systems which includes transmission network links generating stations and load centers

of the entire country. The national grid, connecting hydro generation in the north and thermal

generation in mid-country and the south, consists of a large network of transmission lines and grid

stations to transmit power to load centers throughout the country. This system consists of 615 grid

stations from 500 kV down to 66 kV and 44,030 circuit kilometres of transmission lines (including 500

kV, 220 kV, 132 kV, and 66 kV). The distribution to large loads is at 33 kV and 11 kV; ordinary consumers

are supplied electricity at 415 V.

NTDC’s Power Transmission Lines system is interconnected through a national grid that extends power

from Peshawar to Karachi-Quetta and Azad Kashmir linking all important cities of the country. Details of

the existing transmission network, grid stations and new transmission line are given in the following

tables:

Table 1.8 – Length of Transmission Lines under GM (GSO) as of 31 March 2005

Type of Line 500 kV 220 kV 132 kV 66 kV Total

Double Circuit 0 2921 9755 523 13,199

Single Circuit 4350 287 7851 6408 18,896

Single Circuit on D/C 0 0 320 0 320

Towers (SDT) 0 0 0 0 -

Total 4350 3208 17925 6931 32,415 Source: Wapda (http://www.wapda.gov.pk/htmls/ptransmission-index.html)

Table 1.9 – Grid Station Data under GM (GSO) as of 31 March 2005

Region 500 kV 220 kV 132 kV 66 kV 33 kV Total Consumers Grid

Lahore 1 7 104 21 0 133 0

Islamabad 2 5 107 41 9 164 0

Multan 3 7 112 66 1 189 0

Hyderabad 3 3 76 36 0 124 0

Quetta 0 2 42 9 1 54 0

Total 9 24 441 173 11 29 Source: Wapda



Table 1.10 – 500 kV Transmission Line: Existing

S. No. Region Route (km)

1 Tarbela - Faisalabad (1st Circuit) 330

2 Faisalabad - Multan - Guddu - Karachi 957

3 Tarbela - Faisalabad (2nd Circuit) 327

4 Lahore - Multan - Jamshoro 1075

5 Tarbela - Peshawar 117

6 Tarbela - Lahore (3rd Circuit) 347

7 3rd 500-kV Jamshoro - Guddu - Multan and 2nd Multan - Gatti - Lahore 630

8 First Hub - Jamshoro 182

9 Second 500-kV Line Hub - Jamshoro 181 Source: WAPDA (http://www.wapda.gov.pk/htmls/ptransmission-index.html)

However, the future T/L Development programme from Karachi to up country is provided in the

following table:

Table 1.11 – The Future T/L Development Programme from Karachi to Up Country

Grid St: New

500 kV T/L No of Ckts

T/L length

Expected year of commissioning

Gaddani Gaddani-Gaddani power park 6 20 2017-18

HUBCO-Jamshoro Ckt In/Out at Gaddani 2 30 2017-18

600 KV HVDCT/L from Gaddani to Lahore south 1200 2017-18

Gaddani-Gaddani Power Park 4 20 2018-19

Gaddani-Matiari 2 180 2018-19

600 KV HVDCT/L from Gaddani to Faisalabad West 1100 2018-19

Bin Qasim Coal Power Plant-Matiari In/Out at K-2/K-3

2 5 2019-20

600 KV HVDCT/L from Matiari to Lahore South 1000 2019-20

1.5 OBJECTIVES OF PROJECT

The main objective of the proposed Project is to respond to the Energy Policy 2013 which has set the

goals at 1) “Ensuring the generation of inexpensive and affordable electricity for domestic, commercial,

and industrial use by using indigenous resources such as coal (Thar coal) and hydel”, 2) adopt such

strategy that meets this goal and also focuses on shifting Pakistan’s energy mix towards cheaper fuel

and conservation of gas for power, and 3) utilize coal for power generation and thus provide energy

security to the Country.

The main objectives of the Project are to:

Respond to the urgent need to close the yawning gap between power generation and demand.

Provide an economically viable and environmentally acceptable power generation system to make the coal available for use in power production, in view of the wide gap between supplies of fossil fuel and demand,

Ensure stable power production system for the Country

Respond to the need of improvement in quality of life through sustainable Energy Resource development.

http://www.wapda.gov.pk/htmls/ptransmission-index.html



1.6 NEED FOR EIA

Burning of coal has to address the environmental, social and economic aspects of sustainability.

Accordingly an Environmental Impact Assessment Study is carried out to address the environmental and

social aspects of the Project and to share information on the likely impacts with all stake holders.

The purpose of EIA Study is to respond to the mandatory requirements of Section 17 of Sindh

Environmental Protection Act (SEPA) 2014, which demands an initial environmental examination (IEE)

or an environmental impact assessment (EIA) to be carried out before commencement of Project

activity and the report to be submitted to Sindh Environmental Protection Agency to review and issue

decision in light of the Project findings and recommendations.

1.7 OBJECTIVES OF EIA

The main purpose of this EIA Study is to provide and analyse information on the nature and severity of

environmental aspects of the above issues and propose mitigation measures in case of negative impacts

arising from the construction and operation of the project and related activities that would take place

concurrently or subsequently. The EIA study will in fact respond to the provision of Sindh Environmental

Protection Act 2014 and its associated rules and regulations. Wherever needed, referenced is made to

international best practice which includes, for e.g. the International Finance Corporation (IFC)

Environmental Health and Safety Guidelines 2007.

Accordingly the purpose of EIA study is to evaluate the physical, biological, and socioeconomic impact

of the following:

Construction at site and installation of the coal fired boiler at proposed site

In-country coal transportation to the site

Coal Storage Area

Operation of the new boiler

Ash disposal activities

Ash Pond development and operation

The Study will

Identify all major and minor impacts, negative as well as positive, on the environment during its different stages viz. pre-construction, construction & operation of Power Project

Propose mitigation measures for negative impacts through specified design and construction procedures

Identify Socioeconomic aspects, and

Devise Environmental Management Plan (EMP) for sustainable operation of the Project

This EIA report has been prepared after identifying the environmental aspects and screening the

potential impacts to ensure that the proposed activities pertaining to installation and commissioning of

the boiler are environment friendly and evaluated through environmental assessment carried out in

accordance with applicable laws and regulations of Sindh Environmental Protection Act 2014.



1.8 CATEGORIZATION OF PROJECT

The Sindh Environmental Protection Act, 2014 and Sindh Environmental Protection Agency (Review of

EIA/IEE) Regulations 2014 clearly define Schedules (I & II) of projects falling under the requirement of

EIA or IEE. As per Schedule II (List of projects requiring an EIA), A. Energy-3. Coal Power Projects over 50

MW, the proposed Power Production Project will require an Environmental Impact Assessment (EIA)

study to be undertaken.

1.9 METHODOLOGY

This environmental impact assessment was conducted in the following manner:

1.9.1 SCOPING

A scoping exercise was undertaken to identify the potential issues that are to be considered in the

environmental impact assessment.

Figure 1.8 – Consultation with Primary and Secondary Stakeholders

The scoping exercise included the following tasks:

Data Compilation: A generic description of the proposed activities relevant to this environmental assessment was compiled with the help of the Project proponent.

Review of Published literature: Secondary data on climate, soil, water resources, wildlife and vegetation were reviewed.

Review of applicable Legislation: Information on relevant legislation, regulations, guidelines, and standards was reviewed and compiled.

Identification of potential impacts: The information collected in the above procedures was reviewed and potential environmental issues identified.

Initial site visit: An initial site visit was conducted to get an overview of site conditions and the surrounding areas.

Stakeholder consultation: A stakeholder consultation was undertaken to document the concerns of the local community and other stakeholders, and to identify issues that may require additional assessment in order to address these concerns.



1.9.2 BASELINE DATA COLLECTION

Detailed environmental baseline surveys were conducted to collect primary data on the Project Area to

help identify sensitive receptors. The primary data were examined and compared with secondary data

available from earlier environmental studies in the region.

Figure 1.9 – Primary Data Collection by EIA Study Team

1.9.3 IDENTIFICATION OF ASPECTS

Identification of environmental aspects and their significance is fundamentally important for

determination of severity of incidence of impacts at different stages of the project. This step is aimed at

obtaining an inventory of the aspects. The aspects identified during this step cover all activities during

construction, installation and operation, in order to determine those which have or can have significant

impact on the environment. The aspects that were covered during the surveys included:

Community and socioeconomic indicators

Air quality

Traffic

Sensitive receptors

Marine ecology

Water quality, and

Soil.

1.9.4 IMPACT ASSESSMENT & EMP

Environmental experts at EMC analyzed and assessed the anticipated impacts that are likely to arise due

to the identified aspects. Each of the potential impacts identified during the scoping session was

evaluated using the environmental, socioeconomic, and project information collected. Air quality

Modeling was undertaken to forecast the impact of gaseous emissions. In general, the impact

assessment discussion covers the following aspects:

Present baseline conditions

Potential change in environmental parameters likely to be affected by Project- related activities

Prediction of potential impacts



Evaluation of the likelihood and significance of potential impacts

Defining of mitigation measures to reduce impacts to as low as practicable

Prediction of any residual impacts, including all long- and short-term, direct and indirect, and beneficial and adverse impacts

Monitoring of residual impacts.

An environmental management plan (EMP) was developed to oversee the environmental performance

of the project and adoption of proposed mitigation measures. A monitoring plan has also been

incorporated in the EMP to monitor impact of all activities and performance of mitigation measures and

to identify the residual impact if any, and also the positive/negative changes in the physical, and

socioeconomic environment.

1.9.5 DOCUMENTATION & REVIEW

This is the final step of the EIA study. The data generated during and for the study are compiled and

examined by experts of the respective field. Sections of this report were prepared as the study

progressed, by EMC office staff in consultation with experts. The report was finally reviewed by Team

Leader, who analyzed the information, assessed the potential environmental impacts in the light of

national and international guidelines, examined the alternatives in the light of observations on the field

as well as meetings with the stakeholders, before organizing the Report in the present form.

1.10 STRUCTURE OF THE EIA REPORT

The EIA report has been structured on the standard format, prescribed by the Sindh EPA. The Report

has been presented in the following sections:

Section 1 - Introduction

Section 2 - Policy, Legal and Regulatory Framework

Section 3 - Description of Project

Section 4 - Screening of Alternatives

Section 5 - Environmental and Social Baseline

Section 6 - Screening of Potential Environmental Impacts and Proposed Mitigation Measures

Section 7 - Consultation and Information Disclosure

Section 8 - Environmental Management and Monitoring Plan

Section 9 - Conclusion



2.0 POLICY, LEGAL & REGULATORY FRAMEWORK

This section deals with current legal responsibilities of the project proponent in the context of the

environment and sustainable development and the institutions which exist in the country that may

influence the environmental management of the proposed project. Pakistan is also signatory to a

number of International environmental conventions which have been ratified by the government. In

carrying out this Environmental Assessment, relevant international guidelines have duly been followed.

Lucky Electric Power Company Limited (LEPCL), the proponent of this project will comprehensively

follow the relevant requirements of policy documents, legislative framework and recommendations in

national and international guidelines and all applicable laws. Mitigation measures that have been

proposed in the light of relevant guidelines will be integrated in the Environmental Management Plan

(EMP) which has been formulated for the better management of environmental as well as social aspects

and for any residual impacts.

2.1 NATIONAL POLICY FRAMEWORK

2.1.1 NATIONAL CONSERVATION STRATEGY

Government of Pakistan approved the National Conservation Strategy in March 1992 which later

became the principle document for addressing environmental issues in the country. It has 68 specific

programs in 14 core areas in which policy intervention is considered crucial for the preservation of

Pakistan's natural and physical environment. The core areas that are relevant to the proposed project

are biodiversity conservation, restoration of rangelands, pollution prevention and abatement and the

preservation of cultural heritage.

2.1.2 BIODIVERSITY ACTION PLAN

Pakistan is a signatory to the Convention on Biological Diversity and is thereby obligated to develop a

national strategy for the conservation of biodiversity. The Government of Pakistan constituted a

Biodiversity Working Group, under the auspices of the Ministry of Environment, to develop a

Biodiversity Action Plan for the country, which was completed after an extensive consultative exercise

in 2000.

The plan, which has been designed to complement the NCS and the proposed provincial conservation

strategies, identifies the causes of biodiversity loss in Pakistan and suggests a series of proposals for

action to conserve biodiversity in the country. Pakistan Environmental Protection Council (PEPC) has

approved the action plan and steering committees at the federal and provincial levels have been formed

to implement it.

2.1.3 NATIONAL POWER POLICY 2013

The Ministry of Water and Power has developed Power Policy to support the current and future energy

needs of the country and to set Pakistan on a trajectory of rapid economic growth and social

development. It will also address the key challenges of the power sector in order to provide much

needed relief to the citizens of Pakistan. To achieve the long-term vision of the power sector and

overcome its challenges, following nine goals have been set:

Build a power generation capacity that can meet Pakistan’s energy needs in a sustainable manner.



Create a culture of energy conservation and responsibility

Ensure the generation of inexpensive and affordable electricity for domestic, commercial, and industrial use by using indigenous resources such as coal (Thar coal) and hydel

Minimize pilferage and adulteration in fuel supply

Promote world class efficiency in power generation

Create a cutting edge transmission network

Minimize inefficiencies in the distribution system

Minimize financial losses across the system

Align the ministries involved in the energy sector and improve the governance of all related federal and provincial departments as well as regulators

The main targets of this Policy for year 2017 are:

To fully eliminate load shedding;

To decrease cost of generation from 12c/unit to 10c/unit

To decrease transmission losses from 25% to 16%

To improve collection of bills to 95%

Pertaining to the acute deficit of electricity, the government is taking long-term steps in trying to alleviate

this deficit. The current project is absolutely necessary to take shape in order to achieve these national

targets.

2.1.4 NATIONAL FOREST POLICY 2010

The National Forest Policy aims at establishing a framework for sustainable management of forests and

allied resources including biodiversity, watersheds and wildlife. One of the key objectives of this policy is

to protect mangrove forests. Mangrove forests are vital for protecting coastal belt as it is a habitat for

fish nurseries and shrimp, which are a source of food and help in export earnings. These forests are

threatened by marine pollution, scarcity of fresh-water flowing down the Indus delta, and over-use by

the local communities for fuel wood and fodder.

In line with this policy, LEPCL will take every step to ensure that no harm is done, what-so-ever, to any

mangrove plant by the construction and operation of the proposed power plant. Further, LEPCL shall

replant mangrove trees.

2.1.5 NATIONAL ENVIRONMENTAL POLICY 2005

The objectives of this policy are to:

conserve, restore and manage the environmental resources of the Pakistan

integrate policy making and planning with environmental considerations

capacity building in government for environmental management

meet international obligations while keeping national aspirations

The policy articulates sectorial guidelines for the following areas in order to achieve its objectives:

Water supply management



Air quality and noise

Waste management

Forestry

Biodiversity and protected areas

Climate change and ozone depletion

Energy efficiency and renewables

Agriculture and livestock

Multilateral environmental agreements

Besides these areas, the policy also takes on a multidisciplinary approach towards tackling the difficult

issues of poverty, population, gender inequality, health, trade, local governance & their interconnection

with environment by presenting cross-sectorial guidelines for each.

2.1.6 NATIONAL CLIMATE CHANGE POLICY

The National Climate Change Policy provides a framework for addressing the issues that Pakistan faces

or will face in future due to the changing climate. The main objectives of Pakistan's climate change policy

include:

To pursue sustained economic growth by appropriately addressing the challenges of climate change;

To integrate climate change policy with other interrelated national policies;

To focus on pro-poor gender sensitive adaptation while also promoting mitigation to the extent possible in a cost effective manner;

To ensure Water Security, Food Security and Energy Security of the country in the face of challenges posed by climate change;

To minimize the risks arising from expected increase in frequency and intensity of extreme weather events: floods, droughts, tropical storms etc.;

To strengthen inter-ministerial decision making and coordination mechanism on climate change;

To facilitate effective use of the opportunities, particularly financial, available both nationally and internationally;

To foster the development of appropriate economic incentives to encourage public and private sector investment in adaptation measures;

To enhance the awareness, skill and institutional capacity of relevant stakeholders;

To promote conservation of natural resources and long term sustainability.

2.1.7 NATIONAL STRATEGY AND ACTION PLAN FOR MANGROVES FOR THE FUTURE (2010)

MFF National Strategy and Action Plan (NSAP) will support the development vision of the Government

of Pakistan and associated policies as they relate to sustainable use and management of coastal

ecosystems and adaptation to climate change in the context of integrated coastal management. The

NSAP does not solely focus mangrove forests but entails mangrove ecosystem and associated

biodiversity, thus the term ‘mangrove’ is used as a symbolic label. Pakistan’s NSAP specifically addresses



and treats issues related to the dominant coastal ecosystems viz mangroves, estuaries turtle nesting

beaches and coral reef. NSAP Pakistan will contribute towards ecosystem-based integrated coastal

management (ICM) and its goal would be to improve the quality of life of dependent communities. ICM

by its inherent nature requires actions at local geographic sites - both entire ecosystems and parts

thereof.

The NSAP conforms to Government of Pakistan’s basic requirement of good governance and

community participation in development programmes. It builds on the principles that a central body

(NCB) should perform only those tasks which cannot be performed effectively at a more immediate or

local level. However at local level Programme of Works (PoW) will be implemented by different

organizations under the guidance of NCB. The NSAP follows a cross sectoral collaborative approach in

harmony with other policies and programmes of development sectors including climate change

mitigation and adaptation policy.

In the context of challenges to the coastal areas of Pakistan, the NSAP paves the way for development

of ICM programme for Pakistan to ensure good governance, knowledge management, community

empowerment, and public-private partnership (sustainable financing) by:

Setting up ICM models in selected coastal ecosystems

Scaling up the successful models at the entire coastal belt

2.1.8 NATIONAL DRINKING WATER POLICY

The policy aims to improve access to clean drinking water through various initiatives. Coal-fired thermal

power plant use water for cooling, and environmental standards are needed to ensure that the water

being released is safe for human consumption. National drinking water policy provides guidance to

utilization and use of drinking water through appropriate means.

2.2 THE 18TH AMENDMENT IN CONSTITUTION OF PAKISTAN

Prior to the 18th Amendment to the Constitution of Pakistan in 2010, the legislative powers were

distributed between the federal and provincial governments through two 'lists' attached to the

Constitution as Schedules. The Federal list covered the subjects over which the federal government had

exclusive legislative power, while the 'Concurrent List' contained subjects regarding which both the

federal and provincial governments could enact laws. The subject of 'environmental pollution and

ecology' was included in the Concurrent List and hence allowed both the national and provincial

governments to enact laws on the subject. However, as a result of the 18th Amendment this subject is

now in the exclusive domain of the provincial government.

As a result, the Ministry of Environment at the federal level has been abolished. Its functions related to

the national environmental management have been transferred to the provinces. The international

obligations in the context of environment will be managed by the Ministry of Climate Change.

2.2.1 SINDH ENVIRONMENTAL PROTECTION AGENCY

The Department of Environment, Forest and Wildlife is a newly formed department of the Government

of Sindh. Sindh EPA operates under this department. It is a monitoring and regulating agency with the

following main functions:



enforcing SEPA 2014

enforcing NEQS

implementing the Self-Monitoring and Reporting Tool (SMART)

implementing the Review of IEE and EIA Regulations 2000

coordinating for pollution prevention and abatement measures between government and non-governmental organizations

assisting provincial and local governments in implementation of schemes for proper disposal of wastes to ensure compliance with NEQS

undertaking measures to enhance awareness on environment among general public

conducting research and studies on different environmental issues

attending to public complaints on environmental issues

carrying out any other task related to environment assigned by the government

Sindh EPA is mandated to review and issue decision on the EIA of the LEPCL power plant.

2.2.2 SINDH ENVIRONMENTAL PROTECTION ACT 2014

As described above, because of the eighteenth amendment of the constitution of Pakistan in 2010, the

Ministry of Environment fell under the Federal Government as in the schedule attached with the

constitution. After the said amendment, the Provincial Governments were given the exclusive right to

make their own laws. It was expected that provinces will formulate their own laws suited to their own

needs. In March of 2014, the Government of Sindh passed Act No. VIII of 2014.

This act is applicable to a broad range of issues that extends to air, water, industrial liquid effluent,

marine, and noise pollution as well as to the handling of hazardous wastes. The applicable sections of

the act to this project are:

Section 11(1): Subject to the provisions of this Act and the rules and regulations, no person shall

discharge or emit or allow the discharge or emission of any effluent, waste, pollutant, noise or any

other matter that may cause or likely to cause pollution or adverse environmental effects, as defined

in section 2 of this Act, in an amount, concentration or level which is in excess to that specified in

Sindh Environmental Quality Standards; or, where applicable, the standards established under

Section 6(1)(g)(i); or direction issued under Section 17, 19, 20 and 21 of this Act; or any other

direction issued, in general or particular, by the Agency.

The proposed project shall comply with all applicable standards. Comprehensive and appropriate

control measures will be incorporated in the design of the project such as Flu Gas Desulphurization

(FGD), waste water treatment plant and low NOx burners. Environmentally safe disposal and

recycling of Ash will also be undertaken.

Section 11(2): All persons, in industrial or commercial or other operations, shall ensure compliance

with the Environmental Quality Standards for ambient air, drinking water, noise or any other

Standards established under section 6(1)(g)(i); shall maintain monitoring records for such

compliances; shall make available these records to the authorized person for inspection; and shall

report or communicate the record to the Agency as required under any directions issued, notified

or required under any rules and regulations.



NEQS which have been established for gaseous emission, liquid effluent, ambient air quality, noise,

and drinking water shall be adequately followed. Besides, a Continuous Emissions Monitoring

System (CEMS) is also proposed to continuously monitor all critical gaseous emissions.

Section 11(3): Monitoring and analysis under sub-section (1) and (2), shall be acceptable only when

carried out by the Environmental Laboratory certified by the Agency as prescribed in the rules.

All stipulated tests will be regularly performed from designated laboratories approved by Sindh EPA.

Section 12: No person shall import hazardous waste into Sindh province or its coastal, internal,

territorial or historical waters, except acquiring prior approval of the Agency.

The coal which shall be imported will be free of any radioactivity. No hazardous material will be

imported.

Section 13: Subject to the provisions of this Act, no person shall import, generate, collect, consign,

transport, treat, dispose of, store, handle or otherwise use or deal with any hazardous substance

except- Handling of hazardous substances. (a) under a license issued by the Agency; or (b) in

accordance with the provisions of any other law, rule, regulation or notification for the time being

in force, or of any international treaty, convention, protocol, code, standard, agreement or other

instrument to which Government is a party.

Any hazardous waste generated during construction and operational phase of the project will be

handled only after obtaining a license from Sindh EPA and proper SOPs will duly be developed.

Section 17(1): No proponent of a project shall commence construction or operation unless he has

filed with the Agency an initial environmental examination or environmental impact assessment,

and has obtained from the Agency approval in respect thereof.

The EIA of the proposed Project will be submitted to the Sindh Environmental Protection Agency

(EPA) for approval and only after the issuance of NOC will the construction activity be commenced.

Section 17(3): Every review of an environment impact assessment shall be carried out with public

participation and, subject to the provisions of this Act, after full disclosure of the particulars of the

project.

Section 31(1): The Agency shall cause relevant details of any proposed project regarding which an

Environmental Impact Assessment has been received to be published, along with an invitation to

the public to furnish their comments thereon within a specified period. (2) In accordance with such

procedure as may be prescribed, the Agency shall hold public hearings to receive additional

comments and hear oral submissions. (3) All comments received under sub-sections (1) and (2) shall

be duly considered by the Agency while reviewing the environmental impact assessment or

strategic impact assessment, and decision or action taken thereon shall be communicated to the

persons who have furnished the said comments.

The Sindh EPA will organize public hearing for the proposed project.

2.3 SINDH WILDLIFE PROTECTION ORDINANCE 1972 AND AMENDMENTS 2001

The ordinance aims for the protection, preservation and conservation of wildlife and also lays the

grounds for declaring an area under protected status such as a wildlife sanctuary, national park or a

game reserve. It restricts all form of dealing in animal trophies or meat or any product derived from



wildlife without a license to do so. The protected species which the act specifically addresses are listed

in the attached second schedule at the end of the act.

The proposed area for the installation of LEPCL power plant lies within a designated industrial area of

Port Qasim Authority. The project site is located outside of any wildlife protected area therefore the

project will not contravene with any provisions of this Act.

2.4 SINDH FISHERIES ORDINANCE 1980

This ordinance mainly regulates fishing in any public waters for any purpose. The regulated waters

include the coastal areas and rivers. The section 8 of this ordinance specifically prohibits the dumping

of untreated industrial or domestic sewage waste into a water body in Sindh, unless treated and made

harmless for fish and other aquatic life.

The proposed project will not release any harmful and untreated effluent in any water body, hence

fulfilling the stipulated requirement.

2.5 SINDH FOREST ACT 1927

The act empowers the provincial forest departments to declare any forest area reserved or protected.

The act also empowers the provincial forest departments to prohibit the clearing of forests for

cultivation, grazing, hunting, removing forest produce, quarrying, felling, and lopping. Some vegetation

clearing will be required in the site preparation for the power plant, but since the area is not declared as

a reserve forest this law will have no implication on the project.

The Sindh Forestry Department manages official forestry reserves and has expressed concern about the

level of woodcutting, camel breeding which has taken place in the area. IUCN, Engro Polymer Chemical

Pakistan Ltd, EVTL as well as FOTCO have undertaken plantation of mangrove trees in a systematic

manner and their experience will ensure that the mangroves are conserved/replanted.

Adoption of Conservation practices has been demonstrated at several sites, for e.g. Jhari Creek, where

the Rhizophora species has been introduced at the water line. Similar practices will be adopted at the

proposed project site at the pre-construction and construction stages.

2.6 THE FACTORIES ACT 1934

This act relates to the health and safety of the workers of a factory or an industrial establishment,

employing ten or more than ten workers. The following are the applicable sections which relate to this

project during the construction phase:

Section 13: Workplace should be kept clean and free from effluvia arising from any drain, privy or

other nuisance.

Section 14(2): Where gas, dust or other impurity is generated in the course of work, adequate

measures shall be taken to prevent injury to the health of workers.

Measures will be in place to control any dust emission both during and after construction. An

engineered stack will be built to keep harmful gases away from everyone.

Section 19(1): In every factory a sufficient supply of water fit for drinking shall be provided for the

workers at suitable places.



Safe drinking water will be available to everyone as an RO plant is also in plan.

Section 19(3): In every factory, a sufficient supply of water suitable for washing shall be provided for

the use of workers, at suitable places and with facilities for its use, according to such standards as

may be prescribed.

Section 20: Sufficient latrines and urinals, according to the prescribed standards, shall be provided,

for male workers and for female workers separately, of suitable patterns and at convenient places

as prescribed, and shall be kept in a clean and sanitary condition during all working hours.

All basic sanitation facilities shall be provided to all workers.

Section 26(1): Safety of buildings and machinery. If it appears to the Inspector that any building or

part of a building or any part of the ways, machinery or plant in a factory is in such a condition that

it is dangerous to human life or safety, he may serve on the manager of the factory an order in

writing specifying the measures which in his opinion should be adopted, and requiring them to be

carried out before a specified date.

Section 26(2): If it appears to the Inspector that the use of any building or part of a building or of any part

of the ways, machinery or plant in a factory involves imminent danger to human life or safety, he may

serve on the manager of the factory an order in writing prohibiting its use until it has been properly

repaired or altered.

The proponent is obliged to abide by all of the injunctions presented in this act that apply to this project.

The applicable sections have been mentioned above.

2.7 LAND ACQUISITION ACT (LAA) 1984

The 1894 Land Acquisition Act (LAA) with its successive amendments is the main law regulating land

acquisition for public purpose in Pakistan. The LAA has been variously interpreted by local governments,

and some province has augmented the LAA by issuing provincial legislations. The LAA and its

Implementation Rules require that following an impacts assessment/valuation effort, land and crops are

compensated in cash at market rate to titled landowners and registered land tenants/users,

respectively.

The LAA mandates that land valuation is to be based on the latest 3 years average registered land sale

rates, though, in several recent cases the median rate over the past year, or even the current rates, have

been applied. Due to widespread land under-valuation by the Revenue Department, current market

rates are now frequently used with an added 15 per cent Compulsory Acquisition Surcharge as provided

in the LAA.

1) Based on the LAA, only legal owners and tenants registered with the Land Revenue Department or

possessing formal lease agreements are eligible for compensation or livelihood support.

2) It is also noted that the LAA does not automatically mandate for specific rehabilitation/assistance

provisions benefiting the poor, vulnerable groups, or severely affected PAPs, nor it automatically

provides for rehabilitation of income/ livelihood losses or resettlement costs. This however it is often

done in many projects in form of ad hoc arrangements based on negotiations between a specific EA and

the PAPs.



3) Exceptions to the rule are intrinsic to the fact that the law is elastic and are broadly interpreted at

provincial level depending on operational requirements, local needs, and socio-economic

circumstances. Recourse is often taken to ad hoc arrangements, agreements and understandings for

resettlement in difficult situations. The above is also influenced by the fact that an amendment of the

LAA has been considered necessary by the Ministry of Environment. Accordingly, a National

Resettlement Policy (NRP) and a Resettlement Ordinance have been drafted to broaden LAA provisions

and current practices so as to widen the scope of eligibility and tightening up loopholes (i.e. regarding

definitions of malpractices, cut-off dates, political influence on routing, etc.). But both these documents

are still awaiting government’s approval for implementation.

The Act would apply for all the situations during the project when land area for the purpose of the

project is needed to be acquired.

2.8 PORT QASIM AUTHORITY ACT 1973 (AMENDMENTS 2002)

This Act provides for the establishment of the Port Qasim Authority, defines its functions, powers and

internal organization and lays down rules relative to management of and navigation in marine ports and

inland waterways ports. The particular sections applicable to the Project are:

Section 71(B)(2) No Owner, Agent or Master of a vessel, or any industry, manufacturing

establishment, mill, factory or any kind, cargo handling company, terminal operator, etc.,. shall

discharge any solid or liquid, waste, oily, noxious radioactive and hazardous substances, bilge

discharges, residues and mixtures containing noxious solid and liquid wastes, de-blasting of un-

washed cargo tanks and line washing, garbage, emission of any effluent or waste or air pollution or

noise in any amount concentration or level in excess of the National Environmental Quality

Standards, or standards, which may be specified, from time to time, by the Authority for Port limits.

No wastes that are generated at any stage of the project will ever be discharged into any water body

untreated. A CEMS will continuously monitor all gaseous emissions and NEQS/SEQS shall be

followed accordingly. Coal which will be imported will be free of any radioactivity.

Section 71 (C)(1) No proponent of a project shall commence construction or operation unless he has

filed with this Authority as Initial Environmental Examination (IEE) or, where the project is likely to

cause an adverse environmental effect, an Environment Impact Assessment (EIA), and has obtained

from the authority approval in respect thereof.

Without the prior approval of this EIA, construction activity within PQA cannot be commenced.

2.9 PAKISTAN PENAL CODE

The Pakistan Penal Code (1860) authorizes fines, imprisonment or both for voluntary corruption or

fouling of public springs or reservoirs so as to make them less fit for ordinary use.

Section 277: Fouling water of public spring or reservoir: Whoever voluntarily corrupts or fouls the water

of any public spring or reservoir, so as to render it less fit for the purpose for which it is ordinarily used.

No public spring was found or reported in the vicinity of the proposed plant; nonetheless, every measure

will be taken to prevent any fouling of any water body and prevent it from harming anyone.



2.10 SINDH ANTIQUITIES ACT 1974

The protection of cultural resources in Pakistan is ensured by the Antiquities Act of 1975. The law

prohibits new construction in the proximity of a protected antiquity and empowers the Government of

Pakistan to prohibit excavation in any area which may contain articles of archaeological significance.

Under the Act, the project proponents are obligated to:

Ensure that no activity is undertaken in the proximity of a protected antiquity

If an archaeological discovery is made during the course of the project, it should be reported to the Department of Archaeology, Government of Pakistan.

The Act is designed to protect these antiquities from destruction, theft, negligence, unlawful excavation,

trade, and export. The law prohibits new construction in the proximity of a protected antiquity and

empowers the GOP to prohibit excavation in any area that may contain articles of archaeological

significance.

LEPCL is obligated to ensure that no activity is undertaken within 61 m (200 Ft) of a protected antiquity

and to report to the GOP's Department of Archaeology of any archaeological discovery made during the

course of the project.

2.11 SINDH CULTURAL HERITAGE (PRESERVATION) ACT 1994

The Sindh Cultural Heritage (Preservation) Act, 1994 is the provincial law for the protection of cultural

heritage. Its objectives are similar to those of the Antiquity Act, 1975.

None of the sites protected under these laws has been identified in the vicinity of the project site.

2.12 THE BOILER ACT 1923

The boiler act extends to whole of Pakistan and is applicable to all steam boiler having a volume of

greater than 20 gallons. Every boiler is required to have a registration and certification prior to its use.

The boiler must not exceed the pressure which is mentioned on its certificate.

LEPCL will comply all regulations and statutes that relate with boiler.

2.13 THE MOTOR VEHICLES ORDINANCE 1965 AND RULES 1969

The motor vehicles ordinance stipulates that any vehicle which is in use must be registered with the

provincial transport department. Every vehicle must operate under the legal load limit, should not

exceed the speed limits of the respective road where it is being operated so as to pose hazards to public.

No vehicle should be operated if it is producing noise or air pollution and that the operator of the vehicle

must be of legal age and having good health.

LEPCL shall abide by all the rules and formalities as required in the law.

2.14 ENVIRONMENTAL REGULATIONS & GUIDELINES

2.14.1 SINDH EPA REVIEW OF IEE AND EIA REGULATIONS 2014

The Sindh Environmental Protection Agency (Review of EIA/IEE) Regulations 2000 define Schedules (I &

II) of projects falling under the requirement of IEE or EIA. This EIA Study has, for environmental

classification of the Project into Category A or B, taken account of the requirements of the Sindh



Environmental Protection Agency (Review of EIA/IEE) Regulations 2014 which define Schedules (I & II)

as follows:

Schedule I: A project falls in Schedule I if it is likely to have adverse environmental impacts, but of lesser

degree or significance than those for category ‘A’ and all the mitigation measures to handle the impact

is manageable. Such types of projects need IEE report including EMP.

Schedule II: Projects are categorized in Schedule II if they generate significant adverse environmental

impacts that require a comprehensive management plan, or if the project is located within or passes

through: a) Areas declared by the Government of Pakistan as environmentally sensitive (National

Parks/Sanctuaries/Game Reserve), b) Areas of international significance (e.g. protected wetland as

designated by the RAMSAR Convention), or c) Areas designated by the United Nations Educational,

Scientific, and Cultural Organization (UNESCO) as cultural heritage sites.

According to Sindh Environmental Protection Agency Regulation, 2014, a proponent of a project falling

in any category listed in Schedule II shall file an EIA with the Sindh Environmental Protection Agency,

since the listed projects are generally major projects and have the potential to affect a large number of

people. Coal Power Projects above 50 MW are placed in Schedule II thus requiring an EIA.

SCHEDULE II

(See Regulation 4)

List of projects requiring an EIA

A. Energy

1. Hydroelectric power generation over 50 MW

2. Thermal power generation over 100MW

3. Coal power projects above 50 MW

4. Transmission lines (11 KV and above) and distribution projects.

5. Nuclear power plants

6. Wind energy projects if falls under any sensitive, protected area.

B. Oil and Gas projects

1. Petroleum refineries.

2. LPG and LNG Projects(including LNG Terminals, re-gasification units) except LPG filling stations

3. Oil and gas transmission systems

4. Oil and gas gathering system, separation and storage.

C. Manufacturing and processing

1. Cement plants

2. Chemical manufacturing industries

3. Fertilizer plants

4. Steel Mills

5. Sugar Mills and Distilleries

6. Food processing industries including beverages, dairy milk and products, slaughter houses and related

activities with total cost more than Rs. 200 Million

7. Industrial estates (including export processing zones)

8. Man-made fibers and resin projects with total cost of Rs 200M and above

9. Pesticides (manufacture or formulation)

10. Petrochemicals complex

11. Synthetic resins, plastics and man-made fibers, paper and paperboard, paper pulping, plastic products,

textiles (except apparel),printing and publishing, paints and dyes, oils and fats and vegetable ghee



projects, with total cost more than Rs. 10 million

12. Tanning and leather finishing projects

13. Battery manufacturing plant

D. Mining and mineral processing

1. Mining and processing of coal, gold, copper, sulphur and precious stones

2. Mining and processing of major non-ferrous metals, iron and steel rolling

3. Smelting plants with total cost of Rs. 100 million and above

E. Transport

1. Airports

2. Federal or Provincial highways or major roads (including rehabilitation or rebuilding or reconstruction

of existing roads)

F. Ports and harbor development

1. Railway works

2. Flyovers, underpasses and bridges having total length of more than 500m

G. Water management, dams, irrigation and flood protection

1. Dams and reservoirs with storage volume of 25 million cubic meters and above having surface area of

4 square kilometers and above

2. Irrigation and drainage projects serving 15,000 hectares and above

3. Flood Protection

H. Water supply and filtration

Large Water supply schemes and filtration plants.

I. Waste Disposal and treatment

1. Handling, storage or disposal of hazardous or toxic wastes or radioactive waste (including landfill sites,

incineration of hospital toxic waste )

2. Waste disposal facilities for municipal or industrial wastes, with total annual capacity of 10,000 tons and

above.

3. Waste water treatment facility for industrial or municipal effluents.

J. Urban development and tourism

1. Housing schemes above 10 acres

2. Residential/commercial high rise buildings/apartments from15 stories and above.

3. Land use studies and urban plans (large cities)

4. Large scale public facilities.

5. Large-scale tourism development projects

K. Environmentally Sensitive Areas

All projects situated in environmentally sensitive areas

L. Other projects

1. Any other project for which filing of an EIA is required by the Agency under sub-regulation (2) of

Regulation 5.

2. Any other project likely to cause an adverse environmental effect

2.14.2 ENVIRONMENTAL ASSESSMENT PROCEDURES

The Sindh EPA has prepared a set of guidelines for conducting environmental and social assessments.

The guidelines derive from much of the existing work done by international donor agencies and NGOs.

The package of regulations, of which the environmental and social guidelines form a part, includes the

SEPA 2014 and the SEQS. These guidelines are listed below followed by comments on their relevance to

proposed project:



Policy and Procedures for Filing, Review and Approval of Environmental Assessments: These guidelines

define the policy context and the administrative procedures that govern the environmental assessment

process from the project pre-feasibility stage to the approval of the environmental report.

The overall flow of obtaining the approval of IEE and EIA is shown in figure 2.1 and 2.2.

Figure 2.1 – IEE Review and Approval Procedure



Figure 2.2 – EIA Review and Approval Procedure

Guidelines for the Preparation and Review of Environmental Reports: The guidelines on the

preparation and review of environmental reports target project proponents and specify:

The nature of the information to be included in environmental reports

The minimum qualifications of the EIA conductors appointed

The need to incorporate suitable mitigation measures at every stage of project implementation



The need to specify monitoring procedures.

The terms of reference for the reports are to be prepared by the project proponents themselves. The

report must contain baseline data on the study area, detailed assessment thereof, and mitigation

measures.

Guidelines for Public Consultation, Pakistan: These guidelines support the two guidelines mentioned

above. They deal with possible approaches to public consultation and techniques for designing an

effective program of consultation that reaches out to all major stakeholders and ensures the

incorporation of their concerns in any impact assessment study.

Guidelines for Sensitive and Critical Areas: The guidelines identify officially notified protected areas in

Pakistan, including critical ecosystems, archaeological sites, etc., and present checklists for

environmental assessment procedures to be carried out inside or near such sites. Environmentally

sensitive areas include, among others, archaeological sites, biosphere reserves and natural parks, and

wildlife sanctuaries and preserves.

2.14.3 SINDH ENVIRONMENTAL QUALITY STANDARDS

With the SEPA, 2014 the Sindh EPA revised the Environmental Quality Standards (EQS) with full

consultation of the private sector, industrialist, trade and business associations and NGOs. LEPCL is

committed to comply with the applicable Sindh-EQS in letter and spirit.

Table 2.1 shows Sindh environmental quality standard for ambient air.

Table 2.1: Sindh Environmental Quality Standard for Ambient Air

Pollutant Time-weighted average

Concentration in Ambient Air

Method of measurement

Sulfur Dioxide (SO2) Annual Average* 80μgm3 Ultraviolet Fluorescence Method

24 hours** 120μgm3

Oxides of Nitrogen as (NO)

Annual Average* 40μgm3 Gas Phase Chemiluminescence

24 hours** 40μgm3

Oxides of Nitrogen as (NO2)

Annual Average* 40μgm3 Gas Phase Chemiluminescence

24 hours** 80μgm3

O3 1 hour 130μgm3 Non dispersive UV absorption method

Suspended Particulate Matter (SPM)

Annual Average* 360μgm3 High volume Sampling, (Average flow rate not less than

1.1m3/minute) 24 hours** 500μgm3

Respirable Particulate Matter (PM10)

Annual Average* 120μgm3 Β Ray absorption method

24 hours** 150μgm3

Respirable Particulate Matter (PM2.5)

Annual Average* 15μgm3 Β Ray absorption method

24 hours** 35μgm3

1 hour 15μgm3

Lead (Pb) Annual Average* 1μgm3 ASS Method after sampling using EPM 2000 or equivalent Filter

paper 24 hours** 1.5μgm3

Carbon Monoxide (CO) 8hours** 5mg/m3 Non Dispersive Infra Red (NDIR) method 1hours 10mg/m3

*Annual arithmetic mean of minimum 104 measurements in a year taken twice a week 24 hourly at



Table 2.1: Sindh Environmental Quality Standard for Ambient Air

Pollutant Time-weighted average


Method of measurement

uniform interval.

**24 hourly / 8 hourly values should be met 98% of the in a year. 2% of the time, it may exceed but not on two consecutive days.

Table 2.2 shows the standards for motor vehicle noise.

Table 2.2: The Motor Vehicle Ordinance (1965) and Roles (1969)

Parameter Standards (maximum permissible limit) Measuring method

Noise 85dB(A) Sound-meter at 7.5meter from the source

Table 2.3 shows the proposed national environmental quality standard for noise.

Table 2.3: Sindh Environmental Quality Standard for Noise

S. No. Category of Area / Zone

Limit it in dB(A) Leq*

Day Time Night Time

1 Residential area (A) 55 45

2 Commercial area (B) 65 55

3 Industrial area (C) 75 65

4 Silence Zone (D) 50 45

Note: 1 Day time hours: 6.00 a. m to 10.00 p. m

2 Night time hours: 10.00 p. m to 6.00p. m

3 Silence zone; Zone which are declared as such by competent authority. An area comprising not less than 100 meters around hospitals, educational institutions and courts.

4 Mixed categories of areas may be declared as one of the four above-mentioned categories by the competent authority.

*dB(A)Leq Time weighted average of the level of sound in decibels on scale A which is relatable to human hearing.

The SEQS for effluents are shown in Table 2.4.

Table 2.4: Sindh Environmental Quality Standard for Municipal & Liquid Industrial Effluents

S. #

Parameter Into Inland Waters

Into Sewage Treatment

Into Sea unit

1 Temperature or Temp. increase <3 <3 <3 oC

2 pH value (H+) 6-9 6-9 6-9

3 Biological Oxygen Demand (BOD)5 at 20oC 80 250 80 mg/l

4 Chemical Oxygen Demand (COD) 150 400 400 mg/l

5 Total Suspended Solids (TSS) 200 400 200 mg/l

6 Total Dissolved Solids (TDS) 3500 3500 3500 mg/l

7 Oil and Grease 10 10 10 mg/l

8 Phenolic Compounds (as Phenol) 0.1 0.3 0.3 mg/l

9 Chloride (as Cl-) 1000 1000 SC mg/l

10 Fluoride (as F-) 10 10 10 mg/l

11 Cyanide (as CN-)total 1.0 1.0 1.0 mg/l

12 An-ionic detergents (as MBAS) 20 20 20 mg/l

13 Sulphate(SO42-) 600 1000 SC mg/l

14 Sulphide (S2-) 1.0 1.0 1.0 mg/l

15 Ammonia (NH3) 40 40 40 mg/l

16 Pesticides 0.15 0.15 0.15 mg/l

17 Cadmium 0.1 0.1 0.1 mg/l



Table 2.4: Sindh Environmental Quality Standard for Municipal & Liquid Industrial Effluents

S. #

Parameter Into Inland Waters

Into Sewage Treatment

Into Sea unit

18 Chromium (trivalent and hexavalent) 1.0 1.0 1.0 mg/l

19 Copper 1.0 1.0 1.0 mg/l

20 Lead 0.5 0.5 0.5 mg/l

21 Mercury 0.01 0.01 0.01 mg/l

22 Selenium 0.5 0.5 0.5 mg/l

23 Nickel 1.0 1.0 1.0 mg/l

24 Silver 1.0 1.0 1.0 mg/l

25 Total toxic metals 2.0 2.0 2.0 mg/l

26 Zinc 5.0 5.0 5.0 mg/l

27 Arsenic 1.0 1.0 1.0 mg/l

28 Barium 1.5 1.5 1.5 mg/l

29 Iron 8.0 8.0 8.0 mg/l

30 Manganese 1.5 1.5 1.5 mg/l

31 Boron 6.0 6.0 6.0 mg/l

32 Chlorine 1.0 1.0 1.0 mg/l

The NEQS for drinking water are shown in Table 2.5.

Table 2.5: Sindh Environmental Quality Standards for Drinking Waters (mg/l)

S.# Properties / Parameters Standard Values for Pakistan

S.# Properties / Parameters

Standard Values for Pakistan

Bacterial Chemical

1 All water intended for drinking (E.Coli or Thermo tolerant Coliform bacteria)

Must not be detectable in any 100 ml sample

Essential Inorganics (mg/liter)

3 Aluminum (Al) mg/l

≤ 0.2

4 Antimony (Sb) ≤ 0.005

2 Treated water entering the distribution system (Ecoli or thermo tolerant coliform and total coliform bacteria)

Must not be detectable in any 100 ml sample

5 Arsenic (As) ≤ 0.05

6 Barium (Ba) 0.7

7 Boron (B) 0.3

3 Treated water in the distribution system (E.coli or thermo tolerant coliform and total coliform bacteria)

Must not be Detectable in any 100 ml sample. In case of large supplies, where sufficient samples are examined, must not be resent in 95% of the samples taken throughout any 12 month period.

8 Cadmium (Cd) 0.01

9 Chloride (Cl-) < 250

10 Chromium (Cr) ≤ 0.05

11 Copper (Cu) 2

Organic (mg/L)

12 Phenolic compounds

<0.0002

Toxic Inorganics (mg/liter)

13 Cyanide (CN)- ≤ 0.05

14 Fluoride (F) ≤ 1.5

15 Lead (Pb) ≤ 0.05

16 Manganese (Mn)

≤ 0.5

Physical 17 Mercury (Hg) ≤ 0.001

4 Color < 15 TCU 18 Nickel (Ni) ≤ 0.02

5 Taste

Non-objectionable/ Acceptable

19

Nitrate (NO3)-

≤ 50



Table 2.5: Sindh Environmental Quality Standards for Drinking Waters (mg/l)

S.# Properties / Parameters Standard Values for Pakistan

S.# Properties / Parameters

Standard Values for Pakistan

6 Odor Non-objectionable/ Acceptable

20 Nitrite (NO2)- ≤ 3

7 Turbidity < 5 NTU 21 Selenium (Se) ≤ 0.01

8 Total Hardness as CaCO3 < 500 mg/l 22 Residual Chlorine

0.2-0.5 At consumer

end 0.5-1.5 at

source

9 TDS <1000

10 pH 6.5-8.5

Radioactive

11 Alpha Emitters bq/L 0.1 23 Zinc (Zn) 5.0

12 Beta emitters 1

In August 2014, Sindh department of Forest, Environment and Wildlife published in exercise of powers

conferred under clause (e) sub-section (1) of Section (6) of SEPA Act VIII of 2014 the Environmental

Quality Standards for Ambient Air. The respective standards are in the following table.

The table shows the maximum allowable limits for ambient air as per SEQS 2014 notification no.

EPA/226/ADMIN/2014.

Table 2.6: Sindh Environmental Quality Standards for Ambient Air

S.# Pollutants Time weight average


1 Sulphur Dioxide(SO2) Annual Average

24 hours 80 µg/m3 120 µg/m3

2 Oxides of Nitrogen as (NO) Annual Average


3 Oxides of Nitrogen as (NO2) Annual Average


4 Ozone (O3) 1 hour

130 µg/m3

5 Suspended Particulate Matters (SPM) 24 hours

Annual Average 500 µg/m3

360 µg/m3

6 Respirable Particulate Matter PM10 Annual Average

24 hours 120 µg/m3 150 µg/m3

7 Respirable Particulate Matter PM2.5 Annual Average


8 Lead Pb Annual Average

24 hours 1 µg/m3

1.5 µg/m3

9 Carbon Monoxide (CO) 8 hours 1 hour

5 mg/m3 10 mg/m3

2.14.4 SELF-MONITORING AND REPORTING BY INDUSTRY RULES 2014

The self-monitoring and reporting system (SMRS) defines the priority parameters for each industry that

falls in either of the schedules of liquid and gaseous emissions. It takes into account the resources and

interests of both the EPA and industry.

Schedule I is for industries and establishments producing effluents and places them into categories (A),

(B), and (C), each corresponding to a specified reporting frequency; category (A) being the most



polluting. The category (A) industries are bound to report their effluents and emission levels every

month while category (B) industry quarterly and category (C) industry biannually.

Schedule II categorizes the gaseous emission producing industries. It has two categories (A) and (B)

wherein category (A) again represents industries that are prone to produce more pollutants as

compared to category (B).

The industries must have their effluents tested by an EPA certified/ accredited laboratory and enter the

results in the electronic forms (as well as a hard copy) included in the software package. The data must

be sent to the respective provincial EPA via email or on a floppy disk. Sampling and analysis requirements

and procedures and the charges have evolved through the process of coordination among

representatives of industry, government, environmental NGOs and academic researchers. Appreciable

progress has been made towards operationalizing the process.

Thermal Power Plants have been placed in Category (B) of schedule I for reporting of their liquid

effluents. While in schedule II of gaseous emissions, they are placed in Category (A). They are also

required to report their gaseous emissions, besides their boiler, ovens, furnaces and kilns on monthly

basis. LEPCL shall stick to these requirements in accordance with the law.

2.14.5 THE HAZARDOUS SUBSTANCES RULES 2014

The Hazardous Substances Rules 2014 define the hazardous substances in schedule 1 and make it

compulsory for any proponent who is filing an EIA to apply for a license for transporting any hazardous

substance that it has in its plans. The rules also stipulate a waste management plan to be in place in such

a facility holding hazardous materials. Further SEP Act 2014 also requires the proponent to obtain a

license to store any such hazardous substance.

LEPCL has in its proposed project a storage area for Hydrazine, Ammonia and Oxygen. The Hazardous

Substances Rules 2014 specify Dimethyl Hydrazine (CAS# 57-14-7), Liquid Oxygen (CAS # 7727-37-9),

Ammonia (CAS # 7664-41-7) as hazardous and regulated substances and therefore LEPCL is obligated to

follow in accordance with the provisions of the act and rules and obtain license for these substances

before implementation of the project.

2.14.6 GUIDELINES FOR SENSITIVE AND CRITICAL AREAS

These guidelines are part of a package provided by Pakistan EPA for conducting EIA in a sensitive or a

critical area. The main purpose of these guidelines is to help the proponents identify any officially

notified protected area of Pakistan which may include any critical ecosystem such as a wildlife reserve,

forest etc.; archaeological sites, monuments, buildings, antiquities or cultural heritage sites. Secondly, to

help make a sound approach if the proposed project does lie in an officially notified area thereby

reducing any impacts on the natural habitat.

2.14.7 GUIDELINES FOR PUBLIC CONSULTATION

Public consultation is mandated under Sindh’s environmental law. Regulation 11 of the IEE-EIA

Regulations 2014 provides the general requirements whereas the sectoral guidelines indicating specific

assessment requirements are provided in the Guidelines for Public Consultation 2014 (the ‘Guidelines’).

These are summarized below.



Objectives of Public Involvement: ‘To inform stakeholders about the proposed project, to provide

an opportunity for those otherwise unrepresented to present their views and values, providing

better transparency and accountability in decision making, creating a sense of ownership with the

stakeholders’;

Stakeholders: ‘People who may be directly or indirectly affected by a proposal will clearly be the

focus of public involvement. Those who are directly affected may be project beneficiaries, those

likely to be adversely affected, or other stakeholders. The identification of those indirectly affected

is more difficult, and to some extent it will be a subjective judgment. For this reason it is good

practice to have a very wide definition of who should be involved and to include any person or group

who thinks that they have an interest. Sometimes it may be necessary to consult with a

representative from a particular interest group. In such cases the choice of representative should be

left to the group itself. Consultation should include not only those likely to be affected, positively or

negatively, by the outcome of a proposal, but should also include those who can affect the outcome

of a proposal’;

Mechanism of consultations: ‘Provide sufficient relevant information in a form that is easily

understood by non-experts (without being simplistic or insulting), allow sufficient time for

stakeholders to read, discuss, consider the information and its implications and to present their

views, responses should be provided to issues and problems raised or comments made by

stakeholders, selection of venues and timings of events should encourage maximum attendance’;

Timing and Frequency: Planning for the public consultation program needs to begin at a very early

stage; ideally it should commence at the screening stage of the proposal and continue throughout

the EIA process;

Consultation Tools: Some specific consultation tools that can be used for conducting consultations

include; focus group meetings, needs assessment, semi-structured interviews; village meetings and

workshops;

Other Important Considerations: ‘The development of a public involvement program would

typically involve consideration of the following issues; objectives of the proposal and the study;

identification of stakeholders; identification of appropriate techniques to consult with the

stakeholders; identification of approaches to ensure feedback to involved stakeholders; and

mechanisms to ensure stakeholders’ consideration are taken into account’.

As above, the Guidelines for Public Consultation introduces effective ways to inform the contents of the

project to the general public during the planning stage and that eventually consensus building toward

the implementation of project is reached.

Incorporating public involvement into the stages of environmental assessment is explained in the

guidelines that public consultation meeting has to be carried out after the works on "developing options,

and assessing and mitigating impacts" for comments and assessment.

For the proposed LECPP Project, the consultation program is based on the following principles:

Development and maintenance of an open and transparent dialogue with all parties which have an

interest or influence on the project and its proposed area;



Demonstration of how, when and why input from stakeholders was or was not utilized to make

project iterative and flexible (so that decisions can be continually fed into design, construction and

operation);

Learning from stakeholder experience so as to modify and adapt future consultation activities and

project design;

Maintaining continuous dialogue with stakeholders throughout the project planning, designing,

actual construction and operation;

Development of the consultation process in recognition of the existence of understanding at

different levels amongst the stakeholders, and

Providing complete/updated information about the project, with regard to such issues as design,

construction methodology, engineering and operation, besides necessary mitigation measures.

2.14.8 GUIDELINES FOR COAL FIRED THERMAL POWER PLANTS – NIAP (2014)

With the establishment of Government of Pakistan’s 2013 Energy Policy, one of the goals is to promote

coal fired power plants in the country to meet the growing demand of electricity. These Guidelines have

been prepared in collaboration with IUCN. They cover the key environmental issues that need to be

addressed, mitigation measures and alternatives that need to be considered in the actual EIA.

The guidelines also gives a detailed comparison of the existing technology for both the power generation

and emission control technologies with comparative values of effectiveness of different measures in

order to give a benchmark for comparison and wise decision making.

2.14.9 IFC GUIDELINES FOR THERMAL POWER PLANTS

The IFC industry sector EHS guidelines are designed to be used together with the General EHS

Guidelines, which provide guidance to users on common EHS issues potentially applicable to all industry

sectors. Guidelines are technical reference documents with general and industry-specific examples of

Good International Industry Practice (GIIP).

The Guidelines for Thermal Power Plants has three sections and two annexures. Section 1 deal with

industry specific impacts and their management; section 2 helps establish performance indicators and

monitoring after installation of plants.

The guidelines give the details of following major areas as they particularly relate to thermal power

plants.

Air emissions

Energy efficiency and Greenhouse Gas emissions

Water consumption and aquatic habitat alteration

Effluents

Solid wastes

Hazardous materials and oil

Noise



The aim is to achieve maximum possible efficiency while minimizing the environmental impacts.

Different control measures are described in the section of air emissions which are currently being used

in the industry. Annexure A gives a general description of industrial activities while annexure B describes

the environmental assessment guidance for thermal power projects. IFC Guidelines also contain the

performance levels and measures that are generally considered to be achievable in new facilities by

existing technology at reasonable costs. Application of these Guidelines to K-Electric’s new power plant

facilities will involve the establishment of site-specific targets, with an appropriate timetable for

achieving them.

The guidelines also help establish performance indicators for Effluents and Emissions and Occupational

Health and Safety. For emissions, the guideline describes particular levels for different type of fuels and

combustion technology. For discharge of treated effluent to surface waters for general use, site-specific

discharge levels may be established based on the availability and conditions in the use of publicly

operated sewage collection and treatment systems or, if discharged directly to surface waters, on the

receiving water using classification as described in the General EHS Guidelines. Guideline values for

process emissions and effluents in this sector are indicative of good international industry practice as

reflected in standards of countries with recognized regulatory frameworks.

2.14.10 IFC GENERAL EHS GUIDELINES

These Guidelines are technical reference documents with general and industry-specific examples of

Good International Industry Practice (GIIP). When one or more members of the World Bank Group are

involved in a project, these EHS Guidelines are applied as required by their respective policies and

standards. These General EHS Guidelines are designed to be used together with the relevant Industry

Sector EHS Guidelines which provide guidance to users on EHS issues in specific industry sectors.

The applicability of the EHS Guidelines should be tailored to the hazards and risks established for each

project on the basis of the results of an environmental assessment in which site-specific variables, such

as host country context, assimilative capacity of the environment, and other project factors, are taken

into account. The applicability of specific technical recommendations should be defined as the exercise

of professional skill, diligence, prudence and foresight that would be reasonably expected from skilled

and experienced professionals engaged in the same type of undertaking under the same or similar

circumstances globally.

For IFC, such assessment is carried out consistent with Performance Standard 1, and for the World Bank,

with Operational Policy 4.01 based on the professional opinion of qualified and experienced persons.

When host country regulations differ from the levels and measures presented in the EHS Guidelines,

projects are expected to achieve whichever is more stringent. If less stringent levels or measures than

those provided in these EHS Guidelines are appropriate, in view of specific project circumstances, a full

and detailed justification for any proposed alternatives is needed as part of the site-specific

environmental assessment. This justification should demonstrate that the choice for any alternate

performance levels is protective of human health and the environment.

For complex projects, use of multiple industry-sector guidelines may be necessary. And therefore in the

case of LEPCL 660 MW Power Plant, the industry specific guidelines are being followed along with the

general EHS guidelines.



2.14.11 IFC PERFORMANCE STANDARDS 2012

IFC Performance Standards on Social and Environmental Sustainability applies the Performance

Standards to manage social and environmental risks and impacts and to enhance development

opportunities in its private sector financing in its member countries eligible for financing. The

Performance Standards may also be applied by other financial institutions electing to apply them to

projects in emerging markets. Together, the eight Performance Standards establish standards that the

Proponent is to meet throughout the life of an investment by IFC or other relevant financial institution.

The objectives of Performance standards are given below:

To identify and assess social and environment impacts, both adverse and beneficial, in the project's area of influence

To avoid, or where avoidance is not possible, minimize, mitigate, or compensate for adverse impacts on workers, affected communities, and the environment To ensure that affected communities are appropriately engaged on issues that could potentially affect them

To promote improved social and environment performance of companies through the effective use of management systems

Performance Standard – 1: Social & Environmental Assessment and Management System

This Performance Standard seeks to:

Identify and assess social and environment impacts in the project's area of influence;

Avoid, minimize, mitigate, or compensate for adverse impacts on workers, affected communities, and the environment;

Ensure that affected communities are appropriately engaged on issues that could potentially affect them; and

Promote improved social and environment performance of the project through the effective use of management systems.

Under this Standard, the project is required to establish and maintain a social and environmental management system appropriate to the nature and scale of the project and in accordance with the level of social and environmental risks and impacts.

The management system is required to incorporate the following elements:

Social and Environmental Assessment;

Management program; Organizational capacity;

Training;

Community engagement;

Monitoring; and Reporting

This EIA study has been conducted to respond to requirements of national legislation and international

guidelines and just as well fulfils the above requirements of the IFC Performance Standards PS1.

Performance Standard – 2: Labor and Working Conditions: This PS seeks to establish, maintain and

improve:

the worker-management relationship;



promotion and fair treatment, non-discrimination and equal opportunity for workers, and compliance with national labor and employment laws;

protection of the workforce by addressing child labor and forced labor issues; and

promotion of safe & healthy working conditions, and to protect and promote the health of workers.

