Project for Least Cost Generation and Transmission...

Project for

Least Cost Generation and TransmissionExpansion Plan

(Plant Capacity Analysis)in

Pakistan

Final Report

March 2015

Japan International Cooperation Agency(JICA)

Nippon Koei Co., Ltd.

Project for

Least Cost Generation and TransmissionExpansion Plan

(Plant Capacity Analysis)in

Pakistan

Final Report

March 2015

Japan International Cooperation Agency(JICA)


Project for Least Cost Generation and Transmission Expansion Plan (Plant Capacity Analysis) in Pakistan

Final Report

March 2015 Nippon Koei Co., Ltd.

Location Map

Prepared by the JICA Study Team based on the map downloaded at http://www.freemap.jp/

Thermal Power Plant (500 MW or above)

Hydro Power Plant (500 MW or above)

Solar Power Plant (500 MW or above)

Nuclear Power Plant (500 MW or above)

AJK

Islamic Republic of Pakistan

* Islamabad

* Lahore

* Karachi

Sindh Province

Punjab Province

Khyber Pakhtunkhwa

Province

Gilgit Baltistan

Balochistan Province

Federally Administered Tribal Areas

■ Mangla (1,000 MW

+ Ongoing 62 MW )

■ Tarbela (3,478 MW + Ongoing 1,410 MW)

Ghazi Barotha (1,450 MW) ■

HUBCO (1,292 MW) ■

■ Jamshoro (880 MW)

Bin Qasim ■

(1,820 MW, K-Electric)

■ Guddu (1,655 MW

+ Ongoing 777 MW )

■ KAPCO (1,638 MW)

Uch (586 MW + Ongoing 404 MW ) ■

Chashma (665 MW + Ongoing 680 MW) ■

■ Muzaffargarh (1,370 MW)

■ Dasu (Ongoing 2,160 MW)

Diamer Bhasha

(Ongoing 4,500 MW) ■

■ Lower Palas Valley (Ongoing 665 MW)

■ Neelum-Jhelum (Ongoing 969 MW)

■ Quaid-e-Azam Solar Park

(Ongoing 1,000 MW)

■ Nandipur (Ongoing 566 MW)

Karachi (132 MW + Ongoing 2,200 MW) ■


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March 2015 i Nippon Koei Co., Ltd.

Summary

Background

The Government of Pakistan (GOP) started its energy sector reform, as one of the priority issues

in the Extended Funded Facility arrangement approved by the International Monetary Fund

(IMF) in September 2013. To promote the reform process, the Energy Sector Reform Program

(ESRP) is formulated in collaboration with the Japan International Cooperation Agency (JICA),

World Bank (WB) and Asian Development Bank (ADB). Formulation of long-term least cost

generation and transmission expansion plan (LCP) is the key components of ESRP. The National

Transmission and Despatch Company Limited (NTDC) requested JICA to provide their

assistance in formulating LCP. In reply to the request, JICA decided to dispatch the study team.

Objectives and Scope of the Study

Objectives

This study aims to collect and analyze the data of power plant capacity for the formulation of

LCP.

Terms of Reference

Data collection and analysis of plant capacity of existing power plants;

Data collection and analysis of construction and rehabilitation plans of power plants;

Reporting to and coordination with the collaborating consultants; and

Explanation to and discussion with JICA regarding the output of the above activities

Present Situation of Power Generation Capacity

The current total installed capacity of power generation in the national grid of Pakistan is 20,849

MW, of which the installed capacity of thermal power plants is 12,748 MW, the same of hydro

power plants is 7,097 MW, the same of renewable energy power plants is 207 MW, and the same

of nuclear power plants is 797 MW.

In K-Electric grid, there are thermal power plants of which the total installed capacity is 2,422

kW. The installed capacity of the total grid comprising the national grid and K-Electric grid is

23,271 MW.

The net dependable capacity of the thermal power plants of the national grid is 10,502 MW which

is 82% of their installed capacity. The existing dependable capacity of hydro power generation

decreases in winter. It comes down to 2,449 MW which is around 35% of the installed capacity.

Pakistan has large and viable resources in wind, solar, biomass, waste, geothermal, and small

hydro power. However, the renewable energy has so far failed to achieve a significant share in the

total generation capacity of the country.


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March 2015 ii Nippon Koei Co., Ltd.

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

operation of nuclear power plants. There are two nuclear power stations i.e. Karachi Nuclear

Power Plant (KANUPP) and Chashma Nuclear Power Plant Unit-1 and 2 (C-1 and C-2) in

Pakistan. The total installed capacity of the nuclear power plants is 797 MW.

There is no power import from the foreign countries to the national grid as of January 2015.

Ongoing Project and Development Plans

In order to analyze the future development of electric power sources, the current development

projects and plans were categorized into “ongoing project” and “development plan” in this study.

Guddu and Nandipur GTCC power stations are ongoing project of thermal power plants by public

sector of which the total installed capacity is 1,342 MW. Besides, one ongoing project of thermal

power plant is implemented by private sector of which the installed capacity is 404 MW.

The total installed capacity of ongoing project of hydro power plants is 10,873 MW. The major

hydro power plants are promoted by WAPDA; e.g., Dasu-1 Project with installed capacity of

2,160 MW and Dimaer Bhasha Project with installed capacity of 4,500 MW. The total installed

capacity of ongoing project of hydro power plants by WAPDA is 10,645 MW.

Regarding renewable energy, the total installed capacity of the ongoing projects, which are wind,

solar, and biomass projects, is 1,490 MW. The installed capacity of solar projects is largest in the

renewable energy projects which is 1,000 MW.

PAEC is proceeding with the construction of new nuclear power plants at Chashma Nuclear Plant

site and KANUPP site. The total installed capacity of ongoing nuclear power projects is 2,880

MW.

Ongoing project of power import is only CASA-1000 which is aiming to export surplus

electricity generated by hydro power in both the Kyrgyz Republic and Tajikistan during the

summer period to Pakistan and Afghanistan. The designed capacity for Pakistan to import by this

project is 1,000 MW.

The installed capacity of development plans for thermal, hydro, and renewable energy are 5,280

MW, 19,452 MW, and 2,269 MW, respectively. The development plans of nuclear and power

import were not confirmed in this study.

Conclusion

The possibility for an ongoing project to be materialized is higher than that of a development plan

and the lead time of an ongoing project is shorter than that of a development plan. To understand

the real situation of future development of electric power sources, the period-wise installed

capacity of the ongoing projects were analyzed. By the end of 2017, the installed capacity of

electric power source will increase by 6,813 MW, and by the end of 2020 and 2025, the same will

increase by 4,415 MW and 6,761 MW, respectively.

To realize how the above increase of electric power source capacity will mitigate the power

shortage problem in Pakistan in the short term, the gaps between the forecasted demand and the


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March 2015 iii Nippon Koei Co., Ltd.

net dependable supply capacity in winter were calculated in December 2014, December 2017,

and December 2020. The result shows that the situation of electricity shortage will not be

mitigated; rather, it will become worse.

Some of the development plans may be completed and enter into commercial operation by the

end of December 2020. It seems, however, that such realization is not so simple. Due to the

optimistic assumption of the commercial operation date for the development plans, many

development plans will fail to commence commercial operation at the prescribed date.

From the above situation, short-term countermeasures, like until the end December 2020, to

increase the power source capacity needs to be taken.


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March 2015 iv Nippon Koei Co., Ltd.

Table of Contents

Summary .................................................................................................................................................. i

Table of Contents .................................................................................................................................... iv

Glossary ................................................................................................................................................. vii

Definitions of Terminologies ............................................................................................................. vii

Abbreviation and Key Terms ............................................................................................................ viii

Chapter 1 INTRODUCTION ............................................................................................................ 1

1.1 Background .............................................................................................................................. 1

1.2 Objectives and Scope of the Study ........................................................................................... 2

1.3 Study Team ............................................................................................................................... 3

1.4 Record of Major Activities ....................................................................................................... 4

Chapter 2 PRESENT SITUATION OF POWER PLANTS .............................................................. 5

2.1 Overview of Power Supply in Pakistan ................................................................................... 5

2.2 Present Situation of Thermal Power Plants .............................................................................. 9

2.2.1 Outline .............................................................................................................................. 9

2.2.2 Government-owned Thermal Power Plants .................................................................... 10

2.2.3 Thermal Power Plants of Independent Power Producers ............................................... 13

2.2.4 Assessment of Generating Capability of Thermal Power Plants .................................... 16

2.3 Present Situation of Hydro Power Plants ............................................................................... 20

2.3.1 Outline ............................................................................................................................ 20

2.3.2 Government-owned Hydro Power Plants ....................................................................... 21

2.3.3 Hydro Power Plants of Independent Power Producers ................................................... 23

2.3.4 Assessment of Generating Capability of Hydro Power Plants ....................................... 23

2.4 Present Situation of Renewable Energy Generating Plants .................................................... 25

2.4.1 Outline ............................................................................................................................ 25

2.4.2 Wind Power Plants ......................................................................................................... 25

2.4.3 Solar Power Plants .......................................................................................................... 26

2.4.4 Biomass Power Plants .................................................................................................... 27

2.5 Present Situation of Nuclear Power Plant .............................................................................. 28

Chapter 3 ONGOING PROJECTS AND DEVELOPMENT PLANS ............................................ 29

3.1 General ................................................................................................................................... 29

3.2 Thermal Power Plants ............................................................................................................ 32

3.2.1 Ongoing Projects of Thermal Power Plant ..................................................................... 32

3.2.2 Development Plans of Thermal Power Plant .................................................................. 33

3.3 Hydro Power Plants................................................................................................................ 35


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March 2015 v Nippon Koei Co., Ltd.

3.3.1 Ongoing Projects of Hydro Power Plant ........................................................................ 35

3.3.2 Development Plans of Hydro Power Plant ..................................................................... 38

3.4 Generating Plants of Renewable Energy ................................................................................ 43

3.4.1 Ongoing Projects of Renewable Energy ......................................................................... 43

3.4.2 Development Plans of Renewable Energy ..................................................................... 45

3.5 Nuclear Power Plant and Power Import ................................................................................. 49

3.5.1 Nuclear Power ................................................................................................................ 49

3.5.2 Power Import .................................................................................................................. 50

Chapter 4 CONCLUSION .............................................................................................................. 55

Appendices

Appendix A-1 Collected Data Sheet (Thermal Power Plants)

Appendix A-2 Letter from CPPA (COO-CPPA 10426 dated November 20, 2014)

Appendix A-3 Unit Data of Power Plants with Commissioning Date (Thermal Power Plants)

Appendix A-4 Photographs (Thermal Power Plants)

Appendix B-1 Collected Data Sheet (Hydro Power Plants)

Appendix B-2 Hydropower Development in Pakistan (Location Map)

Appendix B-3 Unit Data of Power Plants with Commissioning Date (Hydro Power Plants)

Appendix C-1 Collected Data Sheet (Renewable Energy)

Appendix C-2 Monthly Histogram and Standard Deviation of Generation by Zorlu Wind

Farm

Appendix D Energy Infrastructure Map - 2012

List of Tables

Table 2.2.1-1 Existing Thermal Power Station (The National Grid) ..................................... 9

Table 2.2.2-1 Summary of Jamshoro Power Station ........................................................... 10

Table 2.2.2-2 Heat Rate Determination of Jamshoro Power Station by NEPRA ................ 11

Table 2.2.2-3 Summary of Guddu Power Station ................................................................ 11

Table 2.2.2-4 Summary of Muzaffargah Power Station ...................................................... 12

Table 2.2.2-5 Summary of Lakhra Power Station ............................................................... 12

Table 2.2.3-1 Summary of Kot Addu Power Station ........................................................... 13

Table 2.2.3-2 Summary of Hub Power Station .................................................................... 14

Table 2.2.3-3 Existing Thermal Power Station (K-Electric)................................................ 15

Table 2.2.3-4 Summary of Bin Qasim Power Station I ....................................................... 15

Table 2.3.1-1 Existing Hydro Power Stations (WAPDA and Hydro IPPs) .......................... 20

Table 2.3.2-1 Summary of Tarbela Power Station ............................................................... 21

Table 2.3.2-2 Summary of Mangla Power Station .............................................................. 21

Table 2.3.2-3 Summary of Ghazi Barotha Power Station.................................................... 22

Table 2.3.2-4 Summary of Warsak Power Station ............................................................... 23

Table 2.4.2-1 Existing Wind Power Plants in Pakistan ........................................................ 25


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Table 2.4.4-1 Existing Biomass Power Plants in Pakistan .................................................. 27

Table 2.5-1 Information of Chashma Nuclear Power Plant .............................................. 28

Table 3.2.1-1 Ongoing Projects of Thermal Power Plants by Public Sector ....................... 32

Table 3.2.1-2 Ongoing Projects of Thermal Power Plants by Private Sector ...................... 32

Table 3.2.2-1 Development Plans of Thermal Power Plants by Public Sector .................... 33

Table 3.2.2-2 Development Plans of Thermal Power Plants by Private Sector ................... 33

Table 3.3.1-1 Ongoing Projects of Hydro Power Plant of WAPDA .................................... 35

Table 3.3.1-2 Ongoing Projects of Hydro Power Plant of Provincial Organization ............ 37

Table 3.3.1-2 Ongoing Projects of Hydro Power Plant through PPIB................................. 37

Table 3.3.2-1 Development Plans of Hydro Power Plan by WAPDA ................................. 38

Table 3.3.2-2 Development Plans of Hydro Power Plan of Provincial Organizations (1/2)39

Table 3.3.2-3 Development Plans of Hydro Power Plan of Provincial Organizations (2/2)39

Table 3.3.2-4 Development Plans of Hydro Power Plants through PPIB ............................ 40

Table 3.3.2-5 Development Plans of Hydro Power Plan by Provincial Organization (1/2) 41

Table 3.3.2-6 Development Plans of Hydro Power Plan by Provincial Organization (2/2) 42

Table 3.4.1-1 Ongoing Wind Power Projects ...................................................................... 43

Table 3.4.1-2 Ongoing Solar Power Projects ....................................................................... 44

Table 3.4.1-3 Ongoing Biomass Power Projects ................................................................. 45

Table 3.4.2-1 Development Plans of Wind Power Generation ............................................ 46

Table 3.4.2-2 Development Plans of Solar Power Generation ............................................ 47

Table 3.4.2-3 Development Plans of Biomass Power Generation ....................................... 48

Table 3.5.1-1 Ongoing Nuclear Power Projects .................................................................. 49

Table 3.5.2-1 Total Project Cost and Financial Arrangement of CASA-1000 ..................... 51

Table 3.5.2-2 Information of CASA-1000 ........................................................................... 51

Table 4-1 Electric Power Source Capacity in Pakistan: Existing and Future ................ 55

Table 4-2 Periodwise Installed Capacity of Ongoing Projects ...................................... 56

Table 4-3 Estimated Gap Between Demand and Net Dependable Supply Capacity in

Winter ............................................................................................................ 57

List of Figures

Figure 2.1-1 Organizational Structures for Power Supply ................................................... 5

Figure 2.1-2 Current System Diagram of the National Grid ................................................ 8

Figure 2.2.4-1 Share of Fuel Type/System Type of Thermal Power Plant ............................ 16

Figure 2.2.4-2 Historical Trend of Thermal Power Plants Commissioning .......................... 17

Figure 2.2.4-3 Comparison of Fuel Cost Component and Variable O&M Cost ................... 18

Figure 2.2.4-4 Comparison of Capacity Factor ..................................................................... 19

Figure 2.3.4-1 Monthly Maximum / Minimum Output and Generated Electricity (Hydro) . 24

Figure 2.4.2-1 Monthly Averaged Wind Speed and Monthly Generation ............................. 26

Figure 3.1-1 Process for Thermal or Hydro Power Generation by Private Sector ............. 30

Figure 3.1-2 Process for Renewable Energy Power Generation by Private Sector ............ 31

Figure 3.5.2-1 Location of CASA-1000 ................................................................................ 52

Figure 3.5.2-2 Location of 220 kV Cross-border Transmission Line from Iran ................... 53


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Glossary

Definitions of Terminologies

Electric Power Grid

The national grid

The electric power grid operated by the National Transmission and Despatch Company

Limited of which the system voltage is 500 kV and 220 kV.

K-Electric grid

The electric power grid operated by K-Electric Limited which consist of transmission

system and distribution system.

DISCO grids

The electric power grids operated by the Distribution Companies which consist of

transmission system and distribution system.

The total grid

The synchronized one electric power grid in Pakistan comprising the national grid,

K-Electric grid, and DISCO grids.

Electric Power Capacity

Installed Capacity

The rated or name plate capacity of power generation plant guaranteed under the standard

ambient conditions.

Derated Capacity

( = Installed Capacity - decreased amount due to the difference from standard ambient

conditions)

This is the guaranteed capacity under the ambient condition at the site of installation. Since

the capacity of thermal power plant is largely affected by the ambient temperature, the

derated capacity was considered only for r thermal power plant.

Dependable Capacity

( = Installed Capacity or Derated Capacity - decreased amount due to the shortage of input

power for the rated input of power plant or due to aging deterioration of power plant)

This is the expected firm capacity at the installation site at given time. The expected

generation capacity of hydro power plant is totally affected by the amount of water flow.

The decreased amount due to aging deterioration of thermal and nuclear power plants is

larger compared to that of hydro power plant.

Generating-end Capacity/Gross Capacity

Capacity at output terminal of generator.


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Sending-end Capacity/Net Capacity

( = Generating-end Capacity - station service consumption)

This is the output capacity to the transmission line from power station. Since the station

service consumption of hydro power station and renewable energy power station is small,

the sending-end capacities of hydro and renewable energy power stations were regarded as

same as their generating-end capacities in this study.

Net Dependable Capacity

The expected firm output capacity to the transmission line from given power station at given

time in line with the definitions of Sending-end Capacity/Net Capacity and Dependable

Capacity.

Abbreviation and Key Terms

Organizations / State Owned Companies in Pakistan

AEDB Alternative Energy Development Board

AJK-PDO AJK Power Development Organization

CPPA Central Power Purchasing Agency

DISCO(s ) Distribution Company(ies)

GENCO(s ) Generation Company(ies)

GHCL GENCO Holding Company Limited

GOP Government of Pakistan

HEB Hydro Electric Board (AJK)

IESCO Islamabad Electricity Supply Company

KANUPP Karachi Nuclear Power Plant

MEPCO Multan Electric Power Company

MOWP Ministry of Water and Power

MPNR Ministry of Petroleum and Natural Resources

NEPRA National Electric Power Regulatory Agency

NPCC National Power Control Centre

NTDC National Transmission and Despatch Company Limited

PAEC Pakistan Atomic Energy Commission

PC Planning Commission

PEC Pakistan Engineering Council

PEDO Pakhtunkhwa Energy Development Organization (formerly SHYDO and PHYDO)

PEPCO Pakistan Electric Power Company Limited

PHYDO Pakhtunkhwa Hydel Development Organization (Currently PEDO)

PPDB Punjab Power Development Board

PPIB Private Power Infrastructure Board

PSO Pakistan State Oil Company Limited

SHYDO Sarhad Hydel Development Organization (Currently PEDO)

SNGPL Sui Northern Gas Pipeline Limited

SSGCL Sui Southern Gas Company Limited

TCEB Thar Coal Energy Board

WAPDA Water and Power Development Authority

WPPO WAPDA Power Privatization Organization

Companies in Pakistan

HUBCO Hub Power Company Limited

KAPCO Kot Addu Power Company Ltd.

KESC Karachi Electric Supply Company (currently K-Electric)


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Foreign Companies

BEEGIL Bright Eagle Enterprises Group Investments Limited

BT Barki Tajik (National Transmission Company in Tajikistan)

CPIH China Power International Holdings

DABS Da Afghanistan Breshna Sherkat (National Transmission Company in Afghanistan)

EDBI Export Development Bank of Iran

KOMIPO Korea Midland Power Co., Ltd.

NEGK National Electric Grid of Kyrgyzstan (National Transmission Company in Kyrgyz Republic)

TBEA Tebian Electric Apparatus Stock Co., Ltd.

International Donor Agencies / Organizations

ADB Asian Development Bank

IDA International Development Association

IMF International Monetary Fund

J ICA Japan International Cooperation Agency

USAID U.S. Agency for International Development

WB World Bank


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General Terms

AC Alternative Current

ARE Alternative and Renewable Energy

BOO Build, Own and Operate

BOOT Build, Own, Operate and Transfer

BTU British Thermal Unit (equivalent to 1055.06 J)

CCPP Combined Cycle Power Plant

COD Commercial Operation Date

CPP Captive Power Plant

DC Direct Current

DE Diesel Engine

DG Distributed Generation

EIA Environmental Impact Assessment

EOI Expression of Interest

EPA Energy Purchase Agreement

EPC Engineering, Procurement and Construction

ESIA Environmental and Social Impact Assessment

FBC Fluidized Bed Combustion

FCC Fuel Cost Component

FO Furnace Oil

FY Fiscal Year or Financial Year

G /S Grid Station

GEPS Gas Engine Power Station

GT Gas Turbine

GTCC Gas Turbine Combined Cycle

GTPS Gas Turbine Power Station

HHV High Heating Value

HPP Hydro Power Plant

HRSG Heat Recovery Steam Generator

HSD High Speed Diesel

HVDC High Voltage Direct Current

IA Implementation Agreement

IPP(s ) Independent Power Producer(s)

LCP Least Cost Planning of the Power Generation and Transmission

LOI Letter of Interest

LOS Letter of Support

LSFO Low Sulfur Furnace Oil

NGPS Natural Gas Power Station

POE Panel of Experts

PPA Power Purchase Agreement

RE Renewable Energy

RFO Residual Furnace Oil

SITE Sindh Industrial and Trading Estate

SPC Specific (or Special) Purpose Company

SPP Small Power Plant

SPS Steam Power Station

ST Steam Turbine

TPS Thermal Power Station

V O&M Variable O&M


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Name of Provinces and Territories in Pakistan

(Provinces)

Balochis tan

KPK (KP) Khyber Pakhtunkhwa (formerly NWFP: North-West Frontier Province)

Punjab

Sindh

(Territories)

AJK Azad Jammu and Kashmir

FATA Federally Administered Tribal Areas

GB Gilgit-Baltistan

ICT Islamabad Capital Territory

Name of Consulting Firms for the Study

NK Nippon Koei Co., Ltd.

NEC National Engineering Corporation

Units of Area and Volume

Acre 1 Acare = 4,047 m2

MAF Million Acre Feet (1 MAF= 1,233.482 m3)

Units of Currency and Exchange Rates

JPY Japanese Yen (JPY 1 = PKR 0.8619, as of FEB 04, 2015, State Bank of Pakistan)

PKR Pakistani Rupee

USD US Dollar ( USD 1 = PKR 101.1311, as of FEB 04, 2015, State Bank of Pakistan)


Final Report

March 2015 1 Nippon Koei Co., Ltd.

Chapter 1 INTRODUCTION

1.1 Background

The Government of Pakistan (GOP) started its energy sector reform, as one of the priority issues

in the Extended Funded Facility arrangement approved by the International Monetary Fund

(IMF) in September 2013. To promote the reform process, the Energy Sector Reform Program

(hereinafter “ESRP”) is formulated in collaboration with the Japan International Cooperation

Agency (JICA), World Bank (WB) and Asian Development Bank (ADB). The overall objective

of ESRP is to support the implementation and goals of the National Power Policy 2013 approved

by GOP to develop an efficient and consumer oriented electric power system that meets the needs

of its people and economy sustainably and affordably.

This program includes a broad range of issues such as tariff and subsidies management,

improvement of sector performance and opening of the market to private sector, and improving

accountability and transparency of the energy sector. One of the key components among these

reforms is the introduction of long-term least cost generation and transmission expansion plan

(hereinafter “LCP”) for 20 years, which is to be drafted by the National Transmission and

Despatch Company Limited (NTDC). LCP is scheduled to be approved by the National Electric

Power Regulatory Agency (NEPRA) by December 2015 and its periodic update is one of the

indicative triggers to be achieved in the matrix of ESRP. The National Power System Expansion

Plan formulated by NTDC in 2011 is planning to update it into LCP.

For this purpose, NTDC requested JICA to support NTDC in terms of technical expertise on

formulating LCP especially in the optimization method of power development plan and

transmission system development plan. Against this background, JICA decided to start this

project which aims to support the formulation of the draft LCP and capacity development of

NTDC in order to acquire expertise in formulating LCP and updating it every three years.

As part of the technical assistance required, the study team (Plant Capacity Analysis) was

organized by JICA to collect and analyze plant capacities to generate electricity and transfer it to

the national grid of Pakistan.


Final Report


1.2 Objectives and Scope of the Study

Objectives

This study (Plant Capacity Analysis) aims to collect and analyze the data of power plant capacity

for the formulation of LCP.

Terms of Reference

Data collection and analysis of plant capacity of existing power plants including data

collection of principal specification of power plants (mainly thermal and hydro) ;

Data collection and analysis of construction and rehabilitation plans of power plants

Reporting to and coordination with the collaborating consultants (herein after referred to as

LCP consultants); and

Explanation to and discussion with JICA regarding the output of the above activities

The LCP consultants will formulate the least cost plan by using software program. The project

team will collect data and provide analysis of the base data as the input to the software for the

LCP consultants.

Since the LCP consultants provided the forms of the data collection sheet (herein after referred to

as Data Sheet) for thermal power plants and hydro power plants, the project team prepared

additional Data Sheet for nuclear power plants, solar power plants, wind power plants, and

biomass power plants.

Target Area

Entire area of Pakistan

Related Organizations

The study team interviewed and collected data at the following organizations.

NTDC: National Transmission and Dispatch Company Limited

CPPA: Central Power Purchasing Agency, a department under NTDC

WPPO: WAPDA Power Privatization Organization, a department under NTDC

WAPDA: Water and Power Development Agency

GHCL: GENCO Holding Company Limited

GENCOs: Generation Companies

MOWP: Ministry of Water and Power

MPNR: Ministry of Petroleum and Natural Resources

NEPRA: National Electric Power Regulatory Authority

AEDB: Alternative Energy Development Board

PPIB: Private Power Infrastructure Board


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1.3 Study Team

The study team is composed of the following three international experts and four national

experts/staff.

International Experts

1 Mr. FUKUCHI Tomoyasu Team Leader / Plant Capacity Analysis (Renewable Energy) NK

2 Mr. SATO Akira Plant Capacity Analysis (Thermal) NK

3 Mr. OGAWA Ryosuke Plant Capacity Analysis (Hydro) NK

NK: Nippon Koei Co., Ltd.

National Experts/Staff

1 Mr. Babar Mahmood National Expert Team Leader / National Expert for Plant Capacity Analysis (Hydro/ Renewable Energy)

NEC

2 Mr. Abdullah Akram Bajwa National Expert for Plant Capacity Analysis (Thermal) (until October 31, 2014)

NEC

3 Mr. Zahid Umair National Expert for Plant Capacity Analysis (Thermal) (from November 5, 2014)

NEC

4 Mr. Tahir Nazir Secretary / Office Administrator / Security-in-Charge NEC

NEC: National Engineering Corporation


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1.4 Record of Major Activities

The major activities of the study are shown below.

Month September

2014

October

2014

November

2014

December

2014

January

2015

February

2015

March

2015

Study in

Pakistan

Wok in Japan

Submission of

Report

Study in Pakistan

First Site Study:

Arrived in Lahore on September 15, 2014

Left Lahore on September 24, 2014 (arrived in Tokyo on September 25, 2014)

Second Site Study:

Arrived in Lahore on October 27, 2014

Left Lahore on November 12, 2014 (arrived in Tokyo on November 13, 2014)

Third Site Study:

Arrived in Lahore on December 9, 2014

Left Lahore on December 17, 2014 (arrived in Tokyo on December 18, 2014).

Submission of Reports

Inception Report: Beginning of September 2014

Interim Report: Beginning of December 2014

Final Report: Beginning of March 2015

Inception Report

(Beginning of September)

Interim Report

(Beginning of December)

Final Report

(Beginning of March)


Final Report


Chapter 2 PRESENT SITUATION OF POWER PLANTS

2.1 Overview of Power Supply in Pakistan

Organization

Figure 2.1-1 shows all the organizational structures for the electric power sector in Pakistan. The

figure shows the position of the different organizations and departments according to their role

and authority.

Function

Note: NEPRA: National Electric Power Regulatory Authority

AEDB: Alternative Energy Development Board

PPIB: Private Power and Infrastructure Board

PAEC: Pakistan Atomic Energy Commission

GHCL: GENCO Holding Company Limited

Regulatory Oversight Executive Oversight SNGPL: Sui Northern Gas Pipeline Limited Executive

SSGCL: Sui Southern Gas Company Limited & Regulation

PSO: Pakistan State Oil Company Limited

PEPCO: Pakistan Electric Power Company Limited

IA: Implementation Agreement

DG: Distributed Generation

IA/Sovereign Guarantee

Energy

Supplier

Energy Source Supply

(To be SPP or IPP after completion of the installation of plant.)

Generation /

Transmission

& Dispatch /

Distribution

Bulk Sales Contracts & Sales

Wheeling Contract Electricity Import from Iran to NTDC System

Bilateral

Sales

Contract Bulk Sales Contracts

Supply for Consumer in Isolated Area nearby Iran

(No Physical Connection to NTDC/DISCOs System,

however DISCO collect the bill from the consumers.)

