State of Industry Report 2015

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STATE OF INDUSTRY REPORT 2015

Contents

FOREWORD ...... 1

1. OVERVIEW...... 5 1.1 China-Pakistan Economic Corridor (C-PEC) Project...... 5 1.2 Donors’ Support...... 5 1.3 Load Shedding...... 5 1.4 Reduction in the Cost of Generation...... 5 1.5 Tariffs of Renewable Energy Projects...... 6 1.6 Performance of GENCOs...... 6 1.7 Transmission Network NTDC...... 6 1.8 Projected Capacity and Power Balance of NTDC System...... 7 1.9 Expansion Plan of NTDC...... 7 1.10 Timely Completion of Upcoming Projects...... 7 1.11 Power Balance of K-Electric System...... 8 1.12 Environmental Impact of Coal Based Power Plants...... 8 1.13 Infrastructure Development...... 8 1.14 Data Reporting...... 8 1.15 Power Market Reforms...... 8 1.16 Receivables of DISCOs...... 9 1.17 Transmission and Distribution (T&D) Losses of DISCOs...... 9 1.18 Circular Debt...... 9 1.19 Tariff Differential Subsidy ...... 9 1.20 Multi-Year Tariff (MYT) Regime for DISCOs...... 9 1.21 Generation Capacity of K-Electric...... 9 1.22 K-Electric Transmission and Distribution Systems ...... 10 1.23 Upfront Tariffs...... 10 1.24 Net-Metering Regime...... 10 1.25 Special Purpose Transmission Licence under Section 19 of NEPRA Act...... 10 1.26 Recommendations...... 11

2. PERFORMANCE OF GENERATION SECTOR...... 15 2.1 General...... 15 2.2 Source-wise Installed Capacity...... 15 2.3 Hydropower...... 15 2.4 Thermal...... 15 2.4.1 Jamshoro Power Company Limited (GENCO-I)...... 15 2.4.2 Central Power Generation Company Limited (GENCO-II)...... 16 2.4.3 Northern Power Generation Company Limited (GENCO-III)...... 16 2.4.4 Lakhra Power Generation Company Limited (GENCO-IV)...... 16 2.4.5 Overall Performance of GENCOs...... 16 2.4.6 Independent Power Producers (IPPs)...... 17 2.4.7 Installed versus Dependable Capacity...... 17 2.4.8 Manpower to MW Ratio...... 17

vi 2.5 Nuclear (CHASNUPP-I and II)...... 18 2.6 Wind...... 18 2.7 Bagasse...... 18 2.8 Solar...... 18 2.9 K-Electric Limited...... 18

3. PERFORMANCE OF TRANSMISSION SECTOR...... 23 3.1 General...... 23 3.2 Overloading of Existing Power Transformers...... 23 3.3 Power Dispersal Constraints in Transmission Networks...... 26 3.3.1 Uch-II Power (Pvt.) Limited...... 26 3.3.2 Engro Powergen Qadirpur Limited...... 26 3.3.3 Altern Energy Limited...... 26 3.3.4 TNB Liberty Power Limited...... 26 3.3.5 Habibullah Coastal Power Company Limited...... 26 3.3.6 Foundation Power Company (Daharki) Limited...... 26 3.3.7 Nishat Power Limited and Nishat Chunian Power Limited...... 27 3.4 Induction of New Generation Power Plants...... 27 3.5 Future NTDC Network...... 29 3.6 NTDC Financial Plans...... 30 3.7 K-Electric Transmission System...... 30

4. PERFORMANCE OF DISTRIBUTION SECTOR...... 35 4.1 Constraints in DISCOs’ System...... 35 4.2 Receivables of DISCOs...... 35 4.3 Transmission and Distribution (T&D) Losses of DISCOs...... 36 4.4 Circular Debt...... 37 4.5 Tariff Differential Subsidy...... 37 4.6 Constraints in K-Electric System...... 37 4.7 Uploading of Performance Reports submitted by DISCOs and K-Electric on Quarterly Basis on Website...... 37 4.8 Legal Proceedings against DISCOs and K-Electric due to non-compliance of Performance Standards (Distribution) Rules, (PSDR) 2005...... 37

5. INITIATIVES BY NEPRA...... 41 5.1 Upfront Tariff for Wind Power Projects...... 41 5.2 Upfront Tariff for New Bagasse based Co-Generation Power Projects...... 41 5.3 Upfront Tariff for Coal Power Projects...... 41 5.4 Tariff for Conversion of Oil to Coal Projects...... 42 5.5 Upfront Tariff for Solar Power Projects...... 42 5.6 Upfront Tariff for Small Hydropower Projects...... 42 5.7 Upfront Tariff for LNG based Power Projects...... 43 5.8 Tariff for Short-Term IPPs...... 43 5.9 Development of NEPRA (Alternative and Renewable Energy) Distributed .Generation and Net Metering Regulations, 2015...... 43 viii 5.10 Integrated Generation, Transmission and Distribution Plans (IGTDPs)...... 43 5.10.1 Development of IGTDPs ...... 43 5.10.2 Evaluation/Review of IGTDPs by NEPRA...... 44 5.10.3 Recommendations for Resubmission of IGTDPs...... 44 5.10.4 Final Guidelines and Formats to Develop IGTDPs by NEPRA...... 45 5.11 Special Purpose Transmission Licence (SPTL) under Section 19 of NEPRA Act...... 45 5.12 Development of NEPRA Interconnection Guidelines, 2015...... 45

6. MONITORING OF THE SECTOR...... 49 6.1 Visits of DISCOs to Verify/Inspect the Sanctioned Load vis-a-vis Connected Load...... 49 6.2 Real Time Monitoring...... 49 6.3 Undue Scheduled/Unscheduled Load Shedding by K-Electric...... 49 6.4 Safety Record of Distribution Companies...... 49 6.5 Annual Performance Report (APR) of NTDC...... 50 6.5.1 Number of Voltage Variations (Violating Prescribed Criteria)...... 51 6.5.2 System Frequency...... 54 6.6 Annual Performance Report (APR) of K-Electric...... 55 6.7 Energy not served in KE System...... 57 6.8 Frequent Tripping of Transmission and Grid System in NTDC...... 58 6.9 Handing Over of Switchyards of GENCOs to NTDC...... 59 6.10 Implementation of Performance Standards (Generation) Rules, (PSGR) 2009...... 59 6.11 Implementation of Grid Code...... 59 6.12 Implementation of Distribution Code...... 59 6.13 Development of Power Safety Code...... 60

7. INITIATIVES BY STAKEHOLDERS...... 63 7.1 Market Structure...... 63 7.2 Creation of Central Power Purchasing Agency - Guarantee Limited (CPPA-G)...... 63 7.3 Modification in Transmission Licence of NTDC...... 63 7.4 Market Operator Registration (Standards and Procedure) Rules, 2015...... 63 7.5 PPIB Policy for Private Sector Transmission Projects 2015...... 64 7.6 Central Asia-South Asia (CASA-1000) Project...... 64 7.7 Import of Electricity from Iran...... 64 7.7.1 Import of 74 MW (Jackigur – Mand)...... 64 7.7.2 Import of 100 MW (Polan – Gawadar)...... 64 7.7.3 Import of 1000 MW (Zahedan – Quetta)...... 64 7.8 Alternative and Renewable Energy Developments...... 65 7.8.1 Steps/initiatives for Development of ARE Sector...... 65 7.8.2 On-Grid Projects...... 66 7.8.3 Off-Grid Applications...... 66

8. MISCELLANEOUS...... 73 8.1 Promulgation of New Rules/Regulations...... 73 8.2 Advisories issued by NEPRA to the Government of Pakistan...... 73 8.3 Consumer Affairs...... 73 8.3.1 Achievements/Development...... 74

viiiii 9. Energy Sector Overview...... 77 9.1 Oil...... 77 9.2 Gas...... 77 9.3 Coal...... 77 9.4 Primary Energy Supplies...... 77 9.5 Final Energy Consumption...... 79 9.6 Fuel Consumption in Power Sector...... 80

10. ELECTRICITY SECTOR OVERVIEW...... 83 10.1 Installed Capacity...... 83 10.2 Load Pattern and Peak Load Hours...... 115 10.3 Maximum Demand...... 117 10.4 Pattern of Electricity Consumption...... 118 10.5 Surplus/Deficit in Demand and Supply during Peak Hours (actual and projected)...... 119

11. ELECTRICITY GENERATION...... 123 11.1 General...... 123 11.2 Thermal Generation...... 124 11.3 Thermal Power Generation and Fuel Consumption...... 124 11.4 Hydel Generation...... 125 11.5 Nuclear Power Plants...... 127 11.6 Renewable Energy...... 128 11.7 Available Power Generation Capacity...... 129 11.8 Investment Plan for Power Generation Projects...... 130 11.9 Economic Load Dispatch System...... 136 11.10 Generation Licenses Granted...... 139

12. ELECTRICITY TRANSMISSION...... 151 12.1 General...... 151 12.2 Transmission Lines and Grid Stations with NTDC...... 151 12.3 Transmission Losses...... 152 12.4 Utilization of Transmission Lines and Power Transformers...... 153 12.5 Investment Plan - NTDC System...... 154 12.6 Transmission Lines and Grid Stations with K-Electric...... 157

13. ELECTRICITY DISTRIBUTION...... 165 13.1 General...... 165 13.2 Function of Distribution Companies...... 166 13.3 Distribution System Performance...... 166

14. ELECTRICITY TARIFF...... 191 14.1 Tariff Setting...... 191 14.2 Tariff Standards...... 191

LIST OF TABLES...... 213

ACRONYMS AND ABBREVIATIONS...... 215

SOURCE OF INFORMATION...... 217 viiiiv State of Industry Report 2015

FOREWORD The power sector is presently undergoing a major transformation where the Federal and Provincial Governments have aligned their priorities for overcoming the energy crises which have been adversely affecting the social, economic and financial progress of the country for the past many years. The Government of Pakistan’s (GoP) efforts for bringing new power generation plants through China-Pakistan Economic Corridor (C-PEC) Agreement reflects the realization that the country is in dire need of energy resources to satisfy base load requirements. Similarly, overall generation mix is also planned to have renewable energy projects which will provide necessary diversification and increased energy security to the sector. The introduction of Re-Gasified Liquid Natural Gas (R-LNG) Projects is also a step towards adding relatively clean and cheaper energy generation resources.

According to the available plans, more than 17,200 MW are expected to be added to the system. In order to meet peak time demand about 8,000 MW will be inducted by the end of June, 2017. Although such a target by June, 2017 is quite ambitious yet this is achievable, as this planned capacity includes Solar and Wind Projects, 3,600 MW R-LNG based Projects, and under-construction hydropower projects at Tarbela and Neelum-Jhelum. Sustained efforts are, however, required at all levels so that smooth and transparent implementation of these projects is achieved within the target dates.

While it is satisfying to note that the generation sector has been drawing all the due attention, strengthening of the transmission and distribution sectors is equally critical. One of the problems faced by these sectors is their overloaded networks which not only hinder their power transfer capability but also add to wastage of electricity through increased losses. The constraints on transmission networks have also led to severe power evacuation problems with the result that the capacities of some of the most efficient plants cannot be utilized to their optimum level. Therefore, addition of new generation facilities of around 8,000 MW by June, 2017 and strengthening of existing transmission system requires large scale investment in this area, besides hugely improved managerial performance by NTDC, in order to ensure availability of a reliable transmission system well before the completion of generation facilities.

In addition to funding constraints, the Distribution Companies (DISCOs) are required to enhance their ability and competence especially in the areas of designing, specifying and constructing 132 kV facilities which shall complement the additional energy referred to above.

It is noted that due to better load management policies, fewer agitations and protests were witnessed during 2014-15, especially in the later part of the year. Not only, improvement in uninterrupted supply to the industrial sector has been ensured, load shedding in the domestic and commercial sectors remained somewhat predictable whereas unscheduled load shedding hours have been considerably reduced. The improved continued electricity supply to the industrial sector is expected to help increase the industrial production besides creating more employment opportunities.

The ability of DISCOs to have accommodated and distributed more than 16,000 MW this year shows an improvement over the previous year.

The DISCOs did not show any noticeable improvement in their performance and continued with the business as usual in the areas of T&D losses, recoveries and technical operations. While overall averages for the year in the above areas remained almost the same as for 2013-14, the second half of the current year (January to June) showed slight improvements in the above areas relative to corresponding period of 2013-14. The safety aspect deteriorated which is reflected in the increased number of fatal incidents over the previous year in most of the DISCOs.

The receivables of distribution sector increased by more than Rs. 120 billion during 2014-15, which on 30th June, 2015 stood at Rs. 633.119 billion. Out of Rs. 120 billion, Rs. 75 billion increase is due to the receivables from private sector, whereas Rs. 15 billion increase stood against AJK share. Another Rs. 13 billion increase is due to the Provincial Governments (especially Government of Sindh’s receivables). The Federal Government needs to

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pay attention to creating a smooth payment mechanism from the government connections especially in Sindh and AJK. The recoveries from agriculture connections also remain a source of constant inflow into the circular debt and cannot be resolved unless the provincial governments lend their active support to DISCOs.

K-Electric, despite having the generation capacity, is continuously carrying out load shedding for certain categories of its consumers. Although K-Electric has been reporting satisfactory performance in relation to NEPRA performance standards, the crises in K-Electric territory in June, 2015 have proved otherwise. The findings of NEPRA’s fact finding team have brought out some real concerns about the health of K-Electric system, these issues are required to be addressed immediately which need reasonable investment specifically in transmission and distribution networks.

Although no major steps were taken for the past many years to move towards a competitive market, despite NEPRA having indicated about the slow pace of reform process initiated in 1992, recent changes by creating a Central Power Purchasing Agency - Guarantee Limited (CPPA-G) out of the umbrella of NTDC are encouraging as these changes aimed at not only bringing transparency in the operations of power procurement agency, but also helping in smooth transition towards market based operations in the power sector.

During the year, the Authority has introduced up-front tariff regimes, in technologies of Solar, Wind, Bagasse, Small Hydro, R-LNG and Coal. The Authority also announced a number of land mark decisions including grant of “Special Purpose Transmission Licence” (SPTL) to a private entity, regulations on sale of power by renewable energy sources and regulations on net-metering regime. It is believed that the above decisions especially about SPTL and net-metering would prove to be the game-changer in the areas of transmission and distribution sectors. NEPRA expects that the GoP would also incentivize solar industry so that consumers are encouraged to participate not only in net-metering regime but also in off-grid application of solar power. Availability of funds would not only facilitate consumers to install solar panels but will also help in meeting supply-demand gap.

It has been observed that the targets set for the sector are reasonably ambitious but critical at the same time. It is, therefore, desired that coherent efforts are made in the sector with continuous vigor and zeal. Continuous monitoring ensuring transparency for timely completion of all envisaged projects is equally important.

The detailed statistics and data provided on the power sector in the State of Industry Report 2015, besides being a source of information, would also be helpful and useful for the decision makers.

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State of Industry Report 2015 1. OVERVIEW

Notwithstanding the issues and shortcomings in the power sector, some of the following factors during the year 2014-15 have shown positive developments as a result of various steps taken by the Federal and Provincial Governments coupled with international trends in the capital and fuel markets.

1.1 China-Pakistan Economic Corridor (C-PEC) Project The US$ 46 billion Agreement under China-Pakistan Economic Corridor (C-PEC) Project between the Governments of China and Pakistan includes around US$ 33.8 billion for various energy projects. Under the C-PEC agreement, US$ 15.5 billion worth of coal, wind, solar and hydropower projects will add 10,400 MW of energy to the National Grid. C-PEC also foresees cooperation between the two countries in developing nuclear energy based projects. It is expected that the development of nuclear and coal projects would meet the necessary base load requirements in the overall demand profile of the country in the long run. Expensive energy mix has remained one of the major contributors to relatively higher tariffs for the end-consumers. Coal power plants operating at high utilization levels will help in bringing down the cost of energy generation.

1.2 Donors’ Support The support of donor agencies in the infrastructure development and capacity building has resulted in some noticeable improvement. In the generation sector, refurbishment through USAID funding in public sector generation companies (GENCOs) has led to recovery of additional useful capacities at relatively better operational efficiencies. GENCOs were also helped by USAID in carrying out performance testing of their generation facilities. Through JICA and USAID support, detailed studies for National Transmission and Dispatch Company Limited (NTDC) have been initiated, including preparation of a National Least Cost Expansion Plan and studies for absorption levels of renewable energy projects in the National Grid. The World Bank has been providing assistance for improving the functioning of Central Power Purchasing Agency (CPPA). Similarly, infrastructure improvement of SCADA system is being contemplated at National Power Control Centre (NPCC), through JICA support. USAID, World Bank and Asian Development Bank are also helping in importing power from Central Asian States.

1.3 Load Shedding Owing to overall monitoring by the Ministry of Water and Power and real time monitoring of power flows at the feeder level, the DISCOs have been able to achieve marked improvement in demand management. Reportedly, the load shedding duration has been reduced from 12 hours in 2013 to 6 hours in 2015 in the urban areas. Similarly, load shedding in the industrial sector has been reduced from 12 hours to 4 hours over the same period. Rural areas have also witnessed relative reduction in their load shedding hours.

1.4 Reduction in the Cost of Generation Due to reduction in oil prices in the international market, the cost of generation declined in the year 2014-15, compared to the last year. A comparison of the two years is shown in the following table:

Source-wise Fuel Cost (Rs./kWh) Import Average Source Hydel Coal HSD RFO Gas Nuclear Mixed Wind Solar Iran Basket Price 2013-14 - 4.05 21.85 15.97 4.81 1.32 9.35 9.31 - - 10.59 2014-15 - 4.50 17.14 12.54 4.81 1.19 10.03 8.23 - - 9.84 Source: NEPRA

It may be noted that up to June 2015, except for coal and import from Iran, which constitute only 0.11% and 0.46% respectively of the overall energy generated, the cost of generating a unit of energy through major fuels declined. Generation on furnace oil made up 32.66% of total energy. The unit cost of energy on furnace oil reduced by Rs. 3.43 per kWh. Similarly, the cost of generation on high speed diesel (HSD) which provided 3.01% of total generation reduced by Rs. 4.71 from 2013-14. The cost of generation on gas remained almost the same. The reduction in cost of generation was passed on to the consumers for the respective months of 2014-15 as tabulated herein. An overall impact of the reduction in cost has been noted as Rs. 87.97 billion during the year:

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Increase/(Decrease) Rs./kWh July Aug. Sept. Oct. Nov. Dec. Jan. Feb. March April May June 0.43 (0.30) 0.52 (0.48) (2.97) (3.24) (2.08) (4.43) (3.62) (1.86) (2.68) (2.19) Source: NEPRA

1.5 Tariffs of Renewable Energy Projects The reduction in capital costs and technological improvements in renewable energy has reaffirmed NEPRA's stance that such projects should be inducted with due consideration to these factors. NEPRA, in order to provide incentives to investors, and to build their confidence and with a view to introducing wind technology in the country, determined an upfront levelized tariff of Rs. 13.1998 per kWh, for wind power projects in 2013. In view of the improvement in technology and overall decline in project costs, the tariff was revised at Rs. 10.6048 in 2015. Similarly, in order to introduce solar technology in the country, NEPRA determined an upfront levelized tariff of Rs. 17.1216 per kWh in 2014 and the same was capped at a maximum of 50 MW, out of which 46.5 MW tariff was secured, which in 2015 has been determined at the rate of Rs. 14.8591 per kWh. Renewable energy not only provides energy security but is also instrumental in saving foreign exchange, guarantees predictability and is environment friendly. In view of the continuous improvements in technology, reduction in prices and the grid stability, renewable energy has to be inducted gradually in the system. For creating more space for renewable energy projects, detailed studies need to be carried out to identify short term and long term expansion plans for strengthening the grid system.

1.6 Performance of GENCOs The performance of GENCOs has been a matter of concern for the regulator and an aggressive monitoring program has been initiated for overseeing GENCOs' regulatory affairs. Earlier, all the GENCOs were advised by the Authority to carryout performance tests so that degradation in their operational capabilities, efficiencies and administrative factors like manpower, timely overhauling and maintenance are set afresh. Particularly, the surplus human resource which is sitting idle due to closure and non-operational plants and over employment are major factors contributing towards higher cost of generation. NEPRA during forthcoming tariff determinations for GENCOs will keep these factors in view in order to rationalize their tariff. The surplus and skilled human resource of these GENCOs can be absorbed and utilized in the upcoming power generation projects.

1.7 Transmission Network NTDC Under its transmission license, NTDC is required to play a number of roles. As a network operator, it is required to construct and operate Extra High Voltage transmission lines and grid stations for transporting power from the existing and new generation facilities to the DISCOs. NTDC has a critical role in the sense that it has to match not only the availability of its transmission facilities with the timing of new power generation plants, but also to periodically refurbish and upgrade its existing system to cater for the increased load demand put on by the DISCOs, besides managing transmission losses. The transmission network of NTDC includes 5,197 km long transmission lines operating at 500 kV level and 9,814 km long 220 kV lines.

As of 30th June 2015, NTDC is maintaining 13 No. 500 kV grid stations with a transformation capacity of 18,624 MVA. There are 33 No. 500/220 kV transformers and 28 No. 220/132 kV transformers installed at these grid stations. At 220 kV level, there are 37 grid stations with a transformation capacity of 24,063 MVA. There are 101No. 220/132 kV transformers installed at 220 kV and after inclusion of 28 No. 220/132 kV transformers installed at 500 kV grid stations, total 220/132 kV transformers come to 129. An overview of the existing transmission capacity shows that EHV network is barely enough to cater for the present generation capacity. It has been noted that out of 33, 500/220 kV transformers, 8 are overloaded. Similarly, out of 129 No. 220/132 kV transformers, 90 are overloaded, which if not rectified are a potential threat to the reliable operation of the system. It is imperative that NTDC besides strengthening of existing transmission network should ensure timely completion of the planned transmission requirements identified for evacuation of power from the upcoming generation projects.

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1.8 Projected Capacity and Power Balance of NTDC System The following table provides peak time demand in NTDC system, year-wise capacity additions and resulting installed capacity till 2020-21:

Financial Year NTDC Peak Demand Capacity Addition per year Total Installed Capacity ending 30th June (MW) in NTDC System (MW) per year (MW) 2015 21,701 1,504 22,928 2016 23,711 689 23,617 2017 24,871 6,643 30,260 2018 26,105 9,961 40,221 2019 27,408 1,279 41,500 2020 28,773 4,580 46,080 2021 30,156 2,200 48,280 Source: NTDC If new generation as noted above is added to the system, it is expected that by 2017, negligible deficit will be faced at the peak time only, while no load shedding during other times be required. However, for this to happen, not only the generation but the transmission and distribution systems must be strengthened so that constraints in the existing system are completely removed.

1.9 Expansion Plan of NTDC To cater for the needs for transmission of power from upcoming generation power plants and strengthening of existing system, grid station expansion plan of NTDC over the next two years is shown in the following table, which provides that by the end of 2017, 3 new grid stations at 500 kV level will be added which will add 3750 MVA in transformation capacity in the system, the fourth 500 kV grid station will be complete by the end of 2020 adding additional 1500 MVA to the system. At 220 kV level, 8 new grid stations with a cumulative transformation capacity of 5750 MVA will be added in the system. Similarly, one overloaded 500 kV grid station will be strengthened, while six such grid station at 220 kV level be improved by 2019-20. The adequacy of NTDC system is discussed further in the later sections of the report.

Grid Station Expansion Plan of NTDC 500/220 kV Grids 220/132 kV Grids Period of Report MVA Expected *Estimated Cost MVA Expected Estimated Cost Nos. Capacity COD (Rs. Million) Nos. Capacity COD (Rs. Million) New Grid Station 2015-16 3 3750 2016-17 20,399 8 5750 2016-17 26,233 2016-17 1 1500 2019-20 3,500 - - - - Extension 2015-16 1 430 2016-17 697 - - - - Addition/Reinforcement of Transformers at Overloaded Grid Stations 2015-16 1 0 2016-17 1,413 - - - - 2016-17 ------2017-18 - - - - 6 3000 2019-20 16,400 * The cost of 500/220 kV Grid Stations also include the cost of 220/132 kV Transformers. Source: NTDC

1.10 Timely Completion of Upcoming Projects It is noted that by June 2017, a large generation capacity has been planned to be added which is expected to reduce the gap between supply and demand. Similarly, transmission system is required to be strengthened for evacuation of power from these generation facilities. However, it is noted that to meet these targets, timely completion of projects is critical and of paramount importance. From the above tables it is also evident that more than 10,000 MW will be surplus to the demand requirements by 2021, which will essentially be required to maintain necessary reserve and operating margins in the system as per international practices.

7 State of Industry Report 2015 1.11 Power Balance of K-Electric System The following table shows year-wise projected figures of power balances in respect of K-Electric i.e. planned generation capability, projected demand growth rate, projected demand during peak hours and surplus/deficit:

Financial Generation* KEL's Projected KEL's Projected Surplus/ Year ending Capability as per Demand Growth Demand during (Deficit) (MW) 30th June K-EL (MW) Rate (%) Peak hours (MW) 2015 2,632 - 3,056 -424 2,752 2016 5.00 3,209 -457 (including 20 + 100 MW SNPC) 2,804 2017 5.00 3,369 -565 (including 52 MW FPCL) 3,674 2018 (including 450 LNG + 420 Coal 5.00 3,538 136 Conversion) 4,374 2019 5.00 3,715 659 (including 700 MW Coal)** 2020 4,374 5.00 3,900 474 * includes 650 MW from NTDC ** Subject to approval of acceptable tariff by NEPRA and other regulatory approvals. Source: K-Electric Limited

It may be noted that the above generation capability data as reported by K-Electric includes 650 MW from NTDC implying thereby that K-Electric will barely meet its requirements by 2019 provided that additional generation capacity is timely achieved.

1.12 Environmental Impact of Coal Based Power Plants Induction of coal based power plants at a large scale would affect the environmental balance due to various issues related to coal power. These include increased emission levels, particulate matter and disposal of ash. Similarly, the coal-based power plants proposed to be constructed in mid-country would also require a robust transportation system for a continued supply of coal. The environmental issues put a huge responsibility on the relevant environmental agencies for monitoring coal based projects during their planning, construction and operation stages.

1.13 Infrastructure Development The Federal Government is also required to ensure availability of infrastructure i.e. road/rail facilities before the completion of coal-based projects for transportation of coal from the port to project sites without interruption. Efforts on war footing are also required for the development of infrastructure at port and transmission lines for R-LNG supply to upcountry power plants.

1.14 Data Reporting The DISCOs have been continuing with manual record keeping and its functionaries are prone to in-accurate reporting as well as human errors and discretion, which distort reported data leading to skewed decisions, not reflecting the true picture. In view thereof, it is reiterated and emphasized that all power sector entities should immediately explore and adopt automation to have system generated reports to minimize the human factor thus forming the basis for informed and real time decisions.

1.15 Power Market Reforms The Authority granted transmission license to NTDC in 2002, which required NTDC to create a number of entities within its setup. In this respect, CPPA was also created which was responsible for procurement of power on behalf of DISCOs. Similarly, an independent system operator, a network operator and a contract registrar were also to be created. The operations of the sector were expected to move forward from a single-buyer mode to single-buyer-plus mode and finally to a bilateral contract market. Under the structure of bilateral market, the CPPA and the contract registrar were to be taken out of the NTDC umbrella for the transparency of functions. Over the years, however, the power sector structure could not make progress as stipulated in the transmission license as the single-buyer mode has continued. Almost all of the major contracts by IPPs have been entered

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into on long terms with CPPA/NTDC through sovereign guarantees of the GoP. During the year, the Authority considered a Licensee Proposed Modification (LPM) by NTDC for revision in its transmission license and creation of a new entity as CPPA-G. NEPRA has approved such modification. Creation of CPPA-G will help providing enabling environment to move from single buyer model to single buyer plus model and finally to the bilateral contract mode.

1.16 Receivables of DISCOs The overall receivables of DISCOs at the end of June, 2015 increased by Rs. 120 billion over the previous year. it is noted that apart from Federal Government and agriculture tube wells in Balochistan which show a reduction of around Rs. 0.7 billion and Rs. 0.2 billion respectively, receivables from other areas increased. As on 30th June, 2015 the overall distribution sector receivables stood at Rs. 633 billion (including Rs. 43.97 billion pertaining to K-Electric).

1.17 Transmission and Distribution (T&D) Losses of DISCOs DISCOs' performance in the area of losses, has been mixed. Certain DISCOs have reported very slight improvement; others have maintained the same level of losses, whereas a number of DISCOs have reported higher losses than they had reported to NEPRA during earlier years. In this respect, PESCO and SEPCO have shown increase in losses. Adding further to T&D losses is the low recovery ratio of DISCOs. The Authority assessed a recovery target of 100% while setting the consumer tariff for DISCOs, however according to the information provided by DISCOs, the actual level of recovery remained around 89.16% for the year 2014-15.

1.18 Circular Debt Circular debt is still a major issue confronting power sector. One of the contributors of circular debt remained high transmission and distribution losses in DISCOs. Based on the currently notified consumer-end tariff of 10th June, 2015, if DISCOs fail to show any improvement in their actual level of losses, the impact of missing the Authority’s set T&D loss target would result in an annual gap of Rs. 41 billion. It is pertinent to mention that the authority has set an average loss target of 15.29% for 2014-15, whereas DISCOs' reported losses for the same period remained around 18.73%.

1.19 Tariff Differential Subsidy GoP is providing Tariff Differential Subsidy (TDS), primarily to the agriculture and residential class of consumers, having consumption of up to 300 units. The GoP intends to decrease the gap between NEPRA determined consumer-end tariff and the GoP notified tariff through imposition of Tariff Rationalization Surcharge on some categories of consumers of different DISCOs so that its burden in the shape of TDS is reduced from Rs. 135 billion to Rs. 65 billion.

1.20 Multi-Year Tariff (MYT) Regime for DISCOs According to NEPRA Tariff Standards and Procedure Rules, 1998 determination of DISCOs' tariff requires a very elaborate procedure to be followed. DISCOs are required to provide extensive information which is generally delayed. Further delays may occur during notification of tariff. Conducting such proceedings annually have been proving to be inefficient. Therefore, to streamline the process and to regulate the revenue streams for the entities involved and further to bring in-built incentives and efficiency, NEPRA has decided to re-introduce MYT regime. MYT being a performance based tariff will require DISCOs to achieve certain targets of performance over the control period to receive revenue streams based on known tariffs.

1.21 Generation Capacity of K-Electric It is noted that K-Electric was required to enhance its generation capacity by 1000 MW over the capacity indicated in its Generation License. K-Electric has added 1034 MW in the system however it has decommissioned or permanently closed 685 MW of its existing generation capacity. Therefore, effectively about 349 MW has been added by K-Electric considering retirement and permanent closure of its generation facilities. Inability of K-Electric to effectively increase its generation capacity has made it dependent on external power sources, including the import from NTDC system. To meet its demand, it has to operate its generation facilities and other resources specifically 650 MW from NTDC at their maximum. It is observed that reserve margins per international standards are required in order to avert any breakdown in the system.

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The contract of power supply between NTDC and K-Electric has already expired, however, the power is still being imported out of necessity. The Authority has advised K-Electric and NTDC to enter into a contract if such arrangement is to continue, without which import of 650 MW will be ostensibly illegal and unlawful.

1.22 K-Electric Transmission and Distribution Systems The Authority has noted that recently with increase in load demand, the tripping on Extra High Voltage Transmission (EHT) network has increased. Normally, EHT is considered the strongest link between power generation and consumers as it is used only for transporting electricity, therefore, increased tripping indicates weakness in K-Electric system.

The loading profile of EHT network during June 2015, shows that out of a total 129 power transformers, 45 are overloaded. Out of these, 16 are overloaded between 90% and 100% whereas a number of transformers are noted to be operating at more than 100% of their rated capacity. It is also noted that in order to ensure that power transformers are loaded within their limits, feeders are isolated by K-Electric as a routine, so that overloading can be avoided. The Authority has noted that EHT system of K-Electric lacks enough capacity to transmit power to the underlying network. NEPRA has taken cognizance of this unwarranted situation and is proceeding as per law.