The Sponsors of proposed project and their contractors will be required to adhere to this PS, in particular

with regard to compliance with:

National labor and employment laws;

Non-employment of child labor, and promoting safe and healthy working conditions, besides protecting and promoting the health of workers.

Performance Standard – 3: Pollution Prevention and Abatement: This standard seeks to avoid or

minimize adverse impacts on human health and the environment by avoiding or minimizing pollution

from project activities, and to promote the reduction of emissions that contribute to climate change.

The Standard requires the project to consider during its entire lifecycle ambient conditions and apply

pollution prevention and control technologies and practices that are best suited to avoid or, where

avoidance is not feasible, minimize or reduce adverse impacts on human health and the environment

while remaining technically and financially feasible and cost- effective. PS 3 will be applicable to all stages

of the proposed project. Various aspects of pollution prevention and abatement of the proposed project

are discussed separately in this report.

Performance Standard – 4: Community Health, Safety and Security: The PS 4 seeks to avoid or minimize

risks to and impacts on the health and safety of local community during the project lifecycle from both

routine and non-routine circumstances, and to ensure that the safeguarding of personnel and property

is carried out in a legitimate manner that avoids or minimizes risks to the community's safety and

security. The PS requires the project to evaluate the risks and impacts to the health and safety of the

affected community during the design, construction, operation, and decommissioning of the project

and establish preventive measures to address them in a manner commensurate with the identified risks

and impacts. The present assessment addresses the requirement of PS 4 for the proposed project, and

has evaluated the impacts of siting the proposed project on health, safety and security of the community

in the micro-environment as well as the macro-environment. The Environmental Management Plan also

addresses company community aspects.

Performance Standard-5: Land Acquisition and Involuntary Resettlement: This PS aims to address the

adverse impacts associated with land acquisition and involuntary resettlement caused by the project.

The PS seeks to avoid or at least minimize involuntary resettlement wherever feasible by exploring

alternative project designs mitigate adverse social and economic impacts from land acquisition or

restrictions on affected persons' use of land by:

providing compensation for loss of assets at replacement cost; and

ensuring that resettlement activities are implemented with appropriate disclosure of information, consultation, and the informed participation of those affected improve or at least restore the livelihoods and standards of living of displaced persons improve living conditions among displaced persons through provision of adequate housing with security of tenure at resettlement sites.

The proposed project is being implemented on a vacant plot of land in the Bin Qasim Town under KMC.

Land Acquisition or Involuntary Resettlement is not involved in this project.



Performance Standard – 6: Biodiversity Conservation and Sustainable Natural Resource Management:

The PS 6 seeks to protect and conserve biodiversity, and promote sustainable management and use of

natural resources through adoption of practices that integrate conservation needs and development

priorities. The present environmental assessment addresses the potential impacts of the proposed

project on the biodiversity. This EIA has recommended measures for the conservation of flora, fauna

and other natural resources.

Performance Standard – 7: Indigenous Peoples: The PS 7 seeks to address the impacts of the project on

the indigenous people. Specifically, the objectives of the PS are to:

ensure that the development process fosters full respect for the dignity, human rights, aspirations, cultures and natural resource-based livelihoods of Indigenous Peoples

avoid adverse impacts of projects on communities of Indigenous Peoples, or when avoidance is not feasible, to minimize, mitigate, or compensate for such impacts; and

to provide opportunities for development benefits, in a culturally appropriate manner establish and maintain an ongoing relationship with the Indigenous Peoples affected by a project throughout the life of the project foster good faith negotiation with and informed participation of Indigenous Peoples when projects are to be located on traditional or customary lands under use by the Indigenous Peoples

respect and preserve the culture, knowledge and practices of Indigenous Peoples

No indigenous people with a social and cultural identity distinct from the existing dominant society that

makes them vulnerable to being disadvantaged in the development process of the proposed project are

known to exist in and around the proposed site.

No such people were found in the area during the present study either. Therefore, this PS is not

applicable for the proposed project.

Performance Standard – 8: Cultural Heritage: The objectives of this PS are to protect cultural heritage

from the adverse impacts of project activities and support its preservation, and to promote the equitable

sharing of benefits from the use of cultural heritage in project activities.

No sites of cultural heritage are known to exist at or in the immediate vicinity of the project location.

There are also no indications of any old settlement in the area, nor is there any site covered under the

listing of cultural heritage sites. This PS will therefore not be applicable to the project.

2.15 INTERNATIONAL CONVENTIONS AND TREATIES

Pakistan is signatory/member of various international treaties and conventions on conservation of

environment and protection of wildlife. The country is therefore obliged to adhere to the commitments

specified in these treaties. The United Nations Conference on Environment and Development (UNCED),

1992 emphasized on protection, rational use and development of resources; preventing further

degradation and reducing the risk of long term irreversible effects; conservation of biodiversity, and

sustainable use of genetic resources.

The International conventions and programs to which Pakistan is a party relating to biodiversity

conservation and for which there is a national legislation are:



2.15.1 CONVENTION ON CONSERVATION OF MIGRATORY SPECIES, 1979

This convention was adopted in Bonn, Germany in 1979 and Pakistan ratified it in 1987. This is the sole

international treaty that seeks to specifically address the conservation of international migratory

animals. The species covered by this convention include Avian, Mammalia and Pisces. Pakistan has its

12% of its area designated as protected as wildlife sanctuaries, national parks, game reserves and as

community conservation area. These measures along with many laws preventing human intervention

and exploitation of wild make sure the compliance of this convention.

Pakistan lies at the Indus-flyway route 4 (also called the green route), a corridor for migratory birds who

come for wintering from Siberia and finally reach India Bharatpure.

The proposed site does not fall in the migratory birds flyway zone.

2.15.2 CONVENTION OF INTERNATIONAL TRADE IN ENDANGERED SPECIES (CITES) 1973

The early 1960s saw an international discussion which started focusing on the rate at which the world’s

wild flora and fauna were being threatened by illegal international trade. Later as a result of a resolution

adopted in 1963, the CITES was drafted at a meeting of the International Union for the Conservation of

Nature (IUCN) in Nairobi, Kenya. At a meeting of representatives of 80 countries in Washington D.C., the

text of the Convention was agreed upon on March 3rd, 1973. Just about 2 years later, on July 1st 1975,

CITES entered into force.

Pakistan’s accession to CITES occurred in 1976 and it was ratified later in the same year.

2.15.3 CONVENTION ON WETLANDS OF INTERNATIONAL IMPORTANCE; RAMSAR

CONVENTION 1971

Pakistan is a signatory to the RAMSAR Convention. The principal obligations of contracting parties to the

Convention are:

To designate wetlands for the List of Wetlands of International Importance

To formulate and implement planning so as to promote wise use of wetlands

To carry out Environmental Assessment before transformations of wetlands, and to make national wetland inventories

To establish nature reserves on wetlands and provide adequately for their wardening and through management to increase waterfowl populations on appropriate wetlands

To train personnel competent in wetland research, management and wardening

To promote conservation of wetlands by combining far-sighted national policies with coordinated international action, to consult with other contracting parties about implementing obligations arising from the Convention, especially about shared wetlands and water system

To promote wetland conservation concerns with development aid agencies

To encourage research and exchange of data

So far 18 sites in Pakistan have been declared as wetlands of International Importance or RAMSAR Sites.

Of these, there are about 45 game sanctuaries and reserves spread over an area of 0.90 million hectares

in Sindh. None of these wetlands have been included within or close to the project area. Haleji Lake and

Kinjhar (Kalri) Lake are the two lakes designated as Wildlife Sanctuary. These freshwater lakes are



internationally important areas for breeding, staging and wintering water birds. They are however at 70

km and 150 km distance from project site.

2.15.4 IUCN RED LIST

It has been about 50 years now when IUCN first established the Red List. It is the world’s most

comprehensive source of information for conservation status of animals, fungi and plant species. The

list categorizes the species as:

Figure 2.3 – IUCN Categorization of Threatened Species (source www.iucnredlist.org)

No faunal species that fall under the IUCN Red List category were observed during the surveys at the site

for the EIA study.

2.15.5 INTERNATIONAL CONVENTION ON BIODIVERSITY 1992

The International Convention on Biodiversity was adopted during the Earth Summit of 1992 at Rio de

Janeiro. The Convention requires parties to develop national plans for the conservation and sustainable

use of biodiversity, and to integrate these plans into national development programs and policies.

Parties are also required to identify components of biodiversity that are important for conservation, and

to develop systems to monitor the use of such components with a view to promoting their sustainable

use.

2.15.6 KYOTO PROTOCOL (1992) AND UNITED NATION’S CLIMATE CHANGE CONVENTION

The United Nations Framework Convention on Climate Change (UNFCCC) and the subsequent Kyoto

Protocol is an attempt to initiate a process to develop a more specific and binding agreement on the

reduction of greenhouse gas emissions in an attempt to address the cause of global warming. Pakistan

ratified the Convention and the Kyoto Protocol was adopted at a Conference of the Parties to the

UNFCCC in Kyoto, Japan in December 1997.

The conference resulted in a consensus decision to adopt a protocol under which industrialized

countries (Annex 1 parties) will reduce their combined greenhouses gas emissions by at least 5%



compared to 1990 levels in the period 2008 to 2012. Pakistan, being a developing country (non-Annex

1 party) does not have to make any comparable greenhouse gas emission reductions.

In developing the Kyoto Protocol, the need to promote sustainable development was recognised. This

means implementing policies and measures to, among others, enhance energy efficiency, protect and

enhance sinks and reservoirs of greenhouse gases, promote sustainable forms of agriculture, increase

the usage of new and renewable forms of energy and of advanced, innovative and environmentally

sound technologies. Pakistan Climate Change Policy is in place and puts emphasis on cleaner technology

and production, and a shift towards sustainable development.



3.0 DESCRIPTION OF PROJECT

Lucky Electric Power Company Limited (LEPCL) has proposed to develop a coal fired power plant

employing one 660 MW supercritical boiler. The major systems of the power plant include;

Super-critical boiler

Coal transportation, handling and storage

Water supply and waste water system

Ash handling system

Emission control system

Flue Gas Desulfurization (FGD) system

Coal for the power plant will be received at the coal yard inside the plant. It will be processed before

feeding into the boiler. Heat from the combustion of coal in the super-critical boiler will be used to

generate steam at high pressure. The steam will then be fed into the steam turbine, where it will

rotate the turbine to generate mechanical energy. The steam, after passing through the turbine, will

be reheated by re-injecting into the boiler. The rotating steam turbine will operate the power

generator, which will generate electricity.

Flue gas from the boiler is normally laden with pollutants, oxides of nitrogen, particulate matter and

sulphur dioxide. The gas will be passed through a series of treatment units before being discharged

into the atmosphere. In the treatment system, pollutants from the gas will be removed.

Cooling water is required for cooling purposes in the operations of the power plants. The water is

obtained from the cooling water system. The water source for the proposed project will be the

Arabian Sea.

Bottom ash from the boiler and fly ash from the flue gas treatment system will be collected and

disposed of through the ash handling system. The proposed project will require several supporting

systems for plant operations. These include the seawater desalination system to provide water for

feeding the boiler, the effluent treatment system, wastewater treatment plants and waste disposal

systems for the wastewater and ash generated by the plants and associated facilities.

3.1 THERMAL POWER GENERATION PROCESS

In a thermal Power plant, the chemical energy of the fuel (coal) is first converted into thermal energy

(during combustion), which is then converted into mechanical energy (through a turbine) and finally into

electrical energy (through a generator). The schematic diagram of the process of power generation a

coal based thermal power plant is shown in Figure 3.1. It has the following steps.

The coal is transferred from the coal handling plant by conveyor belt to the coal bunkers, from

where it is fed to the pulverizing mills, which grind it to fine powder. The finely powdered coal, mixed

with air is then blown into the boiler by a fan where it bums like a gas.

The process of combustion releases thermal energy from coal. The boiler walls are lined with boiler

tubes containing high quality demineralized water (known as boiler feed water). The combustion

heat is absorbed by the boiler tube~ and the heat converts the boiler feed water into steam at high

pressure and temperature. The steam, discharged through nozzles on the turbine blades, makes the

turbine to rotate, which in turn rotates the generator coupled to the end of the turbine. Rotation of

generator produces electricity, which is passed to the step-up transformer to increase its voltage so



that it can be transmitted efficiently. The power is evacuated via switchyard through a Transmission

System.

Figure 3.1 — Schematic diagram of the process of power generation

During combustion, the non-combustible part of coal is converted into ash. A small part of ash

(about 20%) binds together to form lumps, which fall into the ash pits at the bottom of the furnace.

This part of ash, known as bottom ash is water quenched, grounded and then conveyed to pits for

subsequent disposal to ash disposal area or sale.

Major part of the ash (about 80%) is in fine powder form, known as Fly Ash, and is carried out of the

boiler along with the flue gas. The flue gas, after heat recovery, is passed through the electrostatic

precipitators, where the ash is trapped by electrodes charged with high voltage electricity.

The flue gases exiting from the Electrostatic Precipitators (ESPs) are discharged through a tall

chimney for wider dispersal of remaining ash particles and gases. The ash collected in the ESP

hoppers is extracted in dry form and conveyed to dry ash storage silos from where it is supplied to

user industries.

Unused part of fly ash is mixed with water and conveyed to ash disposal area in a slurry form. Ash

can also be lifted from ash disposal areas for utilization later on.

Figure 3.2 shows the layout of the proposed LECPP Project.

Boiler Blow

Down

Dry Ash Storage Silos

Ash Disposal Area

Generator

Transformer

Transmission Tower

Coal Handling Plant

Pulverizing Mills

Boiler

Electrostatic Precipitators

Chimney

Turbine

Heat Exchanger

Discharge

Flue

Gas

Boiler Feed

Water

Stack

Emission

Condensate Bottom

Ash

Fly Ash

Ash Utilization

Outfall

Steam Steam



Figure 3.2 — Layout of proposed LECPP Project



The basic design parameters for these are listed in Table 3.1:

Table 3.1: Basic Design Parameters of LECPP

Parameter Value

Thermal Cycle Information - Gross Capacity 660 MW (approximately) at annual average conditions with turbine max. continuous rating (TMCR)

Thermal Cycle Information - Net Capacity 607.2 MW (target) at annual average conditions TMCR

Net Plant Heat Rate 2,224 kcal/kWh at annual average conditions TMCR

Main Steam Flow 1,993,500 kg/h, 4,394,918 lb/hr

Main Steam Pressure 242 bar, 3,509 psi

Main Steam Temperature 566°C, 1,050 °F

Hot Reheat Flow 1,623,420 kg/h, 3,597,031 lb/hr

Hot Reheat Pressure 42.63 bar, 618 psi

Hot Reheat Temperature 566°C, 1,050°F

Cold Reheat Flow 1,623,420 kg/h, 3,597,031 lb/hr

Cold Reheat Pressure 47.36 bar, 686.7 psi

Cold Reheat Temperature 325.8°C, 618°F

Feedwater Pressure 291.1 bar, 4,221 psi at pump discharge

Coal Burn Rate 269 t/h for the design coal, 100% load

Water Flow to the Plant 82,000 m3/h

Circulating Water Flow 78,000 m3/h to condenser and closed cooling

Circulating Water Temperature Rise in Condenser

8.5°C, 15.3°F

Circulating Water Temperature Rise Total Condenser and Seawater FGD

9°C at 34% scrubbing

Sea Water Flow to Desalination System 600 m3/h

Waste Water Flow 12 m3/h

Potable Water Supply to Plant & Colony 15 m3/h

3.2 BOILER SYSTEM

The boiler is a supercritical, balanced draft, outdoor, coal-fired design, and Low NOx burner, pulverized

coal with front or rear or tilting tangential firing design suitable for operation at the super-critical steam

conditions. The boiler will be equipped with regenerative type air heaters, 2x50% adjustable moving-

blade axial-flow PA fans for FD and 2x50% adjustable stationary-blade axial-flow fans for ID. The design

of the air heaters, fans and associated boiler auxiliaries will be provided with adequate margins to avoid

limiting the capability of the Plant to achieve full rated output throughout the design life of the Facility.

Steam soot blowers will be provided to support the cleaning operation of the boiler to allow continuous

full load operation with the worst case fuel characteristics. The furnace will be equipped with wall soot

blowers and long retractable soot blowers for the superheater, reheater and economizer areas. The air

heaters will have fixed lance type soot blower units. The boiler maximum continuous rating will be

designed with the inclusion of auxiliary steam flow. The boiler will have a suitable number of duty

medium speed coal mill groups which allows the firing of performance coal at BMCR conditions, with

one spare mill group acts as standby. The boiler exit flue gas will pass through an electrostatic

precipitator and the SWFGD plant prior to entry into the stack, but the electrostatic precipitator and

SWFGD plant will have bypass system in order for emergency condition.



The warm-up and ignition fuel will be high speed diesel oil. This fuel will provide initial firing and will

stabilize the combustion until the coal flames are stable, about 30% to 35% load. Details of the design

depend on the specific suppler chosen for the Project.

This project is expected to operate as a base load unit, but the design will include provisions to allow the

unit to operate at lower loads if necessary.

The modern large supercritical boiler has the following major components:

Furnace

Superheaters

Reheaters

Economizer

Air preheater

Mix bottles or levelling vessels (depending on the specific vendor)

Water collection tank

Circulation pumps

Burners

Pulverisers

The characteristics of the design coal are shown below.

Table 3.2 — Proximate Analysis of Design Coal

Total Moisture % 16.5

Ash % 8.3

Volatile Matter % 32.4

Fixed Carbon % 42.8

Total Sulphur % 0.4

Grindability HGI 47.5

Gross Energy, as received (kcal/kg) 5, 861

3.2.1 FURNACE

The furnace is an enclosure to provide space for fuel combustion and cooling of the combustion gasses

before the gases enter the convection pass. In the furnace area the fuel and combustion air are injected

in a controlled manner to efficiently control the combustion. In the furnace walls the water is converted

to steam. Supercritical units have no drum to separate the water and steam. Modern furnaces are

formed by spiral water tube walls. The spiral design insures a more even distribution of heat to each of

the circuits. The heat transfer in the furnace is largely radiant. At the top of the furnace, the tube

arrangement changes to a vertical arrangement. The gases then rise to the convection pass, named

because of the heat transfer is by convection.

3.2.2 SUPERHEATERS AND REHEATERS

Superheaters and reheaters are inline tube bundles that increase the temperature of the saturated

steam. The superheaters, reheaters, and economizer are in the convection pass. There may be several

superheater sections. These may be arranged as platen, intermediate, final, and primary superheaters.

Reheaters are designed similar to the superheaters except they operate at lower temperatures. The gas

flow is from the final to the primary reheater. The steam temperature from the exit of the final



superheater and the final reheater is the steam temperature entering the turbine high pressure and

intermediate pressure turbines respectively.

Steam for steam sampling will be taken from the boiler top outlet stem piping. The superheater outlet

piping will contain spring loaded safety valves.

Drip pot drain and vent connections will be provided at the low and high points respectively.

3.2.3 REHEAT STEAM PIPES

The system between the high pressure turbine exhaust and the reheater inlet header is designated as

cold reheat. A reheat attemperator for reheat temperature control should be provided in each cold

reheat line. The system between the reheater outlet header and the reheat stop valves of the

intermediate pressure turbine of the turbine generator is designated as hot reheat. Steam for sampling

should be taken from the hot reheat outlet steam piping. The reheater outlet piping should contain

spring loaded safety valves.

3.2.4 ECONOMIZER

The economizer is a counter-flow heat exchanger for recovery of the heat remaining in the flue gasses

at the exit of the primary reheater and/or superheater. The tube bundle is usually a serpentine

arrangement of parallel tubes with the water flow opposite to the gas flow. Water enters the

economizer from the feedwater system and discharges to the furnace walls. Tube spacing is critical.

Close spacing has better heat transfer but can result in plugging of the spaces with ash.

3.2.5 STARTUP SYSTEM

The Units should be capable of performing two shifting operation, this means that during low load and

start-up period the boiler operates in sub-critical steam conditions. A suitable start up system should be

designed to provide a lower once-through minimum load. The system should include a water separator

system installed between the water walls and the primary superheater, a water storage tank and a drain

with drain recovery facility. Both the separator and the storage tank should be adequately sized to allow

prolonged low load operation. The drain recovery should include a low load recirculation pump to

maintain the required minimum flow in the economizer and water walls during start up and ‘wet

condition’ of the separator.

3.2.6 AIR PREHEATER

There are many air preheater designs. One of the common designs is a Lungstrom which uses a metallic

heat transfer surface that rotates at 1 to 3 revolutions per minute (rpm). Other designs use rotating

hoods with a stationary metallic heat transfer surface. Radial and axial seals are required to control

leakage between the air and gas sides. These seals must accommodate axial and radial growth in a

difficult environment. Some new designs include automatic seal adjustments depending on

temperatures.

The air preheater are used to warm the inlet air discharged from the forced draft fans from the hot gases

from the outlet of the boiler economizer. The size of the air heater depends on the evaluation of the

manufacturer to balance the size of the economizer and the size of the air heater. The air inlet to the air

heater is typically 27°C (80°F), and it is heated to about 300°C (570°F). The hot gases from the boiler



enter the air heater at about 400°C (750°F) and exit at about 150°C (300°F). Air heaters are usually the

regenerative type.

Each air heater is driven by a main electric motor. It is equipped with an auxiliary motor for spare for

remote control or automatic operation. Each air heater should be equipped with a manual rock arm for

the maintenance operation.

The air heater is installed with reliable and effective soot blowers on the gas side and water flushing

Equipment at the inlet and outlet on the air side. Flushing water system, waste water discharging system

installed in the boiler.

The heating surface at the cold end of the air heater is made of corrosion-resistant steel and made into

small packages to facilitate maintenance and renewal. Cleaning of the air preheater is done regularly on-

line with soot blowers and off-line loads with water wash.

3.2.7 SOOT BLOWERS

Soot blowers are designed to clean soot and slag from the heat transfer surfaces of the boiler and air

preheater. The number and location of the soot blowers will be determined by the boiler supplier based

on his experience with his boiler design and similar coals. Steam is supplied at a constant pressure usually

from the cold reheat pipe.

There are three general types of soot blowers: wall, retractable. Wall blowers use a stream of high-

pressure steam to remove slag from furnace walls. They are inserted into the furnace and rotate in a

circular pattern; typically 20 to 40 per furnace. Retractable soot blowers are used to clean convection

passes using a long lance that is rotated in to the section to be cleaned; typically 30 to 40 per furnace.

Their control systems have become increasingly sophisticated in recent years, and they are commonly

used for difficult coals.

3.2.8 PULVERIZER

Coal pulverisers are required to crush the coal to a uniform fineness and to evaporate moisture to ensure

efficient combustion. Modern coal-firing systems are direct-fire systems; that is, they move the coal and

hotair directly from the pulverizer to the burners with no intermediate storage. There are typically six to

eight pulverisers in the boiler. Based on the design coal, one spare pulverizer will be included in design.

Modern pulverizers are of the air-swept, vertical-shaft, roller type. They are low speed; the table rotates

at 20 to 35 rpm. The typical is driven by an electric motor, typically 375 to 520 kW (500 to 700

horsepower [hp]) through a reduction gear. The coal is crushed between the table and the rollers. A

classifier at the top of the pulverizer separates oversized particles and returns them to the grinding area.

Mills and integral classifiers should be protected by explosion vents. The size and position of the vents

should limit any pressure rise to safe levels. The discharge of the vents should be unobstructed and

should be to an area away from personnel access.

The hot primary air enters the pulverizer from the air preheater, it dries the coal and moves the coal

through the pulverizer and pipes to the individual burners.



3.2.9 BURNERS

The coal burners will provide stable and efficiently combustion of the pulverised fuel and minimize

emissions of oxides of nitrogen (NOx), unburnt carbon in dust and carbon monoxide (CO) for the range

of fuels specified. Low NOx firing system should be used. The coal burners and firing sequence will be

designed in conjunction with the furnace, coal milling facilities and forced draft fans.

Burner management system will be in full compliance with NFPA standard.

The coal burners/coal combustion system will be sized such that it is possible to achieve BMCR with

the design number of burners in service.

The burner shall be fitted with adequate lifting and handling arrangements for erection and

maintenance purposes.

Where a coal burner quart is required it will be of the pre-fired Silicon Carbide tile type. The coal

burner quarts shall incorporate positive design features to prevent the occurrence of quart slagging

and slag eyebrow formation.

Coal burners with non-variable geometry are preferred. Where geometry adjustments are required

for commissioning/optimisation purposes, such adjustment shall be carried out locally, and then

locked for normal operation.

The burner components liable to heat distortion (for example PA/PF front end, swirl generation

system, etc.) shall be sited away from the furnace and therefore the main heat source as far as

possible. The cooling requirements of out of service burners/air nozzles shall be minimized by

positive design features.

3.2.10 SYSTEM OPERATION

In normal operation, the fuel is gravity fed to the feeders from the coal silos. The feeders regulate the

coal flow to maintain the steam generation required by the turbine. The coal then drops into the

pulverizers where it is crushed to a controlled fineness, and then blown into the furnace by primary air

where it is combined with secondary air and combustion occurs. The radiant heat and hot gases then

cause the water in the furnace to be heated to steam.

The combustion air is supplied by forced draft fans, through the air heaters and into the furnace. The

gases are then drawn through the superheaters and back passes the air heater and precipitator.

3.3 TURBINE GENERATOR

The steam turbine-generator converts the energy in the steam to electrical energy. The steam is then

discharged to the condenser.

The steam turbine is a tandem-compound three or four casing design, depending on the manufacturer.

The turbine-generator will operate at 3,000 rpm. Extraction steam is routed from various sections of the

turbine and routed to the feedwater heaters. The cycle is based on eight feedwater heaters, four low-

pressure heaters, one deaerator heater, and three high-pressure heaters. The first one or two heaters

will be installed in the condenser neck.

The following major components are supplied with the turbine:

High-pressure turbine



Intermediate-pressure turbine

Low-pressure turbine

Lubricating oil reservoir, pumps and piping

Electrohydraulic control (EHC) oil system

Generator

Hydrogen seal oil system

Exciter

Control system

These components are discussed individually below.

3.3.1 HIGH-PRESSURE TURBINE

The high-pressure turbine (HP) receives steam from the main steam pipe and expands it through several

stages of blades. The steam that exits the HP turbine returns to the boiler through the cold reheat pipe.

In the boiler, the steam is heated to the design reheat temperature and returned to the intermediate-

pressure (IP) turbine.

3.3.2 INTERMEDIATE-PRESSURE TURBINE

The steam is further expanded in the IP section. It is then brought to the low-pressure (LP) turbines by

the crossover pipe at a temperate of about 400°C (750°F).

3.3.3 LOW-PRESSURE TURBINE

The steam is split between the LP turbines because it is technically impractical to build 600 MW or larger

LP turbines large enough to pass the high volume of low-pressure steam. LP turbine is double flow,

meaning that the steam enters at the center and flows out axially towards both the turbine end and the

generator end. This is called a four-flow machine. Large steam turbines have last-stage blades that are

about1.1 to 1.2 meters (42 to 48 inches) long.

The most significant part of the power plant performance improvement is the turbine improvement.

All turbine sections have benefited in the past decades by improved blade designs that have improved

efficiency and reliability.

3.3.4 LUBRICATING OIL SYSTEM

The lubricating oil system includes the oil tank, pumps, coolers, piping and controls the supply of clean

oil to the turbine and generator bearings. The oil tank contains 7.5 m3 (2,000 gallons) or more of

lubricating oil, pumps, and piping. The pumps are usually vertical pumps with the suction below the low

oil level and the electric motors above the tank.

The main, auxiliary, and emergency pumps discharge to a header, where the oil is cooled to the design

supply temperature, filtered, and distributed to each of the turbine and generator bearings. The oil

discharged from the bearings is collected and drained by gravity to the tank.



3.3.5 ELECTROHYDRAULIC CONTROL OIL SYSTEM

The EHC oil is a high-pressure oil system used to control the stop and control valves that regulate the

admission of steam to the turbines. The system is constructed of mostly stainless steel components to

maintain the required high level of cleanliness required. A fine filtering system also helps achieve the

cleanliness.

3.3.6 GENERATOR

The generator is directly coupled to the turbine shaft. The generator converts the mechanical energy

developed in the turbine to electrical energy. The generator is filled with hydrogen gas to reduce the

wind age losses caused by the cooling flow inside the generator.

3.3.7 HYDROGEN SEAL OIL SYSTEM

This system supplies a constant flow of lubricating oil from its tank to the seals at each end of the

generator stator. The hydrogen seal oil system seals the shaft ends of the generator rotor to reduce the

escape of hydrogen from the generator. This oil is collected and drained to degassing systems and the

seal oil tank. It is also cooled in a similar manner to the lubricating oil system. Hydrogen gas is explosive,

so this system is critical to the safe operation of the plant.

3.3.8 STATIC EXCITER

To control the voltage and phase angle of the power generated in accordance with system needs.

The static exciter supplies the electrical energy to the generator rotor (field).

3.3.9 CONTROL SYSTEM

The turbine manufacturer is to supply the turbine control system to interface all parts of the turbine

generator. Among the items controlled are the steam stop and control valves.


During normal operation, the steam is admitted to the HP turbine through the stop and control valves.

After the steam is expanded through the HP turbine, it is returned to the boiler to be heated to the

design temperature in the reheater section. The reheated steam then expands through the IP turbine

and the LP turbines.

The steam flow is limited by the control valves to achieve the required load. Steam is extracted from the

turbine at several points for use in the feedwater heaters, which improves cycle efficiency. The amount

of steam extracted will not be regulated with a control valve and is therefore termed uncontrolled.

The oil for the bearings of the turbine and generator is supplied from lubricating oil system. Pumps take

suction from the tank and after-coolers deliver the oil to each of the bearings to lubricate the surfaces

and remove heat. The oil then returns to the main tank.

A separate high-pressure oil system EHC is used to open and close the stop and control valves as needed.

The valves are opened to add more steam as load is increased and closed to reduce load. The valves also

close quickly to prevent over-speed in case load is reduced quickly or tripped.



The hydrogen seal oil system is a hydraulic seal between the generator stator and rotor to contain the

hydrogen gas inside the generator.

3.4 MAIN STEAM AND REHEAT PIPING

3.4.1 FUNCTION

The major steam systems include the main steam, cold reheat, hot reheat, and extraction steam pipes.

3.4.2 MAIN STEAM

The main steam pipe will carry the steam from the boiler superheater outlet to the steam turbine stop

and control valves. Due to the operating temperature, this pipe is typically made of P91 or P92 material.

3.4.3 COLD REHEAT

The steam from the HP turbine outlet to the inlet of the boiler reheater will be transported by the cold

reheat pipe. Due to the operating temperature, this pipe is typically made of carbon steel.

3.4.4 HOT REHEAT

The steam from the reheater outlet to the IP turbine inlet stop valves will be carried by the hot reheat

pipe. Due to the operating temperature, this pipe is typically made of P91 or P92 material.

These pipe systems will be designed for the steam conditions established on the heat balances for the

specific boiler and steam turbine selected and the requirements of the American Society of Mechanical

Engineers (ASME) codes or equivalent international standards. The reheat pipes are sized to result in a

low pressure drop that is set by the turbine designer. The main steam pipe for supercritical unit is

typically designed for a maximum of 12 bar (175 pounds per square inch [psi]) pressure drop, and a

maximum velocity of 100 m/s (20,000 feet per minute [fpm]).

3.4.5 EXTRACTION STEAM

The steam from the turbine connections to the feedwater heaters will be carried by the extraction steam

systems. The pressure drop is set by the instructions of the turbine manufacturer and is usually 5% of

the stage pressure.

The shut-off valves and air-assisted check valves as required by code and turbine manufacturer

requirements will be fitted on the extraction pipes.

The condensed steam in the feedwater heaters is termed heater drains. These drains are cascaded from

the higher pressure heaters to the next lowest operating pressure heater. The lowest-pressure HP

heater is drained to the deaerator. The lowest pressure LP heater is drained to the condenser. All

feedwater heaters are also provided with emergency heater drains, which can drain any heater to the

condenser. This capability is needed when heaters are out of service, if leaks occur in the heater tubes,

and at start-up.

All the steam systems will have drain systems. These include drain pots, drain pipes, level detectors, and

drain valves.

The deaerator heater is a direct contact heater; it has no tubes. Also it has no heater drain; the drain is

the suction connection to the feedwater pumps.




The steam will flow through the main steam line to the HP turbine inlet during normal operation. Steam

exhausted from the HP turbine will flow through the cold reheat line to the steam generator reheater

inlet. The steam is reheated in the steam generator and will flow through the hot reheat line to the IP

turbine inlet.

The cold reheat line generally supplies steam to the seventh feedwater heater (depends on the turbine

design).

This, like all extractions, will be uncontrolled.

The steam from the individual turbine connections to the feedwater heaters will be carried by extraction

steam pipes. The isolation and check valves are designed to isolate the feedwater heaters from the

turbine during a turbine trip. This capability will prevent turbine over speeding due to the energy stored

in the heaters. Feedwater heaters installed in the condenser neck do not require this isolation because

of the relatively low energy stored.

The heater drains will normally drain to the lower pressure heater. During start-up, however, there is

commonly inadequate pressure to accomplish this, so the heater is drained to the condenser. Also, if a

tube leak occurs in a heater, the higher pressure water will leak into the shell. This will increase the flow

of the heater drain. If a high level occurs in the heater shell, the emergency drain will open to the

condenser. Relief valves will open to protect the heater shell from overpressure if the pressure exceeds

the design pressure.

When heaters are out of service, the maximum load of the turbine may be reduced due to the increased

steam flow through the LP turbine. This criterion is set by the turbine supplier and will depend on the

project requirements and the supplier’s design specifics.

The water damage induction prevention system is automatically controlled by the instrumentation and

the distributed control system (DCS) system.

3.5 CONDENSATE

3.5.1 FUNCTION

The condensate system transfers the condensed steam from the condenser hot well, through the low-

pressure feedwater heaters, and into the deaerator heater.

3.5.2 DESIGN BASIS

The condensate system will be designed to provide a continuous supply of water from the condenser to

maintain a constant level in the deaerator heater.

Motor-driven condensate pumps, will take suction through strainers from the condenser hot well, there

will be three 50% capacity, or two 100% capacity. These pumps are typically vertical can-type pumps

with the cans mounted in the concrete substructure. A bypass system, with an automatic control valve,

will be provided to ensure the required minimum flow through the pumps. There will be a margin of 3%

in flow and 10% in head in the pump design to account for wear and unknowns. A bypass system, with

an automatic control valve, will be provided to ensure the required minimum flow through the pumps



The condensate will also be pumped through the steam jet air ejector if that is the system selected by

the EPC contractor; rotary vacuum pumps may be used.

The system transfers the water through the condensate polisher, gland steam condenser, and three

low-pressure feedwater heaters. The temperature of the water is increased in each of the feedwater

heaters. Also, water is supplied to the turbine hood sprays and other uses as required.

The condensate is deaerated in the condenser and is further heated and deaerated in the deaerator.

The deaerator is elevated to provide adequate net positive suction head for the boiler feed pumps.

Drains from the gland steam condenser and feedwater heaters will be returned to the condenser.


The condensate pumps take suction from the condenser hot well and discharge to a common header.

During normal operation, makeup water will be delivered to the condenser from the condensate

storage tank to maintain the normal water level in the hot well. This flow is normally accomplished by

the elevation in the condensate tank and the negative pressure in the condenser. Pumps will be

provided to deliver the required water in cases of low water level in the tank or high demand.

Normally, one pump will operate at start-up, and up to 60% load. Above 60% load, a second pump will

be started. If a pump trips or if header pressure is below a predetermined level, then the third pump will

be started automatically.

The bypass system will be controlled by the DCS system. It is typically wide open at initial start-up,

gradually closes as flow through the system increases, and is closed when the unit load approaches full

load.

3.6 FEED WATER

3.6.1 FUNCTION

The feedwater system will be designed to provide a continuous supply of water from the deaerator

heater to the boiler.

3.6.2 DESIGN BASIS

To ensure the continuous supply of water from the deaerator heater to the boiler the feedwater system

will be designed accordingly.

There will be two motor driven 50% capacity, or two turbine-driven 50% capacity feedwater pumps,

and one 40% motor-driven start-up pump feedwater pumps. The final decision on turbine-driven

pumps or motor-driven pumps will be up to the EPC contractor. In general, the studies done comparing

these designs indicate that there is little or no difference in the total evaluated cost. The capital cost will

be higher for the turbine-driven option but operating costs will be reduced. In either case, the net plant

output will not be changed.

Typically these pumps are barrel-type with the barrel supported on a steel base. The pump are designed

to account for wear and unknowns, there will be a margin of 3% in flow and 10% in head. A bypass

system, with automatic control valve, will be provided to ensure the required minimum flow through

the pumps.



These pumps typically use a variable-speed drive. The variable speed allows the pump to operate at

close to the minimum speed required for the load at any particular time. The variable speed may be

achieved by variable speed motors or fluid couplings. This capability reduces the power requirements,

recirculation flow, and wear of the pump. The wear on the pump is a particularly significant factor during

start-up if variable speed is not provided.

The system transfers the water through the high-pressure feedwater heaters. The temperature of the

water is increased in each of the feedwater heaters. Also, water is supplied to attemperators and other

uses as required. The water to the reheat attemperators is supplied from an interstage connection on

the pumps.


The feedwater pumps take suction from the deaerator and discharge to a common header. The header

is the main feedwater line which connects to the HP feedwater heaters. The discharge from the last

heater connects to the boiler economizer inlet.

At start up and up to 60% load normally, one pump will operate A second pump will be started above

60% load. If a pump trips or if header pressure is below a predetermined level, the second pump will be

started automatically.

The pump speed and the bypass system will be controlled by the DCS system. The bypass is typically

wide open at initial start-up, gradually closes as flow through the system increases, and is closed when

the unit load approaches full load.

3.7 CIRCULATING WATER SYSTEM

3.7.1 FUNCTION

The main condenser and the closed cooling water system will be cooled by the circulating water system.

The heated sea water will be returned to the circulating water discharge channel and to the Arabian Sea.

A small portion of the water will supply the desalination system makeup water.

A portion of the condenser discharge water will be pumped to the seawater FGD system when FGD

system is in operation. This water will be returned to the condenser discharge water after aeration. This

is discussed in the seawater scrubber section.

3.7.2 DESIGN BASIS

A once-through seawater cooling system will be used, with two 50% pumps per unit. Vertical wet-pit

mixed-flow type pumps and will be installed in the circulating water pump house adjacent to the intake

channel.

The total flow will be 78,000 m3/h based on an 8.5°C temperature rise through each condenser.

Part of the circulating water will flow through the seawater FGD system after it passes through the

condenser. That will add up to one-half an additional degree of temperature rise through the system.

Therefore the thermal plume analysis in the Environmental Impact Assessment was based on 9°C

temperature rise.

The system will include expansion joints at the pump discharges and at the inlet and outlet of the

condenser.



The condenser will be a one- or two-pass unit with valves to allow part-load operation with one half the

condenser out of service.

The system will include motor-operated valves that will allow single pump operation and isolation of

one half of the condenser for maintenance.

A condenser tube cleaning system will be provided to permit periodic cleaning with the unit on line.

A hypochlorite system will be included to protect the system from biological growth. This system will

produce a hypochlorite product from a small portion of the seawater. This will be injected into the

circulating water pipe.

Screens will be provided to protect the pumps and prevent condenser clogging from objects in the sea

water.

Screens will be cleaned periodically based on pressure drop. The screen size will be about 1 cm. There

will be provisions to capture the debris screened from the water. Any fish caught in the screens will be

returned to the sea.

Stop logs will be provided to allow dewatering each pump house.

Maintenance for the pumps and traveling screens will be provided by a gantry crane.


The circulating water pumps will draw water from the pit and discharge through motor-operated

discharge valves.

The discharge from the individual pumps will be combined to a common pipe; at the condenser the pipe

will split to the individual inlets. Depending on the seawater scrubber vendor, the seal well and the

aeration pond may be combined into a single structure. The discharge will be combined to a single

header that will discharge to a seal well and into the aeration pond. The aeration pond/chamber will

discharge to the discharge channel.

The circulating water pumps will operate in parallel. For low-load operation, start-up, and if one

circulating water pump is out of service for maintenance, the unit can be operated at reduced load. The

level of that load will depend on the seawater temperature.

The tube cleaning system will be operated as needed to optimize the operation of the unit based on

backpressure and cleaning system operating costs.

3.8 CLOSED COOLING WATER SYSTEM

3.8.1 FUNCTION

All water-cooled equipment in the plant except the main condenser will be cooled by closed cooling

water system. The system will use a portion of the circulating water system flow, which is seawater, to

cool a closed-loop freshwater system. The heated seawater will be returned to the circulating water

discharge.



3.8.2 DESIGN BASIS

Demineralized water will be used in the system for initial filling and makeup as needed. The water will

be treated with corrosion inhibitors to minimize corrosion in the piping and heat exchangers. Two 100%

capacity pumps will pump the fresh water through the two 100% capacity heat exchangers and the

cooled equipment, through a closed system, and return to the pump suction. An expansion tank will be

provided to accommodate the thermal expansion and provide a supply of water for makeup required

by small leaks.

The system will provide cooling water to the following equipment:

Main turbine oil coolers

Generator hydrogen coolers

Exciter coolers

Generator stator oil coolers

Boiler auxiliaries (as needed)

Feedwater pump coolers

Water and steam sample coolers

Large motor coolers (if required)

Air compressors (if required)

At least 5% flow margin will be included in the closed cooling water pump design. The heat exchangers

will include at least 10% heat duty margin.

If there is adequate pressure drop through the condenser system, seawater pumps may not be

required. A small 20% capacity pump will be provided to pump seawater through the heat exchanger

for testing and outage operation when the circulating water system is not in use.

The heat exchangers will be the plate-and-frame type with plates, or tube type, suitable for seawater

duty.

A means of chemical addition will be provided without the expansion tank being opened. Each unit will

have a completely independent system.


One of the two closed cooling water pumps will circulate water continuously through the loop during

normal operation. To maintain at least a 30% flow through the pump and heat exchanger an automatic

bypass valve will be provided. The second pump will be in standby. The second pump will start

automatically on low header pressure or a trip of the first pump.

A low water level in the expansion tank will be alarmed in the control room. Water will be added through

a manual valve from the demineralized water system.

A grab sample valve will be used to periodically obtain a sample for testing.

Automatic temperature control valves at each of the major coolers will control the equipment

temperature. Small coolers may be manually controlled.



3.9 HYPOCHLORITE GENERATOR

3.9.1 FUNCTION

The hypochlorite system manufactures a dilute solution of sodium hypochlorite (bleach) from seawater,

which is used for biofouling control in the once-through circulating water system.

3.9.2 DESIGN BASES

The electro chlorination system will be designed based on the following parameters:

Circulating water design flow rate

Low level continuous chlorination dosage of 1 ppm for 22.5 hr/day

Shock chlorination dosage of 3 ppm for 1.5 hr/day

Based on the above requirements, there will be three 50% electro chlorination skids: one for each unit

plus a common spare. Seawater will be the influent to the system.

3.9.3 DESCRIPTION

The system consists of three 50% electro chlorination skids. Each skid contains the required quantity of

modules to convert the chloride in seawater to sodium hypochlorite according to the following reaction:

NaCl + H2O → NaOCl + H2

The electro chlorination skids require direct current. One or more transformer/rectifiers will be provided

to convert AC power to DC power.

Seawater entering the electro chlorination system first passes through strainers to remove relatively

large particulate matter. The strained seawater then flows directly through the electrolytic cells where

the dilute sodium hypochlorite is produced.

As indicated in the above chemical reaction, hydrogen is a by-product of the electrolytic manufacturing

of bleach. In addition, the flow rate of dilute sodium hypochlorite being supplied to the circulating water

system varies throughout the day depending on whether low-level continuous dosing or shock dosing

is being applied. One or more hydrogen release/product storage tanks will be supplied to vent hydrogen

to the outside air and to allow the electro chlorination skids to be base-loaded as the dosage varies

throughout the day. A blower and hydrogen monitor are provided to safely vent the hydrogen. Two sets

of pumps for low-level continuous and shock dosing, respectively are provided to take suction from the

storage tank(s) and to transfer the dilute bleach solution to the circulating water system of each unit.

The electrolytic cells will gradually accumulate chemical scale over a period of time. A portable acid-cart,

consisting of an acid dosing tank and recycle pump are provided to chemically clean the electrolytic cells

on an as-needed basis.

3.9.4 NORMAL OPERATION

During normal operation, two of the three electro chlorination skids are operated at relatively constant

power input and seawater flow to produce the required daily output (kg Cl2 equivalent/day) of dilute

sodium hypochlorite. For approximately 22.5 hr/day, a low-level continuous dosage of product is



applied to either the intake structure or the condenser inlet. For approximately 1.5 hr/day, a high-level

shock dosage is applied at these same locations.

3.9.5 ABNORMAL OPERATION

The system is continuously monitored for several key operating parameters, including transformer/

rectifier internal temperature, DC current to each skid, air flow, and hydrogen concentration in storage

tank vents. Any abnormal parameters can trigger a shutdown of the entire system or a portion of the

system and require bringing the spare electro chlorination skid on-line.

3.10 DESALINATION

3.10.1 FUNCTION

Majority of dissolved and suspended impurities from seawater will be removed by the desalination

system, allowing the treated water to be used for service water and makeup to the potable water

treatment system and demineraliser systems.

3.10.2 DESIGN BASIS

The desalination system with two 50% trains will be provided for the plant. The desalination system will

be designed based on the following parameters:

Seawater analysis in accordance with data available data

Maximum service water requirement

Maximum potable water requirement

Maximum demineralized water requirement

The desalination system is essentially a two-pass reverse osmosis (RO) system consisting of a first-pass

seawater RO unit with pre-treatment and a second-pass freshwater RO unit. Based on the above

requirements, each 50% train of the seawater RO unit will be designed to produce half of the maximum

flow of desalinated water.

Similarly, each 50% train of the freshwater RO unit will be designed to produce half of the maximum

flow of treated water suitable as makeup to the demineralizer system.

3.10.3 DESCRIPTION

As stated above, the desalination system is essentially a two-pass RO system with pre-treatment.

Seawater from the intake structure that enters the desalination system is first treated in a two-stage,

multi-media filtration system that includes coarse and fine filtration, respectively. Coagulants and

polymers may be added to the raw seawater to assist in the filtration process. The filtered seawater then

passes through cartridge filters and enters the suction of the first-pass RO booster pumps that provide

the necessary pressure to pump the seawater through the first-pass RO units. Chemicals are added at

the inlet of the first-pass RO units for pH and scale control and dechlorination. The desalinated water

that passes through the first-pass RO units enters the service water storage tank. The service water

storage tank is provided with three sets of transfer pumps. One set will pump the desalinated water to

various users within the service water system on a near-continuous basis. A second set will pump the

desalinated water to the potable water treatment system on an intermittent basis on demand. A third



set will pump the water to the inlet of the second-pass RO booster pumps and through the second-pass

RO units to the demineralized water storage tanks.

The desalination system produces wastewater streams associated with filter backwashing and the

dissolved solids that are rejected by the first-pass RO units (brine). The backwash and brine streams are

sent to a local sump and then routed to the plant’s wastewater treatment system. There is also a

relatively good quality brine stream associated with the second-pass RO units that is recovered and

recycled to the inlet of the first-pass RO units.


During normal operation, the pre-treatment system and first-pass RO units are operated intermittently

at their rated capacity based on level in the service water storage tank. Chemicals are automatically

added to the pre-treatment and first-pass RO units based on flow and signals from analytical

instruments for pH, oxidation-reduction potential, etc. Coarse filters are backwashed daily, and polishing

filters are backwashed weekly, as required. When the first-pass RO units are operating, there is a

continuous stream of brine that is routed to the wastewater treatment system along with the

intermittent filter backwash.

The second-pass RO units are operated intermittently at their rated capacity based on level in the

demineralized water storage tanks. When the second-pass RO units are operating, there is a continuous

stream of brine that is routed to the inlet of the first-pass RO units.

Depending on demand, one or both trains in either the first- or second-pass systems may be on standby

for extended periods of time. Provisions are included to periodically flush the membranes in each RO

pass to prevent bio-growth and maintain cleanliness.

The RO units are taken out of service and chemically cleaned annually or semi-annually based on

operating history and performance. The membranes are replaced at three- to five-year intervals, again

depending on operating history and performance.


The plant will be tracking the normalized performance of the desalination system using software that

trends output and quality of the treated water and accounts for factors such as the age of the

membranes and seawater temperature. When the normalized performance drops below the expected

trend line, it will be necessary to take appropriate remedial measures, which may include adjusting the

chemical feed rates or product recoveries or taking the units out of service to either chemically clean or

replace the membranes.

3.11 DEMINERALIZATION

3.11.1 FUNCTION

The demineralizer system provides final polishing of the treated effluent from the second-pass RO units

of the desalination system and produces ultrapure water for boiler and other power plant user such as

chemical laboratories; sample analysis, closed cycle cooling water system etc.



3.11.2 DESIGN BASES

One common demineralization system with two 100% trains will be provided for the plant. The

demineralization system will be designed based on the following parameters:

Second pass RO effluent quality in accordance with supplier guarantees

The DM system capacity will be design considering 1.5% BMCR, CCCW makeup, other plant usage

and plus the self-consumption.

The effluent quality will be as shown below.

Table 3.3 – Demineralizer System Effluent Quality

Sodium, ppb < 3

Chloride, ppb < 3

Sulphate, ppb < 3

Silica, ppb ≤ 10

Specific conductivity, μs/cm ≤ 0.15

The demineralization system is essentially a polishing mixed-bed facility complete with the necessary

regeneration equipment.

3.11.3 DESCRIPTION

As stated above, the demineralization system is essentially a polishing mixed-bed facility complete with

the necessary regeneration equipment. Treated water from the second-pass RO units is pumped from

the demineralized water storage tanks through the mixed-bed polishers into the condensate storage

tanks.

Instrumentation is included to monitor the effluent quality from the demineralizer system and to

determine when regeneration of a mixed-bed polisher is required. A complete regeneration facility is

provided including acid and caustic storage tanks and metering skids, hot water tank, regeneration

water pumps, and mixed-bed blowers. Regenerant wastewater is collected in a local building sump and

pumped to the industrial wastewater treatment facility.


During normal operation, the demineralizer system is operated intermittently at its rated capacity based

on the level in the condensate storage tanks. The service cycle continues for a pre-set time or throughput

or until the effluent quality indicates that regeneration is required. Under normal operating conditions,

mixed-bed regenerations will probably be required weekly or semi-weekly. When regeneration is

required, the operating mixed bed is taken out of service and the spare unit is placed in operation.

Regeneration is automatic following manual pushbutton initiation and includes several steps for

resin separation, regeneration, rinsing, and mixing of the cation and anion resins. After regeneration

has been completed, the mixed-bed polisher is placed in standby and is ready for service when the other

operating unit becomes exhausted.

Wastewater produced during the regeneration process is sent to a local building sump from which it is

pumped to the industrial wastewater treatment facility.




Abnormal operation would correspond to a situation in which the mixed bed run length is significantly

reduced and/or the effluent quality is adversely affected. In this situation, an investigation would need

to be performed that would evaluate key parameters including feedwater quality, resin condition,

quality of regenerant chemicals, and more in order to determine the appropriate corrective actions.

3.12 CONDENSATE POLISHING

3.12.1 FUNCTION

The condensate polishing system removes ionic and suspended contaminants from the condensate,

allowing feedwater cycle chemistry to be maintained in accordance with industry guidelines and the

requirements of the boiler and turbine manufacturers.

3.12.2 DESIGN BASES

One complete condensate polishing systems will be provided. There will be three 50% condensate

polisher vessels. The condensate polishing system associated with each unit will be designed based on

the following parameters:

Condensate flow rate at 100% load, valves wide open (VWO)

Condensate pump shutoff head

Maximum condensate temperature

3.12.3 DESCRIPTION

A full-flow deep-bed condensate polishing system is provided. The system associated with each unit

consists of three 50% condensate polisher service vessels. A resin trap is provided at the outlet of each

service vessel to remove any resin fines. Each service vessel also includes a recycle pump that is used

when a vessel containing a freshly regenerated resin charge is being placed in service. A sampling system

is provided to monitor the level of contaminants at the common inlet of the system and the outlet of

each service vessel.

The condensate polisher resin is externally regenerated. The exhausted resin is hydraulically sluiced to

the external regeneration system. One complete external regeneration system is provided for each unit.

The external regeneration system consists of four vessels for resin separation, cation regeneration,

anion regeneration and mixing, and holding of the freshly regenerated cation and anion resin.

Alternately, the regeneration system may include a resin separation vessel that serves a dual purpose

and is also used to regenerate either the cation or anion resin. A freshly regenerated resin charge in the

mix-and-hold vessel is eventually hydraulically transferred back to a service vessel. As discussed above,

the service vessel that has received the freshly regenerated resin is put in recycle mode for a short period

after being returned to service to ensure that any contaminants will not enter the feedwater cycle.


During normal operation, two of the three-condensate polisher service vessels will treat the full

condensate flow. When the resin in one of the two operating service vessels is exhausted as determined

by either conductivity or differential pressure, the vessel is removed from service and the resin is



transferred to the external regeneration system. The standby service vessel containing a freshly

regenerated resin charge is slowly placed in service by first recirculating condensate through the vessel

until the effluent quality is acceptable.

Oxygenated water treatment (OWT) is the recommended mode of operation for a new supercritical

coal-fired unit. In this mode of operation, oxygen is deliberately injected into the condensate and/or

feedwater and the pH is maintained in the range of 8.0 to 8.5. At this low pH, the frequency of

regeneration of each service vessel is approximately once per month. If it is necessary to use

conventional all-volatile treatment (AVT), the operating pH will be in the range of 9.2 to 9.6 and the

frequency of regeneration will be increased to once every few days.

Condensate polishers used in supercritical coal-fired units should be operated in the hydrogen cycle, so

the run length is directly related to the operating pH and the level of ammonia in the feedwater cycle.


Abnormal operation may correspond to a situation in which it is necessary to operate with AVT in lieu

of OWT treatment. As stated above, the run length of each service vessel and individual resin charge is

significantly reduced in this operating mode.

Abnormal operation may also correspond to a situation in which condenser leakage occurs. Because the

condensers will have welded titanium tubes, this is not expected to be a normal occurrence. When

condenser leakage occurs, the frequency of regeneration will increase and the polisher effluent quality

may be adversely affected. Condenser leaks larger than about 0.06 to 0.12 L/s (1-2 gpm) will probably

result in shutdown of the unit because the external regeneration system will be unable to regenerate

individual resin charges faster than the rate at which they become exhausted. Also, the polisher effluent

quality will probably be unacceptable because supercritical units do not have blowdown except during

start-up.

3.13 WASTEWATER SYSTEM

3.13.1 FUNCTION

The wastewater system treats industrial and sanitary wastewater from the power plant to produce

effluent of an acceptable quality that can be used or discharged through the effluent flume of the

circulating water system.

3.13.2 DESIGN BASIS

Wastewater treatment system with a single 100% train will be provided to treat process wastewater

generated by the plant. The wastewater treatment system will be sized for the maximum expected flow

based on the plant water balance.

The wastewater treatment system will be designed to produce treated effluent in accordance with the

following requirements:

Table 3.4 — Wastewater Treatment System Effluent Requirements

Parameter Value

Total Suspended Solids < 30 mg/L

pH 6 - 9.0

Oil and Grease < 15 mg/L



A sanitary treatment facility will be provided to treat domestic wastewater from the power plant and

colony.

3.13.3 INDUSTRIAL WASTEWATER TREATMENT

At various locations within the plant, there will be sumps and packaged oil-water separators for the

interim collection of wastewater and treatment of oily wastewater, respectively. Mixed bed

demineralizer and condensate polisher regenerant wastewater will be treated at the power block in a

packaged neutralization system consisting of a tank with internal mixing device, recirculation pumps, pH

controls, and chemical addition systems. All remaining wastewater will be pumped to one of two

equalization ponds. One pond will provide collection and interim storage of low-volume wastewater

and material storage runoff. The other pond will provide collection and interim storage of metal cleaning

wastewater.

Wastewater from pond will be treated separately on an as-needed basis in a common physical-chemical

treatment system. The wastewater treatment process is expected to include several steps. Raw

wastewater introduced to the treatment process first enters a reaction tank where lime or caustic is

added to raise the pH.

After pH adjustment, the wastewater enters an oxidation tank with air sparging where metals are

oxidized and precipitated as metal hydroxides. The wastewater stream containing precipitated metals

and other solids then enters a flocculation tank followed by a lamella (inclined plate) clarifier in which

solids are removed.

After the final treatment step, the wastewater enters the effluent monitoring basin from which it is

pumped to the circulating water discharge flume. The components of the treatment process are

arranged to allow gravity flow throughout the entire process into the monitoring basin. The treatment

process includes a thickener and filter presses for mechanical sludge dewatering such that a solid waste

by-product is produced that can be landfilled.

3.13.4 SANITARY WASTEWATER TREATMENT SYSTEM

Several lift stations will be provided for transporting raw sewage from the main power block and

outlying areas to the sanitary treatment system.

The concrete basin extended-aeration type sewage treatment plant equipment contains an integral

submerged bar screen at the inlet to the surge tank compartment. Dual sewage pumps provide a flow

to the aeration tank chamber based on the depth of water in the surge tank. Flow from the aeration

chamber to the dual hopper clarifier is by gravity. Aeration blowers are mounted above the aeration

tank and supply air to the biological treatment process. The resulting solids are settled into downstream

clarifier hoppers while floating solids are skimmed from the clarifier surface and returned to the aeration

chamber. The clarified effluent flows into an integral chlorine contact tank where sodium hypochlorite

is added before discharge.

There is an integral airlift system for the return of settled solids from the clarifier hoppers to the aeration

basin.

The treated sanitary effluent will be used for watering of the greenbelt surrounding the power plant and

within the colony.




During normal operation, the mixed bed demineralizer and condensate polisher systems are each

regenerated intermittently. Interlocks are provided so that only one system can be regenerated at a

time. When regeneration occurs, the wastewater is pumped from a local sump to the neutralization

system. After the regeneration process has been completed, the wastewater is recirculated through the

neutralization tank and acid or caustic is added for pH adjustment. After the wastewater has been

sufficiently neutralized, the recirculation step is terminated and wastewater is pumped to the effluent-

monitoring basin.

Other low volume and material storage runoff wastewater generated within the power plant will

gradually accumulate within the first equalization basin. After a sufficient volume of wastewater has

been collected, transfer pumps within the pond are turned on to forward the wastewater to the

treatment system. The treatment system is operated at its rated capacity until the pond has been

sufficiently emptied. During operation of the treatment system, the monitoring basin is continuously

sampled for pH and grab sampled for other constituents as required, and wastewater continues to be

discharged as long as the effluent quality is within specification.

While the treatment system is operating, dewatered sludge is being produced on a semi-continuous

basis and collected within dumpsters that are periodically transported to an on-site landfill.

The second equalization basin is used to store metal cleaning wastewater including air heater wash and

boiler chemical cleaning waste. These streams are generated in large quantities on a very intermittent

basis, only when these operations occur. After the washing or cleaning operation has been completed,

the treatment system is used to process metal cleaning wastewater until the pond has been sufficiently

emptied.


Abnormal operation corresponds to a situation in which the treatment system is unable to operate at

its rated capacity and/or the effluent quality is adversely affected. In this situation, an investigation

would be performed to determine the root cause(s) of the operating deficiencies so that the appropriate

corrective actions can be taken.

Abnormal operation may also correspond to a situation in which excessive quantities of wastewater are

being generated. This situation is likely to occur during initial start-up of the units. To some extent, the

equalization ponds as well as the treatment system itself will have some design margin. However, when

the levels in the ponds remain high for extended periods despite operating the treatment system at high

capacity factor, it would be prudent to determine the root cause(s) and take the appropriate corrective

action.

3.14 EMISSION CONTROLS

3.14.1 LOW NOx BURNERS

3.14.1.1 FUNCTION

When air is used as the source of oxygen for combustion, the heat of combustion causes significant

conversion of nitrogen and oxygen to various oxides of nitrogen (NOx). The Project will be outfitted with

low-NOx burners, designed to keep NOx generation to a minimum.



3.14.1.2 DESIGN BASIS

The burners are expected to operate at an emission rate of 710 mg/Nm3.

3.14.1.3 SYSTEM OPERATION

Low-NOx burners achieve their objective by measuring and controlling fuel flow and air flow at each

individual burner, rather than relying only on a single overall mixture. Also, the burners contain spin

vanes and other aerodynamic devices to obtain the best possible mixing of the fuel and air as they enter

the furnace. In this way, zones of imperfect fuel/air mixture are minimized. Zones of imperfect mixing

typically run too hot, which causes NOx to form.

The design and arrangement of the coal combustion system should be such that when operating in

conjunction with the ignition and support firing Equipment continuous furnace firing can be maintained

when bringing the steam raising unit up to full load from cold conditions without damage to any part of

the unit.