Oversight on Loan Project

Application/Power Supply Application/Power Supply

Note: WAPDA: Water and Power Development Authority

NPCC: National Power Control Centre

CPPA: Central Power Purchase Agency

Bilateral Sales Contract Bilateral Sales Contract WPPO: WAPDA Power Privatization Organization Consumer

DISCO: Distribution Company

SPP: Small Power Plant

CPP: Captive Power Plant

(Consumers in Karachi) (Consumers except in Karachi)

NTDC

SPP/CPP

K-Electric

IPPs Existing Thermal

Power Projects

(Provincial Territory)

ARE-IPPs & ARE-DGs(ARE Project

excluding Hydro Power)

New Hydro(All Capacity)

and Thermal IPP

NuclearPower Plants

GENCOs(Thermal under

PEPCO)

AEDB

Provincial / AJK Dept.

(AJK-PDO, PEDO, PPDB)

DISCOs

PPIB PAEC

NEPRA

Ministry of Water and Power(MOWP)

Bulk Consumers Consumers

(Residential / Agricultural / Commercial / Industrial)

Consumers (Residential / Agricultural / Commercial / Industrial)

Gas: SNGPL/SSGCLOil: PSO etc.Coal: Private Suppliers

Iranian Grid

Bulk Consumers

Bulk Consumers

PEPCO

NPCC WPPOCPPA

WAPDA ( Hydro)

GHCL

Source: Prepared by the JICA Study Team

Figure 2.1-1 Organizational Structures for Power Supply


Final Report


The power sector in Pakistan is under the umbrella of the Ministry of Water and Power (MOWP).

The executive oversight of all power related bodies is done by MOWP. MOWP delegates its

powers to various departments like the Alternative Energy Development Board (AEDB), Private

Power and Infrastructure Board (PPIB), Pakistan Atomic Energy Commission (PAEC), and

GENCO Holding Company Limited (GHCL).

AEDB is only responsible for the development of renewable energy projects by the private sector

excluding hydro power projects. PPIB is responsible for development of all private sector power

projects excluding renewable energy projects but including all kinds of hydro power projects.

PAEC is responsible for developing new nuclear power projects and also for the operations of

existing nuclear power projects. GHCL is an autonomous body of GOP that makes decision

regarding Generation Companies (GENCOs).

The Water and Power Development Authority (WAPDA) is currently responsible for planning,

developing and operating hydro power projects in Pakistan. Originally, WAPDA was the sole

entity responsible for the generation, transmission, and distribution of power in the country but as

a measure of power sector reform, WAPDA was disintegrated and its role was limited to hydro

power only.

There are provincial and areal bodies/departments that are assisting the private sector to invest in

power projects in their territory. These include Punjab Power Development Board (PPDB) in

Punjab Province, Pakhtunkhwa Energy Development Organization (PEDO) in Khyber

Pakhtunkhwa (KP or KPK) Province, Sindh Energy Department in Sindh Province and Hydro

Electric Board (HEB) in Azad Jammu and Kashmir (AJK). These departments are handling all

kinds of power projects and also handling the issues of land allocation.

The National Electric Power Regulatory Authority (NEPRA) is the only regulatory body that

exists in the power sector. NEPRA is mandated to decide tariffs of new and existing power plants

irrespective of being public or private sector. They are also responsible for issuing generation

licenses and power purchase acquisitions.

The Pakistan Electric Power Company Limited (PEPCO), although, announced to be dissolved

many times by GOP, exists and currently has a very limited role of paying the government

subsidy to GENCOs. They are also handling the issues of litigation and human resources-related

matters except those for WAPDA employees.

The National Transmission and Dispatch Company Limited (NTDC) is dealing with the control

of demand and supply balance, the system operation, and the system development of the national

grid. The organizational chart shows that there are three departments in NTDC. The National

Power Control Centre (NPCC) is the implementing body to control the national grid. Another two

departments, namely, WAPDA Power Privatization Organization (WPPO) and Central Power

Purchase Agency (CPPA), are handling payment to independent power producers (IPPs) and

billing Distribution Companies (DISCOs). WPPO was established under the Power Policy of

1994 and all the IPPs established under this power policy are thermal power plants. CPPA is

responsible for payments to IPPs established under the Power Policy of 2002 and onwards.

Besides, both WPPO and CPPA are also responsible to conduct the dependability test for these


Final Report


IPPs to ensure that current capacity is at the contracted level to make capacity payments

accordingly.

For the upcoming projects, the role of CPPA and WPPO is also different. WPPO is responsible

for the negotiations for the energy purchase agreement (EPA) and power purchase agreement

(PPA) with IPPs for thermal and hydro power projects during the period before the commercial

operation date (COD). Once the project is commissioned, the future handling of the project is

transferred to CPPA. During the period before COD, CPPA only handles the negotiation for the

projects that use renewable energy (RE) like wind, solar or biomass. These RE power projects are

also dealt with by CPPA after COD.

Although the provincial and AJK departments can issue the letter of interest (LOI), evaluate

feasibility studies through panel of experts (POE), at the stage of implementation agreement (IA),

letter of support (LOS), and sovereign guarantee, they need to take the project to a federal entity

like AEDB or PPIB. In case of RE projects excluding all kinds of hydro power, they shall contact

AEDB, and for thermal and all kinds of hydro power projects, they shall contact PPIB for

issuance of above to the IPPs.

The National Grid

The national grid of Pakistan consists of 500 kV and 220 kV systems which include 12 of 500 kV

grid station, 29 of 220 kV grid station, 5,077 km of 500 kV transmission line, and 7,359 km of

220 kV transmission line. The national grid extends from north to south within the country and

connects all the major power stations and network of all ten DISCOs as well as K-Electric grid.

Some areas in the Balochistan Province, located southwest of the country, receive electricity from

Iran. This grid is not connected to the national grid of Pakistan.

Figure 2.1-2 shows the current system diagram of the national grid, and Energy Infrastructure

Map - 2012 issued by Ministry of Petroleum and Natural Resources (MPNR) is attached as

Appendix D for reference.


Final Report


Source: NTDC

Figure 2.1-2 Current System Diagram of the National Grid


Final Report


2.2 Present Situation of Thermal Power Plants

2.2.1 Outline

Table 2.2.1-1 shows the list of all thermal power plants in the national grid of Pakistan,,

including both public and private sectors.

Table 2.2.1-1 Existing Thermal Power Station (The National Grid)

Sr .

No.Name of Power Station Fuel

Ins talled Capac ity

(MW)

Net Dependable

Capac ity (MW)

Public Sec tor (GENCOs)

1 TPS Jamshoro #1-4 Gas/FO/RFO 880 648

2 GTPS Kotri #1-7 Gas/HSD 144 120

1,024 768

3 TPS Guddu Steam #1-4 Gas/FO 640 380

4 TPS Guddu C.C. #5-13 Gas 1,015 800

1,655 1,180

5 TPS Muzaffargarh #1-6 RFO/FO/Gas 1,350 1,033

6 GTPS Faisalabad #1-9*2 Gas/HSD 244 0.00

7 SPS Faisalabad #1-2*2 FO/Gas/RFO 132 0.00

1,726 1,033

8 FBC Lakhra Coal 150 31

150 31

9 TPS Quetta*1 Gas 35 25

4,590 3,037

Pr ivate Sec tor (Thermal IPPs )

1 Kot Addu Power Company Ltd. (KAPCO) RFO/Gas/HSD 1,638 1,345

2 Hub Power Project (HUBCO) RFO 1,292 1,205

3 Koihnoor Energy Ltd. (KEL) RFO 131 124

4 AES Lalpir Ltd. RFO 362 350

5 AES Pak Gen (Pvt) Ltd. RFO 365 350

6 SEPCOL RFO 135 110

7 Habibullah Energy Ltd. (HCPC) Gas 140 131

8 Uch Power Project Gas 586 551

9 Rousch (Pak) Power Ltd. Gas 450 395

10 Fauji Kabirwala (FKPCL) Gas 157 151

11 Saba Power Company RFO 134 126

12 Liberty Power Project Gas 235 212

13 Altern Energy Ltd. (AEL) Gas 31 29

14 Attock Generation PP RFO 163 156

15 ATLAS Power RFO 219 214

16 Engro P.P. Daharki, Sindh HSD/Gas/FO 226 214

17 Saif P.P. Sahiwal, Punjab Gas/HSD 225 205

18 Orient P.P. Balloki, Punjab Gas/HSD 225 213

19 Nishat P.P. Near Lahore RFO 200 195

20 Nishat Chunian Proj. Lahore RFO 200 196

21 Foundation Power Gas 174 172

22 Saphire Muridke Gas/HSD 225 212

23 Liberty Tech RFO 200 196

24 Hubco Narowal RFO 220 214

25 Halmore Bhikki HSD/Gas 225 199

8,158 7,465

Total Thermal (Public Sec tor + Pr ivate Sec tor ) 12,748 10,502

Note *1: TPS Quetta is an independent power station by public sector.

*2: Faisalabad is not generate in 2013

FO: Furnace Oil / HSD: High Speed Diesel / RFO: Residual Furnace Oil

Sub-Total Thermal IPPs

Sub-Total GENCO-I

Sub-Total GENCO-II

Sub-Total GENCO-III

Sub-Total GENCO-IV

Sub-Total GENCOs

Source: Prepared by the JICA Study Team based on the copies of licenses published at NEPRA website


Final Report


In the national grid (excluding K-Electric grid), thermal power stations under the public sector,

i.e., GENCOs and IPPs are under the private sector in Pakistan.

Net dependable capacities of GENCOs were obtained by requiring to fill in Data Sheet which is

the data collection form sheet of the JICA Study Team and the collected Data Sheets for thermal

power plants are shown in Appendix A-1. On the other hand, net dependable capacities of IPPs

were not collected by the same way because Data sheets were returned only from five IPPs out of

25 IPPs which the JICA Study Team requested to fill in. Hence, the data of IPPs is based on the

letter from CPPA which is shown in Appendix A-2. The generation capacity (unit-wise) and date

of commissioning are shown in Appendix A-3.

The total installed capacity of thermal power plants is 12,748 MW; however, net dependable is

82% of installed capacity. Percentage of the net dependable capacity of GENCOs is about 66%

and that of IPP is 92% of their respective installed capacity. The low net dependable capacity of

GENCOs is caused due to low capacity factor of each plant and stopping of power supply from

some power plants which have low plant efficiency.

MOWP has jurisdiction GHCL, and GHCL looks at the affairs of the four thermal generation

companies.

2.2.2 Government-owned Thermal Power Plants

Major thermal power stations owned by GENCOs are described below.

(1) Jamshoro Power Station (GENCO I)

The summary of Jamshoro Power Station is shown in Table 2.2.2-1.

Table 2.2.2-1 Summary of Jamshoro Power Station

Location Jamshoro District, Sindh Province

Commissioning December 1989 to January 1991

Total Installed Capacity and Unit Nos.

880 MW 4 units (Unit Nos. 1 to 4)

Fuel Type Unit No. 1: RFO only Unit Nos. 2 to 4 : Dual fuel firing (RFO and Gas)

Generation System Type Steam turbine

Source: Prepared by the JICA Study Team based on Generation License No. GL/01/2002-Jamshoro Power Company Ltd published on the website of NEPRA

Four units of oil fired thermal power plant were installed at the Jamshoro Power Station. Unit No.

1 was supplied by the Japanese manufacturers, namely, Mitsui Shipbuilding Works (boiler) and

Fuji Electric Ltd. (turbine generator). Unit Nos. 2 to 4 adopted the Chinese manufacturers’ boilers

and turbines, namely, Harbin Boiler and Harbin Turbine/Electric. The operation data of Unit No.

1 (Block I) and Unit Nos. 2 to 4 (Block II) is managed separately due to the difference of system,

as mentioned, between Blocks I and II.

The large rehabilitation works to recover deterioration were carried out for Unit Nos. 2 to 4 with

the support of U.S. Agency for International Development (USAID) in FY 2012-2013.

Economizer tubes and heaters for high pressure feed water were replaced, and then heat rates of

Unit Nos. 2 to 4 were recovered.


Final Report


According to NEPRA Tariff Determination (TRF-56 24-11-2006), the total capacity charge was

Rs.271.40/kW/month initially. After revision of the scalable components (e.g., fuel cost, salaries)

and considering the implementation of the rehabilitation works, new tariff determination

(TRF-225 12-9-2014) was issued in which total capacity charge was changed to

Rs.387.54/kW/month in accordance with the repair and maintenance cost of Rs.49.63/kW/month.

Heat rates of all units after the rehabilitation works on Unit Nos. 2 to 4 are shown in Table

2.2.2-2. Average heat rates after the rehabilitation are improved to about 12,092 BTU/kWh

compared with the average of about 12,563 BTU/kWh before the rehabilitation of the units. Net

dependable capacity of the power station is about 648 MW for the four units.

Table 2.2.2-2 Heat Rate Determination of Jamshoro Power Station by NEPRA (Unit: BTU/kWh)

Unit Fuel Net Heat Rate (HHV)

Unit No.1 RFO 10,774.64

RFO 12,092.80

Gas 11,764.75Unit No.2 to 4

Note:

Net heat rate is equal to input energy (BTU/hr) divided by sending-end power generation (kW)

Input energy is calculated as fuel consumption multiplied by calorific value of the fuel.

Source NEPRA Tariff Determination TRF-225 12-9-2014

(2) Guddu Power Station (GENCO II)

The summary of Guddu Power Station is shown in Table 2.2.2-3.

Table 2.2.2-3 Summary of Guddu Power Station

Location Jacobabad District, Sindh Province

Commissioning From March 1974 to March 1994


1,655 MW 4 units of steam turbines (Unit Nos. 1 to 4) 3 sets of gas turbine combined cycle (GTCC) plant (Unit Nos. 5 to 13)

Fuel Type Gas

Generation System Type Steam turbine (Unit Nos. 1 to 4) Gas turbine (Unit Nos. 7 to 12) Steam turbine by HRSG (Unit Nos. 5, 6 and 13)

Source: Prepared by the JICA Study Team based on based on site survey hearing

For the existing Guddu plants, the rehabilitation works were carried out in large and completed in

June 2014 by USAID. During the rehabilitation works, gas turbine components were replaced for

two units (Nos. 5 and 7), which resulted in 9.8%, increase of the plant efficiency and 3.39%

reduction of the heat rate according to the explanation by the staff on the site visit. The upgrade

for Unit Nos. 9 and 10 was carried out in 2011 by self- financing. However, occurrences of major

trouble were recorded on Unit No. 9 in April 2014 and operation is currently suspended. Only

four units (Nos. 1, 5, and 8) of 13 units operate at the power station as of November 2014 due to

major overhaul (e.g., open inspection of turbine) and troubles such as damage on turbine blades.

The new Gas Turbine Combined Cycle (GTCC) plant is planned to compose of two sets of gas

turbine 255.60 MW (installed capacity) each and one set of Heat Recovery Steam Generator

(HRSG) 265.50 MW (installed capacity). The design thermal efficiency and capacity factor are

56.4% and 60%, respectively, and the designed net dependable capacity of design is about 720


Final Report


MW. Fuel gas will be supplied from Kandh Kot gas field. The COD of the plant is scheduled in

March 2015.

After COD of the new units, four units (Nos. 1 to 4) will be decommissioned.

(3) Muzaffargah Power Station (GENCO III)

The summary of Muzaffargah Power Station is shown in Table 2.2.2-4.

Table 2.2.2-4 Summary of Muzaffargah Power Station

Location Muzaffargah District, Punjab Province

Commissioning From September 1993 to December 1997


1,350 MW 6 units (Unit Nos. 1 to 6)

Fuel Type Dual fuel firing ( RFO and Gas)

Generation System Type Steam turbine

Source: Prepared by the JICA Study Team based on based on site survey hearing

The Muzaffargah Power Station is composed of six units. Unit Nos. 1 to 3 were supplied by the

Russian manufacturer, and Unit Nos. 4 to 6 by the Chinese manufacturer. The power station has

an installed capacity of 1,350 MW. However, net dependable capacity was reduced under 900

MW in 2011 due to deterioration. The rehabilitation work was carried out by USAID in FY

2012-2013. The net dependable capacity has been recovered by approximately 1,100 MW at

present.

New tariff determination in consideration of the rehabilitation works has not been informed by

NEPRA as of January 2015, and the heat rate after the rehabilitation is also not publicized.

(4) Lakhra Power Station (GENCO IV)

The summary of Lakhra Power Station is shown in Table 2.2.2-5.

Table 2.2.2-5 Summary of Lakhra Power Station

Location Dadu District, Sindh Province

Commissioning June 1995 to January 1996


150 MW 3 units (Unit Nos. 1 to 3)

Fuel Type Domestic coal

Generation System Type Fluidized bed combustion (FBC) boiler and steam turbine

Source: Prepared by the JICA Study Team based on “Data Collection Survey on Thar Coal Field in Pakistan” Final Report, JICA, 2013

The Lakhra Power Station is the only coal fired power station in Pakistan. The fuel coal is

supplied from Lakhra coal mine, which is located approximately 20 km to the west of the power

station. Heat value of the coal is 3,400 kcal/kg and sulfur content of the coal is 5.0%. The low

capacity factor and performance for all units continued since commissioning due to many

technical problems. For instance, sulfur content of the coal is high, and lime stone has low purity.

This affects the inside of furnace through de-sulfurization. Another is the erosion corrosion of

furnace wall due to occurrence of lots of ash coupled with the lack of management to use the

proper amount of limestone.


Final Report


The comprehensive rehabilitation work for boiler No. 1 only started in 2006, and it was

re-commissioned in March 2007. Then, the unit operates at 31 MW against 50 MW of installed

capacity. The other units have not been renovated because of financial problem; consequently, the

parts of Units Nos. 2 and 3 are used as spare parts for Unit No. 1. Unit No. 1 is low net

dependable capacity; however, the fuel price of coal is Rs.4.50/kWh, which is much cheaper than

other fuel such as oil (Rs.19.50/kWh at Jamshoro Power Station). This is why the plant continues

to still operate as of January 2015.

2.2.3 Thermal Power Plants of Independent Power Producers

Major thermal power stations operated by IPPs are described below.

(1) Kot Addu Power Company Ltd.

Kot Addu Power Company Ltd. (KAPCO) was incorporated in 1996 with the purpose to

contribute economical power to power supplier. The summary of KAPCO is shown in Table

2.2.3-1.

Table 2.2.3-1 Summary of Kot Addu Power Station

Location Muzaffargah District, Punjab Province

Commissioning 5 phases from 1985 to 1996


1,638 MW 3 blocks GTCC

Fuel Type Multi fuel firing (Natural Gas, Low Sulfur Fuel Oil, and High Speed Diesel)

Generation System Type Gas Turbine and HRSG Combined

Source: Prepared by the JICA Study Team by site survey hearing

The power plant was installed and owned by WAPDA (from 1987 to 1996), and then it was

privatized to the National Power (now International Power) of the United Kingdom in 1996. GOP

sold 52% shares of the plant along with management, whereas GOP still holds 48% of the

ownership.

All of the generators run on the base load only. Tariff based capacity factor is 60% as per CPPA.

However, actual capacity factor for FY 2013 was 50% to 56% only due to fuel shortage. KAPCO

is the only plant which runs on low sulfur furnace oil (LSFO) in Pakistan.

The plant has three maintenance blocks, and the average thermal efficiency for the latest block is

47.4% and the overall plant efficiency is 41.5%.

Auxiliary consumption is 3% at optimum load. Annual dependable capacity test of the plant (6

hours test) is carried out by WPPO and net dependable capacity is decided every year based on

this test result. For FY 2014, net dependable capacity is 1,345 MW at 30 °C. After upgrading (due

to plant life extension), the capacity is increased by 1,379 MW, and average heat rate in 2013 is

7,816 BTU/kWh.

(2) Hub Power Station

The Hub Power Station is the first IPP established by following the Power Policy 1994 in

Pakistan. The summary of Hub Power Station is shown in Table 2.2.3-2.


Final Report


Table 2.2.3-2 Summary of Hub Power Station

Location Lasbela District, Balochistan Province

Commissioning Jul.1996 to Mar.1997


1,292 MW 4 x 323 MW

Fuel Type RFO

Generation System Type Drum Sub-C Type, Steam Turbine Generator

Source: Prepared by the JICA Study Team based on the presentation document by HUBCO

The boilers were supplied by IHI, a Japanese manufacturer and the turbine generators were

supplied by Ansaldo Energia, Italy.

The capacity factor, load factor and thermal efficiency have been kept more than 60%, 70% and

38% respectively from the commissioning. And the average monthly heat rate has been

maintained under 9,000 BTU/kWh. The technical management and maintenance resulted in

proper condition of the plants. It was detected through proper monitoring that steam leakage on

boiler tubes occurred frequently. The rehabilitation work of boiler tube was carried out in 2014.

(3) K-Electric Limited and Bin Qasim Power Station

K-Electric Limited, formerly known as Karachi Electric Supply Company Limited (KESC), is at

present the only vertically-integrated power utility in Pakistan that manages the generation,

transmission and distribution of electricity to the city. The company comprises over 2.2 million

customers, and covers Karachi and the nearby towns of Dhabeji and Gharo in Sindh and Hub,

Uthal, Vindar and Bela in Balochistan.

The entity was nationalized in 1952, however, re-privatized as Karachi Electric Supply

Corporation (KESC) in November 2005. KESC came under new management in September 2008

and was renamed as the Karachi Electric Supply Company. The company has been renamed again

as “K-Electric Limited” in January 2014.

K-Electric produces electricity by its own generation units with an installed capacity of 2,422

MW. It also has PPAs for 1,021 MW from various IPPs, WAPDA, and Karachi Nuclear Power

Plant (KANUPP). These purchases are based on an optimized generation cost that is governed by

the fuel cost at the respective power facilities and their operating efficiencies.

Power stations owned by K-Electric are shown in Table 2.2.3-3.


Final Report


Table 2.2.3-3 Existing Thermal Power Station (K-Electric)

Sr .


Ins talled

Capac ity

(MW)

De-Rated

Capac ity * 1

(MW)

Net

Dependable

Capac ity

COD

1 TPS Bin Qasim I Unit #1-6 Gas/RFO 1,260.00 1,200.00 1,170.60 from 1983 to 1997

2 TPS Korangi Unit 3 Gas/RFO 125.00 90.00 80.10 1970

3 CCPP Korangi Unit #1-5 (4GT+1ST) Gas/HSD 220.00 213.40 199.70 2008-2009

4 GTPS Korangi Town Unit 3 Gas/HSD 25.00 18.00 17.10 1978

5 GEPS Korangi Town Unit #1-32 Gas 97.31 87.65 84.61 2009

6 GTPS SITE Unit 2 Gas 25.00 18.00 17.10 No Information

7 GEPS SITE Gas 97.31 87.65 84.61 2009

8 CCPP Bin Qasim II Gas/HSD 572.67 528.40 502.10 2012

Total 2,422.29 2,243.10 2,155.92

Note: *1 Reduce by ambient temperature and include some limitation by deterioration Source: NEPRA License No. GL/04/2002 Modification IV for KESC

Generation Capacity Enhancement

Over the last few years, K-Electric has enhanced its net dependable capacity by 871 MW while it

has improved its fleet efficiency gain by 24% from January-December 2008 to

January-December 2013. The improvement was achieved due to addition of new plants. Around

52% of electricity is generated by K-Electric’s own generation units at the end of 2013.

Coal Conversion Plan of Bin Qasim Power Station

Bright Eagle Enterprises Group Investments Limited (BEEGIL), an Indonesian investor,

formed Special Purpose Company (SPC) named K-Energy (Pvt.) Ltd. K-Electric will lease

Unit Nos. 3 and 4 of Bin Qasim Power Station I to K-Energy under long-term lease

agreement.

K-Energy will acquire the function of an IPP and sell generated power to K-Electric.

Engineering, Procurement and Construction (EPC) agreement has been signed with Harbin

Electric International.

Bin Qasim Power Station I (Result of Site Visit)

Table 2.2.3-4 Summary of Bin Qasim Power Station I

Location Karachi, Sindh Province

Commissioning

Unit Nos. 1 and 2: 1983 Unit Nos. 3 and 4 :1990 Unit No. 5: 1991 Unit No. 6: 1997


1,260 MW 6 x 210 MW

Fuel Type Dual fuel firing (RFO and Gas)

Generation System Type Drum Sub-C Type, Steam Turbine Generator

Source: Prepared by the JICA Study Team based site survey hearing

Unit Nos. 1, 2, 5 and 6 were installed by Hitachi of Japan, while Unit Nos. 3 and 4 were installed

by Ansaldo Energia, Italy. The power plant is located along the Karachi coast; hence, huge

amount of sea water is directly used as the cooling water. The intake point of cooling water is

from the bay side and the discharge point is located in the Port Qasim. Plant efficiency is 33%


Final Report


(High Heating Value: HHV). There is no installation of de-sulfurization system although sulfur

content of fuel is high (approximately 2.0 to 3.0%).

Annual maintenance is scheduled for 30 days per year. In addition, 55 days of turbine overhaul

works are planed every five years. For every periodical maintenance, inspectors and supervisors

from manufactures are invited. As a result of the maintenance works, all plants are kept in good

condition although Unit Nos. 1 and 2 have operated more than 25 years.

Photographs at the site surveys of thermal power plants are attached as Appendix A-4.

2.2.4 Assessment of Generating Capability of Thermal Power Plants

Fuel type share for capacity and system type share against the installed capacity as of January

2015 are shown in Figure 2.2.4-1. Plants under commissioning (Guddu and Nadipur, Uch II) are

also taken into account in the figure.

Note ST; Steam Turbine, GT; Gas Turbine, DE; Diesel Engine or Gas Engine (Internal Combustion Engine) Source: Prepared by the JICA Study Team based on NTDC Annual Report with modification based on Installed capacities mentioned on the latest copies of license published on the website of NEPRA

Figure 2.2.4-1 Share of Fuel Type/System Type of Thermal Power Plant

In terms of fuel typ, GENCO uses RFO and gas as fuel in almost same ratio (18% and 17%)

whereas its coal use is about 1%.

In terms of the system classification, steam turbine type and gas turbine type are 25% and 12%,

respectively, in GENCOs, and steam turbine, gas turbine and diesel engine are 29%, 24%, and

10% in IPPs, respectively. Significant difference is not identified for each fuel type and system

type between GENCOs and IPPs.

Historical trend of thermal power plants commissioning up to 2015 is shown in Figure 2.2.4-2.

GENCO

RFO

18%

GENCO

Gas

17%

GENCO

Coal

1%

IPP RFO

41%

IPP Gas

23%

Fuel Type Rate for the Capacity

(Install Capacity Basis)

GENCO

ST

25%

GENCO

GT

12%

IPP ST

29%

IPP GT

24%

IPP DE

10%

System Type Rate for the Capacty

(Install Capacity Basis)


Final Report


Note ST; Steam Turbine, GT; Gas Turbine, DE; Diesel Engine or Gas Engine (Internal Combustion Engine) Source: NTDC Power System Statics 2011-2012

Figure 2.2.4-2 Historical Trend of Thermal Power Plants Commissioning

The figure shows the trend of commissioning for all existing thermal plants in Pakistan. It is

generally said that the life time of thermal plant is 30 years, therefore units installed before 1985

are supposed not to be considered as dependable power source in the Least Cost Generation and

Transmission Expansion Plan since such plants will be de-commissioned in the near future.

Because of this reason, the issues regarding the generation capacity of thermal power plants

installed in 1985 or later are assessed below.

As for GENCO, main thermal plants are the Jamshoro Power Station, the Muzaffargh Power

Station, and the Guddu Power Station. After the installation of Muzaffargh No. 4 in 1997, no new

plant had been installed for 17 years by GENCOs. Two new GTCC plants (Guddu and Nandipur)

were installed in 2014. These plants are currently under test operation (as of December 2014).

Some IPPs were established and started to supply power in Pakistan by the enactment of the

Power Policy of 1994. The figure shows the increase of installed capacity by 15 IPPs. After

having no installation of new plants from 2002 to 2008, IPPs installed six plants of diesel or gas

engine with heat recovery steam generator (HRSG) from 2009 to 2011.

Fuel cost component (FCC) and variable O&M cost for each power station are shown in Figure

2.2.4-3.

0

200

400

600

800

1,000

1,200

1,400

1,600

befo

re 1

979

1980

1981

1982

1983

1984

1985

1986

1987

1988

1989

1990

1991

1992

1993

1994

1995

1996

1997

1998

1999

2000

2001

2002

2003

2004

2005

2006

2007

2008

2009

2010

2011

2012

2013

2014

2015

Insta

lled C

apacity

in the

Year

(MW

)

Year

IPP DE

IPP GT

IPP ST

GENCO GT

GENCO ST


Final Report


Note: (R) RFO, (G) Gas, (H) HSD Source: Prepared by the JICA Study Team based CPPA Energy Procurement Repot September 2014

Figure 2.2.4-3 Comparison of Fuel Cost Component and Variable O&M Cost

This figure shows that the fuel cost of RFO is about three times that of gas, and fuel cost of

GENCOs is about 30% higher than IPPs. This indicates the heat rate of GENCOs is higher than

IPPs; in other words, the efficiency of GENCOs is lower than IPPs.

The capacity factors of each power station in September 2014 are shown in Figure 2.2.4-4.

0

5

10

15

20

25

30

35

Jam

sh

oro

Blo

ck

I (R

)

Jam

sh

oro

Blo

ck

II (R

)

Ko

tri 3

-7 (G

)

Gud

du B

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Fauji K

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(G

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usch (G

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R)

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an

Po

wer (

R)

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i (G

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(G

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Lib

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En

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n (

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Saif P

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)

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gro

En

erg

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)

Halm

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(H

)

Co

st (R

s./kW

h)

Variable O&M Cost Fuel Cost Compornent

GENCOs IPPs


Final Report


Note; (R) RFO, (G) Gas, (H) HSD Source: Prepared by the JICA Study Team based CPPA Energy Procurement Repot September 2014

Figure 2.2.4-4 Comparison of Capacity Factor

The above figure shows that all the capacity factors of GENCOs plant are less than 50% except

Quetta; however, almost all IPPs have around 70% or more. The reason could not be analyzed

since enough data for analysis was not available from IPPs.