1.23 Upfront Tariffs Under NEPRA Tariff (Standards and Procedure) Rules 1998, it takes around four months to determine tariff of a facility. Taking cognizance of the electricity shortage in the country, which has direct bearing on the social and economic health of consumers besides GDP, NEPRA under its Up-front Tariff (Approval & Procedure) Regulations, 2011 has decided to introduce the regime of up-front tariff. Under this regime, the time has been reduced to 10 days for determination by the Authority in case the investors decide to opt for the respective upfront tariff for that technology. The regime, besides providing predictability and level playing field for all investors, will also allow inbuilt incentives for early completion of the projects. Accordingly, up-front tariffs for all technologies i.e. small hydropower, wind, solar, bagasse, R-LNG and coal have been announced by NEPRA. The up-front tariff for coal is basically structured on using local coal, which will reduce the import of oil and save from shocks of volatile oil market, which can rebound any time as has been experienced by power sector in the past. It is to be noted that the up-front tariffs announced by NEPRA are periodically revised in view of introduction of new technologies and international market trends.

1.24 Net-Metering Regime Pakistan has a huge potential for solar-based energy. In order to make optimum use of this potential, NEPRA, besides announcing up-front tariff for solar technology, has also decided to introduce net-metering regime.

The regime will enable commercial units, industry and household consumers to install solar PV panels on their roof tops who will be able to sell surplus electricity in the national grid through the mechanism provided in net-metering regulations. This will not only provide an opportunity for the common man to earn energy based income but will also mitigate the shortfall of energy, bringing stability in the system. It is expected that GoP will introduce a financial package to facilitate household consumers as has been done in the case of solar tube well schemes.

The introduction of this regime will encourage the investors to setup necessary solar panel and allied equipment manufacturing facilities in the country to further reduce its cost. Such facilities will help in generation of employment opportunities throughout the country. Solar panels and net-metering are also expected to encourage provision of electricity in remote areas through off-grid solutions.

1.25 Special Purpose Transmission Licence under Section 19 of NEPRA Act (Special Transmission Facilities for Private Entities) Only a distribution licensee has an exclusive right to construct, own, maintain and operate the 132 kV and 11 kV lines/networks in the specified service territory of that DISCO as per provisions under Section 20 and 21 of the Act. Therefore, no entity can engage in the distribution regime except a DISCO. However, under Section 19

10 State of Industry Report 2015 of the Act, the Authority granted a Special Purpose Transmission Licence (SPTL) to a private entity to engage in construction, ownership, maintenance and operation of specific transmission facilities (66 kV and above) built for provision of transmission and interconnection services to NTDC and others by connecting its facilities at transmission and distribution networks.

SPTL regime will not only open the sector, it will reduce response time for attending faults, restoration of system and increase reliability of transmission and distribution networks. Due to this regime, the opportunities for the private sector for investment in generation and transmission facilities within reasonable resources will increase. It is expected that introduction of SPTL regime will facilitate off-grid solutions for supplying electricity through the technologies like solar and small hydropower plants.

1.26 Recommendations In view of the above, following recommendations are made:

1.26.1 For the power sector to come out of the existing crises, it is critical that timely completion of planned power generation projects, specifically through China-Pakistan Economic Corridor is ensured.

1.26.2 For the protection of environment from the emissions by coal power projects, the relevant agencies must adopt an aggressive monitoring regime before and during operation of such power plants.

1.26.3 Infrastructure for coal transportation and R-LNG are potential hotspots on which the operation of the mid country coal power plants and R-LNG based power plants is dependent. In view thereof, it shall be ensured that infrastructure for coal transportation and R-LNG meet the timeline envisaged for respective projects.

1.26.4 Transmission and distribution are hardly adequate to meet the existing requirements and have little or no potential to absorb planned generation in the South. In view thereof, it is imperative that transmission and distribution systems may be strengthened and stabilized besides completion of new transmission and distribution systems planned to transmit electricity generated by upcoming projects.

1.26.5 The Federal Government may provide incentives to the households intending to enter into net- metering regime on the lines already announced for solar tube well schemes.

1.26.6 In order to reduce losses, control theft and improve the service delivery to consumers and effective revenue recording, use of technology i.e. smart meters/prepaid meters may be immediately introduced in all DISCOs.

1.26.7 Out-sourcing of inefficient service in distribution system may be explored and considered by the DISCOs.

11 State of Industry Report 2015

12 PERFORMANCE OF GENERATION SECTOR 2

State of Industry Report 2015 2. PERFORMANCE OF GENERATION SECTOR

2.1 General The installed generation capacity of the NTDC's system on 30th June, 2015 stands at 22,928 MW, against 21,424 MW on 30th June, 2014 recording an increase of 1,504 MW or 7.02% over the last year. The power plants connected with NTDC's system generated 97,284 GWh of energy during the year 2014-15, while over the same period during 2013-14, 93,903 GWh were produced; an increase by 3,381 GWh or 3.60%. During July, 2014 to June 2015, the major additions to installed capacity of NTDC's system are Guddu (747 MW) and Nandipur (425 MW) thermal power plants. In addition, 320 MW have been added to NTDC's system through renewable and alternative energy (Solar, Wind and Bagasse) based power plants during 2014-15.

2.2 Source-wise Installed Capacity The following table gives additional details of installed capacity and energy generation by different power plants connected with NTDC's system and comparison of last two years:

Installed Capacity Generation Variation Source (MW) (GWh) Capacity Generation 2013-14 2014-15 2013-14 2014-15 MW % GWh % WAPDA Hydel 6,902 6,902 31,656 31,877 0 -- 221 0.70 IPPs Hydel 214 214 1,015 1,070 0 -- 55 5.43 Total Hydel 7,116 7,116 32,671 32,947 0 -- 276 0.84 GENCO-I 1,024 1,024 3,152 3,320 0 -- 168 5.32 GENCO-II 1,690 2,437 4,484 5,541 747 44.20 1,057 23.56 GENCO-III 1,965 2,390 5,307 5,203 425 21.63 -104 -1.96 GENCO-IV 150 150 112 141 0 -- 29 26.21 Total GENCOs 4,829 6,001 13,055 14,205 1,172 24.27 1,150 8.81 Thermal IPPs 8,723 8,735 43,706 44,332 12 0.14 626 1.43 Nuclear 650 650 4,208 5,006 0 -- 798 18.97 Wind 106 256 263 459 150 141.50 196 74.58 Bagasse 0 70 0 308 70 -- 308 -- Solar 0 100 0 28 100 -- 28 -- GRAND TOTAL 21,424 22,928 *93,903 *97,284 1,504 7.02 3,381 3.60 * The generation from SPPs/CPPs and energy import from Iran have not been included. Source: NEPRA

2.3 Hydropower It may be noted that the installed capacity of WAPDA Hydropower remaining at 6,902 MW in 2014 and 2015, the 31,877 GWh generated in 2014-15 shows an increase of 221 GWh from the last year. Similarly, the IPP (hydel) also contributed 55 GWh more in the system during 2014-15 with the same installed capacity as in 2013-14. The hydropower production pattern over the year remained consistent with the historical trends. The availability and overall performance of hydropower plants has also remained satisfactory during the 2014-15.

2.4 Thermal On the thermal side, overview of the public sector GENCOs is as follows:

2.4.1 Jamshoro Power Company Limited (GENCO-I) There has been no increase in the installed capacity of 1,024 MW of GENCO-I Power Stations at the end of June, 2015 over that of 2014. The GENCO-I has a dependable capacity of 830 MW. The energy generated by GENCO-I during the 2014-15 was 2,961 GWh, while, it was 3,153 GWh in 2013-14; a decrease of 192 GWh or 6.09%, over last year. Net electrical efficiency of GENCO-I during 2014-15 stood at 28.30%. With a capacity utilization of

15 State of Industry Report 2015

45.66% due to forced outages and various maintenance issues, the overall performance of GENCO-I has not been satisfactory.

2.4.2 Central Power Generation Company Limited (GENCO-II) Total installed capacity of GENCO-II, up to 30th June, 2015 has been noted as 2,437 MW, while the capacity available for generation i.e. the dependable capacity is observed as 1,952 MW. The installed and dependable capacities of GENCO-II were 1,690 MW and 1,180 MW respectively at the end of June, 2014. During the 2014- 15, the installed capacity of GENCO-II has increased by 747 MW or 44.20%, as compared to 2013-14, due to the addition of Guddu 747 power plant. The energy generated by GENCO-II during the 2014-15 has been recorded at 5,610 GWh, while, it was 4,444 GWh during the 2013-14. The energy generated by GENCO-II during the 2014- 15, has increased by 1,166 GWh or 26.24%, compared with that of the last year.

It is observed that various units of GENCO-II have been off-bar for more than two years due to various maintenance issues, forced outages, fuel constraints and rehabilitation activities etc. and are not being fully utilized. With annual efficiency of 33.95% and capacity utilization of only 32.43%, the overall performance of GENCO-II has been unsatisfactory.

2.4.3 Northern Power Generation Company Limited (GENCO-III) Total installed capacity of GENCO-III, up to 30th June, 2015 has been noted as 2,151 MW, while the capacity available for generation i.e. the dependable capacity is observed as 1,925 MW. The installed and dependable capacities of GENCO-III were 1,726 MW and 1,530 MW respectively at the end of June, 2014. During the 2014- 15, the installed capacity of GENCO-III has increased by 425 MW or 21.63%, as compared with that of the year 2013-14, due to the addition of Nandipur power plant. The energy generated by GENCO-III during the 2014-15 was 4,627 GWh, while it was 5,307 GWh during the 2013-14 showing a decline of 680 GWh or 12.81%, compared with the last year.

It is observed that various units of GENCO-III have remained off-bar since long due to their poor efficiency levels. The overall net efficiency of GENCO-III is also very low at 24.84%. Furthermore, due to various maintenance issues, forced outages and fuel constraints etc. resulting in annual capacity utilization of 38.44%, the overall performance of GENCO-III cannot be termed as satisfactory.

2.4.4 Lakhra Power Generation Company Limited (GENCO-IV) Total installed capacity of GENCO-IV, up to 30th June, 2015 has been noted as 150 MW, while the capacity available for generation i.e. the dependable capacity is observed as 30 MW. GENCO-IV had three units of 50 MW, however, due to lack of proper maintenance and cannibalization, only one unit is in working condition though at a reduced level for the past number of years. GENCO-IV during 2014-15 generated 102 GWh.

It may be noted that, against the installed capacity of 150 MW, approximately, one third capacity of GENCO-IV is available for generation, which also is not being fully utilized due to forced outages etc. With net efficiency of 17.74%, the overall performance of GENCO-IV has not remained satisfactory.

2.4.5 Overall Performance of GENCOs It is noted that, although the total installed capacity of GENCOs' power plants has increased by 1,172 MW during the 2014-15 (including efficient machines at Guddu), as compared with the capacity of these power stations during the year 2013-14, the impact of increased capacity of GENCOs power plants is yet to be reflected in the performance of these power stations. It is noted that overall non-availability of GENCOs on account of fuel constraints reduced in 2014-15 due to better availability of fuel at all the GENCO power plants. The overall furnace oil inventory at the five plants supplied by PSO (Muzaffargarh, Jamshoro, KAPCO, HUBCO and Nandipur) was only 49,123 metric tons in June 2014, which increased to 223,819 metric tons in June 2015.

It is also observed that other than fuel, GENCOs power plants remained off bar, due to various maintenance issues, forced outages, and rehabilitation activities etc. and their available capacity has not been fully utilized. The prevailing situation warrants maximum generation from public sector thermal power plants to cater for the dire need of the system.

16 State of Industry Report 2015

2.4.6 Independent Power Producers (IPPs) Total installed and dependable capacities of thermal IPPs at the end of June, 2015 are noted as 8,735 MW and 7,935 MW respectively, representing a ratio between dependable and installed capacities of 0.91. These capacities were 8,723 MW and 7,960 MW during June, 2014 representing a ratio of dependable and installed capacities as 0.912. The energy generated by thermal IPPs during the year 2014-15 is noted as 45,369 GWh, against 44,809 GWh during the year 2013-14.

It is also noted that due to certain disputes with NTDC/WAPDA, two IPPs namely Japan Power and SEPCOL are not contributing power to the grid and if these issues are properly addressed, approximately 270 MW will be added to the National Grid, which will help reduce the demand and supply gap of the system.

2.4.7 Installed versus Dependable Capacity The ratios between the dependable capacity and the installed capacity of the four GENCOs are also noted here:

Ratio of Dependable Capacity GENCO-I GENCO-II GENCO-III GENCO-IV and Installed Capacity (JPCL) (CPGCL) (NPGCL) (LPGCL) 2013-14 0.81 0.70 0.78 0.20 2014-15 0.81 0.80 0.80 0.20 Source: NEPRA

The ratios of dependable capacity and installed capacity for GENCOs and IPPs (indicated earlier) provide clear evidence about the manner in which the private and public sectors have been able to maintain their power plants. Whereas such ratios are more than 90% in both the years for IPPs, GENCO-I has a ratio of slightly more than 0.8, whereas ratios close to 0.8 have been achieved by GENCO-II and GENCO-III, only after new plants were added (Guddu 747 and Nandipur 425). The present state of GENCO-IV is evidence of typical public sector management failure, which has deprived the sector of a source of cheap power.

2.4.8 Manpower to MW Ratio The following table compares the ratio between the number of employees and MW installed in different power plants in Pakistan and other countries. It may be noted that only one plant in Bangladesh has comparable ratio with GENCO-II, whereas all other power plants have very low ratios of manpower per MW.

Capacity S. Installed Capacity No. of Manpower Power Plant Location Utilization No. (MW) Employees to MW ratio (%) 1 HUBCO Pakistan 1,292 300 0.232 64.48 2 KAPCO Pakistan 1,345 588 0.437 58.81 3 Lal Pir Power Pakistan 362 110 0.303 54.29 4 Pak. Gen. Power Pakistan 365 110 0.301 40.29 5 Tongi Power Bangladesh 105 98 0.933 --- 6 NTPC India 652 295 0.452 --- 7 MSEB India 912 277 0.303 --- 8 Power Gen. UK 700 33 0.047 --- 9 GENCO-I Pakistan 1,054 1,578 1.490 45.66 10 GENCO-II Pakistan 2,431 1,977 0.813 32.43 11 GENCO-III* Pakistan 1,921 2,634 1.370 38.44 12 GENCO-IV Pakistan 150 546 3.640 53.33 * Excluding Nandipur and Shahdara Power Plant and including NGPS Multan. Source: NEPRA, GENCOs

17 State of Industry Report 2015

2.5 Nuclear (CHASNUPP-I and II) During the year 2014-15, total installed and dependable capacity of Nuclear power plants connected with NTDC's system, are noted as 650 MW and 615 MW respectively, which are the same for the year 2013-14. The energy generated by Nuclear power plants during the year 2014-15 stands at 5,006 GWh, which is an increase of 798 GWh over the energy during the year 2013-14. The overall performance of Nuclear power plants connected with NTDC's system has remained satisfactory during the year 2014-15 as no major outage is noted.

2.6 Wind During 2014-15, total installed capacity of wind power plants connected with NTDC's system, is noted as 256 MW, while, it was 106 MW during the year 2013-14. The installed capacity of wind power plants has increased by 150 MW during the year 2014-15 due to the addition of three wind based power plants (FWEL-I, FWEL-II and TGF) having capacity of 50 MW each. 459 GWh of energy has been generated by wind power plants during the 2014-15 against 263 GWh during the 2013-14.

2.7 Bagasse During 2014-15, three new bagasse based power plants (JDW-II, JDW-III and RYKML) have been connected with the NTDC's system having total installed capacity of 70 MW, while, there was no bagasse based generating facility during the year 2013-14. The energy generated by these power plants, during the 2014-15 is noted as 308 GWh.

2.8 Solar During 2014-15, 100 MW of first solar power project (Quaid-e-Azam Solar) has been added to the NTDC's system, contributing 28 GWh.

2.9 K-Electric Limited As for K-Electric Limited, the Implementation Agreement (IA) and the Amended Implementation Agreement (AIA) put binding requirements on it to make certain investment for refurbishment and development of generation, transmission and distribution sectors. It is noted that K-Electric was required to enhance its generation capacity by 1000 MW over the capacity indicated in its Generation Licence. K-Electric has added the following facilities to its Generation capacity:

Name of Commissioned Plants Capacity (MW) Year Korangi Combined Cycle Power Plant (KCCPP) 220.00 2009 Gas Engines at Korangi 97.31 2013 Gas Engines at SITE 97.31 2013 CCPP at Bin Qasim 572.67 2013 Steam Turbine at KCCPP 27.50 2015 Steam Turbine at Gas Engines at Korangi 10.00 2015 Steam Turbine at Gas Engines at SITE 10.00 2015 Total 1,034.79 Source: K-Electric Limited

18 State of Industry Report 2015

However, at the same time, K-Electric also retired or permanently closed following power plants:

Name of Retired or Closed Plants Capacity (MW) Year Korangi Thermal Power Station (Unit 4) 125 2013 Korangi Town Gas Turbines Power Station (Units 1, 2 & 4) 75 2013 SITE Gas Turbines Power Station (Units 1, 3, 4 & 5) 100 2013 Korangi Thermal Power Station (Unit 3) 125 2015 Korangi Town Gas Turbines Power Station (Unit 3) 25 2015 SITE Gas Turbine Power Station (Unit 2) 25 2015 Bin Qaim Unit 4 (closed) 210 2012 Total 685 Source: K-Electric Limited

Therefore, effectively about 349 MW has been added by K-Electric considering retirement and permanent closure of its generation facilities. Since K-Electric is responsible for maintaining integrated systems of generation, transmission and distribution, therefore shortage of generation capacity is not helpful in overcoming supply and demand gap. Inability of K-Electric to effectively increase its generation capacity has made it dependent on external power sources, including the import from NTDC system. To meet demand, it has to operate its generation facilities and other resources specifically 650 MW from NTDC at their maximum. It may also be noted that the contract of power supply between NTDC and K-Electric has already expired, however, the power is still being imported out of necessity.

19 State of Industry Report 2015

PERFORMANCE OF TRANSMISSION SECTOR

20 PERFORMANCE OF TRANSMISSION SECTOR 3

State of Industry Report 2015

3. PERFORMANCE OF TRANSMISSION SECTOR

3.1 General The transmission line network of NTDC includes 5,197 km long transmission lines operating at 500 kV level and 9,814 km long 220 kV lines. The power generation plants connected at high voltage levels are summarized here:

Voltage Level 500 kV 220 kV 132 kV Total Installed Capacity (MW) 6,948 9,625 6,172 22,745 Source: NTDC

As of 30th June 2015, NTDC is maintaining 13 No. 500 kV grid stations with a transformation capacity of 18,624 MVA. There are 33 No. 500/ 220 kV transformers and 28 No. 220/132 kV transformers installed at these grid stations. At 220 kV level there are 37 grid stations with a transformation capacity of 24,063 MVA. There are 101 No. 220/132 kV transformers installed at 220 kV and after inclusion of 28 No. 220/132 kV transformers installed at 500 kV grid stations, total 220/132 kV transformers come to 129.

3.2 Overloading of Existing Power Transformers As discussed earlier, the transmission system is critical for a reliable power supply to DISCOs. The following table shows overloaded (above 80%) transformers at 500 kV and 220 kV grid stations in different regions defined by NTDC. It is also noted that on average around 11,000 MW to 15,000 MW have been transmitted through these transformers in different months depending on the generation and electricity load demand. With increasing demand and more generation expected in the system as a result of upcoming projects, the overloading of below noted transformers would also increase in future years.

A. Over Loading of 500 kV and 220 kV Transformers at 500 kV Grid Stations:

(above 80%)

Continued..... 23 State of Industry Report 2015

(above 80%)

Source: NTDC

B. Over Loading of 220 kV Transformers at 220 kV Grid Stations

(above 80%)

Continued.....

24 State of Industry Report 2015

(above 80%)

Continued..... 25 State of Industry Report 2015

(above 80%) T-1 220/132 160 700 660 94.29 Shikarpur T-2 220/132 160 700 640 91.43 T-3 220/132 160 700 640 91.43 T.M.K . T-1 220/132 160 700 690 98.57 Road T-2 220/132 160 700 680 97.14 Khuzdar T-1 220/132 160 700 680 97.14

There are 13 No. 500 kV Grid Stations with 33 transformers at 500/220 kV level. Out of these 8 transformers are loaded above 80% of their rated capacity. Similarly, out of total 129 No. 220/132 kV transformers 90 transformers are overloaded representing around 70% overloading in the system.

3.3 Power Dispersal Constraints in Transmission Networks In addition to overloading of EHV transformers, constraints in power dispersal from certain major power plants and quality issues in NTDC's system have also been reported. As per information and data reported to NEPRA, following power plants faced evacuation problems due to transmission constraints.

3.3.1 Uch-II Power (Pvt.) Limited Uch-II is a low BTU Gas fired power plant having gross capacity of 404 MW and net capacity of 375.2 MW located at Dera Murad Jamali, District Naseerabad, Balochistan. It was planned to construct a 125 km long 220 kV double circuit twin bundle transmission line form Uch-II power plant to Sibbi substation for evacuation of power. The proposed transmission line was to pass through three (03) Districts of Balochistan Province (a) Naseerabad (b) Kachi and (c) Sibbi. In addition, a 500 kV grid station at Shikarpur was also to be constructed.

Due to non-fulfillment of contractual obligations by NTDC, Uch-II power plant is facing power dispersal problems, transmission system constraints and frequent tripping on EHV networks. The reasons for delay in completion of the transmission projects by NTDC are reportedly: (a) Late retendering, (b) Bad law and order situation in the area, (c) Security threats to Supervisory Engineers, Revenue Staff and Construction Crews and (d) Failure to start major construction activity on time.

3.3.2 Engro Powergen Qadirpur Limited Engro Powergen Qadirpur Limited (EPQL) is a combined cycle power plant having installed capacity of 226.52 MW with derated capacity of 223.8 MW located at Qadirpur, District Ghotki, Sindh. This plant is also facing the problem of low dispatch/part load operation due to limitation and constraints of auto-transformer at 500 kV Guddu Grid Station, which is reportedly resulting in a revenue loss of Rs. 80 million per year to the GoP.

3.3.3 Altern Energy Limited Altern Energy Limited (AEL) complex is facing frequent tripping due to over/under voltage from 66 kV WAPDA grid. Further during the year 2012-13 and 2013-14, AEL has experienced tripping 63 and 99 times respectively due to WAPDA grid failure resulting in generation loss of 1459.25 MWh and 1309.57 MWh respectively.

3.3.4 TNB Liberty Power Limited The power evacuation constraints confronted by the company are due to the tripping of grid system and other technical reasons of transmission lines.

3.3.5 Habibullah Coastal Power Company Limited The two major issues which have been faced by the generation facility resulting in non-optimal power evacuation are, gas curtailment during the winter months and low voltage on the power system.

3.3.6 Foundation Power Company (Daharki) Limited As per PPA signed between NTDC and FPCDL, the plant was to be connected with 220 kV New Rohri Grid, but due to delay in construction of 220 kV grid and transmission lines, the Daharki power complex was temporarily connected with 132 kV grid station Sadiqabad. NTDC constructed a temporary grid of 220/132 kV adjacent to

26 State of Industry Report 2015

FPCDL. FPCDL has experienced many tripping since commissioning due to the problems in transmission lines between Guddu and Sadiqabad. Later on, 220 kV New Rohri grid was commissioned and power dispersal was provided on both end, but still major part of power dispersal is through 132 kV Sadiqabad which is not an efficient solution.

3.3.7 Nishat Power Limited and Nishat Chunian Power Limited Both companies are facing power evacuation problems since commissioning due to constraints in LESCO grid system. The main problem is the constraint in the capacity of three feeders which connect Bhai Pheru and Sarfraz Nagar Grids. In case one line is out, the remaining two get overloaded and trip; leading to total shutdown of both Nishat Power Plants (400 MW) and supply failure at all the above mentioned grids due to disconnection from NPCC. As reported, Nishat Power has faced 14 such shutdowns during last 12 months. Similarly, Nishat Chunian has faced 45 shutdowns since commissioning of its plant.

3.4 Induction of New Generation Power Plants The following table provides yearly additions in the generation capacity as planned under different initiatives by the federal government and private sector:

Sr. Installed Commissioning Name of the Project Location No. Capacity (MW) Date Addition during Fiscal Year 2015-16 1 Sapphire Wind Power Company Limited Jhampir, Sindh 49.5 October, 2015 2 Appolo Solar Development Pakistan Lal Sohanra, Cholistan, 100 December, 2015 Limited (Zonergy) Punjab 3 Best Green Energy Pakistan Limited Lal Sohanra, Cholistan, 100 December, 2015 (Zonergy) Punjab 4 Crest Energy Pakistan Limited (Zonergy) Lal Sohanra, Cholistan, 100 December, 2016 Punjab 5 CHASNUPP-III Chashma, KPK 340 March, 2016 Addition during Fiscal Year 2016-17 6 Elbel Green Energy Pakistan Limited Lal Sohanra, Cholistan, 100 July, 2016 (Zonergy) Punjab 7 Flare Solar Development Pakistan Lal Sohanra, Cholistan, 100 July, 2016 Limited (Zonergy) Punjab 8 Golden Eye Solar Development Pakistan Lal Sohanra, Cholistan, 100 July, 2016 Limited (Zonergy) Punjab 9 Yunus Energy Limited Jhampir, Sindh 50 July, 2016 10 Metro Power Company Limited Jhampir, Sindh 50 July, 2016 11 Tenaga Generasi Limited Gharo/Bhambore/ 49.5 July, 2016 Kuttikun, Sindh 12 Gul Ahmed Energy Limited Jhampir, Sindh 50 July, 2016 13 Master Wind Energy Limited Jhampir, Sindh 49.5 July, 2016 14 HydroChina Dawood Power Limited Gharo/Bhambore/ 49.5 July, 2016 Kuttikun, Sindh 15 Tapal Wind Jhampir, Sindh 30 July, 2016 16 United Energy Pakistan Limited Jhampir, Sindh 99 July, 2016 17 Zephyr Power (Pvt.) Limited Gharo/Bhambore/ 50 July, 2016 Kuttikun, Sindh 18 Neelum Jhelum Hydel Nauseri/Muzaffarabad, 969 November, 2016 AJK 19 CHASNUPP-IV Chashma, KPK 340 December, 2016 20 High Flying Solar Development Pakistan Lal Sohanra, Cholistan, 100 January, 2017 Limited (Zonergy) Punjab 21 Indigo Solar Development Pakistan Lal Sohanra, Cholistan, 100 February, 2017 Limited (Zonergy) Punjab 22 King Rider Solar Development Pakistan Lal Sohanra, Cholistan, 100 February, 2017 Limited (Zonergy) Punjab 23 Tarbela 4th Ext. Project Tarbela, KPK 1,410 March, 2017 24 Patrind HPP Kunhar River, AJK 147 April, 2017 Continued.....

27 State of Industry Report 2015

Sr. Installed Commissioning Name of the Project Location No. Capacity (MW) Date 25 LNG Based Plants (Phase-I) Bhikki/Baloki, Punjab 2,400 April, 2017 26 Solar Power Plants near Chishtian Chishtian, Punjab 300 June, 2017 Addition during Fiscal Year 2017-18 27 Keyal Khwar Dasu District, KPK 128 October, 2017 28 Coal Plant at Sahiwal Sahiwal, Punjab 1,320 December, 2017 29 Port Qasim Power Plant Port Qasim Karachi, 1,320 December, 2017 Sindh 30 Engro Thar Coal (Unit-1) Thar, Sindh 330 December, 2017 31 Nooriabad Gas Plant Nooriabad ,Sindh 100 December, 2017 32 Hub Power Company Limited Hub, Balochistan 660 December, 2017 33 Other Wind Power Plants Jhampir/Gharo/Bhambore/ 973 December, 2017 Kuttikun, Sindh 34 Engro Thar Coal (Unit-2) Thar, Sindh 330 April, 2018 35 LNG Based Plants (Phase-II) Haveli Bahadur Shah, 1,200 April, 2018 Jhang, Punjab 36 Coal Plant at Salt Range Salt Range, Punjab 300 June, 2018 37 Tarbela 5th Ext. Project Tarbela, KPK 1,320 June, 2018 38 Hub Power Company Limited Hub, Balochistan 660 June, 2018 39 SSRL Thar, Sindh 1,320 June, 2018 Addition during Fiscal Year 2018-19 40 Golen Gol HPP Chitral, KPK 106 July, 2018 41 Siddiqsons Energy Limited Port Qasim, Sindh 350 June, 2019 42 Lucky Electric Power Company Ltd. Port Qasim, Sindh 660 June, 2019 43 Grange Holding Arifwala, Punjab 163 June, 2019 Addition during Fiscal Year 2019-20 44 CASA Cross Border 1,000 July, 2019 Interconnection 45 Gulpur Poonch River Poonch River/Gulpur, 100 October, 2019 AJK 46 TPS Jamshoro (Phase-1) Jamshoro, Sindh 660 December, 2019 47 TPS Jamshoro (Phase-2) Jamshoro, Sindh 660 March, 2020 48 Dasu HPP-1 7 km upstream of Dasu 2,160 June, 2020 Village on Indus River, KPK Addition during Fiscal Year 2020-21 49 Karachi Coastal Power Plant (Unit-1) Karachi, Sindh 1,100 August, 2020 50 Karachi Coastal Power Plant (Unit-2) Karachi, Sindh 1,100 June, 2021 Addition during Fiscal Year 2021-22 51 Suki Kinari HPP Kunhar River/ 840 September, 2021 Mansehra, KPK 52 Karot HPP Jehlum River, Distt. 720 June, 2022 Rawalpindi, Punjab 53 Kotli HPP Poonch River/Kotli, AJK 100 June, 2022 54 Azad Pattan HPP Jehlum River/Sudhnoti, AJK 640 June, 2022 55 Coal Plant at Lakhra Lakhra, Sindh 660 June, 2022 Source: NTDC

A summary of above additions is shown in the following table: (MW) 2015-16 2016-17 2017-18 2018-19 2019-20 2020-21 2021-22 Total Sindh 49.50 477.50 4,373 1,010 1,320 2,200 660 10,090 Punjab 300 3,300 2,820 163 0 0 720 8,303 Khyber Pakhtunkhwa 340 1,750 1,448 106 3,160 0 840 6,644 Balochistan 0 0 1,320 0 0 0 0 1,320 AJK 0 1,116 0 0 100 0 740 1,956 Total 689.50 6,643.50 9,961 1,279 4,580 2,200 2,960 28,313 Source: NTDC

28 State of Industry Report 2015

3.5 Future NTDC Network As discussed earlier new transmission lines and grid stations are essential for the new power generation projects which also include the projects proposed under the China-Pakistan Economic Corridor. NTDC has plans to strengthen its system and also add new transmission facilities to remove system constraints and to cater for the new power generation. The following figure shows NTDC's EHV transmission system planned up to year 2021-22.

29 State of Industry Report 2015

3.6 NTDC Financial Plans NTDC has also prepared its 5 years Investment Plan (2015-16 to 2019-20) for construction of new grid stations/ transmission lines and for augmentation and extension in its existing transmission networks as follows:

Financing Requirement for Five Year Plan Estimated Financing Financing S. Completion No. of Description Cost Arranged Required No. Year Projects Mil. Rs. Mil. US$ Mil. Rs. Mil. US$ Mil. Rs. Mil. US$ Short Term Plan 1 2015-16 22 94,249 1,174 89,419 1,127 4,830 47 (Ongoing Projects) Medium Term Plan 2 (Projects Ready for 2016-17 21 106,017 1,153 47,373 557 58,664 596 Implementation) Long Term Plan 3 (Future Development 2019-20 21 141,882 1,391 51,000 500 90,882 891 Projects) Total 64 342,148 3,718 187,792 2,184 154,356 1,534 Source: NTDC

Under short term projects, expected to complete in 2015-16, new transformation capacity, augmentation in transformation capacity and addition in transmission lines are planned as shown in the table here:

Voltage Level Addition in Transformation Capacity (MVA) Addition in S. No. (kV) New Augmentation Total Transmission Line (km) 1 500 4500 300 4800 549 2 220 6050 900 6950 687 Source: NTDC

The total estimated cost for above plan is US$ 1,174 million of which an amount of US$ 384 million has already been incurred. Under medium term projects, expected to complete in 2016-17, 1800 MVA and 3430 MVA of transformation capacity is to be added at 500 kV and 220 kV grid stations respectively. Further to that 1637 km and 426 km of 500 kV and 220 kV transmission lines respectively will also be added.

Under long term projects, to be completed by 2019-20, 4500 MVA transformation capacity at 500 kV and 6000 MVA at 220 kV grid stations are to be added. Addition of 1099 km at 500 kV and 543 km long 220 kV transmission lines is also be expected under long term plan for which US$ 500 million will be financed by the World Bank and JICA. Remaining financing requirement of US$ 891 million not yet arranged for long term plan. In addition to the plans up to 2019-20, funding will also be required in 2021-22 to meet minimum objectives of reliability, requiring all out efforts by the relevant agencies.