3.14.2 SEAWATER FGD

3.14.2.1 FUNCTION

All the sulphur is converted to sulphur dioxide (SO2) gas, during coal combustion. A flue gas

desulfurization (FGD) system will be used when burning a coal that would produce emissions in excess

of the limit.


The FGD system is expected to operate at an emission rate of 850 mg/Nm3. SWFGD system will be

bypassed when burning coals less than this emission rate. Most of the coals that are anticipated for the

Project will not require any SO2 removal. The FGD system will operate only when coals or blends of coals

that will have an emission rate higher than 850 mg/Nm3 are used.


Seawater discharged from the condenser will be used in wet process scrubber for FGD system. The full

condenser cooling water discharge runs to the FGD pump pit of the basin, from which a portion is

pumped up to the flue gas SO2 absorber vessel. The seawater is poured over a packed zone through

which the flue gas flows upward. The packing provides many surfaces for intimate contact between the

SO2 in the flue gas and the alkali in the seawater. The SO2 is absorbed into the water and reacts with the

alkali to form salts.

The flow excess seawater from the pump pit into the distribution chamber will be controlled by Stoplogs.

Another row of stoplogs controls flow from the distribution chamber into the bypass channel or the

aeration channel. The sulphur-laden water from the absorber is admitted to the aeration channel

through a distribution header. The salts formed are a mixture of sulphites (SO3) and sulphates (SO4). The

sulphites are not acceptable, as they are not stable.

To prevent pH imbalance and a chemical oxygen demand in the discharged water, air must be added to

convert the SO3 to SO4. A second distribution header is used to admit the pressured air for this purpose.



At the end of the basin, the water in the bypass channel and the water in the aeration channel mix and

then discharge to the plant’s discharge channel.

3.14.3 BAGHOUSE/ELECTROSTATIC PRECIPITATOR /SCRUBBER SYSTEM

3.14.3.1 FUNCTION

Coal contains significant quantities of non-combustible material. When burning coal this Non-

combustible material converts to ash. A portion of the ash forms large particles and falls to the bottom

of the furnace. This is known as bottom ash. The rest of the ash (typically 90% of the ash in a pulverized

coal boiler) forms fine, lighter particles that are carried out of the furnace by the flue gas. This is called

fly ash. A particulate control system will be fitted to remove nearly all the particulates form the flue gas.


The particulate collector is expected to operate at an emission rate of 50 mg/Nm3. The Conventional

means of collecting the particulate matter include electrostatic precipitation (ESP) or a fabric filter

baghouse. In this case, either is fully capable of meeting the operating point, as well as a guarantee lower

than that.


In ESP an enlarged box section of duct is used to slow the gas velocity down. In the box parallel to flow,

Metal plates are hanged such that the flow is channelled between them. Either solid ones or weighted

wires are hanged between them as electrodes. Transformer/rectifier (T/R) sets step up the power to

high voltage and convert the current to dc. The voltage is applied between the plates and the electrodes,

such that the electrodes charge the particles, then the particles are attracted to the oppositely-charged

plates. Automatic hammer assemblies, are used periodically to scrap the plates, which cause the ash to

fall into hoppers below the plates.

Figure 3.3 (a) — Proposed ESP System



Figure 3.4 — Conceptual view of ESP System

In baghouse Compartmentalized steel chamber are used with an inlet plenum that distributes ash-laden

flue gas to the compartments and an outlet plenum that collects the cleaned gas from the

compartments. The bags are hanged in each compartment by a tube sheet near the top. Typically, these

bags are 150 mm in diameter and 8 m long, though larger sizes have become commercial. The bag is

hung from the tube sheet after being stretched over a form-fitting wire basket that prevents the bag

from collapsing. Flue gas is admitted at the bottom of the compartment and departs above the tube

sheet, such that the ash is captured on the outside of the bags. When the bags have accumulated a

heavy cake of ash, a compressed air nozzle at the top of each bag gives a strong puff of compressed air,

which momentarily pulses the skin of the bag, releasing the ash cake to the hopper below.

Figure 3.5 —Reverse Jet Bag House

The precipitator should operate in a safe and efficient manner taking account of the complete boiler

operating regime, specified fuels and ambient conditions, to include boiler start-up, shut-down and

anticipated transient operation.

Scrubber systems could be used as air pollution control devices that can be used to remove

some particulates and/or gases from exhaust streams. It complies of a systems that injects a

dry reagent or slurry into a dirty exhaust stream to "wash out" acid gases. Scrubbers are one of the

primary devices that control gaseous emissions, especially acid gases. They can also be used for heat

recovery from hot gases by flue-gas condensation.



Wet Scrubbing: The exhaust gases of combustion may contain substances considered harmful to the

environment, and the scrubber may remove or neutralize those. A wet scrubber is used to clean air, fuel

gas or other gasses of various pollutants and dust particles. Wet scrubbing works via the contact of target

compounds or particulate matter with the scrubbing solution. Solutions may simply be water (for dust)

or solutions of reagents that specifically target certain compounds.

Dry Scrubbing: A dry or semi-dry scrubbing system, unlike the wet scrubber, does not saturate the flue

gas stream that is being treated with moisture. In some cases no moisture is added, while in others only

the amount of moisture that can be evaporated in the flue gas without condensing is added. Therefore,

dry scrubbers generally do not have a stack steam plume or wastewater handling/disposal

requirements. Dry scrubbing systems are used to remove acid gasses (SO2 and HCL) primarily from

combustion sources.

In case there is mercury pollution than wet scrubbers could be used as they are only effective for the

removal of soluble mercury species, such as oxidized mercury, Hg2+. Mercury vapour in its elemental

form, Hg0, is insoluble in the scrubber slurry and not removed. Therefore, additional process of

Hg0 conversion is required to complete mercury capture. Usually addition of the halogens to the flue gas

is used for this purpose.

3.14.3.4 THERMAL DISCHARGE

The thermal discharge is primarily the circulating water and other cooling waters. The impact of the

heated water which is 8.5°C to 9oC above the sea temperature was studied using CORMIX system. The

system has been accordingly designed to achieve NEQS limits of 3oC.

3.14.3.5 NOISE

The plant will be designed to control the noise generated to meet World Bank and Pakistan regulations

within the plant and at the fence line.

3.14.3.6 ASH

Some of the Ash may be stored on site or close by and rest shall be transported to the Lucky Cement

(Karachi Plant). The fly ash may be sold if a market exists. The storage areas will be designed to control

water run-off due to rain. This water will be collected and treated before discharge. Dust will be

controlled by mixing with water, spraying with water, and covering with dirt.

3.14.3.7 AIRBORNE DUST FORM ASH STORAGE YARD

A combination of water sprays, wind screens, and, if necessary, covers will be used to control the

potential dust from the coal piles. Water sprays will reduce the amount of dust pickup by the wind. The

wind screens will be fabric fences to reduce the wind that would dry the surface of the pile and pick up

the dust. In addition, if necessary, fabric covers can be placed over the idle portions of the coal piles to

prevent airborne dust.

3.14.3.8 WASTEWATER DISCHARGE

All water discharges will be collected and treated before discharge to meet NEQS.



3.15 HVAC

3.15.1 FUNCTION

The function of the HVAC systems is to provide safe and appropriate conditions in all rooms, enclosures,

and buildings that are part of the plant. This will include all enclosed spaces, heating (if any), cooling, and

ventilating, for personnel comfort and equipment protection. Functions will include the required

number of air changes, relative humidity control, temperature control, and pressurization.

Dust suppression and collection will be provided for the coal handling areas to protect against fires and

explosions due to dust or gas build-up.

Air conditioning is required for the switchgear and electrical equipment areas/ rooms even if not

required by the vendors and the American Society of Heating, Refrigerating & Air Conditioning Engineers

(ASHRAE) to ensure equipment reliability.

3.15.2 DESIGN BASIS

The systems will be designed to meet the intent and specific requirements of the ASHRAE handbooks

and standards. If Pakistan requirements are more stringent in any aspect, they must be followed. In

addition, the following specific considerations will apply.

3.15.3 AIR CONDITIONING

The main control room, offices, storage areas, and battery room will have a split packaged air

conditioning system(s) for the rooms requiring air conditioning. The system(s) will provide a constant-

volume air supply with a variable outside air supply capability of 10% to 100% (economizer) to achieve

energy conservation. The system will use outside air instead of refrigerant for cooling, when outdoor air

temperature and humidity conditions permits. Each unit will be provided with a compressor, evaporator

coil, detached air-cooled condenser, electric heating coil, and a pre-filter and final filter. The HVAC

system will continuously operate the year round. For the control room, two 100% capacity HVAC

systems will be provided: one operating and one as standby.

The HVAC split units for the air conditioning system will include a mixing section with fresh air, exhaust

air, and return air dampers, filter section (including pre-filter and final filter), electric pre-heating coil

section, cooling coil section, supply fan section, and return/exhaust fan section. The air conditioning

system final filter will meet the requirements of 80% atmospheric dust spot efficiency based on ASHRAE

Standard 52.1 or approved equivalent international standard.

Duct-mounted electric reheat coils will be provided for zone temperature control and high humidity

control.

Careful consideration will be taken for locating outdoor air intakes and air-cooled condensers away from

prevailing wind direction and from airborne sand, coal dust, and dust.

3.15.4 BATTERY ROOM

Ducted exhaust intake will be directed upward to remove hydrogen accumulated at ceiling and in beam

pockets. Discharge air will exceed the air supply by 15%. The supply air for the battery room will come

from an air conditioning system. The exhaust system in the battery room will be operated continuously



to maintain negative pressure and to avoid accumulation of hydrogen gas or leakage to neighbouring

rooms.

Exhaust air rate will meet the requirement of not less than ten volume air changes per hour. Room air

temperature will be kept below 30°C (85°F). Two 50% capacity in-line exhaust fans will be provided.

HVAC system design temperatures are summarized in the following table:

Table 3.5 – HVAC System Design Temperature

Room System Type Indoor Environmental Conditions

Control room, offices, I&C maintenance, administration building, and CEMS enclosure

HVAC 24° ± 1°C (75 ± 2°F), 50% RH in summer 22° ± 1°C (72 ± 2°F), 50% RH in winter

Battery room HVAC 30° ± 2.8°C (85 ± 5°F)

Electrical switchgear and switchyard control house

HVAC 30°C (85°F)

The indoor environmental conditions will be met based upon the internal heat gain in the room and

outdoor ambient design conditions.

Table 3.6 – Equipment Allocated for Each Service

Service Equipment Description

Control room/battery room HVAC split packaged unit (2 x 100%)

Switchgear HVAC split packaged unit

Administration building HVAC split packaged unit

All offices, I&C maintenance room - shop/ and CEMS enclosure, coal handling control room

HVAC split packaged unit

Warehouse/mechanical maintenance area Wall/roof exhaust, louvers, dampers

Water treating building, hypochlorite building, tractor garage

Exhaust power roof ventilators and wall louvers

Coal crusher house , transfer towers, tripper room Ventilation and dust collectors as needed

Fire pump enclosure Supply fans, dampers, louvers

Guard house HVAC, self-contained package, through-wall

Turbine building Supply fans, dampers, louvers

To ensure reasonable noise levels, duct work for all HVAC systems will be designed per ASHRAE

guidelines, for a maximum air velocity of 10 m/s (2,000 fpm).

3.16 COAL DUST COLLECTORS

Pulse-jet bag-type dust collector systems will be used for coal dust collection. The discharge of the

collectors will be to pin mixers that will mix the dust with water and return the moist dust to the

conveyor or silo. Dust collectors will be required for the coal silo tripper, each coal silo, coal transfer

house, and the crusher house.

The dust collectors will have the following characteristics:

Top-bag removal from a clean air plenum

Be designed for continuous operation at the pulse jet pressure provided

Bag cleaning will use low pressure high volume reverse airflow



An air-to-cloth ratio of 5 to1

A minimum efficiency of 99.99%

A maximum pressure differential of 15 cm (6 inches) after the initial bag dust loading

Maximum allowable collector discharge loading of 0.0114 g/m3 (0.005 grains per dry standard cubic

foot [dscf])

Material handling of the air locks will not be less than 1.5 times the continuous mass flow rate

The station system will provide the compressed air required for the dust collectors..

Ductwork will be designed for not less than 10 gauge galvanized steel per the Sheet Metal and Air

Conditioning Contractors National Association (SMACNA) round industrial duct manual. Return dust

ducts will be a minimum of 10 gauge stainless steel. Dust collection ducts will be designed for a velocity

range of 23 to 25 m/s (4,500-5,000 fpm).

Explosion venting assemblies will be provided on each collector module to meet NFPA requirements 68.

If a gas explosion were to occur, the maximum pressure to be reached during the venting would be no

greater than two-thirds the pressure that would cause to weakest part of the dust collector to break or

yield.

The dust processor (pin mixer) will include a main shaft direct drive, variable speed dust feeder 4.8 mm

(3/16 inch) thick 304 SS dust discharge hopper. Each dust processor will be capable of producing free

flowing dust using a minimum of water (less than 25% total moisture) so that when a fresh sample is

dropped from 1.8 m (6 feet) onto a hard surface, it will not dust.

Fans will be centrifugal, direct drive or V-belt drive with bearings designed for 100,000 hours of

operation.

3.17 DRY PIPE DELUGE TYPE SPRINKLER SYSTEM

The contractor will design and furnish an independently operable dry pipe deluge-type sprinkler water

fire protection system, complete with temperature detection switches; deluge valves with solenoid

actuators; tripped pressure, tamper, and limit switches; strainer; spray nozzles for each collector; and all

piping to a common header external to each collector.

The fire protection system design will include sizing piping and locating spray nozzles. All piping will be

self-draining using drips, orifices, or other devices allowed per NFPA codes.

To provide complete coverage of collector internals in case of fire the number, sizing, and spacing of

nozzles will be sufficient. Nozzle orifice size will be not less than 9.5 mm (3/8-inch) diameter.

Each nozzle will be located internally in the dirty air side or clean air side and factory installed.

Additional nozzles will be located in the hoppers and in the duct inlet and outlet connections of the

collector.

One deluge valve will be furnished for each dust collector complete with all trim piping, manual outside

screw and yoke (OS&Y) gate valve, tamper switch, strainer, solenoids, and all other appurtenances.



Temperature switches (heat detectors) will be provided and located within the collectors to provide

complete detection. As a minimum, the clean air plenums, dirty air plenum, hopper, and air inlets and

outlets will have detectors.

Temperatures switches (heat detectors) will be designed with rate compensation for dust collectors and

have a fixed set point of 88°C (190°F).

3.18 DUST SUPPRESSION

To control the escape of dust, dust suppression systems will spray water and wetting agents, if required,

to each of the coal transfer points.


The systems will operate with no operator interface during normal operation. The air conditioning

systems will be independent of all other mechanical systems. They will be air cooled and not require the

closed cooling water or other systems to function.

Whenever coal handling systems are in operation dust collectors will operate to control the dust

generated. Dust that is collected will be conditioned with water or other products to avoid re-

entrainment.

3.18.2 WET CENTRIFUGAL DUST COLLECTOR

Sometimes spraying coal with a binding solution to reduce coal dust while handling it isn’t enough

because dust particles as low as 1 – 10 microns still exists Therefore suitable innovative and efficient

technique of dust suppression should be used. Since moisture addition is futile exercise, therefore wet

dust collector which can reduce dust concentration as low as 1% in the concerned area. Dust collector

is very elegant device which discharges dust in concentrated form reducing water consumption. Even

for suppressing 1mm thick dust layer, we require large amount of water, but dust collector with

minimum use of water, suppresses large amount of dust. The use of “Wet Centrifugal Dust Collector”

could be used to further minimize the coal dust. Centrifugal collectors use cyclonic action to separate

dust particles from the gas stream. In a typical cyclone, the dust gas stream enters at an angle and is

spun rapidly. The centrifugal force created by the circular flow throws the dust particles toward the wall

of the cyclone. After striking the wall, these particles fall into a hopper located underneath.

Figure 3.6 — Wet Centrifugal Dust Collector



3.19 COMPRESSED AIR

3.19.1 FUNCTION

The Station will be provided with a compressed air system for a continuous supply of 8bar air. The air is

used for maintenance to operate air tools, for air movers, and for cleaning. A second piping system

provides the instrument air to all instruments, including air-operated valves.

3.19.2 DESIGN BASIS

The compressed air system will be designed to provide a continuous supply of air to all air users at the

site. The same compressors supply the service air and the instrument air.

There will be three motor-driven 100% capacity, oil-free compressors installed. These compressors will

be packaged units with all controls, coolers, and sound reduction enclosures.

The compressors will discharge to a common header that connects to an air receiver. Air dryers will be

provided for instrument air.

The piping for the service air system will be carbon steel. The piping for the instrument air system will be

stainless steel or copper. Service air will be piped to all areas of the power block area where maintenance

work with air tools is anticipated. A loop will be provided around the turbine and boiler areas with

isolation valves to allow maintenance on sections of the system without removing the entire system

from operation. Valved hose connections will be provided at each location. These locations will include

the grade, mezzanine, and operating floors of the turbine room, all levels of the boiler room, and all

shops and coal handling buildings.

The instrument air system will have a similar design for all areas where air-operated valves or

instruments are anticipated.


During normal operation, two compressors will operate. The operating compressors will maintain the

operating pressure pre-set for receivers. If the pressure drops below that level, the other compressor

will automatically start.

The air dryers will automatically switch desiccant towers as needed to maintain the required dew point.

The inactive tower will be purged with a portion of the dry air to return the desiccant to its original

effectiveness.

3.20 FIRE PROTECTION

3.20.1 FUNCTION

The fire protection system will detect and suppress fires, minimize hazards to station personnel, and

reduce property loss due to fires.

3.20.2 DESIGN BASIS

The fire protection system will include clean agent extinguishing, sprinkler systems, stand pipes and hose

stations, water supply systems and hand-held extinguishers.



A ring header will be included in the system to supply water to fire hydrants spaced throughout the

Project. Lines from this ring header will also supply water to sprinkler systems for some equipment and

areas. This will include the power block area and major buildings. Two stand pipes will be provided on

opposite sides of the boiler with hose stations at all major gallery levels. The design will be to Pakistan

standards and to National Fire Protection Association (NFPA) or equivalent international standards.

The maximum spacing between fire hydrants will be 75 meters .The underground header will be

constructed of cement-lined ductile iron or high-density polyethylene (HDPE) pipe.

A raw water storage tank will be used to supply the water. The water tank will be sized for the

appropriate standards but no less than 1,100 m3 (300,000 gallons) available for fire protection.

A fire pump house which will include the emergency diesel fire pump, the motor driven fire pump, and

a pressure maintenance jockey pump will be included in the system. The emergency fire pump has a

separate fuel oil tank sized for a minimum of 8 hours operation at full load.

In addition, a diesel fire pump will be installed in the pump house taking suction from the seawater in

the pump house. This an emergency source of water to be used only when all other options have been

exhausted or failed. Provisions will be included to allow regular flow tests of this pump without allowing

seawater to enter the piping systems

Any detection of a fire, or actuation of a fire suppression system, will be alarmed in the main control

room and the administration building.

An open shed shelter (with roof but no walls) will be provided next to the fire pump house for the fire

truck. The major areas to be protected are listed in the following table.

Table 3.7 – Major Fire Protection Areas

Area Detection or Actuation

Type Suppression Type Notes

Turbine Room None Hose stations at grade,

mezzanine, and main floor Smoke vents in

roof

Boiler Room Hose stations each side all

major floors

Coal Transfer towers, Crusher House, and Tripper Area above

Silos Spot type smoke

Dry-pipe sprinkler fusible heads

Not to include electrical rooms

Conveyors Linear heat detection Automatic deluge

Coal Pulverizers (mills) Pulverizer outlet

temperature Internal deluge spray with quarter turn valve outside

Administration Building, Locker Rooms, Toilet Areas, Telephone

and Communications

Spot type smoke detectors

Automatic wet pipe sprinkler system, Hand

hoses

Water Treatment Building Spot type detectors Automatic wet pipe

sprinkler system, Hand hoses portable extinguishers

Maintenance Shops, Warehouse Manual pull stations at

each exit door

Hand hoses, automatic wet pipe sprinkler system,

portable handheld

Fuel Oil Storage Tanks, 2,000 m3 None Foam injection plus foam

cannons



Table 3.7 – Major Fire Protection Areas

Area Detection or Actuation

Type Suppression Type Notes

Fuel Oil Truck Unloading Area None Foam Cannons

Steam Turbine and Generator Bearings

Spot type smoke detectors

Automatic pre-action sprinkler system, double

interlock

Turbine Oil Tanks, Piping, Conditioner Skid,

Hydrogen Seal Oil, EHC System

Linear Deluge sprinklers

Turbine Electrical Enclosures Spot type smoke

detectors None

Battery Room Smoke detectors at the

ceiling Pre-action sprinkler system

– Electric release

Control Room Smoke detectors at the

ceiling level and beneath all raised floors

Double interlock pre-action wet pipe sprinkler system

Dry chemical system if

kitchen area

Electrical Equipment Room, Electronics Room, Cable Spreading

Room Spot smoke detectors

Pre-action sprinkler system – electric release

Main Power Transformers, Auxiliary or Reserve Transformers

Linear Automatic deluge, dry pipe

Gas Insulated Substation Beam smoke detection Portable Extinguishers

Black Start Combustion Turbine Vendor Standard CO2 provided by vendor

Intake Pump house None Hydrants, portable

3.20.3 FIRE PROTECTION MASTER PLAN

The EPC contractor will be responsible for preparing a Fire Protection Master Plan. This will consist of

the following documents:

Building and Fire Codes and Life Safety Compliance Review Report

Fire Risk Evaluation Report

Hazardous Area Classification Evaluation

All three documents are to be submitted to the local statutory authorities and the purchaser for review,

comment, and approval. They are discussed individually below.

3.20.4 BUILDING AND FIRE CODES & LIFE SAFETY COMPLIANCE REVIEW

The report will identify and address, at a minimum, the following items for each building, pre-engineered

and/or pre-fabricated building, equipment enclosure and / or structure, and outdoor process,

equipment, and storage areas:

Applicable building and fire codes, standards, recommendations, and amendments

Building classification, occupancy and permitted construction types

Building height and area limitations



Fire resistance requirements for floors, exterior and interior walls and structural supports

Egress and exiting requirements

Detailed exit analysis and calculations, includes preparation of exit analysis drawings documenting

occupant loads, required exit widths, occupant load distribution, and travel distances.

Combustible and flammable gases and liquids process equipment and storage fire protection,

quantity limitations, and storage requirements

Accessibility requirements

Fire department access and firefighting facilities

Occupancy and area separation requirements

Fire alarm and detection systems

Sprinkler/standpipe and fire hose station requirements (including duration, flows, pressures, and

densities)

Fire protection water supply requirements

Emergency power and lighting requirements

Smoke control and ventilation requirements

Elevator requirements

The Building and Fire Codes and Life Safety Compliance Review is to be performed by a firm experienced

in the preparation of fire protection master plans, building code reviews and reports, and exit/egress

analysis calculations and diagrams and be qualified in Pakistan.

3.20.5 FIRE RISK EVALUATION

An NFPA 850 fire risk evaluation is to be initiated as early in the design process as practical to ensure that

the fire prevention and fire protection recommendations as described in this document have been

evaluated in view of the plant-specific considerations regarding design, layout, and anticipated

operating requirements.

The evaluation should result in a list of recommended fire prevention features to be provided based on

acceptable means for separation or control of common and special hazards, the control or elimination

of ignition sources, and the suppression of fires. The fire risk evaluation should be approved by the

owner before final drawings and installation.

3.20.6 HAZARDOUS AREA CLASSIFICATION EVALUATION

The basis for classification evaluation will be NFPA 70, the National Electrical Code (NEC), NFPA 497,

American Petroleum Institute (API) 500, vendor information and other standards, as applicable.


The jockey pump will normally be operating to keep all parts of the fire protection piping systems full of

water and pressurized. If the pressure drops for any reason, the main motor-driven pump is started



automatically. If the pressure is not restored within a predetermined time, the diesel-driven pump is

started automatically and will remain operating until manually stopped.

If the diesel fire pump does not start and pressurize the system within a predetermined time, alarms will

be given. Operators will then start the back-up seawater diesel fire pump and open the isolation valves.

3.21 FUEL OIL STORAGE AND TRANSFER

3.21.1 FUNCTION

The fuel oil storage and transfer system will store the fuel oil and transfer that oil to the main boiler for

ignition and warm-up of the main boiler and the auxiliary boiler and to power the black-start generator.

The system will include truck unloading facilities. Provisions will be made to supply fuel oil to tractors,

trucks, and other equipment. The storage capacity is adequate to have several start attempts or operate

a single boiler at 20% load for 2.5 days.

3.21.2 DESIGN BASIS

Two identical 2,000-m3 welded-steel vertical tanks to store the oil will include the system. The oil is

commonly known as #2 diesel or high-speed diesel. It does not require heating. The tanks will be inside

a berm designed to contain any oil leaks, including complete failure of the tanks. Provisions will be

included to remove the rain water that accumulates inside the berm and to provide treatment before

discharge.

Floating suction will be provided in each tank. The suction will be designed for the oil specifications for

the Project. The float will be designed such that the suction is submerged between 50 and 300 mm

below the oil surface during all modes of operation. Suction will be capable of drawing down to 450 mm

from the tank bottom. A low-level stop will be provided to prevent drawdown below 450 mm.

All tanks pumps and piping will be designed to API 650 standards or international equivalents and to

Pakistan standards. The tanks will be double bottom.

Truck delivery of this oil is expected. A truck unloading station will be included to unload two trucks

simultaneously, contain any spills, and measure the quantity of oil from the trucks. Two centrifugal

pumps will transfer the fuel to the tanks. The pumps will be designed for at least 100 m3 /h (500 gallons

per minute [gpm]).

Pumps will be provided to supply the oil to the burner levels of the boiler, at which point the system will

be the responsibility of the boiler supplier.

A day tank will be provided for the black-start generator, which will be designed for 24 hours operation

at full load and include all the requirements and recommendations of the supplier, including floating

suction, location of fill and suction connections, filters, recirculation, sample connections, and drains.

Three 100% capacity transfer pumps will pump the oil from the storage tanks to the boiler. Each pump

will be designed to provide the maximum fuel required for the igniters and warm-up burners of a single

boiler and the auxiliary boiler.




The tanks will normally be kept full to provide the capacity required to attempt multiple start-ups of the

boiler if there is a forced outage and/or a requirement for a black start. As oil is used for start-up, it will

be replaced within a few days to ensure that an adequate supply is available.

Drains will be checked periodically for signs of water and other contaminants. Appropriate filtering

draining and additives will be used as required to maintain the quality of the oil.

As trucks are unloaded, any oil spilled will be contained and recovered or disposed of in accordance with

the environment regulations.

3.22 COAL UNLOADING AND HANDLING SYSTEM

3.22.1 FUNCTION

The coal handling system will receive coal from the Pakistan International Bulk Terminal (PIBT); from

there the coal will be transported to the coal storage facility (coal yard) via trucks, reclaim coal from

storage, and transport it to storage silos in the power block.

Figure 3.7 —General Coal Storage View

3.22.2 DESIGN BASIS

A common coal handling system will be provided to fuel the units. The coal handling system will be

designed based on the following parameters:

Table 3.8 – Coal Handling System Design Parameters

Parameter Value

Capability of handling different types of coals Four different coals

Coal blending capability By reclaimer

Size of active storage pile for each coal 200,000 tonnes (minimum)

Size of total active storage pile 60 days coal consumption

Size of total inactive coal storage pile 30 days coal consumption



3.22.3 DESCRIPTION

The coal handling system will receive coal from trucks to the coal storage yard, reclaim coal from storage,

and transport it to the silos in the power block.

The coal silos have storage of 24 hours at 100% boiler burn rate. The coal handling system will be

designed to transfer coal from storage to the coal silos at a rate of 540 tonnes per hour to accommodate

filling the silos in one 8 hour shift.

The conveyors will be covered and the transfer points equipped with dust suppression system. The

conveyer belts will use flame retardant material.

A coal measurement system will be included to measure quantity of coal just prior to going into the

boiler. The measurement system will be connected to the DCS system. Two weighbridges will be

included at the plant entrance.

Wind fences will be provided around the coal yard. The coal piles will be equipped with a water spray

dust suppression system. Dust suppression systems will also be provided for conveyor transfer points,

Dust collection systems will be provided for the crusher house (pulse jet collector), and coal silo

ventilation and the tripper conveyor room at the power plant. Additional dust collection system apart

from this can also be installed if felt necessary.

Figure 3.8 – Coal Pile Wind Break




The coal handling control room located within the coal handling building adjacent to the crusher house

will be controlling the complete coal handling system. A programmable logic controller (PLC) system will

be used for the overall control. To allow remote operation of the coal handling system the control boards

will include the controls, graphic display and communication sections. The coal handling building will

also house the necessary electrical equipment to distribute power to the coal handling equipment.

3.23 ASH HANDLING AND DISPOSAL

3.23.1 FUNCTION

The fly ash collection and disposal system will transfer particulate collected from the boiler flue gas to a

fly storage silo for unloading into trucks for disposal (transported to lucky cement Karachi). Fly ash


will also be collected throughout the flue gas system by means of ash hoppers at other locations such as

the air heaters.

The bottom ash handling system will collect, store, and transport bottom ash from the boiler furnace,

economizer hoppers and mill reject hoppers. The system will include a submerged scraper conveyor

(SSC) for collecting, cooling and transporting the bottom ash, a flight conveyor system to convey

economizer ash to the SSC, and a sluice system to convey mill rejects to the SSC. The bottom ash, mill

rejects and economizer ash will be transported to a concrete bunker for removal by trucks.

3.23.2 DESIGN BASIS

3.23.2.1 FLY ASH HANDLING SYSTEM

All fly ash collected in the air heater hoppers, baghouse hoppers and in other hoppers as applicable, will

be pneumatically conveyed to fly ash storage silo.

The fly ash handling system will be sized for 100% maximum continuous rating (MCR) operation. The

design pneumatic transport system conveying rate will be 2.25 times the design makeup rate to allow

for catch up conditions.

The fly ash storage silos will have a nominal storage capacity of 3 days (72 hours).

3.23.2.2 BOTTOM ASH HANDLING SYSTEM

The project will have a dedicated a bottom ash handling system. The bottom ash handling system will

be sized for 100% MCR operation. The design conveying rate will be 2 times the design production rate

to allow for catch up conditions. The bottom ash storage bunker will have a nominal storage capacity

for 3 days (72 hours).

3.23.2.3 MILL REJECTS HANDLING SYSTEM

The mill rejects from each pulverizer will be collected in a separate hopper and will be conveyed by water

jet pump to the boiler bottom ash SSC.

The mill rejects hoppers will be sluiced automatically once per shift, and the time required to sluice each

hopper will not exceed 5 minutes.



3.23.2.4 ECONOMIZER ASH HANDLING SYSTEM

The economizer ash will be collected and transferred to the SSC with a dry flight conveyor (DFC) system.

The design conveying rate will be 2 times the design production rate to allow for catch up condition

3.23.3 DESCRIPTION

3.23.3.1 FLY ASH HANDLING SYSTEM

The fly ash collection and disposal system will be designed to remove fly ash from the flue gas and hold

it in storage silos for unloading into trucks to transport to Lucky Cement Site. A baghouse or electrostatic

precipitator will be used to remove the Fly Ash entrained in the flue gas . Fly ash will also be collected

from other various locations throughout the flue gas system by means of ash hoppers located beneath

the collection locations where the flue gas becomes stagnant. A pneumatic conveyance to transport the

ash to a storage silo will be used in fly ash handling system. The economizer ash will be collected and

discharged into the water filled bottom ash collection trough by drag chain conveyors.

The fly ash settles out of the flue gas duct into various hoppers, where it accumulates into the collection

hoppers. The fly ash accumulates in a collection hopper until the hopper’s discharge valve opens to allow

the ash to flow through a pneumatic pipeline to the storage silo. Each of the hopper valves is cycled open

and closed, allowing fly ash to empty from the individual hoppers and into the conveyance pipe to be

transported to the fly ash silo. A bin vent filter located on top of the silo will filter and discharge the

transport air to the atmosphere.

Fly ash from the baghouse/electrostatic precipitator will be collected in storage silos and will be

transported by truck to the Lucky Cement Karachi plant. Each silo will be equipped with two 100%

capacity fluidizing blowers and two 100% capacity fly ash conditioners to support unloading for truck

transport. The fly ash from each silo will be conditioned using water spray as required to minimize

dusting during truck loading. Each silo will also include a loading spout to load dry fly ash into trucks.

3.23.3.2 BOTTOM ASH AND PYRITE HANDLING

Relatively heavy solid wastes resulting from the combustion of coal in the boiler will be collect, store,

and transport by the bottom ash handling system. This bottom ash includes furnace ash from the boiler,

pyrites from the mills, and economizer ash. Furnace ash from the boiler collects in the water filled trough

below the boiler. Mill rejects from the pulverizer reject hoppers will be conveyed by hydro-ejectors to

the trough.

Economizer ash will be transported by dry flight conveyor to the trough. As ash enters the submerged

conveyor trough, it is quenched and collected against the faces of the drag chain conveyor flight bars.

Movement of the flight bars pushes the accumulated ash toward the inclined dewatering ramp. As the

flight bars travel up the incline, ash is compacted ahead of them. This compaction, together with the

natural drainage of entrained water, effectively dewaters the ash. Water flows down the dewatering

ramp along the outer edges, back into the trough. At the dewatering ramp discharge, the ash falls into

a hopper and is conveyed to an onsite bottom ash storage bunker. From the bunker, the bottom ash

will be loaded into trucks and transported to Lucky Cement Karachi Plant.

The water temperature in the SSC trough will be cooled by using a recirculation system. Water will

overflow from the SSC trough into a settling tank, and will then be pumped by one of two 100% capacity



recirculation pumps through one of two 100% capacity heat exchangers and back to the SSC trough.

Sediment collected at the base of each of the tanks will be removed by one of two 100% capacity slurry

pumps and discharged periodically back to the dewatering section of the SSC.

A service water make-up connection to the SSC will replenish water lost by evaporation and system

losses. Water taken from the same service water source will provide the seal water requirements for

pumps, seals, and system make-up. System design will maximize the use of the wastewater recycle pond

as a source of makeup to the SCC in order to reduce fresh water consumption.


The ash handling system will be controlled in sequence during normal operation. Control of the ash

handling system will be accomplished via the plant DCS. All system control, status indications and alarms

will be available in the main control room.

The ash handling control system will be divided into following parts by function.

SSC system control

Mill rejects removal system control

Economizer flight system control

Water systems control

3.24 ELECTRICAL

3.24.1 FUNCTION

The main generation system will generate power from the turbine generator and transmit the power

through an isolated phase bus and a generator transformer to the switchyard. It will also serve to step

down voltage through two unit-connected transformers used for supplying power to the upper

medium-voltage auxiliary system for the normal operation of the generating unit.

3.24.2 DESIGN BASES

The system will be designed to generate and transmit electrical power to the 100% capability of the

steam turbine. The generator will meet the reactive power requirements of the system from its rated

leading to lagging power factor under all turbine load conditions.

The generator transformer will be rated to transmit the maximum generator output capability, less

transformer losses, to the switchyard. This will permit either unit to deliver maximum generation to the

grid while using the backup source for the auxiliary power when the unit transformers are out of service

or otherwise disconnected. The basic impulse insulation (BIL) level will be coordinated with suitable

lightning and/or switching surge protection.

The unit transformers will be rated to supply all unit auxiliary loads to permit the maximum output

capability of the unit. Impedance will be determined by the optimum auxiliary system voltage

regulation, limitations of the switchgear short-circuit duty and the ability to start the largest motor

connected to the system with the other loads operating.

A static-type exciter will provide excitation and voltage regulation to permit continuous, full-power

operation of the main generating unit and enhance stability under normal or transient conditions.



The excitation system will have the ability to control the field changes of the generator so that transient

changes in regulated voltage are effectively suppressed and so that sustained oscillation in regulated

voltage is not produced by the excitation system during steady-state load conditions or following a

change to a new steady load condition.

The isolated phase bus will be rated to transmit the maximum output of the generator to the main

power transformer. A generator circuit breaker will be located in the isolated phase bus to allow the unit

auxiliary transformers to be able to be energized while the generator is off line. The isolated phase bus

and generator circuit breaker will be self-cooled.

The generator will have an epoxy encapsulated dry-type or oil-type neutral grounding transformer with

a secondary resistor to provide a high-impedance connection to ground in order to limit the magnitude

of ground fault current. To keep transient over-voltages low during breaker restrikes or arcing ground

faults, the secondary resistor will be selected such that its kilowatt loss during a line-to-ground fault is at

least equal to the charging kVA value.

An automatic synchronizing system will be provided for synchronizing the unit to the system.

Synchronizing will be done across the generator circuit breaker located in the isolated phase bus circuit.

The switchyard will be configured in a breaker-and-a-half arrangement with two overhead transmission

lines entering it from the generator transformers of each unit and two transmission lines exiting the yard

to evacuate the power into the 500-kV grid. The yard will be configured as a breaker-and-a-half design.

3.24.3 SYSTEM CONFIGURATION

The generator will be directly coupled to the steam turbine. The generator’s neutral will be connected

to the neutral grounding transformer by an extension of the isolated phase bus duct. Generator line

terminals will be connected to the generator circuit breaker through the isolated phase bus duct, which

will contain the necessary surge arrester, capacitors, instrument and relaying voltage and current

transformers to complete the required equipment for the generator to main and auxiliary transformers

circuit. A disconnect and grounding switch will be provided for backup isolation of the generator from

the transformers during maintenance outages.

The generator transformer will be a three-phase, oil-filled two-winding unit located outdoors in the

transformer bay. The low-voltage winding will be delta connected and the high-voltage winding will be

solidly grounded wye connected. The generator transformer, which will be equipped with an on-line tap

changer, will have a tie line connection to the switchyard by overhead transmission line.

The unit transformers will be three-phase, oil-filled, two-winding transformers located outdoors in the

transformer bay adjacent to the generator transformer. Their high-voltage windings will be delta

connected and their low-voltage windings will be wye connected, grounded through a grounding

transformer/resistor combination to limit ground faults. Cables or non-segregated bus duct will connect

the transformer low voltage terminals to the 11-kV switchgear.


Start-up of the unit will be done by synchronizing the generator across the generator circuit breaker. The

unit’s auxiliaries will have been energized by back-feeding the generator transformer from the

switchyard. The transformer’s load tap changer will be used to bring the system voltage up or down to



the necessary level required by the auxiliary transformers. The medium-voltage switchgear buses will

have backup power provided to them by a connection to the other unit’s similar switchgear bus.

Relays that detect electrical equipment faults will simultaneously trip and lock out the turbine,

generator, excitation, or affected equipment depending on the fault location and type. Electrical faults

on the main power train or generator, transformer, or bus circuit will trip off the entire unit. Faults in

other areas will trip only the affected equipment. When a major fault occurs that trips the unit, a fast

transfer of the auxiliary buses to the other unit will occur so that the auxiliaries necessary for shutdown

will remain available.

Certain devices that detect increasing temperature or vibration will either alarm or cause a trip,

depending on the magnitude. Protective functions for the main generation system will be consistent

with the manufacturers and industry standards.

Generator protection will include but not be limited to the following:

Overcurrent protection

Differential protection

Volts per hertz protection

Negative phase sequence protection

Loss of field protection

Under frequency protection

Under frequency protection

Reverse power (anti-motoring) protection

Ground fault protection

Out of step protection

Generator field ground protection

Over speed protection

High-vibration protection

Low lube oil pressure protection

Transformer protection will include but not be limited to the following:

Differential protection

Neutral ground fault protection

Phase overcurrent protection

Sudden fault pressure protection (Bucholtz relay)

Low oil level protection (alarm only)

Loss of cooling oil/air protection (alarm only)

High oil temperature (alarm only)



High winding temperature (alarm only)

During operation, meters will monitor current, voltage, vars, watts, varhours and watthours.

3.25 STATION TRANSFORMER SYSTEM

3.25.1 FUNCTION

When offline, the station auxiliary transformer system will receive power from the switchyard, back-fed

through the generator transformer that will step it down to unit auxiliary transformers, which will then

power the medium-voltage auxiliary switchgear. When the generator is synchronized to the grid

through the generator transformer, the unit auxiliary transformers will be supplied directly from the

generator. Backup power to the auxiliary buses is from the unit auxiliary transformers of the other unit.

3.25.2 DESIGN BASIS

Two unit auxiliary transformers will be supplied to service each unit. The auxiliary power consumed by

the plant is expected to be 8% to 9% with the unit under full output. Total backup power will be provided

from the other unit for each transformer.


Each unit auxiliary transformer will be rated at 27/36 oil natural / air natural (onan), oil natural / air forced

(onaf). The delta-connected high-voltage side will be at generator voltage and the wye-connected low

voltage side will be at 11 kV. The transformer’s positive sequence impedance will be 8%, and it will

connect to two 11-kV buses through a 2,000-ampere circuit breaker. Each transformer will have an off-

load tap changer with tap settings at -5%, -21/2%. 0%, +21/2%, and +5%. The connection between the

transformers and switchgear will be by non-segregated bus or cable bus.


The transformers will provide start-up and normal auxiliary power to their respective switchgear buses.

They will also provide backup power to the similar switchgear buses of the other unit. Each transformer

will supply half the auxiliary load of the unit with a reserve margin of approximately 20% with the unit

providing maximum output. Loss of a switchgear bus will automatically transfer that bus to the opposite

unit supervised by a sync check relay that will block transfer on a phase angle difference of 20 degrees.

Unnecessary loads will be shed simultaneously with the bus trip.

Protective functions for the unit auxiliary transformers will include but not be limited to the following:

Transformer differential protection

Transformer neutral ground fault protection

Phase overcurrent protection

Transformer sudden fault pressure protection (Bucholtz relay)

Transformer low oil level (alarm only)

Transformer loss of cooling oil/air (alarm only)

Transformer high oil temperature (alarm only)

Transformer high voltage winding temperature (alarm only)



3.26 11-KV UPPER MEDIUM VOLTAGE SYSTEM

3.26.1 FUNCTION

The 11-kV upper medium voltage system is utilized to power the larger plant motors (with kilowatt

ratings greater than 1,000) and to serve as the supply for the 3.3-kV lower medium voltage system and

400-volt low voltage system. Power is supplied to the 11-kV system from the unit auxiliary transformers.

3.26.2 DESIGN BASIS

The 11-kV upper medium voltage system will be designed to distribute power of sufficient quantity and

quality to facilitate safe and reliable unit operation.

To this end, the design will consider factors such as allowable variations of voltages supplied to

equipment, short-circuit levels and corresponding withstand capability of switchgear and cables, and

minimization of the effects of failure of one unit’s 11-kV systems on the operation of the other unit.

Proper selection of transformer rating, impedance, and tap changing capability will ensure voltage

variations and fault levels are maintained within the allowable for the equipment. Variations in the fault

contribution and regulation of the upstream supplies will also be evaluated.


The source of power for the 11-kV system will be from the unit transformer.


In the event of a unit trip or loss of the unit transformer, a fast transfer to the station transformer will be

initiated. The transfer will utilize a contact of the incoming feeder breaker from the unit transformer to

initiate the closing of the station transformer supply breaker. The transfer will be supervised by a

synchrocheck relay and will also be inhibited for a bus fault on the 11-kV system or lack of voltage on the

backup supply bus. Additional protective relaying will be provided to promote safe and reliable system

operation. This relaying will include the following:

Phase overcurrent protection on incoming feeder

Ground overcurrent protection on incoming feeder breakers

Neutral time over current on transformer neutral

Instantaneous ground fault on motor and transformer supply breakers

Bus and transformer differential protection

3.27 3.3-KV LOWER MEDIUM VOLTAGE SYSTEM

3.27.1 FUNCTION

The 3.3kV lower medium voltage system is used to supply plant motors in the range of 250 to 1,000 kW.

3.27.2 DESIGN BASIS

The 3.3-kV system will be designed to provide sufficient power to satisfactorily operate the connected

loads of each unit, as well as those auxiliaries shared between units.



Limits on fault levels and equipment voltage capabilities will be used in the design to ensure proper

selection of transformer, switchgear, and cable parameters.

The 11-3.3 kV transformers will be either dry type or non-PCB oil filled. Each 11-3.3 kV supply

transformer will be sized to supply the anticipated loads for normal unit operation assuming a failure of

the opposite transformer and interconnection of the two buses vie the tie breaker.

The loading of the 3.3-kV buses associated with each unit will be reviewed so as to balance the running

loads as best as possible.


The 3.3-kV system consists of four separate switchgear buses. Each bus services the loads that are

associated with one another and receives its power from a dedicated 11-3.3 kV transformer fed from

the respective unit’s 11-kV bus. Loads supplied off the 3.3-kV system are generally under 1,000 kW but

larger than 250 kW.


Under normal conditions, each 3.3-kV bus is configured in a simple radial configuration fed from its

upstream supply transformer. Upon loss of supply to one of the 3.3-kV buses, the incoming supply

breaker can be opened and the tie breaker manually closed to reenergize the bus. The feeds to motors

on the bus will be controlled by medium-voltage starters, each of which can be isolated by a fused

disconnect switch.

Protective relaying for the 11-3.3 kV transformers will consist of the following:

Neutral time overcurrent on the secondary protection

Differential protection covering the transformer and supply breaker to the 3.3-kV bus

Fault pressure (if the transformer is oil filled)

High oil temperature (alarm only if the transformer is oil filled)

High winding temperature

Motor feeder starters will utilize the following:

Instantaneous ground fault relays

Instantaneous/time phase over current protection

3.28 400-VOLT LOW-VOLTAGE AUXILIARY SYSTEM

3.28.1 FUNCTION

The 400-volt low-voltage system will serve as the supply to electrical motors and other loads rated 400

volts and below. The power source will be the higher medium voltage system by means of 11-0.4 kV

step down transformers.

3.28.2 DESIGN BASIS

11-0.4 kV supply transformers will feed either one dedicated 400-volt power center or a double-ended

400-volt power center that will also be supplied by a second transformer. The 400-volt power centers



or motor control centers will be either radial connected to the supply source or of a split bus

arrangement with a normally open tie breaker interconnecting the two bus sections.

When the split bus arrangement is used, a normally open tie breaker interconnecting the two bus

sections will be included. Each bus section will be fed from a separate transformer, and the tie breaker

will be interlocked to allow it to be closed only when one of the primary source feeders is open. The

operation of the transfer from one transformer to the other and operation of the tie breaker is to be

done manually.

The assignment of loads to each section of bus will be done in a manner that balances them as closely

as possible.


The supply transformers will be either dry-type for indoor service or non-PCB oil-type for outdoor

service.

The high voltage will be delta connected while the low-voltage winding will be wye-configured, solidly

connected to ground. The primary of the transformers will have full capacity no-load taps to allow

voltage variation to be selected between +5% to -5%.

Circuit breakers for the load centers will be either electrically or manually operated depending on the

control function required.

Motor starters will, in general, consist of contactors with thermal overloads in each phase. Contactor

control power will be 220 volts AC supplied from the power center power source.

Non-motor feeder breakers will be of the thermal magnetic type and be capable of interrupting the

maximum fault current available on the 400-volt system.

Relay protection for the 11-0.4 kV supply transformers will consist of the following:

Neutral time over current on the secondary protection

Differential protection covering the transformer and supply breaker to the 3.3-kV bus

Fault pressure (if the transformer is oil filled)

High oil temperature (alarm only if the transformer is oil filled)

High winding temperature


The 400-volt system will normally be operated in a radial fashion with each bus section fed from a unique

transformer. Manual realignment of the power center will allow continued operation in the event a

transformer is out of service.

3.29 DC SYSTEMS

3.29.1 FUNCTION

The plant DC systems will be provided to supply power to the various DC loads required for station

operability and recovery from a sustained loss of AC power.



3.29.2 DESIGN BASIS

The quantity and voltage levels of the DC systems will be based upon the requirements of the major

plant suppliers.

Each battery system will consist of a battery, battery chargers, distribution switchgear and distribution

panel boards. The assignment of loads to the various systems will be based on voltage requirements,

redundancy, and function. In general, loads capable of causing transients on the system such as motors

or large solenoids will be placed on systems separate from loads for control and instrumentation.

The batteries will be of the lead calcium or nickel cadmium type and will be sized to supply power for a

period of time consistent with that required to place the units in a shutdown condition and to prevent

equipment damage following a loss of AC power. Battery sizing will be adjusted based upon aging and

temperature correction factors.

Battery chargers will be sized on the premise of supplying normal DC station loads while concurrently

recharging the respective battery from a design minimum to full charge within 24 hours. During the

recharge period, the charger output voltage will not exceed the maximum allowable for the connected

loads. The chargers will also incorporate a current-limiting feature to restrict maximum fault current to

125% of rating.

A manually operated, non-automatic output breaker will be provided on the output of each charger to

facilitate maintenance.

DC distribution equipment will be rated to withstand the rated DC fault current available. Circuit

breakers, fused switches, and/or DC starters will be supplied depending on the specific application.

The DC system will be ungrounded and furnished with a ground detection scheme to alarm fault

conditions.


The quantity and voltage levels of the various DC systems will be as required to support reliable plant

operation. In general, DC systems will be utilized so the shutdown of one unit will not adversely impact

operation of the other unit. Common facilities will likewise use shared DC systems.

Batteries will be located in a location separate from other plant equipment. Ventilation will be provided

to minimize the potential for hydrogen accumulation. Heating and/or cooling of the batteries will be as

required to minimize capacity derating due to low temperatures, and to reduce the impact on battery

life caused by elevated temperatures.


Under normal conditions, with AC power available, the power to the DC system will be supplied by the

battery chargers. The charger voltage will be maintained slightly higher than the battery open-circuit

voltage so as to maintain a “float” condition on each cell. This will greatly reduce the need for periodic

over voltage charging to equalize each cell’s specific gravity.

With a loss of AC power, the DC loads will be supplied by the battery itself. Critical loads, required either

for unit shutdown or to preclude equipment damage, will thereby be assured of a continuous source of

power.



Upon restoration of AC power, the chargers will resume servicing the DC load requirements as well as

recharging the batteries.

3.30 UNINTERRUPTIBLE POWER SUPPLY SYSTEM

3.30.1 FUNCTION

The uninterruptible power supply (UPS) will be used to supply all 220-VAC plant loads required to be

operational immediately following a loss of station power. Loads supplied by this system will be those

necessary to minimize the impact of a loss of station AC power.

3.30.2 DESIGN BASIS

Power from the UPS system will be supplied at 220-VAC, 50-Hz, grounded single phase. Voltage variation

will be plus or minus 1% when the supply is from either the primary or secondary supply. The primary

UPS power source will be an inverter fed from a rectifier backed up by the station battery.

In the event of a failure of the inverter, a fast-acting static transfer switch will change to a secondary

power supply from a regulated transformer of an AC source. During normal operation, the inverter

output will be maintained in synchronism with the output of the regulating transformer.


One UPS system will be provided for each unit. Each system will consist of rectifier, inverter, regulating

transformer, transfer switch, and distribution panel board. A blocking diode will also be required to keep

the entire output of the rectifier feeding the inverter and not charging the battery.


Under normal operation, the UPS power is supplied from an AC to DC rectifier feeding a DC to AC

inverter, which has a 220-VAC output. The station battery also feeds into the inverter so that there is a

constant power source if AC power is lost. A high-speed static transfer switch will switch the inverter

output to a regulated 220 VAC source if there is an inverter failure. Upon restoration of the inverter

output, the transfer switch will reconnect to it putting the system back into normal operation.

Manual transfer will also be provided to facilitate maintenance activities.

3.31 EMERGENCY DIESEL GENERATOR SYSTEM

3.31.1 FUNCTION

The emergency diesel generator system is utilized to supply AC power to selected plant loads following

a loss of station AC power.

3.31.2 DESIGN CRITERIA

The diesel generator will supply power to the essential service boards. Loads required to remain on line

after a plant shutdown due to a complete loss of AC power will be identified and included with those

supplied by the diesel generator.

To ensure rapid start capability, the diesel will be equipped with item such as lube oil and jacket water

preheaters.



The diesel governor will be capable of operation in a droop mode for testing purposes by synchronizing

it to the energized load. It will run at constant frequency or isochronous when operating independently

to service the emergency loads upon loss of all other AC power.

The diesel rating will be sufficient to supply the load deemed critical for shutdown of both units when

there is a loss of normal AC power. Consideration will be given both to the capability to supply running

motor loads as well as the capability to start larger motor loads.


The diesel generator system will consist of a single machine capable of supplying the shutdown loads of

both units. A bus tied to both unit essential service loads will be provided so that the single machine can

service both units.


Feeder breakers will be provided on each essential bus to allow connection to the diesel both for testing

and operational purposes. The diesel will receive a start signal from an under voltage relay from the

essential buses.

Following a brief time delay to override any transient under voltage, the diesel will start and come up to

rated frequency and voltage. The operator will then close the breaker to energize the diesel to the

essential service bus of each unit.

In addition, provisions to allow periodic diesel testing will be provided. These will consist of manual start

capability as well as a synchronizing relay to prevent an out of phase connection of the machine to the

distribution system

3.32 SWITCHYARD

3.32.1 FUNCTION

The switchyard design will be such as to minimize the effects of equipment failure on station availability

while providing adequate protection of the station power transformers and transmission lines.

3.32.2 DESIGN BASIS

The switchyard will be designed to allow complete power evacuation from the plants into the 500-kV

AC grid while allowing any circuit breaker or other piece of switchyard equipment to be taken out of

service for maintenance or replacement after a failure. Switchyard ratings will be in accordance with

international standards based on the results of system design studies.


The switchyard will be configured as a metal-enclosed pressurized SF6 gas insulated two-bus breaker-

and-a-half arrangement with the line coming in from unit and the line going out to evacuate the power

into the 500-kV AC grid. The switchyard is arranged in a breaker-and-a-half design to accommodate

future expansion either in transmission lines or generating units. Two diameters of three breakers each

will be required for such an arrangement.



Each SF6 circuit breaker can be isolated by disconnect switches. A 1,200-ampere disconnect and

grounding switch will also allow isolation of each incoming and outgoing circuit. Voltage transformers

will be provided on both end buses and on each incoming or outgoing circuit connected between two

circuit breakers. Multicore current transformers will be provided for each of the circuit breakers.

Monitoring of the plant net electrical output will be conducted on the high-voltage side of the station

transformers. Separate metering class instrument transformers and metering instruments will be

provided to allow accurate power measurements.

All switchyard equipment and structures will be connected to a ground grid of stranded copper or

copper clad steel cables. The grounding system for the switchyard will be interconnected with the

overall plant grounding system, and will be designed in accordance with IEEE standard 80.

All metallic equipment and structures will be effectively grounded to reduce step and touch potentials

to tolerable levels for personnel safety.

The switchyard and plant grounding system design will be based on soil resistivity measurements made

at the site. If necessary, ground rods will be utilized to reduce the overall ground resistance to the

calculated safe permissible level.


The GIS switchyard will be configured as a breaker-and-a-half design. The switchyard will be controlled

by master (remote) and local controls. The master control will be from the switchboard panels in the

main control room of the power plant. The local control will be from panels located in the switchyard

building.

Redundant batteries, chargers, and distribution panels for breaker control will be provided. Separate

control panels will be provided for the switchyard and located in the switchyard control building. These

panels will contain the protective relaying, communications, telemetry equipment, and the AC and DC

distribution systems associated with the switchyard.

All 500-kV circuit breakers will have two trip coils supplied from two different DC sources. The 500-kV

transmission line will be protected from phase and ground faults by two sets of protective relays

(primary and backup). The primary protection will consist of a solid-state distance relay terminal

operating in a directional comparison blocking scheme and will communicate with the remote over a

power line carrier channel in one of the phases of the power line. The backup protection will consist of

electromechanical or solid state step distance relays and will operate in conjunction with a bidirectional

transfer trip system over a power line carrier channel in another phase of the power line.

Breaker failure protective relays will also use this communication channel for transferring the trip to the

remote end of the transmission line.

Non-directional overcurrent relays will be provided for transmission line protection against energizing

the line with an accidental three-phase to ground connection.

3.33 INSTRUMENTATION AND CONTROLS

The control and instrumentation systems will be upwardly compatible, the state-of-the-art systems that

have been installed and have been operating in power plants for at least three years.



3.34 DISTRIBUTED CONTROLS AND MONITORING SYSTEMS

The control and monitoring functions will be implemented in a microprocessor-based distributed

control system (DCS) that encompass the following subsystems:

Boiler combustion and miscellaneous modulating control systems (BCS)

Burner management system (BMS)

Data acquisition system (DAS)

Sequence-of-events recording system (SER)

Electrical auxiliary power circuit breakers control system (APCS)

Motor control system (MCS)

Plant protection system (PPS)

Human-Machine CRT-based operator consoles (MMI)

The control and monitoring functions for each of the above systems will be configured in dedicated

redundant controllers located in system cabinets that interface with each other and with the MMI via

redundant data highways. The DCS cabinets will be either geographically distributed throughout the

plant and will be located in environmentally controlled enclosures.

The DCS will also include provisions for interface via redundant Ethernet data links with control and

monitoring systems furnished by equipment suppliers, such as the following:

Turbine-generators

Feedwater pumps

Compressors

Coal and ash handling systems

Load dispatching

Water treatment and condensate polishing systems

Continuous emission monitoring system

Seawater FGD system (may be implemented in the DCS)

Each of the above systems will use either distributed microprocessor-based systems or programmable

logic controllers (PLCs).

A conceptual DCS architecture/overview block diagram IC-001 is attached to this report in Appendix I. It

should be pointed out that this diagram will be revised for the EPC specification.

The DCS will provide scanning, controlling, alarming, and logging functions. All DCS subsystems will

operate in parallel and all system functions will occur in real-time operations.

The monitoring and management functions will be highly centralized by means of a monitor and

keyboard. The functions of control, protection, and interlock will be extensively distributed to

individual microprocessors or programmable controllers.



The sequence-of-events (SOE) system will have one millisecond resolution covering critical boiler,

turbine, generator, and plant protection systems inputs. The SOE will be an integral part of the DCS.

The DCS will have self-diagnosing abilities, so that internal faults can be detected within the system

before the resulting disturbance to the process and so that measures can be taken to prevent spreading

of the fault. Alarming of the fault will also occur simultaneously.

The protection and interlock systems will be provided with redundant channels and multipoint

measurement, as well as self-diagnosing functions and adequate test facilities to meet the following

criteria against failure.

No single fault will cause the complete failure of any system.

Redundancy in the control system structure will be provided so that no single fault within a control

system can cause failure of the controlled equipment or cause the standby equipment to be

unavailable. In case of a failure of in-service equipment, the standby equipment will start up

automatically without any system interference.

For critical parameters, three independent measurements will be provided. Control and direct indication

will be derived from the median value of measurements. High deviation from the median value will be

alarmed and removed from the median signal.

For protection, multi-channel measurements will be provided. All trip circuit will be performed with two-

out-of-three logic.

The DCS will be designed to maintain the control variable limits within the values specifically by the boiler

and turbine manufacturers.

A historical data collection, storage, and presentation (historian) system will be supplied that will fully

automate the collection, storage, and presentation of plant data. The historian will provide a centralized

collection of information, a real-time database, and a historical data archive. The historian will interface

with all of the plant real-time systems simultaneously and will be capable of reading and writing to these

systems.

The system will store data to an adequately sized storage medium with a printer and necessary

software.

3.35 OPERATOR CONSOLE

The operator control console will include the following:

Furniture, material, and design based on human factor engineering

Four operator workstations, each with two 500-mm (21-inch) monitors with keyboard for the DCS

One operator workstation with two 500-mm (21-inch) monitors for the turbine control system (TCS)

PC/PLC network control workstations, each with a 500-mm (21-inch) workstation, as required

Emergency trip pushbuttons for boiler shutdown and turbine trip

Two colour screens for alarm monitoring

Pushbuttons for alarm signal acknowledgement, silence, etc.



PLC network integrated into the DCS.

One operator workstation with monitor and keyboard for monitoring only will be provided for the shift

supervisor’s office.

Two engineering workstations, each with a monitor, will be provided. The engineering workstations will

include all functions and capabilities available for the operator consoles plus the necessary

enhancements for the performance of the required DCS engineering / programming functions. One

color graphics printer common to both engineering workstations will be provided.

There will be networked printers, driven from common drivers, to perform the following functionalities:

Screen copy printer (colour)

Report and SOE printer

Unit monitoring control panels

Conventional indicators, meters, communication equipment, alarm equipment, and code-required

devices used for emergency shutdown, safe unit operation, and critical plant monitoring will be provided

on the monitoring control panels. Panels will include the following:

Emergency shutdown control panel, which will include the emergency pushbuttons for boiler and

turbine

Metering / synchronization control panel, which will include revenue metering (including digital

displays for unit mega wattage, frequency, and time), generator breaker control switches, and

synchroscope

Plant fire protection and alarming panel

Plant paging communication station

3.36 BOILER CONTROL SYSTEM

3.36.1 GENERAL

Boiler control system (BCS) is a part of the DCS.