From the point of life cycle evaluation, GENCOs’ plants were installed earlier than IPPs;

therefore, the systems and facilities of GENCOs could have deteriorated more than that those of

IPPs. In addition, it is found through hearing that some of IPPs, e.g., KAPCO and HUBCO,

carried out replacement work of their facilities for the purpose of life time extension by own

budget. This results in the IPPs’ plants being kept in good conditions.

On the other hand, there is not enough budget allocation for repairing and replacement works on

GENCOs’ plants. Therefore, it is recommendable to formulate strategies such as construction of

proper system, maintenance plans and secure budgets for increasing efficiency or reducing heat

rate.

0

10

20

30

40

50

60

70

80

90

100

Jam

shoro

Blo

ck I

(R)

Jam

shoro

Blo

ck II

(R

)

Kotr

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(G

)

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(G

)

Guddu C

C 5

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)

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team

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)

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)

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I (R

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Ca

paci

ty F

act

or

(%)

GENCOs IPPs


Final Report


2.3 Present Situation of Hydro Power Plants

2.3.1 Outline

The existing installed hydro power generating capacity in Pakistan is given in Table 2.3.1-1.

Table 2.3.1-1 Existing Hydro Power Stations (WAPDA and Hydro IPPs)

Summer Winter

WAPDA

1 Tarbela KPK Reservoir 3,478 3,633 829 Jul. 1977

2 Mangla AJK Reservoir 1,000 960 350 1967

3 Ghazi Barotha Punjab Small Reservoir 1,450 1,357 794 2003

4 Warsak KPK Reservoir 243 200 139 Jun. 1960

5 Chashma Punjab Run-of-the-River 184 157 67 2000

6 Allai Khwar KPK Small Reservoir 121 121 60 Mar. 2013

7 Jinnah Punjab Run-of-the-River 96 96 40 2012

8-18 Small Hydros2 Punjab/KPK Run-of-the-River 128 81 26

19 Khan Khwar KPK Small Reservoir 72 72 15 Oct. 2010

20 Dubair Khwar KPK Small Reservoir 130 130 65 Jun. 2013

Sub-Total (WAPDA) 6,902 6,807 2,385

IPPs

21 Jagran Hydro AJK Run-of-the-river 30 30 10 Oct. 2000

22 Malakand-III Hydro KPK Run-of-the-river 81 81 20 Nov. 2008

23 New Bong Escape AJK Run-of-the-river 84 84 34 Mar. 2013

Sub-Total ( IPPs ) 195 195 64

Total (WAPDA + IPPs ) 7,097 7,002 2,449

1

2

COD

(Oldes t Unit)

Hydro Capability is based on last 5 years' average. "Dependable Capacity" of Tarbela is more than "Installed Capacity" because of more water

discharge in summer.

11 Stations: Dargai, Malakand, Rasul, Chichoki-Mallian, Shadiwal, Nandipur, Kurram Garhi, Renala, Chitral, Gomal Zam and Jabban

LocationSr .

No.Name of Power Station Type

Ins talled

Capac ity

(MW)

Dependable Capac ity 1

(MW)

Source: Prepared by the JICA Study Team based on "Existing Installed Capacity & Capability of X-WAPDA DISCOs System (as of August 2014)" (NTDC), "Power System Statistics 2013-2014 39th Edition" (NTDC), and website of WAPDA and other related organizations

Table 2.3.1-1 above shows that there are 20 existing hydro power plants owned by WAPDA with

total installed capacity of 6,902 MW, whereas only three are owned and operated as IPPs with

installed capacity of 195 MW only, out of the total 7,097 MW. The collected Data Sheets are

shown in Appendix B-1, and the location map of hydro power plants including ongoing projects

and development plan is shown in Appendix B-2.

The current total installed capacity of the national grid of Pakistan is 20,849 MW, of which 7,097

MW (34%) is hydro. The total capacity of three major hydro power plants, namely Tarbela,

Mangla and Ghazi Barotha, accounts for more than 80% of the total capacity of hydro.

As water is mostly available during summer so it is important to know the hydro capability

during summer and winter. The above table shows that dependable capacity1 for installed hydro

1 The dependable capacity is calculated at NTDC Planning based on the daily maximum output for last five years. At

first the 10 days (1st to 10th day, 11th to 20th day, and 21st to the last day of the month) averages of the daily maximum

output is calculated and then the monthly average is given based on the 10 days average of the daily maximum output.

Dependable capacities of particular month and particular duration are given based on the averages of the particular

month or duration. Therefore the dependable capacity can be regarded expected output for peak hours. Because of and

as the result of the method of the calculation, the dependable capacity of Tarbela in summer is larger than the installed

capacity of the plant.


Final Report


plants is 7,002 MW during summer whereas same is reduced to 2,449 MW during winter.

2.3.2 Government-owned Hydro Power Plants

There are a total of 20 hydro power plants owned by GOP through WAPDA. Of these three are

with reservoir whereas the rests are run-of-river type with small pondage or canal type. The

generation capacity (unit-wise), date of commissioning, and yearly generation are shown in

Appendix B-3.

Details of these major hydro power plants are as follows:

Tarbela

The summery of Tarbela Hydro Power Station is given in Table 2.3.2-1.

Table 2.3.2-1 Summary of Tarbela Power Station

Location Haripur District , KPK Province

Commissioning

Unit Nos. 1 to 4: 1977 Unit Nos. 5 to 8: 1982 Unit Nos. 9 and 10: 1985 Unit Nos. 11 to 14: 1993


3,478 MW 10 x 175 MW (Unit Nos. 1 to 10) + 4 x 432 MW (Unit Nos. 11 to 14)

Annual Generation (2012-2013) 14,788.22 GWh

Reservoir 9,178 million m3 (7,441 million Aft)

Source: Prepared by the JICA Study Team based site survey hearing and website of WAPDA

Besides power generation, the water stored in the reservoir is used for irrigation purposes. The

current generation cost from Tarbela is Rs.0.750915/kWh only.

Mangla

The summery of Mangla Hydro Power Station is given in Table 2.3.2-2.

Table 2.3.2-2 Summary of Mangla Power Station

Location Mirpur District , AJK

Commissioning

Unit Nos. 1 to 4: 1967 to 1969 Unit Nos. 5 and 6: 1974 Unit Nos. 7 and 8: 1981 Unit Nos. 9 and 10: 1993 to 1994


1,000 MW 10 x 100 MW


Reservoir 9,238 million m3 (7,489 million Aft)


Like Tarbela the water stored in the reservoir is used for irrigation purposes besides power

generation. According to the data provided by the plant during the site survey for the JICA Study

Team, the current generation cost from Mangla is only Rs.0.3458/kWh based on yearly average

for the year 2013-2014.

During the site visit on November 6, 2014 by the JICA Study Team, it was informed that the

raising of the Mangla Dam resulted not only in more storage but also increased head. This


Final Report


increase in head will result in increased power generation by 31% and Mangla had already

prepared the refurbishing plan for the power house at the end of which, the installed capacity will

be increased to 1,310 MW. The total project cost is estimated at US$ 480 million. This will

involve the remodeling of inlet and then replacing the runners for the turbines. They have planned

to carry out these two units at a time and every two units will take two years to complete. This

way the whole process will be completed in the next ten years. For the refurbishing of Units Nos.

5 and 6, bids are already received and are under evaluation. USAID has provided US$150 million

as grant aid for this purpose. It is also to be noted that during this phase of refurbishing, the units

will be out of production and will not generate any power. So for planning purposes, the number

of working units of Mangla should be considered as eight units instead of ten units for the next

ten years.

Ghazi Barotha

The summery of Ghazi Barotha Power Station is given in Table 2.3.2-3.

Table 2.3.2-3 Summary of Ghazi Barotha Power Station

Location Attock District, Punjab Province

Commissioning Unit Nos. 1 to 5: 2003 to 2004


1,450 MW 5 x 290 MW


Reservoir 25.5 million m3 (Run-of-the-River Type)


A 51.5 km long special purpose canal was built from Tarbela that brings water to the power house.

The design flow of the power house is 1,600 m3/s and there is a small pondage with storage

capacity of 25.5 million m3, which is good for approximately 4.5 hours of steady operations of

the power plant if no water is available in the channel. The current generation cost from Ghazi

Barotha is only Rs.0.8707/kWh based on yearly average for the year 2013-2014. Of the total

generating cost, 43.91% is for the interest payment that is expected to be reduced in the future.

During the site visit on November 7, 2014 it was revealed that the design flow at the inlet of each

turbine is 465 m3/s whereas the water channel is designed for a flow of 1,600 m

3/s. The water

requirement for the power to run at full load needs a total of 2,325 m3/s. The design flow of the

water channel is only to run a power plant of 1,030 MW. The management of the power house

informed the JICA Study Team that the fifth unit is only running during the peak hours to meet

the demand as instructed by NPCC and this is only for 1 to 1.5 hours each in the morning or

evening or at times of emergency requirement by NPCC. During regular operations of the power

house only four units are running and also at around 90% load factor. If the plant needs to run on

full load the water from the pond is utilized and this is only sufficient to run the four units at full

capacity for 27 hours along with the water from the water channel at full supply level of 1,600

m3/s.


Final Report


Warsak

The summery of Warsak Power Station is given in Table 2.3.2-4.

Table 2.3.2-4 Summary of Warsak Power Station

Location Peshawar District , KPK Province

Commissioning Unit Nos. 1 to 4: 1960 Unit Nos. 5 and 6: 1981


242.96 MW 4 x 40 MW (Unit Nos. 1 to 4) + 2 x 41.48 MW (Unit Nos. 5 and 6)


Reservoir 1,156.91 million m3 (0,938 million Aft)


Like other reservoir type hydro power plants the water stored in the reservoir is used for irrigation

purposes besides power generation. The current generation cost from Warsak is only

Rs.1.2342/kWh.

2.3.3 Hydro Power Plants of Independent Power Producers

There are only three hydro power plants owned and operated by IPPs in the private sector with

total installed capacity of 195 MW. These include Jagran Hydro, Malakan-III Hydro and New

Bong Escape. The generation capacity (unit-wise), date of commissioning, and yearly generation

are shown in Appendix B-3.

2.3.4 Assessment of Generating Capability of Hydro Power Plants

The availability of water for power generation varies considerably during the year. The

availability of water is at its peak during summer and is reduced and at the minimum during the

winter months. As the availability of water changes so is the resultant power from the hydro

power plants. As illustrated in Table 2.3.1-1 above, the dependable capacity from hydro power

plants is 7,002 MW during summer whereas it is only 2,449 MW during winter. The summer

period of maximum hydro production in Pakistan normally lasts from June to September and is

reduced and at the minimum during the months of January to March. It is also worth mentioning

that the canal maintenance period is during the month of January during which the discharge of

water is minimum and so is the power generation from the hydro power plants. Figure 2.3.4-1

below shows the monthly maximum and minimum capacity, and net monthly power generation of

these hydro power plants for 2013.


Final Report


Note: Among small hydel power plants of WAPDA, data of Nandipur (13.8 MW), Renala (1 MW) and Shadiwal (13.5 MW) is only added as for the other plants data was not collected Source: Prepared by the JICA Study Team based on the data from WAPDA Hydro Operations

Figure 2.3.4-1 Monthly Maximum / Minimum Output and Generated Electricity (Hydro)

0

500

1,000

1,500

2,000

2,500

3,000

3,500

4,000

4,500

0

1,000

2,000

3,000

4,000

5,000

6,000

7,000

8,000

9,000

Jan. Feb. Mar. Apr. May June July Aug. Sept. Oct. Nov. Dec.

Ge

nera

tion (G

Wh)

Ma

x/M

in O

utp

ut (M

W)

Existing Hydro Power Plants Capacity Statistics- Year 2013

Energy Generation (GWh)

Maximum Output (MW)

Minimum Output (MW)


Final Report


2.4 Present Situation of Renewable Energy Generating Plants

2.4.1 Outline

In line with the purpose of the study to collect data and information for the preparation of the

Least Cost Generation and Transmission Expansion Plan in the country, only the renewable

energy plants and/or projects that are connected to the national grid are the targets of this study.

The collected Data Sheets are shown in Appendix C-1 which are only for wind power plants.

Pakistan has large and viable resources in wind, solar, biomass, waste, geothermal and small

hydro power. The GOP, in order to develop these alternative and renewable resources, offers

lucrative fiscal and financial incentives to the investors. Despite such efforts of GOP, the

renewable energy has so far failed to achieve a significant share in the total electricity output of

the country. The existing grid-connected power plants of renewable energy are the total of wind,

solar, and biomass. The total installation capacities of wind, solar, and biomass are 155.9 MW,

348 kW, and 52.7 MW, respectively.

2.4.2 Wind Power Plants

Three wind power farms are under operation in the wind corridor of Sindh Province as of January

2015, of which the total installation capacity is 155.9 MW.

Table 2.4.2-1 below provides information on the three wind farms.

Table 2.4.2-1 Existing Wind Power Plants in Pakistan

Sr .

No.Name of Company Location

Ins talled

Capac ity

(MW)

Tar iff*

(Rs /kWh)

Commerc ial

Operation Date

1 Fauji Fertilizer Company Energy Ltd.Jhimpir, Thatta District,

Sindh Province49.5 - Dec, 2012

2 Zorlu Enerji Pakistan Ltd.Jhimpir, Thatta District,

Sindh Province56.4 11.3511 July, 2013

3 Three Gorges Wind FarmJhimpir, Thatta District,

Sindh Province50.0 - Dec, 2014

Total 155.9

Note: * Levelized Tariff for 20 years Source: Data collected by the JICA Study Team at the Wind farm sites

Fauji Fertilizer Company Energy Limited

This was the first wind power farm that achieved commercial operation in Pakistan. The

contracted capacity factor was 31% as per tariff determination. Cost-plus basis tariff is applied

under the contract, in which the wind risk is covered by the power purchaser.

Zorlu Energi Pakistan Limited

This was the second wind power farm that entered into the commercial operation in Pakistan,

which was achieved in two stages with the second stage completed on July 26, 2013. In the first

stage, five units of 1.2 MW capacity turbine, total of 6 MW, which were installed at a height of

69 m whereas in the second stage, 28 units of 1.8 MW capacity turbine, total of 50.4 MW, which

were installed at a height of 80 m.


Final Report


According to the data provided to the JICA Study Team at the wind firm site, the annual capacity

factor for the year 2013-2014 was 32%. The cut-in wind speeds are 3.0 m/s for one type of wind

turbine and 3.5 m/s for the other type of wind turbine. For both type of turbines the cut off speed

is 25 m/s.

The monthly averaged wind speed and monthly generation of this wind farm from December

2013 to November 2014 are shown in Figure 2.4.2-1.

Prepared by the JICA Study Team based on the data collected at the wind farm site

Figure 2.4.2-1 Monthly Averaged Wind Speed and Monthly Generation

From the above figure, it is found that the generation in the summer period is higher than that in

winter period by this wind farm. The monthly histogram and standard deviations of generation for

the same period for as the above figure are shown in Appendix C-2.

The output voltages from wind turbines are 620 V and 690 V and those generated outputs are

stepped up to 20 kV with the individual transformer for each wind turbine, then collected, again

stepped up to 132 kV, and finally evacuated to 132 kV transmission line of HESCO grid.

The O&M of the wind farm is done by Zorlu O&M Company, which is an independent company

owned by Zorlu Group.

Three Gorges Wind Farm:

This wind farm entered its commercial operation in December, 2014. All these turbines are of

Chinese origin.

2.4.3 Solar Power Plants

There are two grid-connected solar power plants in Islamabad which were installed under the

Japanese grant aid program. The installed capacities of the plants are all the same at 174 kW

each.

The owners of these plants are Planning Commission (PC) of GOP and Pakistan Engineering

Council (PEC). Since these solar plants were installed under grant aid, these owners have not

paid the capital investment cost. Under this circumstance, the power trades between the owners

0

2

4

6

8

10

12

0

5

10

15

20

25

30

Dec

2013

Jan

2014

Feb

2014

Mar

2014

Apr

2014

May

2014

Jun

2014

Jul

2014

Aug

2014

Sep

2014

Oct

2014

Nov

2014

m/s

GW

h

Sold Electricity to Grid (GWh) Average Wind Speed (m/s)


Final Report


and the Islamabad Electricity Supply Company (IESCO) have been conducted on net metering

basis. Therefore, all the units of electricity exported from the owner’s grid, which are the balance

of electricity generated by the solar power plant and the consumed electricity by the owner’s

facilities, to IESCO grid are deducted from units of the electricity imported from IESCO grid to

the owner’s grid and IESCO bills the owner for the net units of electricity. PPAs for the power

trading between the owners and IESCO have not been formally signed for the current

arrangements.

2.4.4 Biomass Power Plants

There are two operational biomass power plants in the country and these plants are using bagasse

as fuel. Both plants entered into the commercial operation in June 2014.

The total installed capacity of these plants is 52.7 MW.

Table 2.4.4-1 below provides information on these biomass power plants.

Table 2.4.4-1 Existing Biomass Power Plants in Pakistan

Sr .

No.

Name of Power

StationLocation

Ins talled

Capac ity

(MW)

Aux iliary

Load

(MW)

Net

Capac ity

(MW)

Net Annual

Output in Year

2014 (MWh)

Tar iff

(Rs /kWh)

1 JDW-IIRahim Yar Khan District,

Punjab Province26.35 2.35 24.00 88,044.70 10.4078

2 JDW-IIIGhotki District,

Sindh Province26.35 2.35 24.00 39,235.64 10.4078

Total 52.70 4.70 48.00 127,280.34 Source: CPPA

JDW-II

This is the first biomass based power plant in Pakistan using bagasse as fuel. The biomass power

plant is installed at Unit-II of JDW Sugar Mills which is located near Rahim Yar Khan of Punjab

Province. According to the information available at the website of the JDW Group, this sugar mill

unit has total crushing capacity of 8,500 tons per day and the bagasse is used as fuel for power

generation. They have opted for upfront tariff approved by NEPRA for bagasse based

cogeneration. The power plant consists of low pressure steam boilers and turbines for power

generation. Based on the net capacity and the net annual output, the capacity factor in year 2014

is calculated at 42%.

JDW-III

This is the second biomass based power plant in Pakistan using bagasse as fuel. The biomass

power plant is installed at Unit-III of JDW Sugar Mills which is located in Ghotki of Sindh

Province. This unit of sugar mills has total crushing capacity of 11,000 tons per day and the

bagasse is used as fuel for power generation. This power plant also consists of low pressure of

steam boilers and turbines for power generation. Based on the net capacity and the net annual

output, the capacity factor in year 2014 is calculated at 19%.

Both power plants opted for the upfront tariff announced by NEPRA. NEPRA has announced the

upfront tariff for bagasse-based power generation. The upfront tariff is Rs.11.7396/kWh for 1 to


Final Report


10 operation years and Rs.7.9147/kWh for the following 11 to 30 years, and the resulting

levelized tariff is Rs.10.4078/kWh.

Biomass power plants are able to generate power through the year if the biomass fuel is available.

The bagasse is the remains after sugarcane is crushed to extract their juice. The harvesting of

sugarcane in Pakistan is one time starting in November to March every year. According to the

general manager of JDW, JDW has the plan to operate these power plants for a period from

November to July or even August every year.

2.5 Present Situation of Nuclear Power Plant

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

operation of nuclear power plants. There are two nuclear power stations i.e. Karachi Nuclear

Power Plant (KANUPP) and Chashma Nuclear Power Plant Unit-1 and 2 (C-1 and C-2) in

Pakistan.

KANUPP is located in Karachi, Sindh Province and connected to K-electric grid of which the

total installed capacity is 132 MW. The plant has already completed its life of 30 years in 2000;

the date of grid connection is on October 18, 1971. The current dependable gross capacity is 100

MW after rehabilitation according to the Economic Survey of Pakistan Report 2013-14.

The Chashma Nuclear Power Plant is located in the Chashma area near Mianwali in Punjab

Province, and connected to NTDC grid, of which the total installed capacity is 665 MW. Table

2.5-1 shows the information on Chashma Nuclear Power Plant.

Table 2.5-1 Information of Chashma Nuclear Power Plant

Sr.

No.

Name of Power

Station

Ins talled

Capac ity

(MW)

Aux iliary

Load

(MW)

Net

Capac ity

(MW)

Date of Gr id

Connec tion

Net Annual Output

in Year 2014

(GWh)

Tar iff

(Rs /kWh)

1 C-1 325 25 300 June 13, 2000 2,178 5.38

2 C-2 340 25 315 March 14, 2011 2,190 7.72

Total 665 50 615 4,368 Source: WPPO and Economic Survey of Pakistan Report 2013-14

Based on the net capacities and net annual outputs, the capacity factors in year 2014 are

calculated at 83% for C-1 and 79% for C-2.


Final Report


Chapter 3 ONGOING PROJECTS AND DEVELOPMENT PLANS

3.1 General

In the situation of acute shortage of electricity in Pakistan, many generation projects are

recommended to be implemented. However, the actual situation is that the project preparation is

not matured for some projects even such project names are well known. In order to prepare the

least cost generation expansion program effectively, it is necessary to make clear whether the

project is worth assessing or not, and clarify which stage the project preparation is in.

For the above reason, the definitions of ongoing project and development plan, which are the

target of the assessment of the study, are as follows:

(1) Ongoing Project

For Public Sector

The project in which the bidding document for EPC or for the major part of the project has been

completed is considered as an ongoing project.

For Private Sector

The project in which the EPC contract or the contract for the major part of the project has been

signed, or Energy Purchase Agreement (EPA) has been signed is considered as an ongoing

project.

(2) Development Plan

For Public Sector

The plan in which the feasibility study or such equivalent-level study has been completed is

considered as development plan.

For Private Sector

The plan in which the feasibility study in the official process after Letter of Intent (LOI) is given

from the responsible organization has been completed is considered as development plan.

The process flow charts for implementing power generation business by private sector for

thermal and hydro power generation and for renewable energy are shown in Figure 3.1-1 and

Figure 3.1-2, respectively. The process flows indicated in both figures are similar; however, the

organizations concerned are different for thermal and hydro power generation and for renewable

energy.


Final Report


STEP 1

STEP 2

STEP 4

STEP 6

STEP 7

STEP 8

STEP 9

Letter of Intent (LOI)

To be issued by PPIB/ Provincial AJK

Dept

Interconnec tion Study Repor t

To be approved by Planning

Department NTDC through WPPO

Financ ial Clos ing

To be achieved by Sponsor

Upfront Tar iff/Tar iff Approval

To be applied for by Sponsor after

obtaining consent of WPPO and

approved by NEPRA

Feas ibility Study , IEE/EIA

Tar iff Petit ion

To be filed with NEPRA for Approval

Note:

1. The dotted boxes are tentative.

2. Application for Generation License must be submitted before Application of Upfront Tariff.

3. Financial Closing must be achieved within the time period stipulated in LOS.

4. Until Financial Closing is achieved, LOS shall govern the project and supersede all the documents and agreements.

5. Upon Financial Close, Security Agreements (EPA and IA) shall supersede LOS and all other documents.

Power Acquis it ion Reques t

(P.A.R.)

To be filed by WPPO and approved

by NEPRA

Consent to Purchase Power

To be issued by WPPO to sponsor

for application of Upfront Tariff

Implementation Agreement ( IA)

To be signed between PPIB and

Sponsor

Energy Purchase Agreement

(EPA)

To be signed between WPPO and

Sponsor

Technical Literature/ Drawings

To be approved by NTDC's

concerned Departments

Generation License

To be applied for by Sponsor and

issued by NEPRA

Letter of Suppor t (LOS)

To be issued by PPIB on submission

of Performance Guarantee

Cons truc tion of the Projec t

To be done by Sponsor

STEP 3

STEP 5

Commiss ioning of the Projec t

Source: CPPA

Figure 3.1-1 Process for Thermal or Hydro Power Generation by Private Sector


Final Report


STEP 1

STEP 2

STEP 4

STEP 6

STEP 7

STEP 8

STEP 9

Letter of Intent (LOI)

To be issued by AEDB/ Provincial

AJK Dept

Feas ibility Study , IEE/EIA

Interconnec tion Study Repor t

To be approved by Planning

Department NTDC through CPPA

Generation License

To be applied for by Sponsor and

issued by NEPRA

Power Acquis it ion Reques t

(P.A.R.)

To be filed by CPPA and approved

by NEPRA

Upfront Tar iff/Tar iff Approval

To be applied for by Sponsor after

obtaining consent of CPPA and

approved by NEPRA

Letter of Suppor t (LOS)

To be issued by AEDB on

submission of Performance

Guarantee

Cons truc tion of the Projec t

To be done by Sponsor

Commiss ioning of the Projec t

Note:

1. The dotted boxes are tentative.

2. Application for Generation License must be submitted before Application of Upfront Tariff.

3. Financial Closing must be achieved within the time period stipulated in LOS.

4. Until Financial Closing is achieved, LOS shall govern the project and supersede all the documents and agreements.

5. Upon Financial Close, Security Agreements (EPA and IA) shall supersede LOS and all other documents.

Consent to Purchase Power

To be issued by CPPA to sponsor for

application of Upfront Tariff

Tar iff Petit ion

To be filed with NEPRA for ApprovalSTEP 3

STEP 5


(EPA)

To be signed between CPPA and

Sponsor

Implementation Agreement ( IA)

To be signed between AEDB and

Sponsor

F inanc ial Clos ing

To be achieved by Sponsor

Technical Literature/ Drawings

To be approved by NTDC's

concerned Departments

Source: CPPA

Figure 3.1-2 Process for Renewable Energy Power Generation by Private Sector


Final Report


3.2 Thermal Power Plants

3.2.1 Ongoing Projects of Thermal Power Plant

Public Sector

Table 3.2.1-1 shows the ongoing projects of thermal power plants by the public sector..

Table 3.2.1-1 Ongoing Projects of Thermal Power Plants by Public Sector

Sr .

No.Projec t Name

Sponsor /

Company

Name

Location Fuel

Ins talled

Capac ity

(MW)

Net

Dependable

Capac ity

(MW)

Present

Status

Target

Commerc ial

Operation

Date

1

Guddu GT-14,

GT-15, STG-16

GTCC

GHCPL

(GENCO II)

Shikhapura District,

Punjab ProvinceGas 777 720

Commissioning

TestMar 2015

2 Nandipur GTCCGHCPL

(GENCO III)

Gujranwala District,

Punjab ProvinceRFO 566 510

Commissioning

TestMar 2015

Total 1,342 1,230 Source: Prepared by the JICA Study Team based on the copies of licenses published at NEPRA website

GTCC at both Guddu and Nandipur power stations are currently on test commissioning stage and

are progressing smoothly. Tariff determinations for both Guddu and Nandipur power stations

have not been publicized.

As for Nandipur Project, only one gas turbine (95 MW) currently operates as of December 2014.

After oil treatment system (impurity removal facilities) is installed, all plants will operate at full

capacity. Regarding the business entity for the Nandipur Power Station, it was separated from

GENCO III and established as GENCO V, however, the entity is not functioning yet.

Private Sector

Table 3.2.1-2 shows the ongoing projects of thermal power plants by private sector.

Table 3.2.1-2 Ongoing Projects of Thermal Power Plants by Private Sector

Sr .

No.Projec t Name

Sponsor /

Company

Name

Location Fuel

Ins talled

Capac ity

(MW)

Net

Dependable

Capac ity

(MW)

Present

Status

Target

Commerc ial

Operation

Date

1 Uch II GDF Suez

Naseerbad District,

Balochistan

Province

Gas 404 375Commissioning

TestMar 2014

Total 404 375 Source: Prepared by the JICA Study Team based on the copies of licenses published at NEPRA website

Uch II Project started test commissioning in November 2013; however, taking over of the plant

has not been confirmed officially to date. Tariff determination is not publicized yet.


Final Report


3.2.2 Development Plans of Thermal Power Plant

Public Sector

Table 3.2.2-1 shows development plans of thermal power plants by the public sector.

Table 3.2.2-1 Development Plans of Thermal Power Plants by Public Sector

Sr .

No.Projec t Name

Sponsor / Company

NameLocation Fuel

Ins talled

Capac ity

(MW)

Present Status

1Jamshoro 2x660MW

Project (ADB)GENCO

Jamshoro District,

Sindh ProvinceCoal 1,320 L/A conclusion

2Lakhra 1x660MW

Project (JICA)GENCO

Dadu District,

Sindh ProvinceCoal 660 F/S underway

Total 1,980 Source: Public Sector Development Programme 2014-15, Government of Pakistan, June 2014

The current situations of the above two development plans are shown below.

Jamshoro 2 x 660 MW project is implemented with the support of ADB and L/A between

GOP and ADB was concluded. The project management unit in GHCL was established in

Islamabad. Procurement of import coal is under preparation. The target COD for the first

unit is year 2018 and the same for the second unit is year 2019.

The preparatory survey for Lakhra Project is being carried out by JICA as of January 2015.

The target COD of the project is placed in December 2021 in the preparatory survey.

Although the feasibility study of Lakhra Project has not been completed, this project is

counted as the development plan because the preparatory survey is the same level as

feasibility study and will be surely completed soon.

Private Sector

Table 3.2.2-2 shows development plans of thermal power plant by the private sector.