3.7 K-Electric Transmission System Based on the information provided by K-Electric, the year-wise status of Transmission lines and Grid stations is as follows:

Transmission Lines in km 2010-11 2011-12 2012-13 2013-14 2014-15 220 kV 321 321 323 323 323 Overhead Lines 132 kV 611 611 611 611 611 66 kV 149 149 149 149 149 220 kV 17 17 15 15 15 Underground Lines 132 kV 150 150 150 150 151 66 kV 0 0 0 0 0 Source: K-Electric Limited 30 State of Industry Report 2015

It may be noted that only 2 km of 220 kV overhead transmission lines have been added by K-Electric over the five years, whereas the underground 220 kV lines have been reduced by 2 km. Only 7 km of 132 overhead lines and 30 km of 132 kV underground lines have been added in 2010-11 whereas no further additions have been made over the remaining period till 2014-15 and only 1 km of underground line was added. No additions have been made in the 66 kV transmission network. The status of Grid Stations owned by K-Electric is as follows:

K-Electric owned Grid 2010-11 2011-12 2012-13 2013-14 2014-15 Stations No. MVA No. MVA No. MVA N0. MVA No. MVA 220 kV 7 3000 7 3000 7 3000 7 3000 7 3000 132 kV 50 n.p 51 n.p. 52 4611 53 4679 54 4732 66 kV 3 n.p. 3 n.p. 3 60 3 60 3 69 Source: K-Electric Limited

Reportedly, K-Electric has added/refurbished 4 grid stations of 132 kV whereas no transformation capacity has been added at 220 kV level over the 5-year period which stands at 3000 MVA.

31 State of Industry Report 2015

32 PERFORMANCE OF DISTRIBUTION SECTOR 4

State of Industry Report 2015 4. PERFORMANCE OF DISTRIBUTION SECTOR

4.1 Constraints in DISCOs’ System DISCOs have constraints in their network which restrict their ability to supply power from their 132 kV network to 11 kV system. Such constraints in DISCOs' system have taken the back seat up till now, however these are in fact more damaging as the generation capacity though available, is not being supplied to the end-consumers. The following table shows that except for two companies having less than 40% overloaded transformers the others have close to or more than 50% of total transformers overloaded (loaded above 80% of their rated capacity):

132 kV (As on 30th June, 2015) Total Capacity of Total No. of Total No. of Power No. of Power Transformers DISCOs Power Transformers Grid Stations Transformers Overloaded (Above 80%) (MVA) PESCO 67 176 4,559 95 TESCO 7 17 344 8 IESCO 78 168 4,048 65 GEPCO 52 149 3,800 78 LESCO 89 226 6,610 105 FESCO 62 146 3,984 95 MEPCO 96 201 5,106 131 HESCO 53 91 1,868 61 SEPCO 53 80 1,610 07 QESCO 58 118 2,597 63 Total 615 1,372 34,526 708 Source: DISCOs

At the 11 kV level the problem areas are more pronounced. In Khyber Pakhtunkhwa, more than 51%, of 11 kV feeders are overloaded. Similarly, more than 51% distribution transformers are also overloaded in Khyber Pakhtunkhwa. Such a state of affairs calls for immediate attention of the management of the DISCOs and the relevant authorities at the federal level. The table below presents details in this respect:

11 kV Feeders Distribution Transformers No. of No. of No. of No. of Province 11 kV Over-Loaded % Distribution Over-Loaded % Feeders Feeders Transformers Transformers Punjab 5,291 1,465 27.59 441,932 57,672 13.05 Sindh 854 198 23.18 71,555 8,961 12.52 Khyber Pakhtunkhwa 1,029 526 51.12 75,280 38,792 51.53 Balochistan 570 85 14.91 51,886 8,282 15.96 Total 7,744 2,274 29.36 640,653 113,707 17.75 Source: DISCOs

4.2 Receivables of DISCOs The overall receivables of DISCOs at the end of June, 2015 increased by Rs. 120 billion over the previous year. it is noted that apart from Federal Government and agriculture tube wells in Balochistan which show a reduction of around Rs. 0.7 billion and Rs. 0.2 billion respectively, receivables from other areas increased. As on 30th June, 2015 the overall distribution sector receivables stood at Rs. 633 billion (including Rs. 43.97 billion pertaining to K-Electric) as shown in the following table:

35 State of Industry Report 2015

Break-up of Receivables of DISCOs Financial Year ended June, 2015 (Rs. in Billion) Receivables July, 2014 Receivables S. Category (FY ended to June, 2015 (FY ended No. June, 2014) Billing Collection June, 2015) 1 FEDERAL GOVERNMENT a) Federal Governments Departments 0.431 12.207 12.487 0.145 b) Local Bodies under Federal Government 2.344 4.391 5.002 1.730 c) Autonomous Bodies under Fed. Govt. 1.488 6.392 6.284 1.579 d) Defence 0.082 15.855 15.946 -0.043 e) W&P 1.753 1.437 1.270 1.922 Total Federal Government 6.098 40.282 40.989 5.333 2 AJ&K GOVERNMENT i) GoP Share 0.402 - - 0.402 ii) DISCOs Share -0.004 - - -0.004 iii) AJ&K Share 37.571 18.732 3.579 52.725 Total AJ&K 37.969 18.732 3.579 53.123 3 PROVINCIAL GOVT. DEPTTS./AGENCIES a) Punjab 2.906 19.558 19.036 3.46 b) Khyber Pakhtunkhwa 19.851 6.220 6.389 19.715 c) Sindh 56.341 23.086 13.267 66.210 d) Balochistan 5.882 4.169 2.374 7.704 Total Provincial Govt. Deptts./Agencies 84.980 53.033 41.066 97.089 TOTAL (1 TO 3) 129.047 112.047 85.634 155.545 4 FATA (DOMESTIC CONSUMERS) 34.248 12.947 10.106 37.089 5 AGRICULTURAL TUBEWELLS IN BALOCHISTAN i) GoP Share excluding GST subsidy 5.860 3.072 4.000 4.932 ii) GOB Share 2.068 4.609 3.908 2.768 Total Agri. Tubewells in Balochistan 7.928 7.681 7.908 7.700 6 PRIVATE 313.454 829.053 753.859 388.793 7 IPPS 0.028 0.619 0.629 0.018 8 KARACHI ELECTRIC LIMITED 28.204 51.572 36.000 43.974 GRAND TOTAL (3+4+5+6+7+8) 512.909 1013.919 894.136 633.119 Source: PEPCO

4.3 Transmission and Distribution (T&D) Losses of DISCOs DISCOs' losses remained almost at the same level as for previous year, rather a number of DISCOs have reported higher losses than earlier years.

DISCOs' Losses (2014-15) PESCO TESCO IESCO GEPCO LESCO FESCO MEPCO HESCO SEPCO QESCO Targets set by 26.00 22.31 9.44 9.98 11.75 9.50 15.00 20.50 27.50 17.50 the Authority (%) Actual Results of 34.81 21.68 9.41 10.72 14.10 11.03 15.50 27.08 38.29 23.10 DISCOs (%) Source: NEPRA/DISCOs

36 State of Industry Report 2015

Adding further to T&D losses is the low recovery ratio of DISCOs. The Authority assessed a recovery target of 100% while setting the consumer tariff for DISCOs, however as per information the actual level of recovery remained around 89.16% for the financial year 2014-15.

4.4 Circular Debt Circular debt is still a major issue confronting power sector. One of the contributors of circular debt remained high transmission and distribution losses in DISCOs. Based on the currently notified consumer-end tariff of (10th June, 2015), if DISCOs fail to show any improvement in their actual level of losses, the impact of missing the Authority’s set T&D loss target would result in an annual gap of Rs. 41 billion. It is pertinent to mention that the Authority has set an average loss target of 15.29% for the financial year 2014-15, whereas DISCOs' reported losses for the same period remained around 18.73%.

4.5 Tariff Differential Subsidy GoP is providing Tariff Differential Subsidy (TDS), primarily to the agriculture and residential class of consumers, having consumption of up to 300 units. The GoP intends to decrease the gap between NEPRA determined consumer-end tariff and the GoP notified tariff through imposition of Tariff Rationalization Surcharge on some categories of consumers of different DISCOs so that its burden in the shape of TDS is reduced. Without such surcharge, the TDS requirement would have been Rs. 135 billion, which with the tariff rationalization surcharge would be limited to Rs. 65 billion.

4.6 Constraints in K-Electric System According to K-Electric, there are a total of 1,431 feeders (11 kV) for supplying electricity to its consumers as summarized in the following table:

Sept. Year 2008-09 2009-10 2010-11 2011-12 2012-13 2013-14 2014-15 Total 2008 Addition --- 88 93 74 35 20 47 53 410 per year Total 1,021 1,109 1,202 1,276 1,311 1,331 1,378 1,431 Feeders Source: K-Electric

The record shows that K-Electric has generally supplied around 2100 to 2200 MW to its transmission and distribution network. Supplying more than above power through the system this June to meet increased load demand, has brought the constraints in its system to fore with increased tripping of grids, overloading of power transformers, damage to Pole Mounted Transformers and fire incidents in the grid stations. Such behavior of the underlying network directly points to inadequacy of its transmission and distribution systems as these could not support the supply of additional power from generation plants. The Authority attributes this as a failure of K-Electric to timely plan, strengthen and construct its transmission and distribution networks so that reliable power supply is ensured.

4.7 Uploading of Performance Reports submitted by DISCOs and K-Electric on Quarterly Basis on Website The Authority decided that all DISCOs and K-Electric will upload their Performance Reports on their website, on quarterly basis for awareness and information of all stakeholders and to fulfill the requirements of donor agencies. Some of the DISCOs have initiated uploading of their data however the data uploaded in its present form is not relevant to the needs of the stakeholders and the Regulator.

4.8 Legal Proceedings against DISCOs and K-Electric due to non-compliance of Performance Standards (Distribution) Rules, (PSDR) 2005 Legal proceedings in the form of explanation and Show Cause Notices were initiated against all DISCOs and K-Electric due to non-compliance of PSDR, 2005. Accordingly, hearings in the matter were conducted, wherein, DISCOs were called to justify their position in respect of non-compliance of Distribution Standards.

37 State of Industry Report 2015

38 INITIATIVES BY NEPRA 5

State of Industry Report 2015 5. INITIATIVES BY NEPRA

NEPRA undertook following initiatives to facilitate setting up of new power plants of various technologies:

5.1 Upfront Tariff for Wind Power Projects NEPRA announced Upfront Tariff for Wind Power Projects which drew considerable interest of investors. Fourteen companies, with cumulative of 1128.70 MW, opted for Upfront Tariff for Wind Power Projects announced on 24th April, 2013. Three cases, 549.20 MW, were processed during the year under review. However, eight companies, having aggregate installed capacity of 430.30 MW, were able to achieve financial close within the specified deadline of 31st March, 2015.

Upon expiry of the validity period of the previous Upfront Tariff, the Authority in exercise of its powers under the Act, Rules and Regulations decided to initiate proceedings for determination of new Upfront Tariff for generation of electricity from wind. A Public Hearing was held on 16th April, 2015 which was attended by the Alternative Energy Development Board, Planning Commission, Government of Sindh, Project Developers, Turbine Suppliers, and various other stakeholders. After detailed deliberations, Upfront Tariff, determined afresh, was issued on 24th June, 2015. Following levelized Upfront Tariff was determined:

Year Tariff (with 100% Foreign Debt) Tariff (with 100% Local Debt) (Rs./kWh) (US cents/kWh) (Rs./kWh) (US cents/kWh) 1-10 Years 12.4782 12.2938 15.3226 15.0962 11-20 Years 5.7458 5.6609 5.9208 5.8333 Levelized 10.6048 10.4481 12.7064 12.5186 Source: NEPRA

5.2 Upfront Tariff for New Bagasse based Co-Generation Power Projects In order to facilitate co-generation power projects, NEPRA announced Upfront Tariff for new bagasse based co- generation power projects on 29th May, 2013 which was subsequently modified on 28th August, 2013.

Upon expiry of applicability period on 28th May, 2014, the Authority extended the validity of reference Upfront Tariff up to 28th May, 2015. The application for acceptance of Upfront Tariff filed by Hamza Sugar Mills Limited (15 MW) was processed and the decision was issued on 12th September, 2014.

5.3 Upfront Tariff for Coal Power Projects Induction of base-load power plants on relatively cheaper fuels has always been on top of the recommendations proposed by NEPRA. Therefore, for facilitating efforts of the Federal Government for bringing in large coal- based power plants, NEPRA announced Upfront Tariff for power plants on imported coal as well as coal at Thar, having one of the largest reserves of lignite in the world, which is specific for investors in using Thar Coal by offering them relatively more attractive terms.

The Authority announced the following Upfront Tariffs for imported/local coal based power plants on 26th June, 2014 for various categories for 30 years which was notified vide SRO No. 942(I)/2014 dated 5th October, 2014:

Levelized Tariff (US Cents/kWh) Capacity (MW) Local Financing Foreign Financing Local Imported Local Imported 220 9.2978 9.6774 8.2537 8.6417 350 9.2759 9.6240 8.1784 8.5353 660 9.2100 9.5422 8.0116 8.3601 1100 8.7897 9.1198 7.6738 8.0189 Source: NEPRA

41 State of Industry Report 2015

Various companies have unconditionally accepted the Upfront Tariff for Coal announced on 26th June, 2014 including Grange Power Limited (150 MW), Port Qasim Electric Power Company (Pvt.) Limited (2x660 MW), Huaneng Shandong Ruyi (Pakistan) Energy (Pvt.) Limited (2x660 MW), Lucky Electric Power Company Limited (660 MW) and Siddiqsons Energy Limited (350 MW).

The Authority announced following Upfront Tariffs based on Thar Coal on 9th July, 2014 for various categories for 30 years, notified vide SRO No. 51(I)/2015 dated 20th January, 2015:

Levelized Tariff (US Cents/kWh) Capacity (MW) Local Financing Foreign Financing 330 9.5643 8.5015 660 9.5668 8.3341 1100 9.1368 7.9889 Source: NEPRA

The Engro Powergen Thar (Pvt.) Limited unconditionally accepted the Upfront Tariff for Coal.

5.4 Tariff for Conversion of Oil to Coal Projects The Authority has approved the following tariff for coal conversion of existing RFO based Power Plants:

Capacity Levelized Tariff S. No. Company (MW) (US Cents/kWh) 1 Lal Pir Power Limited 362 7.2087 2 Pak. Gen. Power Limited 365 7.1672 3 Saba Power Company (Pvt.) Limited 136 7.8919 Total Net Capacity 863 Source: NEPRA

5.5 Upfront Tariff for Solar Power Projects NEPRA also approved Upfront Tariff for Solar Power Projects during the year for various categories for 25 years which was notified vide SRO No. 183(I)/2015 dated 3rd March, 2015:

Levelized Tariff (US Cents/kWh) Capacity (MW) North Region South Region >1≤20 MW 15.0279 14.4096 >20≤50 MW 14.8953 14.2825 >50≤100 MW 14.7588 14.1516 Source: NEPRA

Several companies unconditionally accepted the Upfront Solar Tariff announced on 22nd January, 2015. These included Quaid-e-Azam Solar Power (Pvt.) Limited, Appolo Solar Development Pakistan, Best Green Energy Pakistan Limited and Crest Energy Pakistan Limited with installed capacity of 100 MW each.

5.6 Upfront Tariff for Small Hydropower Projects NEPRA determined the generation tariff in matter of upfront tariff for Small Hydropower Generation Projects upto 25 MW installed capacity on 2nd April, 2015:

42 State of Industry Report 2015 100% Foreign Financing 100% Local Financing Levelized Tariff (Rs./kWh) (Rs./kWh) Low Head (1-25 MW) 8.3194 10.8941 High Head (1-25 MW) 7.6177 9.9960 Source: NEPRA

5.7 Upfront Tariff for LNG based Power Projects The Authority announced the following Upfront Tariffs on 3rd April, 2015 for various categories of LNG based new power projects for 30 years:

Levelized Tariff (US Cents/kWh) Capacity (MW) Local Financing Foreign Financing LNG HSD LNG HSD 225 10.5541 16.8757 10.1767 16.4983 400 9.9604 15.7785 9.5392 15.3572 800 9.7797 15.5099 9.3628 15.0930 Source: NEPRA

5.8 Tariff for Short-Term IPPs NEPRA determined the generation tariff in the matter of utilization of existing available generation capacity Policy for Short Term IPP’s on 7th April, 2015. Reshma Power and Gulf Power unconditionally accepted the upfront tariff for Short-Term IPPs:

Year 1 Year 2 Year 3 Tariff (Rs./kWh) 11.2799 11.2799 11.2799 Source: NEPRA

5.9 Development of NEPRA (Alternative and Renewable Energy) Distributed Generation and Net Metering Regulations, 2015 In order to encourage and promote renewable energy in Pakistan, specifically solar and wind, the Authority decided to look into the possibility of introducing net metering at the consumer level. Accordingly, an initial draft document of NEPRA (Alternative & Renewable Energy) Distributed Generation and Net Metering Regulations was prepared and uploaded on NEPRA website seeking comments from all concerned stakeholders.

After analyzing the comments of stakeholders, a revised document of NEPRA (Alternative & Renewable Energy) Distributed Generation and Net Metering Regulations was prepared which was approved by the Authority for notification.

5.10 Integrated Generation, Transmission and Distribution Plans (IGTDPs)

5.10.1 Development of IGTDPs Development of IGTDP was initiated to satisfy provisions under:

5.10.1.1 Section 31 (Tariff Setting) and Section 32 (Investment and Power Acquisition Programs) of the NEPRA Act, 1997.

5.10.1.2 NEPRA Tariff (Standards and Procedure) Rules, 1998.

5.10.1.3 Multi-year Tariff Setting for DISCOs under Federal Government’s National Power Policy, 2013.

5.10.1.4 National Tariff and Subsidy Policy, 2014 (Distribution Margin/Charges Determination and Expansion Plans).

5.10.1.5 Part–VI (Annual Tariff Methodology), Section 4 of NEPRA Tariff Methodology Guidelines, 2015. 43 State of Industry Report 2015

Major objective of IGTDPs is planning of power sector in a coordinated and integrated manner by taking into account NTDC’s expansion plan and investment plan. IGTDP also requires integration with generation projects currently under completion and future generation projects to be initiated under the Power Policy, 2013.

NEPRA Tariff Methodology Guidelines, 2015 require an integrated planning process for power sector. In order to comply with NEPRA Guidelines, Power Policy, 2013 and National Tariff and Subsidy Policy 2014, the Ministry of Water and Power directed all DISCOs and NTDC to submit their IGTDPs to NEPRA.

5.10.2 .Evaluation/Review of IGTDPs by NEPRA The following observations were noted while reviewing the IGTDPs of DISCOs:

5.10.2.1 The IGTDPs have been prepared based on a Power Market Survey (PMS) which was carried out in 2012-13 and the same has been added without updating the assumptions under the present scenario.

5.10.2.2 The yearly investments have been proposed without discussing the base-line conditions and the reasons for such base-line conditions. The documents assume that the performance indices as provided by the DISCOs to NEPRA as part of their Annual Reports are not true reflection of their performance therefore using these would not provide the true results.

5.10.2.3 Detailed analysis has not been carried out for the whole network. Top-Down approach has been used and load-flow studies have been carried out to develop expansion plans for 132 kV network which is then translated to lower voltage expansions.

5.10.2.4 Detailed analysis about 11 kV and below system is missing. This approach totally fails to point out the issues at the 11 kV and lower levels.

5.10.2.5 The present approach is based only on estimating future growth of load demand and assuming that expansion based on the simulation studies would by itself take care of different problems.

5.10.2.6 No analysis has been carried out to back up the proposed improvement in Performance Standard Indices. Similarly, no supporting data has been included to justify reduction in Transmission and Distribution losses.

5.10.2.7 The benefit to cost ratios and payback period calculations are based on the simulation studies without linking those to the investment made by the companies over the previous years and whether DISCOs demonstrated to achieve such savings.

5.10.3 .Recommendations for Resubmission of IGTDPs In view of the above observations the IGTDPs submitted by the DISCOs were not accepted. The DISCOs were advised to follow the following guidelines for the preparation of their IGTDPs and resubmit the same for approval:

5.10.3.1 Identify base line conditions in respect of every feeder and every sub-division including technical losses, NEPRA’s Performance Standard Indices and voltage profiles in the area.

5.10.3.2 Recommend concrete proposals for improvement in relevant sub-division which are achievable as-well as measurable. For achieving the desired objectives, categorize the expansion schemes to include improvement in metering system, event recording, network digitization, loss reduction and so on.

5.10.3.3 Expansion due to increased demand is only one of the factors. DISCOs are also required to electrify villages every year which on one hand may not be financially viable and would certainly lead to more losses. It is important to include such schemes for review of the Regulator. 44 State of Industry Report 2015

5.10.3.4 Power Market Survey (PMS) needs to be updated and load growth is also required to be mapped at the sub-division level. The load flow studies will provide the basis for expansion in the 132 kV system along with allied substations.

5.10.3.5 The expansion plans need to be linked with the least cost expansion plan which is missing in the current DISCOs submission.

5.10.4 .Final Guidelines and Formats to Develop IGTDPs by NEPRA A full round of exercises (Workshops and Consultative Meetings) was conducted with USAID (as Consultant), NTDC and DISCOs in June, 2015. Finalized guidelines and associated formats have also been delivered to the licensees for preparation and resubmission of IGTDPs in an appropriate manner within stipulated time period.

5.11 Special Purpose Transmission Licence (SPTL) under Section 19 of NEPRA Act (Special Transmission Facilities for Private Entities) Under Section 19 of the Act, the Authority granted a SPTL to a private entity to engage in construction, ownership, maintenance and operation of specific transmission facilities (66 kV and above) built for provision of transmission and interconnection services to NTDC and others (such as BPCs) by connecting its facilities at transmission and distribution networks.

5.12 Development of NEPRA Interconnection Guidelines, 2015 As per requirement under clause 8.2.1 Guaranteed Market, Mandatory Purchase of Electricity of the Policy for Development of Renewable Energy (RE) for Power Generation 2006, it is mandatory for the DISCO(s) to buy all the electricity offered to them by the RE projects.

Similarly, clause 6.1 Point of Delivery of the Policy for Power Generation Projects 2002 provides different options for construction, maintenance and operations of the lines for power dispersal from power plants to point of delivery. Queries were however raised by the stakeholders about the maximum distance and voltage levels on which such projects were required to be connected. RE Policy 2006 and NEPRA Grid Code 2005 provided some of the relevant information; however, the same was not interpreted in a consistent manner.

NEPRA had already issued NEPRA (Sale of Electric Power by Renewable Energy Companies) Guidelines, 2015 which assign and clarify the responsibility of DISCO(s) and Transmission Company about procurement of power.

In addition of the above guidelines, NEPRA formulated the interconnection guidelines which provide a unified approach about construction of interconnection facilities with the networks of NTDC and DISCOs.

45 State of Industry Report 2015

46 MONITORING OF THE SECTOR 6

State of Industry Report 2015 6. MONITORING OF THE SECTOR

6.1 Visits of DISCOs to Verify/Inspect the Sanctioned Load vis-a-vis Connected Load During the reported period, NEPRA professionals visited different DISCOs for verification of the sanctioned load viz-a-viz connected load of consumers for analyzing tripping and overloading position of DISCOs’ system:

So far, GEPCO, MEPCO, HESCO, SEPCO, LESCO, QESCO and PESCO have been visited and meetings with management of DISCOs were held. Power Distribution Centers were also visited for examining their demand, supply and load shedding plans.

Inquiries were also conducted about overloading of transformers, feeders and increased number of interruptions. Random inspection of load of a small sample of consumers (11 kV and 440 V) was also carried out. It was observed that:

6.1.1 The connected/running load of most of the consumers inspected under domestic, commercial and industrial B-2 consumers is more than their sanctioned load. Whereas, no action in form of issuing notices or extending the load has been taken by DISCOs.

6.1.2 A number of Transformers inspected were loaded from 80% to 100% due to which frequent tripping occur.

6.1.3 11 kV metering rooms inspected were found in poor conditions, having inadequate protection (relay) system.

6.1.4 Certain lines and Poles were also found in poor condition which lead to increasing number of interruptions.

6.2 Real Time Monitoring In order to have improved access to data about the functioning of the sector, a real time monitoring of total power generation in Pakistan, power demand by DISCOs, allocation of power quota and load shedding plans will be started shortly, enabling NEPRA for effective evaluation of the performance of its licensees.

6.3 Undue Scheduled/Unscheduled Load Shedding by K-Electric The Authority noted that undue scheduled/unscheduled load shedding during the recent heat wave in 2015 was carried out by K-Electric. In this regard, the Authority, in order to determine the veracity of data and implementation of Performance Standards, constituted a team which visited K-Electric, wherein, same of its grids were also checked and field surveys were conducted. During the visit, certain grid stations of K-Electric were found in poor conditions lacking proper maintenance.

6.4 Safety Record of Distribution Companies The safety aspect is considered as one of the most important parameters for judging DISCOs' performance. The following table shows that except for LESCO and SEPCO the number of safety incidents increased from last year. DISCOs will be asked to explain their position in this matter.

49 State of Industry Report 2015

Number of Safety Accidents for both Employees and Public DISCOs/Years 2010-11 2011-12 2012-13 2013-14 2014-15 PESCO 19 25 25 20 29 IESCO 19 15 10 12 15 GEPCO 9 11 10 12 15 LESCO 25 29 14 35 24 FESCO 32 22 26 29 29 MEPCO 21 14 12 17 34 HESCO 46 26 7 14 22 SEPCO - 3 3 45 34 QESCO 20 16 07 02 20 K-Electric 26 14 9 5 4 Source: DISCOs

DISCO-wise Number of Safety Accidents 50

45

40

35

30

25

20

15

10

5

0 PESCO IESCO GEPCO LESCO FESCO MEPCO HESCO SEPCO QESCO K-Electric

2010-11 2011-12 2012-13 2013-14 2014-15

6.5 Annual Performance Report (APR) of NTDC As per requirements of Rule 9 of Performance Standards (Transmission) Rules (PSTR) 2005, APRs submitted by both NTDC and K-Electric for 2014-15, were analyzed and a comprehensive Performance Evaluation Report (PER) was prepared. As per PSTR, 2005 a comparison was made for each of the evaluated parameter for the last five years i.e. from 2010-11 to 2014-15.

APR of NTDC for the year 2014-15 indicates variation in voltage limits beyond the permissible limits of ±5% (Normal Condition) and ±10% (N-1 Condition) of nominal voltage. Such deviations of NTDC from the permissible voltage limits reveal the voltage profile for 220 kV Sibbi and Khuzdar Grid Stations remained as low as 180 kV and 185 kV respectively under normal conditions. Further, voltage limits violations show an increase of 6.2% as compared to 2013-14. It is noted that during 2014-15, most of the circuits of NTDC have not complied with the voltage limits as mentioned in PSTR, 2005. NEPRA would initiate necessary proceedings on the performance of NTDC under applicable documents.

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6.5.1 Number of Voltage Variations (Violating Prescribed Criteria) The performance indicator for NTDC with a region-wise breakup is shown as follows:

Condition Region 2010-11 2011-12 2012-13 2013-14 2014-15 Islamabad 14,081 13,413 24,065 22,539 30,165 Lahore 20,570 44,172 57,363 55,990 68,552 Normal Multan 713 182 1,660 1,560 1,439 Hyderabad 17,014 20,754 26,347 43,973 28,958 Islamabad 4,677 1,788 3,215 2,906 1,914 Lahore 1,878 5,980 7,730 11,545 11,684 N-1 Multan ‒ ‒ ‒ 12 ‒ Hyderabad 5,770 6,241 9,666 2,087 6,669 Total NTDC (Normal) 52,378 78,521 109,435 124,062 129,114 Total NTDC (N-1) 12,325 14,009 20,611 16,550 20,267 Total NTDC (Normal & N-1) 64,703 92,530 130,046 140,612 149,381 Source: NTDC

Region-wise Voltage Variations Violating Prescribed Criteria [Nos.] 150,000 125,000 100,000 75,000 50,000 25,000 0

2010-11 2011-12 2012-13 2013-14 2014-15

The region wise details of voltage variations along with a comparison for the preceding years are shown as follows:

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A. Islamabad Region (Total Number of Violations) S. No. Grid Station 2010-11 2011-12 2012-13 2013-14 2014-15 1 500 kV Rawat 611 3,749 7,473 7,242 9,376 2 500 kV Peshawar 1,108 1,521 3,807 335 2,538 3 220 kV Bannu 5,388 473 502 3,381 3,413 4 220 kV Burhan 76 8 30 73 422 5 220 kV Daud Khel 4,725 3,132 4,642 4,863 8,714 6 220 kV ISPR 27 77 13 19 9 7 220 kV Mardan 4,189 4,535 5,161 5,328 4,653 8 220 kV Shahi Bagh 2,100 1,288 4,975 3,840 1,991 9 220 kV University 534 418 677 364 963 Total 18,758 15,201 27,280 25,445 32,079 Source: NTDC

B. Lahore Region (Total Number of Violations) S. No. Grid Station 2010-11 2011-12 2012-13 2013-14 2014-15 1 500 kV Gatti 294 416 789 335 1,189 2 500 kV Nokhar – – – – – 3 500 kV Sheikhupura 78 621 75 78 4,837 4 220 kV Bund Road 707 325 3,035 4,574 4,031 5 220 kV Gakkhar 2,946 1,445 1,639 902 997 6 220 kV Jaranwala 70 19 222 303 278 7 220 kV Kala Shah Kaku 3,995 5,014 8,863 9,114 10,410 8 220 kV Ludewala 1,441 468 646 543 442 9 220 kV Nishatabad 148 0 0 0 20 10 220 kV NKLP 6,937 26,528 28,037 26,251 22,707 11 220 kV Ravi 3,192 7,070 13,756 14,693 19,209 12 220 kV Samundri Road – 24 204 556 1,160 13 220 kV Sarfaraz Nagar 1,317 3,752 3,806 4,636 3,531 14 220 kV Sialkot 1,323 1,533 1,207 1,022 982 15 220 kV WAPDA Town – 2,937 2,814 3,216 4,976 16 220 kV Shalamar Commissioned/Energized on 05-03-2014 1,312 5,165 17 220 kV Ghazi Road Commissioned/Energized on 05-03-2014 61 18 220 kV Bandala Commissioned/Energized on 26-06-2014 – 19 220 kV T.T. Singh Commissioned/Energized on 28-06-2015 241 Total 22,448 50,152 65,093 67,535 80,236 Source: NTDC

52 State of Industry Report 2015

C. Multan Region (Total Number of Violations) S. No. Grid Station 2010-11 2011-12 2012-13 2013-14 2014-15 1 500 kV Multan 10 1 - 13 20 2 500 kV Muzaffar Garh - - - - - 3 500 kV Yousafwala - - 2 6 257 4 220 kV Bahawalpur 31 131 15 421 305 5 220 kV Muzaffar Garh 100 2 184 - 4 6 220 kV Vehari 572 48 1,459 1,132 764 7 220 kV Okara Commissioned/Energized on 30-06-2014 75 8 500 kV D.G. Khan Commissioned/Energized on 05-08-2014 14 9 220 kV Kassowal Commissioned/Energized on 15-07-2015 - Total 713 182 1,660 1,572 1,439 Source: NTDC

D. Hyderabad Region (Total Number of Violations) S. No. Grid Station 2010-11 2011-12 2012-13 2013-14 2014-15 1 500 kV Dadu 112 1,315 1,641 2,863 2,525 2 500 kV Guddu - - - 1,584 2,538 3 500 kV Jamshoro 1,375 673 1,925 1,744 2,112 4 500 kV NKI 2,337 3,884 2,738 4,596 5,389 5 220 kV Dharki 50 11 21 - - 6 220 kV Hala Road 2,624 206 1,086 2,570 162 7 220 kV Quetta 5,376 6,032 6,058 12,636 12,020 8 220 kV Rohri 15 14 330 182 1,060 9 220 kV Shikarpur 214 106 200 1,108 572 10 220 kV Sibbi 10,415 14,302 20,782 17,243 5,841 11 220 kV T.M. K. Road 266 452 1,232 1,534 946 12 220 kV Khuzdar Commissioned/Energized on 09-06-2014 & 24-08-2014 1,140 13 220 kV Loralai Commissioned/Energized on 05-08-2014 & 29-08-2014 1,322 Total 22,784 26,995 36,013 46,060 35,627 Source: NTDC

53 State of Industry Report 2015

6.5.2 System Frequency The data submitted by NTDC for 2014-15 indicates 1264 variation in frequency limits beyond the permissible limits of 49.50 Hertz and 50.50 Hertz. It is also noted that such variations in frequency limits ranged from 45 Hertz to 58.63 Hertz Prima facie contravening Rule 8 of the PSTR, 2005. The following tables and figures show the system frequency profile.