The BCS design will include redundant distributed processors that are physically and functionally

segregated from processors in the other systems. Critical signals between the BCS and the other systems

will be hard-wired. The controls will be partitioned such that the control logic for equipment companion

pairs is not implemented in the same processor.

The control system will meet the requirements set forth in the latest edition of the NFPA 85.

3.36.2 SYSTEM DESCRIPTION

Controlled parameters will not exceed permissible limits along the range from lowest coal-fired load

(30% to 35%) up to 100% MCR load. For parameters required to be controlled throughout the whole

range of load variation, full range control will be implemented in the DCS so as to lessen the intermediate

intervention of the operator.

For adaptation of the unit to the network load and frequency regulation, the turbine-boiler coordination

control system will be employed as the unit main controller. The main controller will meet the need



under all operating conditions of the unit, and control the load variation according to permissible

thermal stress value of boiler and turbine, to get the shortest possible ramp time. The unit target load

may set by the operator or by the load-dispatching center.

Self-diagnostic, interlock, and protection will be provided for the control system. Alarm signals will be

sent to the alarm monitors during initiation of these functions and be logged by the printer. The control

system will not transfer to the “auto” mode, if the necessary conditions are not satisfied. In “auto” mode,

the system will automatically and bumplessly transfer to “manual” mode if necessary control input is

lost or if the system fails.

The interlock and protection system will allow on line testing and maintenance.

The BCS will include the following:

Boiler-turbine coordination control (boiler follow, turbine follow, and coordinated or integrated

control modes)

Fuel control

Draft air control

Furnace pressure control

Feed water flow control

Primary air flow control

Primary draft fan outlet pressure control

Superheater, reheater steam temperature control

Air heater discharge temperature control

Deaerator water level control

Condenser hot-well level control

Bypass system control (if provided)

HP and LP feedwater heaters normal and emergency level control

Condenser air extraction control

Turbine lube oil temperature control

Generator stator hydrogen temperature control

Closed cooling water controls

Any other mechanical/process equipment (furnished for the Project) control

Interface with PLCs provided for various systems

3.37 BURNER CONTROL AND FURNACE SAFETY SYSTEM

The burner management system (BMS) will be designed using redundant distributed processors that

are physically and functionally segregated from processors in the other systems. Critical signals between

the BMS and the other systems will be hard-wired. The control services will be partitioned such that the

control logic for equipment companion pairs is not implemented in the same processor.



The control system will meet the requirements set forth in the latest edition of the NFPA 85.


The system will provide control of start-up/shutdown, fuel feeders, burners and igniters, and provide

furnace monitoring and protection.

The system will provide the following functions:

Furnace purge and ignition system leak test before boiler ignition

Automatic or manual ignition and shutoff of igniters and main flame

Igniter and burner start-up/shutdown monitoring

Coal feeder and igniter trips (main fuel trip)

Operating interface for the monitoring and control of fuel feeders and igniters

Interface for boiler control system and protection system

Flame detection

Igniter fuel leak test

Implosion protection of furnace and flue gas ducts

3.37.2 FLAME SCANNERS

The BMS will be completed with the proper type and quantity of flame scanners for main flame and

ignition fuel flame for the circulating fluidized bed boiler. Each scanner will be connected to a flame

monitor via individually shielded and armoured cable.

3.38 TURBINE CONTROL SYSTEM

3.38.1 GENERAL

The turbine control system (TCS) will be designed using redundant distributed processors that are

physically and functionally segregated from processors in the other systems. Critical signals between the

TCS and the other systems will be hard-wired. Hardwired signals between the TCS and other systems

will be reviewed and finalized during detail design. The control services will be partitioned such that the

control logic for equipment companion pairs is not implemented in the same processor.


The TCS system will provide the following functions:

Roll-up and synchronization. The TCS system will perform pre-checks to ensure that the roll-up

initiation conditions are satisfied. The system will provide turbine roll-up control from turning gear

to target load at the maximum rate compatible with the thermal state of the turbine, the steam

inlet conditions, and the allowable expenditure of turbine life expectancy.

Load control. The turbine generator output will be automatically regulated according to a target

load demand. The system will have maximum and minimum adjustable load limits and a rate limit

of changing load. The system will monitor the process variables and equipment status that restricts



the output of the turbine generator set. When such conditions occur, the system will limit the load

signal and initiate an alarm.

Speed control and protection. The system will have speed control and over speed protection.

Constant pressure operation. When the unit operates with constant pressure, the valve

management function will be employed by the TCS.

Testing. The TCS system will facilitate on line testing of turbine valves and high-speed trip.

Performance monitoring. The TCS system will monitor the main steam parameters, status of

turbine and auxiliaries, and turbine thermal stresses; and it will provide the DAS with input for

calculation of turbine performance.

Turbine emergency trip system. The turbine generator and auxiliaries will be capable of emergency

automatic or manual shutdown from any load.

Sufficient input/output (I/O) capability will be provided in the DCS to allow for hard wiring of critical

turbine parameters.

3.38.3 TURBINE SUPERVISORY INSTRUMENTS

A whole set of turbine supervisory instruments (TSI), sensors, and transmitters required for safe start

up, operation, and shut down of the turbine generator set will be furnished. TSI will include, but not

limited to, the following:

Vibration (amplitude, frequency, and phase) of each bearing

Rotor displacement

Eccentricity

Speed

Differential expansion

Thrust bearing wear

Bearing metal temperature

Turbine metal temperature

Cylinder expansion

Governor valve position

Turbine water induction detection thermocouple

Rotor stress and life cycle calculations

3.39 VIBRATION MONITORING

All large rotating machinery driven by medium-voltage motors will have vibration & thrust monitoring.

The application of monitoring equipment will be subject to the size and type of rotating equipment.

Adequate vibration monitoring sensors will be provided based on equipment manufacturers.



3.40 CONTINUOUS EMISSION MONITORING SYSTEM

A complete extractive-type continuous emission monitoring system (CEMS) will be provided with flue

gas analysers for SO2, NOX, CO2, and opacity meters for each unit. The CEMS will be furnished with

sampling systems, sample conditioning, sample lines, analysers, a programmable logic controller (PLC),

and a shelter to house the CEMS equipment. The PLC will have a redundant link to the plant DCS.

3.41 PROPOSED COAL RECEIVAL

Coal handling facilities are available both at Karachi Port and the Port Qasim. The preferred option for

imported coal is the under-construction Pakistan International Bulk Terminal (PIBT) at Port Qasim. The

terminal is expected to be operational by 2016. PIBT will have a capacity to handle 12 million tons of coal

annually and will have a storage capacity of 0.5 million tons at a given time.

An artist rendering of the PIBT terminal and its storage area is shown in Figure 3.9.

Figure 3.9 – PIBT Jetty and Coal Terminal

Coal will be transported to Pakistan through shipping vessels. The preferred vessel for shipment of coal

is Handymax. Handymax are bulk carriers (Figure 3.10) with a capacity typically between 35,000 and

50,000 DWT. These types of vessels are well suited for small ports with length and draught restrictions,

or ports lacking transhipment infrastructure. As a result, Handymax along with Supramax, a relatively



larger vessel type with capacity typically between 50,000 and 60,000 DWT, represent the majority of

bulk carriers of over 10,000 DWT capacity. These bulk carriers are primarily used for carrying dry cargo

such as iron ore, coal, cement, finished steel, fertilizer, and grains. A handymax vessel is typically 150-

200 m (490-655 ft) long with 5 cargo holds and 4 cranes of 30 metric ton lifting capacity. As they are

equipped with on-deck cranes, they provide best options for carrying cargo to less sophisticated ports.

Figure 3.10: A Typical Bulk Cargo Vessel of Handymax Category



4.0 SCREENING OF ALTERNATIVES

Identification and assessment of feasible alternatives to project design and implementation is among

the main components of Environmental & Social Impact Assessment procedures. Alternatives illustrate

and contrast the environmental implications and consequences of different options available to achieve

the proposed objective. In this way, both the proponent and the authorities who must consider granting

the authorization, are put in a position where all involved are able to make informed choices or

decisions.

Selection of preferred alternative is based on scores of factors including cost, schedule of delivery,

environmental and social impact and the cost for their redressal. The drivers that affect potential

alternative options and scenarios include: availability of project sites, current technologies; design

changes that need to be introduced, operational situation, capital & recurrent costs, environmental &

social issues, their potential impacts, and costs of mitigation. The “No Project” alternative situation is

taken into account to demonstrate the need of the Project. In consideration of the different drivers,

potential alternatives within the Project are restricted to the following aspects:

No Project Option

Project Alternatives

Technology selection

Availability of site and infrastructure

Availability of appropriate energy source

4.1 NO PROJECT ALTERNATIVE

The no-development option simply means that the Government of Pakistan does nothing to address

the purpose and need for the power generation and transmission. The most significant outcomes of this

approach would be a negative impact on current electricity supplies, and the possibility of complete

blackouts at times of high demand. The power generation capacity of Pakistan meets only 40 percent

of the current demand and if the “No Project” is to have its way, the Country will have to slow down the

growth rate of its economy and all its development projects will come to a standstill. At present

additional pressure is being put on already deficient electricity generation capacity by the urban and

industrial demand. The present shortfall is estimated at 10,000 MW and the power outage has gone up

from 6 to 14 hours in urban areas and 10 to 20 hours in rural areas.

Government of Pakistan is desperately looking for all options to bridge this gap. The National Energy

Policy 2013 requires development of strategy to i) ensure the generation of inexpensive and affordable

electricity for domestic, commercial, and industrial use by using indigenous resources such as coal (Thar

coal) and hydel power, ii) address the key challenges of the power sector in order to provide much

needed relief to the citizens of Pakistan, and iii) shift Pakistan’s energy mix towards cheaper fuel and

conservation of gas for power.

It is the professional opinion of the EIA Team that the no-development option is unrealistic, and, indeed,

following this approach would result in the stagnation or cessation of many Government strategies that

have been planned and implemented. Due to the negative consequences of the no-development

option, it has been discarded from further consideration in this EIA.



4.2 TECHNOLOGY SELECTION

4.2.1 THE BOILER

It is important that the proposed solution for coal fired steam generators is a technologically proven and

commercially available. Although technological advances in this field have been achieved, it is imperative

that only commercially proven systems are considered to reduce risks during implementation and

subsequent operation and maintenance. Boiler technologies that can be considered are:

Pulverized coal (PC) combustion technologies (sub-critical or supercritical)

Fluidized bed combustion (FBC) technologies.

PC boiler are less expensive than FBC boiler. FBC boiler and handling systems appear to be 1/3 more

expensive, with few existing installations. FBC installations also require more space. The PC technology

was therefore selected for the Project.

The technology selection also includes the evaluation of subcritical or supercritical boiler. The selection

of the technology will determine the boiler and turbine suppliers as they have definite expertise for

either subcritical or supercritical designs.

The terms “subcritical” and “supercritical” refer to main steam operation conditions being either below

or above the critical pressure of water (221.255 bars, 3,208.2 psia). The significance of the critical point

is the difference in density between steam and water. Above the critical pressure, there is no step

increase in the density between water and steam.

A typical subcritical cycle has a maximum turbine throttle pressure of 173.8 bar (2,520 psig), and a typical

throttle pressure for a supercritical cycle is 248 bars (3,600 psig). The higher pressure of a supercritical

cycle results in a higher efficiency than a subcritical cycle. The difference in pressure results in a heat rate

difference of up to approximately 2%.

There are currently over 400 supercritical units in operation in the United States, Europe, Korea, and

Japan and a few in the developing countries. The European, Japanese, and, recently, the Chinese

suppliers have standardized on supercritical designs for units larger than 600 MW. Due to renewed

interest in large coal-fired plants in the United States, the American suppliers have revived the debate

over subcritical versus supercritical steam cycles. Most recent coal plants now under design and

construction are supercritical.

The selection of the technology also considers the capital cost of a supercritical versus a subcritical plant.

The capital cost of a supercritical plant is generally approximately the same as, or 2% higher than, a

subcritical plant. This cost difference, however, is well within the spread of prices expected in a

competitive bid situation, depending on the selection of the EPC Contractor.

Based on the above, the LEPCL Project will be based on a supercritical cycle to realize the benefit of

higher efficiencies and, thereby, reduced fuel costs over the life of the Project. On top of that higher

efficiency means better environmental plant operation.

4.2.2 UNIT SIZE SELECTION

The general trend in recent coal-fired power plants is to build larger size units, and most of the new coal

fired units built in the last five years have been in the 600 MW to 1,000 MW size range. Some smaller



units (200 MW to 500 MW) have been built, but in most of those cases, the small size was selected due

to grid or transmission limits. The economies of scale, including lower capital cost in $/kW and lower

operating costs ($/MWh), favour the larger sizes.

Based on the policy frame work generation range of 660 MW imported coal based super critical power

plant was studies. The capital cost of a coal fired unit, expressed in the revised coal policy is 1.6 million

$/MW, decreases as the size increases, as shown in the following figure.

Figure 4.1 – Indicative Relative Cost Relationship (Unit size is gross MW)

The typical capital costs are based on a new site, with site development costs, administration buildings,

warehouse, etc. included. The capital cost for two units (e.g. 1x660 versus 2x660) is lower on a $/kW

basis because many of these costs are significantly lower with two units.

There are no significant break points where the unit cost experiences either a step increase or step

decrease change in cost. There will be small step changes for individual suppliers, but when considered

across available suppliers, those step changes disappear. For example, there will be a step increase in

capital cost of approximately $10/kW at approximately 600 MW when there is a change from five to six

pulverizers.

However, this change will not occur at the same size for all boiler suppliers. Therefore, there is no cost

advantage to any specific unit size.

Competitive pricing is a significant factor in the cost of a unit. In the size range of 330 MW to 1,000 MW,

there are several suppliers of all major equipment, with the most competition in the 600 MW to 660

MW size range. Most boiler and turbine suppliers have standard or reference designs that they prefer

to offer. If they can duplicate an existing design, they can reduce costs and can be more competitive. For

this reason, the most competitive prices can be obtained by specifying a size range (e.g. 650 MW to 700

MW) rather than a specific size.

The efficiency of a coal-fired unit increases slightly with size due to improvements in turbine efficiency,

boiler efficiency, and auxiliary power consumption. Larger turbines are more thermally efficient, and

one factor contributing that the higher efficiency is that as turbine blades increase in length, leakage past

the end of the blades becomes a smaller percentage of the total flow. Boiler efficiency increases slightly

with unit size because the heat loss from the boiler casing becomes a smaller percentage of total heat

generated. The auxiliary power, as a percentage of gross output, also decreases with unit size. The

overall impact can be seen by comparing the heat rate of the 330 MW, 450 MW, and 660 MW sizes in

the following figure.



Figure 4.2 – Indicative Heat rates for Unit sizes

Meetings were held with WAPDA and NTDC to discuss generator sizing, and it was determined that the

largest generator that the grid can accommodate is 660 MW. This is a similar size to the 1990 feasibility

study commissioned by WAPDA. On the basis of lower capital cost and improved heat rate, only units

of approximately 660 MW (gross) were considered as the preferred alternative.

4.2.3 PARTICULATE MATTER EMISSION CONTROLS

The main concern with the coal fired is emission of flue gases and particulate matter. The Particulate

Matter of concern is PM10 whose level must be reduced to permissible limits. Technologies need to be

introduced in all coal fired boiler as mitigation measures. Particulate matter treatment technologies that

can meet the environmental control requirements are fabric filters and electrostatic precipitators (ESP).

Fabric Filters: The major advantages of fabric filter dust collectors over electrostatic precipitators are:

lower initial cost, modular construction (permits on-line maintenance), no high voltage requirements,

simplicity, wide economical capacity range, and a high collection efficiency (99 percent plus) that is not

appreciably affected by such variables as inlet grain loading, particle size distribution, turndown, or fuel

constituents. Major disadvantages include: fabric filter is sensitive to flue gas temperature and the flue

gas temperature must be controlled for maximum bag life and preventing bag blinding (clogging),

operation with flue gas temperatures below the dew point will blind the bag house filters within a short

operating period and shorten fabric filter life, operation above the temperature limits of the fabric filter

will result in fabric failure, and fabric filter calls for an increased operating load on the Induced draft fan

due to the higher resistance for gas flow through the bag house.

Electrostatic Precipitators: The major advantages of the electrostatic precipitator are normally smaller

physical size than fabric filters, a wide range of temperature applications and ability to tolerate

temperature excursions outside the normal operating range, low pressure drop with resulting low

energy consumption, and dry continuous disposal of collected dust. A properly designed and operated

precipitator can perform in a reasonably high collection efficiency range Limitations include:

electrostatic precipitators are normally more process sensitive than fabric filters and require tighter

control of boiler and collector operating conditions and fuel selection, low sulfur coal, selected for

reduced sulfur dioxide emissions, normally produces a high resistivity ash. The electrical charge

retention ability of high resistivity ash makes it difficult to remove from the collecting plates thereby

causing excessive ash build-up and electrical arcing resulting in erratic currents and reduced power to



the fields which in turn reduces the collecting ability of the unit, unburned carbon in the fly ash which

reduces resistivity but is an operational problem. Initial cost is usually higher for an electrostatic

precipitator versus a fabric filter of the same design performance.

A comparison of the technology is presented in Table 4.1.

Table 4.1 – Comparison of Options for Control of Particulate Matter

Option ESP Fabric Filter

Removal Efficiency >96.5% (<1 μm), >99.95% (>10 μm)

>99.6% (<1 μm), >99.95% (>10 μm)

Electricity Consumption

0.1-1.8% of electricity generated 0.2-3% of electricity generated

Other factors

- Might not work on particulates with very high electrical resistivity. In these cases, flue gas conditioning (FGC) may improve ESP performance.

- Can handle very large gas volume with low pressure drops

- Filter life decreases as coal S content increases

- Operating costs go up considerably as the fabric filter becomes dense to remove more particles

- If ash is particularly reactive, it can weaken the fabric and eventually it disintegrates.

Source: IFC EHS Guidelines 2007

For Fly ash collection from coal-fired boiler the most common practice is use of electrostatic

precipitators. With the added advantage of low space requirement, wide range temperature operation

and low pressure drop ESP has been preferred for this project.

4.2.4 ASH HANDLING AND DISPOSAL

Fly ash, bottom ash, and boiler slag are other areas of concern in case of coal fired boiler. Recycling of

ash will be the preferred option for ash disposal. A review of the utilization of fly ash produced in the

coal powered plants in India shows that on an average the utilization of fly ash produced by the coal

fired power plants is over 50%, with a number of plants achieving 100% utilization. In China, the nearly

70% of the fly ash produced is recycled.

The quantity of ash production from the proposed Project will depend on the quantity of coal and its

ash content. For 5-10% ash content, the ash production is estimated at 250,000 to 500,000 tonnes/year.

The fly ash collection and disposal system will transfer particulate collected from the boiler flue gas to a

fly storage silo for unloading into trucks for disposal (transported to lucky cement Karachi). Fly ash


will also be collected throughout the flue gas system by means of ash hoppers at other locations such as

the air heaters.








4.3 COAL SOURCE AND PRICING 4.3.1 SUPPLY

It is anticipated that the most economical coal supply will come from Indonesia, South Africa, and/or

Australia. Indonesia is currently the world’s leading exporter of steam coal as of 2013 coal exports in

excess of 423 million metric tonnes (Mt). Australia is the second largest steam coal exporting country

with 2013 exports of 182 Mt, followed by South Africa with 2013 steam coal exports of almost 72 Mt.

These three countries comprise almost 62% of the 2013 seaborne steam coal exports. There is a

possibility that coal can be sourced from China or other compatible countries, at a later date. Indigenous

coal supply from Pakistan is currently being evaluated and can be used provided it meets the quality,

quantity, and cost requirements of the Project.

4.3.2 WORLD PRODUCTION: THE WORLD SEABORNE THERMAL COAL MARKET

The current coal markets are at historical high prices but may depress in the near future due to

oversupply (Figure 4.3).

Source: Global Coal & Indonesian Govt (hist), Wood Mackenzie (Forecast)

Figure 4.3 – Asia Pacific Thermal Coal Prices



Figure 4.4 – Thermal Coal Demand

The low value of the U.S. dollar against other currencies, particularly the Australian dollar, also has a

direct effect on the high price of coal.

This is a coal sellers’ market, and such sustained high demand and high-priced markets tend to skew

their strategy. Coal sellers believe the high-priced market will last, that good-grade coal will basically sell

itself into the future, and that the good-grade coal will always be in demand at high prices. Coal sellers

are now marketing lower calorific value coal from Australia and South Africa and low-rank lignite coal

from Indonesia. Sellers claim that coal is discounted for heat value against 6,332 kcal/kg GAR, but that

little or no discount is given for other properties such as high moisture, ash, or sulfur.

The only coal that is currently offered at a significant discount is low-rank (4500 kcal/kg GAR) Indonesian

coal, which may provide an economic advantage to LEPCL. However, the added freight costs and the in

load and boiler costs must be considered. It is obvious that relying on economically shipping low-rank

lignite coal over such a long distance involves risk of increased freight costs for very low heat coal.

4.3.3 POTENTIAL COAL SUPPLY SOURCES

It is evident based on logistics and coal availability that the most likely sources of competitive coal supply

to the 660 MW LEPCL power plant in Pakistan are Indonesian, South African and/or Australian coal. Due

to relatively shorter shipping distances, Indonesia, South Africa, and, to a lesser extent, Australia enjoy a

delivered cost advantage to Pakistan over more distant coal-exporting countries such as Colombia,

Venezuela, and Russia. The locations of major steam coal exporting countries supplying Indian Ocean

markets and primary shipping routes to the LEPCL power plant site are shown on Figure 4.5. Distances

are given in nautical miles (N.M.).

Russia is not considered a potential supplier because of its location. It supplies export thermal coal

primarily to Europe and does not have economic access to Asia. China is not considered because, due

to its domestic requirements, China’s export coal tonnages have declined in the last few years. It has



recently had difficulty serving its contracted customers. Due to many uncertainties with China’s coal

exports, it is not considered to be a reliable “bankable” source of export coal.

Pakistan itself has identified coal and lignite resources of coal in the Sindh Province. However, the coal

quality is low with heating values of 2,800 to 4,000 kcal/kg (GAR) and high sulfur values of 1.25% to 5%

on an as-received basis (arb). Some of the deposits are mined, and the coal is used locally. There are no

coal resources at a stage of development or with adequate infrastructure to deliver coal to LEPCL in the

foreseeable future.

However, LEPCL would be quite open to purchasing Pakistani indigenous coal that could be delivered at

an acceptable quality, quantity, and price. Indigenous Pakistani coal supply sources are being evaluated.

Figure 4.5 – Coal Supply Map

As noted earlier, Indonesia is currently the world’s leading exporter of steam coal with 2013 steam coal

exports in excess of 423 Mt. Australia is the second largest steam coal exporting country with 2013

exports of 182 Mt, followed by South Africa with 2013 steam coal exports of almost 72 Mt (Table 4.2).

Pakistan currently imports very little steam coal may be because generating electricity through coal has

not been properly implemented yet. The coal specification to be selected for the LEPCL power plant will

be based on the coal that can most economically be used to generate electricity.

Table 4.2 – Summary of Seaborne Steam Coal Exporters

2013 Export Rank Exporting Country 2013 Steam Coal Exports (Mt)

1 Indonesia 423

2 Australia 182

3 Russia 118

4 South Africa 72

5 Columbia 71



Table 4.2 – Summary of Seaborne Steam Coal Exporters

2013 Export Rank Exporting Country 2013 Steam Coal Exports (Mt)

6 USA 47

7 Canada 4

Total 919

The current status of the Australian, China, Indonesian, Pakistan, and South African potential steam coal

supply source markets is described below.

4.3.3.1 AUSTRALIA - NEW SOUTH WALES

While coal is produced throughout Australia, the states of NSW and QLD currently account for almost

all of the country’s steam coal exports. NSW, which exported approximately 75 Mt of thermal coal in

2013, produces both steam and coking coals from a half dozen different coalfields in the east-central

portion of the state. Steam coal is currently exported from all of the producing regions except the

Southern Coalfield, which only produces coking coals. The bulk of NSW steam coals are exported

through the two coal terminals at the port of Newcastle with lesser amounts shipped through Port

Kembla.

Currently, almost 70% of the steam coal produced in NSW is exported to overseas customers with the

domestic power sector accounting for most of the remaining consumption. Major export markets for

NSW steam coals include Japan, Taiwan, South Korea, Hong Kong, and Mexico.

NSW currently exports steam coal from almost 30 different mines distributed throughout five of the

state’s six active coal-producing regions. Almost 80% of the state’s total steam coal exports are derived

from 17 mines in the Hunter Coalfield, which is also referred to as the Hunter Valley. Seven coal mines

located in the Western Coalfield account for an additional 11% of NSW’s steam coal exports, while five

mines in the Newcastle Coalfield contribute another 6.5%. Two mines each in the Gloucester Basin and

the Gunnedah Coalfield account for the remaining exports.

The steam coals currently exported from NSW are bituminous in rank with as-received heat contents

varying from 6,100 kcal/kg to 6,800 kcal/kg (GAR), ash contents typically between 11% and 16%, as-

received volatile matter contents ranging from 23% to more than 34% and total moisture contents

varying from 7% to 11%. NSW export steam coals are generally low-sulfur products with as-received

sulfur contents of less than 0.9%; however, some higher (almost 2%) sulfur steam coals are exported

from the Gloucester Basin. Due to the recent increase in demand for coal, NSW mines are exporting

higher ash content coal, up to and above 18% ash on an air-dried basis (adb).

Table 4.3 – Major Steam Coal Exporters – NSW, Australia

S. No. Company No. Of Export Mines

1 Rio Tinto 4-5

2 Xstrata 10-12

3 BHP Billiton 1

4 Peabody Energy 3

5 Anglo Coal 1

6 Idemitsu Kosan 3

7 Centennial 4-6

8 Noble Group 1-3

9 Bloomfield Collieries 2-3



Table 4.3 – Major Steam Coal Exporters – NSW, Australia


10 CVRD & Toyota 1

11 Felix Resources 0 – 1

12 Whitehaven Coal Mining 0 – 1

4.3.3.2 AUSTRALIA - QUEENSLAND

Over the past few years, roughly 65% of QLD steam coal production has been exported to international

customers with the remainder consumed primarily by the domestic power generation sector. Major

export markets include Japan, South Korea, Europe, Taiwan, and India.

QLD Steam coal is exported from more than a dozen mines in QLD’s Bowen Basin and three mines in

the Moreton-Surat Basin. The mines in the Bowen Basin account for almost 90% of the state’s steam

coal exports with the remainder produced from the operations in the Moreton-Surat Basin.

QLD’s export steam coals are bituminous with heat contents varying from 5,750 kcal/kg to 6,800 kcal/kg,

ash contents typically varying between 9% and 14%, as-received volatile matter contents ranging from

19% to more than 35%, sulphur contents ranging from less than 0.3% to almost 0.7%, and total moisture

contents varying from 6% to 16%.

A dozen different producing-companies or joint venture partnerships currently export steam coal from

QLD. The three largest producers, Xstrata, Rio Tinto, and Idemitsu, each exporting in excess of 7 Mtpy,

dominate export steam coal supply from QLD and accounted for almost 68% of the state’s total steam

coal exports from past few years.

Table 4.4 - Major Steam Coal Exporters - QLD, Australia


1 Xstrata 3

2 Rio Tinto 2

3 Idemitsu Kosan 1

4 Anglo Coal 2

5 New Hope 3

6 Peabody Energy 4

7 BHP Billiton 5

8 Macarthur Coal 1-2

9 Felix Resources 1

10 Wesfarmers 1

11 Other 2

4.3.3.3 INDONESIA

We have thoroughly gone through the technical and economic aspects of the Indonesian and have

worked on all of the major coal mines including PT Adaro Indonesia, PT Kaltim, PT Arutmin, PT Kideco,

PT Berau, PT Banpu, Indominco, and PT Tanito Baraharum.

International markets have traditionally been the principal destination for Indonesian steam coals with

domestic customers providing a secondary market. Historically, approximately 70% of Indonesia’s



steam coal production has been exported with the remainder consumed domestically. Major export

markets for Indonesian steam coals include Japan, Taiwan, South Korea, Hong Kong, India, Southeast

Asian countries, and Western Europe. Some Indonesian coal is exported as far as South America.

Indonesia’s nine existing coal-fired power plants and cement industry currently account for the bulk of

domestic steam coal consumption.

Indonesia produces steam coals from more than 40 different mines in East Kalimantan, South

Kalimantan, and Sumatra. Almost two-thirds of the country’s export steam coal is produced from 18

mines in East Kalimantan with eight mines in South Kalimantan accounting for most of the remaining

exports. Less than 3% of Indonesian steam coal exports currently originate from the four Sumatran

export mines.

Indonesia’s steam coals are bituminous to subbituminous in rank with widely varying ash, moisture,

sulfur, and volatile matter characteristics. In Indonesia, coals with heat contents in excess of 5,500

kcal/kg (GAR) are generally regarded as bituminous coals while coals with heat contents of 4,175 kcal/kg

(GAR) to 6,500 kcal/kg (GAR) are classified as subbituminous coals.

The bituminous and higher heat content subbituminous coals produced from Indonesia are typically

supplied to export markets. The lower heat content Indonesian subbituminous coals are supplied in

varying proportions to both export and domestic markets. Many of the lowest rank Indonesian

subbituminous coals have gained acceptance in export markets due to their ultra-low (i.e., less than

0.2%) sulfur contents and low ash. Up to 6.0 Mtpy of low-rank coal has been produced by PT Arutmin

(Asam Asam and Mulia mines) and PT Padang Karunia (Rantau Mine). Export markets for low-rank

lignitic Indonesian coal are expanding, particularly in India and South America. Domestic Indonesian

markets are also expanding rapidly. At least two Indonesian Independent Power Projects (IPPs) are

designed for low-rank coal (4,200 to 4,600 kcal/kg GAR). Perusahaan Listrik Negara (PLN), the state

electric company of Indonesia, had sign letters of intent for 20 Mtpy of low-rank coal for 20 years. Coal

production in Indonesia is from (1) the state-owned enterprise PT Tambang Batubara Bukit Asam

(PTBA); (2) holders of Coal Contracts of Work (CCoW) or "Coal Contractors"; (3) Mining Authorization (or

KP) Holders; and, (4) Cooperative Units (KUDs). There are three generations of actively producing coal

contractors in Indonesia with different ownership, royalty, and tax provisions applying to each

generation. KPs are allocated by regional authorities, so it is difficult to document how many KPs actually

exist. In some cases, KPs have been allocated by regional authorities (which overlap CCoWs), which were

allocated by the central federal government. This causes disputes over coal resource control, which has

yet to be resolved.

It should also be noted that CCoWs in Indonesia were allocated with a 30-year life. The majority of the

CCoWs will expire during the 2019 to 2025 time frame. It is generally believed that the CCoWs will be

automatically renewed, but there is no guarantee. Long-term coal supply agreements that extend

beyond the CCoW expiration date will be conditional upon renewal of the CCoW. This may be a concern

for the Project Lenders.

Table 4.5 - Major Steam Coal Exporters-Indonesia


1 Bumi Resources 5

2 Adaro Indonesia 2-Jan



Table 4.5 - Major Steam Coal Exporters-Indonesia


3 Banpu 4

4 Kideco Jaya Agung 2

5 Berau Coal 3

6 Tanito Harum 3

7 Straits Resources 1

8 Tambang Batubara Bukit Asam 1

9 Anugerah Bara Kaltim 2-Jan

10 Baramarta 1

11 Bukit Baiduri Enterprise 1

12 Lanna Harita Indonesia 1

13 Gunung Bayan Pratama Coal 1

14 Multi Harapan Utama 1

15 Mandiri Intiperkasa 1

16 Padang Karunia 0 - 2

17 Other n/a

4.3.3.4 BUMI RESOURCES

Bumi Resources, which controls two operating subsidiaries: PT Arutmin Indonesia (Arutmin) and PT

Kaltim Prima Coal (KPC). The Arutmin operations include three operating coal mines, designated as

Asam Asam/Mulia, Satui, and Senakin; associated barge loading facilities for the respective mines; and

the North Pulau Laut coal terminal. The KPC operations consist of the Bengalon and Pinang coal mines;

barge-loading facilities at the Bengalon Mine; the Tanjung Bara ship-loading terminal serving the Pinang

Mine; and various undeveloped coal resources. Bumi can produce a wide range of coals from 4,200 to

6,700 kcal/kg (GAR).

Bumi Resource’s Pinang, Satui, Senakin, and Batulicin operations produce higher heat content

bituminous steam coals almost exclusively for export markets; the Bengalon Mine produces a slightly

lower quality bituminous steam coal for both export and domestic customers; and the Asam

Asam/Mulia Mine produces low-rank, ultra-low sulfur coal primarily for domestic markets. The

company reportedly also plans to increase coal production capacity at its Bengalon Mine by 9 Mtpy with

perhaps 60% of the expanded coal production available for export markets.

4.3.3.5 PT ADARO INDONESIA

PT Adaro Indonesia (Adaro) produces mid-heat content coal of approximately 5,000 kcal/kg (GAR) and

ultra-low sulfur subbituminous coal for both export and domestic markets from its 27 Mtpy Tutupan

Mine. They also control substantial low-rank coal resources in South Kalimantan. Due to the declining

availability of 5,000 kcal/kg (GAR) coal, the domestic and export market for low-rank coal is developing

rapidly. Adaro claimed that the Tutupan higher rank coal is basically committed in the future and would

not be available for LEPCL. It is believed, however, that Adaro is planning a major expansion, which may

expand the availability of Tutupan coal.



4.3.3.6 BANPU PUBLIC COMPANY LTD.

Banpu Public Company Ltd. (Banpu), operates four mines serving export steam coal markets. Banpu’s

Bontang and Trubaindo operations produce mid- to high heat content bituminous steam coals

exclusively for export markets. Banpu’s Embalut Mine produces mid-heat content bituminous coal for

both export and domestic steam coal markets; while the company’s Jorong operation supplies lower

heat content, ultra-low sulfur subbituminous coal to both nearby power station & off-shore customers.

4.3.3.7 PT KIDECO JAYA AGUNG

PT Kideco Jaya Agung (Kideco), which operates the Roto mining complex in southern East Kalimantan.

Kideco’s Roto North mining unit produces a higher heat content subbituminous coal that is exported

exclusively to South Korean power generators. The company’s Roto South operation produces lower

heat content subbituminous coals for both export and domestic markets. Kideco delivers approximately

5.5 Mtpy of domestic coal to PLN and the PEC Paiton and Jawa Power IPPs. Kideco has substantial

undeveloped low-rank coal reserves (4,100 kcal/kg GAR) with ultra-low sulfur content on the order of

0.15% at Samarangau. Kideco is marketing a 4,600 kcal/kg (GAR) ultra-low sulfur coal, which is believed

to be a mix of Samarangau and Roto Middle coals. Kideco is a very reliable supplier. Kideco is also

planning to expand production, which may increase the availability of Kideco coal for the LEPCL project.

4.3.3.8 OTHER LARGE INDONESIAN STEAM COAL PRODUCERS

The other larger Indonesian steam coal producers exporting in excess of 2.5 Mtpy are PT Berau Coal

(Berau), PT Tanito Harum (Tanito), Straits Resources, and PTBA.

Berau currently exports bituminous to subbituminous steam coals from its Binungan, Lati, and

Sambarata mines in East Kalimantan. Berau controls large resources of coal with an approximate heat

content of 4,700 kcal/kg (GAR) and less than 1.0% sulfur. Berau is a reliable coal supplier. The use of

Berau’s coal should be pursued further.

Tanito exports bituminous coal from its two mines in the Mahakam River Region of East Kalimantan and

subbituminous coal from its recently opened Riau Baraharum Mine on the island of Sumatra.

Straits Resources owns PT Bahari Cakrawala Sebuku, which operates the Sebuku Mine, an exporter of

bituminous steam coal located on an island off the South Kalimantan coast. Straits Resources long-term

resources are limited.

PTBA produces bituminous to subbituminous steam coals as well as limited amounts of anthracite from

its Tanjung Enim complex in Sumatra, with roughly one-third of the operation’s total output exported.

PTBA capacity is limited by the condition of the rail line from the mine to the port at Tarahan.

4.3.3.9 PAKISTAN

Coal in Pakistan is mainly used in the process of brick making, and the rest was used in the cement

manufacturing industry.

Coal resources in the Sindh Province of Pakistan in the Thar Coalfield, 400 km to the east of Karachi,

amount to 185Bt according to the Geological Survey of Pakistan (GSP). A survey in 2002, by the Shenhua

Group of China, has identified a 200-Mt reserve within the Thar Coalfield. The coal ranges from lignite-

B to subbituminous-A.



The ability of indigenous coal in Pakistan to supply coal to the LEPCL Project in the future cannot be

determined at this time. LEPCL is willing to consider the purchase of indigenous coal if the delivered

quality and price are acceptable. The indigenous coal would either replace contracted coal, which could

be reduced to minimum tonnage, or replace other spot coal.

Supply of indigenous coal to the LEPCL project is being evaluated.

4.3.3.10 SOUTH AFRICA

Approximately 72% of the coal produced in South Africa is consumed domestically, with the remainder

exported primarily to Atlantic steam coal markets. Domestic demand for Eskom, the government

generating company, is increasing rapidly and may affect coal availability for export. South Africa also

exports lesser amounts of steam coal to Pacific Markets and minor volumes of anthracite and

metallurgical coals. Major export markets for South African steam coals are Western Europe, Israel, the

United Kingdom, and Morocco.

South Africa currently exports steam coal from more than 50 different mines located in the country’s

central coal-producing region, which comprises portions of the Witbank, Highveld, and Ermelo

coalfields. Almost 85% of South Africa’s steam coal exports come from 41 mines in the Witbank

Coalfield. An additional 8.5% of the country’s steam coal exports are supplied from four mines located

in the Highveld Coalfield, while six mines in the Ermelo Coalfield account for the remaining exports.

The steam coals currently exported from South Africa are bituminous with heat contents varying from

5,700 kcal/kg to 6,500 kcal/kg (GAR), ash contents typically ranging between 10% and 15.5%, as-

received volatile matter contents varying from 22% to 31%, sulphur contents ranging from less than

0.3% to more than 1%, and total moisture contents varying from 7% to 10%.

More than 15 companies export steam coal from South Africa; however, only eight of these suppliers

have steam coal export volumes in excess of 0.5 Mtpy. Export steam coal supply is dominated by the

three largest producing-companies, BHP Billiton, Anglo Coal, and Xstrata. The major South African steam

coal exporters are provided in Table 4.6.

It should be noted also that power shortages now occur in South Africa, and for this reason, future

domestic coal demand will rise. This will tend to further constrain coal available to export.

Table 4.6 - Major Steam Coal Exporters-South Africa


1 BHP Billiton 5

2 Anglo Coal 5

3 Xstrata 11

4 Sasol Mining 1

5 Total Coal South Africa 2-3

6 Kangra Group 1

7 Exxaro Resources 2-3

8 Graspan Colliery 1

9 Bisichi Mining & Endulwini Resources 1

10 Anker Holdings 1

11 Euro Coal 1

12 Wakefield Investments 2



Table 4.6 - Major Steam Coal Exporters-South Africa


13 Woestalleen Colliery 1

4.3.3.11 BHP BILLITON

BHP Billiton, which supplies steam coal for export markets from five operations in the Witbank Coalfield.

On behalf of joint venture partner Xstrata, BHP Billiton manages the merged Douglas surface /

underground and the Middelburg surface mine and produces export coal from three wholly-owned

operations: the Klipspruit and Optimum surface mines and the Koornfontein underground mine.

4.3.3.12 ANGLO COAL

Anglo Coal exports steam coal from its Bank, Goedehoop, Greenside, Kleinkopje, and Landau operations

in the Witbank Coalfield. Bank and Greenside are underground mines, Goedehoop has both surface and

underground operations, and Kleinkopje and Landau are surface mines. Anglo Coal’s steam coal exports

represent approximately 26% of the country’s total steam coal export volume for the year.

4.3.3.13 XSTRATA

Xstrata’s steam coal-producing operations consist of five underground mines (Arthur Taylor,

Boschmans, Phoenix, South Witbank, & Tavistock) and two surface mines (ATCOM and Goedgevonden)

in the Witbank Coalfield; two combination surface/underground operations (Waterpan and Witcons) in

the Witbank Coalfield; and two primarily surface mines (Spitzkop and Tselentis) in the Ermelo Coalfield.

Xstrata have export-share of approximately 21%.

4.3.3.14 OTHER MAJOR STEAM COAL EXPORTERS

South Africa’s other major steam coal exporters are Sasol Mining (Sasol), Total Coal South Africa (Total),

Kangra Group, Exxaro Resources, and Graspan Colliery (Graspan). Although Sasol is one of the larger coal

mining groups in South Africa, the company only exports steam coal from its Twistdraai Mine in the

Highveld Coalfield, with the majority of the company’s coal production consumed in the manufacture

of liquid fuels.

Total exports steam coal from two mines, Dorstfontein and Forzando, in the Highveld Coalfield. The

Kangra Group exports steam coal from its Savmore Mine in the southern portion of the Ermelo Coalfield.

Exxaro Resources, which was formed recently through the merger of Eyesizwe and Kumba Resources,

has two export operations in the Witbank Coalfield. Graspan has a single steam coal exporting operation

also in the Witbank Coalfield.

4.3.3.15 MOATIZE MINE

In addition to the South African mines, a new steam and coking coal mine is planned for Moatize,

Mozambique, by Companhia Vale do Rio Doce (CVRD). The Moatize Mine begin in 2010 with production

of 11 Mtpy comprising 8.5 Mtpy coking coal and 2.5 Mtpy steam coal.



4.3.4 COAL QUALITIES

The power plant will be designed to handle a range of coals from Indonesia, South Africa and/or Australia. These coals and coals of similar characteristics are expected to be

available at market prices. A selected list of international coals, which would most likely be available to the LEPCL Project, is presented in Table 4.7.

Table 4.7 - LEPCL Potential Coal Sources

Location Indonesia South Africa Australia

Parent Company ADRO KIDECO KALTIM PRIMA COAL BANPU BHP Billiton – South Africa RIO TINTO PEABODY

MINE NAME Wara Roto Middle Samarangau Melawan Pinang-5700 Trubaindo

MCV Douglas Optimum Middleburg Hunter Valley Wambo

PROXIMATE ANALYSIS (ARB)

Total Moisture wt % 38.00% 26.4% 36.00% 23.00% 19.50% 13.50% 8.00% 7.90% 8.00% 10.01% 9.00%

Ash wt% 1.70% 2.40% 2.50% 4.20% 4.20% 4.80% 14.40% 12.60% 14.20% 12.50% 11.30%

Volatile Matter wt % 31.40% 35.50% 32.50% 36.20% 36.10% 37.50% 23.10% 26.20% 22.40% 28.60% 31.30%

Fixed Carbon wt % 28.90% 35.70% 30.00% 36.60% 40.30% 44.20% 54.50% 53.30% 55.40% 48.90% 48.40%

Total Sulfur wt % 0.10% 0.07% 0.08% 0.37% 0.83% 0.67% 0.52% 0.46% 0.43% 0.51% 0.45%

Chlorine wt % < 0.01% - < 0.01% 0.01% 0.01% - 0.01% 0.01% 0.01% 0.02% 0.03%

Grindability (HGI) 65 48 47 45 45 47 50 47 52 50 51

PROXIMATE ANALYSIS (ADB)

Inherent Moisture wt % 27.00% 15.00% 20.00% 18.00% 13.00% 9.00% 2.50% 4.10% 3.20% 2.50% 3.00%

Ash wt % 2.00% 2.70% 3.10% 4.50% 4.50% 5.00% 15.30% 13.10% 14.90% 13.50% 12.00%

Volatile Matter wt % 37.00% 41.00% 40.00% 38.50% 39.00% 39.50% 24.50% 27.30% 23.60% 31.00% 33.40%

Fixed Carbon wt % 34.00% 41.30% 36.90% 39.00% 43.50% 46.50% 57.80% 55.50% 58.30% 53.00% 51.60%

Total Sulfur wt % 0.12% 0.08% 0.10% 0.39% 0.90% 0.70% 0.55 0.48% 0.45% 0.55% 0.49%

Chlorine wt % n/a n/a n/a 0.01% 0.01% n/a 0.01% 0.01% 0.01% 0.02% 0.03%



Table 4.7 - LEPCL Potential Coal Sources

Location Indonesia South Africa Australia

Parent Company ADRO KIDECO KALTIM PRIMA COAL BANPU BHP Billiton – South Africa RIO TINTO PEABODY

MINE NAME Wara Roto Middle Samarangau Melawan Pinang-5700 Trubaindo

MCV Douglas Optimum Middleburg Hunter Valley Wambo

SPECIFY ENERGY

Gross Air Dried (kcal/kg) 4825 5502 5045 5750 6160 6500 6602 6515 6568 6850 6900

Gross As Received (kcal/kg) 4100 4765 4100 5400 5700 6180 6230 6255 6240 6322 6475

Net As Received (kcal/kg) 3750 4445 3745 5100 5367 5875 6010 3020 6020 6060 6142

ASH FUSION TEMP. (reducing)

Initial Deformation (deg C) 1200 1140 1150 1150 1100 1330 1390 1360 1400 1500 1380

Spherical Deformation (deg C) 1220 1150 1170 - - 1350 1400 1380 1400 1560 1450

Hemispherical Deformation

(deg C) 1250 1170 1200 1200 1150 1390 1400 1390 1400 1560 1540

Flow (deg C) 1310 1190 1250 1250 1250 1430 1400 1400 1400 1560 1540

ULTIMATE ANALYSIS (daf)

Carbon (wt %) 69.00% 69.00% 70.50% 75.50% 77.00% 77.30% 84.20% 82.40% 84.30% 84.40% 82.50%

Hydrogen (wt %) 5.00% 3.00% 4.80% 5.10% 5.60% 5.40% 4.60% 5.00% 4.60% 5.40% 5.40%

Nitrogen (wt %) 1.40% 0.80% 0.80% 1.60% 1.60% 1.50% 2.10% 2.10% 2.00% 1.90% 2.00%

Sulfur (wt %) 0.10% 0.10% 0.10% 0.50% 1.10% 0.80% 0.70% 0.60% 0.50% 0.70% 0.60%

Oxygen (wt %) 24.50% 27.10% 23.80% 17.30% 14.80% 14.90% 8.40% 10.20% 8.30% 7.60% 9.60%



4.3.4.1 SIZE OF SHIPS AND AVAILABILITY OF COAL CARRIERS

The ocean-going vessels used in the seaborne trade of coal and other dry bulk commodities are referred

to as dry bulk carriers. Bulk carriers are classified by deadweight tonnage (dwt), which refers to a vessel’s

carrying capacity of cargo, bunker fuel, fresh water, and stores, into four general size categories:

Handysize, Handymax, Panamax, and Capesize.

The distribution of bulk carriers by size class is summarized in Table 4.8.

Table 4.8 - Summary of World Bulk Carrier Fleets

Vessel Category

Vessel Size Class (dwt)

No. of Vessels in World Fleet

Percent of World Fleet by No. Vessels

Total Fleet Dead-Weight (Mdwt)

Percent of World Fleet by dwt

Handysize < 35,000 2883 43.40% 51.2 15.00%

Handymax 35,000 - 60,000 1713 25.80% 77.2 22.60%

Panamax 60,000 - 80,000 1249 18.80% 88.9 26.00%

Capesize 80,000 - 150,000 277 4.20%

124.3 36.40% > 150,000 519 7.80%

Total 6,641 100% 341.6 100%

Bulk carriers of less than 35,000 dwt constitute the Handysize vessel category. Vessels with carrying

capacities ranging from 35,000 to 60,000 dwt comprise the Handymax class. Recently, a new vessel

subclass dubbed the Supramax, has emerged between traditional Handymax vessel sizes and Panamax

vessels. Traditionally, most Handymax vessels were less than 50,000 dwt, but the aging Handymax fleet

is being increasingly replaced with Supramax vessels in the 50,000 to 60,000 dwt range.

Bulk carriers in the 60,000 to 80,000 dwt size class are termed Panamax vessels. Panamax vessels are

the largest bulk carriers that can transit the Panama Canal, which has a maximum beam restriction of

32.2 m. Ocean-going vessels exceeding 80,000 dwt falls into the Capesize class.

Care must be taken with defining the size and tonnage of ships, as they are constantly changing designs,

which changes the required berthing depths and dock dimensions.

In addition to the above vessels, the Panamax and smaller vessels can also be equipped as geared

vessels. Geared vessels have the ability to load and unload themselves without the need for a sea crane.

There are only a limited number of geared Panamax vessels available at present, about 100 out of the

total Panamax world fleet at present.

4.3.4.2 HANDLING CAPACITY OF COAL LOADING PORTS

Coal for the LEPCL Project is expected to be sourced from Indonesia, South Africa, and/or Australia. All

of the coal load out ports from which coal would be sourced in these countries can load up to Capesize

vessels.

In Australia, Port Kembla can load up to Panamax vessels, and Brisbane can handle Panamax and small

Capes; all the other ports in NSW and QLD can load Capesize vessels. It is not expected that coal will be

loaded for LEPCL at Port Kembla or Brisbane.

South African coal for the LEPCL Project would be out-loaded at Richard’s Bay, which can load Capesize

vessels.

Indonesian coal can be loaded in Capesize vessels by sea cranes or floating loading facilities. The

Balikpapan Coal Terminal can light-load Capesize vessels and top them up with sea cranes. KPC can load



Capesize vessels. The International Bulk Terminal (IBT, Adaro) can only load up to Panamax size, but

Adaro can load Capesize vessels at Taboneo by sea crane.

4.3.4.3 VOYAGE DISTANCE AND FREQUENCY OF TRANSPORTATION

Assuming that the 600 MW plant will consume 2.5 MT/annum, if Capesize vessels are used exclusively,

then there will be three vessel arrivals per month. If Panamax vessels are used exclusively, there will be

eight vessel arrivals per month. A bulk carrier traveling at 14 knots will take 19 days to travel from

Newcastle, NSW, to Karachi; from Richards Bay, South Africa, it will take 11 days and from Balikpapan,

Indonesia, it will take approximately 12 days.

4.3.4.4 INDIGENOUS COAL

It is not possible to determine at this time whether indigenous coal in Pakistan can be used to provide

fuel to the LEPCL Project. LEPCL is willing to consider the purchase of indigenous coal if the delivered

quality and price are acceptable. The indigenous coal would either replace contracted coal, which could

be reduced to minimum tonnage, or replace other spot coal.

The use of indigenous coal in the LEPCL project will continue to be evaluated.

4.4 COAL SHIPPING AND RECEIVAL

4.4.1 TRANSPORTATION TECHNOLOGIES

The alternative modes of coal transportation include railroad, barge, truck, and conveyor for domestic

movement, and shipping for overseas destinations. The transport mode used depends upon the

amount to be moved, haul distance, capital and operating costs for the transport system, plus flexibility,

reliability, and responsiveness to changes in end-user demand. An additional factor affecting the

selection of a coal transportation mode is the resulting environmental impact, air pollution, water

pollution, solid waste, noise levels, traffic congestion, and safety aspects. The following paragraphs

discuss the different modes of transportation and factors affecting each one.

Transportation by Deep-Sea Shipping: Ocean freight prices have been subject to similar volatility and

increases as coal prices evidenced by the Baltic Ocean Freight Dry Bulk Index1 as shown below.

1 The index provides "an assessment of the price of moving the major raw materials by sea. Taking in 23 shipping routes measured on a time charter basis, the

index covers Handysize, Supramax, Panamax, and Capesize dry bulk carriers carrying a range of commodities including coal.

http://en.wikipedia.org/wiki/Handysize

http://en.wikipedia.org/wiki/Supramax

http://en.wikipedia.org/wiki/Panamax

http://en.wikipedia.org/wiki/Capesize

http://en.wikipedia.org/wiki/Dry_bulk

http://en.wikipedia.org/wiki/Coal



Figure 4.6 – Baltic Ocean Freight Dry Bulk Index

Handling Capacity of Coal Loading Ports: All of the coal load out ports from which coal would be sourced

in Indonesia and South Africa can load up to Capesize vessels. South African coal for the proposed Project

would be out-loaded at Richard’s Bay, which can load Capesize vessels. Indonesian coal can be loaded

in Capesize vessels by sea cranes or floating loading facilities. The Balikpapan Coal Terminal can light-

load Capesize vessels and top them up with sea cranes. KPC can load Capesize vessels. The International

Bulk Terminal (IBT, Adaro) can only load up to Panamax size, but Adaro can load Capesize vessels at

Taboneo by sea crane.

Transportation by Rail: The two types of train configurations used for coal transport are general freight

trains and designated unit coal trains. The general purpose freight train carries numerous types of cars,

some of which can be coal-carrying hopper cars, with switching normally occurring along the line.

General purpose freight trains typically handle from 1,500 to 6,000 net tons, with an average of about

3,000 net tons and a gross weight of 4,500 tons. Typical haul distances for coal being moved by general

purpose freight trains is 100 to 500 miles, although greater distances may be involved, with speeds of

20 to 70 miles per hour.

The specifically designated unit coal train only handles coal from a single origin to a single destination so

that it is much faster and cheaper than the general train for coal movement. Unit trains generally have

one-way haul distances of 250 to 2,000 miles and carry from 7,500 to 12,500 net tons per trip.

Transportation by Barge: Coal is normally moved in open hopper barges, which range in capacity from

1,000 to 3,000 net tons with an average of 1,500 net tons. Ten to fourteen barges are normally located

in series. A typical shipment will contain up to 30,000 net tons of coal moving in 10 barges at an average

speed of 6 miles per hour with an average one-way haul distance of 480 miles.

Terminal facilities for coal transport are involved with either the loading or unloading of barges, with

loading capacities for coal ranging from 1,000 to 4,000 tons per hour. Unloading of coal can take place



by bucket, or revolving scoop, with subsequent conveyor movement to storage silos, loading facilities,

or end-use points.

Fuel requirements for barge movement of coal can be as low as 300 to 500 Btu per net ton-mile for

downstream movement for large barges, or as high as 800 to 1,100 Btu per net ton-mile for upstream

movement or coastal movement in small barges. The potentially significant environmental impacts of

waterways movement of coal are dust losses during loading, unloading or transport, oil losses from fuel

systems of barges, and the emissions from towboat fuel combustion.

This option is being studies by the feasibility consultants.

Transportation by Conveyor Belt: Conveyor belts are normally used in mine-mouth power plants to

bring coal from the mining area to the storage or usage area. Conveyor belts can be used for coal

transport in hilly terrain where roads are relatively inaccessible, typically being used to move coal over

5-mile to 15-mile distances. Conveyors have the advantage of being relatively maintenance free but

have the disadvantage of location inflexibility, making a truck haul still necessary. Movable conveyor

belts have been developed and used in Europe, but not in the United States to date. The only adverse

environmental impacts of conveyor belts for coal transport are coal dust losses during loading,

unloading, or transport. Conveyor belts do not use water, except for belt cleaning. They can use plant

electricity and do not require petroleum as the energy source. As a result, conveyor hauls are normally

limited to about ten miles.

This option is being studied by the feasibility consultants.

Transportation by Truck: Coal can be moved by truck over regular highways in vehicles with 35 to 40

tons capacity. Coal can also be transported by large off-road trucks with capacities ranging from 100 to

200 net tons. These trucks are almost always diesel-powered with back or bottom dump.

Trucks are the most versatile of all transportation modes for coal hauling because they can operate over

the widest areas where roads are available. However, trucks do suffer from several disadvantages

relative to other transportation methods:

Highest unit energy consumption requirements

Highest net operating costs

Greatest external damage to highways

Fuel consumption requirements for highway coal hauling are typically from 2,000 to 2,800 Btu per net

ton-mile, with an average of about 2,500 Btu per net ton-mile. Fuel consumption requirements for off-

road diesel trucks are lower, between 1,500 and 2,400 Btu per net ton-mile. As a result, trucks are

normally best only for short hauls of coal.

The roads from the bulk coal terminal to the Project site are sufficiently wide to carry the 35-40 tons

trucks. Since the site is located only at about 2 km from PIBT, the transportation of similarly sized trucks

has been observing traveling to and from Port Qasim. As a result, transportation by truck is the most

suitable mode of transportation of coal from the bulk terminal to the Project site.

Coal Shipping and Receiving Summary: Coal transportation has become an important concern from an

energy, economic, and environmental standpoint. Since the coal supply will be sourced from overseas,

deep-sea shipping will be utilized to transport coal from its origin to the PIBT. Local transportation will



be utilized to transport the coal from the PIBT to the site. Among all local transportation modes, trucks

(with 35 to 40 tons capacity) will be the most versatile mode for the coal transportation from port Bin

Qasim to the Project site via paved roads (approximately 2km distance). The other options for local

transportation (e.g. conveyor, rail, barging, etc.) of the coal require an in-depth study for this Project.

Coal consumption at 100% load is 300 metric tons per hour. At 40 metric tons per truck, this would result

in 180 trucks per day. Option for coal transportation from Port Qasim is also in our consideration.

Once delivered to the site, proper care will be taken to handle coal in a manner suitable for conveying

and storing coal on site. In addition, the surface moisture of the coal will be maintained in such a way

that would limit the propensity to spontaneously combust and produce dust.

4.5 AVAILABILITY OF APPROPRIATE ENERGY SOURCE

Pakistan is currently embarking on diversifying its fuel mix for power generation. The Project is designed

to utilize imported lignite coal as well as lignite that will be produced in the Thar coal fields located in

western Sindh in the near future.

Pakistan’s coal resources are primarily located in three areas: Sindh Province, Balochistan, and Punjab,

each of which contains several major deposits. Figure 4.7 presents a location map of Pakistan coal

resources illustrating the three areas and the major deposits, each of which is briefly described below.

4.5.1 SINDH PROVINCE

The Sindh Province has total coal resources currently estimated to be approximately 184.623 billion

tonnes (Bt). The quality of coal is mostly lignite-B to subbituminous A-C. Three of the major Sindh

deposits are the Thar deposit, the Lakhra coalfield, and the Sonda-Jherruck coalfield.

4.5.1.1 THAR

Thar is a large coalfield in the eastern part of the Province about 400 km southeast of Karachi, having a

resource potential of about 175 Bt. The coalfield extends over 9,000 sq. km, out of which 356 sq. km

area has been studied in detail by the Geological Survey of Pakistan proving 9 Bt of coal in four blocks.

The main coal bed thickness ranges from 12 to 21 meters at an average depth of 170 meters, the upper

50 meters being loose sand. The quality of coal has been determined on the basis of chemical analyses

of more than 2,000 samples. The rank of the coal ranges from lignite-B to subbituminous-A. Coalfield

highlights are as follows:

Thar Desert Area - (approx.) 22,000 sq. km.

Coalfield Area 9,100 sq. km.

Total Drill Holes 217

Coal Deposit 175,506 Mt

Coal Reserves (Bt) 9,000 Mt

Coal Quality Lignite A-B:

o Moisture (AR) 46.77%

o Ash (AR) 6.24%



o Volatile Matter (AR) 23.42%

o Fixed Carbon (AR) 16.66%

o Sulphur (AR) 1.16%

o Heating Value (Av.) 5,774 Btu/lb

Figure 4.7 - Major Coal Fields of Pakistan

4.5.1.2 LAKHRA

The Lakhra Coalfield in Dadu District lies 16 km to the west of Khanot Railway Station on the Kotri-Dadu

section of the Pakistan Railways. It covers an area of approximately 200 sq. km. It is well connected with

Karachi and Hyderabad through roads and railways. Mining in the area is currently done by underground

methods.

Three coal seams are established in the field, but generally only the middle seam known as the Lailian

Bed possesses the necessary persistence and thickness for consideration in large-scale mining. It shows

a variation in thickness from 0.75 meter to 2.5 meters, with average thickness of 1.5 meters.

Coal from Lakhra has an apparent rank of lignite-A to subbituminous C. The coal is dull black and contains

amber resin flakes and about 30% moisture. Although it can be extracted in large lumps, it dries to a



moisture content of about 8% when brought to surface, and tends to crumble on longer exposure to

atmosphere. It is often susceptible to spontaneous combustion.

The total reserves of the deposit have been estimated to be 1,328 million tonnes (Mt) with 244 Mt

measured, 629 Mt indicated, and 455 tonnes inferred. Current average annual production of coal from

Lakhra is over 1 Mt. Most of this production is used in the WAPDA Power Plant at Khanote, Sindh, and

in the brick kiln industry. Coalfield highlights are as follows:

Distance from Karachi 193 km

Area 1309 sq. km

Coal Reserves 1,328 Mt

Chemical Analysis of Coal:

o Moisture (AR) 28.9%

o Ash (AR) 18.0%

o Volatile Matter (AR) 27.9%

o Fixed Carbon (AR) 25.2%

o Sulfur (AR) 4.7% to 7.0%

o Heating Value (Av.) 4,622-7,554 Btu/lb

4.5.1.3 SONDA-JHERRUCK

Over 1 Bt reserves of lignite quality coal have been assessed in the Sonda-Jherruck Coalfield. Owing to

favorable location and developed infrastructure, interest has been expressed by a Chinese consortium

to determine the feasibility of commissioning power generation units at the site.