Table 3.2.2-2 Development Plans of Thermal Power Plants by Private Sector

Sr .

No.Projec t Name

Sponsor / Company

NameLocation Fuel

Ins talled

Capac ity

(MW)

Target Commerc ial

Operation Date

12x660MW Thar Coal

based Power Project

China Power

International Holding

Ltd.(CPIH)

Thar Block-I,

Sindh Province

Coal

(Thar)1,320

Pre-qualification of Sponsors

under Process (COD:Jun.

and Dec.2018)

22x330MW Thar Coal

based Power ProjectEngro Powergen Ltd.

Thar Block-II,

Sindh Province

Coal

(Thar)660

Pre-qualification of Sponsors

under Process (COD:Jun.

and Dec.2018)

3

Port Qasim Project

(2x660 MW Imported

Coal Power Project)

Shinohydro Resources

Ltd. / Al Miraquab

Capital, Qatar

Port Qasim,

Karachi,

Sindh Province

Coal

(Import)1,320

LOI Issued (COD:Jun. and

Dec.2018)

Total 3,300 Source: Prepared by the JICA Study Team based on the website of Private Power and Infrastructure Board (PPIB), Thar Coal Energy Board (TCEB) presentation documents and F/S of each project

The three plans shown in the above table are all coal thermal project.

Two projects out of them are planned to be constructed in Thar Coal Field and use the coal form

this field. The financial arrangement for the Thar Coal Field development is not finalized; thus,


Final Report


the starting time to supply fuel coal from Thar Coal Field is not foreseen. Under the situation, The

COD of the projects will be delayed from their target CODs.

Port Qasim Project is planned to use imported coal as fuel. This project is suspended due to the

problem of environmental countermeasures such as ash disposal plan. From this situation, the

COD of this project is also expected to be delayed from its target COD.

Besides the above three projects, there are projects frequently reported in newspapers. Since these

projects do not meet the definition for the “development plan” in this study and the JICA Study

Team assesses the feasibility of these projects is low. Therefore, JICA Study team does not deal

with these projects as the development plan; however, the situations of two popular projects out

of them are shown below.

The Sahiwal Coal Power Project (Sahiwar District, Punjab Province): The designed installed

capacity of this project is 1,320 MW (2 x 660 MW) and it is planned to use the imported

coal. The project is located at the center of a farm land and it requires many implementation

agreements for the transportation of coal, water source from irrigation and ESIA for Punjab

Province and EIA for Sindh Province.

The JICA Study Team interviewed and requested to share F/S report to PPDB. However,

PPDB did not share the F/S report and related information. The JICA Study Team, thus,

could not confirm the F/S report of this project.

Gadani Coal Power Project (Gadani District, Balochistan Province): The designed installed

capacity of this project is 6,600 MW (10 x 660 MW) and it is planned to use the imported

coal. The project was announced widely and Expression of Interest (EOI) was invited.

However, there was no applicant. In addition, the extremely long jetty and coal-conveying

systems would be required to achieve considerable depths for the imported coal considering

the environmental problem due to the monsoon from the Arabian Sea. Therefore, it seems

that the project will require lots of finance.


Final Report


3.3 Hydro Power Plants

Hydro power projects are categorized into three category based on the implementation body and

supervising body.

WAPDA Project:

Projects implemented by WAPDA

IPP Project through PPIB (Private Power Infrastructure Board):

Projects implemented by IPP under supervision of PPIB

Provincial Project:

Projects implemented by provincial organization (AJK-PDO・PEDO・PPDB) or projects

implemented by IPP under supervision of such provincial organization

Generally large scale projects are implemented by WAPDA or supervised by PPIB, and relatively

small projects are under provincial organizations.

The JICA Study Team contacted the provincial organizations to ask the project status through

NTDC; however, the team could not obtain additional information to update the status apart from

the information published on their websites. Because of the limited information, the projects in

the construction stage are regarded as “ongoing project”, the projects whose F/S is ready are

regarded as “development plan” even if the progress of construction is not confirmed, and the

projects in “Pre-F/S” stage are not listed in this report.

3.3.1 Ongoing Projects of Hydro Power Plant

Public Sector

Ongoing projects implemented by WAPDA are shown in Table 3.3.1-1.

Table 3.3.1-1 Ongoing Projects of Hydro Power Plant of WAPDA

Sr .

No.Name of Projec t Location Type

Ins talled

Capac ity

(MW)

Target

Commerc ial

Operation Date

WAPDA (Ongoing Projec t)

1 Neelum Jhelum Hydel AJK Small Reservoir 969 Nov. 2016

2 Golen Gol HPP KPK Reservoir 106 Dec. 2016

3 Mangla Upgradation Phase1 AJK Reservoir 62 Dec. 2016

4 Tarbela 4th Ext. KPK Reservoir 1,410 Mar. 2017

5 Keyal Khwar KPK Small Reservoir 122 Oct. 2017

6 Basho Hydel GB Small Reservoir 40.5 Jun. 2019

7 Harpo Hydel GB Small Reservoir 34.5 Jun. 2019

8 Phandar Hydro GB Small Reservoir 80 May. 2020

9 Dasu-1 KPK Small Reservoir 2,160 Jun. 2020

10 Diamer Bhasha GB Reservoir 4,500 Dec. 2024

Total 9,484

WAPDA PPP Mode (Ongoing Projec t)

11 Lower Palas Valley HPP KPK Small Reservoir 665 Dec. 2022

12 Lower Spat Gah HPP KPK Small Reservoir 496 Dec. 2022

Total 1,161

Total (WAPDA + PPP Mode) 10,645 Source: Prepared by the Study Team based on interview and data collection at NTDC


Final Report


The major hydro power plants are under the domain of WAPDA. Recently, the GOP had decided

to offer some of these hydro power plants to the private sector through PPIB. PPIB recently had

awarded Karot Hydro power Plant (HPP) of 720 MW, Azad Pattan HPP of 640 MW, and Suki

Kenari of 840 MW to the private sector on a build, own, operate and transfer (BOOT) basis.

WAPDA had started working on Neelum-Jehlum Hydro Power Project with 969 MW capacity.

The hydro power project is located in AJK. The plant is expected to be completed by the end of

2016 and will generate 5,150 GWh of energy per year.

WAPDA has started working on Tarbela 4th Extension Project. The project will add additional

generation to the existing 3,478 MW hydro power installed at Tarbela. The proposed project

would have an installed capacity of 1,410 MW. This would be achieved by installing three new

generating units onto the existing irrigation Tunnel 4 which will be converted into power without

affecting the existing irrigation release capabilities from Tarbela.

Golen Gol is another project of WAPDA that is under construction and is expected to be

completed by June 2016. The total installed capacity of this hydro power plant will be 106 MW

and three units of 35.3 MW each will be installed. This is a high head power project located in

KPK province and once completed, it is expected to add more than 430 GWh of energy to the

national grid annually.

WAPDA had completed the process of pre-qualification of contractors for construction of Dasu-1.

This project will be run-of-river type power project with total installed capacity of 2,160 MW and

will add 12,104.44 GWh of annual net energy to the national grid. The project is expected to

achieve COD by end of 2020. The GOP had expedited the process of completing phase II of this

project with same installed capacity and the process of preparing bidding documents has started

through private consultants and is expected to be completed by January 2015.

Diamer Bhasha is a reservoir type hydro power project that is under construction and according

to information from WAPDA, the plant will be completed by 2025. This power plant will be a

multipurpose hydro power project where water will be used for both irrigation and power

generation purposes. The total installed capacity of this power plant will be 4,500 MW. The water

stored in the reservoir will not be used by this power plant but will be used to regulate generation

from hydro power projects that are downstream of Diamer Bhasha like Dasu. For downstream

hydro power projects, the reservoir of Diamer Bhasha will also act as settling basin for silt.

Keyal Khwar is another high head hydro power project of WAPDA that is under construction.

The plant is located in Dasu District of KPK and will have a total installed capacity of 128 MW.

According to information collected, like existing high head hydro projects of WAPDA, this will

also be used as peaking plant during low water season and will run at the maximum during high

water months. According to collected data, the annual capacity factor from this project will be

around 37%.

The WAPDA is also undertaking two projects under PPP mode and the terms for the agreement

are under final stage of negotiations. These two projects include Lower Palas with 665 MW

installed capacity and Lower Spat Gah with 496 MW. K-Water and Daewoo of South Korea from

the private sector will develop the Lower Palas Valley Project jointly with WAPDA and PEDO.


Final Report


KOMIPO and POSCO of South Korea will develop the Lower Spat Gah jointly with PEDO and

WAPDA. Both of these projects are expected to be completed by December 2022.

Besides the projects implemented by WAPDA or the private sector through PPIB, provincial

organizations like PEDO, formerly known as Sarhad Hydel Development Organization (SHYDO)

or Pakhtunkhwa Hydel Development Organization (PHYDO) in KPK Province, PPDB in Punjab

Province, and AJK-PDO are also working to develop hydro projects in the provinces both in the

public and private sector.

As the hydro power potential is high in KPK Province, these hydro power projects range from 10

MW to more than 300 MW. PPDB in Punjab Province has offered a few micro hydro power

projects to the private sector and at the same time undertaking few by themselves.

Ongoing projects implemented by provincial organization are shown in Table 3.3.1-2. Only some

provincial projects in AJK were identified as “Ongoing Project” according to the website of

provincial organizations.

Table 3.3.1-2 Ongoing Projects of Hydro Power Plant of Provincial Organization

Prov ince /

Ter r itoryStatus

Sr .

No.Power Station

Ins talled

Capac ity

(MW)

AJK Under Cons truc tion 1 Sharda,Neelum 3.00

2 Battar,Havelli 4.80

3 Dhanna,Kotli 1.50

4 Rehra,Bagh 3.20

5 Guin Nullah,Poonch 0.25

6 Hillan,Havelli 0.60

7 Rangar-II,Poonch 0.45

8 Kel, Neelum 0.75

9 Patikka, Muzaffarabad 0.50

10 Jhing, Muzaffarabad 14.40

12 Jari-II, Mirpur 4.00

13 Jagran-II, Neelum 48.00

Total 81.45 Source: Prepared by the JICA Study Team based on websites of provincial organization (AJK-PDO)

Private Sector

Ongoing projects implemented through PPIB are shown in Table 3.3.1-3.

Table 3.3.1-2 Ongoing Projects of Hydro Power Plant through PPIB

Sr.


Ins talled

Capac ity

(MW)

Target

Commerc ial

Operation Date

PPIB (Ongoing Projec t)

1 Patrind HPP KPK/AJK Small Reservoir 147 Apr. 2017

Total 147 Source: Prepared by the JICA Study Team based on interview and data collection at NTDC

Patrind is a sizeable hydro power project that is under construction. The total installed capacity of

this power plant will be 150 MW and it will be commissioned by March 2017. K-Water of South

Korea is the EPC contractor for this hydro power project.


Final Report


3.3.2 Development Plans of Hydro Power Plant

Public Sector

Development plans implemented by WAPDA are shown in Table 3.3.2-1.

Table 3.3.2-1 Development Plans of Hydro Power Plan by WAPDA

Sr .


Ins talled

Capac ity

(MW)

Target

Commerc ial

Operation Date

WAPDA (Development Plan)


2 Tarbela 5th Ext. KPK Reservoir 1,320 Jul. 2019



5 Munda Dam KPK Reservoir 740 Jun. 2023


7 Dasu-II KPK Small Reservoir 2,160 Dec. 2027

8 Bunji KPK Small Reservoir 7,200 Dec. 2027

Total 11,668 Source: Prepared by the JICA Study Team based on interview and data collection at NTDC

WAPDA is planning to develop few hydro power plants in the future. Tarbela 5th Extension is

one of the priority projects that will use water from existing Tarbela Reservoir that is currently

discharged through spillways during high water summer season. This plant will work only during

the flood season when water is discharged through the spillways in Tarbela or will also act as

standby power plant that will run in case of problems with any of the existing hydro power

turbines. The total installed capacity of this project will be 1,320 MW.

Dasu-II is another WAPDA HPP that will be constructed along with Dasu-I. Dasu-I will construct

the required infrastructure including underground power house for Dasu-II as well. This will have

the same installed capacity as Dasu-I of 2,160 MW. According to information provided by

WAPDA Hydel Planning, WAPDA was initially planning to start construction of this in the

beginning of 2025 and complete it by 2029. Now, upon instruction from GOP, WAPDA had asked

the consultant to prepare the bidding documents for Dasu-II and is planning to start construction

of this phase earlier.

Munda Dam is another multipurpose project of WAPDA whose revised feasibility study has been

approved and PC-1 is submitted for approval to GOP by WAPDA. Total installed capacity of this

hydro power project will be 740 MW. The reservoir will be located on the River Swat in KPK

with total storage capacity of 1,594 million m3. According to the data provided by WAPDA Hydel

Planning, around 3,000 GWh of annual energy will be produced by Munda Dam and the

generation cost is expected to be Rs.9.87/kWh since the project cost is relatively high as the

project is a multipurpose project, not only a power generation project.

The GOP has decided to take the private sector on board for the construction of medium to large

size hydro power projects. Initially, the feasibility studies for all these were completed by

WAPDA and then later awarded to the private sector through PPIB. Upon completion, these will

work as IPPs. GOP has awarded Azad Pattan (640 MW), Suki Kenari (840 MW), and Karot (720

MW) either to the Chinese companies or their consortiums through PPIB. For all these hydro


Final Report


power projects, financing has been arranged and EPC has been awarded. All three are expected to

achieve COD by June 2020.

Development plans implemented by provincial organizations are shown in Table 3.3.2-2 and

Table 3.3.2-3.

Table 3.3.2-2 Development Plans of Hydro Power Plan of Provincial Organizations (1/2)

Prov ince /

Ter r itoryStatus

Sr .

No.Power Station

Ins talled

Capac ity

(MW)

AJK PC- I Approved 1 Dowarian HPP 40.00

2 Nagdar HPP 35.00

Total 75.00

In Process of PC- I Approval 3 Shounter HPP 48.00

4 Jagran-IV HPP 22.00

5 Rajhdhani HPP 132.00

6 Chamfall HPP 6.40

7 Bhedi Doba HPP 1.00

8 Up-gradation of Kundal SHahi HPP 1.00

9 Galetar HPP 1.00

10 Sandoa Cross HPP 1.75

Total 213.15

KPK F/S Completed 1 Balakot HPP 300.0

2 Naran HPP 188.0

3 Ghor band Khwar HPP 20.6

4 Nandihar Khwar HPP 12.3

5 Arkari Gol HPP 99.0

6 Mujigram-Shoghor HPP 64.3

7 Istaru-Booni HPP 72.0

8 Shogo-Sin HPP 132.0

9 Sharmai HPP 150.0

10 Shusgai-Zhendoli 144.0

Total 1,182.2 Source: Prepared by the JICA Study Team based on websites of provincial organizations (AJK-PDO and PEDO)

Table 3.3.2-3 Development Plans of Hydro Power Plan of Provincial Organizations (2/2)

Prov ince /

Ter r itoryStatus

Sr .

No.Power Station

Ins talled

Capac ity

(MW)

Punjab No Information 1 MARALA 7.20

2 PAK PATTAN CANAL 3.20

3 DEGOUT FALL 5.00

4 CHIANWALI 5.00

5 OKARA 4.00

6 Lower Chenab Canal (LCC) 7.55

7 Khanki Barrage (KB) 14.09

8 Qadirabad Barrage (QB) 23.00

9 Upper Chenab Canal (UCC) 3.58

10 Qadirabad Balloki Link Canal (QBLC) 7.68

11 Taunsa Hydropower 120.00

Total 200.30 Source: Prepared by the JICA Study Team based on websites of provincial organizations (PPDB)


Final Report


Private Sector

Development plans through PPIB are shown in Table 3.3.2-4.

Table 3.3.2-4 Development Plans of Hydro Power Plants through PPIB

Sr .


Ins talled

Capac ity

(MW)

Target

Commerc ial

Operation Date

PPIB (Development Plan)

1 Gulpur Poonch AJK Small Reservoir 100 Dec. 2017

2 Sehra HPP AJK Small Reservoir 130 Dec. 2018

3 Karot HPP Punjab Small Reservoir 720 Jun. 2020

4 Azad Pattan HPP AJK Small Reservoir 640 Jun. 2020

5 Suki Kinari HPP KPK Small Reservoir 840 Jun. 2020

6 Kotli AJK Small Reservoir 100 Jun. 2020

7 Chakoti Hattian HPP AJK Small Reservoir 500 Dec. 2020

8 Kohala HPP AJK Small Reservoir 1,100 Dec. 2020

9 Kaigah HPP KPK Small Reservoir 548 Dec. 2022

10 Madian HPP KPK Small Reservoir 157 Dec. 2022

11 Asrit-Kedam HPP KPK Small Reservoir 215 Dec. 2022

12 Mahl HPP KPK Small Reservoir 590 Dec. 2023

Total 5,640 Source: Prepared by the JICA Study Team based on interview and data collection at NTDC/PPIB

Gulpur is another hydro power project with 100 MW installed capacity that will be completed as

an IPP. According to information provided by PPIB, financial close for this project is under

process and it is expected to achieve COD by December 2017. This plant will be a run-of-river

type power project and is located on the River Poonch of AJK.

Sehra is another private sector HPP with 130 MW installed capacity whose bids for EPC have

been called and now the EPC stage tariff approval from NEPRA is in process. This HPP will also

be located on the River Poonch of AJK and the expected COD is in December 2018.

Kohala HPP is a large size power project and by far will be the largest HPP by the private sector

with a total installed capacity of 1,100 MW. CWE and Three Gorges of China are the project

sponsors and financing for this project will be secured through the agreement between GOP and

the Government of China. This HPP is located on the River Jehlum near Muzaffarabad in AJK.

According to information provided by PPIB, this HPP is expected to be completed by December

2020.

Development plans of provincial organizations are shown in Table 3.3.2-5 and Table 3.3.2-6.


Final Report


Table 3.3.2-5 Development Plans of Hydro Power Plan by Provincial Organization (1/2)

Prov ince /

Ter r itoryStatus

Sr .

No.Power Station

Ins talled

Capac ity

(MW)

AJK No Information 1 Riali-II HPP 4.80

2 Dachhor Miran HPP 3.00

3 Jagran-III HPP 3.50

4 Ghail HPP 0.80

5 Bheri HPP 2.87

6 Riali-III 3.07

7 Jhing-II 6.05

8 Arja Talen Dhalkot HPP 36.00

9 Chitter Pari HPP 1.00

10 Kathai-III HPP 1.00

11 Ashkot HPP 40.00

12 Batdara HPP 10.20

13 Luat HPP 49.00

14 Naushera HPP 4.60

15 Kathai-II HPP 4.60

16 Gumatnar HPP 40.00

17 Sahng HPP 10.00

18 Sankaya HPP 7.00

19 Khari-II 2.50

20 Raili-I HPP 1.60

21 Hotreri HPP 5.40

22 Dakhari HPP 2.20

Total 239.19 Source: Prepared by the JICA Study Team based on websites of provincial organization (AJK-PDO)


Final Report


Table 3.3.2-6 Development Plans of Hydro Power Plan by Provincial Organization (2/2)

Province /

TerritoryStatus

Sr.

No.Power Station

Installed

Capacity

(MW)

Punjab Status: N/A 1 MARALA 7.20

(Public Sector Project) 2 PAK PATTAN CANAL 3.20

3 DEGOUT FALL 5.00

4 CHIANWALI 5.00

5 OKARA 4.00

6 Low er Chenab Canal (LCC) 7.55

7 Khanki Barrage (KB) 14.09

8 Qadirabad Barrage (QB) 23.00

9 Upper Chenab Canal (UCC) 3.58

10 Qadirabad Balloki Link Canal (QBLC) 7.68

11 Taunsa Hydropow er 120.00

Total 200.30

Status: N/A 12 Rasul HPP (Jhelum) 20.00

(Private Sector Project) 13 Punjnad HPP (Chenab) 15.00

14 B.S. Link Canal (RD.106+250) 11.00

15 Marala (Lucky HPP)(Chenab) 20.00

16 T.P. Link Canal (RD.183+000) 9.00

17 B.S.Link 1 (Tail)(RD.266+000) 9.00

18 C.J. Link Tail Canal Fall (RD. 316+622) 44.30

19 Jhang Branch Canal (RD. 0+000 to 69+000) 1.80

20 L.B.D.C. (RD. 489 + 000) 3.30

21 Muzzaffargarh Canal (RD. 64+357 to 147+500) 2.64

22 B.R.B.D Link Canal (RD. 0+000) (Bombanw ala) 2.00

23 LBDC Canal (RD. 589+000 to 640+200) 1.80

24 PAKPATTAN CANAL (RD. 315 + 000) 1.80

25 Northern Branch ofL.J.C. Low er (RD. 24+320) 1.00

26 Upper Gugera (RD. 214+000 to 220+000) 2.57

27Run of Canal Project at QB Link Whole Canal except

falls at RD.304+985 and RD.379+2653.00

28 Low er Jhelum Feeder Canal (RD. 8 + 626) 5.20

29 Marala Ravi Link Canal (RD. 249 + 850) 9.00

30 Marala Ravi Link Canal (RD. 265 + 400) 12.00

31 B.S. Link II Canal (RD.33+430) 11.00

32 Low er Gugera Branch Canal (RD. 27 + 000) 1.17

33 Marala Ravi Link Canal (RD. 313+500), Out Falls 13.00

34 Low er Chenab Canal (RD. 40+200) 1.77

35 B.S. Link II Canal (RD.193+339) 5.00

36 Trimmu Barrage 19.20

37SAHIWAL HYDRO POWER PROJECT L.B.D.C.

RD.329+058 to RD.340+8504.80

38KHOKHRA HYDRO POWER PROJECT GUJRAT

BRANCH CANAL RD.0+000 to 2+5003.20

39Jhang Branch Canal Upper, Prototype Low Head Pilot

HPP1.00

Total 234.55

Total 2,144 Source: Prepared by the JICA Study Team based on websites of provincial organizations (PPDB)


Final Report


3.4 Generating Plants of Renewable Energy

3.4.1 Ongoing Projects of Renewable Energy

Wind, solar, and biomass projects are ongoing in the renewable energy sector. All the projects are

undertaken by the private sector except for the 100 MW solar project at Quaid-e-Azam Solar Park

in Punjab Province.

Wind

According to information provided by CPPA there are eight ongoing wind power projects. These

projects are all located in the wind corridor of Sindh Province. The installed capacity of most of

these wind power projects is around 50 MW.

The details and current status of these projects are provided in Table 3.4.1-1 below.

Table 3.4.1-1 Ongoing Wind Power Projects

Sr .

No.

Name of

CompanyLocation

Ins talled

Capac ity

(MW)

Tar iff

(US

cent/kWh)

Present Status

Target

Commerc ial

Operation

Date

1Foundation Wind

Energy-I Ltd.

Gharo,

Thatta District,

Sindh Province

50.0 14.1359

Energy Purchase Agreement (EPA) signed

on December 20, 2012 / Financial Close

achieved on July 18, 2013

January 2015

2Foundation Wind

Energy-II Ltd.

Gharo,

Thatta District,

Sindh Province

50.0 14.1164EPA signed on December 20, 2012 /

Financial Close achieved on July 18, 2013

December

2014

3

Three Gorges First

Wind Farm

Pakistan (Pvt.) Ltd.

Jhimpir,

Thatta District,

Sindh Province

49.5 -EPA signed on January 4, 2013 / Financial

Close achieved on July 17, 2013January 2015

4Sapphire Wind

Power Co. Ltd.

Jhimpir,

Thatta District,

Sindh Province

50.0 13.52EPA signed on 20th February 20, 2014 /

Financial Close achieved on July 7, 2014January 2016

5Metro Power Co.

Ltd.

Jhimpir,

Thatta District,

Sindh Province

50.0 - EPA signed on February 26, 2014 March 2016

6Sachal Energy

Development Ltd.

Jhimpir,

Thatta District,

Sindh Province

50.0 14.8618 EPA signed on February 27, 2014 March 2016

7 Yunus Energy Ltd.

Jhimpir,

Thatta District,

Sindh Province

50.0 - EPA signed on March 26, 2014 March 2016

8HydroChina

Dawood Power Ltd.

Jhimpir,

Thatta District,

Sindh Province

49.5 - EPA signed on September 25, 2014 March 2016

Total 398.0 Source: CPPA

The total capacity of these ongoing wind power projects is 398 MW and all these projects will

start commercial operation by the end of March 2016.


Final Report


Solar

The Punjab government had established Quaid-e-Azam Solar Park in Cholistan area near

Bahawalpur and allocated 10,000 acres of land. They have developed infrastructure for solar

power generation. The land will be leased at anominal rate of US$ 1 per acre for the developers

of solar power generation. The annual flat plate tilted at latitude solar radiation in the area is in

the range of 6 to 6.5 kWh/m2-day.

In this Park, there are two ongoing projects which are shown in Table 3.4.1-2 below.

Table 3.4.1-2 Ongoing Solar Power Projects

Sr .


Ins talled

Capac ity

(MW)

Present StatusTarget Commerc ial

Operation Date

1

Quaid-e-Azam Solar (Pvt)

Ltd. Company (owned by the

government of Punjab)

Bahawalpur District,

Punjab Province100.0

As of January 2015, 90% of

construction has been completedFeb. 2015

2 Zonergy Company LimitedBahawalpur District,

Punjab Province900.0

The construction will commence in

March 2015 at Quaid-e-Azam

Solar Park.

June 2016 (300 MW)

June 2017 (600 MW)

Total 1,000.0 Source: Quaid-e-Azam and the Government of Punjab

In order to attract the private investors to Quaid-e-Azam Solar Park, the Government of Punjab

had established Qaid-e-Azam Solar (Pvt) Ltd. and has been constructing Solar PV power plant of

100 MW capacity. Qaid-e-Azam Solar is an autonomous company owned by the Government of

Punjab. The EPC contractor of the project is Tebian Electric Apparatus Stock Co., Ltd. (TBEA)

of China and the operation and maintenance contract is also awarded to this company. As of

January 2015, more than 90% of construction has been completed including the completion of the

grid connection arrangement to 132 kV of MEPCO grid. The inauguration of project is expected

in February 2015. However, EPA between Qaid-e-Azam Solar and CPPA has not been concluded.

The cost of EPC component for this 100 MW solar project is around US$ 131 million. But

considering other costs like feasibility studies and infrastructure, the total cost will reach US$ 157

million.

Regarding the 900 MW solar project, the government of Punjab had allocated land to Zonergi

Company Limited of China for the installation of 900 MW solar power at the Qaid-e-Azam Solar

Park. The Export-Import Bank of China has already approved loan for this project and Zonergi

plans to start construction in March or April 2015 provided that the industrial department of the

Government of Punjab start or complete the boundary wall around the allocated land as this is the

responsibility of the Government of Punjab. The project will be implemented in two phases: the

first phase for 300 MW and the second phase for 600 MW. The solar power plant of 300 MW in

the first phase is designed to be connected to the 132 kV transmission line, while 600 MW in the

second phase is designed to be connected to the new 220 kV transmission line. This connection

plan has been approved by NTDC and NTDC has completed the design of the new 220kV

transmission line.


Final Report


Biomass

According to the current information provided by CPPA, there are two biomass ongoing projects

that are under implementation by the private sector. The installed capacities of the plants are 62.4

MW and 30 MW, totaling 92.4 MW. Table 3.4.1-3 below provides the information of these

biomass power plants.

Table 3.4.1-3 Ongoing Biomass Power Projects

Sr .


Ins talled

Capac ity

(MW)

Tar iff

(Rs /kWh)Present Status

Target

Commerc ial

Operation

Date

1 Chiniot Power Ltd.Chiniot District,

Punjab Province62.4 10.4078


(EPA) signed on July 22, 2014June 2015

2 RYK Mills Ltd.Rahim Yar Khan District,

Punjab Province30.0 10.4078 EPA signed on October 10, 2014 December 2014


These plants opted for the upfront tariff of Rs.10.4078/kWh. According to the terms of upfront

tariff by NEPRA the annual capacity factor of these plants will be 45% with auxiliary load

consumption at 8.5%.

3.4.2 Development Plans of Renewable Energy

According to the definition stated in the Chapter 3.1, the development plans are identified in the

renewable energy sector as follows:

Wind

According to information provided by CPPA, there are 22 development plans of solar power

generation. These projects are all located in the wind corridor of Sindh Province.

Table 3.4.2-1 below provides the information of these plans.


Final Report


Table 3.4.2-1 Development Plans of Wind Power Generation

Sr .


Ins talled

Capac ity

(MW)

Tar iff

(US

cent/kWh)

Present Status

Target

Commerc ial

Operation

Date

1Tenaga Generasi

Limited

Kuttikun, Thatta District,

Sindh Province49.6 14.316


(EPA) under negotiationOctober 2016

2Master Wind Energy

Limited

Jhimpir, Thatta District,

Sindh Province50.0 - EPA under negotiation March 2016

3 Zephyr Power LimitedBhambore, Thatta

District, Sindh Province50.0 -

Approval of interconnection study

is awaited.-

4Gul Ahmed Energy

Limited



5 Wind Eagle Limited – IJhimpir, Thatta District,

Sindh Province50.0 -


is awaited.

December

2016.

6 Wind Eagle Limited – IIJhimpir, Thatta District,



is awaited.

December

2016

7 HAWA Holding LimitedJhimpir, Thatta District,



is awaited.-

8United Energy Pakistan

Ltd.