NTDC Highest System Frequency (2010-11 to 2014-15) Month 2010-11 2011-12 2012-13 2013-14 2014-15 July 50.54 50.56 50.48 50.20 50.71 August 50.53 50.48 50.52 50.31 50.68 September 50.56 50.44 50.56 50.22 50.55 October 50.43 50.44 50.45 50.35 50.69 November 50.44 50.56 50.40 50.30 50.62 December 50.39 50.48 50.40 50.28 58.63 January 50.40 50.44 50.21 50.70 54.69 February 50.40 50.36 50.10 50.63 -* March 50.48 50.48 50.34 50.63 50.65 April 50.44 50.40 50.30 50.68 50.66 May 50.50 50.44 50.26 50.60 50.69 June 50.48 50.48 50.23 50.57 50.68 * Value can’t be validated. Source: NTDC

54 State of Industry Report 2015

NTDC Lowest System Frequency (2010-11 to 2014-15) Month 2010-11 2011-12 2012-13 2013-14 2014-15 July 48.99 48.72 48.76 49.05 48.74 August 48.84 48.72 48.80 49.15 48.91 September 48.91 48.72 48.72 49.35 48.93 October 48.81 48.80 48.80 49.50 48.99 November 49.02 48.92 48.72 49.31 48.83 December 48.80 48.76 48.72 49.15 45.00 January 48.80 48.72 49.10 48.67 45.00 February 48.78 48.80 48.66 48.87 49.06 March 48.81 48.76 49.40 48.92 49.11 April 48.75 48.76 49.32 48.89 49.02 May 48.62 48.76 49.48 49.20 49.20 June 48.68 48.76 49.20 49.19 -* * Value can’t be validated. Source: NTDC

NTDC Lowest System Frequency

6.6 Annual Performance Report (APR) of K-Electric The data submitted by K-Electric in its APR for 2014-15 indicates variation in frequency limits number of times beyond the permissible limits of 49.50 Hertz and 50.50 Hertz. It was observed that in the month of July and November the minimum frequency limit was 48.97 Hertz and 48.94 Hertz respectively. Similarly, in the month of August and December the maximum frequency limit was 50.64 Hertz and 50.82 Hertz respectively. This data indicates, that K-Electric has not complied with the frequency limits which are permissible under NEPRA Performance Standards Transmission Rules (PSTR,) 2005. The following tables and figures show K-Electric system frequency profile along with a comparison with the preceding years.

55 State of Industry Report 2015

K-Electric Highest System Frequency (2010-11 to 2014-15) Month 2010-11 2011-12 2012-13 2013-14 2014-15 July 50.92 50.61 50.60 51.15 50.58 August 50.97 50.96 51.05 51.70 50.64 September 50.61 50.90 50.65 51.70 50.51 October 50.81 50.46 50.65 51.69 50.53 November 50.52 50.55 50.57 51.93 50.55 December 50.73 50.57 50.76 51.68 50.82 January 50.54 50.61 50.80 51.15 50.54 February 50.58 50.56 50.59 51.10 50.51 March 50.77 50.90 50.72 51.91 50.58 April 50.47 50.28 51.08 51.28 50.51 May 50.65 51.25 51.49 51.06 50.57 June 50.73 50.78 51.55 51.72 50.52 Source: K-Electric

KE Highest System Frequency 52.00

51.50

51.00

50.50

50.00

2010-11 2011-12 2012-13 2013-14 2014-15

K-Electric Lowest System Frequency (2010-11 to 2014-15) Month 2010-11 2011-12 2012-13 2013-14 2014-15 July 48.80 48.51 48.56 48.61 48.97 August 48.80 48.60 48.60 48.68 49.10 September 48.80 48.60 48.59 48.73 49.13 October 48.80 48.51 48.60 48.80 49.18 November 48.80 48.67 48.60 48.74 48.94 December 48.80 48.60 48.59 48.76 49.15 January 48.79 48.60 48.50 48.61 49.07 February 48.80 48.52 47.12 48.80 49.39 March 48.88 48.60 48.80 48.59 49.26 April 48.40 48.60 48.74 48.63 49.26 May 46.64 48.54 48.63 48.66 49.29 June 46.38 48.59 48.62 48.80 49.32 Source: K-Electric

56 State of Industry Report 2015

KE Lowest System Frequency 49.50 49.00 48.50 48.00 47.50 47.00 46.50 46.00

2010-11 2011-12 2012-13 2013-14 2014-15 Above statistics about voltage and frequency limits indicates that NTDC and K-Electric have failed to maintain their Transmission Lines and Grid Stations as required under NEPRA Rules, Licences and Codes. In view of above, explanations have been called from both the NTDC and K-Electric under Rule 4 (1) and (2) of the NEPRA (Fines) Rules, 2002.

6.7 Energy not served in KE System The following table and figures show the energy not served in the K-Electric system for the last five years i.e. from 2010-11 to 2014-15.

Year-wise Overall System Energy Not Served (MWh) S. No. Name of Circuit 2010-11 2011-12 2012-13 2013-14 2014-15 1 KDA - Federal B 0 218 0 172 91 2 KDA - Maymar 0 227 0 178 95 3 KDA - Gulshan 0 131 0 103 55 4 KDA - Johar 0 113 0 89 47 5 KDA - Memon Goth 0 183 0 144 77 6 Pipri - RECP 0 52 35 0 0 7 Pipri - BOC 0 39 26 0 0 8 Pipri - Port Qasim 0 96 64 0 0 9 Pipri - KEPZ 0 78 52 0 0 10 Pipri - Landhi 0 74 49 0 0 11 Pipri - Korangi Town 0 65 44 0 0 12 Pipri - Steel 1 0 15 10 0 0 13 Pipri - Steel 2 0 15 10 0 0 14 Korangi West - Defence 8 182 361 144 286 15 Korangi West - PRL 0 48 95 38 75 16 Korangi West - Gizri / Baloch 17 334 664 264 526 17 Korangi West - Korangi East 0 373 740 295 586 18 Korangi West - DHA 1 0 19 38 15 30 19 Queens Road - Elander Road 1 16 96 190 110 92 20 Queens Road - Elander Road 2 16 96 190 110 92 Continued..... 57 State of Industry Report 2015

Year-wise Overall System Energy Not Served (MWh) S. No. Name of Circuit 2010-11 2011-12 2012-13 2013-14 2014-15 21 Queens Road - Gizri 145 497 987 574 477 22 Queens Road - Clifton 41 707 1,405 817 679 23 Queens Road - Old Town 97 516 1,025 597 496 24 Mauripur - Haroonabad 1 468 704 49 631 342 25 Mauripur - Haroonabad 2 468 815 49 631 342 26 Baldia - Hub Chowki 7 51 30 56 32 27 Baldia - SGT 1 16 204 120 222 129 28 Baldia SGT - SITE 16 204 120 222 129 29 Baldia - Orangi 52 663 389 723 418 30 Baldia - Valika 43 578 339 630 364 31 ICI - PTA 0 - - - - Total 1,410 7,393 7,081 6,765 5,460 Source: K-Electric

6.8 Frequent Tripping of Transmission and Grid System in NTDC During the reported period, NTDC's investments and O&M expenditure over last five years were evaluated to know its priorities. Specifically, information was obtained to confirm that NTDC invested on those grids where heavy tripping occurred. The Authority has noted that NTDC could not prioritize its investment for improving those grids where tripping occurred last year.

These observations were sent, in the form of an advisory to the Ministry of Water and Power. NTDC was also asked to provide the details about its plans for the next cycle of foggy weather. NEPRA teams also visited NTDC's following grid stations of Islamabad Region to monitor the precautionary measures taken by NTDC in this regard:

220 kV Burhan Grid Station November 13, 2014 220 kV University Grid Station November 14, 2014 500 kV Rawat Grid Station November 14, 2014

58 State of Industry Report 2015

During visit, it was found that maintenance of lines and grids has not been taken as per their SOPs prepared by NTDC. It was also noted that there was no proper record mechanism and equipment were found in poor conditions.

Further, during the reported period, a major system disturbance occurred in January, 2015 due to tripping at 500 kV Guddu grid station followed by cascaded outages and system breakdown. Taking serious notice of the incident, NTDC/NPCC was asked by the Authority for detailed explanation. Based on the presentation, the concerns of the Authority were sent to Ministry of Water and Power and NTDC.

6.9 Handing Over of Switchyards of GENCOs to NTDC During the reported period, GENCO-III requested the Authority to allow its handing over of the switchyard of TPS, Muzaffargarh to NTDC as it has no expertise to maintain this grid. Based on the requirements under the Grid Code, the Authority decided that GENCO-III shall continue to maintain its own switchyard as the protection schemes of switchyards and grid stations are totally different.

6.10 Implementation of Performance Standards (Generation) Rules, (PSGR) 2009 The quarterly reports on Key Performance Indicators (KPIs) as per requirements of Performance Standards (Generation) Rules, 2009 have been collected from different generation companies i.e. public sector GENCOs, IPPs and hydel plants for the year 2013-14 and 2014-15, which are under analysis. During review, it has been observed that the data submitted by public sector GENCOs is inconsistent and does not meet the requirements of PSGR.

The submitted data by IPPs i.e. HUBCO, FKPCL, Foundation Power etc. was also analyzed and found that the performance of IPPs is relatively better than public sector GENCOs. However, there is also a need of training for awareness of PSGR, 2009. It was also found that non-availability of fuel is the main reason of the poor performance of IPPs. Similarly, analysis of hydel power stations like Tarbela, Mangla, Chashma, Ghazi Barotha is also being carried out.

It is important to note that the data about KPIs would be used for benchmarking their performance for using in the subsequent tariff determinations.

6.11 Implementation of Grid Code NTDC has created a “Grid Code Implementation Cell” to monitor compliance with various provisions of the Grid Code, as the Grid Code was approved by NEPRA in June, 2005 as an “Applicable Document”. NTDC is pursuing the administration/enforcement of various provisions of the Grid Code through Grid Code Cell of NTDC, and keeps NEPRA informed of its activities in this regard. During the reported period a number of meetings of Grid Code Review Panel were held to discuss Grid Code Addendum-I, Development of Grid Code Addendum-II for induction of Solar Power Plants, Development of Grid Code Addendum-III for Small Hydel Power Plants and Issue of Power Factor Range etc. The Authority approved Grid Code Addendum-II for integration of Solar Power Plants.

A major study is also being conducted by NTDC Grid Code Review Panel for setting up a maximum limit on the induction and absorption of renewable energy projects, specifically wind and solar so that there is no adverse effect on the operation and performance of National Grid. However, the delayed finalization of the study by NTDC is hindering further progress in this area.

6.12 Implementation of Distribution Code For addressing the matters related to Distribution Code, a workshop regarding implementation of Distribution Code (Establishment of Distribution Code Review Panel) (DCRP) was conducted by NEPRA in October, 2014 at Lahore. The purpose of establishing DCRP is to ensure implementation of Distribution Code in true letter and spirit. During workshop, following decisions were made:

6.12.1 Initially Chairman of DCRP will be from LESCO for a period of two (02) years with effect from 21st October, 2014.

59 State of Industry Report 2015

6.12.2 After two (02) years, next Chairman from other DISCOs will be on rotation basis on alphabetical order for a period of 01 year.

6.12.3 First meeting of the members of DCRP, will be arranged by LESCO before 30th of November, 2014.

6.12.4 The NTDC will provide proper support and guidance to LESCO, in the functioning/establishment of DCRP.

6.12.5 Website of DCRP will be established by LESCO and mechanism of feedback will also be given due consideration.

6.12.6 Initially Secretariat Support will also be provided by LESCO.

First meeting of the DCRP was held in February, 2015, wherein, concerns of DISCOs pertaining to interconnection issues of generators and upcoming solar and wind projects were discussed.

6.13 Development of Power Safety Code As per requirements of Distribution Code and Grid Code, all Licensees shall have comprehensive, NEPRA approved Power Safety Code in place and available at all times. Pursuant to instructions of the Authority, the first draft of Power Safety Code for Transmission and Distribution Licensees was uploaded on NEPRA’s website and sent to all the concerned stakeholders as well for their comments before finalizing it.

Based on the comments of stakeholders the Authority approved the Power Safety Code for Transmission and Distribution licensees on 8th July, 2015. The Authority also decided that LESCO and MEPCO will prepare a standard Draft Safety Manual in the light of approved Power Safety Code for Transmission and Distribution licensees to be adopted by other DISCOs as well. The Authority further directed NTDC for developing its Safety Manual for the approval of the Authority. The approved document noted above is also uploaded on NEPRA’s website.

Further, all the public sector GENCOs and IPPs have been directed to submit their safety manuals for consideration and approval of the Authority. Some of the IPPs have submitted their safety manuals which are under review.

60 INITIATIVES BY STAKEHOLDERS 7

State of Industry Report 2015

7. INITIATIVES BY STAKEHOLDERS

7.1 Market Structure The market structure envisaged by NEPRA has been outlined in the transmission licence granted to NTDC. The license stipulates a time frame for moving from a single-buyer mode to a competitive market mode. As indicated in earlier sections of report the bilateral market structure required creation and operation of a number of entities for which the Authority noted that progress towards a market structure has not been made as planned. A CPPA has been in operation, however its present role may not support the objectives of a competitive market. Therefore, there was an urgent need to review the present role of CPPA so that its functioning is more aligned to the overall objectives.

7.2 Creation of Central Power Purchasing Agency - Guarantee Limited (CPPA-G) In view of the above and for bringing transparency, promote corporate culture and keep check on circular debt, the Federal Government proposed for the separation the CPPA from NTDC to create an independent company named as Central Power Purchasing Agency - Guarantee Limited (CPPA-G).

The CPPA-G will be an independent company and shall be performing the function of settlement of dues of electricity between buyers and sellers. It is international best practice and imperative to separate the functions and business of settlement and development of competitive power market structure from the generation, transmission and distribution systems. The move is being said a major reform the power sector so a to achieve efficiency through transparent settlement of power sector dues and build industry standards to manage the power sector business.

7.3 Modification in Transmission Licence of NTDC Pursuant to Section 17 of Regulation of Generation, Transmission and Distribution of Electric Power Act, 1997 (XL of 1997) and subject to provisions of Section 7 (4) thereof, NEPRA granted Transmission Licence No. TL/01/2002 on 31st December, 2002 to NTDC for a period of 30 years valid upto 30th December, 2032.

NTDC sought a modification to the Article 7 and 8 of its Transmission Licence through a Licensee Proposed Modification (LPM) for separating the procurement of power on behalf of DISCOs and the settlement, from the network functions performed by NTDC. The administration and development of competitive power markets will also be among the functions of a separate corporate entity; CPPA-G.

It may be noted that CPPA under the umbrella of NTDC was foreseen as a transition measure before taking it out of NTDC, which has core functions of transmission network and system operation business.

NEPRA after following the due process under its law has approved modification in NTDC license and Federal Government is now in the process of transferring the agency functions (power procurement on behalf of DISCOs and the function of settlement, administration and development of competitive power market).

7.4 Market Operator Registration (Standards and Procedure) Rules, 2015 NEPRA has recently approved the Market Operator Registration (Standards and Procedure) Rules, 2015 to authorize CPPA-G as market operator which is responsible to commence and conduct the power market operations such as:

7.4.1 Financial and Organizational Affairs 7.4.2 Accounting Practices and Audit 7.4.3 Maintenance of Records

A preliminary design of power market along with timelines towards a competitive regime is also specified in the document that will substitute the existing single buyer arrangement in the sector.

63 State of Industry Report 2015

7.5 PPIB Policy for Private Sector Transmission Projects 2015 A large scale capacity additions in the electrical generation system are planned in the next few years which will necessitate corresponding augmentation in the transmission network. Due to the encouraging response of the private sector for investment in power generation and the constraints on public sector resources, the GoP has decided to solicit proposals from the private sector for investment in the field of AC and DC Extra High Voltage (EHV) Power Transmission Lines, Substations, and Converter Stations.

7.6 Central Asia-South Asia (CASA-1000) Project The CASA 1000 project is a comprehensive initiative to interconnect Tajikistan, the Kyrgyz Republic, Afghanistan and Pakistan to form a Central Asia-South Asia (CASA) Regional Electricity Market. The core elements of the project include: a 500 kV, 750 km HVDC power interconnection with DC/AC conversion capacities of 1300 MW at Sangtuda (Tajikistan), 300 MW at Kabul (Afghanistan) and 1300 MW at Peshawar (Pakistan); and a 500 kV, 477 km high voltage alternating current (HVAC) power Interconnection between Kyrgyz Republic (Datka substation) and Tajikistan (Khoujand substation). The HVDC converter capacity in Pakistan (Peshawar) is equal to that in Tajikistan (Sangtuda). This provides flexibility for Pakistan to absorb up to 1300 MW, should Afghanistan not need to import its entire share. The present project cost is estimated to be around US$ 873 million (SNC Lavalin, February, 2011).

CASA-1000 project is unique in the sense that it was multi-seller and multi-buyer sort of arrangement and four countries were involved in it as foundation members. Under open access, other states of the Central and South Asia may also get engaged in the project. It was pursued under the concept of establishing an inter-regional electricity trade arrangement among the four participating countries. In view of its unique characteristics and upon the request of the participating countries, USAID with the support of World Bank established a CASA Secretariat to undertake all pre-construction project development activities.

In view of the complexity of the transaction, the contracting parties decided to supervise the project development through a body named as “Inter-Governmental Council” (IGC), headed by the relevant Ministers of four counties. IGC decided that this Project will be implemented by Parties as “Contractual Joint Venture”. Moving forward with this concept, the legal counsels of the participating counties as well as of CASA Secretariat were of the view that there should be a “Master Agreement” (MA) and five independent PPAs to establish the contractual relationship among the parties. The MA and PPAs between NTDC and transmission entities of sellers (Tajikistan and Kyrgyzstan) were finalized in the first week of April, 2015 and signed on 24th April, 2015.

7.7 Import of Electricity from Iran

7.7.1 Import of 74 MW (Jackigur – Mand) WAPDA and Tavanir Iran entered into an Agreement for sale and purchase of 74 MW of Power from Iran to Pakistan to meet the demand of Makran Division Balochistan comprising the Districts of Turbat, Gwadar and Panjgoor and border towns of Mashkail, Mand and Taftan. The existing tariff was agreed within the limit of 7.00 to 10.00 Cents/kWh. Iran has also offered to supply 30 MW additional capacity on the same transmission line. Total supply would be 104 MW.

7.7.2 Import of 100 MW (Polan – Gawadar) A Contract was signed between Tavanir and NTDC on 7th February, 2007 for supply of 100 MW for Gwadar for 30 years and the Tariff at US cents 6.25/kWh. Export Development Bank of Iran will finance 70% and remaining 30% will be financed by NTDC’s out of its own sources. 220 kV double circuit Transmission Line and 220 kV GIS grid station are being constructed at Gwadar by Sunir-Iran. The project cost is estimated as Euro 31 million.

7.7.3 Import of 1000 MW (Zahedan – Quetta) A Memorandum of Understanding (MoU) was signed between Iran and Pakistan on 8th April, 2007 for supply of 1000 MW. In this regard, a Feasibility Study was conducted jointly by Moshanir (Iran) and NESPAK (Pakistan) and submitted on 26th April, 2010. The main points of the Feasibility Study are as follows:

7.7.3.1 The Parties agreed to HVDC interconnection on ± 500 kV level. Converter and Switching stations at Zahedan and Quetta will be constructed.

64 State of Industry Report 2015

7.7.3.2 Total length of Transmission line will be around 678 km. 93 km will be constructed in Iran and 585 km will be constructed in the territory of Pakistan.

7.7.3.3 Iran will construct dedicated 1300 MW power plant at Zahedan for supply of 1000 MW to Pakistan.

The total estimated cost of transmission line project will be US$ 700 million. The cost of ± 500 HVDC interconnection project including two HVDC converter/Inverter substations is estimated to be approximately US$ 700 million excluding the cost of 1300 MW power plant needs to be constructed on the Iranian side. Tavanir consented for financing the HVDC Interconnection Project cost in its own territory (approximately US$ 265 million) side for this project. The parties agree to finance the HVDC Interconnection Project for Pakistani side (approximately US$ 435 million), as follows:

7.7.3.4 70% which is approximately equals to US$ 300 million will be arranged and financed by Iranian Financial Institutions.

7.7.3.5 30% which is approximately equals to US$ 135 million will be financed by Pakistani Financial Institutions.

7.7.3.6 Upon the approval of Economic Coordination Committee (ECC), an application for determination of Tariff has been submitted to NEPRA.

PPA is required to be finalized with Tavanir to initiate further progress on the Project.

7.8 Alternative and Renewable Energy Developments The GoP is promoting the use of Alternative and Renewable Energy (ARE) technologies in order to diversify its energy mix so as to ensure Energy Security, Economic Benefits, Social Equity and Environmental Protection. Alternative and Renewable Energies have the potential of being a strong contributor in the envisaged diversified energy mix. Alternative and Renewable Energy resources are widely and abundantly available in Pakistan that can be effectively and efficiently utilized for power generation.

AEDB, acting as a one-window facility for the development and promotion of ARE technologies in the country, has undertaken a number of supportive measures for the promotion and development of RE technology in the country and to attract private sector investments. With all the requisite ingredients in place - a proven RE potential, robust policy framework, enabling tariff structures and bankable security documents, the RE sector of Pakistan has become an investment destination for private investors and has attracted a foreign investment of more than US$ 3 billion during the last one year.

7.8.1 Steps/initiatives for Development of ARE Sector AEDB has undertaken a number of measures in order to promote ARE technologies and to attract private sector investments, which include:

7.8.1.1 Development of large scale grid connected power generation projects using wind, solar, biomass and bagasse.

7.8.1.2 Identification of new corridors for wind and solar energy projects development. Detailed ground correlated resource mapping of wind, solar and biomass is being carried out thought ESMAP – World Bank’s Assistance.

7.8.1.3 Framework for Power Co-Generation-2013 (Bagasse/Biomass) approved by ECC for high pressure boiler based power generation from the existing sugar mills. 1500-2000 MW of power is expected to be generated in next 3-4 years.

65 State of Industry Report 2015 7.8.1.4 Standard Security Agreements (EPA and IA) developed for wind, solar and biomass co-generation projects.

7.8.1.5 National Grid Code for wind and solar has been amended. Grid Integration Plan 2010-2015 for wind power projects developed by AEDB to support NTDC.

7.8.1.6 Trainings and capacity building of partner departments like NTDC, NEPRA, PMD, DISCOs, Provincial Government Departments, etc. have been arranged by AEDB.

7.8.1.7 Standardized Project Agreements developed for wind, bagasse and biomass power projects. Standard Projects Agreements for solar power projects being developed.

7.8.1.8 Local manufacturing of RE equipment promoted. DESCON has setup a wind turbine tower manufacturing facility and has provided towers for the first wind project in Pakistan. CWE has also established a tower manufacturing facility which will be upgraded to wind turbine assembling facility in future. AEDB has acquired license of micro-hydel turbines and disseminated to local manufacturers.

7.8.1.9 Use of solar based off-grid applications such as solar water heaters, solar-water pumps, solar street lights etc. is being promoted.

7.8.1.10 In order to restrict the import of sub-standard solar equipment, quality standards for import of solar equipment are being introduced.

7.8.1.11 Banks and donor agencies are being approached to announce consumer financing for ARE applications such as solar home systems, solar water pumps etc.

7.8.2 On-Grid Projects AEDB is pursuing the development of ARE based power generation projects through private investors under RE Policy 2006. The current status of on-grid ARE based power projects is as follows.

7.8.2.1 Wind • 05 wind power projects of 255.9 MW operational. • 09 wind power projects of 477 MW are under construction. • 15 wind power projects of 634 MW in different stages of development. • 17 wind power projects of 950 MW are at initial stage.

7.8.2.2 Solar • 01 solar PV project of 100 MW installed. • 03 solar PV projects of 300 MW under construction. • 35 solar PV projects of 1393.44 MW in different stages of development. • 18 solar PV projects of 852 MW are at initial stages.

7.8.2.3 Biomass • 03 biomass projects of 82.7 MW operational. • 10 biomass projects of 333.4 MW in development stages. • 07 biomass projects of 240 MW are at initial stages.

7.8.3 Off-Grid Applications AEDB is also promoting the use of RE technologies for distributed generation and off-grid applications. These include:

66 State of Industry Report 2015

• Solar PV based systems for domestic, commercial and industrial sectors. • Solar water pumping. • Solar water heating. • Solar street lights. • Biogas plants. • Mini/micro hydel power for distribution generation.

The use of ARE technologies for power generation is also being promoted for captive and grid spill-over purposes. In this regard, NEPRA on the request of AEDB, has announced NEPRA (Alternative and Renewable Energy) Distributed Generation and Net Metering Regulations, 2015 which will enable the consumers to supply surplus power generated through ARE sources to the National Grid.

The following table provides details of renewable energy projects:

A: Existing Projects (in-operation and under construction) S. Capacity Expected Estimated Cost Name of Project No. (MW) Commissioning year (US$ Million) Wind Technology: 1 FFC Energy Limited 49.50 May, 2013 133.557 2 Zorlu Energy Pakistan Limited 56.40 July, 2013 143.740 Three Gorges First Wind Farm Pakistan (Pvt.) 3 50 November, 2014 130.279 Limited 4 Foundation Wind Energy-II Limited 50 December, 2014 124.907 5 Foundation Wind Energy-I Limited 50 April, 2015 125.899 Sapphire Wind Power Company (Pvt.) 6 49.50 January, 2016 120.00-130.00 Limited 7 Metro Power Company (Pvt.) Limited 50 August, 2016 125.236 8 Yunus Energy Limited 50 August, 2016 120.00-130.00 9 Master Wind Energy (Pvt.) Limited 49.50 September, 2016 120.00-130.00 10 Hydrochina Dawood Power (Pvt.) Limited 49.50 September, 2016 120.00-130.00 11 United Energy Pakistan Limited 99 September, 2016 240.00-260.00 12 Tapal Wind Energy (Pvt.) Limited 30 September, 2016 72.00-78.00 13 Tenega Generasi Limited 49.50 September, 2016 120.00-130.00 14 Gul Ahmed Energy Limited 50 September, 2016 120.00-130.00 Solar PV Technology: 15 Quaid-e-Azam Solar Power (Pvt.) Limited 100 July, 2015 151.4 16 Appolo Solar Development Pakistan Limited 100 December, 2016 151.40 17 Best Green Energy Pakistan (Pvt.) Limited 100 December, 2016 151.40 18 Crest Energy Pakistan Limited 100 December, 2016 151.40 Bagasse/Biomass Technology: 19 JDW Sugar Mills Limited (Unit-II) 26.35 June, 2014 Based on 20 JDW Sugar Mills Limited (Unit-III) 26.35 October, 2014 Upfront Tariff 21 RYK Mills Limited 30 March, 2015 Continued.....

67 State of Industry Report 2015

B: Future Projects S. Capacity Expected Estimated Cost Name of Project No. (MW) Commissioning year (US$ Million) Wind Technology: 1 Sachal Energy Development (Pvt.) Limited 50 June, 2017 133.918 2 Hawa Holding Limited 50 December, 2017 120.00-130.00 3 China Sunec Energy (Pvt.) Limited 50 December, 2017 120.00-130.00 4 Jhampir Wind Power (Pvt.) Limited 50 December, 2017 120.00-130.00 5 Trident Energy (Pvt.) Limited 10 January, 2018 24.00-26.00 6 Burj Wind Energy (Pvt.) Limited 14 April, 2018 33.60-34.40 Tricon Boston Consulting Corporation (Pvt.) 7 50 April, 2018 120.00 -130.00 Limited (A) Tricon Boston Consulting Corporation (Pvt.) 8 50 April 2018 120.00-130.00 Limited (B) Tricon Boston Consulting Corporation (Pvt.) 9 50 April, 2018 120.00 -130.00 Limited (C) 10 Hartford Alternative Energy (Pvt.) Limited 50 July, 2018 120.00-130.00 11 Wind Eagle Limited (1) 50 July, 2018 120.00-130.00 12 Wind Eagle Limited (2) 50 July, 2018 13 Western Energy (Pvt.) Limited 50 July, 2018 120.00-130.00 14 Zephyr Power (Pvt.) Limited 50 August, 2018 134.099 15 Titan Wind Power (Pvt.) Limited 10 August, 2018 24.00-26.00 Solar PV Technology: 16 Zonergy (Pvt.) Limited 600 June, 2016 840.00-900.00 17 Access Electric (Pvt.) Limited 10 August, 2016 16.00-19.00 18 Buksh Solar (Pvt.) Limited 10 August, 2016 16.00-19.00 19 Sanjwal Solar Power (Pvt.) Limited 5.04 August, 2016 8.00-9.50 20 Safe Solar Power (Pvt.) Limited 10.28 August, 2016 16.00-19.00 21 Access Solar (Pvt.) Limited 11.52 August, 2016 16.00-19.00 22 Blue Star Hydel (Pvt.) Limited 1 August, 2016 1.562 23 Blue Star Electric (Pvt.) Limited 1 April, 2017 1.562 24 Harappa Solar (Pvt.) Limited 10 June, 2017 14.00-15.00 25 Fauji Foundation 10 August, 2017 14.00-15.00 26 Siddiqsons Energy Limited 50 September, 2017 70.00-75.00 27 Integrated Power Station 50 December, 2017 75.00-78.00 28 Jafri and Associates 50 December, 2017 75.00-78.00 29 Solar Blue (Pvt.) Limited 50 December, 2017 75.00-78.00 30 RE Solar (Pvt.) Limited (1) 20 December, 2017 28.00-30.00 31 RE Solar (Pvt.) Limited (2) 20 December, 2017 28.00-30.00 32 Hanergy Global Solar Asia Pacific Limited (1) 50 May, 2018 70.00-75.00 33 Hanergy Global Solar Asia Pacific Limited (2) 10 May, 2018 14.00-15.00 34 Janpur Energy Limited (1) 10 May, 2018 14.00-15.00 35 Janpur Energy Limited (2) 10 May, 2018 14.00-15.00 36 Nizam Power (Pvt.) Limited (1) 5.65 June, 2018 7.00-8.00 37 Nizam Power (Pvt.) Limited (2) 5.65 June, 2018 7.00-8.00 38 Nizam Power (Pvt.) Limited (3) 11.30 June, 2018 16.00-17.00 Continued.....

68 State of Industry Report 2015

S. Capacity Expected Estimated Cost Name of Project No. (MW) Commissioning year (US$ Million) Sino Pak Energy Development Company (Pvt.) 39 10 June, 2018 14.00-15.00 Limited 40 Ayan Energy (Pvt.) Limited 50 June, 2018 70.00-75.00 41 Total Energies Nouvelles Ventures 100 December, 2018 140.00-150.00 42 AJ Power (Pvt.) Limited 10 December, 2018 14.00-15.00 43 Adamjee Power Generation (Pvt.) Limited 5 December, 2018 7.00-8.00 44 ET Solar (Pvt.) Limited (1) 25 December, 2018 35.00-38.00 45 ET Solar (Pvt.) Limited (2) 25 December, 2018 35.00-38.00 46 ET Solar (Pvt.) Limited (3) 25 December, 2018 35.00-38.00 47 Crystal Energy (Pvt.) Limited 2 May, 2019 3.50-4.00 48 ACT Solar (Pvt.) Limited 50 May, 2019 70.00-75.00 49 Asia Petroleum 30 June, 2019 42.00-45.00 50 Forshine (Pakistan) 50 June, 2019 70.00-75.00 Bagasse /Biomass Technology: 51 Chiniot Power Limited 62.40 2015 52 Hamza Sugar Mill Limited 15 2016 54 Layyah Sugar Mills Limited 41 2016 55 Safina Sugar Mills Limited 20 July, 2016 53 Alliance Sugar Mills Limited 19 2017 Based on 56 Almoiz Industries Limited 36 2017 Upfront Tariff 57 Etihad Power Generation Limited 67 January, 2017 58 Shahtaj Sugar Mills Limited 15 2018 59 Chanar Energy Limited 22 2018 60 RYK Energy Limited 36 2018

C: Proposals of following Projects accepted by AEDB and issuance of LOI: S. Capacity Expected Estimated Cost Name of Project No. (MW) Commissioning year (US$ Million) Wind Technology: 1 Gul Ahmed Energy Limited 50 2019 120.00-130.00 2 Metro Power Company Limited 50 2019 120.00-130.00 3 Electrique (Pvt.) Limited 50 2019 120.00-130.00 4 Shaheen Foundation (PAF) 50 2019 120.00-130.00 5 Emerald Energy Limited 50 2019 120.00-130.00 6 Aleph Systems (SMC-Pvt.) Limited 100 2019 240.00-260.00 7 Wind Energy Limited 50 2019 120.00-130.00 Power China Huadong Engineering 8 50 2019 120.00-130.00 Corporation Limited 9 Indus Wind Energy Limited 50 2019 120.00-130.00 10 NASDA Energy (Pvt.) limited 50 2019 120.00-130.00 11 Green Power (Pvt.) Limited (1) 50 2019 120.00-130.00 12 Green Power (Pvt.) Limited (2) 50 2019 120.00-130.00 13 Trans Atlantic Energy (Pvt.) Limited (1) 50 2019 120.00-130.00 14 Trans Atlantic Energy (Pvt.) Limited (2) 50 2019 120.00-130.00 Continued.....