In case the feasibility study justifies commissioning of a project, a quantity of 2 Mt of coal annually would

be mined to cater to the requirements of the power generation units. Highlights of the Thatta-Sonda-

Jherruck coalfield are as follows:

Distance from Karachi 150 km (approx.)

Identified Area 1206 sq. km

Shallowest Coal Bed 37.8 m

Deepest Coal Bed 265.28 m

Coal Reserves (Billion Tonnes) 7.112

Chemical Analysis

o Moisture (AR) 31.23-34.72%

o Volatile Matter 27.9%

o Fixed Carbon 25.2%

o Ash (AR) 7.69-14.7%

o Sulfur (AR) 1.38-2.82%



o Heating Value (AR) Btu/lb 6,780 - 11,029

4.5.2 BALOCHISTAN

The coal seams in Balochistan are found in the Ghazig Formation of Eocene age. The quality of the coal

is subbituminous A to high volatile B bituminous. The coalfields mostly lie around Quetta in Balochistan;

however, the Sor-Range Degari Coalfield and the Chamalang are significant.

4.5.2.1 SOR-RANGE, DEGARI, SINJIDI

The Sor-Range Degari Coalfield lies 13 to 25 km southeast of Quetta covering an area of about 50 sq. km

and is easily accessible through metalled road from Quetta.

The northern half of the field is known as Sor Range, Degari and is situated at the southern end of the

field. The thickness of the coal seam varies from 1.0 meter to 2.0 meters, but in the Sor-Range Seam,

sections up to 5.0 meters have been encountered. The coal is of better quality with low ash and sulfur

content. The quality of the coal is high subbituminous A to high volatile B bituminous.

4.5.3 PUNJAB

The Punjab's coalfields comprise the eastern, central and western Salt Range between Khushab, Dandot

and Khewra while the Makerwal Coalfield lies in Trans-Indus Range (Sanghar Range). The rank of the

coal is subbituminous A to high volatile bituminous. The highlights of the Indus East Coalfield are as

follows:

Thickest coal bed 2.40 meters

Fixed Carbon (AR) 23.9%

Volatile Matter (AR) 27.7%

Sulphur (AR) 2.6%

Moisture (AR) 33.1%

Calorific Value (AR) 6,300 to 8,000 Btu/lb

Ash (AR) 15.2%

4.5.3.1 SALT RANGE

The Salt Range Coalfield covers an area of about 260 sq. km between Khushab, Dandot and Khewra. The

entire coal producing area is well connected with roads and railways.

The top seam varies in thickness from 0.22 meter to 0.30 meter while the middle seam is up to 0.60

meter thick. The lower seam is up to 1 meter thick and is relatively of better quality. Salt Range coal is

being mined in Dandot, Choa-Saiden Shah and adjoining areas. The Punjab Mineral Development

Corporation and several private companies are operating the mines in the area. Reserve of the deposit

is estimated at about 235 Mt.

4.5.3.2 MAKERWAL/GULLAKHEL

Makerwal/Gullakhel Coalfield is situated in Sarghar Range (Trans-Indus Range). The coalfield extends

from about 3.2 km west of Makerwal to about 13 km west of Kalabagh, covering an area of about 75 sq.



km in the Mianwali district. The quality of Makerwal/Gullakhel coal is better than that of Salt Range coal

and is preferred by the consumers. Total reserves of the deposit are estimated to be about 22 Mt.

4.5.4 COAL RESOURCES SUMMARY

Pakistan’s coal resources are summarized in the following table.

Table 4.9 - Coal Resources (million tonnes)

Province/Coalfield Measured Indicated Inferred Hypothetical Total

Sindh

Lakhra 244 629 455 - 1328

Sonda- Thatta 60 511 2197 932 3700

Jherruck 106 310 907 - 1323

Others 82 303 1881 - 2266

Thar 3407 10323 81725 80051 175506

Sub- Total 3898 12076 87165 80983 184123

Balochistan

Kohst-Sharig-Harnai 13 - 63 - 76

Sor-Range/Degari 15 - 19 16 50

Duki 14 11 25 - 50

Mach-Abegum 9 - 14 - 23

Pir Ismail Ziarat 2 2 8 - 12

Chamalong 1 - 5 - 6

Sub-Total 54 13 134 16 217

Punjab

Eastern Salt Range 21 16 2 145 235

Central Salt Range 29 - -

Makerwal 5 8 9

Sub-Total 55 24 11 145 235

Grand Total 4,008 12,113 87,189 81,144 184,575

4.5.5 COAL PRODUCTION

The total national coal production from operational coal mines is approximately 4044 thousand short

tonnes. Approximately 80% of the cement industry has also switched over to indigenous coal from

furnace oil, thereby saving considerable foreign exchange that was otherwise being spent on the import

of furnace oil. The conversion of cement industry from furnace oil to coal has generated a demand for

2.5 to 3.0 Mtpy of coal.

Indigenous coal is blended with imported coal in small proportion, which is necessary for smooth

operation of the cement plant.

4.5.6 COAL MINING AND TRANSPORTATION

4.5.6.1 COAL MINING

Generally, coal mining in Pakistan is not mechanized. While a general area can produce many thousand

tons of coal, this is an aggregate amount of production from several coal lease operators in one

particular area.



Trucking charges vary with the season and destination. In some cases, there is no cargo available for the

return journey, thus increasing coal freight charges.

The nearest coalfield to Karachi and LEPCL is Meting Jhimpir near Thatta. This is an operative coalfield

with two major companies producing small amounts of coal. Other nearest coalfields are Sonda

Jherruck.

At LPGCL's Lakhra Power Station, which uses FBC technology, current coal consumption is

approximately 800 Mt per day for 35 MW, or about 2.3 Mtpy. A parallel mining development could be

planned to supply coal to others including LEPCL. The reported reserves at this location appear sufficient

for several years of service to LEPCL and others.

In the neighbouring district Badin, near the town of Golarchi, a virgin coalfield exists which is leased by

companies signing MOUs for establishing power plants. This is known as the Badin Coalfield.

4.5.6.2 TRANSPORTATION

At the present time, the available transportation mode for coal at power plants is the dumping of trucks

that have been loaded by front-end loaders. This is the only method currently available for the quick

unloading at the coal yards.

Trucks currently plying between the Lakhra Coalfield and the LPGCL Power Plant have a carrying capacity

of 12 to 24 tonnes. However, coal dispatched to brick kilns, mostly to Punjab, is taken by long-chassis

trucks. Three-axle, ten-wheeler load coal for Multan, Bhai Pheru, 45 km south of Lahore.

4.5.7 PAKISTAN COAL FOR LEPCL

LEPCL will accept and use Pakistan indigenous coal, provided that the Pakistan coal can be delivered to

the LEPCL project coal receiving facilities by truck or barge, at a quality and price, and with handling

characteristics, comparable to the quality, price, and handleability of imported coals.

It is notable that some Pakistan coals do clearly appear to be of quality that can be used by LEPCL and,

further, that appropriate transportation infrastructure and trucking industry exist to move coal from

mining areas to the vicinity of LEPCL. It remains to develop mining and transportation practices to deliver

the coal to LEPCL within an economic framework that is acceptable to both LEPCL and Pakistan mining

and transporting companies.



5.0 ENVIRONMENTAL & SOCIAL BASELINE

This Section of the EIA report aims to describe the existing (baseline) social and environmental

conditions at and around the proposed LECPP site and contains the following sections:

Physical Environment;

Physical Oceanography;

Meteorology and Climate;

Air Quality;

Terrestrial Ecology and Birds;

Marine Ecology;

Noise;

Waste Management and Disposal; and

Socio Economic Context

5.1 METHODOLOGY OF BASELINE SURVEY

Environmental Baseline Survey was performed in accordance with the American Society for Testing and

Materials (ASTM) Standard D6008-96, Standard Practice for Conducting Environmental Baseline

Surveys. The baseline data collected will be used in conjunction with the assessment methodologies

described in Section 6 to identify the presence of sensitive receptors; assist with determining the

significance of the potential environmental and social impacts associated with the Project; determine

where specific further mitigation, control and management techniques are required; and identify where

compensatory measures (e.g. habitat reinstatement) are required. The information required for the

baseline section has been obtained from a number of sources, the main ones being: i) Consultation and

data gathering exercises; ii) Desk-top surveys and literature reviews; iii) Existing information sources and

data purchase; iv) Field surveys; and v) Data from the Project Proponent.

Consultation and data gathering exercises have involved a number of sources, including personnel from:

the KMC, PQA, NIO, Government departments, educational institutions, various NGOs and local interest

groups. These are discussed in more detail in the relevant Sections below. As a result of previous

involvement with EIA and related projects at PQA; EMC already hold some of the data required to

characterize the baseline environment. Desk-top surveys and literature reviews have included internet

and library searches, as well as reference to previous EIA reports that have been produced for projects

in PQA. Field surveys have been carried out to supplement the above data sources and for

environmental/social conditions that require site specific information. The following surveys have been

undertaken as part of the EIA process: i) Air quality; ii) Noise; iii) Soil and groundwater; iv) Seawater and

sediment quality; v) Marine biology and ecology; vi) Terrestrial ecology; and vii) Bird survey.

5.2 DESCRIPTION OF MICRO AND MACRO ENVIRONMENT

The microenvironment of the proposed project is the 250 acres of land in Deh Ghangiaro, Bin Qasim

Town Karachi. Geographical area of the macro-environment extends from the Korangi Creek on the

west and along UC Ibrahim Haidery, Rehri, Chashma Goth, Korangi Fish Harbor, the deep sea fish harbor



and salt works along the coast, Lath Basti in the immediate east Juma Goth and Bhains Colony in the

north; the PIBT, Progas jetty, FOTCO Jetty, IOCB, EVTL, and Port Qasim Industrial Area in the east; the

Steel Mills in the far east, and the large mudflat covered by mangroves forest in addition to the

navigation channel of Port Qasim (PQ) in the south.

PQ is located 50 km from Karachi on the coastline of the Arabian Sea. The approach to Port Qasim is

along a 45 km long navigational channel from the Arabian Sea which provides safe and convenient

navigation for vessels. It is country’s second busiest port handling approximately 40% of the national

cargo which was 25 million tons in the year 2009. The port encompasses a total area of 12000 acres

where around 80% of Pakistan’s automotive industry is located. The port also provides direct water front

access to two major nearby industrial areas; export processing zone Landhi and Korangi Industrial area.

The near shore macro-environment of the proposed project comprises a number of creeks, islands,

wetlands, marshes and mangrove forests and forms the westward extension of the Indus Delta. Phitti

creek is the largest amongst the group of creeks developed on the western parts of the Indus delta

formerly the delta of the Indus River. Phitti Creek is connected to a system of creeks including Jhari,

Kadiro, Korangi and Gharo Creeks.

Some smaller creeks branch of these major creeks forming a big network of the Indus delta. This

network of creeks is a very sensitive ecological area of the delta and has all the characteristics of the

deltaic behaviour. A chain of small Islands such as Bundal, Buddo, and Khiprianwala are off shoots of

Indus Delta formation system and are either sand banks or swamps partially submerged at high tide.

Extensive vegetation of mangrove also exists. The islands are mostly flat and swampy. The Malir River

drains into the Gizri Creek. Figure 5.1 shows interconnection of creeks.

Figure 5.1 – Interconnection of Creeks

Project Site



5.3 PHYSICAL ENVIRONMENT

5.3.1 TOPOGRAPHY

The project’s macroenvironment has three distinct/dominant topographic regimes; ridges, plains, and

the coastal belt. The area north of project site mainly comprise of rugged topography. This area consists

of ridges and runnel upland. The vast tract of land lying between the Malir and Lyari rivers forms the

interflous of the drainage systems of the two rivers. This area has very little drainage scars, which

indicate it having a rocky base of alternating layers of consolidated sandstone, intervened by silt and clay

beds. The southern part of the Malir District follows the coastal strip of the Gharo and Korangi creeks,

demarcating the northern boundary of the old Indus Delta. The areas, to the south of the east-west

baseline of the triangular outline of the Karachi Division subsided and were covered by the sea making

a shallow basin. In the course of time the deltaic deposits of the Indus River filled this shallow basin and

the northern part of the basin, which coincided with fault line making the coastal edge. The terrain rises

gradually northward from the Arabian Sea, culminating in low, flat-topped, parallel hills. Sub-parallel

ridges interrupted by wide intervening plains, categorized as marine denudation plains, sand dunes, and

marine terraces, are prominent features of this area.

5.3.2 GEOLOGY, GEOMORPHOLOGY & SOIL

The geological formations belong to the middle and upper Tertiary Periods. The soil formations found in

the area are fresh and slightly weathered, recent and sub recent shoreline deposits. These deposits are

derived from Gaj/Manchar formations of Lower Miocene to Middle Miocene/Upper Miocene to

Pliocene age. Similar deposits are found all along the coastal belt of Karachi and adjoining areas.

Geological investigations for the project’s macroenvironment also suggest the presence of only middle

and upper tertiary rock formations comprising fresh, and slightly weathered recent and sub-recent

shoreline deposits. Principal constituents of the deposits are the inter-bedded sandstone and shale

together with subordinate amounts of large sized gravels or conglomerate.

The Kadiro Creek area is covered with mudflats supporting mangrove vegetation and does not exhibit

much geological and pedagogical diversity. The mud flats are recent deposits of delta are while soil cover

is the drift type that has been slightly withered with time and marine activity, it seems to have been

transferred with the flood flow from Malir rivers from the west and Indus from the east. The

information, as per geologic survey of Pakistan, reveals that in the project area and in its adjoining areas

only the middle and upper tertiary formations are present. The formation found in the area is fresh and

slightly weathered, recent and sub recent shore line deposits. The seabed is predominantly sand and silt

while the sediment of the delta is fine grained and resembles the soil from the continental shelf at the

mouth of the Indus delta. The gravels or conglomerates are poorly transfixed with medium to coarse

brown sand and are derived from Manchar formations of Pleistocene age. The Gaj formation consists

of mostly limestone with sub ordinate shales and sand stones. The limestone is hard, sandy and

extremely and fossiliferous, this formation over lies Nari formation which consists of harder lime stones

beds and shales, conformably overlying Gaj formation is Manchar formation. Similar Manchar formation

exists all along the coastal areas of Karachi and thus exposed in Clifton, Ibrahim Haidery, ghazi, orange

and land areas. This formation is composed of sand stone, clay bed, cemented sand and gravel (pseudo

conglomerate). Sand stone is thick, porous and friable and also contains bands of conglomerate. The

clay has various colours including grey, brown chocolate and orange, however the most widely occurring



clay are of light brown and dark grey in colour. Sandy layers are also found inter bedded with clay and

gravel. The geology of the study area comprises of tidal channel creek deposits in the Kadiro and other

adjacent creeks in the study area.

Tidal Channel Creek: These Deposits constitute dark grey to black silt and clay with organic material.

Tidal Mud Flats: Comprises of mud and sand dominantly composed of fine grained clay and quartz

Mangrove Swamp deposits: These deposits are covered by natural mangrove forests.

The geological map of project area is shown in figure 5.2.

The geomorphology of the study area is dominated by tidal flats, channels and creeks. Tidal flats slope

very gently towards the sea from the high tide level down to a little below the low tide level. Tidal flats

and at the edge of the sea or in major tidal channels the floor of which lie below the lowest tide levels.

Like major tidal channels, tidal creeks flow across tidal flats; these are shallower than tidal channels and

run down to low tide level. On muddy tidal flats, tidal creeks (i.e. Kadiro) often display a dendritic pattern

with widening courses and point bars. Tidal flats are built up from clay size and fine silt size sediments

carried to the course by river. Clay particles meeting salt water flocculate and settle down as a result

provide substrate for colonization of salt tolerant plants i.e. mangroves.

Configuration of the coast line of Phitti Creek and its environs are erratic due to the deltaic formation

where sea boundary cannot be defined. Sand formation is brown in colour and the grain size ranges

from fine to medium. Normally sand thrown by sea waves on the coast are carried inwards, work-up

into dunes by wind action. Beach and sea bottom material in the vicinity of Phitti mouth is

predominantly composed of Micaceous, very well sorted fine sand. Acoustic images suggest fine to

medium grained homogenous seafloor material, most probably clay / silt and fine sand etc.

5.3.2.1 SUB-RECENT AND RECENT DEPOSITS

Alluvial Deposits: Alluvial deposits are present mainly in flood basin and streams; they consist of poorly

sorted, unconsolidated/loose gravels, sand and silt.

Stream bed Deposits: These deposits consist of material brought down by streams and laid down in their

channels comprising loose fine to coarse sand, gravels, pebbles and boulders.

Piedmont and Sub-piedmont Deposits: The sub-recent deposits in the area have been mapped as un-

differentiated piedmont and sub-piedmont deposits consisting of loosely packed boulders, cobbles,

pebbles and coarse to fine stand. The soil in the study area constitutes a part of the Indus plains, which

have been built by the Indus as a large delta at its mouth. These are extensive mud flats sliced by the

tidal channels. This soil mainly constitutes silty clay, clay, sandy silt, dense gravelly sand, hard clay and

shale. The study of the bore hole data identifies from top to bottom following sediments types in the

project area.

Brown, loose, to medium dense fine to coarse, sand, some silt and gravel.

Grey, very soft to soft, Silty Clay and organic matter

Grey, loose to medium dense Sandy Silt.

Grey, soft to hard Silty Clay

Brown, compact, gravelly, medium to coarse Sand.

Greyish brown, hard, Silty Clay/Shale.



Figure 5.2 – Coastal Geology



5.3.3 SEISMIC CONDITIONS

The Geological Survey of Pakistan has defined the area of Port Qasim, where the site under study is

located, to fall in a Seismic Zone 2B region. This suggests the possibility of moderate to major seismic

hazard i.e. probability of earthquakes of intensity VI to VIII MM scale and 5.6 to 6.6 on Richter scale.

From the charts published, the peak ground level acceleration (PGA) for this zone is 28%. The seismic

risk factor of 0.3 is advisable and will need to be incorporated in the design for constructions and

installations in the coastal zone, for operational basis earthquakes (OBE) pertaining to damage due to

moderate level earthquakes (MM-VI to VIII).

The seismicity in the Karachi and at Project site is considered to be low. According to the published data

the Project area lies in zone of low seismic activity, with acceleration ranging from 1.6 to 2.8 m/sec2. A

factor of 2.8 m/sec2 will, on the other hand, have to be taken for a maximum credible earthquake (MCE).

The design of the proposed CPP structures must take these values into consideration.

Figure 5.3 - Seismic Zones of Pakistan

5.3.4 TSUNAMIS

Major damages done by Tsunamis, the impulsively generated seawater waves that are a result of

underwater earthquakes, have not been recorded for the coastal area south of Karachi. There are,

however, evidences of a 1.2 m tsunami generated by an offshore earthquake of intensity 8 M in 1945,

which caused only minor damages in Port Qasim and surrounding areas. This event was followed by

another Tidal wave that was recorded in 1953. The Tsunami of December 26, 2004 had no impact on

the macroenvironment of the project area.



At Karachi, the tsunami arrived from the direction of Clifton and Gizri. It ran along the oil installations at

Keamari and flooded a few compounds. The waves were 6.5 feet or 2.0 meter high when they reached

Karachi. There was a delay of more than one hour between the main shock and arrival of the damaging

tsunami at Karachi.

The sea is 3.36 meter (11ft) below the road level at FOTCO and 2.7 meters (8.8 ft) below the average

ground level at Native Jetty in the Manora Channel. This would suggest that a tsunami of magnitude

similar to the 1945 Tsunami would affect the 2.5 meter contour on the beach front at Clifton but not the

5 to 9 meter contour from Korangi Creek to Ghaggar nala. A tsunami wave of magnitude higher than 5

meter would nevertheless be a matter of concern to the reclaimed areas along the sea front in the DHA,

Korangi- Ibrahim Hyderi-Rehri- Lath Busti and Port Qasim area. Such events are less likely to occur in the

north of the Arabian Sea.

5.3.5 HYDROLOGY

There is no inland surface water body in project area except the mudflat lying between the 9 meter

contour and the coastline of Arabian Sea. There are quite a few springs including the Chashma at

Chashma goth and some along the coastal road that runs along the base of the 5-9 meter contour that

is conspicuous in the region.

The ground water table lies at 1.6 to 2.3 meters depth. The ground water quality is very saline having

total dissolved solids about 20,000mg/l. The chloride content ranges from 7500 to 9550 mg/l and the

concentration of sulfate ranges between 1188 and 1242 mg/liter. It is therefore, very poor quality

ground water and unsafe for any use.

The coastal belt has been used to dispose off sewage from adjacent coastal areas and industries located

in Korangi Industrial Area, Landhi Industrial Trading Estate and Bin Qasim Industrial Area. There are

several open drains carrying untreated raw sewage discharge in to the Korangi and Gharo Creek.

The constant inflow of untreated effluent into the coastal waters has led to marine pollution which, by

various accounts, has reduced the quality of water and led to loss of habitat for flora and fauna, reduced

species diversity, smothering by high suspended solids and oils, accumulation of toxins in marine

organisms especially in the larval stages of commercial species, tar balls on beaches, and reduction in

amenities, and the eventual loss of marine living resources in the polluted areas.

The 3,500 km2 area covered by the creeks off the coast of Karachi were once a spawning ground for a

large number of commercial species of marine organisms. Pollution from the land has reduced the

fishing potential of Gharo, Gizri and Korangi Creeks. Consequently, due to excessive pollution in the

creeks there has also been a significant decrease in fish catch. The creeks adjacent to the mudflats are

recipient of at least 25% of the total pollution load of Karachi through Malir River and about 15% that is

directly discharged into the adjacent open sea coast or to the Gizri, Korangi and Gharo creeks.

Physico-chemical characteristics of water from different sources including seawater, groundwater,

industrial wastewater, spring overflow in the macroenvironment of project area are summarized in

Table 5.3 – 5.42.

2

Mirza Arshad Ali Beg, Yasmin Nergis, and Mughal Shareef, HEC Project 1196, 2008-2010



Table 5.3 - Summary of Water Analysis (Korangi- Ibrahim Hyderi- Rehri - Port Qasim Section)

S.# Parameters/Analytes

Descriptions Results

Unit 1 2 3 4 5 6

1. Collection Time Hr: mn 0550 0600 0649 0700 0910 0920

2. Temperature °C 25.9 27.1 23.5 26.2 29.0 26.5

3. pH Value SU 7.68 8.38 7.47 8.32 7.11 7.24

4. Color App. Susp Susp Muddy Susp Susp Clear

5. Total Dissolve Solids (TDS) mg/L 30010 42900 40000 43280 1932 1549

6. Conductivity µs/cm 61200 68400 60000 67700 4040 3110

7. Dissolve Oxygen (DO) mg/L 4.04 2.01 3.39 4.02 5.13 5.69

8. Chloride (Cl-1) mg/L 14400 2281 21701 23230 770 630

9. Bicarbonate (HCO3) mg/L 2401 22470 2108 2230 330 260

10. Sulfate (SO4) mg/L 1901 970 940 1020 210 120

11. Nitrate (NO3) mg/L 31.8 18.8 13.2 9.8 8.7 4.8

12. Carbonate (CO3) mg/L BDL BDL BDL BDL BDL BDL

13. Calcium (Ca) mg/L 830 1203 1170 1302 225 135

14. Magnesium (Mg) mg/L 520 876 850 990 170 105

15. Sodium (Na) mg/L 9900 14421 13190 14330 487 220

16. Potassium (K) mg/L 231 259 312 270 113 27

17. 5-Days BOD mg/L BDL 237 468 BDL BDL 218

18. Chemical Oxygen Demand (COD) mg/L BDL 304 559 BDL BDL 426

19. Mercury (Hg) mg/L BDL BDL BDL BDL BDL BDL

20. Lead (Pb) mg/L BDL 1.398 BDL BDL BDL BDL

21. Cadmium (Cd) mg/L BDL 0.876 BDL BDL BDL BDL

22. Arsenic (As) mg/L BDL BDL BDL BDL 0.0418 BDL

23. Nickel (Ni) mg/L BDL 1.174 BDL BDL 0.0621 0.2617

24. Zinc (Zn) mg/L BDL 8.984 3.289 BDL 0.5118 1.9146

25. Total Plate Count @37°C Cfu 110 TNTC TNTC TNTC TNTC TNTC

26. Total Coliforms @42°C Cfu 70 TNTC TNTC TNTC TNTC TNTC

27. Escherichia Coli @37°C cfu + ve + ve + ve + ve + ve + ve

28. Sodium Absorption Ratio (SAR) : 66.09 76.84 71.31 72.53 5.94 3.44

1 -Sea Water (Pakistan Steel Mill-Channel). 2-Pakistan Steel Mill Sewage Effluent. 3-Sea Water Creek Ziarat Hasan Shah. 4-Sea Water/Stagnant way to Ziarat Hasan Shah. 5- Spring Water Baba Juman Shah. 6-Spring Water Drain to Dhabji.

Sea water samples collected from Steel Mills intake and outfall channels, and from Ziarat Hasan Shah

had lower SAR ~66 76 but TDS varying from 30,000 to 43,280 at 26 and 27oC, pH 7.44 and 8.4, and DO

~4.0 showing dilution with wastewater discharges and concentration due to evaporation on the outside

of the creek. Seawater at the Ziarat Hasan Shah beach Had SAR 71.3, TDS 40,000, DO 3.39 and pH 7.47

at 23.5oC. The samples from spring and the nala receiving the overflow from the spring show

characteristics of groundwater having higher proportions of sodium and chloride ions.




Unit 1 2 3 4 5 6

1. Collection Time Hr: mn 1240 0104 0110 0150 0230 0240

2. Temperature °C 26.5 26.6 26.6 28.6 29 28.9

3. pH Value SU 7.44 8.45 8.17 7.58 7.28 7.06

4. Color App. susp clear clear susp clear clear






Unit 1 2 3 4 5 6

5. Total Dissolve Solids (TDS) mg/L 38700 228 232 38700 2410 1418

6. Conductivity µs/cm 61500 496 496 64000 4990 2990

7. Dissolve Oxygen (DO) mg/L 4.02 5.08 5.10 3.97 4.07 4.96

8. Chloride (Cl-1) mg/L 20810 58 59 20808 970 528

9. Bicarbonate (HCO3) mg/L 1940 70 72 1920 415 270

10. Sulfate (SO4) mg/L 920 34 34 930 212 92

11. Nitrate (NO3) mg/L 17.6 3.28 1.19 4.26 3.28 7.8

12. Carbonate (CO3) mg/L BDL BDL BDL BDL BDL BDL

13. Calcium (Ca) mg/L 1210 19 20 1220 312 120

14. Magnesium (Mg) mg/L 965 11 12.0 970 230 115

15. Sodium (Na) mg/L 12790 34 34 12770 330 195

16. Potassium (K) mg/L 191 2.9 2.9 189 29.0 43.0

17. 5-Days BOD mg/L 37 BDL BDL BDL BDL BDL

18. Chemical Oxygen Demand (COD) mg/L 57 BDL BDL BDL BDL BDL

19. Mercury (Hg) mg/L BDL BDL BDL BDL BDL BDL

20. Lead (Pb) mg/L BDL BDL BDL BDL BDL BDL

21. Cadmium (Cd) mg/L BDL BDL BDL BDL BDL BDL

22. Arsenic (As) mg/L BDL BDL BDL BDL BDL BDL

23. Nickel (Ni) mg/L BDL BDL BDL BDL BDL BDL

24. Zinc (Zn) mg/L BDL BDL BDL BDL BDL 0.0268

25. Total Plate Count @37°C Cfu TNTC 210 140 TNTC TNTC TNTC

26. Total Coliforms @42°C Cfu TNTC - ve TNTC TNTC TNTC TNTC

27. Escherichia Coli @37°C cfu + ve + ve + ve + ve + ve + ve

28. Sodium Absorption Ratio (SAR) : 66.25 1.53 1.48 65.93 3.44 3.04

1-Sea water Lath Basti. 2-KDA Water Lath Basti #1. 3-KDA Line Water Lath Basti. 4-Sea Water Lath Basti. 5-Boring Water Cattle Farm. 6-Boring Water Cattle Farm 200ft.

Sea water samples collected from Lath Basti had lower SAR~65 but TDS ~38700 at 26 and 28oC, pH 7.44

and 7.58, and DO~4.0 showing dilution with wastewater discharges from the surrounding. The samples

from boreholes show characteristics of groundwater having higher proportions of sodium and chloride

ions. The water supply samples with SAR above 1.2 show characteristics of fresh water contamination

with groundwater.

Wastewater samples collected from Korangi Industrial Area which is the outfall region of Malir River,

had SAR values ranging from 2.79 to 5.56; TDS ranging from 1228 to 4310; low DO 0.39 to 0.62 and the

high BOD and COD values in the samples; they are characterized as industrial wastewater mixed with

sewage. The sewage is in higher proportion upstream while industrial effluent is dominant as the river

enters its delta area. Seawater intrusion was noted at Malir River/Korangi Industrial Area during high

tide. It was noted that the sample collected from here had SAR 57.68, TDS 22300, DO 0.82 and quite

high BOD and COD, and is characterized as seawater contaminated with sewage and industrial effluent.

The quality of water samples collected from the Kadiro Creek in front of the proposed site during the

current EIA study is presented in Table 5.5. Here again it is noted that the Seawater TDS in both samples

is at least 10,000 mg/L lower than what is normal for open seas and much lower than that observed at

the creeks. The BOD5 is much lower than COD values suggesting that the seawater has been



contaminated by chemical oxidants or industrial effluents and that the channel is least exposed to

sewage or biological contaminants.

Table 5.5: Water Quality in the Project Area

S. # Parameters Sea Water Sample # 1 Sea Water Sample # 2

1 Temperature 28.7 28.9

2 pH 7.39 7.24

3 Biological Oxygen Demand (BOD5) (mg/L) 17 21

4 Chemical Oxygen Demand (COD) (mg/L) 1079 1088

5 Total Suspended Solids (TSS) (mg/L) 48 45

6 Total Dissolved Solids (TDS) (mg/L) 26300 25100

7 Oil & Grease (mg/L) < 1 < 1

8 Phenolic Compounds (as Phenols) (mg/L) ND ND

9 Chloride (mg/L) 22000 22400

10 Fluoride (mg/L) 1.8 2.6

11 Cyanide (mg/L) ND ND

12 Anionic detergents (as MBAS) (mg/L) 0.049 0.052

13 Sulphate (mg/L) 4500 4250

14 Sulphide (mg/L) ND ND

15 Ammonia (mg/L) 0.15 0.15

16 Salinity (mg/L) 27100 27200

17 Cadmium (mg/L) ND ND

18 Chromium (mg/L) 0.0481 0.0311

19 Copper 0.1541 0.1012

20 Lead 0.2361 ND

21 Mercury ND ND

22 Selenium 0.1031 0.0393

23 Nickel 0.0397 0.0349

24 Silver 0.0129 0.0056

25 Zinc 0.1582 0.7011

26 Arsenic 0.0971 0.0711

27 Barium 0.3188 0.1622

28 Iron 15.9456 8.1295

29 Manganese 0.4091 0.1352

30 Boron 3.4020 3.2311

31 Chlorine 0.04 0.05

5.3.6 WAVES

The waves and their height at Karachi Coast vary with the season. During NE winter monsoon the wind

speed is around 10 knots and the coastal waters are almost calm and the wave height is less than 1

meter. During SW summer monsoon the winds pick up speed of about 25 knots; the wave height on the

Karachi Coast is then in the range of 3 to 4 meters. In the interim months i.e. inter-monsoon period the

wave height is about 1.5 to 2.5 meters.

Pakistan coastline lies to the north of the Arabian Sea; it is exposed to waves from the south, southwest

and west. During the summer monsoons, the wind and waves originate from the southwest, while

during the winter months the wind direction varies from directionless to 1.5-2.5 m/s. During winter both

swell waves and local wind generated waves are observed at the coast.



For the swell waves, voluntary observations of weather data by ships of passage are considered to give

realistic offshore wave data. For the locally generated waves, wind data from nearby coastal stations are

considered sufficiently accurate.

Deep sea wave data, for the SW monsoon months (May to September) applicable to Pakistan coast is

given in Table 5.6.

Table 5.6: Deep Sea Wave Frequency Distribution Statistics

Resultant Wave Height (m)

Wave Period (Seconds) for Higher of Sea/Swell Height

0-3 4-5 6-7 8-9 10-11 12-13 14-15 16-17 18 Total

0 to 0.5 2.6% 4.1% 0.4% 0.1% 0.0% 0.0% 0.0% 0.0% 0.0% 7.4%

0.6 to 1.0 1.1% 5.3% 1.8% 0.4% 0.1% 0.0% 0.0% 0.0% 8.9%

1.1 to 1.5 1.2% 6.7% 6.3% 2.2% 0.6% 0.1% 0.1% 0.0% 0.0% 17.3%

1.6 to 2.0 0.1% 3.8% 4.9% 2.9% 0.9% 0.2% 0.1% 0.0% 0.0% 12.8%

2.1 to 2.5 0.0% 2.8% 5% 3.6% 1.4% 0.4% 0.1% 0.0% 13.2%

2.6 to 3.0 1.3% 3.4% 3.2% 1.5% 0.5% 0.1% 0.0% 0.0% 10.0%

3.1 to 4.0 1.1% 4.9% 6.1% 2.9% 1.0% 0.3% 0.1% 0.0% 16.4%

4.1 to 5.0 0.2% 1.8% 3.3% 1.9% 0.8% 0.2% 0.0% 0.0% 8.3%

5.1 to 6.0 0.0% 0.5% 1.4% 1.1% 0.4% 0.1% 0.0% 0.0% 3.6%

6.1 to 7.0 0.2% 0.5% 0.4% 0.2% 0.1% 0.0% 0.0% 1.5%

7.1 to 8.0 0.0% 0.2% 0.2% 1.0% 0.1% 0.0% 0.0% 0.5%

8.1 to 9.0 0.0% 0.0% 0.0% 0.0% 0.1% 0.1%

9.1 to 10.0 0.0% 0.0% 0.0% 0.0% 0.0%

10.1 to 12.0 0.0% 0.0% 0.0%

12.1 or more 0.0%

Total 5.1% 25.3% 29.4% 23.9% 11.0% 3.7% 1.3% 0.3% 0.1% 100% Notes: 1. Sea Area Coverage: 15-25 N, 60-70 E 2. Seasonal Coverage: May to September 3. Period of data: January 1949-October 1995 4. Blank indicates zero frequency whilst 0.0% indicates less than 0.05% 5. Total number of observations were 38143 Source: EIA report of EVTL Terminal by Hagler Bailly Pakistan

5.3.7 TIDES & SURGES

Tides along Karachi Coast are semidiurnal but diurnal inequality is also present. The effect of this

inequality shows up in daily tidal cycle as there are two High Water tides and two Low Water tides which

also vary considerably from each other in tidal heights. These are classified as HHW, LHW, LLW and HLW.

The tides move from west to east i.e. the tide arrives at the Hub River estuary about 20 minutes earlier

than at Karachi. Similarly the tides at Karachi Harbor arrive about 10 minutes earlier than at entrance of

Port Qasim. When tides progress up the Phitti Creek their magnitude increases and there is a time lag.

At Port Bin Qasim which is about 32 km from Karachi and about 25 km up the creek from the sea, the

tides reach after 22 minutes. At Gharo Creek tides fall rapidly due to frictional effects and the gradual

weakening of the tidal forces. At Gharo 60 km from the Phitti Creek entrance the tides are almost half

of the mean sea tides at the entrance.

The tide levels at Port Qasim are presented in Table 5.7. The flow pattern within this large, relatively

deep and generally stable creek system around Port Qasim is strongly influenced by tides and the

presence of extensive inter-tidal flats.



Table 5.7: Tidal Levels at Port Qasim

Location MLLW MHLW MLHW MHH HAT LAT

Bundal Island +0.6 +1.2 +2.3 +2.9 NA NA

Hasan Point +0.6 +1.3 +2.8 +2.9 +3.4 +0.6

Phitti Creek 01.0 +1.4 +2.1 +3.4 +4.00 -0.6

5.3.8 SEAWATER CURRENTS

The speed of sea currents is generally low: ~ 0.5 knots. The speed increases up to 1 knot during SW

monsoon. The direction of the sea current is directly related with the prevailing wind system. The set is

generally easterly in the SW monsoon and westerly in the NE monsoon. The slight difference in direction

in the Western and Eastern part of Karachi Coast is due to circulatory pattern of the current around

gyrals which are usually formed at the center of the sea. There is a clockwise gyre during SW monsoon

and anti-clockwise gyre during NE monsoon (Quraishee, 1988). Quraishee (1984, 1988) has also

observed the existence of warm core eddies in the offshore areas of Pakistan.

Figure 5.4 - Wind pattern over Arabian Sea during SW and NE monsoons

(Source: Pearson P. Hall Inc, 2004)

5.3.9 CLIMATE

The coastal meteorology and hydrography of Karachi is controlled by the seasonal change in the north

Arabian Sea viz. monsoon system. The data collected for a number of studies along the Karachi coast

show the influence of NE and SW monsoon winds. The meteorological conditions in the area around

Port Qasim are characterized by generally hot and relatively humid conditions especially in the summers

(April to October) when the prevailing wind is from the south west. The south west monsoon brings

humid air in from the sea, but the rainfall is generally very low with nearly 80% of the 265mm of rain

falling from July to September. Rainfall, when it does come is often torrential causing problems of

drainage and erosion of the light and sparsely vegetated land.



The winters are short and mild from December to mid-February with the prevailing wind coming from

the northeast with very little rainfall. The most important characteristics of the prevailing meteorological

conditions are the generally high dusty conditions as a result of the aridity of the surrounding area; dust

storms occur especially during the summer as well as winter monsoons. The higher winds during the

south west monsoon tend to carry any air-borne contaminant inland during the summer months. In

winter the winds tend to be light to moderate in intensity.

The proposed CPP site located in the coastal zone has a relatively mild climate, characterized by dry, hot

and humid conditions. There is minor seasonal intervention of a mild winter from mid-December to

mid-February into a long hot and humid summer extending from April to mid-September.

Variation of climatic parameters during the past few years is described hereunder:

5.3.9.1 TEMPERATURE

The air temperature of entire coastal zone of Karachi is invariably moderate. The mean maximum

summer temperature is 37°C, while the mean minimum temperature is 10°C. There are occasion when

the coastal belt is in the grip of heat wave and the maximum temperatures exceeds 40°C but this

happens only a few times in the year and lasts for a maximum of three days. Average maximum and

minimum temperatures recorded at Air Port station are shown in Tables 5.8 and 5.9 respectively.

Table 5.8: Mean Monthly Maximum Temperature oC

Year Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Annual

2001 27.2 29.6 33.1 34.6 35.1 34.9 32.2 32.3 33.1 36.0 33.5 30.4 32.7

2002 27.0 28.2 33.3 35.4 35.6 35.1 32.2 31.6 31.4 36.5 32.7 28.1 32.3

2003 27.6 28.5 32.4 36.6 35.7 34.9 34.1 32.6 32.5 37.0 32.2 28.3 32.7

2004 26.6 29.9 36.2 35.4 36.8 35.6 33.8 32.7 32.8 33.7 33.1 29.4 33.0

2005 24.9 26.3 31.5 35.3 35.4 36.0 33.2 32.2 34.2 35.2 33.1 28.4 32.1

2006 26.0 31.3 31.8 34.0 34.6 35.3 33.8 31.0 34.2 35.0 33.4 26.3 32.2

2007 26.9 29.4 31.4 37.7 36.0 36.4 N/A N/A N/A N/A N/A N/A 33.0

2008 24.4 26.9 34.3 34.4 33.9 35.1 33.5 31.9 34.7 35.5 32.5 27.2 32.0

2009 26.2 29.8 33.0 36.0 36.8 35.7 34.5 33.0 32.8 35.9 33.0 28.6 32.6

2010 27.5 29.2 34.0 35.7 36.5 34.7 34.6 33.2 34.5 35.9 32.7 28.0 33.0

2011 26.9 28.5 33.2 35.8 35.3 35.3 34.2 32.8 32.9 N/A N/A N/A N/A

2012 25.7 26.9 31.7 35.1 35.5 34.6 33.2 32.7 33.2 35.0 32.7 28.2 32.0

2013 26.7 28.0 33.3 34.0 35.1 36.5 33.8 32.1 33.0 35.7 32.3 28.3 32.4

Source: Pakistan Meteorological Department

Table 5.9: Mean Monthly Minimum Temperature oC


2001 11.5 14.9 19.6 23.8 28.1 29.0 27.1 26.5 25.9 24.4 18.6 15.8 22.1

2002 12.8 13.8 19.5 23.9 27.0 28.2 29.6 25.6 24.8 22.5 17.7 14.9 21.7

2003 12.7 16.9 19.8 24.2 26.5 28.2 23.6 27.0 25.3 20.9 15.2 12.0 21.0

2004 12.9 14.5 19.1 24.8 27.3 28.8 27.5 26.3 25.3 22.4 18.0 15.4 21.9

2005 12.3 11.3 20.3 23.0 26.4 28.3 27.2 26.6 26.6 22.9 18.9 13.0 21.4

2006 11.7 18.1 19.6 24.5 27.5 28.5 28.3 26.3 26.8 25.7 19.4 14.0 22.5

2007 13.0 17.3 19.7 24.7 27.6 28.6 N/A N/A N/A N/A N/A N/A 21.8

2008 10.1 11.1 19.6 24.0 27.3 29.1 27.9 26.8 26.6 23.8 17.6 14.9 21.6

2009 14.7 16.5 20.8 23.8 27.6 28.7 28.1 27.5 26.5 22.6 17.0 13.9 22.3

http://www.answers.com/topic/climate



Table 5.9: Mean Monthly Minimum Temperature oC


2010 12.2 14.7 21.3 25.1 28.0 28.2 28.3 27.2 25.8 23.9 17.4 11.1 21.9

2011 11.0 14.5 19.7 23.1 27.1 28.8 27.8 28.6 26.5 N/A N/A N/A N/A

2012 11.2 11.9 19.1 24.5 27.2 28.0 27.9 26.9 26.4 22.7 18.6 14.2 21.5

2013 11.6 15.1 19.2 24.2 27.1 29.3 28.0 26.6 25.5 25.4 18.1 13.0 21.9


Figure 5.5 - Average temperatures of Karachi (The daily average low (blue) and high (red) temperature with percentile bands (inner band from 25th to 75th percentile, outer band from 10th to

90th percentile).

5.3.9.2 PRECIPITATION

The rain fall in the Karachi coastal zone is extremely low and erratic; therefore this region falls in the

semi-arid climatic zone. Table-5.10 shows the last few year’s precipitation data recorded at Karachi

Airport station.

Table 5.10: Monthly Amount of Precipitation (mm) at Karachi Air Port


2001 0.0 0.0 0.0 0.0 0.0 10.6 73.6 16.2 N/A 0.0 0.0 0.0 100.4

2002 0.0 2.4 0.0 0.0 0.0 N/A N/A 52.2 N/A 0.0 0.5 0.4 55.5

2003 6.4 21.8 0.0 0.0 0.0 16.3 270.4 9.8 N/A 0.0 0.2 0.0 324.9

2004 13.7 0.0 0.0 0.0 0.0 N/A 3.0 5.6 N/A 39.3 0.0 4.3 65.9

2005 6.6 12.8 N/A 0.0 0.0 N/A N/A 0.3 54.9 0.0 0.0 17.1 91.7

2006 N/A 0.0 N/A 0.0 0.0 0.0 66.2 148.6 21.9 0.0 3.1 61.3 301.1

2007 0.0 13.2 33.4 0.0 0.0 110.2 N/A N/A N/A N/A N/A N/A 156.8

2008 8.0 Trace 1.1 0.0 0.0 0.0 54.0 37.5 Trace 0.0 0.0 21.0 121.6

2009 3.0 Trace 0.0 Trace 0.0 2.6 159.9 44.0 68.9 0.0 0.0 1.5 55.68

2012 0.2 0.0 0.0 0.0 0.0 Trace Trace 8.1 121.0 0.0 0.0 22.8 152.1

2013 Trace 20.0 2.8 30.0 0.0 Trace 5.5 105.4 4.0 1.2 0.0 0.0 168.9




The above record for rainfall provide by PMD for Karachi Airport (2001-2013) suggests that July and

August are the wettest months and that the maximum rainfall recorded in Karachi during last few years

is 270.4 mm in July 2003.

On the other hand, during the year of 2006, heavy monsoon and winter rainfall was recorded during the

months of July/August and November respectively. Average rainfall recorded for the month of

December 2006 is around 61.3 mm.

Highest rainfall events have occurred in July 1994: 256.3mm, July 2003: 270.4mm and August 2006:

77mm in 3 hours. According to observations recorded for the year 2007, August 10 and 11 was witness

to unusually high rainfall of 107 mm in 24 hours compared with the normal of about 60 mm for August.

The wettest August ever experienced by the city was in 1979, when over 262mm of rainfall was

recorded. The record for the maximum rainfall within 24 hours in the eighth month was 166mm of rain

on August 7, 1979. The heavy rainfall was not unusual since it was caused by the general monsoon

system that travels from across Rajasthan and lays over Sindh. The monsoon weather system did not

move towards Baluchistan but the penetration of moist currents from Sindh brought scattered to heavy

rain in southern Baluchistan, particularly along its coastal regions.

The probability that precipitation will be observed at this location varies throughout the year.

Precipitation is most likely around August 4, occurring in 35% of days. Precipitation is least likely around

April 27, occurring in 2% of days.

Figure 5.6 - The fraction of days in which various types of precipitation are observed. If more than one type of precipitation is reported in a given day, the more severe precipitation is counted. For example, if light rain is observed in the same day as a thunderstorm, that day counts towards the thunderstorm totals. The order of severity is from the top down in this graph, with the most severe at the bottom.



5.3.9.3 HUMIDITY

The relative humidity typically ranges from 25% (dry) to 91% (very humid) over the course of the year,

rarely dropping below 10% (very dry) and reaching as high as 100% (very humid). The air is driest around

February 9, at which time the relative humidity drops below 33% (comfortable) three days out of four;

it is most humid around August 2, exceeding 83% (humid) three days out of four.

Figure 5.7 - The average daily high (blue) and low (brown) relative humidity with percentile bands (inner bands from 25th to 75th percentile, outer bands from 10th to 90th percentile).

5.3.9.4 WIND DIRECTION AND SPEED

During the summer or south-west monsoon (from June to August), winds reverse their direction and

blow from the west-south-west, with wind speed vary from 0 kn to 16 kn (calm to fresh breeze), rarely

exceeding 25 kn (strong breeze). Inter-monsoon transitions occur during October to November and

March to May is between 4-6 knots in the NNE direction. The wind direction is unsettled and speed is

low during the period intervening the two seasons viz. summer and winter. Wind direction and

distribution are given in Figure 5.9.

Figure 5.8 - Wind direction and distribution in Karachi



Figure 5.9 - The average daily minimum (red), maximum (green), and average (black) wind speed with percentile bands (inner band from 25th to 75th percentile, outer band from 10th to 90th percentile).

5.3.10 AMBIENT AIR & NOISE QUALITY

EMC acquired the services of SUPARCO to study the pollutants concentration levels in ambient air in the

microenvironment of project site. The monitoring was carried out at three locations in the

microenvironment of the project site as shown in Figure. 5.10.

5.3.10.1 DATA ACQUISITION CRITERIA

→ Air Quality data (concentration) of criteria pollutants such as NOx (as sum of NO & NO2), SO2, CO,

O3, TSP, PM10, PM2.5, and Lead were collected at each site.

→ The meteorological parameters (wind speed, wind direction, temperature & relative humidity) were

also measured onsite.

→ The data (air quality and meteorological parameters) was collected with interval of 15 minutes for

24 hours at each site

→ The USEPA methods/procedures as given in Table 5.12 were adopted for monitoring the air quality.

→ The data was analyzed under Sindh EQS guidelines and international standards for ambient air

quality given in Table 5.13.

Table 5.11 Concentration Limits of Equipment

Equipment Min.Concentration Limits

SO2 Analyzer ~1 µg/m3

CO ~0.5 µg/m3

NOx (NO + NO2) ~1 µg/m3

TSP/PM10 Sampler ~5 µg/m3

Surface O3 Analyzer ~0.3 ppb



Figure 5.10 (a) - Ambient Air Quality Monitoring Stations.

Figure 5.10 (b) - Ambient Air Quality Monitoring Activity

5.3.10.2 AMBIENT AIR QUALITY MONITORING METHODS & AMBIENT AIR QUALITY STANDARDS

The air quality parameters were measured by state of the art instruments based upon the USEPA and

ASTM methods. The detail is given in Table 5.12. The ambient air quality standards/guidelines of Sindh

EPA, USEPA, WHO and World Bank for data analysis and comparison are given in Table 5.13.

Table 5.12: Ambient Air Quality Monitoring Methods

NOx Reference Method in Appendix F of 40 CFR Part 50 Chemiluminescence

SO2 Ambient Monitoring Reference & Equivalent Method of 40CFR Part 52 Fluorescence Method

CO Method in Appendix C of 40 CFR Part 50 IR Gas Filter Correlation



Table 5.12: Ambient Air Quality Monitoring Methods

O3 Method in Appendix D of 40 CFR Part 50 UV Photometry

TSP Reference Method in Appendix B of 40 CFR Part 50 Beta Source

PM10 Reference Method in Appendix J of 40 CFR Part 50 Beta Source

PM2.5 Reference Method of 40 CFR Appendix L of Part 50 Beta Source

Lead Reference Method in Appendix G of 40 CFR Part 50 USEPA 200.8 (Analysis Using ICPMS)

Table 5.13: Ambient Air Quality Standards of Sindh EPA, USEPA, WHO and World Bank

Pollutants

USEPA WHO World Bank Sindh EQS

Avg. Time

Standard Avg. Time

Standard Avg. Time

Standard Avg. Time Standard

SO2 24 HRS 365µg/m3 (140 ppb)

24 HRS 1 HR

90µg/m3 (34 ppb) 350µg/m3

Annual Mean 24 Hrs

100µg/m3 500µg/m3

Annual Mean 24 Hrs

80µg/m3 120µg/m3

CO 8 HRS 1 HR

10 mg/m3 (9 ppm) 40 mg/m3

8 Hrs 10mg/m3 (8.7 ppm)

- - 8 Hrs 1 Hr

5 mg/m3 10mg/m3

NOx Annual Mean

100µ/m3 (53 ppb)

1 HR 190-320µg/m3

Annual Mean

100µb/m3 (50 ppb)

Annual Mean 24 HRS

40µg/m3 80µg/m3

O3 1 Hr 235µg/m3 8 Hrs 1hr

120µg/m3 200µg/m3

- - - 130µg/m3

SPM 24 Hrs 260µg/m3 24 Hrs 150-230µg/m3

Annual Mean 24 Hrs

100µg/m3 500µg/m3

Annual Mean 24 Hrs

360µg/m3 500µg/m3

PM10 24hrs 150µg/m3 - - - - Annual Mean 24 HRS

120µg/m3 150µg/m3

PM2.5 Annual Mean 24 HRS

75µg/m3 35µg/m3

Lead 24 Hrs - - - - - Annual Mean 24 Hrs

1µg/m3 1.5µg/m3

5.3.10.3 RESULTS

Health effects of criteria pollutants

The health effects of NOx exposure range from eye, nose and throat irritation at low levels of exposure

to serious damage to the tissues of the upper respiratory tract, fluid build-up in the lungs and death at

high exposure levels. In addition to the adverse effects of direct exposure, NOx emissions from coal

plants also pose a very serious health risk as ozone precursors.

Ozone pollution, also known as smog, is formed when NOx reacts with volatile organic compounds

(VOCs) in the presence of sunlight. Smog is a powerful respiratory irritant that can cause an array of

health problems. At low levels of exposure, ozone can cause coughing, wheezing, shortness of breath

and chest pain. At higher concentrations, breathing ozone can lead to more serious effects, including

lung tissue damage, reduced lung capacity, asthma exacerbation, as well as increased risk of



hospitalization for asthma, bronchitis and other chronic respiratory diseases. Recent studies

demonstrate that ozone exposure also may lead to premature death.

While particulate matter is released directly from smokestacks to some extent, a much greater amount

of particle pollution is formed from atmospheric reactions of SO2 and NOx. Inhaling particulate matter

can result a wide range of adverse health effects, including asthma attacks, lung tissue damage, stroke,

heart attack and premature death. The public health burden of particle pollution is staggering; a recent

study by Aga Khan University’s department of community health sciences has revealed that: “PM2.5

levels in Karachi exceeded the WHO’s 24-hour air quality guideline almost every day and often by a factor

of greater than five-fold. Frequent peaks at levels as high as 279 µg/m3 were also recorded. The study

shows that higher levels of PM2.5 are associated with a striking elevation in rates of ER (emergency

room) visits and hospital admissions for cardiovascular diseases.”

Monitoring Results

The air monitoring results are provided in Table 5.14-5.16.

The results show that ambient air concentration of all parameters i.e., SO2, NO2, NO, CO, PM10, PM2.5, SPM and Lead in the area meets Sindh Ambient Air quality Standards.

Table 5.14: Ambient Air Quality at AAQS1

SO2 (µg/m3)

NO (µg/m3)

NO2 (µg/m3)

CO (mg/m3)

O3 (µg/m3)

PM 2.5

(µg/m3) PM 10

(µg/m3) SPM

(µg/m3) Noise (dBA)

12.7 11.7 1.8 1.5 23.3 11

79 128

66

20.6 15.2 3.55 1.7 26.2 10 61

27.4 12.6 2.25 1.6 40.4 13 64

24.5 19.7 5.8 1.5 33.5 13 61

22.4 19 5.45 1.4 22.0 9 65

21.6 17.3 4.6 1.2 15.7 11 67

24 15.4 3.65 1.6 19.7 12 69

21.6 14.7 3.3 1.5 22.7 12 64

29.2 13.9 2.9 1.5 28.0 11 65

16.6 15.6 3.75 1.5 25.9 11 61

15.1 15.4 3.65 1.5 15.9 10 66

15.6 12 1.95 1.5 13.6 13 59

13.2 11.5 1.7 1.2 10.6 13 55

14 10.5 1.2 1.2 6.8 10 54

13.2 10.7 1.3 0.8 0.3 9 53

11.9 9.8 0.85 0.5 0.4 7 51

13.5 12 1.95 0.1 1.8 8 58

10.1 10.2 1.05 0 3.4 11 49

9.8 8.8 0.35 0.2 9.3 13 51

9.3 9.6 0.75 0.6 10.3 17 55

8.8 7.7 0.2 0 16.2 17 54

8.8 8.5 0.2 0 17.4 12 51

9.3 10 0.95 0 18.4 17 53

10.9 12.8 2.35 0.9 18.1 15 54

12.7 11.7 1.8 1.5 18.5 11 49

22.9 21.3 6.6 1.7 18.5 15 48




SO2 (µg/m3)

NO (µg/m3)

NO2 (µg/m3)

CO (mg/m3)

O3 (µg/m3)

PM 2.5

(µg/m3) PM 10

(µg/m3) SPM


27.7 17.1 4.5 1.7 7.7 17 48

30.8 19.9 5.9 2 5.9 16 56

28.4 21.6 6.75 1.5 2.3 13 57

30.5 26.5 9.2 1.6 1.5 15 51

24 29 10.45 1.4 1.2 16 59

24.2 30.5 11.2 1.2 2.8 16 55

29.2 25.2 8.55 1.3 2.5 17 59

22.4 17.7 4.8 1.8 2.3 15 60

19 16.4 4.15 1.6 2.0 15 61

16.4 14.1 3 1.7 2.0 17 66

13.8 13.7 2.8 1.4 0.5 18 64

15.1 14.1 3 1.2 1.6 15 65

14.3 13.7 2.8 1.4 2.5 15 67

13.5 14.7 3.3 1 0.9 17 69

15.3 15.4 3.65 0.6 0.2 15 61

14.8 13 2.45 0.5 1.8 13 68

11.1 12 1.95 0.4 1.6 19 61

10.6 12.2 2.05 0.5 1.5 21 69

10.4 11.9 1.9 0.2 0.8 21 66

9.6 11.9 1.9 0.2 1.8 18 67

9.1 11.5 1.7 0.4 1.6 19 63

11.9 15.4 3.65 1.3 2.8 15 62

16.4 16.2 4.9 1.7 0.1 13 67


SO2 (µg/m3)

NO (µg/m3)

NO2 (µg/m3)

CO (mg/m3)

O3 (µg/m3)

PM 2.5

(µg/m3) PM 10

(µg/m3) SPM


14.5 14 10 1.3 11.8 30

70 167

60

14.4 11 7 1.3 1.9 20 61

14.2 12 8 1.3 11.9 20 63

14.2 11 7 1.2 11.9 20 58

14.2 9 5 1.2 11.9 20 57

14.2 10 6 1.2 11.8 20 61

14.4 12 8 1.2 10 20 62

14.4 11 7 1.2 10.9 20 63

14.2 14 10 1.3 10.8 20 66

15.5 12 8 1.3 10.8 20 68

13.6 12 8 1 10.9 20 57

13.6 14 10 1 10.9 20 57

13.7 11 7 1 10.8 20 57

16.2 12 8 1 10.9 20 61

17.7 13 9 1 10.8 20 60

16.6 11 7 0.9 10.8 30 55

13.3 9 5 0.9 10.9 20 57

15.3 10 6 0.9 10.6 20 59




SO2 (µg/m3)

NO (µg/m3)

NO2 (µg/m3)

CO (mg/m3)

O3 (µg/m3)

PM 2.5

(µg/m3) PM 10

(µg/m3) SPM


13.4 12 8 0.9 10.6 20 61

13.4 14 10 0.8 10.5 20 64

10.3 15 11 0.9 9.6 20 62

9.3 12 8 0.8 8.6 20 63

9.5 12 8 0.9 8.6 20 64

7.5 9 5 0.9 9.6 20 61

8.6 10 6 0.9 8.6 20 61

7.3 11 7 0.9 6.6 20 61

8.5 12 8 0.8 6.5 20 61

6.3 9 5 0.9 5.6 20 59

6.3 8 4 0.9 5.5 20 59

4.4 8 4 0.7 5.5 20 61

5.6 9 5 0.7 4.6 30 61

6.6 8 4 0.7 4.5 35 63

6.4 7 3 0.7 4.5 20 59

5.5 7 3 0.7 4.6 20 64

6.3 7 3 0.7 6.7 20 58

6.3 7 3 0.7 5.4 20 61

6.3 9 5 0.8 5.6 20 53

5.3 7 3 0.8 4.5 20 50

5.3 9 5 0.8 5.4 20 55

5.3 9 5 0.9 1.6 20 57

4.5 8 4 0.8 0.9 20 57

4.4 8 4 0.8 0.8 20 53

4.5 7 3 0.9 0 20 51

4.4 7 3 0.9 2.1 20 50

3.4 7 3 0.6 0.2 19 51

3.3 5 1 0.6 0.5 21 55

3.1 5 1 0.8 1.2 20 56

4.4 4 0 0.8 0.9 20 53

4.4 5 1 0.9 0.1 30 55


SO2 (µg/m3)

NO (µg/m3)

NO2 (µg/m3)

CO (mg/m3)

O3 (µg/m3)

PM 2.5

(µg/m3) PM 10

(µg/m3) SPM


10.8 5 8 0.7 9 30

61 115

52

10.9 5 7 0.8 7.1 20 48

10.9 4 9 0.9 7.3 30 51

10.9 4 10 0.8 7.4 30 50

9.8 4 6 0.9 9 20 47

8.7 2 7 0.9 8.1 30 49

7.6 2 5 0.9 8 20 47

5.8 2 4 0.8 8.1 20 52

5.8 3 3 0.9 8.1 20 52

4.6 4 3 0.9 7 20 52




SO2 (µg/m3)

NO (µg/m3)

NO2 (µg/m3)

CO (mg/m3)

O3 (µg/m3)

PM 2.5

(µg/m3) PM 10

(µg/m3) SPM


4.9 5 4 0.8 8.1 22 52

4.9 5 5 0.9 8 20 59

4.9 5 5 0.9 8.2 20 47

4.9 4 3 0.9 8.4 25 44

4.8 4 6 0.9 8.2 27 49

4.6 6 7 0.9 8.4 28 49

4.5 9 8 0.9 8.5 25 51

4.8 9 4 0.9 8.4 28 51

4.5 9 3 0.9 8.1 25 53

4.6 8 5 0.9 8 20 49

4.6 9 5 0.9 8.1 18 51

4.5 9 5 1.5 8.2 17 52

4.5 9 9 1.5 8 14 53

8.8 10 8 1.4 7.7 15 51

8.7 11 9 1.4 7.6 16 52

9.9 12 10 1.4 7.4 16 53

11.1 9 8 1.5 7.5 15 51

11 9 11 1.5 7.5 16 51

7.6 9 8 1.5 10.7 16 51

10.6 8 6 1.5 9.5 16 51

11.6 9 7 1.6 9.5 16 51

11.6 9 9 1.5 11.4 16 61

10.6 10 7 1.2 12.4 17 65

10.6 10 6 1.2 12.4 16 64

11.7 10 8 1.2 12.3 15 69

11.6 10 6 1.2 12.5 15 61

11.7 12 5 1.2 12.8 18 62

11.7 14 3 1.1 16.3 20 63

11.7 14 2 1.1 19.1 20 62

11.6 12 1 1 19.3 22 61

12.3 9 0 1.1 18.1 20 65

14.6 10 2 1.1 16.2 20 69

15.4 9 2 1.1 18.1 20 71

16.5 9 4 1 16.1 10 59

17.5 11 3 0.9 18.1 18 58

18.4 9 5 1.1 16.2 19 57

18.4 12 5 1.1 16.4 15 59

17.3 11 4 1 18.4 20 51

17.2 12 3 1.1 19.5 21 59



5.4 ECOLOGY

The baseline program was carried out in support of biological studies in the marine environment in the vicinity of the proposed CPP site. The survey of marine ecology focuses on mangrove ecosystem, marine organisms, their habitats, productivity, bird fauna of the creek system and the ecosystems in which they inhabit. The baseline also takes into consideration the probability of the ecosystem being affected by port development, and evaluates unique creek ecosystems, key linkages, habitat loss for any endangered organisms found in the Mangrove Ecosystem, marine flora and fauna of the Mudflats that may require special management during project’s development and operation.