9Jhimpir Wind Power

Limited


Sindh Province49.6 13.5 EPA under negotiation June 2016

10 Tapal WindJhimpir, Thatta District,


11NBT Wind Power

Pakistan (Pvt) Limited



Power Acquisition Request

submitted to NEPRA-

12Titan Energy Pakistan

(Pvt) Limited




is awaited.-

13China Sunec Energy

(Pvt) Limited


Sindh Province50.0 - Interconnection study approved June 2016.

14Tricon Boston

Consulting Corporation




is awaited.-

15Tricon Boston





is awaited.-

16Tricon Boston





is awaited.-

17Burj Wind Energy (Pvt)

Limited




is awaited.May 2016

18Hartford Alternate

Energy




is awaited.-

19Western Energy (Pvt)

Ltd




is awaited.-

20United Energy Pakistan

LimitedSindh Province 350.0 -

Letter of Intent (LOI) was obtained

and Feasibility Study was done.

Land is not allocated.

-

21Zaver Petroleum

Corporation LimitedSindh Province 50.0 -

LOI was obtained and Feasibility

Study was done. Land is not

allocated.

-

22Trident Energy (Pvt)

LimitedSindh Province 50.0 -

LOI was obtained and Feasibility

Study was done. Land is not

allocated.

-

Total 1,804.0 Source: CPPA

The total capacity of the above development plans of wind power generation reaches 1,804 MW.

Half of the plans are targeting to commence their commercial operation in 2016.


Final Report


Solar

There are 11 development plans of solar power generation. Table 3.4.2-2 below shows the

information of these plans.

Table 3.4.2-2 Development Plans of Solar Power Generation

Sr .

No.

Name of

CompanyLocation

Ins talled

Capac ity

(MW)

Tar iff

(US cent/kWh)Present Status

1M/s. Dacc

Associates


Punjab Province50.0

Awaiting announcement

of upfront tariff by

NEPRA

Negotiating on EPA with CPPA and IA with

AEDB, awaiting land allocation by Punjab

gov.

2First Solar 2 MW

Solar Power Project


Punjab Province2.0 Applied to NEPRA

Generation License awarded, applied for

tariff, however, LoI expired.

3Access Solar Pvt

Ltd

Pind Dadan Khan,

Jhelum District,

Punjab Province

11.5 17.003 (Levelized)

Feasibility study done, generation license

and upfront tariff awarded, obtained LOS

from AEDB, negotiating EPA and IA

4Access Electric Pvt

Ltd

Pind Dadan Khan,

Jhelum District,

Punjab Province

10.0 17.003 (Levelized)




5M/s. Sanjwal Solar

(Pvt) Ltd.

Sanjawal,

Attock District

Punjab Province

5.0 17.003 (Levelized)




6M/s. Bakhsh

Energy (Pvt) Ltd.


Punjab Province10.0 17.003 (Levelized)




7 Safe Solar (Pvt) LtdBahawalpur District,

Punjab Province10.0 17.003 (Levelized)




8M/s. Integrated

Power SolutionSindh Province 50.0



NEPRA

Feasibility study done, applying for

generation license and upfront tariff

9M/s. Jafri &

AssociatesSindh Province 50.0



NEPRA



10M/s. Solar Blue

(Pvt) Ltd.Sindh Province 50.0



NEPRA



11Blue Star Hydel

(Pvt) Ltd.

Pind Dadan Khan,

Jhelum District,

Punjab Province

1.0 17.003 (Levelized)




Total 249.5 Source: AEDB

The total capacity of the above development plans of solar power generation reaches 249.5 MW.


Final Report


Biomass

According to the current information provided by CPPA, there are seven development plans of

biomass power generation. Five projects are located in Punjab Province and the remaining two

projects are located in Sindh Province.

Table 3.4.2-3 below provides the information of these development plans of biomass power

generation.

Table 3.4.2-3 Development Plans of Biomass Power Generation

Sr .


Ins talled

Capac ity

(MW)

Tar iff

(Rs /kWh)Present Status

1 Hamza Sugar Mills Ltd.Rahim Yar Khan District,


Energy Purchase Agreement (EPA)

negotiation is being executed.

2 SSJD Bio energy Ltd.Mirpurkhas District,


Economic Coordination Committee (ECC)

approval on the draft EPA is awaited.

3 Kamalia Sugar Mills Ltd.Kamalia, Toba Tek Singh

District, Punjab Province17.0 10.4078

Approval of interconnection study is

awaited.

4 Alliance Sugar Mills Ltd.Ghotki District,



awaited.

5 Almoiz Industries Ltd.Mianwali District,



awaited.

6 Layyah Sugar Mills Ltd.Layyah District,



awaited.

7Etihad Power

Generation Ltd.

Rahim Yar Khan District,



awaited.


The total installed capacity of the above development plans of biomass power generation is 216

MW.


Final Report


3.5 Nuclear Power Plant and Power Import

3.5.1 Nuclear Power

According to Economic Survey of Pakistan Report 2013-2014, PAEC is proceeding with the

construction of new nuclear power plants at Chashma Nuclear Plant site and KANUPP site. At

both sites, two units of nuclear plant are constructed, respectively, i.e. Chashma Unit Nos. 3 and 4

(C-3 and C-4) and KANUPP Unit Nos. 2 and 3 (K-2 and K-3). The domes of containment

buildings of C-3 and C-4 were placed in March 2013 and January 2014, respectively. The ground

breaking ceremony of K-2 and K-3 was held on November 26, 2013.

Table 3.5.1-1 below shows the information of ongoing nuclear power plants.

Table 3.5.1-1 Ongoing Nuclear Power Projects

Sr.

No.Name of Projec t Location Capac ity (MW)

Target Commiss ioning

Date

1 Chashma Unit 3 (C-3) 340 April 2016

2 Chashma Unit 4 (C-4) 340 December 2016

3 KANUPP Unit 2 (K-2) 1,100 August 2020

4 KANUPP Unit 3 (K-3) 1,100 June 2021

Total 2,880

Chashma, District Mianwali,

Punjab Province

Karachi, Sindh Province

Source: Economic Survey of Pakistan Report 2013-2014

PAEC is implementing the Nuclear Power Program 2030 set by the Energy Security Plan of GOP.

In the plan, it is emphasized that generation by nuclear power plants will be increased to 8,800

MW by 2030. However, the information on further development plans of nuclear power plants

was not available.


Final Report


3.5.2 Power Import

i) Import from Kyrgyz Republic and Tajikistan (CASA-1000)

The development of the 1,000 MW Electricity Transmission and Trade Project for Central Asia

and South Asia is called CASA-1000 and it aims to create the conditions for sustainable

electricity trade between the Central Asian countries of Tajikistan and the Kyrgyz Republic and

the South Asian countries of Afghanistan and Pakistan. CASA-1000 is aiming to export surplus

electricity generated by hydro power in both the Kyrgyz Republic and Tajikistan during the

summer period to Pakistan and Afghanistan which have fast-growing demand of electricity. Even

without adding any new hydro power generation in Tajikistan and the Kyrgyz Republic, sufficient

quantities of surplus electricity are available in the countries for export.

With CASA-1000, initially, the Kyrgyz Republic and Tajikistan will export 1,300 MW electricity

and Pakistan will import 1,000MW of electricity while Afghanistan will receive the remaining

300 MW.

Infrastructure component of CASA-1000 includes these construction of high voltage transmission

system which comprises the following sub-components:

DC line: high voltage (+/- 500 kV) direct current (HVDC) transmission line with a

capacity of 1,300 MW from Sangtuda, Tajikistan to Peshawar, Pakistan via Kabul,

Afghanistan (750 km);

AC-DC converter: alternative current to direct current (AC-DC) converter station in

Sangtuda with a capacity of 1,300 MW, the same in Peshawar with a capacity of 1,300

MW, and the same in Kabul with a capacity of 300 MW;

AC line: AC 500 kV transmission line from Datka, the Kyrgyz Republic to Khujand,

Tajikistan (477 km); and

Reinforcement: Tajikistan grid reinforcement including the construction of AC 500

kV line from Regar substation to Sangtuda substation (115 km) and other parts of the

network along with associated substation equipment to ensure the transfer of power in

the Kyrgyz Republic and Tajikistan to the Sangtuda converter station.

The project is implemented by the national transmission companies in each country, namely:

In Afghanistan – Da Afghanistan Breshna Sherkat (DABS);

In the Kyrgyz Republic – Joint Stock Company National Electric Grid of Kyrgyzstan

(NEGK);

In Pakistan – National Transmission and Despatch Company (NTDC); and

In Tajikistan – Open Joint Stock Holding Company Barki Tajik (BT)

CASA-1000 is the ongoing project and coordinated mainly by WB. Financing for the project is

expected to be from multiple sources including WB, Islamic Development Bank and other

bilateral agencies. The total project cost and financial arrangement are shown in Table 3.5.2-1

below.


Final Report


Table 3.5.2-1 Total Project Cost and Financial Arrangement of CASA-1000

(Unit: million USD)

Total Projec t Cos t: 1,170.00

For Loans /Credits /O thers Amount

Borrower/Recipient 134.50

World Bank 526.50

International Development Association (IDA) (WB) 158.25

IDA Grant (WB) 368.25

Afghanistan Reconstruction Trust Fund 40.00

US (USAID, State Department) 15.00

Islamic Development Bank 250.00

Bilateral Agencies (unidentified) 31.00

Total F inanc ial Ar rangement: 997.00

Financ ing Gap: 173.00 Source: Implementation Status & Results Report, Dec. 27, 2014, the World Bank, and http://www.casa-1000.org/

Table 3.5.2-2 below shows the information of CASA-1000.

Table 3.5.2-2 Information of CASA-1000

Name of

Projec tImpor t from

Capac ity

(MW)

Time of Year for

Impor t

Impor t Tar iff

(US cent/kWh)Present Status

Target

Commiss ioning

Date

CASA-1000

The Kyrgyz

Republic and

Tajikistan via

Afghanistan

1,000

Summer: 4 months

mid-May to

mid-September,

for Peak 2.5 hours

every day

Purchase price:

5.00

Transit fee:

1.25

Under bidding for major

part of the Project with

deadline for bid submission

of March 2, 2015

December 31, 2020

Source: Implementation Status & Results Report, Dec. 27, 2014, the World Bank, and http://www.casa-1000.org/ , and CASA-1000 Project Feasibility Study Update Final Report, February 2011

Figure 3.5.2-1 shows the location of CASA-1000. The power import of 1,000 MW is available in

summer from the middle of May to the middle of September as peak supply for 2.5 hours every

day.


Final Report


Source: http://www.casa-1000.org/

Figure 3.5.2-1 Location of CASA-1000


Final Report


ii) Import from Iran

The present interconnection between Pakistan and Iran has a capacity of 74 MW. These

cross-border transmission lines supply electricity locally in the area and not connected to the

national grid of NTDC.

Pakistan and Iran agreed to construct 220 kV line for import of another 100 MW. For this purpose,

a double circuit twin bundle 220 kV line will be constructed from Polan in Iran to Gwadar in

Pakistan. Length of transmission line in Pakistan would be 75 km and 51 km in Iran. Project cost

is estimated at Rs 3,664 million. Figure 3.5.2-2 shows the location of the project to import the

electricity from Iran.

Source: Prepared by the JICA Study Team based on the map in Data Collection Survey on Infrastructure Improvement of Energy Sector in Pakistan Final Report, JICA, February 2014 and “QESCO Electricity Demand Forecast”, (December, 2012)

Figure 3.5.2-2 Location of 220 kV Cross-border Transmission Line from Iran

The loan agreement in which the Export Development Bank of Iran (EDBI) would finance 70%

of the project cost and the remaining 30% would be borne by NTDC was signed between EDBI

and NTDC on February 4, 2010. The contractor of the project was selected and the construction

kickoff meeting was held between NTDC and the contractor from May 29 to June 2, 2012.

TUFTAN

To: MIR JAWA

MASHKHEL

To: JALAQ / JAGARD

To: JACKIGOR

MANDTo: POLAN

GWADAR

Thermal Power Station

220 kV Grid Station / Line




Final Report


However, due to the sanction on Iran, the project was halted. As of January 2015, NTDC is not

considering this project in its planning.

Pakistan and Iran agreed to construct HVDC interconnection on ±500 kV from Zahedan (Iran) to

Quetta (Pakistan) for importing 1,000 MW. The project is recognized as the development plan

because the feasibility study of the project was completed in October 2011. The total length of the

transmission line will be around 678 km, out of which, 93 km will be constructed in Iran while

585 km will be constructed in Pakistan. Iran will construct a 1,300 MW power plant in Zahedan

dedicated for this purpose. The total estimated cost of the transmission line project is US$ 656

million.

Due to the same reason as that on the above mentioned 220 kV transmission line, NTDC is not

considering this HVDC project in its planning as of January 2015.


Final Report


Chapter 4 CONCLUSION

As a conclusion of this study, the existing and future capacities of the electric power source in

Pakistan are summarized in Table 4-1 below.

Table 4-1 Electric Power Source Capacity in Pakistan: Existing and Future (Unit: MW)

Ongoing

Projec t

Development

Plan

Thermal Power Generation Ins talled Net Dependable * 1 Ins talled Ins talled

Total 15,170 12,657 1,746 5,280

NTDC grid by GENCOs 4,590 3,037 1,342 1,980

NTDC grid by IPPs 8,158 7,465 404 3,300

K-Electric 2,422 2,155 - -

Hydro Power Generation Ins talledDependable * 2

Summer

Dependable * 2

WinterIns talled Ins talled

Total 7,097 7,002 2,449 10,873 19,452

by WAPDA 6,902 6,807 2,385 10,645 11,668

by IPPs 195 195 64 147 5,640

by Provincial Organizations and

IPPs- - - 81 2,144

Renewable Energy Generation Ins talledNet Dependable

Summer

Net Dependable

WinterIns talled Ins talled

Total 207 94 47 1,490 2,269

Wind*3 155 74 27 398 1,804

Solar 0.3 - - 1,000 249

Biomass*4 52 20 20 92 216

Nuc lear Power Generation Ins talled Net * 5 Net

Dependable * 6Ins talled Ins talled

Total 797 705 564 2,880 -

KANUPP 132 90 72 2,200 -

Chashma Nuclear Power Plant 665 615 492 680 -

Power Impor t Ins talled * 7

from Kyrgyz Republic and

Tajikistan (CASA-1000)- - - 1,000 -

Ins talled

Es timated

Net Dependable

Summer

Es timated

Net Dependable

Winter

Ins talled Ins talled

Grand Total 23,271 20,317 15,717 17,989 27,001 Notes

*1: Net dependable capacity means dependable capacity at sending-end of power station to transmission line.

*2:

*3:

*4

*5:

*6:

*7:

Elec tr ic Power Source Ex is ting

Power import is available for 4 months in summer from the middle of May to the middle of September.

These are estimated values with the installed capacities and station service loads. The station service load is assumed at 10

MW for KANUPP and 50 MW is applied for Chashma Nuclear Power Plant.

This is dependable capacity at generating-end of power station (gross capacity). Since the station service consumption of

hydro power plant is small, it is regarded as the same value as net dependable capacity for the calculation of the grand total.

The net dependable capacities in summer and winter are estimated as average generating output in each season assuming

that load factor is 48% in summer and 18% in winter the station service load is negligible.

The net dependable capacities in summer and winter are estimated as average generating output through the year assuming

that load factor at the sending-end is 41.6% with 48 MW of net capacity.

These are estimated values with the net capacities and the capacity factor which is assumed be 80% for both KANUPP and

Chashma Nuclear Power Plant.



Final Report


The existing net dependable capacity of thermal power generation is the technically dependable

capacity. It does not consider the generation constraint due to the financial problem of IPPs.

Therefore, the actual supply capacity of thermal power generation at present seems to be less than

12,657 MW as shown in the above table. The existing dependable capacity of hydro power

generation decreases in winter. It comes down to around 35% of the installed capacity. This is the

major reason why the grand total of the existing net dependable capacity in winter is estimated to

be much lower than that in summer. Both the grand totals of the estimated net dependable

capacity in summer and winter are largely less than the existing electricity demand.

In order to analyze the future development of electric power sources, the current development

projects and plans were categorized into “ongoing project” and “development plan” in this study.

The possibility for an ongoing project to be materialized is higher than that of a development plan

and the lead time of an ongoing project is shorter than that of a development plan. To understand

the real situation of future development of electric power sources, the period-wise installed

capacity of the ongoing projects is shown in Table 4-2.

Table 4-2 Periodwise Installed Capacity of Ongoing Projects (Unit: MW)

2015-17

end

2018-20

end

2020-25

end

2026-35

end

2015-35 end

(Total)

Thermal Power Generation Total 1,746 - - - 1,746

NTDC grid by GENCOs 1,342 - - - 1,342

NTDC grid by IPPs 404 - - - 404

K-Electric - - - - -

Hydro Power Generation Total 2,897 2,315 5,661 - 10,873

by WAPDA 2,669 2,315 5,661 - 10,645

by IPPs 147 - - - 147

by Provincial Organizations and IPPs* 81 - - - 81

1,490 - - - 1,490

Wind 398 - - - 398

Solar 1,000 - - - 1,000

Biomass 92 - - - 92

Nuc lear Power Generation Total 680 1,100 1,100 - 2,880

KANUPP - 1,100 1,100 - 2,200

Chashma Nuclear Power Plant 680 - - - 680

Power Impor t Total - 1,000 - - 1,000

from Kyrgyz Republic and Tajikistan (CASA-1000) - 1,000 - - 1,000

Grand Total 6,813 4,415 6,761 - 17,989 Notes

* : Since no information has been obtained about the targeting commercial operation date, the assumption for the projects to

enter their commercial operation by the end of 2017 is placed.

Ins talled Capac ity Targeting on Enter ing Commerc ial

Operation in the Per iod of :Elec tr ic Power Source

Renewable Energy Generation Total


By the end of 2017, the installed capacity of electric power source will increase by 6,813 MW,

and by the end of 2020 and 2025, the same will increase by 4,415 MW and 6,761 MW,

respectively.

To realize how the above increase of electric power source capacity will mitigate the power

shortage problem in Pakistan in the short term, the gaps between the forecasted demand and the


Final Report


net dependable supply capacity in winter are calculated in December 2014, December 2017, and

December 2020 as shown in Table 4-3 below.

Table 4-3 Estimated Gap Between Demand and Net Dependable Supply Capacity in Winter (Unit: MW)

Dec . 2014 Dec . 2017 Dec . 2020

(Ex is ting) Inc reased Accumulate

d

Inc reased Accumulate

dThermal Power Generation 12,657 1,456 14,113 14,113

Hydro Power Generation 2,449 999 3,448 798 4,246

Renewable Energy Generation*1 47 904 951 951

Nuclear Power Generation 564 480 1,044 777 1,821

Total 15,717 3,839 19,556 1,575 21,131

2014/15 2017/18 2020/21

23,202 26,715 30,766

-7,485 -7,159 -9,635

Notes

*1 :

*2 : Source: Demand Forecast Report December 2012, NTDC

*3 : The estimated gaps in 2017/18 and 2020/21 are -7,959 MW and -10,435, respectively, without increase of the solar power

generation.

Solar power generation is included as day time power supply at 80% of the installed capacity into the increase capacity by

December 2017.

Estimated Demand including Unserved Electricity

by Load Shedding and Export to K-Electric*2

Estimated Gap between Demand and Supply*3

Net Dependable Capacity in Winter


As explained earlier in this chapter, the actual supply capacity of thermal power generation at

present is smaller than its net dependable capacity. Therefore, it seems that the estimated gap in

December 2014 is larger than 7,485 MW. The above table shows that the situation of electricity

shortage will not be mitigated; rather, it will become worse.

Some of the development plans may be completed and enter into commercial operation by the

end of December 2020. It seems, however, that such realization is not so simple. Due to the

optimistic assumption of the commercial operation date for the development plans, many

development plans will fail to commence commercial operation at the prescribed date.

From the above situation, short-term countermeasures, like until the end December 2020, to

increase the power source capacity needs to be taken.

Appendices

Appendix A-1 Collected Data Sheet (Thermal Power Plants)

Appendix A-2 Letter from CPPA (COO-CPPA 10426 dated November 20, 2014)

Appendix A-3 Unit Data of Power Plants with Commissioning Date (Thermal Power Plants)

Appendix A-4 Photographs (Thermal Power Plants)

Appendix B-1 Collected Data Sheet (Hydro Power Plants)

Appendix B-2 Hydropower Development in Pakistan (Location Map)

Appendix B-3 Unit Data of Power Plants with Commissioning Date (Hydro Power Plants)

Appendix C-1 Collected Data Sheet (Renewable Energy)

Appendix C-2 Monthly Histogram and Standard Deviation of Generation by Zorlu Wind Farm

Appendix D Energy Infrastructure Map - 2012

Appendix A-1

Collected Data Sheet (Thermal Power Plants)

Result of Data Collection (Existing Plant)

Sr .


Ins talled

Capac ity

(MW)

Result of Data Collec tion

GENCOs

1 TPS Jamshoro #1-4 Gas/FO/RFO 850 Collected

2 GTPS Kotri #1-7 Gas/HSD 174 Collected

3 TPS Guddu Steam #1-4 Gas/FO 640 Collected

4 TPS Guddu C.C. #5-13 Gas 1,015 Collected

5 TPS Muzaffargarh #1-6 RFO/FO/Gas 1,350 Collected

6 NGPS Multan #1&2 Gas/RFO/HSD/FO 0 Decommissioned

7 GTPS Faisalabad #1-9 Gas/HSD 244 Collected (Generation stopped)

8 SPS Faisalabad #1&2 FO/Gas/RFO 132 Collected (Generation stopped)

9 Shahdra G.T. Gas 0 Decommissioned

10 FBC Lakhra Coal 150 Collected

11 TPS Quetta Gas 35 Collected

Thermal IPPs

12 KAPCO RFO/Gas/HSD 1,638 Collected

13 Hub Power Project (HUBCO) RFO 1,292 Collected

14 Kohinoor Energy Ltd. (KEL) RFO 131 Collected

15 AES Lalpir Ltd. RFO 362 Collected

16 AES Pak Gen (Pvt) Ltd. RFO 365 Not collected

17 SEPCOL RFO 135 Generation stopped from Feb 2013

18 Habibullah Energy Ltd. (HCPC) Gas 140 Not collected

19 Uch Power Project Gas 586 Not collected

20 Rousch (Pak) Power Ltd. Gas 450 Not collected

21 Fauji Kabirwala (FKPCL) Gas 157 Not collected

22 Saba Power Company RFO 134 Not collected

23 Japan Power Generation Ltd. RFO 135

Generation stopped because of

breaking down tariff negotiation to

NEPRA

24 Liberty Power Project Gas 235 Not collected

25 Altern Energy Ltd. (AEL) Gas 31 Not collected

26 Attock Generation PP RFO 163 Not collected

27 ATLAS Power RFO 219 Not collected

28 Engro P.P. Daharki, Sindh HSD/Gas/FO 226 Not collected

29 Saif P.P. Sahiwal, Punjab Gas/HSD 225 Not collected

30 Orient P.P. Balloki, Punjab Gas/HSD 225 Not collected

31 Nishat P.P. Near Lahore RFO 200 Not collected

32 Nishat Chunian Proj. Lahore RFO 200 Not collected

33 Foundation Power Gas 174 Collected

34 Saphire Muridke Gas/HSD 225 Not collected

35 Liberty Tech RFO 200 Not collected

36 Hubco Narowal RFO 220 Collected

37 Halmore Bhikki HSD/Gas 225 Not collected

FO: Furnace Oil / HSD: High Speed Diesel / RFO: Residual Furnace Oil

Other Collected Data (Ongoing Project / Development Plan)

No data was available.

Questionnairefor

Least Cost Generation and TransmissionExpansion Plan (Plant Capacity Analysis)

in Pakistan

<< DATA SHEETS >>GENCO-1

Jamshoro Thermal Power Plant


Data Sheet <FORM-1> Existing power stations (thermal)

Thermal Power Plant Questionnaire (All power plant : excluding SPP) Thermal NoGENCO-1

Power Plant Name Installed Capacity Derated Capacity Fuel Heat Value (Gas) Fuel Cost (Gas)Jamshoro 850 (MW) 648 (MW) 8831 (kcal/m3) 20773.144 ($/103Nm3)

Construction Cost Generation Cost Fuel Heat Value (Diesel) Fuel Cost (Diesel)

(106Rs) *17.4618 (Rs/kWh) 9349 (kcal/ltr ) 95229.90 ($/kl )

Owner Fuel Heat Value (Coal) Fuel Cost (Coal)***JPCL N.A (kcal/kg) N.A ($/103kg)

Fuel Heat Value(Oil-HSFO, RFO) Fuel Cost (FO)

10128 (kcal/kg) 66233.848 ($/103kg)

Unit No. Unit size Unit size Type Fuel Type F.O.R S.O Min. Output Thermal Efficiency Necessary hours to startInstalled Dearetd at 100% load at 75% load at 50% load M.S.S W.E.S. D.S.S.

(MW) (MW) ST, GT, CC. **(%) **% **(MW) (%) (%) (%) **(Hours/start) (Hours) (Hours)1 250 182 ST FO 3.11 120 36.63 720.852 200 155 ST Gas/FO 33.95 100 33.89 163.813 200 155 ST Gas/FO 8.88 100 33.89 338.954 200 156 ST Gas/FO 100 0 33.89 056789

10

Unit No. M.S.S. W.E.S. D.S.S. C.O A.F.C Width Construction Cost

Y or N Y or N Y or N yy/mm (%) (106$) F. O. R : Forced Outage Rate1 Y N N 1990/01 S. O : Scheduled Outage2 Y N N 1989/12 Min. Output : Minimum Output3 Y N N 1990/01 M. S. S : Monthly Start & Stop4 Y N N 1991/01 W. E. S : Weekend Start & Stop5 D. S. S. : Daily Start & Stop6 C. O : Commercial Operation7 A. F. C : Automatic Frequency Control89

10

Actual records of operation Jan. Feb. Mar. Apr. May June July Aug. Sept. Oct. Nov. Dec.2013 Maximum Ouput (MW) 470 640 510 735 710 715 712 710 680 697 450 440

Minimum Output (MW) 263 425 300 400 425 330 363 403 343 343 250 385Average Monthly Load (MW) 335 267 260 264 345 328 539 492 498 469 255 309Average Monthly Heat rate (BTU/kWh) 11277 11650 10785 11326 10491 10834 10431 10416 10533 10568 10601 11562Gross Monthly Generation (MWh) 269889.2 307364.9 317429.3 372044.9 230200.7 208380 384060.7 331883.4 341874.1 322108.5 163085.3 178601.2Auxiliary Consumption (MWh) 26184.2 29939.94 22872 35769.92 26225.68 23465.05 39565.7 33348.45 34159.08 33988.51 16100.3 21291.22

2012 Maximum Ouput (MW) 440 340 425 300 300 440 425 425 690 225 495 475Minimum Output (MW) 313 300 425 175 230 333 343 320 313 163 325 263Average Monthly Load (MW) 251 153 165 148 143 110 190 163 135 110 123 196Average Monthly Heat rate (BTU/kWh) 11988 10921 12037 13321 13004 11521 11858.69 11706 13365 12450 11172 12326Gross Monthly Generation (MWh) 176644.9 99477.9 117171.4 95948.01 96661.23 75887.81 132587.2 116680 74375 73200 284475.3 129171Auxiliary Consumption (MWh) 21274.92 10912.9 14621.35 14313.01 15081.23 9842.806 16032.22 13769.95 11759 7703.18 26760.26 14155.9

2011 Maximum Ouput (MW) 610 675 620 575 525 580 550 710 530 450 340 440Minimum Output (MW) 363 363 363 343 323 343 363 585 353 330 263 385Average Monthly Load (MW) - - - 285 - - 307 327 188 184 165 259Average Monthly Heat rate (BTU/kWh) 10819 11241 11241 11241 16771 11473 11856 11525 12223 10954 11408 11562Gross Monthly Generation (MWh) 179852 238401.5 310449.7 187465 163071.8 244413.2 206940.1 340802.9 130088.2 134145.1 108390.8 178601.2Auxiliary Consumption (MWh) 14768.28 25266.54 32110.03 24030.03 20956.8 28578.2 25782.95 46280.71 18163.24 16655.1 13875.85 21291.22

2010 Maximum Ouput (MW) 607 700 675 677 655 657 645 660 630 630 460 430Minimum Output (MW) - - - - - - 363 363 370 375 263 300Average Monthly Load (MW) 466 547 610 636 554 534 560 485 360 386 205 174Average Monthly Heat rate (BTU/kWh) 11691 11017 11293 11227 11348 11441 11246 11289 11756 11265 11654 11954Gross Monthly Generation (MWh) 320977.4 336462.8 425927.6 424427.6 385355.9 355919.9 395474.9 233323.2 236631.3 257169.7 136852 116065Auxiliary Consumption (MWh) 31632.4 32887.83 38532.57 38847.58 37175.91 34742.87 36999.88 34231.5 27611.33 27734.66 16446.97 14349.99

2009 Maximum Ouput (MW) 312 460 520 620 495 635 595 610 600 600 600 520Minimum Output (MW) - - - - - - - - - - - -Average Monthly Load (MW) 225 314 368 532 387 476 508 452 528 498 444 445Average Monthly Heat rate (BTU/kWh) 11466 11369 11400 10965 11560 11577 11463 11671 11473 11399 11396 11641Gross Monthly Generation (MWh) 167515.8 207334.1 261310.7 369760.4 282801.2 331526.7 362849.5 323970.3 370932.3 351996.7 304896.7 317606.9Auxiliary Consumption (MWh) 16865.78 19799.06 24895.66 34505.44 31481.18 34661.7 37369 35235.26 39262.3 36491.72 29306.68 30321.94

2008 Maximum Ouput (MW) 455 610 630 630 615 445 400 390 370 385 410 507Minimum Output (MW) 313 350 458 423 380 283 - - - - - -Average Monthly Load (MW) 372 450 549 529 423 315 372 306 318 263 305 423Average Monthly Heat rate (BTU/kWh) 11277 11650 11448 11326 11329 12047 11684 11599 12000 12126 11940 10941Gross Monthly Generation (MWh) 269889.2 307364.9 398675.3 372044.92 312793.38 221764.2 266925.5 223023.04 225030.16 192938 293498.1 304724.2Auxiliary Consumption (MWh) 26184.2 29939.94 37660.28 35769.92 30703.380 23816.67 27910.5 23518.04 24980.16 23258.02 25622.95 28059.18

RemarksNote: *Annual figure 2013-14 (Avg) **ALL figures are for the month of August 2014 ***(Jamshoro Power Company Limited)

15682.6

Data Sheet <FORM-3> Simulation data of demand-and-supply operation

1. Assumptions for economic analysis

Power Plant Name Unit No. Reporting Year1 2014

1) Fixed Costs

unit Hydro Gas Diesel RFO/HSFO Coal OthersDiscount Rate %Life Time year 24 24Salvage Value %Capital Cost Rs/kW 18450.13 18450.13Construction year 1990 1990Fixed O&M Rs/kW/mo. 220.3812 220.3812Variable O&M Rs/MWh 145.4 145.4Tax & Others (%) 17 17Fuel Use (%) 0 100

2) Fuel Costs

2005 2010 2013 8831 (kcal/m3) 2.57 4.97 6.91 (Rs/kWh)9349 (kcal/l ) (Rs/kWh)N.A (kcal/kg) N.A N.A (Rs/kWh)10,128 (kcal/kg) 4.99 13.48 17.62 (Rs/kWh)

2. WASP Simulation Data

1) Input Data of the latest power sources development planfree format

2) Output Data of the latest power sources development planfree format

Unit Price

Jamshoro- GENCO 1

Others

Heat value (LHV)Type

GasDieselCoalRFO/HSFO




1) Fixed Costs


2) Fuel Costs

2005 2010 2013 8831 (kcal/Nm3) 2.57 4.97 6.91 (Rs/kWh)9349 (kcal/l ) (Rs/kWh)N.A (kcal/kg) N.A N.A (Rs/kWh)10,128 (kcal/kg) 4.99 13.48 17.62 (Rs/kWh)




Unit Price

RFO/HSFOOthers

Jamshoro- GENCO 1

Type Heat value (LHV)

GasDieselCoal




1) Fixed Costs


2) Fuel Costs





Unit Price

RFO/HSFOOthers

Jamshoro- GENCO 1


GasDieselCoal




1) Fixed Costs


2) Fuel Costs





Unit Price

RFO/HSFOOthers

Jamshoro- GENCO 1


GasDieselCoal

Questionnairefor


in Pakistan


Kotri Thermal Power Plant



Thermal Power Plant Questionnaire (All power plant : excluding SPP) Thermal No. GENCO-1

Power Plant Name Installed Capacity Derated Capacity Fuel Heat Value (Gas) Fuel Cost (Gas)Kotri-GENCO 1 174 (MW) 120 (MW) 8565 (kcal/m3) 20773.144 (Rs/103Nm3)

Construction Cost Generation Cost Fuel Heat Value (Diesel) Fuel Cost (Diesel)2243 (106$) *7.053 (¢/kWh) N.A (kcal/ltr ) N.A ($/kl )

Owner Fuel Heat Value (Coal) Fuel Cost (Coal)***JPCL N.A (kcal/kg) N.A ($/103kg)

Fuel Heat Value(Oil-HSFO, RFO) Fuel Cost (FO)

N.A (kcal/kg) N.A ($/103kg)

Unit No. Unit size Unit size Type Fuel Type F.O.R S.O Min. Output Thermal Efficiency Necessary hours to startInstalled Derated at 100% load at 75% load at 50% load M.S.S W.E.S. D.S.S.