69 State of Industry Report 2015

S. Capacity Expected Estimated Cost Name of Project No. (MW) Commissioning year (US$ Million) 15 MepconIncemet Energias Renovables 50 2019 120.00-130.00 16 Master Green Energy Limited 100 2019 240.00-260.00 17 Din Energy Limited 50 2019 120.00-130.00 Solar PV Technology: 18 MST Power (Pvt.) Limited 5 2019 7.00-8.00 19 RT Power (Pvt.) Limited 10 2019 14.00-15.00 20 Ravi Renewable Energy 20 2019 28.00-30.00 21 Gran Solar 20 2019 28.00-30.00 22 First Solar (Pvt.) Limited 2 2017 2.80-3.00 23 Pakistan PV Power 01 (Pvt.) Limited 50 2019 70.00-75.00 24 KSJ International FZE 200 2019 280.00-300.00 25 Sapphire Wind Power Company Limited 40 2019 56.00-60.00 26 Gul Ahmed Energy Limited 50 2019 70.00-75.00 27 Metro Solar Power Limited 50 2019 70.00-75.00 28 Master Solar Energy Limited 20 2019 28.00-30.00 29 Uch-II Power (Pvt.) Limited 10 2019 14.00-15.00 30 China Han Power Company Limited (1) 50 2019 70.00-75.00 31 China Han Power Company Limited (2) 200 2019 280.00-300.00 32 Liberty Solar (Pvt.) Limited 50 2019 70.00-75.00 33 Adamjee Power Generation 5 2019 7.00-8.00 34 Conergy 20 2019 28.00-30.00 35 Fotwatio Renewable Ventures 50 2019 70.00-75.00 Bagasse/Biomass Technology: 36 Ansari Powergen Company (Pvt.) Limited 30 2019 37 Bandhi Powergen Company (Pvt.) Limited 30 2019 38 TAY Powergen Company (Pvt.) Limited 30 2019 Based on 39 Faran Sugar Mills Limited 25 2019 Upfront Tariff 40 Shakargarj Mills Limited (1) 40 2019 41 Shakarganj Mills Limited (2) 60 2019 42 Indus Sugar Mills Limited 25 2019 Notes: The expected dates for some of the projects as provided by AEDB do not exactly match with the expansion plans provided by NTDC. For consistency of report the data provided by NTDC has been used in the analysis.

70 MISCELLANEOUS 8

State of Industry Report 2015 8. MISCELLANEOUS

8.1 Promulgation of New Rules/Regulations The following Rules/Regulations/Guidelines and amendments in existing Rules and Regulations have been promulgated during the period being reported:

8.1.1 NEPRA (Market Operator Registration, Standards and Procedure) Rules, 2015

8.1.2 Standards Operating Procedures (SOPs) for Inspection, Examination and Provision of Copies of Documents, 2015

8.1.3 NEPRA (Sale of Electric Power by Renewable Energy Companies) Guidelines, 2015

8.1.4 NEPRA Guidelines for determination of Consumer-end Tariff (Methodology and Process), 2015

8.1.5 Amendment made in NEPRA (Tariff Standards and Procedure) Rules, 1998

8.1.6 Amendment made in NEPRA Performance Standards (Distribution) Rules, 2005

8.1.7 Amendment made in NEPRA (Fines) Rules, 2002

8.1.8 Amendment made in NEPRA (Uniform System of Accounts) Rules, 2009

8.2 Advisories issued by NEPRA to the Government of Pakistan

Sr. No. Subject Sent to Delay in finalization of Security Documents in the matter of Upfront Solar Ministry of Water and 1 Power Projects Power Ministry of Water and 2 Frequent Tripping EHV Transmission and Grid System during Foggy Weather Power Delay Caused in Execution of Hydropower Projects due to repeated extensions Ministry of Water and 3 of Letter of Intents Power Advisory in the matter of Finalizing PPA ad IA in the stipulated time regarding Ministry of Water and 4 Solar Power Projects Power Delay in Finalization of Security Documents in the matter of Upfront Tariff of Ministry of Water and 5 Solar Power Projects Power Delay Caused in Execution of Hydropower Projects due to repeated extensions Ministry of Water and 6 of Letter of Intents Power Ministry of Water and 7 Transmission System Breakdown on 24th January, 2015 Power Need for Strengthening the Security Measures at Grid Stations/ Switches of Ministry of Water and 8 Generating Companies Power

8.3 Consumer Affairs Safeguarding the interest of consumers and protection them from discriminatory treatment or victimization is a vital objective of NEPRA. The Consumer Affairs Department is responsible for handling the complaints of consumers who can approach NEPRA without any procedural hindrance. NEPRA has established its Regional Offices at all the Provincial Capitals in order to facilitate the electricity consumers for speedy redressal of their grievances.

73 State of Industry Report 2015

Status of Complaints during the Period 1st July, 2014 to 30th June, 2015 NEPRA Head Office Total Complaints Total Complaints Under Distribution Company Received/Processed Disposed of/Redressed Process PESCO 104 93 11 IESCO 212 198 14 GEPCO 111 101 10 LESCO 194 176 18 FESCO 139 131 8 MEPCO 800 761 39 HESCO 234 220 14 SEPCO 233 218 15 QESCO 16 15 1 KE 1,540 1,500 40 BTPL 2 2 0 Total 3,585 3,415 170 Source: NEPRA

NEPRA Regional Offices Total Complaints Total Complaints Under Distribution Company Received/Processed Disposed of/Redressed Process PESCO 91 89 2 LESCO 92 86 6 FESCO 61 60 1 GEPCO 48 48 0 MEPCO 95 93 2 HESCO 2 2 0 SEPCO 1 0 1 QESCO 34 15 19 KE 23 15 8 Total 447 408 39 Source: NEPRA

8.3.1 .Achievements/Development Following cases referred by Honorable Lahore High Court to NEPRA have been decided by NEPRA:

8.3.1.1 Writ Petition No. 5327/15 in the matter of Rana Muhammad Ali against LESCO. 8.3.1.2 Writ Petition No. 5329/15 in the matter of Mr. Farasat Ali against LESCO. 8.3.1.3 Writ Petition No. 847/15 in the matter of Mr. Mohammad Safdar vs LESCO. 8.3.1.4 Mr. Allah Dad S/o Muhammad Khan vs FESCO. 8.3.1.5 WAPDA Employees Cooperative Housing Society vs GEPCO.

In addition to above, following court cases are under process: 8.3.1.6 Writ Petition No. 2204/08: Shifa International Hospital vs IESCO (referred by Islamabad High Court). 8.3.1.7 Writ Petition No. 2958/13: Mian Muhammad Ayaz and others vs NEPRA and others (referred by Peshawar High Court).

Further, main cases pertaining to K-Electric have been decided by NEPRA: 8.3.1.8 Charging of meter rent by K-Electric Limited. 8.3.1.9 Bill collection charges of Rs. 8/- being charged by K-Electric from its consumers. 8.3.1.10 6 complaints against K-Electric with respect to email floated by K-Electric regarding excessive billing.

74 Energy Sector Overview 9

State of Industry Report 2015 9. Energy Sector Overview Primary commercial energy supplies in Pakistan comprise of oil, natural gas, coal, hydro and nuclear electricity. The primary energy supplies of the country during 2013-14 increased by 3.50% and reached 66.85 MTOE as compared to 64.59 MTOE during the same period last year. The overall contribution of gas in primary energy supplies of the country, during 2013-14, was the highest with 30.96 MTOE (46.32%) followed by the Oil 23.01 MTOE (34.42%), Hydro Electricity 7.61 MTOE (11.38%), Coal 3.59 MTOE (5.37%), Nuclear Electricity 1.22 MTOE (1.82%), LPG 0.36 MTOE (0.54%) and Imported Electricity 0.10 MTOE (0.15%).

9.1 Oil The balance recoverable reserves of crude oil of the country as on 30th June, 2014 were 371.029 million barrels while the production during 2013-14 was recorded as 31.58 million barrel. The total oil refining capacity of the country as on 30th June, 2014 was 18.79 million tonnes per year while the total crude oil processed in the refineries of the country were 11.76 million tonnes. The total import of the crude oil of the country during 2013- 14 was 8.04 million tonnes which cost an amount of 6572.68 million US$ while during 2012-13 the total import of crude oil was 7.40 million tonnes with total cost of 6006.10 million US$. The consumption of petroleum products (Furnace Oil, Light Diesel Oil, High Speed Diesel and Motor Spirit) in power sector during 2013-14 was recorded as 9.01 million tonnes while during 2012-13 it was recorded as 7.75 million tonnes.

9.2 Gas The balance recoverable reserves of natural gas of the country as on 30th June, 2014 were 23.64074 trillion cft. while the production during 2013-14 was recorded as 1493508 million cft. The consumption of natural gas in power sector during 2013-14 was recorded as 349535 million cft. while during 2012-13 it was recorded as 362262 million cft. The total network for distribution of natural gas in Pakistan as on 30th June, 2014 was 149516 km. The total number of natural gas consumers in Pakistan, as on 30th June, 2014 was 7373708 of which the share of domestic, commercial and industrial consumers were (7285402), (77697) and (10609), respectively.

9.3 Coal The estimated total coal reserves of the country as on 30th June, 2014 were about 186 billion tonnes while production of coal during 2013-14 was recorded as 3.44 million tonnes. The total coal imported by the country during 2013-14 was 3.12 million tonnes, which cost an amount of Rs. 31072 million. The total coal consumption in power sector during 2013-14 was 160710 tonnes as compared to 63039 tonnes, same period last year. However, the electricity generated through coal during 2012-13 and 2013-14 was 40 GWh and 112 GWh respectively.

9.4 Primary Energy Supplies The main primary energy production of the country consists of oil, gas, coal, nuclear electricity net generation (converted to Btu using the nuclear plants heat rate); and conventional hydroelectricity net generation (converted to Btu using the fossil-fueled plants heat rate). The primary commercial energy supplies by source from 2009-10 to 2013-14 is given in table 1.

77 State of Industry Report 2015

TABLE 1 Primary Energy Supplies by Source (MTOE) Annual Fiscal Hydro Nuclear Imported Unit Gas Oil1 LPG2 Coal Total Growth Year Electricity3 Electricity3 Electricity4 Rate (%) Million 30.81 19.81 0.40 4.62 6.71 0.69 0.06 63.09 2009-10 TOE 0.83 % share 48.83 31.39 0.63 7.33 10.63 1.10 0.09 100.00 Million 30.68 20.67 0.34 4.35 7.59 0.82 0.06 64.52 2010-11 TOE 2.27 % share 47.55 32.04 0.53 6.74 11.77 1.27 0.10 100.00 Million 32.03 19.96 0.32 4.29 6.81 1.26 0.07 64.73 2011-12 TOE 0.32 % share 49.49 30.83 0.50 6.62 10.52 1.94 0.10 100.00 Million 31.14 20.97 0.31 3.86 7.13 1.09 0.09 64.59 2012-13 TOE -0.21 % share 48.22 32.47 0.48 5.98 11.03 1.68 0.14 100.00 Million 30.96 23.01 0.36 3.59 7.61 1.22 0.10 66.85 2013-14 TOE 3.50 % share 46.32 34.42 0.54 5.37 11.38 1.82 0.15 100.00 1 Excluding petroleum products exports and bunkering. 2 Include imports and production from field plants. 3 Converted @ 10,000 Btu/kWh to represent primary energy equivalent of hydro and nuclear electricity as if this was generated by using fossil fuels. 4 WAPDA importing electricity from Iran since October, 2002. Source: Pakistan Energy Yearbook, HDIP, Islamabad

Figure 1. Primary Energy Supplies by Source (MTOE) 33.00 30.00 27.00 24.00 21.00 18.00 15.00 12.00 9.00 6.00 3.00 0.00 2009-10 2010-11 2011-12 2012-13 2013-14 Gas Oil LPG Coal Hydro Electricity Nuclear Electricity

78 State of Industry Report 2015

9.5 Final Energy Consumption Final energy is a form of energy available to the user following the conversion from primary energy. Gasoline or diesel oil, purified coal, purified natural gas, electricity, mechanical energy are different forms of final energy. When going from primary energy to final energy, there are always loss of some energy which depends on the efficiency of the conversion device. The final energy consumption by source from 2009-10 to 2013-14 is given in table 2.

TABLE 2 Final Energy Consumption by Source (MTOE) Annual Fiscal Year Unit Gas2 Oil1 LPG Coal2 Electricity3 Total Growth Rate (%) Million TOE 17.02 10.83 0.58 4.28 6.05 38.77 2009-10 3.81 % share 43.91 27.93 1.49 11.05 15.62 100.00 Million TOE 16.78 11.25 0.50 4.03 6.28 38.84 2010-11 0.19 % share 43.20 28.97 1.30 10.36 16.17 100.00 Million TOE 17.62 11.62 0.48 4.06 6.25 40.03 2011-12 3.05 % share 44.02 29.03 1.20 10.14 15.62 100.00 Million TOE 17.52 12.22 0.53 3.66 6.25 40.18 2012-13 0.40 % share 43.60 30.41 1.31 9.11 15.56 100.00 Million TOE 16.28 12.72 0.59 3.45 6.79 39.82 2013-14 -0.91 % share 40.88 31.94 1.47 8.65 17.06 100.00 1 Excluding consumption for power generation. 2 Excluding consumption for power generation and feedstock. 3 @ 3412 Btu/kWh being the actual energy content of electricity. Source: Pakistan Energy Yearbook, HDIP, Islamabad

Figure 2. Final Energy Consumption by Source (MTOE) 18.00

16.00

14.00

12.00

10.00

8.00

6.00

4.00

2.00

0.00 2009-10 2010-11 2011-12 2012-13 2013-14

Gas Oil LPG Coal Electricity

79 State of Industry Report 2015

9.6 Fuel Consumption in Power Sector The share of installed generation capacity of thermal power plants using oil, natural gas and coal to the total installed generation capacity in the country, during 2014-15, was about 67.74% while the electricity produced by the thermal power plants, during 2013-14, to the total electricity generated in the country during same period was about 66.25%. The statistics of different fuel used and their percent share to the total fuel used for thermal electricity generation of the country from 2009-10 to 2013-14 are given in table 3.

TABLE 3 Fuel Consumption for Thermal Power Generation (TOE) Fiscal Furnace Annual Growth Unit Gas Diesel Oil Coal Total Year Oil Rate (%) TOE 7,106,962 8,339,330 262,499 56,141 15,764,932 2009-10 3.28 % share 45.08 52.90 1.67 0.36 100.00 TOE 6,493,766 7,827,500 105,160 43,169 14,469,595 2010-11 -8.22 % share 44.88 54.10 0.73 0.30 100.00 TOE 6,732,876 7,206,839 203,072 46,800 14,189,587 2011-12 -1.94 % share 47.45 50.79 1.43 0.33 100.00 TOE 7,084,177 7,342,755 218,584 28,204 14,673,720 2012-13 3.41 % share 48.28 50.04 1.49 0.19 100.00 TOE 6,602,422 8,486,744 304,994 71,902 15,466,062 2013-14 5.40 % share 42.69 54.87 1.97 0.46 100.00 Source: Pakistan Energy Yearbook, HDIP, Islamabad

Figure 3. Fuel Consumption for Thermal Power Generation (%)

55.00 50.00 45.00 40.00 35.00 30.00 25.00 20.00 15.00 10.00 5.00 0.00 2009-10 2010-11 2011-12 2012-13 2013-14

Gas Furnace Oil Diesel Oil Coal

80 ELECTRICITY SECTOR OVERVIEW 10

State of Industry Report 2015 10. ELECTRICITY SECTOR OVERVIEW

10.1 Installed Capacity The total nominal power generation capacity of Pakistan as on 30th June, 2015 was 24,823 MW; of which 16,814 MW (67.74%) was thermal, 7,116 MW (28.67%) was hydroelectric, 787 MW (3.17%) was nuclear and 106 MW (0.43%) was wind. The installed power generating capacity of Pakistan from 2011 to 2015 is given in table 4.

TABLE 4 Installed Generation Capacity by Type (MW) As on 30th June 2011 2012 2013 2014 2015 HYDEL WAPDA Hydel 6,516 6,516 6,733 6,902 6,902 IPPs Hydel 129 214 214 214 214 Sub-Total 6,645 6,730 6,947 7,116 7,116 % Share (Hydel Installed Generation Capacity) 28.47 28.65 29.28 29.99 28.67 THERMAL GENCOs with PEPCO 4,785 4,785 4,785 4,590 5,762 KEL Own 1,821 2,381 2,359 1,951 1,874 Connected with PEPCO 8,325 8,312 8,342 8,726 8,726 IPPs Connected with KEL 252 252 252 252 252 Connected with PEPCO 353 0 0 0 0 RPPs Connected with KEL 50 0 0 0 0 CPPs/SPPs connected with KEL 324 239 203 200 200 Sub-Total 15,910 15,969 15,941 15,719 16,814 % Share (Thermal Installed Generation Capacity) 68.16 67.99 67.19 66.25 67.74 NUCLEAR CHASNUPP (I&II) 650 650 650 650 650 KANUPP 137 137 137 137 137 Sub-Total 787 787 787 787 787 % Share (Nuclear Installed Generation Capacity) 3.37 3.35 3.32 3.32 3.17 WIND Wind Power Plants connected with PEPCO 0 1 50 106 106 Sub-Total 0 1 50 106 106 % Share (Wind Installed Generation Capacity) 0.00 0.00 0.21 0.45 0.43 Total Installed Generation Capacity of the 23,342 23,487 23,725 23,728 24,823 Country Source: PSS/NTDC/KEL

83 State of Industry Report 2015

Figure 4. Share of Installed Generation Capacity by Type (%) 70.00

60.00

50.00

40.00

30.00

20.00

10.00

0.00 2011 2012 2013 2014 2015

% Share (Hydel Installed Generation Capacity) % Share (Thermal Installed Generation Capacity) % Share (Nuclear Installed Generation Capacity) % Share (Wind Installed Generation Capacity)

TABLE 5 Plant-wise Installed Generation Capacity (MW) as on 30th June Type of Power Power Station Plant Location Station 2011 2012 2013 2014 2015 A1: Hydel (WAPDA) Major Hydropower Units Tarbela Tarbela, KPK Reservoir 3,478 3,478 3,478 3,478 3,478 Ghazi Barotha Ghazi Barotha, Punjab Run of River 1,450 1,450 1,450 1,450 1,450 Mangla Mangla, AJ&K Reservoir 1,000 1,000 1,000 1,000 1,000 Warsak Warsak, KPK Reservoir 243 243 243 243 243 Chashma Chashma, Punjab Run of River 184 184 184 184 184 Khan Khwar Shangla, KPK Reservoir 72 72 72 72 72 Allai Khwar Battagram, KPK Reservoir 0 0 121 121 121 Jinnah Mianwali, Punjab Run of River 0 0 96 96 96 Duber Khwar Kohistan, KPK Reservoir 0 0 0 130 130 Small Hydropower Units Dargai Dargai, KPK Run of Canal 20 20 20 20 20 Rasul Rasul, Punjab Run of Canal 22 22 22 22 22 Shadiwal Shadiwal, Punjab Run of Canal 14 14 14 14 14 Chichoki Mallian, Chichoki Mallian Punjab Run of Canal 13 13 13 13 13 Nandipur Nandipur, Punjab Run of Canal 14 14 14 14 14 Kurram Garhi Kurram Garhi, KPK Run of Canal 4 4 4 4 4 Renala Renala, Punjab Run of Canal 1 1 1 1 1 Chitral Chitral, KPK Run of Canal 1 1 1 1 1 South Waziristan Gomal Zam Agency, KPK Reservoir 0 0 0 17 17 Malakand/Jabban Malakand, KPK Run of River 0 0 0 22 22 Total Hydel (WAPDA) 6,516 6,516 6,733 6,902 6,902 Continued..... 84 State of Industry Report 2015

Type of Power Power Station Plant Location Station 2011 2012 2013 2014 2015 A2: Hydel (IPPs) Jagran AJ&K Jagran, AJ&K Hydro 30 30 30 30 30 Malakand-III (PEDO) Malakand, KPK Hydro 81 81 81 81 81 Pehur (PEDO) Swabi, KPK Hydro 18 18 18 18 18 Laraib Energy Jhelum River, AJ&K Hydro 0 84 84 84 84 Garam Chashma Chitral, KPK Hydro 0 1 1 1 1 Total Hydel (IPPs) 129 214 214 214 214 Total Hydel (A1+A2) 6,645 6,730 6,947 7,116 7,116 B1: Thermal (GENCOs in PEPCO system) TPS Jamshoro Jamshoro, Sindh STs 850 850 850 850 850 GTPS Kotri Kotri, Sindh GTs+CCPP 174 174 174 174 174 TPS Guddu Guddu, Sindh STs+GTs+CCPPs 1,655 1,655 1,655 1,655 2,402 TPS Quetta Quetta, Balochistan GT 35 35 35 35 35 TPS Muzaffargarh Muzaffargarh, Punjab STs 1,350 1,350 1,350 1,350 1,350 SPS GTPS Faisalabad Faisalabad, Punjab STs+GTs+CCPPs 376 376 376 376 376 NGPS Multan Multan, Punjab STs 195 195 195 0 0 Nandipur Gujranwala, Punjab GTs+CCPPs 0 0 0 0 425 FBC Lakhra Lakhra, Sindh STs 150 150 150 150 150 Total Thermal (GENCOs in PEPCO system) 4,785 4,785 4,785 4,590 5,762 B2: Thermal (IPPs connected with PEPCO system) Lal Pir Power Mehmood Kot, Punjab ST 362 362 362 362 362 Pak Gen. Power Mehmood Kot, Punjab ST 365 365 365 365 365 Altern Energy Fateh Jang, Punjab GEs 31 31 31 31 31 Fauji Kabirwala Kabirwala, Punjab GTs+CCPP 157 157 157 157 157 Habibullah Coastal Quetta, Balochistan GTs+CCPP 140 140 140 140 140 HUBCO Hub, Balochistan STs 1,292 1,292 1,292 1,292 1,292 Japan Power Raiwind, Punjab DE 135 135 135 135 135 KAPCO Kot Addu, Punjab GTs+CCPPs 1,639 1,638 1,638 1,638 1,638 Kohinoor Energy Raiwind, Punjab DEs+ST 131 131 131 131 131 Rousch Power Sidhnai, Punjab GTs+ST 450 450 450 450 450 Saba Power Farooqabad, Punjab ST 134 134 134 134 134 Southern Electric Raiwind, Punjab DEs 136 117 136 136 136 TNB Liberty Power Daharki, Sindh GTs+CCPP 235 235 235 235 235 Murad Jamali, Uch Power Balochistan GTs+ST 586 586 586 586 586 Attock Gen. Attock Morgah, Punjab DGs+ST 165 164 164 165 165 Atlas Power Sheikhupura, Punjab REs+ST 224 224 224 219 219 Engro Power Gen. Qadirpur Qadirpur, Sindh GT+ST 226 227 227 217 217 Saif Power Sahiwal, Punjab GTs+ST 225 225 225 225 225 Orient Power Balloki, Punjab GTs+ST 225 225 225 225 225 Nishat Power Qasur, Punjab REs+ST 202 202 202 202 202 Nishat Chunian Qasur, Punjab DEs+ST 202 202 202 202 202 Sapphire Electric Muridke, Punjab GTs+ST 229 235 235 235 235 Halmore Power Bhikki, Punjab GTs+ST 225 225 225 225 225 HUBCO Narowal Narowal, Punjab DEs+ST 225 225 225 214 214 Continued.....

85 State of Industry Report 2015

Type of Power Power Station Plant Location Station 2011 2012 2013 2014 2015 Liberty Power Tech. Faisalabad, Punjab DEs+ST 202 202 202 202 202 Foundation Power Daharki, Sindh GT+ST 182 183 183 185 185 Davis Energen. Jhang, Punjab GEs 0 0 11 11 11 Murad Jamali, Uch Power-II Balochistan GTs+ST 0 0 0 381 381 Rahim Yar Khan, JDW (II & III) (Bagasse) Punjab STs 0 0 0 26 26 Rental Power Plants 353 0 0 0 0 Total Thermal (IPPs connected with PEPCO system) 8,678 8,312 8,342 8,726 8,726 Total Thermal in PEPCO system (B1+B2) 13,463 13,097 13,127 13,316 14,488 C1: Thermal (KEL Own) Bin Qasim TPS-I Karachi, Sindh STs 1,260 1,260 1,260 840 840 Bin Qasim TPS-II Karachi, Sindh GTs 0 560 560 572 572 Korangi TPS Karachi, Sindh STs 125 125 125 125 0 Korangi Town GTPS-I Karachi, Sindh GTs 20 20 0 0 0 Korangi Town GTPS-II Karachi, Sindh GTs 88 88 97 97 107 Site GTPS-I Karachi, Sindh GTs 20 20 0 0 0 Site GTPS-II Karachi, Sindh GTs 88 88 97 97 107 Korangi CCPP Karachi, Sindh GTs 220 220 220 220 248 Total Thermal (KEL Own) 1,821 2,381 2,359 1,951 1,874 C2: Thermal (IPPs connected with KEL) Gul Ahmed Karachi, Sindh DE+ST 128 128 128 128 128 Tapal Energy Karachi, Sindh DE+ST 124 124 124 124 124 Total Thermal (IPPs connected with KEL) 252 252 252 252 252 C3: Thermal (Others connected with KEL) PASMIC Karachi, Sindh STs 110 110 165 165 165 Anoud Power Karachi, Sindh DGs 12 12 15 12 12 DHA Cogen. Karachi, Sindh GT+ST 94 94 0 0 0 ISL (19 MW) Karachi, Sindh GEs+ST 19 19 19 19 19 IIL (4 MW) Karachi, Sindh GEs 4 4 4 4 4 Aggreko (Rental) Karachi, Sindh --- 50 0 0 0 0 Engro Polymer Karachi, Sindh GTs+ST 70 0 0 0 0 Al-Abbas (Coal) Karachi, Sindh ST 15 0 0 0 0 Total Thermal (Others connected with KEL) 374 239 203 200 200 Total Thermal KEL (C1+C2+C3) 2,447 2,872 2,814 2,403 2,326 D: Nuclear CHASNUPP-I Chashma, Punjab STs 325 325 325 325 325 CHASNUPP-II Chashma, Punjab STs 325 325 325 325 325 KANUPP Karachi, Sindh STs 137 137 137 137 137 Total Nuclear (D) 787 787 787 787 787 E: Renewable Energy (connected with PEPCO system) Zorlu Enerji Pakistan Thatta, Sindh Wind 0 1 50 56 56 FFC Energy Thatta, Sindh Wind 0 0 0 50 50 Total Renewable Energy (connected with PEPCO system) (E) 0 1 50 106 106 Grand Total (A+B+C+D+E) 23,342 23,487 23,725 23,728 24,823 Source: PSS/NTDC/KEL

86 State of Industry Report 2015

TABLE 6 Installed Generation Capacity by Systems and by Sectors (MW) As on 30th June 2011 2012 2013 2014 2015 BY SYSTEM Total Installed Generation Capacity in PEPCO 20,758 20,478 20,774 21,188 22,360 System % Share (Installed Generation Capacity in PEPCO 88.93 87.19 87.56 89.30 90.08 System) Total Installed Generation Capacity in KEL System 2,584 3,009 2,951 2,540 2,463 % Share (Installed Generation Capacity in KEL 11.07 12.81 12.44 10.70 9.92 System) BY SECTOR Total Installed Generation Capacity in Public 11,951 11,951 12,168 12,142 13,314 Sector % Share (Installed Generation Capacity in Public 51.20 50.88 51.29 51.17 53.64 Sector) Total Installed Generation Capacity in Private 11,391 11,536 11,557 11,586 11,509 Sector % Share (Installed Generation Capacity in Private 48.80 49.12 48.71 48.83 46.36 Sector) Total Installed Generation Capacity in the 23,342 23,487 23,725 23,728 24,823 Country Source: PSS/NTDC/KEL Note: See tables 4 and 5 for breakup details.