5.4.1 FLORA

Pakistan is divided into four phyto-geographical regions based on similarity of natural flora. Karachi falls in the Saharo-Sindian region. Floristically this region is considered very poor as represented by the fact that despite its size, only 9.1% of the known 4,940 floral species of Pakistan are found in this region. However the project is located close to the coast therefore, marine phytoplankton and mangrove forests are in relative abundance in the coastal areas. A list of plants found in the project area, their local and scientific names, distribution, and status are given in Table 5.17.

Table 5.17: Vegetation of the Macroenvironment

No. Local Name Scientific Name Local Status Local Distribution

Trees

1 Mangrove Tree, Timar Avicennia marina Common Coastal Area, Lyari,

2 Mangrove Tree, Timar Aegiceras corniculatus Rare Coastal, Lyari and Estuaries

3 Mangrove Tree, Timar Bruguiera gymnorhiza Karachi and Indus delta

4 Mangrove Tree, Timar Ceriops tagal Coast of Sindh

5 Mangrove Tree, Timar Ceriops decandra Sindh tidal zone

6 Mangrove Tree, Timar Rhizophora apiculata Tidal marshes of Indus:

7 Mangrove Tree, Timar Rhizophora mucronata Mouth of Indus and tidal

8 Mangrove Tree, Timar Sonneratia caseolaris Engler Mouth of Indus and

9 Jal, Peelu Tree Salvadora oleoides Common Coastal area

10 Babool, Kikar Acacia nilotica Common Coastal area

11 Masquit Tree Prosopis juliflora Common Karachi region

12 Kandi Kheji Prosopis cineraria Common Lyari, and Gond Pass

13 Neem Azadirachta indica Common Around the settlement in Karachi

14 Barr Ficus bengalensis Common Around the settlement in Karachi

15 Sireh Albezia lebbek Common Around the settlement in

16 Jungali Ber Zyziphus nummularia Common Coastal area

17 Khajoor Phoenix dactylifera Scarce Coastal area

Shrubs

1 Akro Plant Calotropis procera Scarce Waste land

2 Kaneer Nerium oleandr Scarce Waste land

3 Salsola foetida Common Saline and Coastal Area

4 Salsola bryosoma Common Saline and Coastal Area

5 Haloxylon recurvum Common Saline and Coastal Area

6 Suaeda nudiflora Common Saline and Coastal Area

7 Suaeda fruticosa Scarce Saline and Coastal Area

8 Salicornia indicum Common Saline and Coastal Area



Table 5.17: Vegetation of the Macroenvironment

No. Local Name Scientific Name Local Status Local Distribution

Reed and Sedges

1 Cane Grass-Munj Phragmites karka Common Fresh water and along the Sea coast

2 Grass-Deer Typha angustata Common Fresh water and along the Sea coast

3 Saccharum Grass Saccharum sponteneum Common Fresh water and along the Sea coast

Coastal Belt: The natural setting of creek coastal ecosystem of the project area has been characterized as (Saifullah et al.):

Dwarf common plants: Prosopis juliflora, Salvadora persica, Cressa cretica.

Grasses: Suaeda nudiflora, Cenchrus bliflora, Sporobolus tremulus and Juncellus laerigatis.

Mangrove plants: 8 species of mangroves have been documented along the coast of Karachi with Avicennia marina and Rhizophora sp are dominant species. Rhizophora is being planted by IUCN and WWF under different rehabilitation programs.

Mangrove associated microorganisms: Phaeocystis (phytoplankton) algae occur exclusively in areas rich

in organic matters along the detritus of mangroves and sewage pollutants from residential settlements, discharged into the sea.

According to Flora of Pakistan (1972) eight species of mangroves have been reported from Pakistan as listed in above Table. Though eight species of mangroves, only four continue to thrive. These are Avicenna marina, Aegiceras corniculatum, Ceriops tagal and Rhizophora mucronata.

Bacterial and fungus populations observed along with the mangrove community in creek area belong to species Entrophospo sp., Acailospora gadanskensis, A. mellea and A. gadanskis. The reported marine algae in the region are Ulva reticulate, U. lactuca, U. fenestrate and Enteromorpha compressa. Honeybees, which were once common in the mangrove forest, have now become rare. The possible

causes are pollution, mangrove clearing and over harvesting.

Data on the Phytoplankton along the shelf and coastal waters of Pakistan is scarce. According to IUCN, more than 200 species of diatoms, more than 59 species of cocolithophorids, and more than 120 species of dinoflagellates are known to occur in the Arabian Sea.

The Avicenna marina is the dominant species of the mangroves in the Indus Delta. In the microenvironment of project area the most dominant species is also Avicenna marina that forms a thick green cover over Kadiro Creek. The density of mangrove trees was between 50-60/100 m2. The height of the individual tree within the established Avicenna marina habitats was mostly greater than 3 m.

The mangrove trees growing 200-300 m away from the creek (seawater) in the land ward direction

showed an overall decline in the height of the mangrove plantations.

The density of mangrove vegetation was randomly evaluated in an area of 100m2. The trees were characterized (visual observations) according to the arbitrary height of the plants.



→ The height of mangrove seedling were characterized as <0.5 m → Mangrove sapling height 0.5 -1.0 m → Short mangroves trees were characterized as having 1-2 m height. → Medium height mangroves trees had were characterized as having 2-3 m height. → High mangroves trees had were characterized as having more than 3 m height.

Figure 5.11 - Mangroves plantation in the Creek

Figure 5.12 - Prosopis juliflora (left), Sueda monaica, PJ and Avicenna marina (Right)

5.4.2 FAUNA

Three sampling site were identified to evaluate the distribution of benthic faunal densities, macro faunal

diversities, & similarities of faunal organisms within the stations sampled. The sampling was undertaken

at low tidal position so that maximum coastline was exposed at receding tide.

5.4.2.1 METHODOLOGY

Sampling was done using a shallow draft boat. A hand held GPS (Garmin) was used for identifying the

station positions. A plastic spade was used to excavate approx. 20x20 cm2 of sediments from a depth of

15 cm depth of exposed coastal area at low tide from each station. The silty cum muddy substrate

sediments along with the benthic infaunal organisms were preserved in 10% formalin (Figure 4) in large

mouth plastic jars for further analysis of the collected samples in the laboratory. The organism in the

sediment samples were sieved identified and enumerated. Statistical software was used for calculating

distribution, diversity, faunal affinities etc.



Table 5.18 - Sampling stations

Station No. Time Tidal Position Sediment Type

1 1230 hrs Ebb 0.26 m Silty cum Muddy

2 1245 hrs Ebb 0.26 m Sitly cum muddy

3 1330 hrs Ebb 0.26 m Silty cum Muddy

Figure 5.13 - Sampling and preservation of benthic sediments

Benthic community: This community includes the microbes: detritus feeders, small and large

herbivores, and small and large carnivores. In the mangrove ecosystem, the benthic community of the

adjacent shallow water is a subject of interest. Here, the microbes decompose the plant litter into

organic detritus - a fundamental commodity of system energy. This detrital matter is picked up by the

detritus feeders over the bottom, such as fishes, shrimps and shellfish, and then carried to the littoral

zone by wave action, shared by the intertidal fauna such as crabs, shrimps, mudskippers, invertebrates

and waders. At low tide, when a large part of muddy bottom is exposed, crabs, mudskippers and"

waders are seen in large numbers picking up their food which includes worms and different animals left

behind by the receding tide.

5.4.2.2 SURVEY RESULTS

The descriptive statistics of benthic organisms observed in the three sampling stations are given in table

5.19. The mean number of organisms ranged from 50 to 185 per 10 cm2. The total species encountered

at the three sampling stations ranged from 5-8.

Table 5.19 - Descriptive Statistics Benthic Fauna

Sample Mean

Individuals Variance Std Dev Std Error

Total Individuals

Total Species

Max Mean

Confidence Interval

Sample 1 50.6 22892.71 151.303 47.846 506 7 481 14189.04

Sample 2 95.4 75569.39 274.899 86.931 954 8 877 46838.39

Sample 3 185.8 331346 575.627 182.029 1858 5 1824 205370.39

Species Distribution Benthic Fauna: The distribution of benthic organisms observed collectively from the

project site shows Nematode worms to be by far the dominant species followed by Harpactoid Copepods

in the sediment samples. Nematodes, Harpactoid Copepodes, Polycheate worms and larva and

organisms show an aggregate behavior, presumably due to their mode of reproduction. While other



benthic organisms show a random distribution. The random distribution may be due to strong tidal flows

in the creek. The Benthic organism encountered are not listed as threatened or endangered by the IUCN.

Table 5.20 - Species distribution of Benthic Fauna

Species Variance Mean Chi-sq d.f. Aggregation

Nematode worm 476212 1060.667 897.9492 2 Aggregated

Harpacticoid copepod 252 22 22.9091 2 Aggregated

Nauplii 0.3333 0.3333 2 2 Random

Cyclopoid copepodite 14.3333 5.3333 5.375 2 Random

Calanoid copepod 0.3333 0.3333 2 2 Random

Polychaete larva 21 4 10.5 2 Aggregated

Polychaete worm (juvenile) 49 11 8.9091 2 Aggregated

Mollusc larva (gastropod) 2.3333 1.3333 3.5 2 Random

Amphipod 1.3333 0.6667 4 2 Random

Sabellid polychaete 0.3333 0.3333 2 2 Random

Shannon Weiner diversity Index: The Shannon Weiner biodiversity Index was undertaken; the results

are given in table 4. Both the species diversity and the species richness is relatively poor. The species

diversity ranges from 0.69 to 0.90 (normal range is 3.0) whereas the species richness i.e. number of

species in each of the community measured between 0.07 at sample 3 to 0.188 at station 1 (species

richness ranges from 0.01 (low) to (1.0) high. It is not unusual, since the creeks are generally a disturbed

area.

Table 5.21 - Diversity Index vales at the three sampled stations

Index Sample 1 Sample 2 Sample 3

Shannon H' Log Base 10. 0.111 0.17 0.05

Shannon Hmax Log Base 10. 0.845 0.903 0.699

Shannon J' 0.131 0.188 0.071

Bray and Curtis Cluster analysis: The Bray and Curtis similarity dendrogram shows sampling station with

high similarity clubbed together. Sampling Station 2 and 3 have been clubbed while station 1 is dissimilar

to station 2 and 3. Both sampling stations 2 and 3 are sheltered while station 1 is exposed to strong

sediment erosional forces, possibly due to ebb and flow of tides and waves action in the creek.

Figure 5.14 - Cluster analysis sampling station have similar species have been clubbed together



Station # 1 Macrofauna (0.5 mm)

Nematode worm Polychaete worm (Juvenile)

Meiofauna (0.063 mm) Nematode worm Harpacticoid copepod Nauplii

Cyclopoid copepodite Calanoid copepod Polychaete larva

Polychaete worm (juvenile)



Sample # 2 Macrofauna (0.5 mm)

Amphipod Polychaete worm (Juvenile)

Polychaete worm-2 Sabellid polychaete

Meiofauna (0.063 mm)

Nematode worm Harpacticoid copepod Mollusc larva (gastropod)

Cyclopoid copepod Calanoid copepod Polychaete larva

Polychaete worm-1 (juvenile)



Sample # 3 Macrofauna (0.5 mm)

Nematode worm Polychaete worm-1 Polychaete worm-2 Polychaete worm-3

Polychaete worm-4 Polychaete worm-4 (J.) Polychaete juvenile-

2 Bivalve-1

Bivalve-2 Bivalve-3

Meiofauna (0.063 mm)

Nematode worm Harpacticoid copepod Polychaete worm-4 (juvenile)

Cyclopoid copepod Calanoid copepod Polychaete juvenile



Endemic birds: The intertidal areas of the Indus Deltaic Creeks also provide food and shelter to a number

of endemic species of birds. (Figure 5.15). Some of these birds are also migratory. The more common

among these a Oystercatcher, Lesser Sand Plover, Greater Sand Plover, Grey Plover, Golden Plover, Little

Ringed Plover, Kentish Plover, Sanderling, Dunlin, Curlew, Whimbrel, Marsh Sandpiper and Common

Sandpiper.

Breeding activities of a number of endemic birds have been reported in the coastal wetlands the Delta

particularly of the Little Tern, Common Tern, Gullbilled Tern, Yellow legged Herring, Lesser Black backed

Gull and Great Black headed Gull.

The diversity of bird fauna is indicative of food availability, different bird have a range of benthic animals

to feed on. The birds feed on a range of organisms from plankton to polychaete worms, crabs and mud

skipper.

Sand Plover curlew bird

Stork Coots and Seagull

Figure 5.15 - Endemic species of birds



5.5 SOCIOECONOMIC ENVIRONMENT

The ecology of the two UCs viz. Ibrahim Haidery and Rehri, which are the main constituencies of the

macroenvironment of the proposed project site, has completely changed by having grown from villages

dominated mainly by fishermen until the late 1950s with hardly 250 huts each scattered along the coast

to attain the category of towns with population estimated by the local residents to exceed 50,000. Both

of them are now the headquarters for Union Council Administration. Lath Basti and Chashma Goth have

also grown from villages to small towns; they are both part of Rehri Union Council.

Residents of Ibrahim Haidery and Rehri were traditional fishermen involved in fishing business since the

last few centuries. They have been joined by scores of migrants from coastal villages and towns like Shah

Bunder and Keti Bunder on the east and west of Indus Delta respectively and also the Bangladeshis and

Burmese who appeared here as cheap labor. Lath Basti on the other hand is home for the Jat tribe, who

were traditionally engaged in cattle and camel farming. The Jat tribe had migrated from the interior of

Sindh and has been residing at the present site of Lath Basti for the last seven or eight decades. Juma

Goth with its Railway Station and a large plot of land, designated to house the KCR displaced population,

lies between Cattle Colony and Port Qasim Employees Residential area.

5.5.1 DEMOGRAPHY

Population in the built environment of proposed site belongs to different clans and tribes. Traditionally,

these clans/tribes had hereditary productive activities. For example, the Khaskhelis were agriculturists;

the Jats were pastoral people, breeders of camels and suppliers of timber/fuel. The Memons and Shidis

were merchants and traders, the Dablas were fishermen. These people served the clan communities

and in exchange were maintained by them. All economic relations between the clans were those of

barter. Cash transactions only took place between the Sardars (tribal chiefs) and Waderas (tribal elders)

and through them with the outside world. This system guaranteed not only the economic independence

of the village but also the supremacy of the feudal class.

Survey of the villages in macroenvironment reveals that “Old Jokhio” used to live there before the

industrial developments.

The population mix in UC Ibrahim Haidery is overwhelmingly Sindhi and Balochi speaking, followed by

the Bengali-speaking people. Gulshan-i-Hadeed has a combination of all ethnicities with Sindhis forming

the slightly larger group. Union Council Rehri is overwhelmingly Sindhi and Balochi and while the number

of other clans is almost negligible.

The cattle colony is the center of cattle and meat trade in Karachi. The Cattle Colony is the dairy products

shopping and supply center of Karachi. Its population is overwhelmingly Punjabi.

5.5.2 EMPLOYMENT AND LIVING CONDITIONS

The macroenvironment does not offer opportunities for employment and the population is primarily

employed as cheap unskilled labor force in the industrial areas of PQA. Agriculture is limited to

subsistence farming due to scarcity of water. In Juma Goth and areas close to Cattle Colony extensive

areas are under cultivation of vegetables using the effluent from the cattle yards. Livestock herding is

not a healthy and reliable income generating option, and the few livestock holdings in the settlements

are primarily for household and domestic use, a source of dairy consumables. Skilled labor is rare and



the categories of skilled labourers are mostly drivers, welders, plumbers and electricians. Government

service is rarely available.

The population in the UCs can be broadly placed in three categories - fishing communities residing in

small clusters of households down south along the coastline, labor class and workers employed in the

industries in the area, and very few white-collar workers. Majority being illiterate or lacking education,

the people find employment either in subsistence farming or at best as casual and unskilled labor

engaged in the surrounding industrial installations, with the Pakistan Steel, KESC Thermal power plant,

Dewan/Pakland Cement factory and the Pakistan Railway Marshalling Yard being major employers.

Numerous small villages in the UC have not been supplied with electricity despite the fact that high

tension lines bring in power for numerous industries that have been established here.

Port Qasim colony has a total estimated population of 2200 consisting of families of PQA’s employees

having average household comprising 8 persons. Port Qasim Colony has all the basic facilities of life

including; electricity, telecommunication, gas, and drinking water. Transportation and access to main

highway through the link road is available. Amenities and mosques are present. People working in PQA

belong to low to high-income groups having average earning up to Rs 15,000 per month.

The population resident in UC Ibrahim Haidery and Rehri is totally dependent on low level engagements

including fishing. The UCs surrounding the microenvironment of the proposed site consist of scattered

villages inhabited by old Jokhio tribe. Being farther away from the main highway they have not been

provided with all the basic civic facilities and are among the underdeveloped areas of Karachi City

District. The area is marked with poverty with average household income not exceeding Rs 8,000.

The Settlements in the Korangi Creek area are fisherman’s villages but the dwellers are engaged in other

low level occupations as well. The employment and therefore earnings for a large section of population

in the area is variable, heavily dependent on fisheries. Prawn, shrimp and crab fishing from inshore

waters is the main source of income of the majority. However, quite a substantial segment of population

is employed on deep-sea fishing boats. The relatively low level of income in this rural setting is reflected

in the poor condition of housing, with water supply and sanitation being too inadequate. Some of these

villages are now provided with electricity, connected by paved road and served by Public Transport.

5.5.3 DEPENDENCE ON MANGROVES

Mangroves are a valuable resource for many of the coastal villages. They are primarily used as a source

of fuel and fodder and provide the feeding grounds for prawn and shrimp, besides protecting the land

from erosion. The people have been overexploiting this resource over the years. IUCN has, in association

with Sindh Forestry Department, initiated a program of mangrove conservation, replanting and

sustainable management along the coastline of Rehri village. Engro Asahi Polymers has undertaken an

extensive program of plantation of mangroves. They have a nursery where they cultivate the mangroves

from the millions of propogules shed by the mature trees in the surrounding.

5.5.4 EDUCATION

Educational facilities in the surrounding area of the UCs Ibrahim Haideri and Rehri are limited to primary

and secondary schools. Each village in the area has access to a primary school within a distance of three

to four kilometres. There is also a high school in Ibrahim Haideri and Rehri that covers and meets the

demands of nearby Deh. Availability and access to education may be regarded inadequate because of



lack of efficient and effective schooling system to facilitate and promote literacy and education. Literacy

rate among females is low, especially in adult females who are rarely literate.

Training in technical skills is inadequate. Skilled labor consists of drivers, mechanics, water pump

attendants which are estimated to be less than 10 % of the total labor force. Thus the resident

population in the immediate neighbourhood is not capable of being employed in skilled category as

might be perceived by the proposed CPP Project in near future.

5.5.5 HEALTH

Clean and safe water is one of the major problems being faced by the residents of UCs Ibrahim Haideri

and Rehri. Though the Karachi Water and Sewerage Board’s pipelines bring in approximately 580 million

gallons of water daily from the Indus river and Hub Dam to Karachi and route it through Bin Qasim Town,

yet a majority of the villages have not been given water connections and have to depend on ground

water and other sources including the unhealthy springs, for drinking as well as domestic purposes.

Health problems of the UCs Ibrahim Haideri and Rehri are generally associated with water availability

and quality aggravating sanitary conditions due to lack of facilities and reliable water supply. Health

facilities are inadequate and sub-standard. Both UCs have one Basic Health Unit (BHU) and a primary

health care unit (PHCU) but both units are understaffed and not well-equipped. For advanced medical

aid treatment cases are referred to health centres at Quaidabad or city centres of Karachi.

5.5.6 LANDSCAPING

The terrestrial environment around the UCs consists of sparse scrub and a few trees of Acacia nilotica,

Prosopis juliflora with some grazing from domesticated animals including camels, goats and cattle. The

land adjacent to the coastline has deposits of poorly sorted, unconsolidated loose gravel, sand and silt.

It has sand bar deposits comprising medium to coarse sand, which is being exploited for cut-and-fill in

the construction industry, and for land preparation for the industrial zone and for reclamation of land

area on extensive areas in the south. This has disturbed the landform during and has irreversibly

changed the landscape of the near-shore area.

5.5.7 ARCHAEOLOGICAL AND HISTORICAL SITES

A review of investigations in the Port Qasim area and a visit to the macroenvironment of the project site,

did not indicate existence of any feature or structure of cultural significance or of archaeological interest

within the area of the proposed activity.



Social Conditions of the Project Area



6.0 SCREENING OF POTENTIAL ENVIRONMENTAL IMPACTS AND PROPOSED MITIGATION MEASURES

Presented in this chapter are the screening of potential environmental aspects and assessment of their

severity based on stakeholder perceptions about the project which was obtained at the outset of the

EIA activity together with the data collected during the baseline survey.

Screening process has been adopted to identify significant environmental and social aspects during the

pre-construction, construction and operation stages of proposed 1 x 660 MW CPP Project. Based on the

environmental aspects identified for the different stages and during the stakeholder meetings,

mitigation measures have been proposed. Mitigation Measures will have to be adopted in order to

reduce, minimize or compensate for the negative impact as far as possible.

6.1 IMPACT ON LANDUSE

About 250 acres of land has been acquired for the project. The land acquisition has a direct impact on

the change in land use pattern of the land, which will be converted to industrial use. However, as the

hinterland is mostly barren with a gentle upward slope from the sea shore towards southeast and free

from forests and agricultural fields, the impacts on land use pattern is likely to be insignificant.

The near shore environment of the project site is characterized by long and narrow creeks, mud flats

and the mangroves forest ecosystems. However, it has been committed that for any mangrove tree /

plant destroyed due to Project activities, five mangrove seedlings / species will be planted in another

part of the coast/project site in presence of independent observers such as IUCN-P, WWF-P and LEPCL

shall be responsible to provide necessary care until they reach maturity.

The construction activities will attract a sizeable population and influx of population is likely to be

associated with construction of temporary camps for construction work force. However, this will be only

a temporary change and shall be restricted to construction period. As soon as the construction phase is

over, the land use pattern modified to meet the requirement of construction phase shall be reversed.

Changes in land use due to influx of labours and construction activities, if any, shall be temporary and

restricted to construction sites only. Further, the construction of project on barren land along with

proposed landscaping and green belt all around, is likely to improve upon the aesthetics of the area and

shall have a positive impact on land use pattern of the area.

6.2 IMPACT OF CONSTRUCTION ACTIVITIES

Construction activities have different types of environmental impacts. Some of these relate to activities

at the construction site where as others relate to the setting up and operation of the construction crew

camp. Typical issues include:

Site clearance leading to dust emission

Removal of vegetation leading of loss of vegetation cover

Erosion and sedimentation

Air quality impact from operation construction machinery

Noise and vibration



Waste management

Off-site impacts such as those related to borrow pits

Effluent from construction camp

Cultural impact related to presence of non-local workers

Generally, the exposed soil after excavation for foundations is vulnerable to erosion and runoff by rains.

Such a situation is of temporary nature and short duration. It lasts only during the landscaping and

concreting phase of construction at the site. The situation will be mitigated by taking the following

measures:

Covering the open soil especially during the rainy season until concreting and landscaping is

complete.

Intensification in fugitive dust emission caused by erosion of soil will be mitigated by appropriate

measures to reduce the level of impact to minor significance.

Control of air emission during construction is the responsibility of Proponent and their contractors

who will be mandated to adopt the following mitigation measures:

Exposed surface to be regularly wetted to effectively keep airborne dust levels to minimum

Stockpiles of fine material to be wetted or covered with tarpaulin especially during windy weather

conditions.

Site workers to wear dust masks especially during dry and windy weather conditions.

The project site in particular the activity areas are vulnerable to spill of chemicals and fuel during their

handling, transportation and storage. The soil at the construction site may be impacted adversely if the

materials are not handled carefully. Oil & grease if present in the run-off will result in soil contamination

and this result in significant impact. The spill may take place:

During transfer from one container to another or during refuelling;

During maintenance of equipment and vehicles;

Due to leakages from equipment and containers; and

Due to traffic accidents.

The following measures will be adopted to prevent soil contamination:

Fuel oils, lubricants, and chemicals will be stored in covered dyked areas, underlain with impervious

lining.

Vehicles will only be washed in designated areas.

Maintenance of vehicles and equipment will only be carried out at designated areas.

The area will be provided with hard surface or tarpaulin will be spread on the ground to prevent

contamination of soil.

Regular inspections will be carried out to detect leakages in construction vehicles and equipment.

Appropriate implements such as shovels, plastic bags and absorbent materials will be made

available near fuel and oil storage areas for removal of oil and contaminated soil.



Contaminated soil will be removed and properly disposed after treatment such as by incineration

or bio-remediation.

Many of the construction related impacts are temporary & end with the completion of the construction

activity. However, poor management can result in damage to the environment during activities.

To avoid adverse impact of the construction activities on the environment, following measures are

proposed:

The construction contractor will develop a specific Construction Management Plan (CMP) based on

the CMP included in the EMP. The CMP will be submitted to the LEPCL for approval.

The CMP will clearly identify all areas that will be utilized during construction for various purposes.

For example, on a plot plan of the construction site the following will be shown:

o Areas used for camp

o Storage areas for raw material and equipment

o Waste yard

o Location of any potentially hazardous material such as oil

o Parking area

o Loading and unloading of material

o Septic tanks

o Safe distance from water front

Other key mitigation measures are as follows:

The new equipment will be stored in properly demarcated and identified areas;

Lifting equipment (cranes) used for the equipment will follow the prescribed safety specification;

Material Safety Data Sheet (MSDS) for chemicals, if any, will accompany the consignment. A copy

of the MSDS will be available near the storage area at all times;

Appropriate PPEs will be provided to the workers and it will be ensured that the PPEs are used;

The staff will be provided with training in use of PPE;

Proper scaffolding platforms will be provided for all work areas located more than 1 m above floor

level;

First Aid facilities and fire protection devices will be placed in areas where activates will be

performed;

Ear protection will be used if the noise level is above 85dB(A);

All confined spaces will be identified;

The temperature of the confined space will be in the human tolerance range;

Artificial and intrinsically safe lighting will be provided in the confined spaces;

If there is a risk of gases or fumes in the confined space the provisions for ventilation will be made.



6.3 SOIL DISTURBANCE

Constructional activities like levelling, excavation and removal of existing vegetation invariably disturbs

the soil of the area. The project site is generally flat with a gentle upward slope from the sea shore

towards southeast. The existing ground elevation is approximately 0 to 2 meters above mean sea level

(MSL) along the coastline to approximately 10 to 15 meters above MSL along the southeast boarder.

The soils on the project site consists of alluvial deposits of gravels, windblown sand deposits, silty sand,

and stiff clayey silt, which is evident from the soil boring data. Below the silt and sandy overburden, the

harder and more stable conglomerate is formed followed by shale and limestone bed rock at a shallow

depth. To bring the plant grade to above the 100-year flood level, the plant site will be back filled to an

approximate elevation of 5 m above the MSL using the granular soil materials from the higher elevation

areas.

The impacts on soil during construction phase mainly results due to loss of topsoil in the construction

areas and contamination of the soils of surrounding area due to construction materials such as cement,

sand, oils, etc. The disturbances are more pronounced during the summer and monsoon seasons with

strong rains. However, as the project site is located on mostly barren and rocky terrain, the loss of top

soil will be insignificant.

Further; such impacts, if any, shall be temporary and confined to the areas of construction only. After

construction of project, appropriate soil treatment measures shall be taken within the main plant and

associated areas and large scale afforestation shall be undertaken which would contribute positively

towards soil improvement. Green belt and afforestation shall act as barrier to fugitive dust from the

construction area to the surrounding area. Removed top soil, if any, may be utilised for land scaping and

land improvement in other areas, which are not under construction.

During operation of a thermal power project, the soils within the deposition zone of pollutants may

undergo physico-chemical changes due to deposition of SPM (ash particles) and washout of gases (SOx

and NOx) during the rains. However, the impacts of these are likely to be marginal, as the impacts on

soil due to gaseous emissions from operation of LECPP, are likely to be negligible as the maximum

incremental PM and SO2 levels are in the range of 1.3 and 15.1 µg/m3 respectively.

6.4 STABILITY OF STRUCTURES

The area presents a moderate to high hazard potential for earthquake activity. The coastline is already

under stress and hence becomes vulnerable to seismic shocks. Moreover the triple point of the faults

and the Allah bund fault are not far from the site. Karachi hilly zones have often been subject to shocks

although of low order. The most recent seismic event on April 16, 2013 had its epicentre at Sistan but

the project area was jolted just the same.

The recently developed (after the October 2005 earthquake) seismic zone map of Pakistan has divided

the country into 4 seismic zones ranging in term of major, moderate, minor and negligible zones with

respect to ground acceleration values. Under this zoning the proposed project site lies in the moderate

to high hazard zone with minor to moderate damaging impact.

The recently developed guidelines for earthquake design of buildings in Karachi have assigned an

expected Peak Ground Acceleration'(PGA) value of 0.20g for large structures. This would place the



proposed site within Uniform Building Code (UBC) Zone 2B. The expected intensity according to the

Modified Mercallis Scale (MM) would be VIII and higher.

No specific mitigation measure other than construction of the LECPP Project in accordance with the UBC

Zone 2B is recommended. The power plant building structure(s) would be reinforced concrete

(recommended by UNDP for Tsunami affected areas). This responds to the Tsunami hazard that has

been identified recently.

6.5 SOIL & WATER CONTAMINATION

During the construction phase site preparation (levelling, excavations etc.) and erection of structures will

have temporary effect on the water quality of receiving water body, i.e. Kadiro Creek. Flow of loose

materials (soil and construction material) into the drain, especially during monsoons will result in higher

turbidity and suspended solids content. However, such impacts will be short term and limited to

construction areas only. Adequate arrangement would be made to ensure proper drainage and disposal

of the wastewater; so that water does not stagnate in the form of cess pools promoting breeding of

mosquitoes and creating in-sanitary conditions. The wash off will be directed to a septic tank before

discharge. Hence no significant increase in the suspended solid content of the water regime is expected.

Possible sources of soil and water impact include:

Spills during refuelling, discharges during vehicle and equipment maintenance, traffic accidents,

handling of chemicals and leakages from equipment and vehicles often result in contamination of

soil during construction;

Runoff after a storm from the plant site or the construction site may contain oil that may pollute the

surrounding lands. Earthwork may also alter the drainage pattern and affect the storm water flow

and result in possible flooding of sections of surrounding land;

Improper disposal of domestic effluent from the camp may result in contamination of soil and water

and become a health hazard;

Various types of wastes such as packing waste; metal scrap, and excess materials, uprooted

vegetation, and excess soil will be generated during the construction phase. Besides being an

eyesore, the waste can be a health hazard and pollute waterways, if disposed improperly;

The untreated discharge of sanitary wastewater effluent from the power plant can potentially affect

the sea water;

The direct discharge of liquid waste effluent from the power plant can potentially affect the water

resources;

Sea contamination during the coal handling and transfer;

The direct discharge of heated water from the power plant to the water resources.

The operations phase will require use of process chemicals some of which can be hazardous. These

chemicals require proper handling in order to avoid any potential damage.

Soil Contamination

A significant impact on soil will be interpreted if visible amounts of hydrocarbons are observed in the

soil. A significant impact will be interpreted if:



Visible quantity of liquid waste (oil and grease etc) & coal dust is present in the runoff from the site

A significant impact on the environment will be interpreted if wastewater discharged to the

environment is not in compliance with the SEQS.

As no regulations for waste handling and disposal exists, an adverse impact on the environment will be

interpreted if,

Any person is exposed to potentially hazardous waste generated by the Project

The Project generates waste that can be avoided through practicable means (waste minimization)

Reusable waste generated by the Project is discarded

Recyclable waste instead of separation at the source is dumped at the trash bins

Any waste generated by the Project is scattered at any place outside the designated bins, or

Non-recyclable and non-reusable waste ends up at any place other than the designated disposal

site.

A significant impact will be interpreted if hazardous material is handled in manner other than that

prescribed in the Material Safety Data Sheets (MSDS), without a valid justification.

Ash generated from the project is stored at any place other than designated disposal site

Drainage and Storm Water Run-off

The storm water runoff from construction sites can carry oil and grease if the soil is contaminated or the

potentially contaminated areas (oil and grease storage areas, maintenance areas and workshops) are in

contact with the run-off from the surrounding areas and will release in the sea water. Any risk may be

eliminated by taking measures to avoid spills and taking immediate remedial measures in case of

accidental spillage of oil.

Camp Effluent

The staff and labor camps for the construction and operation of the power plant will be a source of

wastewater generated from the toilets, washrooms, and the kitchen. The untreated wastewater will not

meet the national environmental standards and will therefore need treatment prior to disposal.

Plant Effluent

The effluents from the plant include the boiler blow down, cooling water and waste water from the

plant. A water treatment plant will be constructed at the plant site which will ensure the effluents meet

the SEQS limits.

While developing the water system for the project, utmost care has been taken to maximise the

recycle/reuse of effluents and minimize effluent quantity. All major water systems of the plant (cooling

water system, service water system, coal handling water system and bottom ash handling system) have

re-circulatory systems. However, discharge of effluents from a power plant cannot be totally eliminated.

It is proposed to adopt the direct-flow circulating water supply for the circulating cooling water system

of the 1x660 MW supercritical unit in this project, and the source of the circulating cooling water is the

seawater. According to the stability of tide, silt and shore at the sea area where this project is located

and the overall planning of the power plant, the circulating water intake is set within the sea area at the



south side of the coal transport; it is proposed to set the outlet on the mud flat at the south side of the

coal transport wharf and nearby the north-side elevation of -3.5m isobaths. It is planned to adopt the

different-level mode of "deep taking and shallow draining" for arranging the water intake and outlet.

The unit water supply system is adopted for circulating water supply; one water intake is set for the

1x660 MW unit, located at the southwest side of the plant-area wharf and about 500m from the power

plant; the water outlet is located at the northeast side of the plant-area wharf and is about 750m from

the power plant; the 1x660 MW unit is also provided with one artesian diversion tunnel, 4 circulating

water pumps, two pressure water supply pipelines, one dual-hole circulating water drainage ditch, and

one artesian drainage channel. The technological process of the circulating water system is:

Water intake artesian diversion tunnel circulating water pump pressure water supply pipeline condenser siphonic water-collecting well.

A hydrodynamic plume model, CORMIX (Cornell Mixing Zone Expert System), developed by the U.S.

Environmental Protection Agency was used to study the impact of thermal discharge from the power

plant. According to the findings, Plume is vertically fully mixed at 749.15 m downstream.

The plume conditions at the boundary of the specified RMZ are as follows:

Pollutant concentration c= 0.996933 deg.C

Corresponding dilution s= 7.1

Plume location: x= 98.73 m

Plume dimensions): half-width = 121.11 m

Thickness = 5.91 m

Cumulative travel time < 0 sec (RMZ is with NFR)

Regulatory Mixing Zone analysis: The RMZ specification occurs before the near-field mixing regime (NFR)

has been completed. The specification of the RMZ is highly restrictive.

One common, wastewater treatment system with a single 100% train

will be provided to treat process wastewater generated by the plant. The wastewater treatment system

will be sized for the maximum expected flow based on the plant water balance. The wastewater

treatment system will be designed to produce treated effluent in accordance with the requirements of

Sindh EQS.



A sanitary treatment facility will be provided to treat domestic wastewater from the power plant and

colony.

INDUSTRIAL WASTEWATER TREATMENT: At various locations within the plant, there will be sumps and

packaged oil-water separators for the interim collection of wastewater and treatment of oily

wastewater, respectively. Mixed bed demineralizer and condensate polisher regenerant wastewater

will be treated at the power block in a packaged neutralization system consisting of a tank with internal

mixing device, recirculation pumps, pH controls, and chemical addition systems. All remaining

wastewater will be pumped to one of two equalization ponds. One pond will provide collection and

interim storage of low-volume wastewater and material storage runoff. The other pond will provide

collection and interim storage of metal cleaning wastewater.

Wastewater from each pond will be treated separately on an as-needed basis in a common physical-

chemical treatment system. The wastewater treatment process is expected to include several steps.

Raw wastewater introduced to the treatment process first enters a reaction tank where lime or caustic

is added to raise the pH.

After pH adjustment, the wastewater enters an oxidation tank with air sparging where metals are

oxidized and precipitated as metal hydroxides. The wastewater stream containing precipitated metals

and other solids then enters a flocculation tank followed by a lamella (inclined plate) clarifier in which

solids are removed.

After the final treatment step, the wastewater enters the effluent monitoring basin from which it is

pumped to the circulating water discharge flume. The components of the treatment process are

arranged to allow gravity flow throughout the entire process into the monitoring basin. The treatment

process includes a thickener and filter presses for mechanical sludge dewatering such that a solid waste

by-product is produced that can be landfilled.

SANITARY WASTEWATER TREATMENT SYSTEM: Several lift stations will be provided for transporting

raw sewage from the main power block and outlying areas to the sanitary treatment system. The

concrete basin extended-aeration type sewage treatment plant equipment contains an integral

submerged bar screen at the inlet to the surge tank compartment. Dual sewage pumps provide a flow

to the aeration tank chamber based on the depth of water in the surge tank. Flow from the aeration

chamber to the dual hopper clarifier is by gravity. Aeration blowers are mounted above the aeration

tank and supply air to the biological treatment process. The resulting solids are settled into downstream

clarifier hoppers while floating solids are skimmed from the clarifier surface and returned to the aeration

chamber. The clarified effluent flows into an integral chlorine contact tank where sodium hypochlorite

is added before discharge. There is an integral airlift system for the return of settled solids from the

clarifier hoppers to the aeration basin.

The treated sanitary effluent will be used for watering of the greenbelt surrounding the power plant and

within the colony.

The following control measures are proposed to mitigate the impact on soil and sea water:

Spill prevention trays will be provided and used at refuelling locations

During on-site maintenance of construction vehicles and equipment, tarpaulin or other

impermeable material will be spread on the ground to prevent contamination of soil



Regular inspections will be carried out to detect leakages from construction vehicles and equipment

Vehicles and/or equipment with leakage will not be used until repaired

Fuels, lubricants, and chemicals will be stored in covered bunded areas, underlain with impervious lining

Appropriate spill control arrangements, including shovels, plastic bags and absorbent materials, will be available near fuel and oil storage areas

Measures will be taken to minimize soil contamination. Contaminated soil will be immediately collected to minimize the volume of contaminated soil. Heavily contaminated soil will be segregated from the rest of the soil. Various final disposal options for contaminated soil are available. These include incineration at facilities in Karachi, disposal through licensed hazardous waste contractors, encapsulation at site, and bioremediation at site or off-site location. Appropriate disposal method will be employed, however, until an acceptable method is found the contaminated soil will be stored at the site in secure containers.

Through contouring and installation of embankments, where necessary, it will be ensured that storm water from the surrounding areas does not enter the construction site and pass to the sea water

All unpaved exposed areas of the plant will be compacted to minimize water erosion

Run-off from all areas containing potentially hazardous materials will be isolated from the remaining site.

Soil banks from ditching operations will not be placed where they might impair natural drainage

Channel runoff will be provided, where necessary, to avoid flooding

No untreated effluents will be released to the environment

Liquid waste will be collected and treated in an on-site wastewater treatment plant to comply with NEQS before releasing to the environment

Good practice measure will be followed while handling coal at the site and while transferring coal from ships.

Regular monitoring of the coal handling will be in place at the plant site berth if the sea transportation is selected.

Implementation of the proposed mitigation measures is not likely to leave any long-term residual impact on the soil. However, insignificant amounts of hydrocarbons may be left in the soil due to minor spills, where remedial measures are not possible.

Even after implementation of the control measures, it is possible that some littering may take place. Periodic monitoring and clean-up will be undertaken to minimize the residual impact.

6.6 IMPACT ON AIR QUALITY

IMPACT DURING CONSTRUCTION PHASE

Site preparation activities would include clearing, excavation, earth & fill movement, and transportation of machinery and associated equipment to the site. Since heavy machinery will be involved during the



entire construction period the said activities may lead to extensive soil erosion, or alteration of soil

quality or removal of topsoil at the site. Impact due to wind erosion of exposed surfaces and uncovered

stock piles, dust emission from movement of dump trucks, construction equipment and other vehicles

on unpaved roads, and mixing and batching of aggregate for concrete preparation (if done on site) will

be of moderate order. Most of the material excavated from the project site will be used as fill within the

project area; this will not require additional borrow material.

Suspended particulate matter (SPM) is likely to be a major problem because of the arid and dusty

environment all around. Particulate matter (PM10), according to Sindh’s Ambient Air Quality Standards

should not to exceed 150µg/m3 for a weighted average time of 24 hours. Mitigation measures needed

under the circumstances would aim at protection of the personnel.

Combustion of fuel for running the generators and construction equipment will have negative impact

on the ambient air quality of the microenvironment of construction site if the operation of the

equipment is not environment friendly in the sense that their engines are not appropriately tuned and

their exhaust fumes are not suitably discharged.

Control of air emission during construction will be the responsibility of LEPCL and their contractors who

will be mandated to follow the Environmental Management Plan in letter and spirit. The following

mitigation measures will be adopted:

Regular and periodic sprinkling of water on all exposed surfaces to suppress emission of dust.

Frequency of sprinkling may be increased to keep dust emissions under control, particularly during

the stormy season of mid-April to mid-June when wind is blowing at high speed and varying

direction.

Keeping the construction material in moist condition (if possible) at site.

Locating stockpiles away from the wind direction and covering it with tarpaulin or thick plastic

sheets, to prevent dust emissions.

All routes within the project construction site facility will be paved providing hardened surface as

early as possible upon the commencement of construction work. Other temporary tracks within the

site boundary will be compacted and sprinkled with water during the construction works.

Construction traffic will maintain a maximum speed limit of 20km/hr on all unpaved roads within

the proposed site.

Construction materials that are vulnerable to dust formation or those that comprise loose materials

will be transported only in securely covered trucks to prevent dust emission during transportation.

The exposure of construction workers to dust will be minimized by providing dust masks.

All vehicles, generators and other equipments used during the construction will be appropriately

tuned and maintained in good working condition in order to minimize exhaust emissions.

The stacks of the generators while in operation will be vented through vertical stacks to safe heights

in order to minimize dispersions at ground level.

Diesel and other petroleum products used for the operation of construction machinery and

transportation equipment would cause air pollution besides causing soil pollution through oil spills.



The impact from such activity would be of minor significance and would be controlled by good

housekeeping practices.

IMPACT DURING OPERATION PHASE

The main mode of air pollution from a thermal power plant is point emission –emissions from the boiler

and the combustion of fuel (HSFO, natural gas and coal) results in the emission of various types of

pollutants from the plant stack. The main pollutants are Particulate Matter, Oxides of Nitrogen (NOx),

and Sulphur Dioxide (SO2).

The impact of particles on human health is largely dependent on (i) particle characteristics, particularly

particle size and chemical composition, and (ii) the duration, frequency and magnitude of exposure. The

potential of particles to be inhaled and deposited in the lung is a function of the aerodynamic

characteristics of particles in flow streams. The aerodynamic properties of particles are related to their

size, shape and density. The deposition of particles in different regions of the respiratory system

depends on their size.

The nasal openings permit very large dust particles to enter the nasal region, along with much finer

airborne particulates. Larger particles are deposited in the nasal region by impaction on the hairs of the

nose or at the bends of the nasal passages. Smaller particles (PM10) pass through the nasal region and

are deposited in the tracheobronchial and pulmonary regions. Particles are removed by impacting with

the wall of the bronchi when they are unable to follow the gaseous streamline flow through subsequent

bifurcations of the bronchial tree. As the airflow decreases near the terminal bronchi, the smallest

particles are removed by Brownian motion, which pushes them to the alveolar membrane (CEPA/FPAC

Working Group, 1998; Dockery and Pope, 1994).

Air quality guidelines for particulates are given for various particle size fractions, including Suspended

Particulate Matter (SPM), thoracic dust or PM10, and respirable particulates of PM2.5 (i.e. particulates

with an aerodynamic diameter of less than 2.5 μm). Although SPM is defined as all particulates with an

aerodynamic diameter of less than 100 μm, an effective upper limit of 30 μm aerodynamic diameter is

frequently assigned. PM10 and PM2.5 are of concern due to their health impact potentials. As indicated

previously, such fine particles are able to be deposited in, and damaging to, the lower airways and gas-

exchanging portions of the lung.

The most direct information on the acute effects of sulphur dioxide comes from controlled chamber

experiments on volunteers. Most of these studies have been for exposure periods ranging from a few

minutes up to 1 hour, but the exact duration is not critical because responses occur very rapidly, within

the first few minutes after commencement of inhalation. The effects observed include reductions in

respiratory volume capacity, increases in specific airway resistance, and symptoms such as wheezing or

shortness of breath. Such effects are enhanced by exercise, which increases the volume of air inspired

thereby allowing sulphur dioxide to penetrate further into the respiratory tract (WHO 2000).

Nitrogen Oxides (NOx), primarily in the form of Nitrogen Oxide (NO), are one of the primary pollutants

emitted during combustion. Nitrogen Dioxide (NO2) is formed through oxidation of these oxides once

released in the air. NO2 is an irritating gas that is absorbed into the mucous membrane of the respiratory

tract. The most adverse health effect occurs at the junction of the conducting airway and the gas

exchange region of the lungs. The upper airways are less affected because NO2 is not very soluble in



aqueous surfaces. Exposure to NO2 is linked with increased susceptibility to respiratory infection,

increased airway resistance in asthmatics and decreased pulmonary function.

Mathematical models are used to compute the distribution of pollutant concentrations in air, given the

rate and height of emission and the relevant meteorological data. Mathematical models are the basic

and very important tools to quality the impacts of existing (or) a proposed project. In this study, the

industrial source complex model has been used for estimating GLC of SO₂, NOx & PM.

THE GAUSSIAN EQUATION: The ISC short-term model for stacks uses the steady-state Gaussian plume

equation for a continuous elevated source. For each source and each hour, the origin of the source’s

coordinate system is placed at the ground surface at the base of the stack. The x-axis is positive in the

downwind direction, the y-axis is crosswind (normal) to the x-axis and the z-axis extends vertically. The

fixed receptor locations are converted to each source’s coordinate system for each hourly calculation of

concentrations. The hourly concentrations calculated for each source at each receptor are summed to

obtain the total concentration produced at each receptor by the combined source emissions.

Figure 6.1 – Gaussian Dispersion Pattern of Air Pollutants

For a steady-state Gaussian plume, the hourly concentration at downwind distance x (meters) and

crosswind distance y (meters) is given by:

Where, Q= pollutant emission rate (mass per unit time) K= scaling coefficient to convert calculated concentrations to desired units (default value of 1 x 106 for Q in g/s and concentration in mg/m3) V= vertical term D= decay term F, Fz= standard deviation of lateral and vertical concentration distribution (m) Us= mean wind speed (m/s) at release height



Equation (1) includes a Vertical Term (V), a Decay term (D), and dispersion parameters (Fy and Fz).

The modeling for the proposed LECPP Project was carried out using the US EPA ISCST3 Model. The

model is capable of handling multiple sources, including point, volume, area and open pit source types.

However, in the present scope the model was used for point emission (chimney) source type. In the run

stream setup file, default mode (regulatory dispersion modeling options) of operation for the model was

selected. The default mode consider followings in the computation of ground level concentration.

→ Use of stack-tip downwash, and

→ Routine for processing averages when calm winds or missing meteorological data occur.

METEOROLOGICAL DATA: The 5 year hourly micro-meteorological parameters like wind direction, wind

speed and ambient temperature were utilized for the modeling purpose. The analysis of meteorological

data reveals that the winds were flowing predominantly from the WSW direction and the calm

conditions (wind speed less than 1m/s) were 3.6%. The wind-rose diagram is presented in Figure 3.1. In

addition to the measured meteorological parameters, ISCST3 also required atmospheric stability classes

and mixing height data. These additional parameters were estimated or obtained from the secondary

sources as discussed in the following paragraph.

Figure 6.2 – Wind rose Diagram

ATMOSPHERIC STABILITY CLASSES: The required hourly Pasquill - Gifford Stability Classes were

determined using Turner’s method and solar isolation. Reference: US EPA “Meteorological Monitoring

Guidance for Regulatory Modeling Applications3”.

MIXING HEIGHT: The mixing height is defined as the height of the layer adjacent to the ground over

which an inert non-buoyant emission will be mixed (by turbulence) within a time scale of about one

hour or less. For routine application, the Holzworth Method is recommended for estimating mixing

heights. Hourly mixing heights, for use in regulatory dispersion modeling, are interpolated from the

morning and evening radiosonde data for Karachi.

3 EPA-450/4-87-013.



RECEPTOR LOCATIONS: A study area of 05km radius around the proposed power plant was considered

and receptors were placed on Cartesian grid system, origin at 200 m high stack.

EMISSION SOURCE DATA: Emission inventory has been prepared based on the engineering details

available with LEPCL. Release rate of pollutants has been calculated after considering the pollution

control measures. Emission inventory of PM10, PM2.5, SO2 and NOx has been prepared for modeling

because they are considered criteria pollutants covered under the local regulations (ambient air and

emission standards). The name of unit, stack diameter, exit velocity, gas temperature and pollution load

(inventory) is given in Table 6.2.

Table 6.2 - Modeling Parameters

Parameter Value

No. of Stacks 01

Stack Height, m 200

Inner Dia, m 5

Flue Gas Temperature, K 343.15

Exit velocity, m/s 16

Pollutant Flow Rate

Parameter Value

SO2 75.59 g/s

NOx 198.716 g/s

PM10 8.50 g/s

PM2.5 4.25 g/s (50% of PM10 flow rate)

DEFAULT VALUES: The ISCST model by default does the extrapolation of wind speed (Irwins exponents)

to the effective height of release and calculates final plume rise as per Briggs equation. Since 50% of land

inside a circle of 5 km radius around the site does not have considerable build-up area, rural dispersion

coefficient is considered for modeling. Dry depletion and wet depletion of pollutants, exponential decay

of pollutants during the travel time from source to receptor was not modeled, hence the modeled

results depicts worst case scenario. The model used regulatory default options for stack tip downwash,

buoyancy induced dispersion, uses calm processing routines, default wind processing exponents,

vertical potential temperature gradients.

MODELING RESULTS: The model was set up for calculation of 24-hour & annual average values. The

Ground Level Concentration (GLC) were plotted as isopleths.

Discussion: The worst incremental 24 hourly average GLC value of SO2, NOx, PM10 and PM2.5 from the

project at full operating load with 200 m high stack will be 15.1 μg/m3, 40 μg/m3, 1.3 μg/m3 and 0.85

μg/m3 respectively in the downwind ENE direction (at 2.0 km distance). The worst incremental annual

average GLC vale of SO2, NOx, PM10 and PM2.5 from the project at full operating load will be 3.6 μg/m3,

9.5 μg/m3, 0.4 μg/m3 and 0.2 μg/m3 respectively in the downwind ENE direction (at 1.0 km distance).

The maximum incremental GLC is superimposed over the maximum baseline ambient air level and the

resultant values are shown in Table 6.5 (24 -hour average in μg/m3). The 200 m tall stack heights with

high momentum and buoyancy takes the plume above the highest mixing height. 99.98%. PM emissions

are controlled using ESP, SO2 by FGD and NOx by Low NOx burners. This results in lowest ground level

concentration of air pollutants in the study area.



Table 6.3 – Incremental GLC due to LECPP

Parameter Incremental GLC (max) Background Level Superimposed Value Sindh EQS

SO2 15.1 μg/m3 12.06 μg/m3 27.16 μg/m3 120 μg/m3

NOx 40 μg/m3 7.89 μg/m3 47.39 μg/m3 80 μg/m3

PM10 1.3 μg/m3 70 μg/m3 71.3 μg/m3 150 μg/m3

PM2.5 0.9 μg/m3 19.25 μg/m3 19.2 μg/m3 75 μg/m3

Maximum Predicted 24-HOUR Average Ground – Level Concentrations of PM10 without Control

would be 265 µg/m3 in ENE direction at a distance of 2000 meters from Project site;

Maximum Predicted 24-HOUR Average Ground – Level Concentrations of PM10 with Control would

be 1.3 µg/m3 in ENE direction at a distance of 2000 meters from Project site

Maximum Predicted ANNUAL Average Ground – Level Concentrations of PM10 without Control

would be 81.2 µg/m3 in ENE direction at a distance of 1000 meters from Project site;

Maximum Predicted ANNUAL Average Ground – Level Concentrations of PM10 with Control would


Maximum Predicted 24-HOUR Average Ground – Level Concentrations of PM2.5 with Control

would be 0.9 µg/m3 in ENE direction at a distance of 2000 meters from Project site

Maximum Predicted ANNUAL Average Ground – Level Concentrations of PM2.5 with Control would


Maximum Predicted 24-HOUR Average Ground – Level Concentrations of SO2 without Control


Maximum Predicted 24-HOUR Average Ground – Level Concentrations of SO2 with Control would


Maximum Predicted ANNUAL Average Ground – Level Concentrations of SO2 without Control


Maximum Predicted ANNUAL Average Ground – Level Concentrations of SO2 with Control would


Maximum Predicted 24-HOUR Average Ground – Level Concentrations of NOx without Control


Maximum Predicted 24-HOUR Average Ground – Level Concentrations of NOx with Control would

be 40 µg/m3 in ENE direction at a distance of 2000 meters from Project site

Maximum Predicted ANNUAL Average Ground – Level Concentrations of NOx without Control

would be 237 µg/m3 in ENE direction at a distance of 1000 meters from Project site

Maximum Predicted ANNUAL Average Ground – Level Concentrations of NOx with Control would


The following are the key conclusions:

Apparently all the emissions are getting dispersed at the designed height of 200 m.

The values of the emissions at the fallout distance are within the Sindh Environmental Quality

Standards (SEQS). The value of PM10 & PM2.5 which is the parameter of concern in coal fired power

plants is much within the limits suggested by SEQS. As such introduction of mitigation measures will

entail emissions that will be within all standards and guidelines.

A complete extractive-type continuous emission monitoring system (CEMS) will be provided with

flue gas analysers for SO2, NOX, CO2, and opacity meters for the unit. The CEMS will be furnished

with sampling systems, sample conditioning, sample lines, analysers, a programmable logic



controller (PLC), and a shelter to house the CEMS equipment. The PLC will have a redundant link to

the plant DCS.

Coal and coal waste products, including fly ash, bottom ash, and boiler slag, contain many heavy

metals, including arsenic, lead, mercury, nickel, vanadium, beryllium, barium, cadmium, chromium,

selenium and, radium, which are dangerous if released into environment. Major portion of these

heavy metals may remain with ash. The efficient ash management system adopted for the

proposed power plant shall control release of ash as well as heavy metal into environment.

Particulate emission level below the prescribed EPA limit of 150 µg/Nm3, will be achieved by the use

of efficient dust collection system having efficiency not less than 99.95%.

Use of low sulphur containing coal (<0.5%) will be maintained to reduce SO2 emission. Flue Gas

Desulphurization plant will be installed to control excess SOx.

As Dry Low NOx burners (DLNB) will be installed to control NOx emission from the combustion

process, routine checking of the DLNB performance will be done during the boiler maintenance

period. Boiler will be designed with sufficient over fire air to further improve NOx control.

High combustion efficiency will be achieved by ensuring proper air to fuel ratios and providing

adequate turbulence and residence time for combustion of fuels within the furnace, thus ensuring

compliance with the permissible emission levels for residual carbon monoxide.

Continuous online monitoring system for SPM, CO, SO2 and NOx with computer display and

recording facility will be installed to facilitate regular check-up of air emissions and ensure

compliance with the prescribed standards. Any faults in the system will be reflected in the computer

of control room. Display will be also provided at plant gate and EMD.

ID fan will be interlocked with the ESP tripping so that the operating boiler can be stopped / adjusted

till the defect is rectified.

Coal dust will be suppressed by water spraying arrangements at suitable locations such as unloading

yard, transfer points, etc. Transfer towers and crusher house will be provided with dust extraction

systems. In addition, water sprinklers will be provided in the coal storage area to suppress the coal

dust generated during stacking and re-claiming of coal.

All major roads with in the plant boundary will be paved and periodically cleaned by mechanical

sweeping machines to avoid any re-suspension of air borne dust particles.

Ash handling including conveying system will be monitored for timely intervention and control in

case of leakages detected in the line.

Ash pond will have a freeboard of 1 m. Ash disposal method (location and duration) in the pond will

be controlled so that there is no unwarranted build-up of ash at one location. A minimum water

depth of 1 feet will be maintained in the ash pond to prevent ash from blowing with surface wind.



Figure: Isopleth of Maximum Predicted 24-HOUR Average Ground – Level Concentrations of PM10 (µg/m3) without Control

Figure: Isopleth of Maximum Predicted ANNUAL Average Ground – Level Concentrations of PM10 (µg/m3) without Control



Figure: Isopleth of Maximum Predicted 24-HOUR Average Ground – Level Concentrations of PM10 (µg/m3) with Control

Figure: Isopleth of Maximum Predicted ANNUAL Average Ground – Level Concentrations of PM10 (µg/m3) with Control



Figure: Isopleth of Maximum Predicted 24-HOUR Average Ground – Level Concentrations of PM2.5 (µg/m3) with Control

Figure: Isopleth of Maximum Predicted ANNUAL Average Ground – Level Concentrations of PM2.5 (µg/m3) with Control



Figure: Isopleth of Maximum Predicted 24-HOUR Average Ground – Level Concentrations of SO2 (µg/m3) without Control

Figure: Isopleth of Maximum Predicted ANNUAL Average Ground – Level Concentrations of SO2 (µg/m3) without Control



Figure: Isopleth of Maximum Predicted 24-HOUR Average Ground – Level Concentrations of SO2 (µg/m3) with Control

Figure: Isopleth of Maximum Predicted ANNUAL Average Ground – Level Concentrations of SO2 (µg/m3) with Control



Figure: Isopleth of Maximum Predicted 24-HOUR Average Ground – Level Concentrations of NOx (µg/m3) without Control

Figure: Isopleth of Maximum Predicted ANNUAL Average Ground – Level Concentrations of NOx (µg/m3) without Control



Figure: Isopleth of Maximum Predicted 24-HOUR Average Ground – Level Concentrations of NOx (µg/m3) with Control

Figure: Isopleth of Maximum Predicted ANNUAL Average Ground – Level Concentrations of NOx (µg/m3) with Control



6.7 COAL DUST CONTROL

The dust control system will consist of the dust suppression system and dust collection system. Dust

suppression by water sprinkling is considered appropriate. An improved stockpile water spray system,

designed to be effective in high wind conditions and more efficient in where and when sprays are

activated. Coal is not allowed to remain dry since such conditions can create an explosion hazard.

Vacuum filters would not work with wet coal and hence pollution control will be achieved by a water

spraying system that will be installed for dust suppression at the Coal Yard.

Continuous water sprinkling shall be carried out on the top of the heap at regular intervals to prevent

dusting, fire & smoke. To prevent fugitive emission during loading/unloading, fixed pipe network with

sufficient water storage and pump shall be installed. Water sprinkling shall be carried out at each and

every stage of handling to avoid generation of coal dust or other dust within premises.

Contractors and operators must be mandated to use new generators and to regularly maintain them so

that the emission levels are within acceptable range. Mitigation measures including proper

maintenance of construction equipment and controlling unnecessary idling of equipment will be

implemented. The dust collection system will be provided for transfer tower, crusher house, and coal

bunkers. Wash down systems will be provided in transfer tower, crusher house, tunnels and trestles.