(MW) (MW) ST, GT, CC. **(%) **% **(MW) (%) (%) (%) **(Hours/start) (Hours) (Hours)1 15 De-Commisioned GT Gas - - - - -2 15 De-Commisioned GT Gas - - - - -3 25 20 GT Gas - - 18 27.85 228.44 25 20 GT Gas - - 15 27.85 41.15 25 20 GT Gas - - 17 27.75 229.26 25 20 GT Gas - - 17 27.75 48.27 44 40 ST CCP - - 7 40.43 226.889

10


Y or N Y or N Y or N yy/mm (%) (106$) F. O. R : Forced Outage Rate1 Y N N 1969/12 S. O : Scheduled Outage2 Y N N 1970/01 Min. Output : Minimum Output3 Y N N 1979/05 M. S. S : Monthly Start & Stop4 Y N N 1979/05 W. E. S : Weekend Start & Stop5 Y N N 1981/05 D. S. S. : Daily Start & Stop6 Y N N 1981/05 C. O : Commercial Operation7 Y N N 1994/12 A. F. C : Automatic Frequency Control89

10


Minimum Output (MW) 75 75 68 66 52 52 0 46 0 60 67 44Average Monthly Load (MW) 13 72 48 42 30 24 0 24 0 11 25 2Average Monthly Heat rate (BTU/kWh) 11858 10576 10938 9867 10937 11033 0 11195 0 11419 11543 11341Gross Monthly Generation (MWh) 55790.35 60687.03 80588.15 62422.9 20706 14151.2 0 17663 0 15802 15887 1581Auxiliary Consumption (MWh) 1499.75 2084.397 2859.75 2337.611 1057.643 865.384 129.168 777.646 126.229 835.963 903.68 141.043

2012 Maximum Ouput (MW) 79 0 79 114 112 109 101 110 116 97 115 115Minimum Output (MW) 67 0 53 78 49 70 53 61 67 53 86 76Average Monthly Load (MW) 6 0 13 69 92 85 53 52 21 54 31 -Average Monthly Heat rate (BTU/kWh) 15948 0 15912 10874 10928 10610 11163 11306 10839 11095 10700 10676Gross Monthly Generation (MWh) 4309.5 0 9308.1 48783.31 60875 55912.75 34992 39231 53072.35 39057 60773.1 20379Auxiliary Consumption (MWh) 304.4999 253.0039 521.1 2134.314 2520 2458.75 1517.79 1610.698 2094.95 1504.314 839.78 839.78

2011 Maximum Ouput (MW) 141 133 103 94 125 105 105 109 108 56 107 0Minimum Output (MW) 85 89 57 68 73 58 58 60 75 37 64 0Average Monthly Load (MW) - - - 33 - - 37 27 45 15 14 0Average Monthly Heat rate (BTU/kWh) 13818 11040 10790 11298 11270 10857 11425 11646 12071 11408 11141 0Gross Monthly Generation (MWh) 33787.2 16367.25 36136 23587.25 45943.55 34615.65 24928.65 28458.3 31806.9 9807.45 9645.75 0Auxiliary Consumption (MWh) 784.882 671.511 1407.808 1074.366 1751.028 1504.573 1675.649 1424.303 1334.903 705.446 656.753 293.0011

2010 Maximum Ouput (MW) 84 90 130 134 131 120 120 119 119 112 123 129Minimum Output (MW) - - - - - - 85 78 78 69 95 99Average Monthly Load (MW) 51 59 74 109 93 84.2 72 79 61 54 69 60Average Monthly Heat rate (BTU/kWh) 12913 11601 12175 12050 11973 12021 11676 12457 11821 11799 11551 11276Gross Monthly Generation (MWh) 38965.1 39221.1 52140.7 73693.9 66088.5 57773.9 49782.5 56660.15 42936.1 37775.81 48495.45 44109.55Auxiliary Consumption (MWh) 983.1 1500.1 2090.7 2540.9 2234.8 1994.9 1967.626 264.646 1636.541 1559.286 1594.919 1365.486

2009 Maximum Ouput (MW) 120 132 105 130 125 123 125 121 123 114 136 134Minimum Output (MW) - - - - - - - - - - - -Average Monthly Load (MW) 59 72 92 108 107 110 98 88 90 75 76 69Average Monthly Heat rate (BTU/kWh) 14679 11234 12636 12409 12636 12171 11513 11870 12040 11322 11864 11795Gross Monthly Generation (MWh) 43803.7 46609.45 69095.5 75553.45 75244.95 76474.15 68365.15 63926.15 64052.7 54080.6 54995.2 49345.75Auxiliary Consumption (MWh) 695.5 1325.45 2105.5 2211.45 2178 2390.15 2449.15 2154.15 2054.7 1870.6 1856.2 1545.75

2008 Maximum Ouput (MW) 148 144 139 134 134 131 128 125 128 131 139 144Minimum Output (MW) 87 87 78 92 93 97 - - - - - -Average Monthly Load (MW) 77 92 124 119 115 120 101 96 103 36 85 65Average Monthly Heat rate (BTU/kWh) 12009 10935 11951 11798 12173 12109 11834 11577 11546 11985 10832 12211Gross Monthly Generation (MWh) 56641.350 62870.03 89598.15 82217 81177.2 83302.65 72500.550 69429 71751.3 76187.6 60083.65 48084.15Auxiliary Consumption (MWh) 1499.750 2084.397 2765.55 2450.099 2435.195 2407.154 2128.650 2102.7 2285.7 2145.3 1897.25 1419.65

RemarksNote: *Annual figure 2013-14 (Avg) **ALL figures are for the month of August 2014 ***(Jamshoro Power Company Limited)




1) Fixed Costs

unit Hydro Gas Diesel RFO/HSFO Coal OthersDiscount Rate % - - - - - -Life Time year - 45 - - - -Salvage Value % - - - - - -Capital Cost Rs/kW - 12890.92 - - - -Construction year - 1969 - - - -Fixed O&M Rs/kW/mo. - - - - - -Variable O&M Rs/MWh - - - - - -Tax & Others (%) - 17 - - - -Fuel Use (%) - - - - - -

2) Fuel Costs

2005 2010 2013 8565 (kcal/Nm3) - - - (Rs/kWh)

- (kcal/l ) - - - (Rs/kWh)- (kcal/kg) - - - (Rs/kWh)- (kcal/kg) - - - (Rs/kWh)- - - -




Unit Price

Kotri- GENCO 1

Others






1) Fixed Costs

unit Hydro Gas Diesel RFO/HSFO Coal OthersDiscount Rate % - - - - - -Life Time year - 44 - - - -Salvage Value % - - - - - -Capital Cost Rs/kW - 12890.92 - - - -Construction year - 1970 - - - -Fixed O&M Rs/kW/mo. - - - - - -Variable O&M Rs/MWh - - - - - -Tax & Others (%) - 17 - - - -Fuel Use (%) - - - - - -

2) Fuel Costs

2005 2010 2013 8565 (kcal/Nm3) - - - (Rs/kWh)

- (kcal/l ) - - - (Rs/kWh)- (kcal/kg) - - - (Rs/kWh)- (kcal/kg) - - - (Rs/kWh)- - - -




Unit Price

RFO/HSFOOthers

Kotri- GENCO 1


GasDieselCoal




1) Fixed Costs

unit Hydro Gas Diesel RFO/HSFO Coal OthersDiscount Rate %Life Time year 35Salvage Value %Capital Cost Rs/kW 12890.92Construction year 1979Fixed O&M Rs/kW/mo. 220.38Variable O&M Rs/MWh 899 Tax & Others % 17Fuel Use (%) 100

2) Fuel Costs

2005 2010 2013 8565 (kcal/Nm3) 2.46 4.69 7.05 (Rs/kWh)N.A (kcal/l ) N.A N.A N.A (Rs/kWh)N.A (kcal/kg) N.A N.A N.A (Rs/kWh)N.A (kcal/kg) N.A N.A N.A (Rs/kWh)




Unit Price

RFO/HSFOOthers

Kotri- GENCO 1


GasDieselCoal




1) Fixed Costs


2) Fuel Costs





Unit Price

RFO/HSFOOthers

Kotri- GENCO 1


GasDieselCoal




1) Fixed Costs


2) Fuel Costs





Unit Price

RFO/HSFOOthers

Kotri-GENCO 1


GasDieselCoal




1) Fixed Costs


2) Fuel Costs





Unit Price

RFO/HSFOOthers

Kotri-GENCO 1


GasDieselCoal




1) Fixed Costs

unit Hydro Gas Diesel RFO/HSFO Coal OthersDiscount Rate %Life Time year 20Salvage Value %Capital Cost Rs/kW 12890.92Construction year 1994Fixed O&M Rs/kW/mo. 220.38Variable O&M Rs/MWh 899 Tax & Others (%) 17Fuel Use (%) 100

2) Fuel Costs





Unit Price

RFO/HSFOOthers

Kotri-GENCO 1


GasDieselCoal

Questionnairefor


in Pakistan


Guddu Thermal Power Plant




Power Plant Name Installed Capacity Derated Capacity Fuel Heat Value (Gas) Fuel Cost (Gas)Guddu 1655 (MW) 1180 (MW) 7358 (kcal/m3) 19123.949 ($/103Nm3)

Construction Cost Generation Cost Fuel Heat Value (Diesel) Fuel Cost (Diesel)16433 (106Rs) *11.887 (¢/kWh) N.A (kcal/ltr ) N.A ($/kl )

Owner Fuel Heat Value (Coal) Fuel Cost (Coal)***CPGCL N.A (kcal/kg) N.A ($/103kg)

Fuel Heat Value(Oil-HSFO, RFO) Fuel Cost (FO)10282 (kcal/kg) ($/103kg)


(MW) (MW) ST, GT, CC. **(%) **% **(MW) (%) (%) (%) **(Hours/start) (Hours) (Hours)1 110 50 ST Gas 15.54 0 15 37.5 314.192 110 60 ST Gas 100 0 0 37.5 03 210 130 ST RFO/Gas 3.67 0 70 38 716.674 210 140 ST RFO/Gas 100 0 0 38.7 05 100 70 ST CCP 20.35 19.59 10 45 55.866 100 80 ST CCP 100 0 0 45 07 100 105 GT Gas 3.48 14.01 20 31.5 204.648 100 105 GT Gas 0 9.36 30 31.5 337.189 100 100 GT Gas 100 0 0 31.5 0

10 100 100 GT Gas 100 0 0 31.5 011 136 80 GT Gas 100 0 0 32 012 136 80 GT Gas 100 0 0 32 013 143 80 ST CCP 100 0 0 49 0


Y or N Y or N Y or N yy/mm (%) (106$) F. O. R : Forced Outage Rate1 Y N N 1974/03 S. O : Scheduled Outage2 Y N N 1974/10 Min. Output : Minimum Output3 Y N N 1980/11 M. S. S : Monthly Start & Stop4 Y N N 1985/12 W. E. S : Weekend Start & Stop5 Y N N 1985/12 D. S. S. : Daily Start & Stop6 Y N N 1986/03 C. O : Commercial Operation7 Y N N 1986/04 A. F. C : Automatic Frequency Control8 Y N N 1986/049 Y N N 1987/12

10 Y N N 1988/011 Y N N 1992/0912 Y N N 1992/1213 Y N N 1994/05


Minimum Output (MW) 555 499 597 455 291 449 361 330 347 512 325 235Average Monthly Load (MW) 915 889 822 645 724 491 582 583 644 717 703 702Average Monthly Heat rate (BTU/kWh) 13166 11849 10576 11961 9549 10277 12205 9881 10583 10522 9700 10002Gross Monthly Generation (MWh) 699329.9 764152.9 670580 485810.7 639511.2 290746.5 419430.2 499331.6 450736.5 553175.3 487683.1 495424.5Auxiliary Consumption (MWh) 26316.05 28773.58 20496.23 18225.73 23997.76 18185.15 13655.59 11884.95 12677.78 17920.79 17140.25 17083.5

2012 Maximum Ouput (MW) 1187 1255 1255 1212 994 1026 1028 990 1023 1034 1054 1160Minimum Output (MW) 597 489 594 508 496 375 426 572 582 498 705 769Average Monthly Load (MW) 954 981 1041 910 855 781 842 899 577 795 878 970Average Monthly Heat rate (BTU/kWh) 9988 9860 9825 10566 10671 10199 10925 9967 9818 11361 10647 11325Gross Monthly Generation (MWh) 687407.1 645689 720166.6 612359.2 579512.9 532780.9 589506.1 650121.1 672204.5 724304.8 581645.2 764665Auxiliary Consumption (MWh) 20335.33 20556.69 22985.58 25152.58 25117.12 20434.64 24609.93 28187.22 23212.18 19846.04 12286.56 25323.6

2011 Maximum Ouput (MW) 1104 1115 988 1063 1072 997 1164 1163 1111 1133 1130 1187Minimum Output (MW) 289 339 284 405 457 478 435 518 459 465 499 635Average Monthly Load (MW) - - - 700 - - 859 957 834 879 919 942Average Monthly Heat rate (BTU/kWh) 10041 9893 11565 11037 10392 10642 10704 10367 10581 10311 10145 9950Gross Monthly Generation (MWh) 635385.7 504628.4 467776.9 500150.4 573328.8 539711.5 608371.5 658799.5 566320.2 608270.1 618178.5 672699.8Auxiliary Consumption (MWh) 22331.51 17080.55 16768.47 16199.78 21149.19 18615.11 18359.63 20053.95 17338.6 16473.79 20917.4 18002.74

2010 Maximum Ouput (MW) 943 944 942 910 809 944 872 956 856 919 1028 1112Minimum Output (MW) 465 0 480 529 475 583Average Monthly Load (MW) 847 886 848 732 750 759 690 583 567 686 701 667Average Monthly Heat rate (BTU/kWh) 20734 20429 20542 23153 22929 23649 11410 11328 11322 11616 10518 10732Gross Monthly Generation (MWh) 633711.7 588826.5 622919 511381 546751 527600 496031.9 430422.1 407510.5 507890.8 500993.1 510557.5Auxiliary Consumption (MWh) 28415.71 26816.97 29271 23934 27875 22745 19338.11 14418.52 12250.25 19435.73 20872.49 18956.11

2009 Maximum Ouput (MW) 1101 1102 1095 1021 1066 1071 1011 1047 1030 1115 941 960Minimum Output (MW)Average Monthly Load (MW) 958 1033 986 834 897 968 878 910 777 815 869 904Average Monthly Heat rate (BTU/kWh) 20726 20553 21429 21973 21626 21190 22878 22010 21904 21342 20938 20183Gross Monthly Generation (MWh) 729901 698543 738149 602499 658553 685372 634540 669528 563142 602957 626668 684096.3Auxiliary Consumption (MWh) 30281 27051 32182 28999 27235 30504 26793 26387 21539 25913 29122 32420.18

2008 Maximum Ouput (MW) 1058 1214 1063 1063 1089 1140 1085 987 1064 1001 994 989Minimum Output (MW) 670 469 722 602 493 426Average Monthly Load (MW) 981 959 1006 843 915 926 980 896 852 894 963 818Average Monthly Heat rate (BTU/kWh) 19926 20164 20360 21816 21919 21540 21405 21456 21455 21225 20719 21491Gross Monthly Generation (MWh) 742481.5 672473 754075 610385.5 662316.9 658313.9 721800.6 649407 600386 667454 700826 617460Auxiliary Consumption (MWh) 24155.65 19368 25439 23345.58 31532 28599 34021 31350 29549 31347 33786 29295

RemarksNote: *Annual figure 2013-14 (Avg) **ALL figures are for the month of August 2014 ***(Central Power Generation Company Limited)




1) Fixed Costs

unit Hydro Gas Diesel RFO/HSFO Coal OthersDiscount Rate %Life Time year 40Salvage Value %Capital Cost Rs/kW 9929.3051Construction year 1974Fixed O&M Rs/kW/mo. 126.596Variable O&M Rs/MWh 68.9 Tax & Others (%) 17%Fuel Use (%) 100

2) Fuel Costs

2005 2010 2013 7358 (kcal/Nm3) 4.33 8.83 11.89 (Rs/kWh)N.A (kcal/l ) N.A N.A N.A (Rs/kWh)N.A (kcal/kg) N.A N.A N.A (Rs/kWh)10,282 (kcal/kg) 3.58 11.83 N.A (Rs/kWh)




Unit Price

Guddu- GENCO 2

Others






1) Fixed Costs


2) Fuel Costs





Unit Price

RFO/HSFOOthers

Guddu- GENCO 2


GasDieselCoal




1) Fixed Costs


2) Fuel Costs





Unit Price

RFO/HSFOOthers

Guddu- GENCO 2


GasDieselCoal




1) Fixed Costs


2) Fuel Costs





Unit Price

RFO/HSFOOthers

Guddu- GENCO 2


GasDieselCoal




1) Fixed Costs


2) Fuel Costs





Unit Price

RFO/HSFOOthers

Guddu- GENCO 2


GasDieselCoal




1) Fixed Costs


2) Fuel Costs





Unit Price

RFO/HSFOOthers

Guddu- GENCO 2


GasDieselCoal




1) Fixed Costs


2) Fuel Costs





Unit Price

RFO/HSFOOthers

Guddu- GENCO 2


GasDieselCoal




1) Fixed Costs


2) Fuel Costs





Unit Price

RFO/HSFOOthers

Guddu- GENCO 2


GasDieselCoal




1) Fixed Costs


2) Fuel Costs





Unit Price

RFO/HSFOOthers

Guddu- GENCO 2


GasDieselCoal




1) Fixed Costs


2) Fuel Costs





Unit Price

RFO/HSFOOthers

Guddu- GENCO 2


GasDieselCoal




1) Fixed Costs

unit Hydro Gas Diesel RFO/HSFO Coal OthersDiscount Rate %Life Time year 26Salvage Value %Capital Cost Rs/kW 9929.3051Construction year 1988Fixed O&M Rs/kW/mo. 126.5959Variable O&M Rs/MWh 68.9Tax & Others (%) 17%Fuel Use (%) 100

2) Fuel Costs





Unit Price

RFO/HSFOOthers

Guddu- GENCO 2


GasDieselCoal




1) Fixed Costs


2) Fuel Costs





Unit Price

RFO/HSFOOthers

Guddu- GENCO 2


GasDieselCoal




1) Fixed Costs


2) Fuel Costs





Unit Price

RFO/HSFOOthers

Guddu- GENCO 2


GasDieselCoal

Questionnairefor


in Pakistan


MuzaffargarhThermal Power Plant




Power Plant Name Installed Capacity Derated Capacity Fuel Heat Value (Gas) Fuel Cost (Gas)Muzaffargarh 1350 (MW) 1033 (MW) 8204.1 (kcal/m3) 172.4168 ($/103Nm3)

Construction Cost Generation Cost Fuel Heat Value (Diesel) Fuel Cost (Diesel)17628 (106$) *18.4332 (Rs/kWh) 9557.993 (kcal/ltr ) 900 ($/kl )

Owner Fuel Heat Value (Coal) Fuel Cost (Coal)***NPGCL N.A (kcal/kg) N.A ($/103kg)

Fuel Heat Value(Oil-HSFO, RFO) Fuel Cost (FO)N.A (kcal/kg) N.A ($/103kg)


(MW) (MW) ST, GT, CC. **(%) **% **(MW) (%) (%) (%) **(Hours/start) (Hours) (Hours)1 210 167 ST Gas/FO 17.41 110 36.77 131.072 210 168 ST Gas/FO 0 110 36.77 711.643 210 167 ST Gas/FO 0 110 36.77 693.24 320 225 ST Gas/FO 0.27 110 36.7 741.985 200 153 ST Gas/FO 2.36 60 31.65 726.426 200 153 ST Gas/FO 9.35 25 31.65 337.21789

10


Y or N Y or N Y or N yy/mm (%) (106$) F. O. R : Forced Outage Rate1 Y N N 1993/09 S. O : Scheduled Outage2 Y N N 1994/03 Min. Output : Minimum Output3 Y N N 1995/02 M. S. S : Monthly Start & Stop4 Y N N 1997/12 W. E. S : Weekend Start & Stop5 Y N N 1995/02 D. S. S. : Daily Start & Stop6 Y N N 1997/01 C. O : Commercial Operation7 A. F. C : Automatic Frequency Control89

10


Minimum Output (MW) 760 620 580 515 660 485 585 570 725 625 610 680Average Monthly Load (MW) 878 577 575 582 578 631 742 735 756 674 624 472Average Monthly Gross Heat rate (BTU/kW 7940 10800 10609 10561 10751 26732 10568 10583 10612 10443 10547 10572Gross Monthly Generation (MWh) 657109 435305.3 481400 378057.9 402519.9 150654.8 531055.3 539166.1 532795.4 482568.3 420852.2 331655.3Auxiliary Consumption (MWh) 36271.81 31801.93 39741.51 27988.19 42277.86 48433.29 59924.19 59653.22 54438.74 53131.58 42357.73 34339.01

2012 Maximum Ouput (MW) 895 415 795 725 590 760 985 925 855 950 800 1130Minimum Output (MW) 665 270 560 425 445 625 600 530 455 875 890 535Average Monthly Load (MW) 505 292 523 455 349 372 697 518 437 490 512 515Average Monthly Gross Heat rate (BTU/kW 10429 10326 10441 10515 10543 10312 10601 13613 9104 11884 12876 7170Gross Monthly Generation (MWh) 377851.5 202638.4 386795 322871.3 256263.4 266776.6 521008 302256.8 313045.7 359224.6 358327.4 669297.7Auxiliary Consumption (MWh) 21274.92 21657.79 35148.19 32750.65 29091.53 27198.25 56591.73 27728.33 34284.8 37180.63 38115.26 34545.34

2011 Maximum Ouput (MW) 695 505 685 735 695 605 845 710 790 890 705 520Minimum Output (MW) 570 380 535 625 515 470 665 585 530 610 650 405Average Monthly Load (MW) - - - 489 - - 546 550 359 436 416 365Average Monthly Gross Heat rate (BTU/kW 11255 13023 10848 10928 11082 10847 10797 10738 11266 11097 10793 10540Gross Monthly Generation (MWh) 441780.2 279601.2 345859.1 349466.1 258133.1 353287.4 393417.7 340802.9 254695 316123 292521.6 270470Auxiliary Consumption (MWh) 49725.36 30360.57 37381.47 41110.72 33490.59 39503.4 45567.26 46280.71 38190.55 39425.68 30787.9 22618

2010 Maximum Ouput (MW) 870 860 865 810 830 800 840 775 795 810 805 790Minimum Output (MW) - - - - - - 600 540 550 520 560 500Average Monthly Load (MW) 742 751 672 752 648 638 503 467 559 650 403 367Average Monthly Gross Heat rate (BTU/kW 10850 10872 11109 10786 10926 11194 11745 11796 8744 11245 11408 11744Gross Monthly Generation (MWh) 545125.2 490092.5 494976.4 532048.2 476481.1 439266.2 344109.8 323009.2 386855.3 473657.2 286190.5 265292.8Auxiliary Consumption (MWh) 46734.7 44994.32 49369.88 48051.01 46232.15 47311.59 39395.75 43444.19 52386.28 52142.24 31865.45 27309.23

2009 Maximum Ouput (MW) 1100 935 935 1095 1040 975 920 900 885 905 900 875Minimum Output (MW) - - - - - - - - - - - -Average Monthly Load (MW) 715 769 765 920 873 818 802 758 731 735 607 616Average Monthly Gross Heat rate (BTU/kW 10478 10314 10288 10653 10900 10954 10909 10793 10836 10835 10725 10825Gross Monthly Generation (MWh) 514651.3 499947.6 562313.7 649285.9 638845 573334.7 586949.1 549730.6 517060.3 536599 434499.8 452749.2Auxiliary Consumption (MWh) 40686.07 42898.8 49652.18 55585.4 59465.08 55662.09 60187.29 56029.73 54105.66 53159.29 41292.63 43059.71

2008 Maximum Ouput (MW) 835 805 1050 1085 1065 1045 835 935 965 880 905 1120Minimum Output (MW) 620 620 594 624 670 600 - - - - - -Average Monthly Load (MW) 678 623 662 868 766 744 505 572 744 704 593 680Average Monthly Gross Heat rate (BTU/kW 10521 10800 10901 10456 10649 10686 10571 10500 10549 10552 10478 10549Gross Monthly Generation (MWh) 495903.8 435305.3 481400 613669.9 537684 519347.5 369740.2 417315.5 525665.1 510980.7 406637.9 494251.5Auxiliary Consumption (MWh) 36271.81 31801.93 39741.51 51303.92 50542.18 49729.72 36773.76 43042.97 53493.28 43408.97 43352.19 38711.72

RemarksNote: *Annual figure 2013-14 (Avg) **ALL figures are for the month of August 2014 ***(Nothern Power Generation Company Limited)




1) Fixed Costs

unit Hydro Gas Diesel RFO/HSFO Coal OthersDiscount Rate %Life Time year 21 21Salvage Value %Capital Cost Rs/kW 13057.48 13057.48Construction year 1993 1993Fixed O&M Rs/kW/mo. 91.8999 91.8999Variable O&M Rs/MWh 0.025 0.025Tax & Others $/MWhFuel Use (%) 2 98

2) Fuel Costs

2005 2010 2013 8204.100182 (kcal/Nm3) 3.07 - 8.47 (Rs/kwh)9557.99294 (kcal/l ) N.A N.A N.A (Rs/kwh)N.A (kcal/kg) N.A N.A N.A (Rs/kwh)N.A (kcal/kg) 5.94 15.13 - (Rs/kwh)