Figure 6A. Share of Installed Gen. Capacity by System (%)

90.00

75.00

60.00

45.00

30.00

15.00

0.00 2011 2012 2013 2014 2015

% Share (Installed Generation Capacity in PEPCO System) % Share (Installed Generation Capacity in KEL System)

87 State of Industry Report 2015

Figure 6B. Share of Installed Gen. Capacity by Sector (%) 60.00

50.00

40.00

30.00

20.00

10.00

0.00 2011 2012 2013 2014 2015

% Share (Installed Generation Capacity in Public Sector) % Share (Installed Generation Capacity in Private Sector)

TABLE 7 Electricity Generation by Type (GWh) As on 30th June 2010-11 2011-12 2012-13 2013-14 2014-15 HYDEL WAPDA Hydel 31,685 28,207 29,327 31,204 31,941 IPPs Hydel 305 436 706 1,035 1,038 Sub-Total 31,990 28,643 30,033 32,239 32,979 % Share (Hydel Electricity Generation) 31.80 28.85 30.44 30.50 30.24 THERMAL GENCOs with PEPCO 13,018 12,652 12,872 13,016 13,300 KEL Own 7,826 8,029 8,567 8,709 9,319 Connected with PEPCO 41,209 42,222 40,062 43,701 44,638 IPPs Connected with KEL 1,538 933 1,116 1,380 1,525 Connected with PEPCO 546 758 0 0 0 RPPs Connected with KEL 158 0 0 0 0 CPPs/SPPs connected with PEPCO 587 730 1,280 1,108 1,015 CPPs/SPPs connected with KEL 287 154 137 168 191 Sub-Total 65,169 65,478 64,034 68,082 69,988 % Share (Thermal Electricity Generation) 64.79 65.94 64.91 64.41 64.17 NUCLEAR CHASNUPP (I&II) 2,930 4,413 3,640 4,402 4,996 KANUPP 200 459 541 293 353 Sub-Total 3,130 4,872 4,181 4,695 5,349 % Share (Nuclear Electricity Generation) 3.11 4.91 4.24 4.44 4.90 IMPORT Import from Iran 269 296 375 419 443 Import from KEL 26 0 0 0 0 Sub-Total 295 296 375 419 443 % Share (Imported Electricity Generation) 0.29 0.30 0.38 0.40 0.41 WIND Wind Power Plants connected with PEPCO 0 6 32 263 300 Sub-Total 0 6 32 263 300 % Share (Wind Electricity Generation) 0.00 0.01 0.03 0.25 0.27 Total Electricity Generation of the Country 100,584 99,295 98,655 105,698 109,059 Source: PSS/NTDC/KEL

88 State of Industry Report 2015

Figure 7. Share of Electricity Generation by Type (%) 70.00 60.00 50.00 40.00 30.00 20.00 10.00 0.00 2010-11 2011-12 2012-13 2013-14 2014-15

% Share (Hydel Electricity Generation) % Share (Thermal Electricity Generation) % Share (Nuclear Electricity Generation) % Share (Imported Electricity Generation) % Share (Wind Electricity Generation)

TABLE 8 Plant-wise Electricity Generation (GWh) Primary Alternate Power Station 2010-11 2011-12 2012-13 2013-14 2014-15 Fuel Fuel A1: Hydel (WAPDA) Major Hydropower Units Tarbela Hydel Hydel 15,909 14,057 14,756 15,138 14,809 Ghazi Barotha Hydel Hydel 7,354 6,979 7,083 6,937 6,694 Mangla Hydel Hydel 5,969 4,666 4,577 5,725 6,496 Warsak Hydel Hydel 1,036 991 1,034 870 975 Chashma Hydel Hydel 1,001 1,016 1,115 1,024 987 Khan Khwar Hydel Hydel 114 179 288 257 253 Allai Khwar Hydel Hydel 0 0 0 470 462 Jinnah Hydel Hydel 0 0 189 291 191 Duber Khwar Hydel Hydel 0 0 0 0 613 Small Hydropower Units Dargai Hydel Hydel 83 84 94 89 108 Rasul Hydel Hydel 96 68 48 51 68 Shadiwal Hydel Hydel 32 33 31 30 26 Chichoki Mallian Hydel Hydel 32 34 40 36 33 Nandipur Hydel Hydel 43 42 49 41 35 Kurram Garhi Hydel Hydel 10 11 14 19 19 Renala Hydel Hydel 3 3 3 3 2 Chitral Hydel Hydel 3 4 4 4 4 Gomal Zam Hydel Hydel 0 0 0 26 44 Malakand/Jabban Hydel Hydel 0 0 2 73 122 Others Hydel Hydel 0 40 0 120 0 Total Hydel (WAPDA) 31,685 28,207 29,327 31,204 31,941 Continued..... 89 State of Industry Report 2015

Primary Alternate Power Station 2010-11 2011-12 2012-13 2013-14 2014-15 Fuel Fuel A2: Hydel (IPPs) Jagran AJ&K Hydel Hydel 0 57 107 105 92 Malakand-III (PEDO) Hydel Hydel 292 337 395 409 408 Pehur (PEDO) Hydel Hydel 13 42 159 51 49 Laraib Energy Hydel Hydel 0 0 45 470 489 Garam Chashma Hydel Hydel 0 0 0 0 0 Total Hydel (IPPs) 305 436 706 1,035 1,038 Total Hydel (A1+A2) 31,990 28,643 30,033 32,239 32,979 B1: Thermal (GENCOs in PEPCO system) TPS Jamshoro FO+Gas FO 2,497 1,445 1,681 2,997 2,655 GTPS Kotri Gas HSD 452 270 190 156 306 TPS Guddu Gas FO 5,863 7,258 6,357 4,357 5,512 TPS Quetta Gas - 94 105 97 87 98 TPS Muzaffargarh Gas FO 3,629 3,279 4,477 5,142 4,306 SPS GTPS Faisalabad Gas HSD+FO 366 184 30 165 77 NGPS Multan Gas FO 51 45 0 0 0 Nandipur FO HSD 0 0 0 0 244 FBC Lakhra Coal Coal 66 66 40 112 102 Total Thermal (GENCOs in PEPCO system) 13,018 12,652 12,872 13,016 13,300 B2: Thermal (IPPs connected with PEPCO system) Lal Pir Power RFO - 1,105 1,787 1,643 2,081 1,663 Pak Gen. Power RFO - 1,311 1,689 1,936 2,031 1,222 Altern Energy Gas - 179 182 194 205 173 Fauji Kabirwala Gas HSD 1,088 1,237 1,107 1,191 991 Habibullah Coastal Gas HSD 811 685 658 670 719 HUBCO RFO - 8,114 7,769 7,673 7,086 6,809 Japan Power RFO - 371 281 101 0 0 KAPCO Gas FO+HSD 5,688 6,065 5,522 6,479 6,933 Kohinoor Energy RFO - 888 727 725 890 877 Rousch Power Gas HSD 3,039 2,733 2,536 2,760 2,465 Saba Power RFO - 244 116 85 129 33 Southern Electric Gas - 466 245 97 0 0 TNB Liberty Power Gas HSD 1,333 1,484 1,438 943 1,218 Uch Power Gas HSD 4,221 4,278 3,796 4,314 4,127 Attock Gen. RFO - 1,203 1,172 1,255 1,243 1,209 Atlas Power RFO - 1,484 1,067 1,383 1,519 1,462 Engro Powergen. Qadirpur Gas HSD 1,562 1,744 1,692 1,441 1,429 Saif Power Gas HSD 1,172 912 742 723 765 Orient Power Gas HSD 1,090 682 573 541 1,037 Nishat Power RFO - 1,473 1,063 1,276 1,464 1,409 Nishat Chunian RFO - 1,452 1,073 1,283 1,471 1,415 Continued.....

90 State of Industry Report 2015

Primary Alternate Power Station 2010-11 2011-12 2012-13 2013-14 2014-15 Fuel Fuel Sapphire Electric Gas HSD 843 871 877 760 944 Halmore Power Gas HSD 209 570 374 504 713 HUBCO Narowal RFO - 463 1,321 820 1,562 1,418 Liberty Power Tech. RFO - 997 1,068 892 1,520 1,515 Foundation Power Gas - 403 1,401 1,380 1,359 1,323 Davis Energen. Gas - 0 0 4 54 70 Uch Power-II Low BTU Gas - 0 0 0 752 2,415 JDW (II & III) (Bagasse) Bagasse + Biomass 0 0 0 9 284 Others (SPPs/CPPs) in PEPCO system 587 730 1,280 1,108 1,015 Rental Power Plants 546 758 0 0 0 Total Thermal 42,342 43,710 41,342 44,809 45,653 (IPPs/SPPs/CPPs connected with PEPCO system) Total Thermal in PEPCO system (B1+B2) 55,360 56,362 54,214 57,825 58,953 C1: Thermal (KEL Own) Bin Qasim TPS-I Dual 5,068 4,704 3,722 3,765 3,925 Bin Qasim TPS-II Dual 0 1,140 3,567 3,639 3,907 Korangi TPS Dual 271 163 0 0 0 Korangi Town GTPS-I Gas 1 0 0 0 0 Korangi Town GTPS-II Gas 675 595 327 393 435 Site GTPS-I Gas 0 0 0 0 0 Site GTPS-II Gas 586 416 156 113 160 Korangi CCPP Gas 1,225 1,011 795 799 892 Total Thermal (KEL Own) 7,826 8,029 8,567 8,709 9,319 C2: Thermal (IPPs connected with KEL) Gul Ahmed FO 745 452 432 582 718 Tapal Energy FO 793 481 684 798 807 Total Thermal (IPPs connected with KEL) 1,538 933 1,116 1,380 1,525 C3: Thermal (Others connected with KEL) PASMIC Gas 64 8 4 9 21 Anoud Power Gas 75 52 56 84 95 DHA Cogen. Gas 0 0 0 0 0 ISL (19 MW) Gas 99 88 72 67 67 IIL (4 MW) Gas 5 6 5 8 8 Aggreko (Rental) Gas 158 0 0 0 0 Engro Polymer Gas 2 0 0 0 0 Al-Abbas (Coal) Coal 43 0 0 0 0 Total Thermal (Others connected with KEL) 445 154 137 168 191 Total Thermal KEL (C1+C2+C3) 9,809 9,116 9,820 10,257 11,035 Continued.....

91 State of Industry Report 2015

Primary Alternate Power Station 2010-11 2011-12 2012-13 2013-14 2014-15 Fuel Fuel D: Nuclear CHASNUPP-I NUC NUC 2,387 2,127 2,121 2,194 2,455 CHASNUPP-II NUC NUC 543 2,286 1,519 2,208 2,541 KANUPP NUC NUC 200 459 541 293 353 Total Nuclear (D) 3,130 4,872 4,181 4,695 5,349 E: Import Import from Iran (Tavanir) 269 296 375 419 443 Import from K-Electric Limited 26 0 0 0 0 Total import in PEPCO system (E) 295 296 375 419 443 F: Renewable Energy (connected with PEPCO system) Zorlu Enerji Pakistan Wind Wind 0 6 32 134 161 FFC Energy Wind Wind 0 0 0 129 139 Total Renewable Energy 0 6 32 263 300 (connected with PEPCO system) (F) Grand Total (A+B+C+D+E+F) 100,584 99,295 98,655 105,698 109,059 Source: PSS/NTDC/KEL

TABLE 9 Electricity Generation by Systems and by Sectors (GWh) As on 30th June 2010-11 2011-12 2012-13 2013-14 2014-15 BY SYSTEM Total Electricity Generation in 90,549 89,720 88,294 95,148 97,671 PEPCO System % Share (Generation in PEPCO System) 90.02 90.36 89.50 90.02 89.56 Total Electricity Generation in KEL 10,035 9,575 10,361 10,550 11,388 System % Share (Generation in KEL System) 9.98 9.64 10.50 9.98 10.44 BY SECTOR Total Electricity Generation in 47,833 45,731 46,380 48,915 50,590 Public Sector % Share (Generation in Public Sector) 47.56 46.06 47.01 46.28 46.39 Total Electricity Generation in 52,751 53,564 52,275 56,783 58,469 Private Sector % Share (Generation in Private Sector) 52.44 53.94 52.99 53.72 53.61 Total Electricity Generation of the 100,584 99,295 98,655 105,698 109,059 Country Source: PSS/NTDC/KEL Note: See tables 7 and 8 for details and explanations.

92 State of Industry Report 2015

Figure 9A. Share of Electricity Generation by System (%)

90.00 80.00 70.00 60.00 50.00 40.00 30.00 20.00 10.00 0.00 2010-11 2011-12 2012-13 2013-14 2014-15

% Share (Generation in PEPCO System) % Share (Generation in KEL System)

Figure 9B. Share of Electricity Generation by Sector (%)

60.00

50.00

40.00

30.00

20.00

10.00

0.00 2010-11 2011-12 2012-13 2013-14 2014-15

% Share (Generation in Public Sector) % Share (Generation in Private Sector)

93 State of Industry Report 2015

TABLE 10 Electricity Statistics of K-Electric Limited Units Auxiliary Consumption Units Sent Name of Plant Year Generated GWh % Out 1 Units Generated by KEL Own (GWh) 2010-11 5068.28 435.91 8.60 4632.37 2011-12 4704.00 414.00 8.80 4290.00 Bin Qasim Thermal Power 1.1 2012-13 3722.00 341.00 9.16 3381.00 Station-I (BQTPS-I) 2013-14 3765.00 341.00 9.06 3424.00 2014-15 3925.00 360.00 9.17 3565.00 2011-12 1140.00 102.00 8.95 1038.00 Bin Qasim Thermal Power 2012-13 3567.00 239.00 6.70 3328.00 1.2 Station-II (BQTPS-II) 2013-14 3639.00 237.00 6.51 3402.00 2014-15 3907.00 251 6.42 3656.00 2010-11 270.51 34.10 12.61 236.41 2011-12 163.00 20.00 12.27 143.00 Korangi Thermal Power 1.3 2012-13 0.00 2.00 0.00 -2.00 Station (KTPS) 2013-14 0.00 0.00 0.00 0.00 2014-15 0.00 0.00 0.00 0.00 2010-11 0.61 0.02 3.28 0.59 Korangi Town Gas 2011-12 0.00 0.00 0.00 0.00 1.4 Turbine Power Station-I 2012-13 0.00 0.00 0.00 0.00 (KTGTPS-I) 2013-14 0.00 0.00 0.00 0.00 2014-15 0.00 0.00 0.00 0.00 2010-11 675.07 15.13 2.24 659.94 Korangi Town Gas Turbine 2011-12 595.00 14.00 2.35 581.00 1.5 Power Station-II 2012-13 327.00 9.00 2.75 318.00 (KTGTPS-II) 2013-14 393.00 10.00 2.54 383.00 2014-15 435.00 11.00 2.53 424.00 2010-11 0.10 0.01 10.00 0.09 2011-12 0.00 0.00 0.00 0.00 Site Gas Turbine Power 1.6 2012-13 0.00 0.00 0.00 0.00 Station-I (SGTPS-I) 2013-14 0.00 0.00 0.00 0.00 2014-15 0.00 0.00 0.00 0.00 2010-11 586.20 15.06 2.57 571.14 2011-12 416.00 11.00 2.64 405.00 Site Gas Turbine Power 1.7 2012-13 156.00 8.00 5.13 148.00 Station-II (SGTPS-II) 2013-14 113.00 6.00 5.31 107.00 2014-15 160.00 8.00 5.00 152.00 2010-11 1225.50 91.39 7.46 1134.11 2011-12 1011.00 75.00 7.42 936.00 Korangi Combined Cycle 1.8 2012-13 795.00 66.00 8.30 729.00 Power Plant 2013-14 799.00 64.00 8.01 735.00 2014-15 892.00 74.00 8.30 818.00 Continued.....

94 State of Industry Report 2015

Units Auxiliary Consumption Units Sent Name of Plant Year Generated GWh % Out 2010-11 7826.27 591.62 7.56 7234.65 Total Units Generated 2011-12 8029.00 636.00 7.92 7393.00 1.9 from KEL's Own Power 2012-13 8567.00 665.00 7.76 7902.00 Plants 2013-14 8709.00 658.00 7.56 8051.00 2014-15 9319.00 704.00 7.55 8615.00 2 Units Purchased by KEL (GWh) 2010-11 2011-12 2012-13 2013-14 2014-15 2.1 KANUPP 199.53 458.82 541.00 293.00 353.00 2.2 Gul Ahmed 745.01 451.52 432.00 582.00 718.00 2.3 Tapal Energy 793.16 481.46 684.00 798.00 807.00 2.4 NTDC 5449.00 5683.67 5463.00 5441.00 5427.00 2.5 PASMIC 63.61 8.06 4.00 9.00 21.00 2.6 Anoud Power 75.07 52.13 56.00 84.00 95.00 2.7 DHA Cogen. 0.00 0.00 0.00 0.00 0.00 2.8 ISL (19 MW) 98.71 87.98 72.00 67.00 67.00 2.9 IIL (4 MW) 5.19 6.07 5.00 8.00 8.00 2.10 Aggreko (Rental) 158.21 0.00 0.00 0.00 0.00 2.11 Engro Polymer 1.52 0.00 0.00 0.00 0.00 2.12 Al-Abbas (Coal) 43.13 0.00 0.00 0.00 0.00 2.13 Total 7632.14 7229.71 7257.00 7282.00 7496.00 Total Units Purchased 3 by KEL including Own 15458.41 15258.71 15824.00 15991.00 16815.00 Generation (GWh) Units Available for 4 14866.79 14622.71 15159.00 15333.00 16111.00 Distribution (GWh) 5 Units Sold (GWh) 10071.27 10279.00 10942.00 11453.00 12294.00 T&D Losses GWh 4795.52 4343.71 4217.00 3880.00 3817.00 6 (excluding Auxiliary Consumption) % 32.26 29.71 27.82 25.30 23.69 7 Percentage (%) Ratio of Fuel Consumption in KEL Generation 2010-11 2011-12 2012-13 2013-14 2014-15 7.1 Gas 65.53 72.00 73.00* 75.00 73.00 7.2 Furnace Oil 34.47 28.00 27.00* 25.00 27.00 * Based on SSGC Gas Bills 8 Average Fuel Price 2010-11 2011-12 2012-13 2013-14 2014-15 8.1 Gas (Rs./MCF) 393.76 471.98 525.00* 515.23* 488.23* 8.2 Furnace Oil (Rs./M. Ton.) 44200.00 56009.64 65509.00 65906.00 51391.00 8.3 LDO (Rs./Ltr.) 0.00 0.00 0.00 0.00 0.00 8.4 HSD (Rs./Ltr.) 0.00 0.00 0.00 0.00 0.00 * This is based on GIDC of Rs.27/MMBTU, effective from October 8, 2012 as per the Order of Honourable High Court of Sindh. Source: K-Electric Limited

95 State of Industry Report 2015

Figure 10. T&D Losses of K-EL (GWh) (excluding Auxiliary Consumption)

3880.00 5330.00 (25.30%) (34.99%)

4217.00 (27.82%) 4795.52 (32.26%) 4343.71 (29.71%)

2010-11 2011-12 2012-13 2013-14 2014-15

TABLE 11 Thermal Electricity Generation by Fuel (GWh)

2010-11 2011-12 2012-13 2013-14 2014-15 In PEPCO Area Gas* 31,498 24,161 21,817 23,877 23,903 Percentage share to the total thermal 56.90 42.87 40.24 41.29 40.55 generation in PEPCO Percentage share to the total thermal 48.33 36.90 34.07 35.07 34.15 generation in the Country FO + HSD** 23,796 32,135 32,357 33,836 34,948 Percentage share to the total thermal 42.98 57.02 59.68 58.51 59.28 generation in PEPCO Percentage share to the total thermal 36.51 49.08 50.53 49.70 49.93 generation in the Country Coal 66 66 40 112 102 Percentage share to the total thermal 0.12 0.12 0.07 0.19 0.17 generation in PEPCO Percentage share to the total thermal 0.10 0.10 0.06 0.16 0.15 generation in the Country Sub-Total 55,360 56,362 54,214 57,825 58,953 Percentage share to the total thermal 84.95 86.08 84.66 84.93 84.23 generation in the Country In KEL Area Gas* 5,578 6,001 6,373 6,892 7,293 Percentage share to the total thermal 56.87 65.83 64.90 67.19 66.09 generation in KEL Percentage share to the total thermal 8.56 9.16 9.95 10.12 10.42 generation in the Country Continued.....

96 State of Industry Report 2015

2010-11 2011-12 2012-13 2013-14 2014-15 FO + HSD** 4,188 3,115 3,447 3,365 3,742 Percentage share to the total thermal 42.70 34.17 35.10 32.81 33.91 generation in KEL Percentage share to the total thermal 6.43 4.76 5.38 4.94 5.35 generation in the Country Coal 43 0 0 0 0 Percentage share to the total thermal 0.44 0.00 0.00 0.00 0.00 generation in KEL Percentage share to the total thermal 0.07 0.00 0.00 0.00 0.00 generation in the Country Sub-Total 9,809 9,116 9,820 10,257 11,035 Percentage share to the total thermal 15.05 13.92 15.34 15.07 15.77 generation in the Country In the Country Gas 37,076 30,162 28,190 30,769 31,196 Percentage share to the total thermal 56.89 46.06 44.02 45.19 44.57 generation in the Country FO + HSD 27,984 35,250 35,804 37,201 38,690 Percentage share to the total thermal 42.94 53.83 55.91 54.64 55.28 generation in the Country Coal 109 66 40 112 102 Percentage share to the total thermal 0.17 0.10 0.06 0.16 0.15 generation in the Country Total 65,169 65,478 64,034 68,082 69,988 * Including generation of SPPs. ** Including generation of CPPs. Source: PSS/NTDC/KEL

TABLE 12 Fuel Cost in GENCOs and K-Electric Limited Fiscal Year Cost of Fuel Electricity Generation Cost of Fuel ending 30th (Rs. in million) (GWh) (Paisa/kWh) June GENCOs KEL Own GENCOs KEL Own GENCOs KEL Own 2010-11 151,260 50,691 13,018 7,826 1,159.61 647.73 2011-12 144,251 58,436 12,652 8,029 1,060.00 727.81 2012-13 165,065 67,808 12,872 8,567 1,167.00 791.50 2013-14 193,334 64,336 13,016 8,709 1,283.38 738.73 2014-15 n.p. 59,950 13,300 9,319 1,025.69 643.31 Source: PSS/NTDC/KEL

97 State of Industry Report 2015

TABLE 13 Fuel Consumption and Cost of Electricity Generation in GENCOs 2010-11 2011-12 2012-13 2013-14 2014-15 GAS: Generation on Gas (GWh) 7,184.00 7,857.00 7,410.60 5,099.22 n.p. Quantity of Gas Used (000 MCF) 97,029.00 103,294.00 102,912.00 55,788.00 n.p. Consumption/kWh (Cft) 13.51 13.17 13.89 10.94 n.p. Cost/kWh (Paisa) 428.81 494.88 597.00 588.00 n.p. FURNACE OIL (FO): Generation on Furnace Oil (GWh) 6,802.45 5,639.00 6,676.30 8,971.30 n.p. Quantity of Furnace Oil Used (000 1,882.00 1,542.00 1,741.99 2,325.20 n.p. M.Tons) Consumption/kWh (Kg) 0.28 0.27 0.26 0.26 n.p. Cost/kWh (Paisa) 1367.49 1,854.17 1,806.00 1,814.00 n.p. HIGH SPEED DIESEL (HSD): Generation on HSD (GWh) 35.00 13.00 - - n.p. Quantity of HSD Used (000 Ltrs.) 10,057.00 3,460.00 420.12 368.38 n.p. Consumption/kWh (Ltr.) 0.29 0.32 - - n.p. Cost/kWh (Paisa) 1,840.24 2,447.40 - - n.p. COAL: Generation on Coal (GWh) 66.00 66.00 40.00 112.00 n.p. Quantity of Coal Used (000 M.Tons) 96.00 105.00 63.04 160.71 n.p. Consumption/kWh (Kg) 1.09 1.09 1.04 1.03 n.p. Cost/kWh (Paisa) 278.26 339.29 348.00 374.00 n.p. Overall Fuel Cost and Cost of Fuel per kWh Overall Fuel Cost used in GENCOs for 151,260.00 144,251.00 165,065.00 193,334.00 n.p. Generation of Electricity (Rs. Million) Overall Cost of Fuel (Paisa/kWh) 1159.61 1,060.00 1,167.00 1,283.38 1,025.69 Source: PSS/NTDC

98 State of Industry Report 2015

TABLE 14 Fuel Consumption and Cost of Generation Data - GENCOs Gas Consumption FO Consumption Total Cost of Gen. on Gas Gen. on Power Station Year Generation Generation (GWh) Total Cft/kWh FO (GWh) (000 (Kg/ (MMCFT) (Average) M.Ton) kWh) (GWh) (Paisa/kWh) 2010-11 477.00 7,226 13.48 2,020.00 623 0.27 2,497.00 1,258.60 TPS 2011-12 67.32 881 11.16 1,377.82 466 0.29 1,445.14 1,839.00 Jamshoro 2012-13 151.00 2,105 13.07 1,530.00 462 0.27 1,681.00 1,704.00 (GENCO-I) 2013-14 2,951.00 623 12.09 46.00 852 0.26 2,997.00 1,980.76 2014-15 418.58 n.p. n.p. 2,236.62 n.p. n.p. 2,655.21 1363.79 2010-11 452.00 5,530 11.72 0.00 - - 452.00 575.24 2011-12 270.00 3,228 11.37 0.00 - - 270.00 517.00 GTPS Kotri 2012-13 190.00 6,483 13.06 0.00 - - 190.00 742.00 (GENCO-I) 2013-14 169.98 2,144 11.98 0.00 - - 169.98 799.63 2014-15 306.11 n.p. n.p. 0.00 - - 306.11 662.35 2010-11 5,714.00 80,245 - 149.00 46 0.26 5,863.00 - 2011-12 7,093.00 96,602 - 165.00 49 0.28 7,258.00 - TPS Guddu 2012-13 6,357.00 91,846 - 0.70 0 0.28 6,357.70 - (GENCO-II) 2013-14 4,357.48 47,747 - 0.00 0 0.00 4,357.48 638.44 2014-15 5,511.72 n.p. n.p. n.p. 0 0.00 5,511.72 565.80 2010-11 94.00 1,558 16.25 0.00 - - 94.00 646.23 TPS Quetta 2011-12 105.41 1,765 16.32 0.00 - - 105.41 773.00 (Isolated 2012-13 97.00 1,744 17.62 0.00 - - 97.00 918.00 Generation) (GENCO-II) 2013-14 87.19 1,549 18.29 0.00 - - 87.19 930.86 2014-15 98.13 n.p. n.p. 0.00 - - 98.13 866.89 2010-11 16.00 381 20.44 3,613.00 1,124 0.27 3,629.00 1,417.98 TPS 2011-12 23.76 312 20.67 3,254.84 954 0.26 3,278.61 1,840.00 Muzaffargarh 2012-13 5.50 326 53.84 4,471.50 1,279 0.26 4,477.00 1,811.00 (GENCO-III) 2013-14 8.45 296 36.25 5,134.00 1474 0.26 5,142.45 1,898.83 2014-15 0.00 n.p. n.p. 4,306.15 n.p. n.p. 4,306.15 1,501.36 2010-11 144.00 30 0.00 0.00 0 0 144.00 1,595.48 2011-12 35.68 61 380.25 0.00 0 0 35.68 2,241.00 SPS Faisalabad 2012-13 30.00 0 0.00 0.00 0 0 30.00 0.00 (GENCO-III) 2013-14 165.00 814 15.73 0.00 0 0 165.00 1,645.13 2014-15 7.21 n.p. n.p. 39.89 0 0 47.10 2,217.08 2010-11 0.00 12 0.00 51.00 23 0.37 51.00 2,267.63 2011-12 0.00 4 0.00 45.30 22 0.40 45.30 2,318.00 NGPS Multan 2012-13 0.00 0 0.00 0.00 0 0.00 0.00 0.00 (GENCO-III) 2013-14 0.00 0 0.00 0.00 0 0.00 0.00 0.00 2014-15 0.00 0 0.00 0.00 0 0.00 0.00 1.00

FO Consumption Gen. HSD Consumption Total Cost of Gen. on FO Power Station Year (000 on HSD (000 (Kg/ Generation Generation (GWh) (Kg/kWh) M.Ton) (GWh) M.Ton) kWh) (GWh) (Paisa/kWh) 2010-11 188.00 2,046 12.87 34.00 9,728 - 222.00 847.15 2011-12 144.00 441 11.96 5.14 2,978 - 149.14 581.00 GTPS Faisalabad 2012-13 0.00 408 11.51 0.00 0 - 0.00 622.00 (GENCO-III) 2013-14 0.00 2,613 13.25 0.00 0 - 0.00 724.00 2014-15 29.88 n.p. n.p. 0.00 0 - 29.88 526.26 Nandipur 2014-15 n.p. n.p. n.p. 244.00 n.p. n.p. 244.00 n.p. (GENCO-III) Continued.....

99 State of Industry Report 2015

FBC Lakhara (GENCO-IV) Generation on Coal Coal Consumption Coal Consumption Cost of Generation Year (GWh) (000 metric tons) (kg/kWh) (Paisa/kWh) 2010-11 66.00 96 1.09 1,141.99 2011-12 66.00 105 1.09 312.00 2012-13 40.00 63 1.04 358.00 2013-14 112.00 161 1.03 422.86 2014-15 102.27 n.p. n.p. 465.98 Source: PSS/NTDC

TABLE 15 Fuel Consumption and Cost of Generation Data - K-Electric Limited Dual (Gas+Furnace Oil) Gas Consumption FO Consumption Cost of Gen. on Gen. Total Power Total Generation Year Gas Total CFT/kWh on FO (kg/ Generation Station (000 M. (Paisa/ (GWh) MMCFT (Average) (GWh) kWh) (GWh) Tons) kWh) 2010-11 2,492 28,756 11.54 2,576 681.00 0.26 5,068 798 2011-12 2,577 29,279 11.36 2,127 560.00 0.26 4,704 934 Bin Qasim 2012-13 1,446 16,299 11.00 2,276 587.00 0.30 3,722 1,250 TPS-I 2013-14 1,865 19,624 10.50 1,900 497.00 0.26 3,765 1,249 2014-15 1,802 18,313 10.20 2,122 568.00 0.30 3,924 1,073 2010-11 271 3,533 13.06 0 0.00 0.00 271 498 2011-12 163 2,199 13.48 0 0.00 0.00 163 564 Korangi 2012-13 0 0 0.00 0 0.00 0.00 0 0 TPS 2013-14 0 0 0.00 0 0.00 0.00 0 0

2014-15 0 0 0.00 0 0.00 0.00 0 0

Gas Power Gas Consumption Cost of Generation Year Gen. on Gas (GWh) Station Total MMCFT CFT/kWh (Average) (Paisa/kWh) 2011-12 1,139 11,111 9.75 440 2012-13 3,567 31,740 9.00 434 BQTPS-II 2013-14 3,639 30,333 8.00 454 2014-15 3,907 30,775 7.90 417 2010-11 1 12 19.92 700 2011-12 0 0 0.00 0 Korangi Town 2012-13 0 0 0.00 0 GTPS-I 2013-14 0 0 0.00 0 2014-15 0 0 0.00 0 2010-11 675 7,112 10.53 0 2011-12 595 6,188 10.39 462 Korangi Town 2012-13 327 3,452 11.00 505 GTPS-II 2013-14 393 4,140 10.50 512 2014-15 435 4,321 9.90 476 Continued.....

100 State of Industry Report 2015

Gas Power Gas Consumption Cost of Generation Year Gen. on Gas (GWh) Station Total MMCFT CFT/kWh (Average) (Paisa/kWh) 2010-11 0 2 20.49 700 2011-12 0 0 0.00 0 Site GTPS-I 2012-13 0 0 0.00 0 2013-14 0 0 0.00 0 2014-15 0 0 0.00 0 2010-11 586 6,075 10.36 378 2011-12 416 4,311 10.41 440 Site GTPS-II 2012-13 156 1,678 11.00 546 2013-14 113 1,216 10.80 541 2014-15 160 1,659 10.40 490 2010-11 1,226 10,704 8.73 333 2011-12 1,011 8,678 8.59 393 Korangi 2012-13 795 6,629 8.00 433 CCPP 2013-14 799 6,961 8.70 487 2014-15 892 7453 8.40 451 Furnace Oil FO Consumption Power Cost of Generation Year Gen. on FO (GWh) Total Station (kg/kWh) (Paisa/kWh) (000 M. Tons) 2010-11 745 n.p. n.p. 1,324 2011-12 452 n.p. n.p. 1,584 Gul Ahmed 2012-13 432 n.p. n.p. 1,564 2013-14 582 n.p. n.p. 1,846 2014-15 718 n.p. n.p. 1,442 2010-11 793 172.92 n.p. 1,330 2011-12 481 n.p. n.p. 1,512 Tapal Energy 2012-13 684 n.p. n.p. 1,548 2013-14 798 n.p. n.p. 1,795 2014-15 807 n.p. n.p. 1435 Source: KEL

101 State of Industry Report 2015 TABLE 16 Fuel Consumption and Cost of Generation Data – IPPs Furnace Oil Average Fuel Cost Overall Generation Power Station Year Units Generated Quantity of FO (Rs./kWh) Cost (Rs./kWh) (GWh) used (M. Tons) Steam Turbine-RFO 2010-11 1104 260986 13.39 15.68 2011-12 1787 431390 16.10 18.78 Lal Pir Power 2012-13 1643 398303 16.46 19.03 2013-14 2081 495584 16.66 18.88 2014-15 1663 391215 12.00 14.32 2010-11 1300 310420 12.19 15.12 2011-12 1689 408873 15.92 18.99 Pak Gen. Power 2012-13 1936 462041 16.36 18.64 2013-14 2031 489366 16.81 19.31 2014-15 1222 289599 14.53 17.06 2010-11 8114 1901299 11.83 14.95 2011-12 7769 1812055 15.74 18.66 HUBCO 2012-13 7673 1801653 17.54 19.35 2013-14 7086 1681641 16.73 18.86 2014-15 6809 1609458 13.58 15.89 2010-11 244 62269 11.39 17.37 2011-12 116 30410 15.65 25.12 Saba Power 2012-13 91 21516 16.98 25.29 2013-14 129 33261 17.46 22.92 2014-15 33 8924 16.46 17.63 Engine - RFO 2010-11 371 84109 11.06 12.85 2011-12 281 64151 14.64 17.58 Japan Power 2012-13 101 23345 n.p. n.p. 2013-14 0 0 0.00 0 2014-15 0 0 0.00 0 2010-11 466 103056 10.39 14.13 2011-12 245 54436 14.29 19.68 Southern Power 2012-13 97 22750 15.19 17.22 2013-14 0 0 0.00 0 2014-15 0 0 0.00 0 2010-11 888 160392 10.78 12.31 2011-12 727 142004 14.60 16.65 Kohinoor Energy 2012-13 747 140857 13.09 15.86 2013-14 890 172037 15.65 16.99 2014-15 877 169389.6 12.05 13.36 2010-11 1203 218970 11.49 14.36 2011-12 1172 n.p. 15.29 18.14 Attock Gen. 2012-13 1255 n.p. 14.73 17.26 2013-14 1243 225236 14.87 17.43 2014-15 1209 222892 15.43 18.21 2010-11 1484 289469 11.02 14.77 2011-12 1067 n.p. 14.80 18.24 Atlas Power 2012-13 1383 n.p. 14.90 17.99 2013-14 1519 294601 13.57 16.38 2014-15 1462 283960 15.92 19.21 2010-11 1473 279219 10.83 13.79 2011-12 1063 n.p. 14.96 18.61 Nishat Power 2012-13 1276 n.p. 15.80 18.91 2013-14 1464 287997 14.17 16.80 2014-15 1410 277312 11.07 13.64 Continued..... 102 State of Industry Report 2015

Furnace Oil Average Fuel Cost Overall Generation Power Station Year Units Generated Quantity of FO (Rs./kWh) Cost (Rs./kWh) (GWh) used (M. Tons) 2010-11 1452 256117 11.11 14.37 2011-12 1073 n.p. 15.02 18.95 Nishat Chunian 2012-13 1283 n.p. 15.69 18.95 2013-14 1471 289439 14.12 16.81 2014-15 1415 278398 11.05 13.77 2010-11 997 124767 11.44 13.10 2011-12 1068 n.p. 14.85 19.32 Liberty Power 2012-13 1438 n.p. 15.07 18.02 Tech. 2013-14 1520 298903 14.27 17.06 2014-15 1515 297916 15.42 18.57 2010-11 464 61935 11.89 13.32 2011-12 1321 n.p. 14.86 17.15 HUBCO Narowal 2012-13 820 n.p. 15.22 22.17 2013-14 1562 308585 14.28 18.33 2014-15 1418 278760 11.73 16.26 Gas Average Fuel Cost Overall Generation Power Station Year Units Generated Quantity of Gas (Rs./kWh) Cost (Rs./kWh) (GWh) used (MMBTU) Gas Engines / Gas Turbine (CCPP) 2010-11 179 1827204 3.06 5.54 2011-12 182 1829598 3.99 6.31 Altern 2012-13 194 1759674 5.58 7.48 Energy 2013-14 205 2021299 5.63 7.63 2014-15 173 1744940 5.37 7.38 2010-11 1088 9161323 2.82 5.65 2011-12 1237 10458701 3.10 5.24 Fauji Kabirwala 2012-13 1107 8735108 4.37 5.65 2013-14 1191 10203547 4.42 5.50 2014-15 991 8514108 4.62 6.02 2010-11 811 6692114 2.71 4.89 2011-12 685 5792294 3.61 6.29 Habibullah Coastal 2012-13 658 5686043 5.26 7.53 2013-14 670 5734357 4.65 7.40 2014-15 719 6187693 4.63 7.06 2010-11 3039 24342820 2.78 4.98 2011-12 2733 21952366 3.56 6.06 Rousch 2012-13 2535 20172645 4.91 5.19 Power 2013-14 2760 20002297 4.63 5.89 2014-15 2465 19635093 4.49 7.22 2010-11 1333 10848976 7.55 10.29 2011-12 1484 12045461 10.13 13.34 TNB Liberty Power 2012-13 892 7269215 11.02 12.33 2013-14 943 7640542 17.40 22.52 2014-15 1218 10004282 12.39 14.66 2010-11 4221 32561224 2.22 5.07 2011-12 4278 33037265 2.27 5.04 Uch Power 2012-13 3796 28724603 3.07 5.65 2013-14 4314 30644390 3.01 5.63 2014-15 4127 31549804 2.93 5.08 Davis 2013-14 54 397509 7.14 11.17 Energen. 2014-15 70 n.p. 5.20 8.09 Continued.....