Water spray will be provided in coal storage yard. Coal conveyers will be equipped with bag house at

suitable intervals to capture the coal dust formed within the enclosed conveyers.

To reduce emission of dust from coal yard, wind break will be installed around the coal yard. Wind

breaks are made of steel mesh. The height of the walls is typically kept at least 30% more than the height

of the coal pile. Wind break ensures that no wind enters the coal yard and cause propagation of coal

dust. The advanced steel windbreak can effectively control the dust pollution of bulk material in the

open air. It is claimed that the technology can reduce dust emission from coal yard by more than 80%.

Figure 6.3: Coal Pile Wind Break

6.8 IMPACT DUE TO NOISE

IMPACT DURING CONSTRUCTION PHASE: The major noise generating sources during the construction

phase are vehicular traffic, construction equipment like, dozer, scrapers, concrete mixers, cranes,

generators, pumps, compressors, pneumatic tools, vibrators etc. The operation of these equipment will

generate noise ranging between 75-90 d8 (A).

Impacts on noise quality can occur from the following sources.



During construction: construction camp; earth moving and excavation equipment; concrete mixers;

cranes and transportation of equipment, materials and people. Although there are techniques

available to predict the likely noise effects from construction works, such as those contained within

BS5228: Part 1: 1997 and Part 4: 1992: Noise and Vibration Control on Construction and Open Sites,

they are necessarily based on quite detailed information of the type and number of plant being

used, their location and the length of time they are in operation. Noise levels measured at and also

reported from noise producing activities at construction sites (such as piling, earthworks etc)

generally range in the order of 100-110 dB (A) at source. These noise levels generally attenuate to

less than 70dB (A) within 200m from the source.

The nearest human settlement (hereinafter referred as sensitive receptors) is “Lath Basti”, a village

located at 150 meters West of LECPP project site. The residential area of “Bhains Colony” is also

located at about 900 meters North of Project site as shown in the following figure:

Figure 6.4 – Sensitive receptors in the vicinity of LECPP

The construction activities will be for a short duration and thus any noise impact on receptors will

be of temporary nature. The ambient noise level recorded during field studied in the

microenvironment of Project area ranges between 48-57 dB (A). The predicted noise level due to

operation of such equipment at a distance of 150 m from the source is 45 dB(A). As the predated

noise levels are less the ambient noise levels range, due to masking effect, no increase in the

ambient noise levels during construction phase is envisaged.

LECPP

Site

LATH BASTI

BHAINS COLONY



The construction activities of the proposed project will generate additional traffic. However,

impacts from increased traffic will not be significant as even doubling the number of vehicles on a

road increases noise levels by 3dB (A).

Table 6.4 - World Bank Recommended Noise Levels

Specific Environment Maximum Allowable Log Equivalent (Hourly

Measurements), in dBA

Day (7:00-22:00) Night (22:00-7:00)

Residential, institutional, educational 55 45

Industrial, commercial 70 70

Table 6.5: WHO Guideline Values for Community Noise in Specific Environments

Specific Environment LAeq (dB) Averaging Time (hours)

LAmax, fast (dB)

Outdoor living area 55 16 -

Dwelling (indoors) 35 16

School classrooms (indoors) 35 During class

Hospital, ward rooms, night-time (indoors) 30 8 40

Industrial, commercial, shopping and traffic 70 24 110

areas (indoors and outdoors)

Table 6.6: Construction Equipment Noise Ranges (dBA)

Equipment Peak Noise Range at 15.2 m

Typical Peak Sound Level in a Work Cyclea

Typical ‘Quieted Equipment’ Sound

Levelb

Construction Phase

Earthworks Structures Installation

Batching plant 82-86 84 81 Y

Concrete mixers 76-86 85 82 Y

Cranes 70-94 83 80 Y Y

Excavators 74-92 85 82 Y

Tractors & trolleys 77-94 88 85 Y Y Y

Water bowsers 85-93 88 85 Y Y Y

Graders 72-92 85 82 Y

Bulldozers 65-95 80 75 Y

Paver 87-89 88 80 Y

Pumps 68-72 76 75 Y Y Y

Diesel generators 72-82 78 75 Y Y Y

Vibrators 68-82 76 75 Y Y

Drilling machines 82-98 90 87 Y Y

Compressors 74-84 81 71 Y

Dumpers 77-96 88 83 Y Y Y

Road rollers 73-77 75 72 Y Sources: Bolt, Beranek, and Newman, Noise from Construction Equipment and Operations, Building Equipment, and Home Appliances. USEPA, 1971; http://www.waterrights.ca.gov/EIRD/text/Ch11-Noise.pdf; http://www.lacsd.org/LWRP%202020%20Facilities%20Plan%20DEIR/4_6_Noise.pdf; http://newyorkbiz.com/DSEIS/CH18Construction.pdf Notes: a. Where typical value is not cited in literature, mean of the peak noise range is assumed



b. Quieted equipment can be designed with enclosures, mufflers, or other noise-reducing features. Where data is not available, a 3 dB reduction is assumed.

Table 6.7: Predicted Noise Level for Construction Equipment (dBA)

Equipment Equivalent Noise Level in an 8-hr Shift at

Receptor 700 m from Source

Batching Plant 49.5

Concrete mixers 50.5

Cranes 41.1

Excavators 46.1

Tractors and trolleys 48.7

Water bowzer 48.7

Graders 46.1

Bulldozers 41.1

Paver 49.1

Pumps 41.5

Diesel generators 44.7

Vibrators 37.1

Drilling machines 48.1

Compressors 44.7

Dumpers 46.1

Road rollers 36.1

Mitigation Measures: The following mitigation and control measures will be implemented to minimize

the intensity of the above impacts:

All construction activities will be conducted in accordance with the principles of Best Practicable

Means (BPM). BPM describes methods of working and equipment usage to ensure that potential

construction noise nuisance is prevented wherever possible.

Engineered noise control measures will be implemented in order to reduce noise during the

construction phase. This may involve:

o All vehicles, equipment and machinery used during construction phase will be in good condition

and will be regularly maintained to avoid generation of unnecessary noise.

o Vehicles, power generators, pneumatic tools etc will be fitted with acoustic silencers or mufflers.

The generators during construction phase will be kept within enclosures to minimise noise.

The construction workers will be provided with adequate hearing protection devices for working in

high noise areas;

Vehicles will not be fitted with pressure horns.

Where required, local hoarding, screens or barriers will be erected to shield noisy activities.

The generator sets shall be installed in the canopy in safe area under a shed. The noise limits of the

total skid shall not be more than 85dB (A) at 1 meter distance from the edge of the canopy.

The sound proofing shall be provided together with weatherproofing as unique enclosure for

personnel sound protection and machine’s protection against sand storms and rainfall. The

enclosure shall be designed in such way to ensure as minimum the following:



o Adequate ventilation of the inner space (forced type, 20 air replacement/hour)

o Adequate equipment for fire prevention/alarm and extinguishing. Device for explosion limit

monitoring shall also be included.

o Stability calculated at the wind load mentioned in the Plant environmental conditions

o Vibration isolation from piping and equipment

o Adequate access doors and lighting for regular operation/ maintenance

o Joints between component panels shall be designed as “easy-to-dismantle”, for the case of

emergent intervention to the machine or for regular Inspections and Maintenance.

Compliance monitoring will be done by the proponent and its contractors to check and ensure

compliance with mitigation measures outlined above.

Noise measurements will be undertaken during key construction activities especially during

construction near the sensitive receptors and communities.

IMPACT DURING OPERATIONAL PHASE

Noise Sources: The main noise generating sources from coal based power plant are turbine, boiler feed

pump, air compressor, pumps, forced draft fan, induced draft fan, primary air fan and coal mills.

Intermittent noise is generated due to operation of diesel generator.

Impact on Noise Level: Any industrial complex in general consists of several sources of noise in clusters

or single. This clusters/single source may be housed in buildings of different dimensions made of

different materials or installed in open or under sheds. The material of construction implies different

attenuation co-efficient. In order to predict ambient noise levels due to the proposed power plant the

noise modeling has been done. For computing the noise levels at various distances with respect to the

plant site, noise levels are predicted by a user friendly model the details of which are elaborated below.

Model for Sound Wave Propagation during Operation: For an approximate estimation of dispersion of

noise in the ambient air from the point source, a standard mathematical model for sound wave

propagation is used. The noise generated by equipment decrease with increase distance from the

source due to wave divergence. An additional decrease in sound pressure level with distance from the

source is expected due to atmospheric effect or its interaction with objects in the transmission path. For

hemispherical sound wave propagation through homogenous loss free medium, one can estimate noise

levels at various locations, due to different sources using model based on first principles, as per the

following equation:

Lp2= Lp1 - 20Log (r2/r1)-AE - AM (1)

Where,

Sound Lp2 and Lp1 are the Sound Pressure Levels (SPL) at points located at a distances of r2 and r1 from

the source. AE & AM are attenuations due to Environmental conditions (E) and Machine correction (M).

The combined effect of all the sources can be determined at various locations by the following equation.

Lp (total) =10Log (10 (Lpa)/10 + 10 (Lpa)/10 + 10 (Lpa)/10 + ...............) (2)

Where Lpa, Lpb, Lpc are noise pressure levels at a point due to different sources.



Machine Correction (AM)

The background noise level, when the machine is not in operation should be determined at one or more

locations while conducting the test. The readings at each location, with the machine in operation should

exceed the background levels by at least 10 dB in each pressure level of interest. If the difference is less

than 10 dB, correction should be applied. If the difference between the measured sound and the

background sound in any sound pressure level is less than 3 dB a valid measurement of the machine

cannot be made. In order to reduce background noise to acceptable levels, it may be necessary to

acoustically treat the equipment.

Environmental Correction (AE): The equivalent sound pressure level can be calculated from the

measured sound pressure level (Leq measured) averaged over the measurement surface area 'S' and from

corrections K1and K2 and is given by;

(Leq calculated) = (Leq measured) – K1 – K2

Where,

K1 = Factor tor the background noise correction. The correction was not applied in this modeling

exercise, as it was not possible to measure the background noise levels by putting off machines. Hence

it was considered as zero.

K2 = Environmental correction

Model Details: Based on the above equation user friendly model has been developed. The details of the

model are as follows:

Maximum number of sources is limited to 200;

Predicted Noise levels at any distance specified from the source;

Model is designed to take topography or flat terrain;

Co-ordinates of the sources in meters;

Maximum and Minimum levels are calculated by the model;

Output of the model in the form of isopleths; and

Environmental attenuation factors and machine corrections have not been incorporated in the

model but corrections are made for the measured Leq levels

Input for the model: The design noise level for the various equipments tor LECPP are given in Table 6.8.

Table 6.8 - design noise level for the various equipments for LECPP

S. No. Source Noise Level Leq in dB(A)

1 Turbine Hall 90

2 Boiler Feed Pump 90

3 Circulating Water Pump 90

4 Primary Air Fan 90

5 Force Draft Fan 90

6 Instrument Air Compressor 90

7 Diesel Generator 85

8 Induced Air Fan 85



Presentation of Results

Ambient Noise Levels: The ambient noise levels have been predicted with proposed value for LECPP.

The predicted noise levels at the boundary of the plant in different directions are given in Table 6.9. The

ambient noise level recorded during field studies in the nearby areas located at a distance of 150 m from

the site ranges between 48 - 57dB(A). The predicted noise level due to operation of such equipment at

a distance of 150 from the source is 45 dB(A). As the ambient noise levels are higher than the predicted

noise levels, due to masking effect, no increase in the ambient noise levels during operation of the

project is anticipated.

Table 6.9 - Predicted Noise Levels

S. No. Distance (m) Noise Level dB(A)

1 150 45.1

2 200 42.8

3 300 40.3

4 400 39.1

5 500 37.5

6 600 35.3

7 700 33.3

8 800 32.1

9 900 30.9

Industrial Noise Standards: The OSHA has recommended permissible noise exposure limit for Industrial

worker which is based on 90 dB (A) for 8 hours exposure a day with 5 dB (A) trading rates. The limits are

given in Table 6.10.

Table 6.10 - Permissible Exposure Noise Limits

Total time of exposure per day in hours Sound Pressure Level dB(A)

8 90

6 92

4 95

3 97

2 100

1 105

½ 110

¼ 117

Work Zone Noise Levels: The protective measures need to be provided to the operators and workers

working near the high noise generating machinery. As per Occupational Safety and Health

Administration (OSHA) Standards, the maximum allowable noise level for the workers is 90 dB CA) for 8

hours exposure a day. Therefore, adequate protective measures in the form of ear muffs/ear plugs to

the workers working in high noise areas need to be provided. In addition reduction in noise levels in the

high noise machinery areas could be achieved by adoption of suitable preventive measures such as use

of enclosures with suitable absorption material, etc. Further, in addition to the in plant noise control

measures, all the open areas within the plant premises and all along the plant boundary will be provided

with adequate green belt to diffuse the noise.



Figure 6.5 – Noise Contour Map for Operational Phase



6.9 IMPACT ON TERRESTRIAL ECOLOGY


About 250 acres of land has been acquired for the project. However, as the land identified is barren, and

free from human habitation, forests and agricultural fields, the direct impacts on ecology of the study

area (e.g. loss of flora and fauna) is likely to be insignificant.

As the study area is devoid of natural forests, the overall impacts on terrestrial ecosystem will be

negligible. Removal of topsoil often leads to soil erosion. Deposition of fugitive dust on pubescent leaves

of nearby vegetation may lead to temporary reduction of photosynthesis. Such impacts would,

however, be confined mostly to the construction phase and would also be regulated and minimized

through adoption of control measures such as paving and surface treatment, water sprinkling and

plantation schemes. The impact would generally be restricted to surrounding flora within the plant

boundary and on the immediate agricultural field.


Particulates and sulphur dioxide are major air pollutants of a coal based thermal power plant. The impact

on the terrestrial ecosystem due to operation of the thermal power project may occur from deposition

and absorption of air pollutants on flora and soil surfaces.

Deposition of fly ash on leaves may interrupt gaseous exchange through stomatal clogging, thereby

affecting plant growth However, the impact due to operation of the project is envisaged to be negligible,

as incremental ground level concentration ofPM10 due to emissions from the project is predicted to be

1.3 µg/m3 only. The predicted maximum incremental ground level concentration of SO2 due to

operation of project is 15.1 µg/m3 and maximum ground level concentration of SO2 after operation of

the project is predicted as 27.16 µg/m3. This is well within the Sindh Ambient Air Quality Standards.

A 100 meter wide green belt shall be developed all around the project and extensive afforestation shall

be undertaken within main plant, township and ash disposal areas. Such activities would help

ameliorating the impact and improving the environmental quality of the surrounding area. It is

envisaged that the plantation in and around the project site would act as sink to pollutants.

6.10 IMPACT ON AQUATIC ECOLOGY


The runoff from construction area may lead to a short-term increase in suspended solids and decrease

in dissolved oxygen near the discharge point in receiving water body. This may lead to a temporary

decrease in the photosynthetic activity of phyto-planktons, rise in anaerobic conditions, habitat

destruction and food chain modification. However, for major part of the year during construction phase,

no detectable impact is expected because water quality will not change significantly.


LECPP Project will draw water from the Kadiro Creek, so there is a likelihood of entrapment or

impingement of phytoplankton/zooplankton in the water intake system. The provisions of trash rack

shall be kept in the intake water pump house, which will further reduce impacts, if any.



A small quantity of treated effluents conforming to the regulatory standards shall only be discharged

into Kadiro Creek. It has been concluded that there will be no significant impact on the water quality due

to discharge of effluents. It may, therefore, be concluded that there would be no impact on aquatic life.

Appropriate mitigation measures will be adopted including compensation by replanting 5 mangrove

plants for each plant removed, if any, due to Project activities. This can be done in another part of the

coast under the supervision of independent observers such as IUCN-P (International Union for

Conservation of Nature) and WWF-P (World Wide Fund for Nature). Moreover, a monitoring program

to study the abundance of Avicennia sp in the Project vicinity should be initiated.

The fish, crabs and crustaceans provide a source of livelihood for the local fisher folk in the vicinity of the

Project and habitat loss can lead to a decline in their abundance and diversity. The local fisher folk use

small gill set nets across small tidal creeks to trap between 2-10 kg of fish in a day mostly mullets (Mugil

cephalus) during ebb and flow tides. The local fishermen are also engaged in catching undersize juveniles

of fish that is converted into trash fish, swimming crabs (Portunus pelagicus) and juvenile shrimps

(Metapenaeus spp) from the area. The land reclamation will lead to short-term decline in the abundance

of these species of economic importance. Long-term impacts can be avoided by limiting reclamation

and construction activities during the spawning period of coastal fish. None of these species are included

in the IUCN Red List 2012 and are abundantly found in other parts of the coast. The fish and to some

extent the other species are likely to avoid disturbance and move to a less disturbed area.

The following mitigation measures are proposed:

To the extent possible, avoid construction and reclamation activities during the spawning period of

coastal fish (July - August)

For any mangrove plant destroyed due to Project activities, plant five mangrove seedlings in another

part of the coast in presence of independent observers such as IUCN-P, WWF-P and provides

necessary care until they reach maturity.

Initiate a quarterly monitoring program to study the abundance of Avicennia sp in the Project vicinity

6.11 DISPOSAL OF WASTE


The construction activities will generate considerable amount of waste. An inventory of the waste will

be prepared. The waste will includes metals (mainly iron and copper), concrete, wood, cotton, plastic,

packing materials, electronic, and insulation material. Several types of hazards are associated with the

wastes. For example:

Sharp edges in metals

Tripping hazards if material is left in the pathways

Soil contamination from leaking oil from equipment

Slipping hazard from oil on floors

Potentially toxic content

Dust and soot

Respiratory disorders



All recyclable material, such as metals (mainly iron and copper), will be recycled through waste

contractors. A comprehensive waste management plan will be instituted during which re-use

opportunities for waste generated from the plant during routine operation and maintenance will be

actively investigated. Hazardous waste identified, if any, will be stored in separate designated and

contained facility and disposed of in accordance with the regulatory requirements and safe practices.

An EPA certified contractor will be hired for disposal of any hazardous waste.


If the waste generated during the operational activities is disposed of in the creek, the marine life

consisting of the marine benthic invertebrates, phytoplankton, mangroves and fish will suffer negative

impacts especially if the waste contains oils, hazardous chemicals and toxic metals. If the edible species

of fish and crabs are contaminated, the negative health impacts will be transferred to other organisms

in the food chain including humans.

The proposed LECPP Project is not expected to change the pollutant load and no untreated liquid

effluent will be discharged into the creek. However, it is recommended that all measures outlined in the

Waste Management Plan for Project construction and operation be implemented to ensure minimal

pollution of marine waters.

The marine ecological resources including the mangrove plants, MBI, fish, crabs and shrimps may also

suffer harm from the coal dust and ash dust generated as a result of project activities. Leakage from the

prospective ash disposal site due to seepage or an accident may release toxic or hazardous materials

into the creek water, negatively impacting marine biodiversity.

Good practice measures will be adopted including:

Waste management measures outlined in the Waste Management Plan.

Monitoring of liquid effluents from Project to ensure they meet the SEQS.

Monitoring of gaseous emissions including coal and ash dust

Monitoring to ensure that there is no leakage from the ash disposal site.

6.12 ASH HANDLING AND UTILIZATION

The annual ash produced from the coal boiler could be several hundred thousand ton based on the ash

content of the coal. In order to avoid airborne dust about 99.9% fly ash shall be captured in the ESP. The

fly ash collection and disposal system will transfer particulate collected from the boiler flue gas to a fly

storage silo for unloading into trucks to carry the ash to the Lucky Cement factory in Karachi. Fly ash will

also be collected throughout the flue gas system by means of ash hoppers at other locations such as the

air heaters.






Use of fly ash in cement have the following advantages:



Reduction in heat of hydration and thus reduction of thermal cracks

Improves soundness of concrete mass.

Improved workability / pump ability of concrete

Converting released lime from hydration of OPC into additional binding material – contributing

additional strength to concrete mass.

Pore refinement and grain refinement due to reaction between fly ash and liberated lime improves

impermeability.

Improved impermeability of concrete mass increases resistance against ingress of moisture and

harmful gases resulting in increased durability

Reduce requirement of cement for same strength reducing cost of concrete.

Environmental benefits:

o Reduce cement requirement

o Less emission of carbon

6.13 GREENBELT DEVELOPMENT

About 25% of total land area will be developed as green belt, lawns and other forms of greenery. Over

10,000 trees will be planted in and around the project area. The main objective of greenbelt is to provide

a barrier between the sources of pollution and the surrounding habitation. The greenbelt will help to

capture the fugitive dust and attenuate the noise apart from improving the aesthetics. Greenbelt and

greenery development also prevent soil erosion and washing away of top soil besides helping in

stabilizing the functional ecosystem, make the climate more conducive and restore water balance.

6.14 EXPLOSION RISK AND PREVENTION

Two explosion risks exist with firing pulverized coal; dust and methane. Adherence to the National Fire

Protection Association requirements and guidelines, in particular NFPA 8504 and NFPA 6545, reduces

the risk of explosion hazards. These documents cover all aspects of the generating facility including:

Fire Risk Control program

General Plant Design

General Fire Protection Systems and Equipment

Identification of and Protection against Hazards

Fire Protection for the Construction site

The methane risk is addressed by proper ventilation of enclosed coal storage spaces. In regards to coal

dust, the NFPA addresses:

Coal storage and cautions about spontaneous heating and how that can be limited in the coal pile

storage through separation of different types of coal that are not chemically compatible, working

the pile to prevent dead pockets of coal, and locating the pile away from heat sources

4 Recommended Practice for Fire protection for Electric Generating Plants and High Voltage Direct Current Converter Stations 5 Standard for the Prevention of Fire and Dust Explosions from the Manufacturing, Processing, and Handling of Combustible Particulate Solids



Storage in bins, silos and bunkers including the provision of dust tight barriers between boiler houses

and the area above the silos, bunkers, or bins

Dust suppression and control including methods to control dust, proper cleaning methods, warning

against the use of vigorous sweeping or compressed air and the use of listed vacuum cleaners for

the dust environment or the use of low velocity water

Coal conveying and handling structures with attention to designing the structures to limit the ledges

for the accumulation of dust by utilizing beam shields or placing the structural members exterior to

the building;

Use of approved equipment in the areas, the electrical classification of the areas and means to

reduce the hazard of static electricity through permanent bonding and grounding

Fire protection being recommended in coal handling structures, conveyors, bag-type dust collectors

An important risk mitigation is keeping the area free of combustible dust and ensuring that proper

methods are employed through the use of a Fuel Handling Housekeeping procedure which calls for daily

wash down, reporting of fuel spills, and cautions involving hot fuel. Large fuel spills and dust

accumulations should only be removed utilizing non-sparking tools or water hoses. The use of

compressed air is strictly prohibited. Vacuums must meet the proper classification to be used.

Vacuuming by a contractor who specializes in the removal of coal dust is acceptable if they have written

procedures for the activity that have been reviewed and approved by the site’s coal dust coordinator.

This includes ensuring that the vacuum truck is grounded and the area is watered down initially and

during operations. The vacuuming is not of dry dust but wet coal/dust.

6.15 SOCIOECONOMIC IMPACT

The Project activities will result mostly in positive impact on the existing socioeconomic environment of

the project area. The Project will contribute to stimulating economic growth through employment and

outsource opportunities for in–country suppliers, increase in the stock of skilled human capital and

enhancement in labor–productivity due to transfer of knowledge and skill under the Project. The major

socio economic impacts due to the Project activities include: (i) The reduction in power generation cost

due to use of cheaper source and consequent benefit to the citizens; and (ii) Employment opportunities

mainly during the Project‘s construction phase benefitting the labor force in the project area.

No specific monitoring or mitigation measures is required for the impact as the Project will create

positive impacts by community development, empowerment of vulnerable groups through increased

participation in Project and economic decline at closure.

6.16 SAFETY & OCCUPATIONAL HEALTH

Plant operation will involve working on high height, near rotary machinery and parts, high voltage yards,

storage, handling and use of hazardous materials like heavy fuel, coal, chemicals, etc. These essential

components of the project may cause different types of hazards for example, fire, explosion, falls,

electrocution, intoxication/toxic exposure etc. and the consequences of these hazards may be health

injury, electrocution, organ disease outburst, loss of health, loss of life etc. Employees carrying

contagious disease may aggravate health problems. In addition with keeping all safety & precaution

measure, the proponent shall implement hazard and risk management plans - fire safety plan, explosion



safety plan, electrocution safety plan, medical emergency plan, hazardous material management plan

etc., to avoid these adverse impacts on occupation health.

Plant safety and industrial hygiene measures will be given utmost attention as per provisions stipulated

in the Factories Act. Hazardous chemicals shall be handled and stored in plant as per the guidelines

provided in Hazardous Substances Rules, 2014.

Fire protection with ring system and fire hydrant points at every 30 m intervals will be provided around

the coal storage yard. Adequate number of hand held fire extinguishers and wall-mounted CO2 fire

extinguishers would be kept at other locations to be used in the case of fire.

Workers exposed to mechanical accident-prone areas will be provided with personal protective

equipment (PPE). The non-respiratory PPE includes tight rubber goggles, safety helmets, welders hand

shields and welding helmets, plastic face shields, ear plugs, ear muffs, rubber aprons, rubber gloves,

shoes with non-skid soles, gum boots, safety shoe with toe protection which will be provided to workers.

All safety and health codes prescribed by the OSHA will be strictly implemented in the plant.

The work environment will be monitored for occupational accidents, diseases and dangerous

occurrences. A proper record of the same will be maintained. The following will be adopted to ensure

good health condition of employees.

Pre- employment checkup

Awareness programme

Routine checkup

Periodic vaccination programme etc.

A well-equipped medical center with adequate number of qualified medical staff will be available at the

plant. First aid facilities, medicines and ambulance are available to meet any emergency situation.



7.0 CONSULTATION & INFORMATION DISCLOSURE

This section presents the findings of the consultation meetings held with the project’s primary and

secondary stakeholders as part of the Environmental Impact Assessment (EIA) process requiring

information disclosure and sharing. For this purpose consultation meetings were held at the outset for

scoping of the EIA study, followed by a series of meetings at the grassroots level.

7.1 OBJECTIVES

The objectives of these meetings were to:

Share information with the gate keepers and area residents about the Lucky Electric Coal Power

Plant Project being established in the environs of Lath Basti in Bin Qasim Town of Karachi,

Inform the stakeholders of the positive and negative aspects identified for the project and the

environmental issues likely to emerge while the Project is in the pre-construction, construction and

operation stages.

Request the stakeholders to share their knowledge / information on significant physical, biological

and socioeconomic status of the micro and macroenvironment that must be taken into

consideration during the different stages of the Project, and measures to be adopted to minimize

the severity of impact;

Assess the level of awareness on the environment and the proposed project, and

Determine the impact of future development plans in the project area.

7.2 CONSULTATION FRAMEWORK

The consultation being a continuous process needs to be maintained throughout the project (Social

Analysis Sourcebook: Incorporating Social Dimensions into Bank-Supported Projects: The World Bank.

December 2003). The consultation framework adopted for the pre-construction, construction and

subsequent phases of the Lucky Electric Coal Power Plant Project is elaborated in the Table 7.1:

Table 7.1: Consultation Framework

Project Phase Proposed Tool Stakeholders Consulted/ to be Consulted

Responsibility

Pre-Construction

Formal and informal meetings, focus group discussions

Institutional stakeholders; Grass root stakeholders, including communities in neighbourhood likely to be involved during the Project Implementation Stage

EMC, LEPCL

Construction

i. Formal and informal contact and liaison with the community and other relevant stakeholders (e.g. Sindh EPA, NIO, WWF, IUCN)

i. Institutional stakeholders ii. Grass root stakeholders, including communities in neighbourhood involved during Project Implementation Stage

IMC, LEPCL

ii. Grievance Redress iii. Consultations with communities during environmental

Communities in neighbourhood involved during Project Implementation Stage

IMC, LEPCL



Table 7.1: Consultation Framework

Project Phase Proposed Tool Stakeholders Consulted/ to be Consulted

Responsibility

compliance & Impacts monitoring iv. during external monitoring v. during site visits by Equator Principles Financial Institutions (EPFIs) Monitoring Mission

Operation Liaison with communities in neighbourhood

Communities in neighbourhood Involved during the Project Operation Stage

IMC, LEPCL

7.3 CONSULTATION PROCESS

Initially public consultation in form of group discussions was carried out at different locations of the

project area during the preparation of the Environmental Impact Assessment (EIA) with a view to

minimize adverse impact of the project through creating awareness among the communities on

potential benefits of the project. The meetings with communities were held during the months of Dec

2014 and January 2015. Moreover, the Scoping session with major stakeholders was conducted on

December 22 2014 at Pearl Continental Hotel, Karachi.

Group discussions and consultation meeting were conducted with stakeholders particularly with

Information secretary PPP District Malir (resident of lath basti), Director Fishermen’s Co-operative

Society Ltd, Vice Chairman of Fisherman Association for Rural Development, Ex-General Secretary

Pakistan Fisher-folk Forum (PFF) Ibrahim Haidery, Health Specialist of Rehri Health Development

Organization (RHDO) and Fisherman’s Association for Community Empowerment (FACE), Rehri.

For this purpose semi structured questionnaires were used for data collection. These questionnaires

consisted of open and close ended questions. The consultation team consisted of Environment & Social

issues specialists and enumerators. In most cases, the team was accompanied by a local representative.

The local representatives were instrumental in the selection of venues and timings for the meetings and

focus group discussions. Local CBOs played a vital role to mobilize the community to attend public

consultation meetings.

The comments expressed by the participants at public consultation and focus group discussions were

noted (an outline of issues and concerns expressed by individuals, the community, NGOs and public

agencies is detailed in the following table and elsewhere in this section). Similarly, the comments made

by stakeholders at scoping meeting were noted. These comments have been analyzed as

socioeconomically viable statements of the participants and have been reflected in the detailed

engineering design as much as possible.

Since these consultation meetings / FGDs were an open forum for all, there was a representation from

all groups by language, age and income levels. This is a continuous process and will be continued until

the issues pertaining to pre-construction, construction & operational phases of project are settled to the

reasonable satisfaction of stakeholders, especially the affected local communities if any. The result of

the consultation was a clear identification of the issues perceived to be important by the community

and stakeholders and the need to respond to those issues in the EIA. Mitigation of potential



environmental effects of concern to the community and other stakeholders has been incorporated into

the project planning and will occur throughout the construction and operational phases of the project.

The stakeholders were briefed during scoping sessions about the background and objectives of the CPP

Project, its needs, and the necessity of introducing the EIA process. Observations of the participants

were noted and have been incorporated into the text of the EIA. At the consultation meeting the

stakeholders and area representatives were informed that:


inexpensive and affordable electricity for domestic, commercial, and industrial use by using

indigenous resources such as coal (Thar coal) and hydel power, ii) address the key challenges of the

power sector in order to provide much needed relief to the citizens of Pakistan, and iii) shift

Pakistan’s energy mix towards cheaper fuel, and conservation of natural resources.

Figure 7.1 - Goal and Strategy for Affordable Power in National Power Policy (2013)

Pakistan is experiencing the worst ever energy crisis in its history, since the industrial production has

slowed down to a grinding halt, the fuel resources have been exhausted and new finds are only

slowly been commissioned, in the meantime the vegetative cover has been deforested and the land

has been desertified. The availability of water resources has been erratic all along. The hydrological

potential is decreasing both because of losses and lack of good governance. The gap between

availability of electric power and demand has widened. On the one hand the current shortfall of

5,000 to 7,000 MW is continuing and on the other hand the circular debt arising out of withholding

of payments by the public sector is hampering the cash fluidity which could sustain even the present

shortfall.

Power outages have gone up from six hours to eight hours in the urban area and 14 hours to 18

hours in the rural. This is not all because in the winter the outage had increased to 12 hours in the

urban & industrial area. This is the result of ad-hocism because the gap between supply and demand

was of consumerism. Unfortunately additional power generation facilities were not introduced,



alternative energy sources if identified were not adopted/implemented with the result that the

existing power production units went idle during the last decade.

The Nexus of Climate Change - Environmental degradation - Poverty is caught in the cobweb of

Social Pollution in that impoverishment of resources leads to environmental disasters which in turn

lead to poverty and the vicious circle repeats when poverty leads to continuous impoverishment.

The status quo just cannot continue because the country is falling deeper and deeper into debt while

the current resources are being impoverished at a very fast rate. Indigenous Coal has remained a

disregarded resource and steam coal is being imported for cement and power production. The

technology for utilization of lignite at Lakhra was inappropriately transferred with the result that

only one of the three units could operate ever since its adoption. The present position is that the

Lakhra Power Plant is unable to continue to generate electricity even at the current low capacity,

inefficiency, non-availability of fuel and cash starvation. Such being the case the Government of

Pakistan has in September 2013 introduced the policy on developing coal-fired thermal power

plants gradually substituting the fuel with the coal reserve in the Thar coalfield.

Coal has traditionally been the most widely used source of energy in the world followed by oil and

gas which are cleaner and more convenient fuels. However, the last two are much more expensive

fuels compared to coal which is by far the cheapest, barring hydel and renewable energy.

Technological development has also helped make coal a cleaner fuel and it is still being widely used

in the world for power generation and other purposes. China, US and India respectively produce

63%, 36% and 47% of their electricity from coal. Australia and Germany also use coal to produce

substantial amounts of electricity. Pakistan has not paid much attention to coal development as a

fuel for industry and power sector although we have estimated reserves of 187 billion tons which

are said to be the second largest in the world.

Figure 7.2 - Pakistan’s Energy Mix

Hydro31.93%

Gas28.73%

Fuel Oil35.50%

HSD1.07%

Coal0.1

Nuclear2.35%

Imports0.30%



South Africa 93% Poland 94% PR China 79%

Australia 78% Kazakhstan 75% India 68%

Israel 58% Czech Rep 51% Morocco 51%

Greece 54% USA 45% Germany 41%

Figure 7.3 - Coal – Worldwide in Electricity Generation

Coal is one of the world‘s most important sources of energy, fuelling almost 40% of electricity

worldwide. In many countries, this figure is much higher: Poland relies on coal for over 94% of its

electricity; South Africa for 93%; China for 79%; and Australia for 78%. Coal has been the world‘s

fastest growing energy source in recent years - faster than gas, oil, nuclear, hydro and renewable

sources.

In order to contribute toward meeting Pakistan’s growing electricity demand, Lucky Electric Power

Company Limited (LEPCL) proposes constructing a 660 x1 MW coal base power station near Port

Qasim Karachi. LEPCL has acquired 250 acres of land from Sindh Board of Revenue for the

establishment of proposed power plant.

The Project will involve the following components:

o Super-critical boiler

o Coal transportation, handling and storage

o Water supply and waste water system

o Ash handling system

o Emission control system

o Flue Gas Desulfurization (FGD) system

o Coal for the power plant will be received at the coal yard inside the plant. It will be processed

before feeding into the boiler. Heat from the combustion of coal in the super-critical boiler

will be used to generate steam at high pressure. The steam will then be fed into the steam

turbine, where it will rotate the turbine to generate mechanical energy. The steam, after

passing through the turbine, will be reheated by re-injecting into the boiler. The rotating

steam turbine will operate the power generator, which will generate electricity.

o Flue gas from the boiler is normally laden with pollutants, oxides of nitrogen, particulate

matter and sulphur dioxide. The gas will be passed through a series of treatment units before

being discharged into the atmosphere. In the treatment system, pollutants from the gas will

be removed.

o Cooling water is required for cooling purposes in the operations of the power plants. The

water is obtained from the cooling water system. The water source for the proposed project

will be the Arabian Sea.



o Bottom ash from the boiler and fly ash from the flue gas treatment system will be collected

and disposed of through the ash handling system. The proposed project will require several

supporting systems for plant operations. These include the seawater desalination system to

provide water for feeding the boiler, the effluent treatment system, wastewater treatment

plants and waste disposal systems for the wastewater and ash generated by the plants and

associated facilities.

Construction and Operation of the LECPP will require the following environmental issues to be

addressed:

o Land reclamation

o Site clearance leading to dust emission

o Removal of vegetation leading of loss of vegetation cover

o Erosion and sedimentation

o Air quality impact from operation construction machinery

o Noise and vibration

o Waste management

o Off-site impacts such as those related to borrow pits

o Effluent from construction camp

o Cultural impact related to presence of non-local workers

o Transportation and storage of coal

o Ash handling and disposal

o Air emissions

o Waste Water Discharge

Concerns expressed by the public/stakeholders during different meeting and focus group

discussions are presented below:

o No developmental activity of the past has ever benefitted locals. Instead, after Port Qasim

channel’s development, the fishermen have been forbidden to trespass the channel and have

to travel a long distance to reach the open sea which costs so much that they can barely pay

the fuel cost from the profit of fish caught. A plan should be worked out in consultation with

PQA for local fishermen so that they can economically reach the deep/ open sea as they used

to go before development of PQA channel.

o Since the development of Bhains Colony, the wastewater that falls untreated into the sea has

severely polluted the water at the outfall of Lath Basti and fishes can no longer survive. A

treatment plant must be installed for the wastewater before the outfall so that the water

quality is restored. A wastewater treatment should be setup for the wastewater of Bhains

Colony so that natural environment can be restored

o The polluted water contains chemicals and insects born out of cow dung which has severely

impacted the livelihoods of all local fishermen as the service life of their boats which previously



could last a decade, now lasts merely 2 years. All effluent wastes should be monitored at

Bhains Colony farms and they should be heavily penalized for discharging any chemicals

exceeding SEQS limits.

o Whenever there is any development project underway, new promises are made, but all

promises made in the past are forgotten shortly. LEPCL cannot force the fulfillment of

promises made and broken by proponents of other projects, but assures that whatever

promises it will make with the locals shall be duly fulfilled.

o The locals are unskilled in fields other than fishing. As fishing is no longer possible after the

government put a ban for the last 4 months they urgently want some form of employment.

Capacity development programs shall be undertaken under the CSR policy of LEPCL and

whenever possible, locals shall be preferred over outsiders for skilled/ unskilled jobs as per

the qualifications and requirements.

o There is no hospital anywhere nearby neither any ambulances standby or that can reach in

less than an hour or two. In emergencies for example, the women have to wait hours before

they can reach a hospital for deliveries.

o A majority of children do not have any schools to go besides two, where teachers barely come

for 2 to 3 hours only and have to teach without a roof and any proper facility. There is currently

no school for girls in the area.

o Since the development of Bhains Colony, Hepatitis A, B and C have spread like an epidemic

and according to HANDS, an NGO working in the area, about 75% of the Lath Basti’s

population is now suffering from it which is due to polluted water that comes from Bhains

Colony.

o Sewage system is one of the biggest issues of Lath Basti as it is near to non-existent. The

women have to wait until dark to go outside and relieve themselves in the open. It is a bitter

reality they have to face every day.

o Another issue that has risen is the dumping of dirt in Rehri from reclamation activities. The

authorities have taken no action over this dumping and instead, due to their high-level

contacts, the developers have gotten away without any penalties.

o The stakeholders were informed their concerns have been addressed through project design

as well as environmental management and monitoring plan.

o The village representatives gave firm assurance that there would be no hindrance to

completion of the project from any stakeholder provided they are treated with respect and

given whatever is their due. They would be happy if employment was offered to their

youngsters and petty contract to local residents.

Concerns expressed by the stakeholders during scoping meeting are presented below:

o Representative from Engro Polymers Limited expressed concerns regarding coal handling and

transportation and subsequent disposal of ash. It was replied that a screw type un-loader will

be used with closed conveyor belts with dust suppression systems for minimum and

internationally practiced transportation of coal. On question of maximum GLC it was

explained that CPP will be so designed that fall-out of the emissions from the plant does not



go beyond the macroenvironment of the project and that the maximum ground level

concentration is well within the acceptable limits for ambient air quality. The incremental

impact shall be assessed using mathematical modeling tools. A water treatment plant will be

constructed at the plant site which will ensure the effluents meet the NEQS limits.

o Representative from Pakistan International Bulk Terminal (PIBT) recommended the utilization

of PIBT (an under-construction port) to be used for importing coal and also asked about the

type of fire prevention system to be installed for the conveyor. The proponent replied that

they are currently the largest coal consumer in the country and in future the demand will

further grow so it is economically more viable to operate without any dependency.

Internationally accepted NFPA standards shall be followed for fire prevention and control.

o Representative from World Wide Fund for Nature (WWF) Pakistan inquired about the

methodology for air dispersion and plume modeling to be used for the study and that

whether marine benthic fauna and fishes would be included in the study. It was replied that

thermal plume modeling shall be carried out using CORMIX and air modeling will be done

using US-EPA recommended applications for predicting the respective impacts. Fauna and

flora including the marine benthic will all be studied.

o Representative from National Institute of Oceanography (NIO) asked that why is Thar coal not

being considered instead of imported coal and showed concerns for the disturbance which

will be caused by dredging activity and temperature rise. The proponent replied that they

currently suffer from inadequate transport facilities offered by local transporters. If Thar coal

is procured, there will not be enough transporters; besides Thar coal has consistency issues.

There will be very little dredging done as existing PQA channel shall be used by the coal

vessels. Besides, all dredged material will be used for land reclamation for the project.

o Representative from Thar Coal Energy Board (TCEB) informed about the myths surrounding

the Thar coal quality and expressed that Thar it should be considered seriously as an option.

Also suggested that trace elements may be extracted from coal ash and turn waste into an

asset. Coal ash should be used as an aggregate in cement manufacture as is the international

practice. Lucky Cement, a sister company will utilize 100% of ash without any problem

o Representative from Institute of Space Technology (IST) expressed concerns for pollution free

transport of coal ash to cement factories for recycling. It was replied that The coal ash will

always be transported in the same sealed trucks in which cement is transported

o The stakeholders were briefed on the Environmental Management Plan of which process of

monitoring is an effective tool that keeps track of environmental performance throughout the

lifecycle of the Project. The stakeholders and village representatives consulted in this

connection assured their unhindered support towards completion of the Project.

7.4 COMMUNITY ENGAGEMENT RESPONSIBILITIES

LEPCL is committed as well as required under its environmental approvals from the Sindh Environmental

Improvement Agency to:

create “no threat to livelihood of local communities”

repair/compensate any damages to community assets caused by project components



employ an Independent Environmental Monitoring Consultant for the life of the project who will

submit quarterly reports on LECPP Project activities.

In addition, Environmental Management Plan identifies a Site Environmental Coordinator charged with

monitoring and evaluating permit compliance and environmental impacts associated with constructing

and operating the project.

LEPCL has to designate a Community Liaison Officer (CLO), reporting to the Project Manager, who is

tasked to help manage and facilitate communications with the local community, including people

making their living from agriculture and farming. The CLO’s duties include providing the main point of

contact with the local community, and transmitting concerns and complaints to the projects’

management structure. The CLO is responsible for actively identifying and communicating with local

community leaders, NGOs active in the area and loosely affiliated common-interest groups. The CLO is

available to address questions about and concerns with project activities, and to provide information

about jobs (especially during construction), opportunities to provide goods and services to the project,

and opportunities for the project to pro-actively engage in promoting the health, welfare and quality of

life for the local community. The CLO is charged with creating a positive relationship between the

project, its contractors and the local community, managing and planning future public consultations,

disclosure meetings and events, maintaining records, and leading dispute resolution proceedings. The

CLO is responsible for implementation of the Community Grievance Procedure outlined below.

The CLO is responsible for communicating job and economic opportunities to the local community. His

duties include establishing good relations with the local community and to act as a ‘clearing house’ for

questions about how to apply for jobs, how to become qualified for bidding on provision of goods and

services to the project, and similar economic opportunities. The CLO and stakeholders will together

develop a list of economic opportunities targeted toward the local community to help create goodwill

towards the project.

The following compensation plan has been adopted by LEPCL in response to project concerns expressed

during the initial consultation process:

Separate funds allocated to initiate public welfare programs.

For all unskilled jobs, the project will attempt to fill those positions from local applicants.

Local community leaders and first responders will be informed and updated regularly on emergency

response procedures.

The project’s Community Grievance Procedures will be easy to participate in and free of cost.

In addition to proposed project activities, the Project Contractor shall:

o be responsible for community affairs as it relates to industrial relations, human resources,

procurement, and sub-contracting associated with the Contractor’s Work;

o establish community affairs office(s) as appropriate to support the Contractor’s community

affairs activities. Such offices shall be located at sites that facilitate effective management of

community affairs, industrial relations, recruitment and hiring without disrupting the Work;



o work with appropriate community leaders to reduce the adverse effects of their activities on

the community, and to facilitate resolution of community unrest and disruptions resulting

from Contractor’s performance of the Work;

o confirm that its personnel and the personnel of its sub-contractors are appropriately qualified

and trained to be aware of and manage local cultural issues to the extent required to minimize

and manage local community disruptions arising as a result of Contractor’s performance of its

Work. LEPCL shall provide induction materials for new workers and necessary briefings for

workers and Contractor(s) as required;

o comply with the Community Grievance Procedures detailed below.

o gain the prior approval of LEPCL before making any direct agreements with local

communities.

7.5 TRAINING ON COMMUNITY RELATIONS

The CLO is responsible for ensuring that LEPCL and the Contractor(s) workers and subcontractors receive

adequate training in project-specific community relations, so as to be aware of health, safety and

security issues as well as the standard of conduct expected when engaging with the community.

Induction training for all new workers shall be provided and will cover at a minimum:

General liaison and interaction with communities;

Cultural sensitivities;

Awareness-raising on health, safety and security considerations;

Project Code of Conduct.

Additional training on community relations will be delivered through:

Tool Box Meetings;

Safety, Security, Health and Environment Safety Committee Meetings;

In-House Training / Seminars;

Notice Boards; and

Newsletters.

7.6 STAKEHOLDER ENGAGEMENT PLAN FRAMEWORK

7.6.1 OBJECTIVES AND PRINCIPLES

LEPCL will establish a Stakeholder Engagement Plan (SEP) that will be applicable for the entire project

lifecycle. The Stakeholder Engagement Plan will consider the analysis, mapping and feedback of

consultations that have been undertaken for the project thus far.

The SEP will take into consideration the applicable legal framework for public disclosure in Pakistan. The

main objective of the SEP will be to increase the effectiveness of LEPCL’s relationships with all their

stakeholders.

This framework provides details on the general principles for LEPCL’s stakeholder engagement as well

as suggestions on the mechanisms and tools which can be used.



7.6.2 PRINCIPLES OF STAKEHOLDER ENGAGEMENT

LEPCL commits to the following principles for effective and long-term engagement:

Providing meaningful information in a format & language that is readily understandable and tailored

to the needs of the target stakeholder group(s);

Providing information in advance of consultation activities and decision-making;

Providing information in ways and locations that make it easy for stakeholders to access it and that

are culturally appropriate;

Respect for local traditions, languages, gender sensitivities, timeframes, and decision-making

processes;

Two-way dialogue that gives both sides the opportunity to exchange views and information, to

listen, and to have their issues heard and addressed;

Inclusiveness in representation of views, including ages, women and men, vulnerable and/or

minority groups;

Processes free of intimidation or coercion or incentives;

Clear and simple mechanisms for responding to people’s concerns, suggestions, and grievances; and

Incorporating, where appropriate and feasible, feedback into project or program design, and

reporting back to stakeholders.

7.6.3 IMPLEMENTATION PLAN

Based on the Framework for stakeholder engagement planning, LEPCL will develop a detailed

implementation plan with the following suggested information:

Identification of key stakeholders that LEPCL considers most relevant on the basis of those provided

in the EIA and developing mechanisms to engage with the same;

Structure a stakeholder engagement program that will describe the most culturally appropriate

mechanisms to consult the prioritized stakeholders;

Provide a schedule outlining dates and locations when various stakeholder engagement activities

will be conducted;

Indicate what staff and resources will be devoted to managing and implementing the company’s

Stakeholder Engagement Program;

Describe in detail the Grievance Mechanism that has been finalized by the senior management in

consultation with local communities;

Describe any plans to involve project stakeholders (including affected communities) or third-party

monitors in the monitoring of project impacts and mitigation programs.

The Implementation Plan will include a clear plan of actions with deadlines and responsibilities in order

to assure the maximum engagement level for all relevant stakeholders.



7.6.4 GRIEVANCE MANAGEMENT

LEPCL will adopt the Community Grievance Procedure outlined below, which requires interaction,

consultation, targeted information and timely resolution of legitimate grievances. This approach is

aimed at building a reputation of responsiveness, concern and responsibility among the community,

with a view to building and sustaining acceptance and support for the construction and operation of the

project.

LEPCL and its Contractor(s) shall foster a sense of working with the local community and demonstrate

that the Project takes a proactive stance to grievances.

LEPCL’s grievance management system and database will comply with and has the flexibility to feed

information into the Community Grievance Procedure. Proponent will also provide all Contractor(s)

teams with training in Community Grievance Procedures.

In implementing LEPCL’s Community Grievance Procedure, the Contractor(s) shall:

Record all grievances using the template Grievance Form;

Assess & advise the resolution of the grievance in the time frame required by the assessment.

All grievances will be investigated and a response (outlining a resolution) provided by LEPCL /

Contractor(s) as soon as possible and not more than 30 days after receiving the grievance. If more

time is required for resolution, the person raising the grievance and LEPCL shall be kept informed.

While the Contractor(s) is not prevented from initiating the grievance resolution, any corrective

action taken must be in coordination with LEPCL.

LEPCL, through the CLO, will ensure that the details of the Community Grievance Procedure are

publicized at community meetings and via posters and other means to all communities in the vicinity

of the project.

Grievance Registration

Complaint Redressal Process

Complaint Recording Complaint Resolution Monitoring, Reporting

&Complaint Analysis

Feed Back



In addition, LEPCL and its Contractor(s) shall ensure that the local populations working/residing in

the local area receive necessary information for contacting and initiating a grievance through

meetings, pamphlets and similar community outreach programs under the direction of the CLO.

LEPCL and its Contractor(s) shall ensure sufficient resources are allocated on an ongoing basis to

achieve effective implementation of this Plan. The Contractor Plan shall describe the resources

allocated to and responsibility for the execution of each task and requirement contained therein,

and shall describe how roles and responsibilities are communicated to relevant personnel.

7.6.5 COMMITMENT REGISTER

LEPCL should develop a commitment register to record, implement and track any public commitment

or request that is made to the project’s stakeholders. This includes any requests of direct development

interventions, expectations on employment, petty procurement etc.

7.6.6 ROLES AND RESPONSIBILITIES

Stakeholder Engagement will be on going throughout the entire project lifecycle and will be

coordinated across project activities and contractors by designated personnel the Community

Relations team. The Community Relations team will support the EHS Coordinator in implementing

Details of corrective action recorded

Outcome

accepted by

Complainant

Recorded outcome in Log Register and

Close Out Administrative, Judicial Proceedings

Recorded in Grievance Log Register

Supplementary actions (If any) and / or agreed by the GRU/ Complainant

Corrective action

implemented

Agreed corrective action, timeframe

and implementing department and

recorded in log Discuss proposed corrective action with

the Complainant

Reduce adverse effects or conflicts with

the complainant by adjusting procedures if

possible or otherwise required

Immediate and/or long term corrective actions agreed by

the GRU

Complaint received in

writing/verbal

Complaint Received

No Yes



the Environmental and Social Management and Monitoring Plan and will also lead the stakeholder

engagement process which will have the following tasks:

o Interface between LEPCL, contractors, sub-contractors and the local community;

o Disclosure of project specific information for all components to village settlements within the

footprint area and other external groups as required;

o Establish a mechanism to obtain, report, redress and monitor all grievances from the local

community;

o Regular engagement with key informants and local leaders to ensure a transparent feedback

process in to the project; and

o To plan, implement and evaluate community development programs.

The Community Relations Team will consist of Two (02) personnel who would coordinate with the

overall Environmental and Social Manager. This will include the Community Relations Officer and

the Human Resources Officer.

7.6.7 COMMUNITY DEVELOPMENT

LEPCL’s personnel have already commenced the process of early identification of community support

projects, such as drinking water and sanitation, and providing investment for the same. These activities

will be streamlined under the framework of stakeholder engagement to develop a detailed Community

Development Plan which looks into options of CSR activities and social investments and suggests models

of interventions to suit the needs of the community.

To the extent possible the CSR activities will be relevant to the needs of the locality and in no case should

be detrimental to the E&S sensitivities of the project area. These plans and activities are to be

implemented in consultation with the local community. The plan will also include indicators for regular

monitoring of these development activities in order to assess their impacts and to suggest changes in

the approach.

7.6.8 MONITORING AND EVALUATION

LEPCL will monitor the principles and commitments of the stakeholder engagement process and

will need to report on the status of implementation of different aspects, such as information

disclosure, grievance redressal, etc.

Engagement levels can be monitored by developing a set of indicators which will include:

o Number and Type of Communications and Issues discussed;

o Frequency of communications;

o Type, subject and number of grievances;

o Sources of complaints;

o Average time taken to resolve and close grievances;

o Number of presentations and frequency on EHS and economic status of the company;

o Number and diversity of stakeholders involved per action;

o Comments on any disclosed documents/presentations;



o Level/degree of involvement for stakeholders;

o Partnerships with stakeholders;

o Number of mass media articles/announcements.

7.6.9 PERFORMANCE INDICATORS

Table 7.2 outlines the indicators used for measuring and verifying performance in relation to community

engagement. However LEPCL may modify or add to these indicators to enhance the Plan based on

learning from the performance indicators.

Table 7.2: Performance Indicators

ID #

Performance Indicator Measurement Internal

Assessment Frequency

1 Maximize use of the Project Community Grievance Procedure.

100% of grievances (except those related to worker issues) channelled through the Community Grievance Procedure.

Monthly

2 Resolution of Community Grievances.

75% of grievances resolved (from the Project perspective) within 30 days, categorized according to cause of grievance.

Monthly

3 Disruptions to work.

Number of hours lost due to community disruption categorized according to cause of disruption (to be coordinated with Security departments to ensure consistent reports).

Monthly

4 Compensation payments. Amount of compensation paid as a result of Project impacts

Monthly



8.0 ENVIRONMENTAL MANAGEMENT & MONITORING PLAN

8.1 INTRODUCTION

An Environmental Management and Monitoring Plan (EMMP) is a management tool that helps ensure

that all reasonably avoidable adverse impacts of a project’s pre-construction, construction, operation

and decommissioning phases are prevented or mitigated. The main focus of this EMMP is not only the

protection of environment surrounding the proposed site, but also the long-term impacts on people

living in the immediate vicinity. This EMMP will assist in ensuring continual improvement of

environmental performance, reduction of negative impacts and enhancement of positive effects during

all the stages of this project.

8.2 SCOPE OF EMMP

The mitigation measures apply to the following four phases of the development process:

The Pre-Construction (Design) Phase: These measures relate to the detailed layout, planning and

design of the power plant and will largely be implemented by the planning and development team,

prior to the commencement of any physical on site activities.

The Construction Phase: These mitigation measures are applicable during site preparation and

construction of the power plant and must be implemented by the relevant contractors and sub-

contractors.

The Operations Phase: These mitigation measures are applicable during the long-term operation of

the power plant and must be implemented by the plant management.

A Conceptual Decommissioning Plan (CDP): This part provides the mitigation measures for an

environmental friendly decommissioning of the plant to be undertaken at the end of plant’s

designed life.

This EMMP mainly focuses on the following environmental aspects at each of the above mentioned

phases of the project:

Pollution prevention: Those aspects of planning and management which support minimization of

air, water and noise pollution and contamination of land.

Materials management: Those services or activities which support the reduction of resource

utilization or resource recovery (e.g. reuse and recycling) and environmentally sound disposal of

solid and liquid waste materials.

Contingency planning: Development of plans to tackle emergency situations likely to arise during

all stages of project such as fires, natural calamities etc.

Protection of ecosystems: Those aspects of management and maintenance which support

conservation and enhancement of biodiversity and environmentally sustainable use of open space

in the project area.

Health and Safety: The health and safety of all personnel associated with the project in any way as

well as those living in its vicinity.



Water management: All aspects of supply, usage and disposal of water/waste water and

application of conservation strategies in every possible manner.

Transport systems: Including all transportation aspects for materials as well as personnel.

8.3 OBJECTIVES OF EMMP

The objectives of this EMMP are to provide consistent information and guidance for implementing the

management and monitoring measures which will help achieve compliance with recommendations and

conditions specified through the EIA process as well as to ensure continuous improvement of

environmental performance, reduction of negative impacts and enhancement of positive effects during

the construction, operation and decommissioning of the facility.

The aims of this EMMP are to:

Ensure that all relevant legislations (including national, provincial and local) are complied with during

all the phases;

Identify entities that will be responsible for the implementation of the measures and outlines the

functions and responsibilities;

To propose mechanisms for monitoring compliance and prevent long-term or permanent

environmental degradation;

Ensure that the best management/ industry practices and best available techniques are

incorporated and implemented to minimize potential environmental and social impacts during each

phase;

Ensure that the project operation does not result in undue or reasonably avoidable adverse

environmental impacts, and that any potential environmental benefits are enhanced;

Enforce the company policies through training, supervision, regular reviews and consultation;

Adhere to high standards of safety and care for the protection of the Employees and public.

8.3.1 PROJECT

The proposed [1 x 660 MW] Lucky Electric Coal Power Project (LECPP] will be established over an area

of 250 acres of land acquired from Sindh BoR in Deh Ghangiaro, Bin Qasim Town, Karachi.

The boiler technology shall be based on super critical boiler parameters having higher thermal efficiency

as compared to conventional pulverized coal fired units. The increase in efficiency results in lower coal

consumption as well as lower generation of ash and gaseous emissions. Coal for the power plant will be

made available through Indonesia, South Africa or Australia.

8.4 EMMP PROCESS

The EMMP Process consists of the following areas and defines the methods and procedure for its

implementation.

Organizational Structure

Requirements for implementation of EMMP

Mitigation measures and Impacts management



Monitoring plan with Emphasis on specific parameters

In preparation of this plan several aspects concerning the construction and operation of Lucky Electric

power plant have been taken into consideration and management related issues have been provided

to guide through the procedures.

The responsibilities of this EMMP are divided in two different ways, based on the phase of project; and

management hierarchy. A table below describes the former and its details follow below. It should be

noted that only roles and responsibilities that directly relate to environmental management are

described here.

Phase of Project Key Role Player

Design / Pre-construction - LEPCL (the proponent) - Engineering Procurement and Construction (EPC) Contractor - The Supervision Consultant (IMC)

Construction - LEPCL (the proponent) - EPC Contractor - Subcontractors (SCs) of EPC Contractor

Operational - LEPCL - SCs of LEPCL

Decommissioning - LEPCL - Contractor hired by LEPCL

8.5 PRE-CONSTRUCTION (DESIGN) PHASE

8.5.1 RESPONSIBILITIES OF LEPCL

LEPCL will be responsible for ensuring that EPC Contractor is aware of and takes into consideration all

the measures presented in the EMMP and confirm that all environmental management measures have

been incorporated into the project design on completion of the design phase. LEPCL Manager shall also

ensure redundancy in all critical environmental pollution control systems as the foremost priority.

The LEPCL HSE manager shall:

Form an Emergency Response Team and an Emergency Response Plan

Develop a waste management plan and/or hire a waste management contractor

Hire an Independent Monitoring Contractor for overseeing the implementation of the EMMP

Hire competent HSE Officer, HSE Coordinator, HSE Trainer and required staff as necessary for the

implementation of this EMMP

Develop a spill management procedure (some guidelines have also been provided at the end of this

EMMP)

Take appropriate action as per the recommended change management plan provided in EMMP in

case of any changes to plant design that alter its environmental impacts

In liaison with the LEPCL HSE Manager, the EPC Contractor shall develop:

an HSE plan for the construction phase

a traffic management and mobilization plan for the construction phase



an effluent management plan for construction and operation phase describing handling, storage

and disposal of wastewater effluents

a hazardous waste management plan

8.5.2 RESPONSIBILITIES OF EPC CONTRACTOR

The responsibilities as mentioned above and:

Hire only competent sub-contractors when necessary that will be bound to comply with the

provisions of this EMMP.

Hire an HSE manager for dealing with HSE affairs

8.5.3 CONSTRUCTION PHASE

During the construction phase, the following hierarchy shall be followed for the proper management

and implementation of environmental protection measures.

Figure 8.1 - Expected Construction Phase Organizational Structure



During the construction phase, LEPCL HSE Manager will have overall accountability and responsibility

for environmental and social management and monitoring of the Power Plant construction project to

ensure that environmental compliance is achieved. This includes responsibility for the environmental

performance and management of LEPCL employees and activities, as well as oversight of Engineering

Procurement and Construction (EPC) Contractor and its Sub-Contractors (SCs). The monitoring of the

project is to be undertaken by an Independent Monitoring Contractor (IMC) who shall regularly submit

the report to SEPA on a periodic basis or as per terms of EIA approval.