N.A N.A N.A




Unit Price

Muzaffargarh- GENCO 3

Others






1) Fixed Costs

unit Hydro Gas Diesel RFO/HSFO Coal OthersDiscount Rate %Life Time year 20Salvage Value %Capital Cost Rs/kW 13057.48148 13057.48148Construction year 1994Fixed O&M Rs/kW/mo. 91.8999 91.8999Variable O&M Rs/MWh 0.025 0.025Tax & Others $/MWhFuel Use (%) 2 98

2) Fuel Costs


N.A N.A N.A




Unit Price

RFO/HSFOOthers



GasDieselCoal




1) Fixed Costs


2) Fuel Costs


N.A N.A N.A




Unit Price

RFO/HSFOOthers



GasDieselCoal




1) Fixed Costs


2) Fuel Costs


N.A N.A N.A




Unit Price

RFO/HSFOOthers



GasDieselCoal




1) Fixed Costs


2) Fuel Costs


N.A N.A N.A




Unit Price

RFO/HSFOOthers



GasDieselCoal




1) Fixed Costs


2) Fuel Costs


N.A N.A N.A




Unit Price

RFO/HSFOOthers



GasDieselCoal

Questionnairefor


in Pakistan


SPS Faisalabad Thermal Power Plant




Power Plant Name Installed Capacity Derated Capacity Fuel Heat Value (Gas) Fuel Cost (Gas)SPS Faisalabad 132 (MW) 63 (MW) 8116.0 (kcal/m3) 172.417 ($/103Nm3)

Construction Cost Generation Cost Fuel Heat Value (Diesel) Fuel Cost (Diesel)463.4 (106Rs) *8.4735 (Rs/kWh) N.A (kcal/ltr ) N.A ($/kl )


Fuel Heat Value(Oil-HSFO, RFO) Fuel Cost (FO)10095.8 (kcal/kg) 733.86 ($/103kg)


(MW) (MW) ST, GT, CC. **(%) **% **(MW) (%) (%) (%) **(Hours/start) (Hours) (Hours)1 66 27 ST Gas/FO 5.79 20 32.06 348.92 66 36 ST Gas/FO 28 32.06 105.853456789

10


Y or N Y or N Y or N yy/mm (%) (106$) F. O. R : Forced Outage Rate1 Y N N 1976/06 S. O : Scheduled Outage2 Y N N 1976/11 Min. Output : Minimum Output3 M. S. S : Monthly Start & Stop4 W. E. S : Weekend Start & Stop5 D. S. S. : Daily Start & Stop6 C. O : Commercial Operation7 A. F. C : Automatic Frequency Control89

10


Minimum Output (MW) 0 0 0 0 0 0 0 0 0 0 0 0Average Monthly Load (MW) 0 0 0 0 0 0 0 0 0 0 0 0Average Monthly Gross Heat rate (BTU/kWh) 0 0 0 0 0 0 0 0 0 0 0 0Gross Monthly Generation (MWh) 0 0 0 0 0 0 0 0 0 0 0 0Auxiliary Consumption (MWh) 0 0 0 0 0 0 0 0 0 0 0 61

2012 Maximum Ouput (MW) 0 0 72 70 70 0 0 0 0 0 0 0Minimum Output (MW) 0 0 26 40 40 0 0 0 0 0 0 0Average Monthly Load (MW) 0 0 13 54 15 0 0 0 0 0 0 0Average Monthly Gross Heat rate (BTU/kWh) 0 0 13483 12803 13122 0 0 0 0 0 0 0Gross Monthly Generation (MWh) 0 0 9095 38575 11690 0 0 0 0 0 0 0Auxiliary Consumption (MWh) 103 90 1050 4381 1382 117 0 0 0 0 0 0

2011 Maximum Ouput (MW) 85 0 85 70 70 70 0 70 70 70 0 0Minimum Output (MW) 31 0 30 20 45 60 0 45 40 40 0 0Average Monthly Load (MW) - - - 22 - - 47 49 11 36 0 0Average Monthly Gross Heat rate (BTU/kWh) 11950 0 12804 13163 13250 13530 13098 13206 13848 13060 0 0Gross Monthly Generation (MWh) 38115 0 8940 14791 18342 18335 0 30283 7309 31000 0 0Auxiliary Consumption (MWh) 4285 0 1101 1922 2396 2296 117 3690 879 3972 89 91

2010 Maximum Ouput (MW) 75 70 70 70 70 70 68 70 60 60 0 45Minimum Output (MW) 23 22 33 40 0 30Average Monthly Load (MW) 55 54 53 60 66 59 16 31 54 26 0 24Average Monthly Gross Heat rate (BTU/kWh) 12508 13218 13256 13134 12941 13204 13634 13717 13849 13464 0 13637Gross Monthly Generation (MWh) 41139 35430 39040 42270 49328 41930 12503 23124 38029 19516 0 16370Auxiliary Consumption (MWh) 3361 3082 3798 4447 5545 4609 1416 2608 4295 2072 0 1712

2009 Maximum Ouput (MW) 90 80 90 87 86 83 74 75 70 70 42 75Minimum Output (MW)Average Monthly Load (MW) 45 43 63 60 70 68 61 61 62 49 28 17Average Monthly Gross Heat rate (BTU/kWh) 12496 13177 12964 12443 12058 12417 12762 12729 13069 13098 12682 12832Gross Monthly Generation (MWh) 34210 28568 48840 43189 50744 48449 44899 44557 45262 36329 19769 13605Auxiliary Consumption (MWh) 2934 2683 4388 4142 5546 4822 4877 4893 4803 3814 2070 1161

2008 Maximum Ouput (MW) 90 88 88 88 84 78 76 48 48 92 92 90Minimum Output (MW) 47 25 20 42 45 35Average Monthly Load (MW) 75 76 64 82 66 56 57 39 38 63 55 73Average Monthly Gross Heat rate (BTU/kWh) 12899 13319 13796 13246 13862 14549 14260 13742 13230 12878 12473 11363Gross Monthly Generation (MWh) 54910 52139 48438 56989 49298 41676 43080 29922 27471 46468 35689 53210Auxiliary Consumption (MWh) 5126 4819 4804 5600 3031 4590.8 4469 2436 2291 4400 3112 4510

Remarks Note: *Annual figure 2013-14 (Avg) **ALL figures are for the month of August 2014 ***(Nothern Power Generation Company Limited)




1) Fixed Costs

unit Hydro Gas Diesel RFO/HSFO Coal OthersDiscount Rate %Life Time year 38Salvage Value %Capital Cost Rs/kW 3510.76Construction year 1976Fixed O&M Rs/kW/mo. 91.90Variable O&M Rs/kWh 0.025Tax & Others $/MWhFuel Use (%) 30 70

2) Fuel Costs

2005 2010 2013 8116.0 (kcal/Nm3) 3.07 - 8.47 (Rs/kwh)N.A (kcal/l ) N.A N.A N.A (Rs/kwh)N.A (kcal/kg) N.A N.A N.A (Rs/kwh)10,096 (kcal/kg) 5.94 15.13 - (Rs/kwh)

N.A N.A N.A




Unit Price

Faisalabad- GENCO 3

Others






1) Fixed Costs

unit Hydro Gas Diesel RFO/HSFO Coal OthersDiscount Rate %Life Time year 38Salvage Value %Capital Cost Rs/kW 3510.76Construction year 1976Fixed O&M Rs/kW/mo. 91.90Variable O&M Rs/kWh 0.025Tax & Others $/MWhFuel Use (%) 30 70

2) Fuel Costs

2005 2010 2013 8116.0 (kcal/Nm3) 3.07 - 8.47 (Rs/kwh)N.A (kcal/l ) N.A N.A N.A (Rs/kwh)N.A (kcal/kg) N.A N.A N.A (Rs/kwh)10,096 (kcal/kg) 5.94 15.13 - (Rs/kwh)

N.A N.A N.A




Unit Price

RFO/HSFOOthers

Faisalabad- GENCO 3


GasDieselCoal

Questionnairefor


in Pakistan


Faisalabad Thermal Power Plant




Power Plant Name Installed Capacity Derated Capacity Fuel Heat Value (Gas) Fuel Cost (Gas)GTPS Faisalabad 244 (MW) 202 (MW) 8116.0 (kcal/m3) 172.42 ($/103Nm3)

Construction Cost Generation Cost Fuel Heat Value (Diesel) Fuel Cost (Diesel)1861 (106Rs) *7.2435 (Rs/kWh) 9558.0 (kcal/ltr ) 787.48 ($/kl )



Unit No. Unit size Unit size Type Fuel Type F.O.R S.O Min. Output Thermal Efficiency Necessary hours to startInstalled Derated at 100% load at 75% load at 50% load M.S.S W.E.S. D.S.S.

(MW) (MW) ST, GT, CC. **(%) **% **(MW) (%) (%) (%) **(Hours/start) (Hours) (Hours)1 25 18.5 GT Gas/HSD - - - 27.6 -2 25 18.5 GT Gas/HSD - - - 27.6 -3 25 18.5 GT Gas/HSD - - - 27.6 -4 25 18.5 GT Gas/HSD - 36.69 - 27.6 -5 25 22.5 GT Gas/HSD - - - 27.6 -6 25 22.5 GT Gas/HSD - - - 27.6 -7 25 22.5 GT Gas/HSD - - - 27.6 -8 25 22.5 GT Gas/HSD - - - 27.6 -9 44 38 ST CCP - - - 38.86 -

10

Unit No. M.S.S. W.E.S. D.S.S. C.O A.F.C Width Construction CostY or N Y or N Y or N yy/mm (%) (106$) F. O. R : Forced Outage Rate

1 Y N N 1975/05 S. O : Scheduled Outage2 Y N N 1975/05 Min. Output : Minimum Output3 Y N N 1975/05 M. S. S : Monthly Start & Stop4 Y N N 1975/05 W. E. S : Weekend Start & Stop5 Y N N 1975/07 D. S. S. : Daily Start & Stop6 Y N N 1975/07 C. O : Commercial Operation7 Y N N 1975/07 A. F. C : Automatic Frequency Control8 Y N N 1975/119 Y N N 1994/12

10


Minimum Output (MW) 0 0 0 0 0 0 0 0 0 0 0 0Average Monthly Load (MW) 0 0 0 0 0 0 0 0 0 0 0 0Average Monthly Gross Heat rate (BTU/kWh) 0 0 0 0 0 0 0 0 0 0 0 0Gross Monthly Generation (MWh) 0 0 0 0 0 0 0 0 0 0 0 0Auxiliary Consumption (MWh) 70.81 33.101 58.988 68.102 83.266 102.416 86.062 78.004 70.118 76.654 55.806 54.052

2012 Maximum Ouput (MW) 0 0 0 113 68 67 69 0 0 0 0 0Minimum Output (MW) 0 0 0 0 0 0 0 0 0 0 0 0Average Monthly Load (MW) 0 0 0 26 14 15 50 0 0 0 0 0Average Monthly Gross Heat rate (BTU/kWh) 0 0 0 10977 10088 11479 10610 0 0 0 0 0Gross Monthly Generation (MWh) 0 0 0 16947 10386.2 9268 35453.8 0 0 0 0 0Auxiliary Consumption (MWh) 345 376 340 1127 796.2 694 888.698 99.036 104.161 62.731 49.386 67.798

2011 Maximum Ouput (MW) 0 0 35 0 0 123 0 113 20 0 0 0Minimum Output (MW) 0 0 0 0 0 0 0 0 0 0 0 0Average Monthly Load (MW) - - - 0 - - 0 0 0 0 0 0Average Monthly Gross Heat rate (BTU/kWh) 0 0 19521 0 17488 13599 0 10182 43495 0 0 0Gross Monthly Generation (MWh) 0 0 55 0 0 8998.184 0 11171 69 0 0 0Auxiliary Consumption (MWh) 464.824 55 91.306 69.532 235.178 512.568 379.004 1481.004 353.998 483.002 305.998 345.9988

2010 Maximum Ouput (MW) 97 67 125 176 193 198 210 174 146 80 0 0Minimum Output (MW) 0 0 0 0 0 0Average Monthly Load (MW) 65 33 30 132 111 108 118 107 34 12 0 0Average Monthly Gross Heat rate (BTU/kWh) 9897 10182 10616 11059 10638 12131 12872 10914 10554 24644 0 0Gross Monthly Generation (MWh) 44568 19220.2 19234.8 85644.6 68441 66191 77296 69903.2 23383.2 9494.6 0 0Auxiliary Consumption (MWh) 2111 1082.253 1119.8 3012.6 2561 2614 2865 2587.2 1414.2 600.6 326 328

2009 Maximum Ouput (MW) 167 133 195 209 208 206 159 154 173 82 87Minimum Output (MW)Average Monthly Load (MW) 98 51 52 104 164 129 113 93 47 22 0 21Average Monthly Gross Heat rate (BTU/kWh) 9276 9781 10846 10708 10820 12231 10487 11075 11290 9997 0 10182Gross Monthly Generation (MWh) 64208 29469.6 34319.8 56001.6 92538 67463 66388 54329.2 22529.4 17118.6 14683.8Auxiliary Consumption (MWh) 2309 1434.6 1572.8 2359.6 3392 2474 2751 2446.2 1417.4 1202.6 351 1010.8

2008 Maximum Ouput (MW) 0 25 25 0 0 0 0 22 22 28 25 0Minimum Output (MW) 0 10 10 0 0 0 0 - - - - 0Average Monthly Load (MW) 40 12 95 47 75 60 40 40 42 62 18 22Average Monthly Gross Heat rate (BTU/kWh) 11834 10962 11091 9950 9896 13353 11984 12093 9941 10227 8561 10537Gross Monthly Generation (MWh) 33591.4 10543 56112.8 26855.8 46328 22875.8 17948.8 16190.4 18969.4 40305.6 11770.8 16605.6Auxiliary Consumption (MWh) 6252.4 1460.8 2824.4 1599.8 2180 1133.8 1104.8 1032.4 1212.4 1780.6 798.8 1132.6





1) Fixed Costs

unit Hydro Gas Diesel RFO/HSFO Coal OthersDiscount Rate %Life Time year 39Salvage Value %Capital Cost Rs/kW 7627.09Construction year 1975Fixed O&M Rs/kW/mo. 91.90Variable O&M Rs/kWh 0.025 Tax & Others $/MWhFuel Use (%) 90 10

2) Fuel Costs

2005 2010 2013 8116.0 (kcal/Nm3) 2.43 4.73 7.24 (Rs/kwh)9558.0 (kcal/l ) N.A N.A N.A (Rs/kwh)N.A (kcal/kg) N.A N.A N.A (Rs/kwh)N.A (kcal/kg) N.A N.A N.A (Rs/kwh)

N.A N.A N.A




Unit Price

Faisalabad- GENCO 3

Others






1) Fixed Costs


2) Fuel Costs


N.A N.A N.A




Unit Price

RFO/HSFOOthers

Faisalabad- GENCO 3


GasDieselCoal




1) Fixed Costs


2) Fuel Costs


N.A N.A N.A




Unit Price

RFO/HSFOOthers

Faisalabad- GENCO 3


GasDieselCoal




1) Fixed Costs


2) Fuel Costs


N.A N.A N.A




Unit Price

RFO/HSFOOthers

Faisalabad- GENCO 3


GasDieselCoal




1) Fixed Costs


2) Fuel Costs


N.A N.A N.A




Unit Price

RFO/HSFOOthers

Faisalabad- GENCO 3


GasDieselCoal




1) Fixed Costs


2) Fuel Costs


N.A N.A N.A




Unit Price

RFO/HSFOOthers

Faisalabad- GENCO 3


GasDieselCoal




1) Fixed Costs


2) Fuel Costs


N.A N.A N.A




Unit Price

RFO/HSFOOthers

Faisalabad- GENCO 3


GasDieselCoal




1) Fixed Costs


2) Fuel Costs


N.A N.A N.A




Unit Price

RFO/HSFOOthers

Faisalabad- GENCO 3


GasDieselCoal




1) Fixed Costs


2) Fuel Costs


N.A N.A N.A




Unit Price

RFO/HSFOOthers

Faisalabad- GENCO 3


GasDieselCoal

Questionnairefor


in Pakistan


Lakhra Thermal Power Plant




Power Plant Name Installed Capacity Derated Capacity Fuel Heat Value (Gas) Fuel Cost (Gas)Lakhra 150 (MW) 93.6 (MW) N.A (kcal/m3) N.A ($/103Nm3)

Construction Cost Generation Cost Fuel Heat Value (Diesel) Fuel Cost (Diesel)5591.81 (Rs 106 ) *3.7864 (¢/kWh) N.A (kcal/ltr ) N.A ($/kl )

Owner Fuel Heat Value (Coal) Fuel Cost (Coal)***LPGCL 3407 (kcal/kg) 39.62 ($/103kg)



(MW) (MW) ST, GT, CC. **(%) **% **(MW) (%) (%) (%) **(Hours/start) (Hours) (Hours)1 50 31.2 ST Coal 60.46 - 5 27.232 50 31.2 ST Coal 100 - - -3 50 31.2 ST Coal 100 - - -456789

10


1 Y N N 1995/06 S. O : Scheduled Outage2 Y N N 1995/06 Min. Output : Minimum Output3 Y N N 1996/01 M. S. S : Monthly Start & Stop4 W. E. S : Weekend Start & Stop5 D. S. S. : Daily Start & Stop6 C. O : Commercial Operation7 A. F. C : Automatic Frequency Control89

10


Minimum Output (MW) 0 0 0 5 5 0 4 22 6 4 5 0Average Monthly Load (MW)Average Monthly Gross Heat rate (BTU/kWh) 0 0 0 15649 12973 14772 13046 12532 14752 13368 13456 14579Gross Monthly Generation (MWh) 0 0 0 7697 853 10100 15385 17905 9294 18806 8971 0Auxiliary Consumption (MWh) 217.404 165 179.664 1237 784 2147.448 4527 4657 3086 5027 2832 382

2012 Maximum Ouput (MW) 0 32 26 31 30 32 37 37 37 34 40 32Minimum Output (MW) 0 7 5 20 3 7 5 0 3 5 5 5Average Monthly Load (MW)Average Monthly Gross Heat rate (BTU/kWh) 0 14696 14603 14799 15117 14832 14032 16604 16638 16394 13946 16697Gross Monthly Generation (MWh) 0 17120 1840 4482 5188 15260 14894 9907 12795 9682 9336 4168Auxiliary Consumption (MWh) 408.96 4201 1304 1648 2472.564 4039.692 3931.248 1061.676 3646.998 3288 548.74 745.5

2011 Maximum Ouput (MW) 32 35 36 35 36 32 31 32 32 32 31 31Minimum Output (MW) 7 7 4 5 5 0 5 20 5 5 5 6Average Monthly Load (MW)Average Monthly Gross Heat rate (BTU/kWh) 14792 14686 14821 14580 12973 14772 13992 14076 14752 14741 14825 14579Gross Monthly Generation (MWh) 6281 7086 19260 9290 10321 13404 13798 17082 1629 3814 8217 7535Auxiliary Consumption (MWh) 1857 1907 4328 2407 3036 3632 3842 4384 1514 1701 2588 2326

2010 Maximum Ouput (MW) 34 32 33 31 31 32 33 30 0 0 0 0Minimum Output (MW) - - - - - - 12 0 0 0 0 0Average Monthly Load (MW)Average Monthly Gross Heat rate (BTU/kWh) 14424 14578 14703 15436 14872 14771 16696 16604 16638 0 0 0Gross Monthly Generation (MWh) 7097 4049 12754 13360 11242 15312 22586 43 0 0 0 0Auxiliary Consumption (MWh) 1800 1355 3134 2957 3049 3967 5314 448 0 0 0 0

2009 Maximum Ouput (MW) 35 36 0 0 32 35 38 35 33 35 35 0Minimum Output (MW) - - 0 0 - - - - - - - 0Average Monthly Load (MW)Average Monthly Gross Heat rate (BTU/kWh) 15759 0 0 0 14477 13448 13745 14834 15187 13499 13692 0Gross Monthly Generation (MWh) 3936 11868 0 0 7853 9714 14122 12867 9421 12046 4109 0Auxiliary Consumption (MWh) 1247 2469 416 497 2198 2594 3657 3582 2894 2954 1293 240

2008 Maximum Ouput (MW) 38 38 36 38 35 34 35 35 37 37 36 42Minimum Output (MW) 10 10 6 10 8 4 - - - - - -Average Monthly Load (MW)Average Monthly Gross Heat rate (BTU/kWh) 16776 16666 16109 15215 12973 14772 14898 15265 12910 14200 14491 15463Gross Monthly Generation (MWh) 13637 6038 7393 7697 10896 9340 11062 12903 24396 13195 6498 11769Auxiliary Consumption (MWh) 2719 1551 1891 2196 3193 2903 3191 3571 5433 3161 1902 2686

RemarksNote: *Annual figure 2013-14 (Avg) **ALL figures are for the month of August 2014 ***(Lakhra Power Generation Company Limited) Only One Unit Of Lakhra Operates at at time




1) Fixed Costs

unit Hydro Gas Diesel RFO/HSFO Coal OthersDiscount Rate %Life Time year 19Salvage Value %Capital Cost Rs/kW 37278.73Construction year 1995Fixed O&M Rs/kW/mo. 4.3544Variable O&M Rs/kWh 0.1271Tax & Others $/MWhFuel Use (%) 100

2) Fuel Costs

2005 2010 2013 N.A (kcal/Nm3) N.A N.A N.A (Rs/kwh)N.A (kcal/l ) N.A N.A N.A (Rs/kwh)3406.959153 (kcal/kg) 1.33 2.78 3.74 (Rs/kwh)N.A (kcal/kg) N.A N.A N.A (Rs/kwh)

N.A N.A N.A




Unit Price

Lakhra- GENCO 4

Others

Heat value (HHV)Type





1) Fixed Costs


2) Fuel Costs


N.A N.A N.A




Unit Price

RFO/HSFOOthers

Lakhra- GENCO 4

Type Heat value (HHV)

GasDieselCoal




1) Fixed Costs


2) Fuel Costs


N.A N.A N.A




Unit Price

RFO/HSFOOthers

Lakhra- GENCO 4

Type Heat value (HHV)

GasDieselCoal

Questionnairefor


in Pakistan

<< DATA SHEETS >>

Quetta Thermal Power Plant



Thermal Power Plant Questionnaire (All power plant : excluding SPP) Thermal No. GENCO

Power Plant Name Installed Capacity Derated Capacity Fuel Heat Value (Gas) Fuel Cost (Gas)Quetta 35 (MW) 25 (MW) 8652 (kcal/m3) 17241.68 ($/103Nm3)

Construction Cost Generation Cost Fuel Heat Value (Diesel) Fuel Cost (Diesel)418 (106Rs) *10.6897 (¢/kWh) N.A (kcal/ltr ) N.A ($/kl )

Owner Fuel Heat Value (Coal) Fuel Cost (Coal)***CPGCL N.A (kcal/kg) N.A ($/103kg)



(MW) (MW) ST, GT, CC. **(%) **% **(MW) (%) (%) (%) **(Hours/start) (Hours) (Hours)1 35 25 GT Gas 5.51 10 27.8323456789

10


1 Y N N 1984/11 S. O : Scheduled Outage2 Min. Output : Minimum Output3 M. S. S : Monthly Start & Stop4 W. E. S : Weekend Start & Stop5 D. S. S. : Daily Start & Stop6 C. O : Commercial Operation7 A. F. C : Automatic Frequency Control89

10


Minimum Output (MW) 0 10 10 10 10 10 10 10 10 10 0 0Average Monthly Load (MW) 0 0 13 13 13 24 25 25 22 23 0 0Average Monthly Heat rate (BTU/kWh) 0 15234 14324 15916 17024 16879 17348 17246 17045 17597 0 0Gross Monthly Generation (MWh) 0 6097.3 5512.7 6960.9 6271.9 12746.5 14234.5 15075.5 12479.8 11550.3 0 0Auxiliary Consumption (MWh) 55.145 131.8 133.7 162.9 167.9 312.5 351.5 372.5 310.8 272.3 31 51

2012 Maximum Ouput (MW) 0 0 26 26 26 26 25 25 25 25 25 0Minimum Output (MW) 0 0 10 10 10 10 10 10 10 10 10 0Average Monthly Load (MW) 0 0 3 26 26 25 24 25 25 25 10 0Average Monthly Heat rate (BTU/kWh) 0 0 18312 16709 17162 16360 17701 17833 14991 14607 15220 0Gross Monthly Generation (MWh) 0 0 1762 15571 15037.9 15426.6 14501.8 14817.2 16096.8 11993.8 10965.9 0Auxiliary Consumption (MWh) 65 39 35 339 325.9 340.6 327.8 354.2 338.3 379 230.9 50.347

2011 Maximum Ouput (MW) 0 0 25 25 25 25 25 25 25 25 25 0Minimum Output (MW) 0 0 0 15 15 15 10 10 10 15 15 0Average Monthly Load (MW) - - - 10 - - 24 25 25 15 8 0Average Monthly Heat rate (BTU/kWh) 0 15234 14324 17383 15915 15690 16074 16067 15715 15298 15706 0Gross Monthly Generation (MWh) 0 0 5512.7 6938 14836 15048 13994 15162 15696 10722 4768.3 0Auxiliary Consumption (MWh) 55.11 44.15 44.465 76.742 114.348 127 299 316 322 214 100.3 53.08

2010 Maximum Ouput (MW) 0 0 25 25 25 25 25 25 25 25 0 0Minimum Output (MW) 0 0 - - - - 25 25 10 10 0 0Average Monthly Load (MW) 0 0 5 25 25 25 25 24 25 16 0Average Monthly Heat rate (BTU/kWh) 0 0 16773 15464 15449 15789 15769 15769 15769 17711 0 0Gross Monthly Generation (MWh) 0 0 2728.1 16274 16500 15965 16515.5 16000 15826.5 10746.5 0 0Auxiliary Consumption (MWh) 54 50 54 336 346 339 353.5 338 331.5 215.5 36.73 53.385

2009 Maximum Ouput (MW) 0 0 25 25 25 25 25 25 25 25 25 0Minimum Output (MW) 0 0 - - - - - - - - - 0Average Monthly Load (MW) 0 0 24 25 23 25 24 23 25 25 8 0Average Monthly Heat rate (BTU/kWh) 0 0 15411 15304 15542 15631 16243 16065 15675 15473 15060 0Gross Monthly Generation (MWh) 0 0 16587.8 15935.1 15400.5 15847.2 14907.6 14728.7 15668.5 16787 5996.9 0Auxiliary Consumption (MWh) 57 47 356.3 618 289 382.533 56 322 340 358 120.9 54.635

2008 Maximum Ouput (MW) 0 25 25 0 0 0 0 22 22 28 25 0Minimum Output (MW) 0 10 10 0 0 0 0 - - - - 0Average Monthly Load (MW) 0 10 9 0 0 0 0 6 7 2 4 0Average Monthly Heat rate (BTU/kWh) 0 15234 14324 0 0 0 0 17953 15274 19796 18084 0Gross Monthly Generation (MWh) 0 6097.3 5512.7 0 0 0 0 3785.9 4511 1632.7 2786.9 0Auxiliary Consumption (MWh) 55.145 131.8 108.7 6.417 5.912 6.548 7 80 99 48 45 50





1) Fixed Costs

unit Hydro Gas Diesel RFO/HSFO Coal OthersDiscount Rate %Life Time year 30Salvage Value %Capital Cost Rs/kW 11942.86Construction year 1984Fixed O&M Rs/kW/mo. 126.5959Variable O&M Rs/MWh 68.90 Tax & Others $/MWh 17%Fuel Use (%) 100

2) Fuel Costs





Unit Price

Quetta

Others



Questionnairefor


in Pakistan

<< DATA SHEETS >>

Existing Thermal/Biomass

KAPCO Kot Addu Power Station



Thermal Power Plant Questionnaire (All power plant : excluding SPP) Thermal No.