103 State of Industry Report 2015

Gas FO Overall HSD Total Average Power Generation Year Units Quantity of Units Quantity Generation Generation Fuel Cost Station Cost (Rs./ Generated Gas used Generated of FO used (GWh) (GWh) (Rs./kWh) (GWh) (MMBTU) (GWh) (M.Tons) kWh) Dual Fuel 2010-11 446 4332015 5175 1056863 68 5689 10.08 15.21 2011-12 414 4228212 5629 1156728 22 6065 13.57 19.01 KAPCO 2012-13 170 1673453 5222 1064832 129 5521 12.44 19.83 2013-14 306 3116410 6027 1233299 146 6479 14.04 20.00 2014-15 845 8097993 5852 1179958 236 6933 13.37 16.39

Gas Overall HSD Total Average Generation Power Station Year Units Quantity of Generation Generation Fuel Cost Cost (Rs./ Generated Gas used (GWh) (GWh) (Rs./kWh) (GWh) (MMBTU) kWh) 2010-11 705 5427189 137 842 4.00 6.49 2011-12 404 n.p. 467 871 12.12 16.62 Sapphire 2012-13 369 n.p. 509 877 14.20 18.07 Electric 2013-14 268 2051567 493 761 15.61 20.95 2014-15 282 2153880 685 967 14.60 19.24 2010-11 1056 7762893 116 1172 4.04 7.33 2011-12 398 n.p. 512 909 12.52 16.52 Saif Power 2012-13 386 n.p. 357 742 12.69 17.17 2013-14 265 2037078 458 723 15.47 21.56 2014-15 95 744873 675 771 16.01 21.83 2010-11 983 7311571 107 1090 3.90 6.22 2011-12 487 n.p. 195 682 9.82 14.28 Orient Power 2012-13 346 n.p. 228 573 11.40 16.32 2013-14 266 2065360 274 541 13.60 20.31 2014-15 311 2385081 726 1037 14.44 18.14 2010-11 1562 15134204 n.p. n.p. 3.09 4.60 2011-12 1742 n.p. 2 1744 4.04 5.84 Engro Power 2012-13 1692 n.p. 2 1693 4.79 6.72 Gen. Qadirpur 2013-14 1441 11881740 0 1441 5.06 5.37 2014-15 1429 11993204 0 1429 5.06 5.37 2010-11 403 1312680 n.p. n.p. 3.09 4.33 2011-12 1401 n.p. n.p. n.p. 3.71 6.05 Foundation 2012-13 1380 n.p. n.p. n.p. 4.84 7.14 Power 2013-14 1359 10563546 0 1359 4.91 7.25 2014-15 1305 10421325 18 1322 4.36 7.71 2011-12 407 n.p. 162 570 8.45 11.48 Halmore 2012-13 294 n.p. 79 374 8.23 18.42 Power 2013-14 250 n.p. 254 504 6.10 13.66 2014-15 93 n.p. 620 713 9.43 13.98 2013-14 752 n.p. 0 752 3.45 6.18 Uch Power-II 2014-15 2415 18014780 0 2415 1.08 1.94 Source: PSS/WPPO (NTDC)

104 State of Industry Report 2015

TABLE 17 Auxiliary Consumption and other Factors of Hydel Power Stations Power Auxiliary Consumption Maximum Load Factor Capacity Utilization Year Station (GWh) (%) Load (MW) (%) Factor (%) Factor (%) 2010-11 97.44 --- 3594 50.70 103.34 52.39 2011-12 48.30 0.30 3702 43.38 106.44 46.17 Tarbela 2012-13 18.02 0.12 3674 45.95 105.64 48.54 2013-14 16.07 0.10 3605 47.93 103.65 49.68 2014-15 15.94 0.11 3605 46.89 103.65 48.61 2010-11 118.86 --- 1150 60.26 115.00 69.30 2011-12 133.40 2.80 1120 48.78 112.00 54.64 Mangla 2012-13 10.00 0.21 1115 48.25 111.50 53.80 2013-14 10.08 0.17 1115 59.95 111.50 66.84 2014-15 11.31 0.17 1115 66.51 111.50 73.86 2010-11 80.68 --- 1450 58.37 100.00 58.37 2011-12 98.56 1.40 1450 55.43 100.00 55.43 Ghazi 2012-13 8.67 0.12 1450 56.41 100.00 56.41 Barotha 2013-14 9.61 0.11 1450 55.02 100.00 55.02 2014-15 7.75 0.12 1450 52.70 100.00 57.94 2010-11 4.19 --- 215 55.09 88.49 48.75 2011-12 0.32 0.00 204 55.31 83.96 46.44 Warsak 2012-13 1.50 0.14 203 58.09 83.55 48.53 2013-14 1.58 0.16 201 52.89 82.73 43.77 2014-15 1.63 0.17 185 60.17 76.14 45.82 2010-11 -85.14 --- 184 56.66 100.00 56.66 2011-12 7.95 0.70 184 62.86 100.00 62.86 Chashma 2012-13 5.97 0.53 184 69.62 100.00 69.62 2013-14 6.05 0.58 184 63.75 100.00 63.76 2014-15 5.64 0.01 184 61.22 100.00 61.22 2010-11 0.32 --- 19 51.08 92.50 47.25 2011-12 0.37 0.40 17 56.69 85.00 48.18 Dargai 2012-13 0.30 0.31 18 60.32 90.48 55.19 2013-14 0.30 0.33 18 56.65 68.50 50.98 2014-15 0.41 0.39 18 67.59 79.52 60.63 2010-11 4.99 --- 19 60.51 86.36 52.26 2011-12 2.93 4.30 16 48.42 72.73 35.21 Rasul 2012-13 0.51 1.03 9 59.47 43.18 25.68 2013-14 0.80 1.52 13 47.85 56.82 28.10 2014-15 2.80 4.18 14 67.27 63.64 36.36 2010-11 2.60 --- 8 49.12 56.30 27.65 2011-12 0.91 2.80 7 82.55 52.59 41.58 Shadiwal 2012-13 0.42 1.34 7 69.23 38.36 26.54 2013-14 0.39 1.27 6 55.59 39.81 25.94 2014-15 0.44 1.7 5 60.87 36.30 22.10 Continued.....

105 State of Industry Report 2015

Power Auxiliary Consumption Maximum Load Factor Capacity Utilization Year Station (GWh) (%) Load (MW) (%) Factor (%) Factor (%) 2010-11 0.90 --- 8 49.08 60.61 29.75 2011-12 2.25 6.50 8 49.06 60.61 29.74 Chichoki 2012-13 0.40 0.93 8 61.49 60.61 37.27 Malian 2013-14 0.40 1.09 9 46.31 58.25 31.58 2014-15 0.35 0.89 7 53.88 53.03 28.57 2010-11 0.88 --- 9 54.57 66.67 36.38 2011-12 0.90 2.20 9 55.00 66.67 50.12 Nandipur 2012-13 0.60 1.13 9 62.47 66.67 41.64 2013-14 0.50 1.18 9 52.03 66.67 34.69 2014-15 0.81 2.30 9 43.09 66.67 28.72 2010-11 2.10 --- 4 34.29 100.00 34.29 2011-12 0.48 4.40 4 31.05 100.00 31.05 Kurram 2012-13 0.43 3.01 4 40.78 100.00 40.78 Garhi 2013-14 0.44 2.09 4 57.16 100.00 54.30 2014-15 0.54 2.70 4 56.25 100.00 56.25 2010-11 0.04 --- 1 40.69 72.73 29.59 2011-12 0.06 2.00 1 41.04 72.72 29.85 Renala 2012-13 0.03 0.95 1 63.75 46.61 32.83 2013-14 0.02 0.68 1 56.14 45.65 30.00 2014-15 0.04 1.60 1 54.83 43.79 25.67 2010-11 0.02 --- 1 39.25 100.00 39.25 2011-12 0.02 0.40 1 38.33 103.80 39.79 Chitral 2012-13 0.01 0.30 1 42.28 103.80 49.97 2013-14 0.01 0.30 1 42.02 103.20 41.90 2014-15 0.01 0.19 1 46.36 102.90 42.09 2011-12 3.34 1.90 68 30.38 30.38 28.69 Khan 2012-13 1.35 0.00 72 41.24 41.24 41.24 Khwar 2013-14 1.24 1.80 72 41.24 41.40 41.24 2014-15 4.40 1.99 72 40.11 40.11 40.11 2012-13 1.99 0.99 60 38.63 24.02 24.02 Jinnah 2013-14 3.18 1.10 70 48.25 61.44 35.18 2014-15 2.91 1.50 45 47.95 47.29 22.67 2012-13 0.11 0.05 121 44.34 65.21 44.34 Allai 2013-14 0.84 0.18 121 44.45 90.95 44.45 Khwar 2014-15 0.79 0.17 121 44.19 78.32 43.44 Gomal 2013-14 0.02 0.38 17 16.99 17.80 17.00 Zam 2014-15 0.18 2.04 17 31.01 66.00 31.00 2013-14 0.58 0.77 22 38.37 100.00 38.37 Jabban 2014-15 0.92 0.76 22 61.85 81.25 76.12 Duber 2013-14 0.19 0.07 130 65.55 59.71 64.77 Khwar 2014-15 0.74 0.12 130 53.59 100.00 53.59 Source: PSS/NTDC

106 State of Industry Report 2015

TABLE 18 Auxiliary Consumption and other Factors of Public Sector Thermal Power Stations Auxiliary Maximum Load Factor Capacity Utilization Power Station Year Consumption Load (MW) (%) Factor (%) Factor (%) (GWh) (%) 2010-11 306.99 11.46 645 49.49 79.38 43.85 2011-12 211.21 12.75 510 36.98 60.00 27.00 TPS Jamshoro 2012-13 206.19 10.93 520 41.42 61.18 30.77 (GENCO-I) 2013-14 345.71 10.47 722 52.07 84.94 53.70 2014-15 n.p. n.p. n.p. n.p. n.p. n.p. 2010-11 19.69 4.17 135 39.89 77.59 37.39 2011-12 13.81 5.00 108 29.92 62.00 23.00 GTPS Kotri 2012-13 28.81 5.80 114 49.70 65.52 40.47 (GENCO-I) 2013-14 10.10 5.64 119 17.13 68.39 14.56 2014-15 n.p. n.p. n.p. n.p. n.p. n.p. 2010-11 n.p. n.p. n.p. n.p. n.p. n.p. 2011-12 n.p. n.p. n.p. n.p. n.p. n.p. TPS Guddu 2012-13 n.p. n.p. n.p. n.p. n.p. n.p. (GENCO-II) 2013-14 n.p. n.p. n.p. n.p. n.p. n.p. 2014-15 n.p. n.p. n.p. n.p. n.p. n.p. 2010-11 0.00 n.p. 25 43.68 99.27 39.10 TPS Quetta 2011-12 2.40 2.00 25 49.00 71.00 49.00 (Isolated 2012-13 2.51 2.54 26 43.47 74.29 45.21 Generation) (GENCO-II) 2013-14 2.26 2.67 25 38.57 71.43 38.57 2014-15 n.p. n.p. n.p. n.p. n.p. n.p. 2010-11 478.12 11.64 785 59.73 58.15 43.01 2011-12 402.62 10.94 865 48.45 64.07 37.93 TPS Muzaffargarh 2012-13 478.86 9.66 1115 50.74 82.59 50.06 (GENCO-III) 2013-14 596.52 10.41 1157 56.37 85.70 57.72 2014-15 n.p. n.p. n.p. n.p. n.p. n.p. 2010-11 24.13 11.60 85 27.94 64.39 24.79 2011-12 19.71 12.06 72 25.83 54.54 19.37 SPS Faisalabad 2012-13 0.92 0.00 0 0.00 0.00 0.00 (GENCO-III) 2013-14 7.89 15.25 70 8.42 53.03 5.89 2014-15 n.p. n.p. n.p. n.p. n.p. n.p. 2010-11 0.01 n.p. 210 10.55 94.06 10.55 2011-12 7.03 14.69 92 5.92 37.70 2.59 GTPS Faisalabad 2012-13 5.43 15.30 69 5.87 28.28 1.93 (GENCO-III) 2013-14 16.54 8.39 192 11.70 78.69 10.69 2014-15 n.p. n.p. n.p. n.p. n.p. n.p. 2010-11 9.82 16.14 72 9.65 36.92 3.56 2011-12 9.37 16.84 64 9.90 49.00 11.00 NGPS Multan 2012-13 2.04 0.00 0 0.00 0.00 0.00 (GENCO-III) 2013-14 1.34 0.00 0 0.00 0.00 0.00 2014-15 n.p. n.p. n.p. n.p. n.p. n.p. Nandipur 2014-15 n.p. n.p. n.p. n.p. n.p. n.p. (GENCO-III) 2010-11 22.52 25.52 36 27.99 30.00 8.40 2011-12 30.46 32.00 32 34.14 64.00 36.00 FBC Lakhra 2012-13 20.97 34.51 40 17.34 80.00 23.12 (GENCO-IV) 2013-14 30.46 19.44 34 52.45 68.00 59.45 2014-15 n.p. n.p. n.p. n.p. n.p. n.p. Source: PSS/NTDC

107 State of Industry Report 2015

TABLE 19 Auxiliary Consumption and other Factors of K-Electric and Other Thermal Power Stations Power Auxiliary Consumption Year Maximum Load Factor Capacity Utilization Station (GWh) (%) Load (MW) (%) Factor (%) Factor (%) K-EL 2010-11 435.91 8.60 1095 52.84 86.90 45.92 2011-12 414.00 8.80 1040 52.00 42.50 83.00 Bin Qasim 2012-13 341.00 9.16 1030 41.00 34.00 82.00 TPS-I 2013-14 341.00 9.06 890 51.00 51.00 85.00 2014-15 360.00 9.20 915 n.p. n.p. 71.00 2011-12 102.00 8.95 529 55.00 23.17 94.00 Bin Qasim 2012-13 239.00 6.70 566 74.00 73.00 100.00 TPS-II 2013-14 237.00 6.51 560 79.00 74.00 100.00 2014-15 251.00 6.40 548 n.p. n.p. 97.90 2010-11 34.10 12.61 70 82.42 24.70 24.70 2011-12 20.00 12.27 65 93.00 14.86 52.00 Korangi 2012-13 2.00 0.00 0 0.00 0.00 0.00 TPS 2013-14 0.00 0.00 0 0.00 0.00 0.00 2014-15 0.00 0.00 0 0.00 0.00 0.00 2010-11 0.02 3.28 17 70.98 81.48 71.42 Korangi 2011-12 0.00 0.00 0 0.00 0.00 0.00 Town 2012-13 0.00 0.00 0 0.00 0.00 0.00 GTPS-I 2013-14 0.00 0.00 0 0.00 0.00 0.00 2014-15 0.00 0.00 0 0.00 0.00 0.00 2010-11 15.13 2.24 88 88.00 87.57 n.p. Korangi 2011-12 14.00 2.35 88 78.00 77.02 100.00 Town 2012-13 9.00 2.75 88 54.00 42.00 100.00 GTPS-II 2013-14 10.00 2.54 85 55.00 51.00 94.40 2014-15 11.00 2.60 85 n.p. n.p. 96.60 2010-11 0.01 10.00 15 82.00 81.48 61.97 2011-12 0.00 0.00 0 0.00 0.00 0.00 Site 2012-13 0.00 0.00 0 0.00 0.00 0.00 GTPS-I 2013-14 0.00 0.00 0 0.00 0.00 0.00 2014-15 0.00 0.00 0 0.00 0.00 0.00 2010-11 15.06 2.57 88 80.00 76.04 n.p. 2011-12 11.00 2.64 88 73.00 53.87 100.00 Site GTPS- 2012-13 8.00 5.13 88 60.00 20.00 100.00 II 2013-14 7.00 5.80 85 58.00 15.00 94.40 2014-15 8.00 4.70 85 n.p. n.p. 96.60 2010-11 91.39 7.46 203 69.66 63.59 63.59 2011-12 75.00 7.42 190 66.00 52.29 83.00 Korangi 2012-13 66.00 8.30 191 58.00 41.00 87.00 CCPP 2013-14 64.00 8.01 196 66.00 41.00 89.00 2014-15 74.00 8.30 222 n.p. n.p. 89.90 IPPs (Connected with KEL System) 2010-11 21.73 n.p. 128 94.08 66.96 90.88 2011-12 n.p. n.p. 120 n.p. n.p. n.p. Gul 2012-13 n.p. n.p. n.p. n.p. n.p. n.p. Ahmed 2013-14 n.p. n.p. n.p. n.p. n.p. n.p. 2014-15 n.p. n.p. n.p. n.p. n.p. n.p. 2010-11 11.04 n.p. 124 73.31 73.31 99.54 2011-12 n.p. n.p. 117 n.p. n.p. n.p. Tapal 2012-13 n.p. n.p. n.p. n.p. n.p. n.p. Energy 2013-14 n.p. n.p. n.p. n.p. n.p. n.p. 2014-15 n.p. n.p. n.p. n.p. n.p. n.p. Source: KEL

108 State of Industry Report 2015

TABLE 20 Auxiliary Consumption and other Factors of Private Sector Thermal Power Stations Auxiliary Maximum Load Factor Capacity Utilization Power Station Year Consumption Load (MW) (%) Factor (%) Factor (%) (GWh) (%) 2010-11 1.28 5.93 351 78.90 36.30 57.60 2011-12 n.p. 6.40 350 83.80 58.00 58.30 Lal Pir Power 2012-13 115.27 6.55 350 82.64 53.60 53.60 2013-14 151.37 6.78 350 79.79 67.87 67.87 2014-15 123.67 6.92 350 75.66 65.11 65.11 2010-11 1.01 6.89 344 76.60 42.80 52.91 2011-12 n.p. 6.54 350 84.20 55.00 55.21 Pak Gen. Power 2012-13 130.94 5.96 350 84.17 63.14 63.14 2013-14 141.82 6.53 350 80.90 66.25 66.25 2014-15 95.12 7.22 350 75.14 59.87 59.87 2010-11 n.p. 3.00 n.p. 96.79 77.00 94.88 2011-12 n.p. 2.80 27 95.51 78.00 97.47 Altern Energy 2012-13 10.59 5.18 30 93.05 93.90 94.82 2013-14 10.94 5.06 30 94.50 96.10 94.94 2014-15 9.04 4.96 30 97.35 96.33 95.04 2010-11 30.51 2.83 157 92.25 82.11 87.72 2011-12 n.p. 2.84 151 96.10 93.10 100.21 Fauji Kabirwala 2012-13 32.24 2.83 157 92.68 84.10 98.30 2013-14 36.03 3.16 157 94.87 89.85 94.99 2014-15 31.40 2.07 157 94.54 75.91 83.59 2010-11 20.36 2.55 129 73.13 83.13 85.80 2011-12 n.p. 2.74 129 60.86 60.40 82.93 Habibullah 2012-13 n.p. 2.40 129 58.20 57.90 53.65 Coastal 2013-14 15.66 2.32 128 70.56 59.56 76.98 2014-15 17.88 2.40 126 76.49 63.52 86.76 2010-11 453.11 5.29 1,200 77.20 89.10 86.70 2011-12 n.p. 4.87 1,200 73.70 73.70 69.40 HUBCO 2012-13 481.64 5.90 1,200 73.00 82.00 89.00 2013-14 416.21 5.00 1,200 67.40 78.30 86.30 2014-15 398.00 5.84 1,200 65.00 76.00 83.00 2010-11 17.59 4.71 121 41.00 52.40 48.47 2011-12 n.p. 4.50 107 38.50 29.90 56.60 Japan Power 2012-13 n.p. 1.50 107 10.80 10.70 8.54 2013-14 0.00 0.00 0 0.00 0.00 0.00 2014-15 0.00 0.00 0 0.00 0.00 0.00 2010-11 171.59 2.90 1,361 48.40 48.30 56.10 2011-12 n.p. 2.80 1,342 51.50 51.40 58.10 KAPCO 2012-13 158.00 2.78 1,238 47.00 91.70 51.20 2013-14 185.00 2.78 1,444 55.10 80.20 68.70 2014-15 196.00 2.75 1,431 59.00 85.54 69.00 2010-11 27.46 3.17 124 98.10 81.78 86.72 2011-12 n.p. 2.80 124 97.30 66.70 72.50 Kohinoor Energy 2012-13 22.00 2.97 124 92.84 66.71 71.09 2013-14 27.00 2.91 124 94.36 81.89 85.20 2014-15 26.35 2.92 124 93.80 80.73 84.80 Continued.....

109 State of Industry Report 2015

Auxiliary Maximum Load Factor Capacity Utilization Power Station Year Consumption Load (MW) (%) Factor (%) Factor (%) (GWh) (%) 2010-11 54.03 1.74 443 90.00 89.57 96.95 2011-12 n.p. 1.73 395 92.05 78.70 97.39 Rousch Power 2012-13 46.60 1.80 452 72.83 73.45 98.31 2013-14 48.10 1.71 457 82.13 98.99 81.75 2014-15 44.88 1.78 450 72.04 91.70 78.90 2010-11 17.04 6.94 126 47.93 22.20 22.31 2011-12 n.p. 6.73 126 46.80 10.40 10.53 Saba Power 2012-13 5.63 6.21 134 58.35 7.73 7.73 2013-14 9.05 6.53 134 46.40 11.76 11.76 2014-15 2.55 7.20 126 41.59 5.94 5.94 2010-11 15.60 3.43 111 49.74 55.24 53.48 2011-12 n.p. 2.75 110 27.90 25.20 28.42 Southern Power 2012-13 n.p. 2.46 110 10.10 9.90 9.46 2013-14 0.00 0.00 0 0.00 0.00 0.00 2014-15 0.00 0.00 0 0.00 0.00 0.00 2010-11 3.20 2.34 219 75.81 71.78 92.48 2011-12 n.p. 2.05 212 84.80 79.60 86.07 TNB Liberty 2012-13 18.78 2.04 207 55.84 48.75 86.31 Power 2013-14 18.27 1.90 219 53.93 51.07 93.24 2014-15 24.83 2.00 216 67.44 65.91 91.76 2010-11 70.44 1.67 590 87.40 87.30 87.45 2011-12 n.p. 1.59 551 88.60 88.20 88.59 Uch Power 2012-13 61.50 1.62 584 78.61 80.60 98.09 2013-14 67.73 1.57 591 89.37 90.99 99.09 2014-15 67.52 1.60 549 85.93 87.08 96.37 2010-11 n.p. n.p. n.p. n.p. n.p. n.p. 2011-12 n.p. n.p. 156 85.10 n.p. 85.70 Attock Gen. 2012-13 29.48 2.29 157 98.42 92.30 100.37 2013-14 28.86 2.27 157 98.48 91.49 100.41 2014-15 27.88 2.31 157 98.00 89.00 100.00 2010-11 54.35 n.p. 215 80.00 80.00 91.00 2011-12 n.p. n.p. 214 57.00 n.p. n.p. Atlas Power 2012-13 46.45 2.48 214 73.67 73.82 77.71 2013-14 37.66 1.96 215 81.08 81.08 86.68 2014-15 36.24 1.89 215 78.02 78.02 82.99 2010-11 n.p. n.p. n.p. n.p. n.p. n.p. 2011-12 n.p. n.p. 195 62.00 n.p. 62.10 Nishat Power 2012-13 33.44 2.55 195 83.66 72.76 83.66 2013-14 39.39 2.62 195 95.30 83.57 95.30 2014-15 38.88 2.68 195 90.13 80.47 90.13 2010-11 15.33 n.p. 196 96.89 93.68 98.08 2011-12 n.p. n.p. 196 62.20 n.p. 62.20 Liberty Power 2012-13 n.p. n.p. 196 83.70 n.p. n.p. Tech. 2013-14 32.25 2.10 197 97.70 88.44 90.58 2014-15 32.07 2.10 197 97.80 88.15 90.27 2010-11 n.p. n.p. n.p. n.p. n.p. n.p. 2011-12 n.p. n.p. 214 70.50 n.p. 70.50 HUBCO Narowal 2012-13 n.p. n.p. 214 43.80 n.p. n.p. 2013-14 30.25 1.94 217 83.41 83.41 96.13 2014-15 25.72 1.81 217 75.71 75.71 88.40 Continued.....

110 State of Industry Report 2015

Auxiliary Maximum Load Factor Capacity Utilization Power Station Year Consumption Load (MW) (%) Factor (%) Factor (%) (GWh) (%) 2010-11 26.54 n.p. 196 97.00 86.00 93.00 2011-12 n.p. n.p. 196 62.60 n.p. 62.60 Nishat Chunian 2012-13 n.p. n.p. 196 74.80 n.p. n.p. 2013-14 27.50 2.37 196 95.66 85.80 88.70 2014-15 27.40 2.36 196 93.05 81.33 85.02 2010-11 n.p. n.p. n.p. n.p. n.p. n.p. 2011-12 n.p. n.p. 212 47.00 n.p. 48.10 Sapphire Electric 2012-13 n.p. n.p. 212 47.20 n.p. n.p. Power 2013-14 23.68 2.93 225 45.61 40.87 45.73 2014-15 29.83 2.91 222 54.36 51.88 54.50 2010-11 43.81 n.p. n.p. 86.60 93.50 92.60 2011-12 n.p. n.p. 214 92.40 n.p. 93.10 Engro Power 2012-13 45.50 2.69 214 89.00 90.13 99.80 Gen. Qadirpur 2013-14 39.50 2.75 217 84.56 101.00 84.00 2014-15 41.00 2.80 217 84.00 91.00 91.00 2010-11 n.p. n.p. n.p. n.p. n.p. n.p. 2011-12 n.p. n.p. 205 47.50 n.p. 50.70 Saif Power 2012-13 n.p. n.p. 205 40.60 n.p. n.p. 2013-14 23.61 3.16 216 43.20 38.95 41.31 2014-15 24.15 3.04 220 47.52 41.86 43.03 2010-11 25.87 n.p. 224 59.00 62.00 98.00 2011-12 n.p. n.p. 213 36.60 n.p. 36.60 Orient Power 2012-13 n.p. n.p. 213 30.80 n.p. n.p. 2013-14 18.36 3.40 219 33.93 31.38 31.38 2014-15 29.17 2.81 218 65.45 60.54 60.54 2010-11 n.p. n.p. n.p. n.p. n.p. n.p. 2011-12 n.p. n.p. 172 90.00 n.p. n.p. Foundation 2012-13 49.98 3.61 193 100.10 92.90 n.p. Power 2013-14 49.55 3.64 200 97.68 92.57 90.12 2014-15 48.75 3.69 197 96.31 89.97 87.59 Uch 2013-14 n.p. n.p. n.p. n.p. n.p. n.p. Power-II 2014-15 59.16 2.38 381 72.56 73.89 79.30 Davis 2013-14 n.p. n.p. n.p. n.p. n.p. n.p. Energen. 2014-15 n.p. n.p. n.p. n.p. n.p. n.p. Source: PSS/NTDC

111 State of Industry Report 2015

TABLE 21 Main Electricity Statistics of the Country 2010-11 2011-12 2012-13 2013-14 2014-15 1: Maximum Energy Demand (MW) PEPCO Area 20,559 21,997 22,883 23,425 23,381 KEL Area 2,591 2,596 2,778 2,929 3,056 Un-diversified Energy Demand 21,086 21,536 21,605 23,505 n.p. of the Country Diversified Energy Demand of 20,673 21,114 21,181 23,044 n.p. the Country 2: Consumers (Nos.) Domestic 17,321,552 17,977,777 18,712,912 19,322,664 20,147,827 Commercial 2,421,224 2,482,677 2,550,812 2,635,089 2,723,707 Industrial 273,067 286,393 296,849 305,294 315,116 Agricultural 280,603 286,287 301,115 310,578 318,081

PEPCO Area PEPCO Public Lighting 8,386 8,696 8,927 9,158 9,348 Bulk Supply + Others 4,650 4,778 4,985 5,087 5,168 Total in PEPCO Area 20,309,482 21,046,608 21,875,600 22,587,870 23,519,247 Domestic 1,632,604 1,659,766 1,660,768 1,650,034 1,695,782 Commercial 452,667 456,537 452,329 438,150 439,130 Industrial 20,595 20,537 20,462 20,464 20,613 Agricultural 2,233 2,536 2,616 2,410 77 KEL Area Public Lighting 57 67 66 74 198 Bulk Supply + Others 1,464 423 367 202 2 Total in KEL Area 2,109,620 2,139,866 2,136,608 2,111,334 2,155,802 Total in the Country 22,419,102 23,186,474 24,012,208 24,699,204 25,675,049 3: Auxiliary Consumption and System Losses (in percentage) PEPCO Area Auxiliary Consumption 3.11 2.95 n.p. 2.70 2.70 Transmission Losses 3.03 2.82 3.05 2.82 2.63 Distribution Losses 18.37 18.17 17.60 19.80 19.90 KEL Area Auxiliary Consumption (KEL 7.56 7.92 7.76 7.56 7.55 Own) T&D Losses (excluding 32.26 29.71 27.82 25.30 23.69 Auxiliary Consumption) 4: Average Sales Price (Rs./kWh) PEPCO Area 6.25 8.03 8.94 10.35 9.32 KEL Area 8.29 9.01 11.02 12.15 12.08 5: Per Capita Electricity Consumption PEPCO system Population (Million) 162.59 165.70 168.82 172.12 n.p. Energy Sale (GWh) 71,661.57 71,155.56 70,447.04 76,493.93 78,070.12 Per capita electricity 441 431 418 445 n.p. consumption (kWh) Continued.....