LEPCL HSE Manager will retain responsibility for ensuring that EPC and its SCs fully implement the

provisions of the EMMP. In order to facilitate this, and to demonstrate commitment to the EMMP,

LEPCL’s HSE coordinator will monitor and evaluate the activities and performance of EPC and its SCs and

report to LEPCL HSE Officer. These inspections/audits will be carried out in conjunction with the

management teams of EPC Contractor and its SCs in order to ensure that all areas of concern are rapidly

addressed and the results of all inspections/audits are documented.

EPC Contractor is anticipated to hire only specialized subcontractor, appointed after tendering. It will

execute construction activities and will be responsible for implementing environmental management

measures during construction as defined in this EMMP. EPC Contractor will enhance environmental

performance during the construction phase through Implementation and management of a program of

environmental inspection, monitoring and reporting, ensuring that all staff undergoes environmental

awareness training, focusing on the key environmental and socio-economic issues concerning this

project and implementation of a program for follow-up and analysis of all environmental incidents or

accidents.

Construction will mainly involve the following activities:

Excavation;

Ground works;

Piling;

Welding;

Building erection; and

Lifting.

8.5.4 ROLES AND RESPONSIBILITIES DURING CONSTRUCTION

Responsibilities of LEPCL

(1) HSE Manager

The Lucky Electric Power Plant HSE Manager has overall responsibility for better HSE management of

the Project is fully responsible for the health and safety of all personnel within the construction site.

In terms of environmental management, HSE Manager will:

Provide direction on strategic matters to HSE Officer and EPC Contract Manager;

Review periodic reports on the performance of the environmental management and monitoring of

the Project that are submitted by HSE officer;



Allocate sufficient resources for implementation of Emergency Response Plan and head the

Emergency Response Team;

Oversee the activities of Waste Management contractor; and

Coordinate with IMC in facilitating the monitoring activities.

To ensure that the points of views of staff, contractors and HSE officers are considered and placed

likewise in the EMMP;

To identify issues and propose solutions for inclusion in the EMMP review process;

To improve coordination and exchange of information between top management, employees, and

contractors;

To contribute to actions required to deliver the management plan and ensure its continued

development;

(2) HSE Officer:

The LEPCL HSE Officer will manage all HSE matters relating to the Project, of which environmental

aspects will form a part that require input or assistance. The HSE Coordinator will:

Be responsible with intercepting and managing HSE issues during the construction phase that

require LEPCL to intervene;

Be the direct counterpart for the LEPCL HSE Manager;

Verify that LEPCL, EPC Contractor and its SCs’ activities are conducted in accordance with the

requirements of the EMMP and that international standards of environmental management are

pursued;

Provide direction and advice to HSE Coordinator on HSE matters in events that such matters cannot

be mitigated by EPC Contractor or SCs;

Provide professional guidance on questions relating to the environmental management and issues

raised by contractors/relevant personals;

Supervise the training coordinator and provide appropriate resources for providing training;

Issue Corrective Action Requests to EPC Contractor or its SCs if corrective action is required; and

Review periodic reports presented by HSE Coordinator for monitoring environmental compliance

of all project activities.

Maintain a balanced, holistic approach to the solution of concerned issues in accordance with and

compliance of legislative requirements.

(3) HSE Coordinator:

LEPCL HSE Coordinator is required to collect and submit the following to HSE Officer:

Periodic environmental compliance reports prepared by EPC Contractor and its Sub-contractors;

Action Plans submitted by EPC Contractor and its SCs designed to address non-conformance with

environmental guidelines. Approval must be given by HSE Officer prior to the EPC Contractor or SCs

taking action;



Incident reports submitted by EPC Contractor or its Sub-contractors ;

Any Method Statements that EPC Contractor or its SCs are required to compile;

Periodic environmental compliance reports from EPC Contractor. (In the event of significant

environmental non-conformance, the LEPCL HSE Manager will be informed immediately.

The HSE Coordinator and HSE officer will be in continuous contact with the training coordinator so as to

facilitate the environmental training of EPC contractor’s and SCs’ staff. The HSE Coordinator will also

prepare periodic monitoring reports describing the progress of EPC Contractor and its Sub-contractors’

environmental compliance and submit to HSE Officer.

Responsibilities of EPC Contractor

The EPC Contractor has a duty to demonstrate respect and care for the environment. The EPC

Contractor will be directly responsible for managing all environmental aspects of construction activities

under its control to a satisfactory level. “Satisfactory level” in terms of environmental performance is

taken to mean full compliance with:

Legislative and Regulatory Requirements;

Applicable international conventions addressing environmental and social matters;

LEPCL HSE management standards, guidelines and other corporate instruments;

Agreed procedures and standards for the Project; and

The provisions of the EMMP.

EPC Contractor is responsible for the day-to-day management of the project activities. In terms of

environmental management, it will:

Carry out construction activities in environmentally sound manner.

To coordinate with LEPCL HSE department to resolve any pertinent issues.

Manage and implement environmental management practices as given in the impact assessment

report as well as HSE polices adopted/prepared by LEPCL;

Try to reduce the environmental risks;

Appoint a dedicated environment officer to understand and handle environmental issues more

easily in coordination with HSE officer/coordinator.

Prepare periodic reports on the performance of the environmental management and monitoring

of the project to be submitted to LEPCL HSE Coordinator. In the event of significant environmental

non-conformance the LEPCL HSE Coordinator will be informed immediately;

Ensure that all construction activities are conducted in accordance with the requirements of the

EMMP and that international standards of environmental management are pursued;

Allocate and manage sufficient resources to ensure adequate management and monitoring of

environmental matters;

Submit incident reports to LEPCL HSE Coordinator;

To regularly review the following:



Periodic environmental compliance reports prepared by its SCs for submission to LEPCL HSE

Coordinator ;

Action Plans submitted to SCs to address non-conformance with environmental guidelines.

Approval must be given by LEPCL HSE Officer prior to EPC Contractor or its SCs taking action;

Any Method Statements that its SCs are required to compile;

That any environmental monitoring results are within specified limits;

The contractor is also required to undertake regular site inspections to determine compliance with the

EMMP and monitor its SCs for compliance with the requirements of the EMMP and to:

Investigate the cause of environmental non-conformances and verify that the party responsible for

the situation rectifies it;

Issue Corrective Action Requests to its SCs if required;

Oversee development of environmental awareness and training materials and their

implementation during training and induction sessions for new workers at regular periods, as

appropriate;

Ensure that its SCs are informed of the EMMP and associated responsibilities and implications prior

to commencement of construction; and

Verify that any environmental corrective actions arising from compliance reports or incident reports

are promptly implemented.

Responsibilities of Subcontractors (SCs)

The SCs will comply with the specifications of the EMMP and abide by instructions issued by the

Management of EPC Contractor regarding the implementation of the EMMP. The SCs will ensure that

copies of the EMMP are available at their offices and on site and that all personnel on site are familiar

with and understand the relevant requirements of the EMMP.

Other responsibilities include:

Notifying LEPCL HSE Coordinator of any non-compliance with project HSE requirements, including

environmental requirements;

Ensuring that any problems and non-conformances are remedied in a timely manner, to the

satisfaction of the LEPCL HSE Coordinator;

Notifying EPC Contractor and LEPCL HSE Coordinator of incidents and complaints; and

Compiling and submitting Method Statements to HSE Coordinator;

Compiling and submitting the following reports:

Periodic environmental compliance reports for submission to EPC Contractor;

Corrective Action Plans, designed to address non-conformance with environmental guidelines, for

submission to EPC Contractor; and

Incident reports for submission to LEPCL HSE Coordinator.



In the event of an environmental non-conformance, the SCs will work with EPC Contractor, supported

by the LEPCL HSE Officer, to find solutions to the problem and ensure they are promptly implemented.

The Supervision Consultant (IMC)

LEPCL shall appoint an Independent Monitoring Consultant (IMC) who will oversee that the operational

activities are in accordance with the provisions of the EIA. IMC shall be responsible for the preparation

of periodic reports on the project progress. The consultant will maintain records, decisions made at

meetings, progress on civil works, certified achievements, milestones, and financial records and any

deviations from or changes to the contract plans. The consultant will assist the LEPCL and EPC Contractor

in preparing monitoring and evaluation reports as required under the agreement.

8.6 OPERATIONS PHASE

LEPCL HSE Manager will have accountability and full responsibility for the environmental performance

of the operation of the Power Plant. It is assumed that there will be no significant role for contractors

during operations, but if there is the contractor will have to abide by all applicable legal requirements as

described for the SCs in the previous section.

LEPCL will enhance environmental performance during the operations phase through the following

activities:

Implementation & management of a program of environmental inspection, monitoring & reporting;

Complying with the relevant legislation and regulations;

Regularly reviewing the impacts on the environment;

Developing appropriate indicators to monitor core impacts;

Setting appropriate annual objectives, targets and report the progress; and

Communicate openly with internal and external stakeholders on environmental issues;

It should be noted that only roles and responsibilities that directly relate to environmental management

are described here; the general roles and responsibilities related to environmental management are

outlined in the sections below.

8.6.1 EXPECTED HSE ORGANIZATIONAL STRUCTURE

The expected organizational structure of LEPCL during operations is illustrated in the organogram below

(Figure 8.2):

The HSE Manager reports directly to LEPCL Managing Director, ensuring that HSE matters continue to

receive attention at the highest level. If any services of a contractor are taken during operations, they

will report directly to the HSE Manager on all HSE matters.



Figure 8.2 - Expected LEPCL HSE Organizational Structure (Operations)

8.6.2 ROLES AND RESPONSIBILITIES DURING OPERATIONS PHASE

Managing Director

The Managing Director of LEPCL has overall accountability for all the operation, including HSE matters.

The key responsibilities of Managing director related to Environmental issues are:

To consider and react to issues and solutions proposed by the HSE Manager;

To cooperate and consult with the relevant environmental agency to perform better;

To evaluate the progress of implementation of EMMP; and

To approve any change in decision-making and authorities in consultation with Manager HSE, if

appropriate.

The HSE Manager

The LEPCL HSE Manager will manage all HSE matters relating to the power plant operations. He will be

supported by an Environmental Team.

The LEPCL HSE Manager will:

Be responsible for the integration of environmental management controls into day-to-day activities

in collaboration with the HSE Officer;

Ensure that operations comply with the provisions of the EMMP;

Allocate and manage resources to ensure adequate supervision of environmental matters;

Ensure that activities are conducted in accordance with the requirements of the EMMP and that

high standards of environmental management are pursued;



Oversee development of environmental awareness and training materials by the HSE officer and

their implementation during training and induction sessions for new workers and at regular periods

as appropriate;

Oversee and review environmental monitoring and data management and verify that

environmental monitoring results are within specified limits;

Submit periodic environmental performance reports to the Managing Director;

Review and take appropriate action on the following information submitted by the LEPCL HSE

Officer:

o Periodic environmental compliance reports;

o Periodic data monitoring reports; and

o Incident reports.

The LEPCL HSE Officer

The LEPCL HSE Officer is responsible for the day-to-day management of the power plant and

management of the environmental aspects associated with the operations. In terms of environmental

management, the HSE Officer will:

Put a system in place to ensure that environmental performance is recorded in an appropriate

format to inform external stakeholders of LEPCL’s environmental management and monitoring

performance;

Maintain a community complaint mechanism to receive and respond to complaints and other issues

of concern from local communities with the project area and from any other stakeholders; and

Provide periodic environmental trainings to training staff on environmental compliance and

overlook the duties of HSE Coordinator and Training Coordinator.

Take corrective and preventive actions and carry out investigations for incidents.

Review the following:

Quarterly performance reports submitted by the power plant management team; and

Incident reports submitted by HSE Coordinator.

LEPCL HSE Coordinator

The HSE Coordinator will be responsible for updating procedures and writing plans, safety and

environmental trainings, orientation trainings and regular on-site inspections for checking

environmental compliance.

The HSE Coordinator will:

Oversee and keep records of environmental trainings

Complete orientation trainings for new employees

Design training requirements to suit the audience level for understanding

Verify that proper implementation of the provisions of this EMMP are being followed



Prepare regulatory compliance reports to be submitted to SEPA

Prepare incident reports

8.7 CLOSURE AND DECOMMISSIONING PHASE

The power plant closure and subsequent decommissioning shall be carried out under supervision of

LEPCL HSE Manager who shall be fully responsible for the safe and environmental friendly

decommissioning of the plant. The LEPCL may hire a competent Contractor for this purpose.

The LEPCL HSE Manager shall:

Be responsible for safe decommissioning and closure of the plant

Commissioning of a reputable contractor for dismantling of the plant

All hazardous waste shall be disposed off in compliance with the national and local laws

All recyclable and reusable wastes shall appropriately be taken care of in order to reduce

environmental impacts

A traffic management plan similar to the one developed for construction phase shall be developed

and followed

The plant site shall be restored to original conditions as at the time immediately before its

construction.

8.8 MITIGATION PLAN

Mitigation measures are proposed for this project in order to control and lessen the impacts of all

potential negative impacts that are either expected during the normal operation of the system or

unexpected due to uncontrolled events that lead to accidents in the system. The feasibility or validity of

the mitigation suggestions can be measured in terms of either decreasing the severity of the impact or

the probability of its happening.

For each stage of the project, a different set of mitigation measures shall be applicable. There are four

major stages of the project; Pre-Construction, Construction, Operation and Decommissioning.

Keeping in mind that strict implementation of the EMP and project management’s strict enforcement

of the adequate construction practices and standards will greatly reduce the negative impacts of the

project.



Table 8.1 - LEPCL Environmental Impact Mitigation Plan

Environmental Aspect

Environmental Impacts / Sensitive Receptors

Proposed Mitigation Measures Responsibility Scheduling Implementation Tool

Residual Impacts

Traffic

Increased traffic flows leading to congestion on main roads during transportation of workers, raw materials and construction vehicles

Defining transport routes and durations to avoid busy roads and peal traffic times

EPC Contractor + LEPCL HSE Manager

Pre-Construction, During Construction

Traffic management and mobilization plan

With the adoption of the given measures, the residual impacts will be minimum

Traffic/ trip and journey management

Adaptation of car-pooling practices and use of group transport methods (Such as buses, 12 m vehicles)

Avoiding road closures and diversions as much as possible

Planning of project access roads to avoid interference with congested public main roads

Fire

Besides incurring huge economic losses and environmental damage, fires can be fatal

Only intrinsically safe equipment should be procured for operation in and near the coal yard

EPC Contractor Pre-Construction Phase

EPC Contract


NFPA or more stringent standards should be adapted to be complied throughout the project life

Thermal IR cameras to be installed for coal yard and conveyor belt monitoring for detecting hotspots

Air Quality - Dust Emissions

Dust released in construction areas and near roads affects people and green cover within the project area

Limit vehicle speeds on unpaved roads

EPC Contractor

Pre-Construction and during Construction

EPC Contract

Dust emissions are difficult to be eliminated, but these measures can significantly reduce these impacts during construction. The

Continuous spray of treated wastewater on unpaved roads in the project area







Residual Impacts

Cleaning of vehicle tires when exiting the construction area

dust emissions will be dispersed within the atmosphere then settle down. Residual impacts will be of low significance.

Storage and handling of spoil, soil and potentially dusty material to be carried out in a careful manner so as not to cause dust blown downwind

Covering all trucks carrying dusty material with tarp or other similar material

Water the material stockpiles, access roads and bare soils on an as required basis to minimize dust

Social Issues

Interference of local community in construction site activities, handling general concerns and disturbance.

Increase awareness about project and at least tell its objectives, benefits, milestones, duration, map and time schedule.

LEPCL HSE Manager

Pre-Construction, during Construction and during operation

Stakeholder consultation


Establish and implement a complaint handling system and a communication system with the public

Assign a staff person for coordination with public.

A grievance redress mechanism has been provided at the end of this document which may be adapted or a similar one developed.







Residual Impacts

Announce in advance to the public about the location and timing of any possible road that needs to be blocked due to construction activities

EPC Contractor/ Sub-Contractor

During Construction

EMMP

Put visible legible warnings signs in local language for any kind of announcement including self-explaining signs for illiterate people.

Keep safe passages or walkways opened for pedestrians.

Put warning tapes or movable fences around construction sites

Put warning signs on each construction excavation or lifting location announcing the type, limit and duration of hazard in the specific area

Accidents, Injuries and Emergencies

Public, workers of construction contractors and LEPCL staff

Emergency Response Team headed by LEPCL EHS Manager

LEPCL HSE Manager Pre-Construction

Action taking and Early Response With the adoption of the

given measures, the residual impacts will be minimum

Provide safety trainings, prohibit work without proper safety equipment and reporting every incident and near miss.

EPC Contractor / Sub-Contractor

During Construction

EMMP

Manual Handling

Ergonomic Hazards – Handling of heavy machine parts, blocks etc.

Appropriate manual handling procedures EPC Contractor / Sub-

Contractor

Pre-Construction and

HSE Plan


Lifting and handling training for supervisors







Residual Impacts

Availability of appropriate equipment for handling all materials required to be moved during construction

During Construction

Conducting ergonomic hazard analysis for all aspects of construction work and provide appropriate training/ equipment or measures to reduce the impacts

Air Emissions – Power Plant

SOx emissions can cause acid rain which has several negative effects on vegetation, wildlife and physical structures

Only low Sulfur content coal shall be imported (having about 0.4%

EPC Contractor + LEPCL HSE Manager

Pre-Construction and During Construction

EPC Contract, Waste Management Plan and EMMP


50% of the Flu gas shall be desulfurized before being released into atmosphere (confirming to national emission standards)

NOx emissions can cause acid rain, ground level Ozone and photochemical smog and several other complex interactions causing deleterious effects on environment

Low NOx burners to be installed for reducing maximum NOx generation and bring emissions to nationally acceptable limits

Ash contains glassy material as well as trace metals that are harmful for all living organisms.

An Electrostatic Precipitator (ESP) or a Bag House filter shall be installed for collection of all of the Fly Ash generated. The storage and transportation of the ash than should be done in a proper







Residual Impacts

way so that zero spillage occurs as it is highly toxic to the environment.

A silo and an ash pond is to be constructed for bottom and fly ash respectively.

Bottom ash from boiler furnace, economizer hopper and mill reject hoppers shall be collected via a conveyor belt and sent to ash silo.

Sprinklers shall be installed at the ash pond and silos to suppress entrainment of ash in air

Coal dust can cause various lung diseases besides causing asset damage and substantive economic cost of clean-up.

Screw jacks shall be used to unload coal from vessel to conveyor belt to minimize dust generation in the first place

Coal will be transferred from the jetty to storage yard via a covered conveyor belt

Fine sprinklers shall be placed in the conveyor as well as in the coal yard to settle any entrained coal dust particles that will use recycled waste water for this purpose

Coal yard will have its own dust suppression sprinklers that will keep the moisture content of top layer coal







Residual Impacts

to an extent at which minimum dust emissions will occur

A windbreak shall be installed around the perimeter of the coal yard 0.5 m higher than highest coal pile to be made to prevent wind erosion that causes fugitive dust emission

Water Quality

Waste water can adversely impact the marine ecosystem by several means which can have short term as well as long term effects

All wastewater generated anywhere inside or due to any construction or operation activity shall be treated before disposal.

EPC Contractor / Sub-Contractor , LEPCL HSE Manager

Pre- Construction, During Construction and During Operation

EPC Contract and EMMP


An onsite Effluent Treatment Plant (ETP) shall be constructed.

The sludge generated as a result of ETP operation shall be disposed according to hazardous waste management plan.

Landscape and Visual Impacts

Loss of green cover due to excavation activities and disturbance of visual amenity in construction areas

The work area shall be limited to the minimum required for construction purposes


During Construction

EMMP

Preventive measures are very important for minimization of this impact. However, in case these could not be avoided, the adoption of an effective rehabilitation plan will ensure that the residual impacts will be of low significance.

Where removal of existing landscape features (such as trees, shrubs, etc.) is necessary, the species selected for replantation shall be of the similar type to that particular area.

Removal of trees should be restricted to the development footprint







Residual Impacts

Biological Environment - Flora

Potential loss of trees and green cover (e.g. where roads will be paved, impact from poor waste management affecting existing vegetation and dependent flora etc.)

A procedure shall be prepared to manage vegetation removal, clearance and reuse


During Construction

EMMP

Similar impacts as in the previous case; If these measures could not be adopted, the adoption of an effective rehabilitation plan will ensure that the residual impacts will be of low significance.

Encourage use of non-evasive construction techniques to avoid removal of vegetation of importance (e.g. mature trees, mangroves)

Construction activities shall minimize the loss or disturbance of vegetation

Cleared areas to be re-vegetated

Informing the LEPCL management before clearing any trees

Management of wastes and preventing effluents from reaching plants

Creating awareness among workers about environmentally friendly practices

Chemical- Welding Fumes

Workers’ increased chances of getting pneumonia, occupational asthma and lung cancer among other ailments

Evaluation of both metals and the welding rods


During Construction

HSE Plan No residual impacts if all measures taken appropriately.

Adequate ventilation for welders

Develop a welding procedure

Use of active chemical respirators where necessary (e.g. when welding on galvanized metals)

Gaseous releases in construction area and

Relocation of all stationary combustion equipment downwind


During Construction

Due to the rapid dispersive nature and prevailing







Residual Impacts

Air Quality – Gaseous Emissions

nearby roads affects people downwind and green cover within the project area besides long-term environmental impacts

and away from all public receptors and workers

Traffic management and mobilization plan

weather conditions, the residual impacts will be of low significance Exhaust of all stationary equipment

(e.g. generators) to be positioned high enough so as to assure proper emission dispersion

Routine inspection and scheduled maintenance of combustion emission sources according to manufacturer’s service manual

Turning of all engines of machinery and equipment when idling

Soil and Geology – relief, contamination and erosion

Contamination from hydraulic oil, waste water and similar spillages; Soil erosion and siltation;

Whenever possible, rock soil shall be used as fill and aggregate for concrete.


During Construction

Spill management plan, Hazardous waste management plan, EMMP


The time an area is left disturbed or exposed shall be minimized.

Hazardous materials shall be collected separately and disposed as per MSDS for each chemical and as per local regulations for waste disposal.

On completion of works, all temporary structures, surplus materials and wastes shall be completely removed.

All the work sites (except permanently occupied by the plant







Residual Impacts

and supporting facilities) should be reinstated to its initial conditions (relief, topsoil, vegetation cover).

Fuel tanks at construction and storage sites shall be provided with bunding (a minimum of 110%)

All fertile top soils enriched with nutrients shall be stripped to a depth of 15 cm. and preserved in form of stockpiles not exceeding 2m height; soil shall be prevented from erosion and anaerobic decomposition and shall be used for rehabilitation of proposed plantation sites

Groundwater Contamination

Indirect groundwater contamination due to accidental leaks from construction machinery, hydro testing waters, wastewater as well as other uncontrolled wastes

Construct temporary cut-off drains across excavated area


During Construction

EMMP


Check dams shall be constructed along catch drains in order to slow the flow and capture sediments

Length of all runoff slopes shall be reduced.

If dewatering practice is required, the generated groundwater shall be discharged into clean drainage channels.

Fuel tanks and any liquid chemical stored at construction and storage







Residual Impacts

sites shall be provided with bunding (a minimum of 110%)

Implement the effluent management plan for effluents generated by any construction activity.

Hazardous materials shall be collected separately and disposed as per MSDS for each chemical and as per local regulations for waste disposal

Vibration

Physical hazard for workers using jack hammers and similar equipment

Adequate work scheduling to prevent long-term effects EPC Contractor / Sub-

Contractor During Construction

HSE Plan


Proper procedures to use equipment

Archaeology and Cultural Heritage

No foreseen possible impact on any archaeological and cultural impact as per studies of EIA baseline.

A procedure to be established and in place in case an archaeological finding is made during excavation works


During Construction

EMMP


Marine Ecology and Seawater Quality

Damage to marine ecology and seawater quality may occur in case of release of discharge of land based effluents (drilling muds, oil spills, etc.)

Provision of booms in case of mud fluid or oil spill to sea


During Construction

EMMP








Residual Impacts

Biological - Fauna

Beautiful birds in the area may be poached other than domestic animals of the nearby community

Contractual obligation to be kept to avoid illegal poaching and strict action to be taken in case of any incident EPC Contractor / Sub-

Contractor During Construction

EPC Contract


Employees should be provided adequate knowledge of applicable legal laws related to illegal poaching

Ponding of water

Mosquito breeding grounds may develop

Ponding of water should be prevented in any waste container by covering


During Construction

EPC Contract


Any excavated land should be reinstated

Infectious Diseases such as HIV/Aids

Temporary influx of migrant labor during construction may increase risk of infection

Implementation of periodic medical check-ups by temporary medical team. Education and training on health care of workers

Contractor/Environmental Consultant, Supervisor: LPCL

During Construction Phase

EPC Contract After flowing this Sanitation for local residents will be ensured

Construction camp facilities

Prevent pressure on local services

Adequate housing for all workers


During Construction

EPC Contract


Safe and reliable water supply

Hygienic sanitary facilities and sewerage treatment facilities

Storm water drainage facility

Proper fuel supply for domestic purpose to prevent any illegal wood consumption

Solid wastes generated by the onsite camps /

Ensure proper collection and disposal of solid wastes in the approved disposal sites







Residual Impacts

housing to be properly disposed

Store inorganic wastes in a safe place within the household and clear organic wastes on daily basis to waste collector

Establish waste collection, transportation and disposal systems

Ensure that materials with the potential to cause land and water contamination or odor problems are not disposed of on the site.

Ensure that all on-site wastes are suitably contained and prevented from escaping into neighbouring fields, properties, and waterways, and the waste contained does not contaminate soil, surface or groundwater or create unpleasant odors for neighbours and workers.

Biological Hazards

Food Poisoning due to unsanitary conditions, poor controls on food, possible transmission of disease from food handlers

Procedures and systems in place to do regular checks on catering

EPC Contractor / Sub-Contractor and LEPCL HSE Manager

During Construction and operation

HSE Plan


Periodic audits of catering facility by external party

Chemicals and Hazardous wastes

Exposure to chemicals, paints, additives, corrosion inhibitors etc.

Procedures and systems in place to ensure up to date Material Safety Data Sheets (MSDS) are in place

EPC Contractor / Sub-Contractor and LEPCL HSE Manager

During Construction and operation

HSE Plan With the adoption of the given measures, the







Residual Impacts

Adequate placement and labelling of all hazardous substances

residual impacts will be minimum

First aid kits and showers as necessary for the type and safety measure of chemicals to be available nearby at all times

Implementation of hazardous waste management plan

Physical – Machinery and equipment noise

Confusion and performance effects on humans. Permanent shift of Threshold of hearing (TOH), if continuously exposed to high noise levels. Possible long-term effects on survival of wildlife.

Use of low noise generating machinery such as equipment with mufflers, engine covers etc. and preferable use electric powered equipment instead of diesel powered and hydraulic tools instead of pneumatic whenever possible

EPC Contractor/ Sub-Contractor + LEPCL HSE Manager

During Construction and Operation

HSE Plan

No residual effects on humans if preventive measures undertaken properly.

Regular and proper maintenance of all noise generating machinery and vehicles according to the service manual be certified personnel

Providing PPE and appropriate training for proper use of such PPE to workers

Operating noise producing equipment only during day time

Regular rotation of staff exposed to higher noise







Residual Impacts

Physical – Heat stress

Exhaustion due to work in open areas during excavation, piling and other earth works

Adequate supply of water and replacement fluids to all workers and supervisors

EPC Contractor/ Sub-Contractor + LEPCL HSE Manager

During Construction and Operation

HSE Plan

No residual effects on humans if preventive measures undertaken properly.

Heat stress abatement procedure

Proper work scheduling during hot periods

Training and awareness courses for all supervision staff and workers including first aid

Air Quality – Power plant emissions

The air quality of an air shed can deteriorate rapidly if control measures fail or stop performing well

All Pollution Control equipment should be regularly inspected and maintained

LEPCL HSE Manager During Operation

EMMP, OEM Instructions


If all redundant pollution control systems fail, plant should be immediately shut down until problem is resolved

All air emissions including Coal dust should regularly be monitored and if any parameter exceeds

Top layer of Coal piles should be kept moist

Fire

Besides incurring huge economic losses and environmental damage, fires can be fatal

Keep the implemented systems maintained and up-to-date


EMMP


Regular evacuation drills conducted for all staff in-case of a huge fire

Trainings provided to staff to use the right fire extinguisher







Residual Impacts

Coal fires as a result of self-heating start very gradually (usually after several hours of steaming) The coal piles should be kept compacted to prevent oxidation and subsequent heating

Steaming coal should be removed from the pile and spread in thin layer until it cools down. Coal pile should never be inundated as it will increase the chances of fire due to heat of watering

Spills

Any spill has the potential to harm the environment besides posing a direct hazard to health and safety of humans

A complete spill management plan has been provided which may be adopted after minor amendments


EMMP


Storm Water

Typical storm water runoff contains suspended sediments, metals, petroleum hydrocarbons, coliform, etc.

Rainfall runoff from the coal pile will contain mainly suspended solids. This runoff will be routed to the settling basin for retention and settling of suspended solids, and the clean water from there may be used for dust suppression system. Storm water will be separated from process and sanitary wastewater streams in order to reduce the

LECPC During Operation

EMMP Minimize the pollution







Residual Impacts

volume of wastewater to be treated prior to discharge. Surface runoff from process areas or potential sources of contamination will be prevented. Oil water separators and grease traps will be installed and maintained as appropriate at refuelling facilities, workshops, parking areas, fuel storage and containment areas. Adequate storm drains will be constructed along the boundary of the plant area and within the plant area to drain off the storm water during monsoon period. Limestone and gypsum storage areas will be covered so that there will be no contaminated runoff.

Solid Waste

Solid wastes if improperly disposed is nuisance in itself besides imposing several new hazards

A generic waste management plan has been provided which may be followed after some amendments.


EMMP


Stack Emissions SO2, NOx and PM emissions from the stack

Ensure that the following equipment are included in the project design: ESP (High Efficiency) to limit the total PM emissions

LECPL During detailed designing

EMMP

Will minimize the pollution rate and keep the plant operating within the proposed standards set by the government.







Residual Impacts

Dry low NOx burners to minimize the NOx generation FGD to limit SO2 emission The equipment type and details may be changed as long as the objectives are met

Effluent discharge from the Power Plant

Discharge from the power plant includes cooling tower, boiler blowdown, washing effluent, sanitary waste, and some other effluents

A proper disposal system for the waste is required.

LEPCL During Operation

EMMP

Will help the plant run within the limits set up by the EPA and will protect the environment from severe damage



8.9 MONITORING PLAN

Environmental monitoring is the second part of an EMMP and it is the mechanism through which the

effectiveness of the EMMP is gauged. The feedback provided by environmental monitoring is

instrumental in identifying any problems and planning corrective actions.

8.9.1 OBJECTIVES OF MONITORING PLAN

The main objectives of environmental monitoring during the operation of LEPCL Power Plant are:

To provide a mechanism to determine whether the management is carrying out the project in

conformity with the EMMP.

To identify areas where the impacts of the projects are exceeding the criteria of significance and,

therefore, require corrective actions.

To document the actual project impacts on physical, biological, and socioeconomic receptors,

quantitatively where possible, in order to design better and more effective mitigation measures.

To provide data for preparing the monitoring report to be submitted to the Sindh EPA in accordance

with the regulatory requirement.

Monitoring of activities during the operation of Power Plant will be necessary to assess the impacts of

these activities on the environment. For this purpose, Lucky Electric Power Company Limited (LEPCL)

will engage an Independent Monitoring Consultant (IMC) for implementing a monitoring program to

monitor the:

Air Emissions

Effluent Quality

Solid waste management

Environmental performance of the facility

IMC will follow the monitoring frequency of selected parameters as per the monitoring plan given in the

table below. It will record all non-conformities observed and report them along with actions to Project

Management for corrective action and send final report to SEPA.

LEPCL HSE Manager shall take note of the recommendations relating to issues identified in the

monitoring report. Similarly, the EHS department will consider the issues identified by IMC for the

operations phase monitoring. Table below presents a proposed monitoring plan to monitor different

environmental aspects during the operational phase of the Power Plant. This monitoring plan can be

improved by the EHS Manager of LEPCL if found necessary to improve its effectiveness.



Table 8.2 - Environmental Monitoring Plan for LEPCL

Monitoring Aspect

Location Parameters to Monitor Monitoring frequency Standards Responsibility Supervision

Stack Emissions At the stack SOx, NOx, CO and Particulates. Monthly

NEQS LEPCL HSE Manager Independent Monitoring Consultant (IMC) Heavy Metals Every 2 years

Ambient Air

All operational areas including the residential area in the power plant vicinity.

PM10, PM2.5 and TSP for 24-hour filter based low volume sampler, Ambient 24-hour CO, SOx, NOx and Lead using active sampler.

Monthly SEQS LEPCL HSE Manager IMC

Reinstatement of Work sites

All work sites Visual Inspection Monthly Site Restoration Plan Contractor IMC

Grievance Plant location and areas around it

Nature and frequency of grievances and time taken to address them

Quarterly Grievance Redressal Mechanism

LEPCL IMC

Coal and fly ash specifications

Heavy metals (Mainly As, Be, Cd, Cr, Pb, Hg, and Ni)

Quarterly International

A consultant would be hired which will test the results through recognized laboratory

IMC

GHG emission Stacks Monitoring of flue gases flow and carbon content

Once in 6 months International

A consultant would be hired which will test the results through recognized laboratory

IMC




Monitoring Aspect


Wastewater All effluent discharge points

Under Normal conditions: Effluent flow, Temperature, pH, TSS, Oil and Grease

Monthly

NEQS

LEPCL HSE Manager

IMC

Under Upset and start-up Conditions: Effluent flow, Temperature, pH, TSS (No. of hours of upset condition operation to be mentioned in the monthly report)

Hourly Basis

Solid Waste Project Area

Solid waste quality ,quantity and disposal methods / locations

Visual checks to assess the situation.

Quarterly N.A LEPCL HSE Manager

IMC

Fire & Safety All operational areas

Fire hazards & safety protocols Continuous NFPA LEPCL HSE Manager IMC

Vehicles and equipment

Anywhere inside LEPCL premises

Random speed checks

At different locations and different times

Traffic management plan LEPCL Traffic Manager

IMC

Transport office or workshop

Records of maintenance

As per manufacturer’s instructions

Manufacturer’s recommendations

LEPCL Equipment Maintenance Department

IMC

Within 100 m of equipment

Baseline noise emissions of new equipment

On commissioning of all new equipment

NEQS LEPCL HSE Manager IMC

Noise All operational areas

Noise intensity measurement dB(A)

Monthly OSHA LEPCL HSE Manager IMC




Monitoring Aspect


Hazardous spill All operational areas

Spill on Land Continuous Spill Management / SOPs LEPCL HSE Manager IMC

Traffic management

Entry exit routes, road-loading terminal area

Traffic Management Plan Continuous Traffic Management Plan LEPCL HSE Manager IMC

Health and Safety of Workers

Operational areas Accidents, PPEs, Diseases. On quarterly basis Health and safety procedures developed by HSE department

LEPCL HSE Manager IMC

Accidents All areas Inspection and record keeping On quarterly basis

Health and safety procedures developed by HSE department,

SOPs

LEPCL HSE Manager

IMC

Compliance monitoring

All areas EIA Commitments, Mitigation Measures, Conditions of Environmental Approval, SOPs

Monthly Environmental Management & Monitoring Plan (EMMP)

Independent Monitoring Consultant (IMC)

Sindh EPA



8.10 WASTE MANAGEMENT PLAN

Although the waste management may be contracted to a third party, a generic waste management

plan is given below for LEPCL which may be followed appropriately. Waste generation is inevitable at

every step of a project and proper mechanisms need to be in place in order to deal with every possible

kind of waste that may be generated.

Ash particles will be the major waste to be generated from the power plant and details of the ash

management are described in this report. Some waste will also be generated from the coal storage

yard and belt conveyor facilities. To control flying coal dust, a water spraying system will be installed in

the coal yard.

Table 8.3 – Waste Management Matrix

No. Material Waste

Associated Risks Recommended Procedure Final Disposal

Method

1 Rocks, cement, concrete

Non-hazardous bulk waste Ensure safe storage till disposal

Landfill or reuse as for filling

2 Oil May cause contamination of soil or waterways

Ensure disposal is carried out by certified recycling contractors

Recycling Contractors

3

Wood, Cotton, Plastic, Waste and Packing Materials

Burning of wood, paper, plastic and other materials can cause air pollution and littering due to improper disposal

Dispose all non–recyclable plastic wastes and other non– recyclable materials at proper waste disposal site

Recycling / Landfill

4 Electronics

Some electronics equipment may contain toxic and hazardous materials and pose a health risk if opened or dismantled.

Ensure contractor disposes equipment properly and equipment is opened only under guidance of qualified professional.

Recycling/ Hazardous landfill

5

Steel, Iron, Copper, Brass and similar recyclable metals

Equipment and parts may be contaminated with oil or other liquids. This may pose hazards during recycling.

Separate contaminated parts and ensure disposal contractor cleans and removes contaminations before recycling.

Recycling

6 Asbestos

Causes irreversible lung damage such as asbestosis and lung cancer. A known carcinogen.

To be handled according to asbestos management plan

Sealed in a marked container and stored at a hazardous landfill

7 Other Materials

Some waste materials may contain hazardous materials (such as mercury and lead) which can pose health risks if not handled or disposed of properly.

All hazardous substances such as Lead and Mercury should be identified and separated. It should be ensured that waste contractor disposes

Material Recycled/ Disposed to Hazardous Landfill



Table 8.3 – Waste Management Matrix

No. Material Waste

Associated Risks Recommended Procedure Final Disposal

Method

hazardous material in accordance with accepted methods.

8 Food waste

Can become hazardous if comes in contact with any hazardous waste such as infectious waste

Should not be mixed with non-degradable waste and composted.

Compost is a soil conditioner

9 Insulation Materials

Burning may cause air pollution. Littering due to improper disposal

Ensure contractor disposes insulation properly at and in fill site

Re – use Landfill

10

Ash

Lung disease Developmental problem Multiple type cancer Decrease in IQ Birth Defects and many more

Ensure safe and adequate method is implied for coal ash handling, and transportation from the power plant to the cement plant. Maintain optimum spray on the conveyor belt and coal storage site to prevent coal dust from blowing out.

Re-use for different products such as cement production, brick making and for landfill purpose also

8.11 SPILL MANAGEMENT

Liquid waste spills that are not appropriately managed have the potential to harm the environment.

By taking certain actions, it can be ensured that the likelihood of spills occurring is reduced and that the

effect of spill is minimized. To enable spills to be avoided and to help the clean-up process of any spill,

the management staff of LEPCL should be aware of spill procedures. By formalizing these procedures

in writing, staff members can refer to them when required thus avoiding undertaking incorrect spill

procedures. A detailed spill management plan should be prepared for the operational phase of LEPCL

Power Plant. The plan should contain the following:

Identification of potential sources of spill and the characterization of spill material and associated

hazards

Risk assessment (likely magnitude and consequences)

Steps to be undertaken when a spill occurs (stop, contain, report, clean up and record)

A map showing the locations of spill kits or other contingency measures

8.11.1 AVOIDING SPILLS

By actively working to prevent spills, money and time can be saved by not letting resources go to waste.

In addition, the environment is protected from contaminants that can potentially cause harm. All

liquids must be stored in sealed containers that are free of leakage. All containers should be on sealed



ground and in a covered area. Sharp parts must be kept away from liquid containers to avoid damage

and leaks.

To prevent spills from having an effect on the plant site operations or the environment, bunding should

be placed around contaminant storage areas. A bund can be a low wall, tray, speed bump, iron angle,

sloping floor, drain or a similar structure and is used to capture spilt liquid for safe and proper disposal.

8.11.2 SPILL KITS

Spill kits are purpose built units that contain several items useful for cleaning up spills that could occur.

Typical items are:

Safety gloves & appropriate protective clothing (depending on the type of chemicals held onsite)

Absorbent pads, granules and/or pillows

Booms for larger spills

Mops, brooms and dustpans.

Spill kits are used to contain and clean up spills in an efficient manner. Sufficient number of spill kits

should be provided. Spill kits should be kept in designated areas that are easily accessible to all staff.

Staff members are to be trained in using the spill kit correctly.

After cleaning up a spill, the materials used to clean up must be disposed of correctly. Depending on

the spill material, the used material may be disposed in the hazardous waste facility or the landfill site.

8.11.3 RESPONDING TO SPILLS

If it is safe to do so, the source of the spill should be stopped immediately. This may be a simple

action like upturning a fallen container.

To stop the spill from expanding, absorbent materials and liquid barriers should be placed around

the spill and worked from the outside to soak up the spill. It is vital that spilt liquid is not allowed to

reach storm water drains, sewer drains, natural waterways or soil.

For large scale spills that involve hazardous materials, authorities may have to be alerted.

Using the information from Material Safety Data Sheets (MSDS) about the properties of the liquid

spilled and the spill equipment available, spills should be cleaned up promptly.

By keeping a simple log of all spills, precautionary measures can be put in place to avoid similar

accidents from occurring in the future.

8.12 COAL DUST MANAGEMENT PLAN

The coal dust suppression system will be designed during detail design stage. The following is a general

description of the system.

Coal dusts from coal stockpile and coal conveyor belt area are the major source of fugitive emissions.

Dust suppression using a sprinkler system will be primarily employed to control the coal dust from

these areas. Recycled water from the waste water treatment plants and cooling water blow down will

be the primary source of water to the sprinkler system.



Coal dust suppression will comprise wetting air–borne dust particles with a fine spray of water, causing

the dust particles to agglomerate and move by gravity to the coal stream flow. Once properly wetted,

the dust particles will remain wet for some period and will not tend to become airborne again. The

dust suppression system in the stockpile yard will consist of swiveling and wide–angle full–cone spray

nozzles. These nozzles will be provided on both sides of the pile and at ground level, spaced every 50

m. Ventilation slots are proposed in the top portion of the raw coal bunkers, allowing coal fed into the

bunkers to displace any gases that may have formed as a result of resident coal.

In addition coal dust extraction system may also be employed. In this system, dust is extracted from

operations area that generates dust in large quantities such as screening, loading and unloading.

Rainfall runoff from the coal pile and runoff from the application of dust suppression sprays will contain

mainly suspended solids. This runoff will be routed to the settling basin for retention and settling of

suspended solids, and the clear water from there may be used for the dust suppression system.

8.13 TRAINING PROGRAM

LEPCL will initiate a training program to ensure that its employees and that of its contractors have the

required knowledge and skill to manage the environmental aspects of their respective jobs. The

proposed environmental trainings listed in Table below.

Table 8.4: Training Program

S.#. Type of Training Personnel to be

Trained Training Description

1 Occupational Health and Safety

EHS Manager Plant managers and supervisors

Awareness to conform to safety codes. Mandatory use of PPE by the senior administration during all plant visits.

2 Occupational Health and Safety

Workers Staff

Health, safety and hygiene Proper usage of personnel protective gear Precautions to be taken for working in confined areas.

3 Health, Safety and Environmental Auditing

Staff responsible for inspection/audits

Procedures to carry out Health, Safety and Environmental Audits Reporting requirements

4 Waste Disposal and Handling

Relevant Workers Relevant Staff

Segregation, identification of hazardous waste, use of PPEs, waste handling

5

Social & Environmental laws & regulations, norms, procedures and guidelines of Government

EHS staff Plant managers and supervisors

Environmental standards and their compliance

6

Implementation of environmental management and monitoring plant

EHS staff Responsible supervisory staff Management

Concepts of environmental management and monitoring plan



Table 8.4: Training Program

S.#. Type of Training Personnel to be

Trained Training Description

7 Defensive driving All drivers and their supervisors

Safe driving and handling of equipment

8.14 CONSTRUCTION MANAGEMENT PLAN

Every contractor will develop a specific construction management plan (CMP) based on the conceptual

CMP shown in the Table Below. The CMP will be submitted to the LEPCL for approval before start of

construction activities.

The CMP will clearly identify all areas that will be utilized during construction for various purposes. For

example, on a plot plan of the construction site the following will be shown:

Areas used for camp

Storage areas for raw material and equipment

Waste yard

Location of any potentially hazardous material such as oil

Parking area

Loading and unloading of material

Septic tanks

Housing and construction camp

Fuel storage and pipelines

Access routes

Table 8.5: Construction Management Plan

S.# Aspects objectives Mitigation and Management Measures

1 Vegetation clearance

Minimize vegetation clearance and felling of trees

Removal of trees should be restricted to the development footprint.

Construction activities shall minimize the loss or disturbance of vegetation

Use clear areas to avoid felling of trees

A procedure shall be prepared to manage vegetation removal, clearance and reuse

Inform the plant management before clearing trees

Cleared areas will be re-vegetated

2 Poaching Avoid illegal poaching Contractual obligation to avoid illegal poaching

Provide adequate knowledge to the workers relevant government regulations and punishments for illegal poaching





3 Discharge from construction sites

Minimize surface and ground water contamination.

Reduce contaminant and sediment load 4discharged into water bodies affecting humans and aquatic life

Install temporary drainage works (channels and bunds) in areas required for sediment and erosion control and around storage areas for construction materials

Prevent all solid and liquid wastes entering waterways by collecting waste where possible and transport to approved waste disposal site or recycling depot

Ensure that tires of construction vehicles are cleaned in the washing bay (constructed at the entrance of the construction site) to remove the mud from the wheels. This should be done in every exit of each construction vehicle to ensure the local roads are kept clean.

4 Soil Erosion and siltation

Avoid sediment and contaminant loading of surface water bodies and agricultural lands.

Minimize the length of time an area is left disturbed or exposed.

Reduce length of slope of runoff

Construct temporary cut off drains across excavated area

Setup check dams along catch drains in order to slow flow and capture sediment

Water the material stockpiles, access roads and bare soils on an as required basis to minimize dust.

Increase the watering frequency during periods of high risk (e.g. high winds)

All the work sites (except permanently occupied by the plant and supporting facilities) should be reinstated to its initial conditions (relief, topsoil, vegetation cover).

5 Excavation, earth works, and construction yards

Proper drainage of rainwater and wastewater to avoid water and soil contamination.

Prepare a program for prevent/avoid standing waters, which LECPL will verify in advance and confirm during implementation

Establish local drainage line with appropriate silt collector and silt screen for rainwater or wastewater connecting to the existing established drainage lines already there

6 Ponding of water

Prevent mosquito breeding

Do not allow ponding of water especially near the waste storage areas and construction camps

Discard all the storage containers that are capable of storing of water, after use or store them in inverted position





Reinstate relief and landscape.

7 Storage of hazardous and toxic chemicals

Prevent spillage of hazardous and toxic chemicals

Implement waste management plans

Construct appropriate spill containment facilities for all fuel storage areas

Remediate the contaminated land using the most appropriate available method to achieve required commercial/industrial guideline validation results

8 Land clearing Preserve fertile top soils enriched with nutrients required for plant growth or agricultural development.

Strip the top soil to a depth of 15 cm and store in stock piles of height not exceeding 2 m and with a slope of 1:2

Spread the topsoil to maintain the physio–chemical and biological activity of the soil.

The stored top soil will be utilized for covering all disturbed area and along the proposed plantation sites

Topsoil stockpiles will be monitored and should any adverse conditions be identified corrective actions will include: o Anaerobic conditions – turning the

stockpile or creating ventilation holes through the stockpile;

o Erosion – temporary protective silt fencing will be erected;

9 Avoid change in local topography and disturb the natural rainwater/ flood water drainage

Ensure the topography of the final surface of all raised lands are conducive to enhance natural draining of rainwater/flood water;

Reinstate the natural landscape of the ancillary construction sites after completion of works

10 Construction vehicular traffic

Control vehicle exhaust emissions and combustion of fuels

Use vehicles with appropriate exhaust systems and emission control devices.

Establish and enforce vehicle speed limits to minimize dust generation

Cover haul vehicles carrying dusty materials (cement, borrow and quarry) moving outside the construction site

Level loads of haul trucks travelling to and from the site to avoid spillage

Use of defined haulage routes and reduce vehicle speed where required.

Transport materials to site in off peak hours.

Regular maintenance of all vehicles





All vehicle exit points from the construction site shall have a wash-down area where mud and earth can be removed from a vehicle before it enters the public road system.

11 Minimize nuisance due to noise

Maintain all vehicles in good working order

Make sure all drivers comply with the traffic codes concerning maximum speed limit, driving hours, etc.

12 Avoid impact on existing traffic conditions

Prepare and submit a traffic management plan

Restrict the transport of oversize loads.

Operate transport vehicles, if possible, in non–peak periods to minimize traffic disruptions.

13 Prevent accidents and spillage of fuels and chemicals

Restrict the transport of oversize loads.

Operate transport vehicles, if possible, in non–peak periods to minimize traffic disruptions.

Design and implement safety measures and an emergency response plan to contain damages from accidental spills.

Designate special routes for hazardous materials transport.

14 Construction machinery

Prevent impact on air quality from emissions

Use machinery with appropriate exhaust systems and emission control devices.

Regular maintenance of all construction machinery

Provide filtering systems, duct collectors or humidification or other techniques (as applicable) to the concrete batching and mixing plant to control the particle emissions in all stages

15 Reduce impact of noise and vibration on the surrounding

Appropriately site all noise generating activities to avoid noise pollution to local residents.

Ensure all equipment is in good repair and operated in correct manner.

Install high efficiency mufflers to construction equipment.

Operators of noisy equipment or any other workers in the vicinity of excessively noisy equipment are to be provided with ear protection equipment

The project shall include reasonable actions to ensure that construction works do not result





in vibration that could damage property adjacent to the works

16 Construction activities

Minimize dust generation Water the material stockpiles, access roads and bare soils on an as required basis to minimize dust.

Increase the watering frequency during periods of high risk (e.g. high winds).

Stored materials such as gravel and sand should be covered and confined

Locate stockpiles away from sensitive receptors

17 Reduce impact of noise and vibration on the surrounding

Avoid driving hazard where construction interferes with pre– existing roads

Notify adjacent landholders or residents prior to noise events during night hours

Install temporary noise control barriers where appropriate

Avoid working during 21:00 to 06:00 within 500m from residences

18 Minimizing impact on water quality

Stockpiles of potential water pollutants (i.e. bitumen, oils, construction materials, fuel, etc.) shall be locate so as to minimize the potential of contaminants to enter local watercourses or storm-water drainage

19 Storm-water runoff from all fuel and oil storage areas, workshop, and vehicle parking areas is to be directed into an oil and water separator before being discharged to any watercourse.

Prepare an Emergency Spills Contingency Plan shall be prepared.

20 Siting and location of construction camps

Minimize impact from construction footprint

Arrange accommodation in local towns for small workforce

Locate the construction camps at areas which are acceptable from environmental, cultural or social point of view

Construction Camp Facilities

Minimize pressure on local services

Adequate housing for all workers

Safe and reliable water supply.

Hygienic sanitary facilities and sewerage system.

Treatment facilities for sewerage of toilet and domestic wastes

Storm water drainage facilities.

In–house community entertainment facilities





21 Disposal of waste

Minimize impacts on the environment

Ensure proper collection and disposal of solid wastes in the approved disposal sites

Store inorganic wastes in a safe place within the household and clear organic wastes on daily basis to waste collector.

Establish waste collection, transportation and disposal systems

Ensure that materials with the potential to cause land and water contamination or odor problems are not disposed of on the site.

Ensure that all on-site wastes are suitably contained and prevented from escaping into neighbouring fields, properties, and waterways, and the waste contained does not contaminate soil, surface or groundwater or create unpleasant odors for neighbours and workers

22 Fuel supplies for cooking purposes

Discourage illegal fuel wood consumption

Provide fuel to the construction camps for domestic purpose

Conduct awareness campaigns to educate workers on preserving the protecting the biodiversity and wildlife of the project area, and relevant government regulations and punishments on wildlife protection

23 Site Restoration

Restoration of the construction camps to original condition

Restore the site to its condition prior to commencement of the works

24 Construction activities near religious and cultural sites

Avoid disturbance to cultural and religious sites

Stop work immediately and notify the site manager if, during construction, an archaeological or burial site is discovered.

It is an offence to recommence work in the vicinity of the site until approval to continue is given by the plant management.

Maintain appropriate behaviour with all construction workers especially women and elderly people

Resolve cultural issues in consultation with local leaders and supervision consultants

25 Best practices Minimize health and safety risks

Implement suitable safety standards for all workers and site visitors which should not be less than those laid down on the international standards (e.g. International Labor Office guideline on ‘Safety and Health in Construction; World Bank Group’s





‘Environmental Health and Safety Guidelines’) and contractor’s own national standards or statutory regulations,

Provide the workers with a safe and healthy work environment, taking into account inherent risks in its particular construction activity and specific classes of hazards in the work areas

Provide personal protection equipment (PPE) for workers, such as safety boots, helmets, masks, gloves, protective clothing, goggles, full–face eye shields, and ear protection.

Maintain the PPE properly by cleaning dirty ones and replacing them with the damaged ones

26 Water and sanitation facilities at the construction sites

Improve workers’ personal hygiene

Provide portable toilets at the construction sites and drinking water facilities.

Portable toilets should be cleaned once a day.

All the sewerage should be pumped from the collection tank once a day into the common septic tank for further treatment

8.15 CHANGE MANAGEMENT

An environmental assessment of LEPCL Power Plant has been made on the basis of existing technology

and processes in use at the time of preparing this report. However, it is possible that changes in project

design may occur in future. This section describes the mechanism that will be put into place to manage

changes that might affect the project’s environmental impacts. Potential changes in project design

have been categorized as first-order, second-order, and third-order. These are defined below.

8.15.1 FIRST-ORDER CHANGE

A first-order change is one that leads to a significant departure from the project described in the

environmental assessment report and consequently requires a reassessment of the environmental

impacts associated with the change.

In such an instance, the environmental impacts of the proposed change will be reassessed, and the

results sent to the Sindh EPA for approval.

8.15.2 SECOND-ORDER CHANGE

A second-order change is one that entails project activities not significantly different from those

described in the environmental assessment report, and which may result in project impacts whose

overall magnitude would be similar to the assessment made in this report.



In case of such changes, the environmental impact of the activity will be reassessed, additional

mitigation measures specified if necessary, and the changes reported to the Sindh EPA.

8.15.3 THIRD-ORDER CHANGE

A third-order change is one that is of little consequence to the environmental assessment reports’

findings. This type of change does not result in impact levels exceeding those already discussed in the

environmental assessment; rather these may be made onsite to minimize the impact of an activity.

The only action required in this case will be to record the change in the change record register.

To illustrate the magnitude of changes within these orders, examples are presented in the table below.

These types of changes presented encompass a range of scenarios for illustration purposes only, and

by no means reflect any intention on the part of LECPL to make these changes. The list is also not meant

to be comprehensive, i.e., inclusive of all possible changes that may potentially take place in the design

or operation of the plant as described in the EIA. For any changes not described in this table, the

definition of the first, second and third order changes will be used to determine its category.

Change First Order Second Order Third Order

Criteria Significant departure from the project described in the EIA OR significant change in the environmental conditions

Relatively small departure from the project described in the EIA OR relatively small change in the environmental conditions

Minor departure from the project described in the EIA OR relatively minor change in the environmental conditions.

Consequence Major change in nature or magnitude of environmental impacts

Environmental impacts may change but the overall impact remain same

Nature or magnitude of environmental impacts remain unchanged

Required Action

Reassess the environmental impact and obtain environmental approval from Sindh EPA

Reassess the environmental impact and inform Sindh EPA at least a month before undertaking the change

Reassess the environmental impact, if needed and keep a record

Examples

Power plant location

Relocated such that the villages in the area of influence changes

Recoated such that the villages in the area of influence do not changes

Power plant capacity

If increased significantly (for example, by more than 33%) from the proposed capacity.

If increased but not significantly (for example, by more than 20% but less than 33%) from the proposed capacity.

If increased by a small amount (for example, by less than 20%) from the proposed capacity.

Technology A different technology or process for power generation resulting in altogether different environmental impacts.

A different technology or process for power generation, resulting in environmental impacts of similar nature or magnitude.



8.15.4 CHANGES TO THE EMMP

Change-Record Register: A change-record register will be maintained at the site, in order to document

any changes in EMMP and procedures related to changes in the project design, construction plan or

external environmental changes affecting the EMMP. These changes will be handled through the

change management mechanism discussed above. In case of a change in EMMP, following actions will

be taken:

A meeting will be held between the Owners and the contractor representatives, to discuss and

agree upon the proposed addition to the EMMP

Based on the discussion during the meeting, a change report will be produced collectively, which

will include the additional EMMP clause and the reasons for its addition

A copy of the report will be sent to the head offices of the Owners and the contractor

All relevant project personnel will be informed of the addition

8.16 EMERGENCY RESPONSE PLAN

Emergency Response operations will be managed and monitored by the Emergency Response Team

headed by the EHS Manager of LEPCL. The Response team will ensure that the operations are carried

out in minimal time avoiding any fire, safety and security hazard and affecting the environment. The

team will ensure:

Evaluation of the situation to identify the most important steps, which must be taken first and can

have an important bearing on the overall action to be taken.

Deployment of required manpower and equipment.

Organizing required logistical support so that there are no bottlenecks hampering the operation.

See to it that injured persons are cared for.

Respond to calls for ambulances for shifting the injured persons to neighbourhood hospitals/

healthcare units.

Isolate all sources of ignition and environmental hazards.

Evacuation of people who are in immediate or imminent danger.

EHS Manager and/or in-charge of the Campsite will exert positive leadership and give instructions

calmly, firmly, explicitly, and courteously and obtain help of law enforcement agencies, if

necessary.

Block roads if necessary for safety of operations.

Arrange for emergency notifications of water shed areas, public utilities, and the like to safeguard

the public and property.

Surveillance and monitoring operations.

Retrieval and disposal of earth/debris and resources affected by the hazard at approximate site.

Termination of clean-up operation.

In developing of an emergency response plan, the following 9 steps must be followed:



1

• Review hazard or threat scenarios identified during the risk assessment for each company site / facility

2

• Assess the availability and capabilities of resources for incident stabilization including people, systems and equipment available within your company (Fire department, internal medical services, plant physician).

3

• Talk with public emergency services (e.g., fire, police and emergency medical services) to determine their response time to your facility, knowledge of your facility and its hazards and their capabilities to stabilize an emergency at your facility

4

• Determine if there are any regulations pertaining to emergency planning at your facility (i.e. escape & rescue plans corresponding with ISO 2360:2009)

5

• Develop protective actions for life safety and hazard and threat-specific emergency procedures

6

• Coordinate emergency planning with public emergency services to stabilize incidents involving the hazards at your facility

7

• Train personnel so they can fulfill their roles and responsibilities (occupational first aiders, evacuation assistants and fire protection assistants).

8

• Carry out regular evacuation drills to check the emergency response plan for its effectiveness as well as to train of staff how to act in an emergency scenario

9

• Based on the lessons learned from the evacuation drills and in case of facility changes, the emergency response plan must be adjusted and other measures need to be developed.



The potential hazards, which have to be considered when developing an emergency response plan,

are listed in the chart below.



9.0 CONCLUSION

Screening of potential environmental impacts at the different stages of the Project namely siting,

construction and operation of the proposed 1 x 600 MW Coal Power Plant by Lucky Electric Power

Company Limited (LEPCL) leads to the following conclusion:

Environmental impacts of the proposed Project are localized to the microenvironment of the

activity area and consequently are rated as minor or insignificant.

Severity of impact of the activities is of small order.

Implementation of recommended mitigation measures and strictly following the environmental

management plan shall minimize the impact of proposed activities.

The proposed project will create enormous potentiality of economic and social development of the

region. The present electricity crisis and rising electricity demand urge installation of new power plant.

It will offer large number of job opportunity during its life time where the local people will get priority.

The potential benefits of the project will compensate the negative impact if the prescribed EMP is

implemented with honesty. The proposed Project would, on adoption of mitigation measures, have

no significant impact on the microenvironment and macroenvironment of the project area.

This EIA Study finds that the proposed project would fulfil the requirements of sustainable

development by being socially equitable, and economically viable in improving the quality of life for all

citizens of Pakistan, without altering the balance in the resources of the ecosystem of the region.

The Study therefore recommends that the EIA report should be approved with the provision that the

suggested mitigation measures will be adopted and the Environmental Management & Monitoring

Plans shall be followed in letter and spirit.

EMC Pakistan Pvt. Ltd Annexures


ANNEXURES

EMC Pakistan Pvt. Ltd Annex – I


ANNEX – I Sindh Environmental Protect Act, 2014

EMC Pakistan Pvt. Ltd Annex – I - 1


EMC Pakistan Pvt. Ltd Annex – II


ANNEX – II IEE / EIA Regulation 2014

EMC Pakistan Pvt. Ltd Annex – II - 1


EMC Pakistan Pvt. Ltd Annex – III


ANNEX – III National Environmental Quality Standards (NEQS)

EMC Pakistan Pvt. Ltd Annex – III - 1


Eia lucky electric power company 660 mw coal power project

Environment

Transcript of Eia lucky electric power company 660 mw coal power project