Power Plant Name Installed Capacity Derated Capacity1600 (MW) 1345 (MW) 915 BTUl/ft3) 4.78 ($/MMBTU)

Construction Cost Generation Cost(106$) (¢/kWh) 19000 (BTU/lb) 0.8506 ($/Litr)

(kcal/kg) ($/103kg)

18200 (BTU/lb) 556.05 ($/M ton)

(kcal/kg) ($/103kg)

Unit No. Unit size Unit size Type Fuel Type F.O.R PPA Allowed S.O Min. Output Necessary hours to startInstalled* Derated** at 100% load at 75% load at 50% load Cold Start Warm Start Hot Start

(MW) (MW) ST, GT, CC. GWh 2013-14 (days/year) (MW) (%) (%) (%) (Min) (Min) (Min)1 110 97 GT LSFO 8.6 36 Base load 28.6 NA NA 4 4 42 110 91 GT LSFO 22.3 36 Base load 28.8 NA NA 4 4 43 96 80 GT GAS/HSD 11.1 36 Base load 25.1 NA NA 28 28 284 96 78 GT GAS/HSD 8.2 36 Base load 24.5 NA NA 28 28 285 95 79 GT LSFO 183.4 36 Base load 29.2 NA NA 10 10 106 95 80 GT LSFO 19.1 36 Base load 29.3 NA NA 10 10 107 95 77 GT LSFO 18.4 36 Base load 29.4 NA NA 10 10 108 95 77 GT LSFO 17.6 36 Base load 28.5 NA NA 10 10 109 112 98 ST CC 12.8 36 Base load STG NA NA 224 114 54

10 112 98 ST CC 19.1 36 Base load STG NA NA 224 114 5411 103 80 ST CC 108.2 36 Base load STG NA NA 260 180 9012 103 78 ST CC 21.8 36 Base load STG NA NA 260 180 9013 123 112 GT LSFO 92.4 36 Base load 31.3 NA NA 3.3 3.3 3.314 123 108 GT LSFO 40.0 36 Base load 31.1 NA NA 3.3 3.3 3.315 149 112 ST CC 74.0 36 Base load STG NA NA 210 120 103

Unit No. M.S.S. D.S.S. C.O A.F.C Width Construction Cost

Y or N Y or N yy/mm (%) (106$) F. O. R : Forced Outage Rate1 Y S. O : Scheduled Outage2 Y Min. Output : Minimum Output3 M. S. S : Monthly Start & Stop4 W. E. S : Weekend Start & Stop5 Y D. S. S. : Daily Start & Stop6 Y C. O : Commercial Operation7 Y A. F. C : Automatic Frequency Control8 Y9

10111213 Y14 Y15


Minimum Output (MW) 0 0 295 440 361 223 625 327 299 281 121 424Average Monthly Load (MW) 617 572 568 754 651 637 870 866 636 671 475 862Average Monthly Net Heat rate (Kj/kWh 8057 8042 8180 8191 8243 8303 8449 8326 8264 8258 8383 8259Gross Monthly Generation (MWh) 453 381 418 542 476 452 639 640 457 501 337 632Auxiliary Consumption (MWh) 11 9 11 13 14 15 19 19 14 14 10 15

2012 Maximum Ouput (MW) 1049 980 944 1321 1386 1251 1238 1087 1006 918 622 1228Minimum Output (MW) 167 167 183 641 588 282 630 700 647 155 0 169Average Monthly Load (MW) 559 556 630 998 1056 747 1026 898 656 744 264 524Average Monthly Net Heat rate (Kj/kWh 8064 8038 8177 8177 8177 8177 8363 8251 8201 8094 7866 7996Gross Monthly Generation (MWh) 424 381 460 708 780 526 757 661 487 490 182 378Auxiliary Consumption (MWh) 11 10 13 17 21 16 21 18 14 13 7 10



2009 Maximum Ouput (MW) 1475 1198 1191 1373 1379 1309 1334 1342 1127 1062 1173 1523Minimum Output (MW) 339 180 581 262 324 276 469 247 513 172 180 337Average Monthly Load (MW) 932 642 939 966 1072 832 961 1070 817 755 721 1022Average Monthly Net Heat rate (Kj/kWh 8358 8270 8239 8303 8333 8356 8427 8425 8368 8364 8266 8286Gross Monthly Generation (GWh) 701 430 695 687 795 595 707 796 586 564 521 790Auxiliary Consumption (GWh) 17 11 17 18 22 18 21 22 17 16 14 19

2008 Maximum Ouput (MW) 1575 1266 1389 1396 1394 1350 1354 1352 1436 1409 1030 972Minimum Output (MW) 305 80 345 708 171 274 567 292 243 460 86 87Average Monthly Load (MW) 989 744 1104 1046 1100 1045 1082 753 1050 1018 684 666Average Monthly Net Heat rate (Kj/kWh 8270 8254 8283 8335 8342 8350 8346 8296 8371 8417 8258 8182Gross Monthly Generation (GWh) 732 538 814 753 813 750 804 557 748 753 499 495Auxiliary Consumption (GWh) 22 17 25 24 25 24 24 18 22 21 13 13

RemarksNote: *at ISO conditions **at reference at site conditions

Fuel Cost (Gas)

Fuel Cost (Diesel)

Fuel Cost (Coal)

Fuel Cost (FO)

Fuel Cost (Biomass)

Fuel Heat Value (Gas)

Fuel Heat Value (Diesel)

Fuel Heat Value (Coal)

Fuel Heat Value(Oil-LSFO)

Fuel Heat Value(Biomass)

S.S aft 250 hourson LSFO

KAPCO CCPP

Kot Addu Power Company Ltd. (KAPCO), Kot Addu, PakisOwner

Thermal Efficiency



Power Plant Name Unit No. Reporting Year2014

1) Fixed Costs

unit Hydro Gas Diesel RFO/HSFO Coal Others/BiomassDiscount Rate %Life Time yearSalvage Value %Capital Cost $/kWConstruction yearFixed O&M $/kW/mo.Variable O&M $/MWh Tax & Others $/MWhFuel Use (%)

2) Fuel Costs

2004-05 2009-2010 2013-14 915 (BTU/ft3) 637.0 1060 1915.0 (Rs/Hm3)19000 (BTU/lb) 20 58 94.65 (Rs/Litre)18200 (BTU/lb) 14239 43133 71860 (Rs/Ton)




Unit Price

KAPCO

Others/Biomass


GasDieselLSFO

Questionnairefor


in Pakistan

<< DATA SHEETS >>IPP

HUBCO Hub Power Station




Power Plant Name Installed Capacity Derated Capacity Fuel Heat Value (Gas) Fuel Cost (Gas)HUBCO 1292 (MW) 1200 (MW) (kcal/m3) ($/103Nm3)

Construction Cost Generation Cost Fuel Heat Value (Diesel) Fuel Cost (Diesel)(106$) * (Rs/kWh) (kcal/ltr ) ($/kl )

Owner Fuel Heat Value (Coal) Fuel Cost (Coal)***HUBCO (kcal/kg) ($/103kg)

Fuel Heat Value(Oil-HSFO, RFO) Fuel Cost (FO)9616 (kcal/kg) 713.53 ($/103kg)


(MW) (MW) ST, GT, CC. **(%) **% **(MW) (%) (%) (%) **(Hours/start) (Hours) (Hours)1 323 300 ST RFO 9 45 64.6 38.131 N.A N.A 06 h 50 m 05 h 30 m 01 h 40 m2 323 300 ST RFO 9 45 64.6 38.131 N.A N.A 06 h 50 m 05 h 30 m 01 h 40 m3 323 300 ST RFO 9 45 64.6 38.131 N.A N.A 06 h 50 m 05 h 30 m 01 h 40 m4 323 300 ST RFO 9 45 64.6 38.131 N.A N.A 06 h 50 m 05 h 30 m 01 h 40 m5 (Base Load6 Plant)789

10


Y or N Y or N Y or N yy/mm (%) (106$) F. O. R : Forced Outage Rate1 N.A Y Y 1996/07 48.5-51 S. O : Scheduled Outage2 N.A Y Y 1996/09 48.5-51 Min. Output : Minimum Output3 N.A Y Y 1996/11 48.5-51 M. S. S : Monthly Start & Stop4 N.A Y Y 1997/03 48.5-51 W. E. S : Weekend Start & Stop5 D. S. S. : Daily Start & Stop6 C. O : Commercial Operation7 A. F. C : Automatic Frequency Control89

10

Actual records of operation Jan. Feb. Mar. Apr. May June July Aug. Sept. Oct. Nov. Dec.2013 Maximum Ouput (MW) N.A N.A N.A N.A N.A N.A N.A N.A N.A N.A N.A N.A

Minimum Output (MW) N.A N.A N.A N.A N.A N.A N.A N.A N.A N.A N.A N.AAverage Monthly Load (MW) 1237 1221 1203 891 1185 1174 1160 1181 910 905 863 1206Average Monthly Gross Heat rate (BTU/k 8972.05 8972.05 8972.05 8972.05 8972.05 8972.05 8972.05 8972.05 8972.05 8972.05 8972.05 8972.05Gross Monthly Generation (MWh) 828413 569515 724114 532902 557691 529251 552127 553778 584962 573564 447420 599001Auxiliary Consumption (MWh) 42758 31694 40171 30837 32454 32385 32858 32959 34178 33710 27999 34870

2012 Maximum Ouput (MW) N.A N.A N.A N.A N.A N.A N.A N.A N.A N.A N.A N.AMinimum Output (MW) N.A N.A N.A N.A N.A N.A N.A N.A N.A N.A N.A N.AAverage Monthly Load (MW) 1259 945 942 1071 1219 1232 1241 1239 1230 917 1225 1231Average Monthly Gross Heat rate (BTU/k 8967.77 8967.77 8967.77 8967.77 8967.77 8967.77 8967.77 8967.77 8967.77 8967.77 8967.77 8967.77Gross Monthly Generation (MWh) 862139 585318 556023 632939 667942 784249 833512 758727 758136 537721 636286 629142Auxiliary Consumption (MWh) 45794 32141 31069 35199 37760 43425 45871 41915 32698 30353 35343 34552





RemarksNote: *Annual figure 2013-14 (Avg) **ALL figures are for the month of August 2014 ***(HUB Power Company Limited)



Power Plant Name Unit No. Reporting YearComplex 2014

1) Fixed Costs

unit Hydro Gas Diesel RFO/HSFO Coal OthersDiscount Rate % 9.5Life Time year 30Salvage Value %Capital Cost Rs/kW 150000000Construction year 1994-1997Fixed O&M Rs/kW/mo. 0.34Variable O&M Rs/MWh 177Tax & Others $/MWhFuel Use (%) 100

2) Fuel Costs

2005 2010 2013 (kcal/Nm3) (Rs/kwh)(kcal/l ) (Rs/kwh)(kcal/kg) (Rs/kwh)

9,616 (kcal/kg) (Rs/kwh)




Unit Price

HUBCO

Others



Questionnairefor


in Pakistan

<< DATA SHEETS >>IPP

Kohinoor (KEL) Thermal Power Plant



Thermal Power Plant Questionnaire (All power plant : excluding SPP) Thermal NoIPP

Power Plant Name Installed Capacity Fuel Heat Value (Gas) Fuel Cost (Gas)131.4 (MW) (kcal/m3) ($/103Nm3)

Construction Cost Generation Cost Fuel Heat Value (Diesel) Fuel Cost (Diesel)138,800.00 (106$) (c/kWh) (kcal/ltr ) ($/kl )

Owner Fuel Heat Value (Coal) Fuel Cost (Coal)IPP (kcal/kg) ($/103kg)

Fuel Heat Value(Oil-HSFO, RFO) Fuel Cost (FO)9700 (kcal/kg) 634.12 ($/103kg)

Unit No. Unit size Type Fuel Type F.O.R S.O Min. Output Thermal Efficiency Necessary hours to startInstalled at 100% load at 75% load at 50% load M.S.S W.E.S. D.S.S.

(MW) ST, GT, CC. (%) (days/year) (MW) (%) (%) (%) (Hours) (Hours) (Hours)1 15.68 DG RFO 5.708 30 5.35 42.722 15.68 DG RFO 5.708 30 5.35 42.723 15.68 DG RFO 5.708 30 5.35 42.724 15.68 DG RFO 5.708 30 5.35 42.725 15.68 DG RFO 5.708 30 5.35 42.726 15.68 DG RFO 5.708 30 5.35 42.727 15.68 DG RFO 5.708 30 5.35 42.728 15.68 DG RFO 5.708 30 5.35 42.729 6 ST Steam 5.708 30 NA

10


Y or N Y or N Y or N yy/mm (%) (106$) F. O. R : Forced Outage Rate1 Y Y Y 1997/06 NA Not available S. O : Scheduled Outage2 Y Y Y 1997/06 NA Not available Min. Output : Minimum Output3 Y Y Y 1997/06 NA Not available M. S. S : Monthly Start & Stop4 Y Y Y 1997/06 NA Not available W. E. S : Weekend Start & Stop5 Y Y Y 1997/06 NA Not available D. S. S. : Daily Start & Stop6 Y Y Y 1997/06 NA Not available C. O : Commercial Operation7 Y Y Y 1997/06 NA Not available A. F. C : Automatic Frequency Control8 Y Y Y 1997/06 NA Not available9 Y Y Y 1997/06 NA Not available

10


Minimum Output (MW) 45 45 45 45 45 45 45 45 45 45 45 45Gross Monthly Generation (MWh) 62182.98 48554.684 56692.19 61466.991 69621.866 73654.526 77624.405 81166.427 67015.169 70999.033 66487.844 74270.7Auxiliary Consumption (MWh) 1634.98 1321.684 1617.188 1823.991 2161.866 2321.526 2506.405 2588.427 2072.169 2022.033 1851.844 2030.705

2012 Maximum Ouput (MW) 124 124 124 124 124 124 124 124 124 124 124 124Minimum Output (MW) 45 45 45 45 45 45 45 45 45 45 45 45Gross Monthly Generation (MWh) 44323.949 46197.415 79892.97 72845.107 64679.459 62643.131 75682.612 79342.148 48528.363 63090.32 46928.137 61115.315Auxiliary Consumption (MWh) 1256.949 1286.415 2138.973 2163.107 1977.459 1986.131 2369.612 2440.148 1651.363 1900.32 1327.137 1638.315

2011 Maximum Ouput (MW) 124 124 124 124 124 124 124 124 124 124 124 124Minimum Output (MW) 45 45 45 45 45 45 45 45 45 45 45 45Gross Monthly Generation (MWh) 86055.588 70090.16 82482.09 71016.657 71690.989 77925.278 67314.596 80536.925 72930.884 69574.591 44298.959 44327.492Auxiliary Consumption (MWh) 2252.588 1928.716 2319.089 2140.657 2421.989 2580.278 22.96.596 2570.925 2335.884 2101.591 1302.959 1276.492




Remarks

Kohinoor Electric Limited




1) Fixed Costs

unit Hydro Gas Diesel RFO/HSFO Coal OthersDiscount Rate % - - - 10 - -Life Time year - - - 30 - -Salvage Value % - - - 10 - -Capital Cost $/kW - - - 1119 - -Construction year - - - 1997 - -Fixed O&M $/kW/mo. - - - Not available - -Variable O&M $/MWh - - - 5.6685 - -Tax & Others $/MWh - - - Not available - -Fuel Use (%) - - - Not available - -

2) Fuel Costs

2005 2010 2013 - (kcal/Nm3) - - - ($/103Nm3)- (kcal/l ) - - - ($/kl )- (kcal/kg) - - - ($/103kg)9,700 (kcal/kg) 244 515 735 ($/103kg)




Unit Price

KEL - IPP

Others






1) Fixed Costs


2) Fuel Costs





Unit Price

RFO/HSFOOthers

KEL - IPP


GasDieselCoal




1) Fixed Costs


2) Fuel Costs





Unit Price

RFO/HSFOOthers

KEL - IPP


GasDieselCoal




1) Fixed Costs


2) Fuel Costs





Unit Price

RFO/HSFOOthers

KEL - IPP


GasDieselCoal




1) Fixed Costs


2) Fuel Costs





Unit Price

RFO/HSFOOthers

KEL - IPP


GasDieselCoal




1) Fixed Costs


2) Fuel Costs





Unit Price

RFO/HSFOOthers

KEL - IPP


GasDieselCoal




1) Fixed Costs


2) Fuel Costs





Unit Price

RFO/HSFOOthers

KEL - IPP


GasDieselCoal




1) Fixed Costs


2) Fuel Costs





Unit Price

RFO/HSFOOthers

KEL - IPP


GasDieselCoal




ST1) Fixed Costs


2) Fuel Costs





Unit Price

RFO/HSFOOthers

KEL - IPP


GasDieselCoal

Questionnairefor


in Pakistan

<< DATA SHEETS >>

AEL Lalpir Power stationExisting Thermal/Biomass



Thermal Power Plant Questionnaire (All power plant : excluding SPP) Year-2013 Thermal No.

Power Plant Name Installed Capacity Derated CapacityLalPir Power Limite 362 (MW) 350 (MW) (kcal/m3) ($/103Nm3)

Construction Cost Generation Cost(106$) (¢/kWh) (kcal/ltr ) ($/kl )

OwnerAES (kcal/kg) ($/103kg)

9636 (kcal/kg) 17.4 Rs/kWh

(kcal/kg) ($/103kg)

Unit No. Unit size Unit size Type Fuel Type F.O.R S.O Min. Output Thermal Efficiency Necessary hours to startDearetd at 100% load at 75% load at 50% load M.S.S W.E.S. D.S.S.

(MW) (MW) ST, GT, CC. (%) (days/year) (MW) (%) (%) (%) (Hours) (Hours) (Hours)1 362 350 ST HSFO 30 days/year 70 36.6%2 (Major Overhauling is conducted after every 4 years. Last Major Overhauling for LalPir was carried out in 2014.)3 456789

10


Y or N Y or N Y or N yy/mm (%) (106$) F. O. R : Forced Outage Rate1 Y N N 1997 No S. O : Scheduled Outage2 Min. Output : Minimum Output3 M. S. S : Monthly Start & Stop4 W. E. S : Weekend Start & Stop5 D. S. S. : Daily Start & Stop6 C. O : Commercial Operation7 A. F. C : Automatic Frequency Control89

10


Minimum Output (MW) 70 70 70 70 70 70 70 70 70 70 70 70Average Monthly Load (MW) 53% 61% 50% 41% 65% 86% 76% 76% 35% 65% 69% 75%Average Monthly Gross Heat rate (BTU 9152.36 9372.65 9387.90 9109.90 9116.23 9376.40 9504.13 9562.74 9470.21 9119.76 9444.53 9258.06Net Monthly Generation (kWh) 1.37E+08 1.44E+08 1.3E+08 1.04E+08 1.7E+08 2.17E+08 1.99E+08 1.99E+08 87730300 1.69E+08 1.74E+08 1.96E+08Auxiliary Consumption (MWh)

2012 Maximum Ouput (MW) 350 350 350 350 350 350 350 350 350 350 350 350Minimum Output (MW) 70 70 70 70 70 70 70 70 70 70 70 70Average Monthly Load (MW) 54% 47% 66% 51% 80% 71% 76% 70% 49% 28% 0 64%Average Monthly Gross Heat rate (BTU 9004.19 9101.94 9079.68 9118.20 9102.13 9305.93 9350.07 9320.39 9423.18 9408.53 9155.84Gross Monthly Generation (kWh) 1.41E+08 1.13E+08 1.72E+08 1.3E+08 2.09E+08 1.8E+08 1.97E+08 1.82E+08 1.23E+08 73019000 0 1.67E+08Auxiliary Consumption (MWh)

2011 Maximum Ouput (MW) 350 350 350 350 350 350 350 350 350 350 350 350Minimum Output (MW) 70 70 70 70 70 70 70 70 70 70 70 70Average Monthly Load (MW) 80% 66% 32% 74% 44% 70% 71% 60% 58% 81% 16% 40%Average Monthly Gross Heat rate (BTU 8876.23 9066.57 9067.94 9064.94 9389.59 9192.84 9338.65 9423.64 9385.00 9281.35 9525.24 9040.00Gross Monthly Generation (kWh) 2.08E+08 1.56E+08 83426000 1.87E+08 1.13E+08 1.78E+08 1.85E+08 1.57E+08 1.45E+08 2.11E+08 40544000 1.04E+08Auxiliary Consumption (MWh)

2010 Maximum Ouput (MW)Minimum Output (MW)Average Monthly Load (MW)Average Monthly Gross Heat rate (BTU/kWh)Gross Monthly Generation (kWh)Auxiliary Consumption (MWh)



Remarks

Fuel Cost (Gas)

Fuel Cost (Diesel)

Fuel Cost (Coal)

Fuel Cost (FO)

Fuel Cost (Biomass)

Fuel Heat Value (Gas)

Fuel Heat Value (Diesel)

Fuel Heat Value (Coal)

Fuel Heat Value(Oil-HSFO, RFO)

Fuel Heat Value(Biomass)




1) Fixed Costs

unit Hydro Gas Diesel RFO/HSFO Coal Others/BiomassDiscount Rate %Life Time yearSalvage Value %Capital Cost $/kWConstruction yearFixed O&M $/kW/mo.Variable O&M $/MWh Tax & Others $/MWhFuel Use (%)

2) Fuel Costs

2005 2010 2013 (kcal/Nm3) ($/103Nm3)(kcal/l ) ($/kl )(kcal/kg) ($/103kg)(kcal/kg) ($/103kg)




Unit Price

Others/Biomass



Questionnairefor


in Pakistan

<< DATA SHEETS >>Foundation Power





Power Plant Name Installed Capacity Derated Capacity Fuel Heat Value (Gas) Fuel Cost (Gas)Foundation Power C 180 (MW) (MW) 4986 (kcal/m3) 74.5 ($/103Nm3)

Construction Cost Generation Cost Fuel Heat Value (Diesel) Fuel Cost (Diesel)212 (106$) 7.2 (¢/kWh) (kcal/ltr ) ($/kl )

Owner Fuel Heat Value (Coal) Fuel Cost (Coal)Foundation Power Company Daharki Limited (kcal/kg) ($/103kg)

Fuel Heat Value(Oil-HSFO, RFO) Fuel Cost (FO)(kcal/kg) ($/103kg)

Fuel Heat Value(Biomass) Fuel Cost (Biomass)(kcal/kg) ($/103kg)

Unit No. Unit size Unit size Type Fuel Type F.O.R S.O Min. Output Thermal Efficiency Necessary hours to startDerated at 100% load at 75% load at 50% load M.S.S W.E.S. D.S.S.

(MW) (MW) ST, GT, CC. (%) (days/year) (MW) (%) (%) (%) (Hours) (Hours) (Hours)1 180 CC Gas 4 22 Days/yea 72 48.84 45.43 38.91 N.A N.A N.A2 (Startup and Shudown on HSD)3 60 Days in MI year4 note5 114.9 GT Source ;JST addid from Nepra licence6 64.15 ST7 6.057 Aux 89

10


Y or N Y or N Y or N yy/mm (%) (106$) F. O. R : Forced Outage Rate1 N N N 2011/05 4 212.068 S. O : Scheduled Outage2 Min. Output : Minimum Output3 M. S. S : Monthly Start & Stop4 W. E. S : Weekend Start & Stop5 D. S. S. : Daily Start & Stop6 C. O : Commercial Operation7 A. F. C : Automatic Frequency Control89

10


Minimum Output (MW) 130 95 130 68 150 151 158 161 164 161 169 171Average Monthly Load (MW)Average Monthly Gross Heat rate (BTU/kWh)Gross Monthly Generation (MWh) 131396 105988 130047 126664 106549 113191 126851 121698 110743 121402 59497 133652Auxiliary Consumption (MWh) 4261.18 3689.84 4398.24 4515.28 2436.28 4632.32 5000.38 4715.48 4224.22 4555.32 2471.7 4178.02

2012 Maximum Ouput (MW) 193 196 195 186 182 174 174 173 179 183 190 193Minimum Output (MW) 118 115 121 157 104 96 154 157 130 165 166 170Average Monthly Load (MW)Average Monthly Gross Heat rate (BTU/kWh)Gross Monthly Generation (MWh) 133438 107494 138869 118421 126340 105687 113682 126892 107828 129865 107824 132177Auxiliary Consumption (MWh) 3942.51 3277.56 4076.93 3911.05 4415.84 4082.65 4262.83 4473.04 3975.4 4177.03 6010.29 3975.4

2011 Maximum Ouput (MW) 175 174 174 178 181 185 185 196Minimum Output (MW) 156.6 155 96 109 122 144 150 108Average Monthly Load (MW)Average Monthly Gross Heat rate (BTU/kWh)Gross Monthly Generation (MWh) 59614 118528 122207 123501 101213 129931 124721 93515Auxiliary Consumption (MWh) 2223.65 4335.76 4460.17 4518.8 3832.4 4182.75 3896.75 3221.79

2010 Maximum Ouput (MW)Minimum Output (MW)Average Monthly Load (MW)Average Monthly Gross Heat rate (BTU/kWh)Gross Monthly Generation (MWh)Auxiliary Consumption (MWh)



RemarksPlant Commercial Operation Started from May 16, 2011.



Power Plant Name Unit No. Reporting YearCCPP 2014

1) Fixed Costs

unit Hydro Gas Diesel RFO/HSFO Coal Others/BiomassDiscount Rate % -Life Time year 25Salvage Value % -Capital Cost $/kW 1178Construction year 2011Fixed O&M $/kW/mo. 1.85Variable O&M $/MWh 51 Tax & Others $/MWh 0Fuel Use (%) 100

2) Fuel Costs

2005 2010 2013 4986 (kcal/Nm3) N.A N.A 74.5 ($/103Nm3)

(kcal/l ) ($/kl )(kcal/kg) ($/103kg)(kcal/kg) ($/103kg)




Unit Price

Foundation Power Company Dahar

Others/Biomass



Questionnairefor


in Pakistan

<< DATA SHEETS >>


HUBCO Nalowal Power station



Thermal Power Plant Questionnaire (All power plant : excluding SPP) Thermal NoNarowal Plant

Power Plant Name Installed Capacity Derated Capacity Fuel Heat Value (Gas) Fuel Cost (Gas)Hub Power Narowal 213.82 (MW) 219.158 (MW) (kcal/m3) ($/103Nm3)

Construction Cost Generation Cost Fuel Heat Value (Diesel) Fuel Cost (Diesel)(106$) (¢/kWh) (kcal/ltr ) ($/kl )

Owner Fuel Heat Value (Coal) Fuel Cost (Coal)Hub Power CO. Ltd. (kcal/kg) ($/103kg)

Fuel Heat Value(Oil-HSFO, RFO) Fuel Cost (FO)10202 (kcal/kg) RS. 71,353/Ton (/103kg)

Fuel Heat Value(Biomass) Fuel Cost (Biomass)(kcal/kg) ($/103kg)

Unit No. Unit size Unit size Type Fuel Type F.O.R S.O Min. Output Thermal Efficiency Necessary hours to startDerated at 100% load at 75% load at 50% load M.S.S W.E.S. D.S.S.

(MW) (MW) ST, GT, CC. (%) (days/year) (MW) (%) (%) (%) (Hours) (Hours) (Hours)1 18.428 18.428 DG RFO 3 25 17.9 45.2 45.1 44.92 18.428 18.428 DG RFO 3 25 17.9 45.2 45.1 44.93 18.428 18.428 DG RFO 3 25 17.9 45.2 45.1 44.94 18.428 18.428 DG RFO 3 25 17.9 45.2 45.1 44.95 18.428 18.428 DG RFO 3 25 17.9 45.2 45.1 44.96 18.428 18.428 DG RFO 3 25 17.9 45.2 45.1 44.97 18.428 18.428 DG RFO 3 25 17.9 45.2 45.1 44.98 18.428 18.428 DG RFO 3 25 17.9 45.2 45.1 44.99 18.428 18.428 DG RFO 3 25 17.9 45.2 45.1 44.9

10 18.428 18.428 DG RFO 3 25 17.9 45.2 45.1 44.911 18.428 18.428 DG RFO 3 25 17.9 45.2 45.1 44.912 16.45 16.45 ST Steam 3 6 6.061


Y or N Y or N Y or N yy/mm (%) (106$) F. O. R : Forced Outage Rate1 N N N 2011/04 47.5 to 52.5 EPC Cost was 149.5 millions EuroS. O : Scheduled Outage2 Min. Output : Minimum Output3 M. S. S : Monthly Start & Stop4 W. E. S : Weekend Start & Stop5 D. S. S. : Daily Start & Stop6 C. O : Commercial Operation7 A. F. C : Automatic Frequency Control89

1031 28 31 30 31 30 31 31 30.00 31 30 31

Actual records of operation Jan. Feb. Mar. Apr. May June July Aug. Sept. Oct. Nov. Dec.2013 Maximum Ouput (MW)

Minimum Output (MW)Average Monthly Load (MW) 75 45 26 0 35 0 148 192 186 179 177 203Average Monthly Gross Heat rate (BTU/ 7,934 8,265 8,116 - 8,245 7,958 7,926 7,902 7,947 7,976 7,903 7,875 Gross Monthly Generation (MWh) 55,448 30,554 19,501 - 25,711 213 109,852 142,560 133,979 133,075 127,553 150,934 Auxiliary Consumption (MWh) 1,052 971 1,052 182 774 320 2,343 2,980 2,817 2,660 2,400 2,751

2012 Maximum Ouput (MW)Minimum Output (MW)Average Monthly Load (MW) 118 73 137 181 160 157 152 158 167 150 143 176Average Monthly Gross Heat rate (BTU/ 7,980 7,787 7,897 7,802 7,887 7,923 7,985 7,962 7,945 7,948 7,847 7,845 Gross Monthly Generation (MWh) 87,863 50,890 101,850 130,254 119,069 112,876 113,351 117,727 120,213 111,807 103,167 131,167 Auxiliary Consumption (MWh) 642 443 955 1,349 1,318 1,396 1,426 1,443 2,572 2,657 2,572 2,657

2011 Maximum Ouput (MW)Minimum Output (MW)Average Monthly Load (MW) 159 111 132 196 174 191 163 138Average Monthly Gross Heat rate (BTU/kWh) 7,869 7,837 7,956 7,922 7,912 7,927 7,980 7,858 Gross Monthly Generation (MWh) 118,206 79,659 97,990 145,559 125,388 142,259 117,423 102,812 Auxiliary Consumption (MWh) 1,434 905 1,029 1,519 1,316 1,366 1,024 598




Remarks




1) Fixed Costs

unit Hydro Gas Diesel RFO/HSFO Coal Others/BiomassDiscount Rate % 10%Life Time year 25Salvage Value % 0Capital Cost $/kW Approx. $ 1,440/kWConstruction year 2011Fixed O&M RS/kW/mo. 0.1274Variable O&M RS/MWh 821.7Tax & Others RS/MWh NAFuel Use (%) 100%

2) Fuel Costs

2005 2010 2013 (kcal/Nm3) ($/103Nm3)(kcal/l ) ($/kl )(kcal/kg) ($/103kg)(kcal/kg) ($/103kg)




Unit Price

Hub Power Narowal

Others/Biomass



Appendix A-2

Letter from CPPA (COO-CPPA 10426 dated November

20, 2014)

Date post:	22-Feb-2018
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