112 State of Industry Report 2015

2010-11 2011-12 2012-13 2013-14 2014-15 Average Sale/ Consumer 3,260.18 3,110.80 2,970.62 3,145.62 3,088.67 (kWh) KEL system Population (Million) 13.84 14.34 15.11 16.06 n.p. Energy Sale (GWh) 10,098.00 10,280.00 10,942.00 11,454.00 12,293.00 Per capita electricity 570 586 547 487 523 consumption (kWh) Average Sale/ Consumer 4,804.03 5,121.20 5,425.00 5,695.71 (kWh) 4,774.31 Source: PSS/NTDC/DISCOs/KEL

TABLE 22 Category-wise Energy Sales in PEPCO and K-Electric System (GWh) 2010-11 2011-12 2012-13 2013-14 2014-15 PEPCO System Domestic 30,972 30,203 30,321 33,322 34,566 Percentage share 43.22 42.45 43.04 43.56 44.28 Commercial 4,682 4,562 4,434 4,793 4,853 Percentage share 6.53 6.41 6.29 6.27 6.22 Industrial 17,699 18,399 18,641 20,551 21,085 Percentage share 24.70 25.86 26.46 26.87 27.01 Agricultural 8,847 8,410 7,550 8,129 7,866 Percentage share 12.35 11.82 10.72 10.63 10.08 Public Lighting 353 363 387 390 393 Percentage share 0.49 0.51 0.55 0.51 0.50 Bulk Supply 2,581 2,598 3,623 3,837 3,846 Percentage share 3.60 3.65 5.14 5.02 4.93 Others + Traction 1,078 936 27 31 33 Percentage share 1.50 1.32 0.04 0.04 0.04 Supplied to KEL 5,449 5,684 5,463 5,441 5,427 Percentage share 7.60 7.99 7.75 7.11 6.95 Total in PEPCO area 71,662 71,156 70,447 76,494 78,070 KEL System Domestic 4,257 4,564 5,083 5,489 6,161 Percentage share 42.16 44.40 46.45 47.92 50.12 Commercial 1,043 1,128 1,507 1,507 1,589 Percentage share 10.33 10.97 13.77 13.16 12.93 Industrial 3,447 3,342 3,445 3,568 3,648 Percentage share 34.14 32.51 31.48 31.15 29.68 Continued.....

113 State of Industry Report 2015

2010-11 2011-12 2012-13 2013-14 2014-15 Agricultural 125 134 149 160 166 Percentage share 1.24 1.30 1.36 1.40 1.35 Public Lighting 82 118 111 106 110 Percentage share 0.81 1.15 1.01 0.93 0.89 Bulk Supply + Others 1,118 994 647 624 619 Percentage share 11.07 9.67 5.91 5.45 5.04 Supplied to NTDC 26 0 0 0 0 Percentage share 0.26 0.00 0.00 0.00 0.00 Total in KEL area 10,098 10,280 10,942 11,454 12,293 Country Domestic 35,229 34,767 35,404 38,811 40,727 Percentage share 46.18 45.90 46.63 47.04 47.95 Commercial 5,725 5,690 5,941 6,300 6,442 Percentage share 7.50 7.51 7.82 7.64 7.59 Industrial 21,146 21,741 22,086 24,119 24,733 Percentage share 27.72 28.70 29.09 29.23 29.12 Agricultural 8,972 8,544 7,699 8,289 8,032 Percentage share 11.76 11.28 10.14 10.05 9.46 Public Lighting 435 481 498 496 503 Percentage share 0.57 0.63 0.66 0.60 0.59 Bulk Supply + Others 4,778 4,528 4,297 4,492 4,498 Percentage share 6.26 5.98 5.66 5.44 5.30 Total in the Country* 76,285 75,752 75,926 82,507 84,936 * excluding supplied to KEL and supplied to NTDC Source: PSS/NTDC/DISCOs/KEL

TABLE 23 Category-wise Consumers and their Electricity Consumption (%) 2010-11 2011-12 2012-13 2013-14 2014-15 PEPCO Area (Consumers and Consumption in percentage to the total) Consumers 85.29 85.42 85.54 85.54 85.67 Domestic Consumption 43.22 42.45 43.04 43.56 44.28 Consumers 11.92 11.80 11.66 11.67 11.58 Commercial Consumption 6.53 6.41 6.29 6.27 6.22 Consumers 1.34 1.36 1.36 1.35 1.34 Industrial Consumption 24.70 25.86 26.46 26.87 27.01 Consumers 1.38 1.36 1.38 1.37 1.35 Agricultural Consumption 12.35 11.82 10.72 10.63 10.08 Consumers 0.04 0.04 0.04 0.04 0.04 Public Lighting Consumption 0.49 0.51 0.55 0.51 0.50 Continued..... 114 State of Industry Report 2015

2010-11 2011-12 2012-13 2013-14 2014-15 Bulk Supply + Traction + Consumers 0.02 0.02 0.02 0.02 0.02 Others Consumption 5.11 4.97 5.18 5.06 4.97 Supplied to KEL Consumption 7.60 7.99 7.75 7.11 6.95 KEL Area (Consumers and Consumption in percentage to the total) Consumers 77.39 77.56 77.73 78.15 78.66 Domestic Consumption 42.16 44.40 46.45 47.92 50.12 Consumers 21.46 21.33 21.17 20.75 20.37 Commercial Consumption 10.33 10.97 13.77 13.16 12.93 Consumers 0.98 0.96 0.96 0.97 0.96 Industrial Consumption 34.14 32.51 31.48 31.15 29.68 Consumers 0.11 0.12 0.12 0.11 0.00 Agricultural Consumption 1.24 1.30 1.36 1.40 1.35 Consumers 0.00 0.00 0.00 0.00 0.01 Public Lighting Consumption 0.81 1.15 1.01 0.93 0.89 Consumers 0.07 0.02 0.02 0.01 0.00 Bulk Supply + Others Consumption 11.07 9.67 5.91 5.45 5.04 Supplied to NTDC Consumption 0.26 0.00 0.00 0.00 0.00 Country (Consumers and Consumption in percentage to the total) Consumers 84.54 84.69 84.85 84.91 85.08 Domestic Consumption 46.18 45.90 46.63 47.04 47.95 Consumers 12.82 12.68 12.51 12.44 12.32 Commercial Consumption 7.50 7.51 7.82 7.64 7.59 Consumers 1.31 1.32 1.32 1.32 1.31 Industrial Consumption 27.72 28.70 29.09 29.23 29.12 Consumers 1.26 1.25 1.26 1.27 1.24 Agricultural Consumption 11.76 11.28 10.14 10.05 9.46 Consumers 0.04 0.04 0.04 0.04 0.04 Public Lighting Consumption 0.57 0.63 0.66 0.60 0.59 Consumers 0.03 0.02 0.02 0.02 0.02 Bulk Supply + Others Consumption 4.85 4.74 5.62 5.41 5.26 Consumers 0.00 0.00 0.00 0.00 0.00 Traction Consumption 1.41 1.24 0.04 0.04 0.04 Source: PSS/NTDC/DISCOs/KEL

10.2 Load Pattern and Peak Load Hours The electrical load pattern in the country varies from season to season; during summer season there is an increase in the inductive load while in winter season increase in resistive load has been observed. The peak hour timing in the system is normally from 6 PM to 10 PM. The hourly load figures for a typical working and non- working day in summer and winter, during 2014, are given hereunder.

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TABLE 24 Hourly System Demand (MW) Maximum Demand (MW) System Demand for a System Demand for a (January, 2014 - December, Typical day in Summer Typical Day in Winter Hours 2014) (January, 2014 - December, 2014) (January, 2014 - December, 2014) of the day Summer Winter Working day Non-working day Working day Non-working day (23-07-2014) (03-01-2014) (23-07-2014) (20-07-2014) (03-01-2014) (05-01-2014) 1 19,167 11,205 19,167 18,016 11,205 10,449 2 19,090 10,903 19,090 17,674 10,903 10,158 3 19,514 10,611 19,514 18,298 10,611 10,126 4 19,922 10,791 19,922 18,269 10,791 10,123 5 18,640 11,041 18,640 17,445 11,041 10,090 6 18,756 11,432 18,756 16,848 11,432 10,970 7 18,657 12,374 18,657 17,025 12,374 11,271 8 19,035 12,620 19,035 17,380 12,620 11,324 9 19,249 12,613 19,249 17,751 12,613 11,507 10 19,448 12,804 19,448 17,905 12,804 11,591 11 19,718 13,139 19,718 18,022 13,139 12,127 12 19,775 13,226 19,775 18,420 13,226 12,215 13 19,701 13,080 19,701 18,544 13,080 11,865 14 20,899 12,684 20,899 18,812 12,684 12,035 15 20,376 12,577 20,376 18,642 12,577 11,548 16 19,722 12,555 19,722 18,721 12,555 11,363 17 19,772 12,410 19,772 18,421 12,410 11,956 18 19,518 13,711 19,518 18,451 13,711 13,580 19 19,161 13,577 19,161 18,470 13,577 13,575 20 20,929 13,566 20,929 19,688 13,566 13,222 21 20,720 13,058 20,720 20,268 13,058 12,210 22 20,391 12,320 20,391 20,466 12,320 11,720 23 20,218 11,577 20,218 19,707 11,577 11,022 24 19,103 10,977 19,103 18,798 10,977 10,698 * Highlighted area indictes maximum demand. Source: National Power Control Centre, Islamabad

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Figure 24B. System Demand for a Typical Day in Summer and Winter (MW) 24,000 21,000 18,000 15,000 12,000 9,000 6,000 3,000 - 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 HOURS OF THE DAY

Working day Non-working day Working day Non-working day (23-07-2014) (20-07-2014) (03-01-2014) (05-01-2014)

10.3 Maximum Demand The maximum demand in PEPCO and K-Electric systems for the years 2010-11 to 2014-15 and the year-wise percentage change in maximum demand is given in the following table.

TABLE 25 Maximum Electricity Demand in the Country (MW) Financial Year ending 30th June 2010-11 2011-12 2012-13 2013-14 2014-15 PEPCO Area 20,559 21,997 22,883 23,425 23,381 % change in Maximum Demand 6.59 6.99 4.03 2.37 -0.19 KEL Area 2,591 2,596 2,778 2,929 3,056 % change in Maximum Demand 1.13 0.19 7.01 5.44 4.34 Un-diversified Energy Demand 21,086 21,536 21,605 23,505 n.p. of the Country % change in Maximum Demand 0.96 2.13 0.32 8.79 - Diversified Energy Demand of 20,673 21,114 21,181 23,044 n.p. the Country % change in Maximum Demand 0.96 2.13 0.32 8.80 - Source: PSS/NTDC/KEL

117 State of Industry Report 2015

Figure 25. Maximum Electricity Demand in the Country (MW)

25,000 2 2,883 23,425 23,381 21,997 22,500 20,559 20,000 17,500 15,000 12,500

10,000 7,500 3,056 5,000 2,591 2,596 2,778 2,929 2,500

- 2010-11 2011-12 2012-13 2013-14 2014-15 PEPCO Area KEL Area

10.4 Pattern of Electricity Consumption The overall electricity consumption in the country since 2000 was growing steadily. However, during 2014-15 electricity consumption in the country excluding K-Electric area increased by 2.06%. The sector-wise electricity consumption and their share in total electricity consumption of the country, for the years 2010-11 to 2014-15 are given in the following table.

TABLE 26 Annual Growth Rate of Electricity Consumption 2010-11 2011-12 2012-13 2013-14 2014-15 A: PEPCO area GWh 30,972 30,203 30,321 33,322 34,566 Domestic % 5.12 -2.48 0.39 9.90 3.73 GWh 4,682 4,562 4,434 4,793 4,853 Commercial % 4.83 -2.56 -2.82 8.09 1.27 GWh 17,699 18,399 18,641 20,551 21,085 Industrial % 7.96 3.96 1.32 10.24 2.60 GWh 8,847 8,410 7,550 8,129 7,866 Agricultural % -7.68 -4.94 -10.22 7.67 -3.24 GWh 353 363 387 390 393 Public Lighting % -5.14 2.84 6.67 0.73 0.87 GWh 2,581 2,598 3,623 3,837 3,846 Bulk Supply % -22.92 0.65 39.43 5.90 0.24 Others + GWh 1,078 936 27 31 33 Traction % 3494.17 -13.18 -97.10 15.52 5.16 GWh 5,449 5,684 5,463 5,441 5,427 Supplied to KEL % 4.63 4.31 -3.88 -0.40 -0.26 Total GWh 71,662 71,156 70,447 76,494 78,070 Percentage % 4.06 -0.71 -1.00 8.58 2.06 change Continued.....

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2010-11 2011-12 2012-13 2013-14 2014-15 B: KEL area GWh 4,257 4,564 5,083 5,489 6,161 Domestic % 2.14 7.21 11.37 7.99 12.24 GWh 1,043 1,128 1,507 1,507 1,589 Commercial % -4.40 8.15 33.60 0.00 5.44 GWh 3,447 3,342 3,445 3,568 3,648 Industrial % 1.77 -3.05 3.08 3.57 2.24 GWh 125 134 149 160 166 Agricultural % 20.19 7.20 11.19 7.38 3.75 GWh 82 118 111 106 110 Public Lighting % -5.75 43.90 -5.93 -4.50 3.77 Bulk Supply + GWh 1,118 994 647 624 619 Others % 4.68 -11.09 -34.91 -3.55 -0.80 Supplied to GWh 26 0 0 0 0 NTDC % 30.00 -100.00 0.00 1.00 2.00 Total GWh 10,098 10,280 10,942 11,454 12,293 Percentage % 1.74 1.80 6.44 4.68 7.32 change C: Country area GWh 35,229 34,767 35,404 38,811 40,727 Domestic % 4.75 -1.31 1.83 9.62 4.94 GWh 5,725 5,690 5,941 6,300 6,442 Commercial % 3.02 -0.60 4.40 6.04 2.27 GWh 21,146 21,741 22,086 24,119 24,733 Industrial % 6.90 2.81 1.59 9.20 2.55 GWh 8,972 8,544 7,699 8,289 8,032 Agricultural % -7.38 -4.77 -9.88 7.66 -3.11 GWh 435 481 498 496 503 Public Lighting % -5.26 10.58 3.58 -0.44 1.49 Bulk Supply + GWh 3,699 3,592 4,270 4,461 4,465 Others % -16.25 -2.90 18.86 4.46 0.09 GWh 1,078 936 27 31 33 Traction % 3494.17 -13.18 -97.10 15.52 5.16 Total GWh 81,760 81,436 81,389 87,948 90,363 Percentage % 3.77 -0.40 -0.06 8.06 2.75 change Source: NTDC/KEL

10.5 Surplus/Deficit in Demand and Supply during Peak Hours (actual and projected) The actual position of demand and supply of the electric power during peak hours in the NTDC’s and K-Electric’s system have been reproduced in the following tables. Further, the projected figures of planned generation capacity, demand growth rate and surplus/deficit of electric power for the years to come, in the NTDC and K-Electric area have also been collected through respective companies and are included in the above stated tables.

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TABLE 27 Surplus/Deficit in Demand and Supply during NTDC’s System Peak Hours A: Actual Figures Demand During Financial Year Generation Surplus/ NTDC’s System Peak ending 30th June Capability (MW) (Deficit) (MW) Hours (MW) 2011 13,193 18,521 -5,328 2012 12,320 18,940 -6,620 2013 14,600 18,827 -4,227 2014 16,170 20,576 -4,406 2015 16,500 21,701 -5,201 B: Projected Figures Planned Generation NTDC Projected NTDC’s Projected Surplus/ Financial Year Capability as per Demand Growth Demand during (Deficit) ending 30th June NTDC (MW) Rate (%) Peak Hours (MW) (MW) 2016 17,551 5.98 22,457 -4,906 2017 20,641 6.05 23,816 -3,175 2018 25,077 5.56 25,140 -63 2019 29,171 5.17 26,439 2,732 2020 31,216 4.86 27,725 3,491 Source: NTDC

TABLE 28 Surplus/Deficit in Demand and Supply during K-Electric’s System Peak Hours A: Actual Figures

Financial Year Generation Demand During KEL’s Surplus/ ending 30th System Peak Hours June Capability (MW)* (MW) (Deficit) (MW) 2011 2,237 2,565 -328 2012 2,163 2,596 -433 2013 2,246 2,778 -532 2014 2,601* 2,929 -328 2015 2,632* 3,056 -424 B: Projected Figures KEL’s Projected Financial Year Planned Generation KEL’s Projected th Demand during Surplus/ ending 30 Capability as per Demand Growth Peak hours (Deficit) (MW) June KEL (MW) Rate (%) (MW) 2,752 2016 (including 20 + 100 MW NPC) 5.00 3,209 -457 2,804 2017 (including 52 MW FPCL) 5.00 3,369 -565 3,674 2018 (including 450 LNG + 420 5.00 3,538 136 Coal Conversion) 4,374 2019 (including 700 MW Coal)** 5.00 3,715 659 2020 4,374 5.00 3,900 474 * includes 650 MW from NTDC. ** Subject to approval of acceptable tariff by NEPRA and other regulatory approvals. Source: KEL

120 ELECTRICITY GENERATION 11

State of Industry Report 2015 11. ELECTRICITY GENERATION 11.1 General Pakistan faces chronic electricity shortage due to demand growth, high system losses, and seasonal reductions in the availability of hydropower, circular debt etc. rotating power outages (“load shedding”) are common and many villages are not yet electrified.

The power sector in Pakistan is a mixed industry of thermal, hydro and nuclear power plants. Originally the ratio of hydel to thermal installed generation capacity, in the country was about 67% to 33% (1985) but with the passage of time, due to different reasons more of thermal generation was added and thereby reduced share of hydel generation. At present, this hydel to thermal installed generation capacity ratio turns to about 30% to 65%. As on 30th June, 2015, the total installed capacity of the country was 24,823 MW of which the share of thermal power plants was 16,814 MW (67.74%) followed by hydel power plants 7,116 MW (28.67%), nuclear power plants 787 MW (3.17%) and wind power plant 106 MW (0.43%). It is a drawback of the country that its power production is dominated by thermal power plants running on oil and gas. Pakistan is a country which is heavily dependent on import of oil for its domestic energy requirement due to large amount of oil-fired power plants.

During 2014-15, the total energy generated in the country was 109,059 GWh of which the share of thermal electricity generation was 69,988 GWh (64.17%), hydel power plants were 32,979 GWh (30.24%), nuclear power plants were 5,349 GWh (4.90%) and wind power plant was 300 GWh (0.27%). The increasing share of thermal electricity generation increased the utilities financial burden particularly in foreign exchange. It is a strong need of the time to increase the hydel generation by adding new hydropower plants. The share of private sector is increasing as compared to the public sector. Electricity generation by source and sector during 2010-11 to 2014- 15 are shown in the following table.

TABLE 29 Energy Generation by Sector and Source (GWh) Sector/Source of Generation 2010-11 2011-12 2012-13 2013-14 2014-15 Public Sector 47,833 45,731 46,380 48,915 50,590 Public (Hydel) 31,685 28,207 29,327 31,204 31,941 Public (Thermal) 13,018 12,652 12,872 13,016 13,300 Public (Nuclear) 3,130 4,872 4,181 4,695 5,349 Private Sector 52,751 53,564 52,275 56,783 58,469 Private (Hydel) 305 436 706 1,035 1,038 Private (Thermal*) 52,446 53,128 51,569 55,748 57,431 Total 100,584 99,295 98,655 105,698 109,059 * including Import from Iran, Wind and KEL Source: PSS/NTDC

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Figure 29: Energy Generation by Sector and Source (GWh)

50,000 45,000 40,000 35,000 30,000 25,000 20,000 15,000 10,000 5,000 - 2010-11 2011-12 2012-13 2013-14 2014-15

Public (Hydel) Private (Hydel) Public (Thermal) Private (Thermal) Public (Nuclear)

11.2 Thermal Generation Majority of Pakistan’s power generation is thermal, with furnace oil, high-speed diesel and natural gas as fuels; coal is almost non-existent yet. During 2014-15, the share of thermal power generation in the energy mix of Pakistan was 64.17% as against 64.41% during last year.

Most of the upcoming power projects in the country would be based on coal and gas. The list of power plants planned in private sector shows the fuel of their operation, prepared by PPIB, is also included in this report. The thermal power plants running on oil will increase the current account deficit which is already problem for the country. The import of oil is one of the main reasons of current account deficit. Any strategy to cut current account deficit requires to cut down the oil imports and for this it is essential to reduce the electricity generation through oil. Similarly, the thermal power plants running on natural gas has negative externality. The economic loss resulting from deficiency of natural gas due to excessive reliance on gas fired power generation is a negative externality. The total installed capacity of thermal power plants in the country as on 30th June, 2015 was 16,814 MW out of which thermal power plants of 5,762 MW were in public sector.

11.3 Thermal Power Generation and Fuel Consumption Gas: During the year 2014-15, the share of electricity generated using gas in the total electricity generation of the country was 44.57% while this share during 2013-14 was 45.19%.

Oil: During the year 2014-15, the share of electricity generated using oil in the total electricity generation of the country was 55.28% while this share during 2013-14 was 54.64%.

Coal: During the year 2014-15, the share of electricity generated using coal in the total electricity generation of the country was 0.15% while this share during 2013-14 was 0.16%.

The historical record of thermal electricity generation using different fuels, from the years 2010-11 to 2014-15 is given in the following table.

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TABLE 30 Thermal Electricity Generation by Sector and by Fuel (GWh) 2010-11 2011-12 2012-13 2013-14 2014-15 Thermal Genertion by: GENCOs 13,018 12,652 12,872 13,016 13,300 KEL Own Power Plants 7,826 8,029 8,567 8,709 9,319 PEPCO Area 41,209 42,222 40,062 43,701 44,638 IPPs KEL Area 1,538 933 1,116 1,380 1,525 PEPCO Area 546 758 0 0 0 RPPs KEL Area 158 0 0 0 0 PEPCO Area 587 730 1,280 1,108 1,015 CPPs/SPPs KEL Area 287 154 137 168 191 Total Thermal Generation 65,169 65,478 64,034 68,082 69,988 Thermal Generation using: PEPCO Area* 31,498 24,161 21,817 23,877 23,903 Gas KEL Area 5,578 6,001 6,373 6,892 7,293 Total 37,076 30,162 28,190 30,769 31,196 PEPCO Area** 23,796 32,135 32,357 33,836 34,948 FO and HSD KEL Area 4,188 3,115 3,447 3,365 3,742 Total 27,984 35,250 35,804 37,201 38,690 PEPCO Area 66 66 40 112 102 Coal KEL Area 43 0 0 0 0 Total 109 66 40 112 102 Total Thermal Generation 65,169 65,478 64,034 68,082 69,988 * Including generation of SPPs. ** Including generation of CPPs. Source: PSS/NTDC/KEL

11.4 Hydel Generation Water flowing in the rivers has kinetic energy. Once it is used to drive the turbine and produce electricity, the power thus generated is called hydel energy. Power produced by the turbines depends on quantity of water flowing per minutes and the head of water available.

Pakistan has a potential of around 40,000 MW hydropower, whereas the installed hydel power capacity of Pakistan at the end of 2014-15 was 7,116 MW. The share of existing hydel power installed capacity to the total installed generation capacity of the country is only 28.67% while this share in year 1985 was around 67%. The share of hydel power generation during 2014-15, in the energy mix of Pakistan, was 30.24% as against 30.50% during same period last year. Most of the installed hydel power capacity of the country is owned by public sector (WAPDA) and only 214 MW installed hydel power capacity is in private sector.

As discussed earlier, the availability of hydel power generation is subject to seasonal variation i.e. it depends upon the reservoir levels, inflow of water and discharge of water from the reservoir. Monthly variation in maximum hydro generation capacity, during past five years, has been collected from NPCC and is given in the following table.

125 State of Industry Report 2015

TABLE 31 Monthly Variation in Maximum Hydel Generating Capability (MW)

Ghazi Chashma Jinnah Allai Khan Duber Small Year Tarbela Mangla Warsak Total Barotha Hydel Hydel Khwar Khwar Khwar Hydels Month

2010 3,546 1,150 1,450 205 176 - - - - 55 6,582 2011 3,238 1,035 1,450 204 184 - - - - 117 6,228 2012 2,923 1,039 1,450 186 144 - - - - 116 5,858 July 2013 3,605 1,115 1,450 190 160 39 121 - - 127 6,807 2014 3,522 1,115 1,450 180 120 n.p. n.p. n.p. n.p. 80 6,467 2010 3,594 1,150 1,450 207 86 - - - - 48 6,535 2011 3,634 1,060 1,450 200 184 - - - - 106 6,634 2012 3,603 1,092 1,450 203 168 - - - - 126 6,642

August 2013 3,578 1,115 1,450 191 160 32 121 - - 128 6,775 2014 3,605 1,115 1,450 175 184 n.p. n.p. n.p. n.p. 78 6,607 2010 3,600 1,150 1,450 150 184 - - - - 54 6,588 2011 3,702 1,120 1,450 200 184 - - - - 107 6,763 2012 3,674 1,115 1,450 203 184 - - - - 120 6,746 2013 3,613 1,115 1,450 190 184 70 121 - - 114 6,857 September 2014 3,605 1,115 1,450 150 184 n.p. n.p. n.p. n.p. 81 6,585 2010 3,395 1,150 1,450 215 176 - - - - 54 6,440 2011 3,438 1,115 1,450 200 184 - - - - 109 6,496 2012 3,587 1,115 1,450 203 191 - - - - 86 6,632

October 2013 3,397 1,115 1,450 160 184 73 121 121 - 60 6,681 2014 3,605 1,000 1,450 150 181 n.p. n.p. n.p. n.p. 82 6,468 2010 3,056 1,035 1,450 180 161 - - - - 44 5,926 2011 3,371 1,115 1,450 166 168 - - - - 94 6,364 2012 2,980 1,115 1,450 144 160 - - - - 76 5,925 2013 2,654 1,115 1,160 130 184 60 121 68 - 40 5,532 November 2014 2,808 1,115 1,450 150 168 n.p. n.p. n.p. n.p. 80 5,771 2010 2,914 980 1,450 150 136 - - - - 34 5,664 2011 3,199 1,111 1,450 133 136 - - - - 52 6,081 2012 2,853 1,081 1,450 144 147 - - - - 71 5,746

December 2013 2,584 1,115 1,160 130 184 58 121 72 - 51 5,475 2014 2,268 1,115 1,160 148 140 n.p. n.p. n.p. n.p. 61 4,892 2011 1,440 754 1,450 150 154 - - - - 16 3,964 2012 2,139 711 1,160 133 161 - - - - 29 4,333 2013 1,661 674 1,250 142 138 - - - - 49 3,914

January 2014 1,604 880 1,160 140 120 36 121 68 - 34 4,163 2015 1,100 1,018 960 142 126 n.p. n.p. n.p. n.p. 25 3,371 2011 2,420 776 1,450 150 161 - - - - 74 5,031 2012 2,384 966 1,450 133 161 - - - - 66 5,160 2013 2,147 812 1,450 141 184 - - - - 102 4,836

February 2014 2,000 1,013 1,350 140 161 60 121 68 - 45 4,958 2015 2,049 977 1,450 141 158 n.p. n.p. n.p. n.p. 77 4,852 Continued.....

126 State of Industry Report 2015

Ghazi Chashma Jinnah Allai Khan Duber Small Year Tarbela Mangla Warsak Total Barotha Hydel Hydel Khwar Khwar Khwar Hydels Month 2011 2,182 714 1,450 150 126 - - - - 54 4,676 2012 1,740 650 1,450 140 133 - - - - 47 4,160 2013 1,478 730 1,160 177 161 - - - - 118 3,824 March 2014 1,879 751 1,160 129 149 67 121 68 130 60 4,514 2015 1,355 803 1,160 140 150 n.p. n.p. n.p. n.p. 73 3,681 2011 1,800 889 1,450 182 184 - - - - 118 4,623 2012 1,148 726 1,450 166 184 - - - - 118 3,792 2013 1,605 833 1,450 180 184 - - - - 122 4,374 April 2014 1,698 1,002 1,450 165 184 70 121 68 130 78 4,966 2015 1,395 1,000 1,350 140 183 n.p. n.p. n.p. n.p. 78 4,146 2011 2,590 1,060 1,450 205 184 - - - - 120 5,609 2012 1,882 750 1,450 190 184 - - - - 116 4,572 2013 2,197 947 1,450 196 178 60 121 - - 124 5,273 May 2014 2,200 1,107 1,450 201 184 67 121 68 128 87 5,613 2015 3,290 1,115 1,450 185 181 n.p. n.p. n.p. n.p. 93 6,314 2011 2,662 1,097 1,450 205 184 - - - - 115 5,713 2012 2,182 850 1,450 190 152 - - - - 120 4,944 2013 3364 1,115 1,450 192 160 45 122 - - 126 6,574 June 2014 2670 1115 1450 175 144 66 121 68 120 89 6,018 2015 3152 1115 1450 185 181 n.p. n.p. n.p. n.p. 88 6,171 Source: NPCC, Islamabad

11.5 Nuclear Power Plants Pakistan Atomic Energy Commission, interalia, undertakes the projects of nuclear power plants’ development, operation and maintenance in the country. The 1st Nuclear Power Plant (NPP) of the country, namely Karachi Nuclear Power Plant (KANUPP), was commissioned in 1971 in Karachi through a turn-key agreement. The total installed capacity of this plant was 137 MW and the useful life of this plant was 30 years. However, after completion of 30 years life, the Pakistan Nuclear Regulatory Authority extended the operational life of this plant, by another 15 year at reduced capacity. The 2nd NPP of the country, namely the Chashma Nuclear Power Plant (CHASNUPP-I) was commissioned in year 2000 also through a turnkey agreement by China National Nuclear Corporation. The 3rd NPP namely Chashma Nuclear Power Plant (CHASNUPP-II) was commissioned on 18th May, 2011. The installed capacity of this plant is 325 MW.

Total installed capacity of NPPs, as on 30th June, 2015, in the country was 787 MW as against the total installed electricity generation capacity of 24,823 MW, which constitutes a share of NPPs to the total installed generation capacity as 3.17%. The share of electricity generated through NPPs in the country, during 2014-15, was recorded as 5,349 GWh (4.90%) as against 4,695 GWh (4.44%) in the preceding year.

127 State of Industry Report 2015 TABLE 32 Nuclear Power Statistics 2010-11 2011-12 2012-13 2013-14 2014-15 Installed Capacity (MW) CHASNUPP-I (connected with PEPCO system) 325 325 325 325 325 CHASNUPP-II (connected with PEPCO system) 325 325 325 325 325 KANUPP (connected with KEL system) 137 137 137 137 137 Total 787 787 787 787 787 % share to the total installed Capacity 3.37 3.35 3.32 3.32 3.17 Total Installed Capacity of the Country 23,342 23,487 23,725 23,728 24,823 Energy Generated (GWh) CHASNUPP-I (connected with PEPCO system) 2387 2127 2121 2194 2455 CHASNUPP-II (connected with PEPCO system) 543 2286 1519 2208 2541 KANUPP (connected with KEL system) 200 459 541 293 353 Total Nuclear Power Gen. in the Country 3,130 4,872 4,181 4,695 5,349 % share to total electricity generation 3.11 4.91 4.24 4.44 4.90 Total Energy Generated in the Country 100,584 99,295 98,655 105,698 109,059 Source: PSS/NTDC

Figure 32. Nuclear Power vs. Total Electricity Gen. in the Country (GWh)

105,698 109,059 100,584 99,295 98,655 120,000 105,000 90,000 75,000 60,000 45,000 30,000 3,130 4,872 4,181 4,695 5,349 15,000 - 2010-11 2011-12 2012-13 2013-14 2014-15

Total Nuclear Power Gen. in the Country Total Energy Generated in the Country

11.6 Renewable Energy Pakistan, like other developing countries of the region, is facing a serious challenge of energy deficit. Hence, Pakistan is working to expand the use of renewable energy to help bridge the gap of energy deficiency in the country. The country is blessed with natural resources that can be utilized to create electricity.

Renewable resources that are technologically viable and have prospects to be exploited commercially in Pakistan include wind energy, solar energy, micro-hydel, bio-energy, and emerging technologies like Fuel cell. Pakistan can benefit from these resources and can supplement existing energy resources as well as can use as primary energy source when no other option in available. The Coastal Belt of Pakistan is blessed with a wind corridor that is 60 km wide (Gharo – Kati Bandar) and 180 km long (upto Hyderabad). This corridor has the exploitable potential of 50,000 MW of electricity generation through wind energy. In addition to that there are other wind

128 State of Industry Report 2015

sites available in Coastal Area of Balochistan and some in Northern Areas. Technically the grid can take upto 30-40% of wind energy. Most of the remote villages in the south can be electrified through micro wind turbines. More than 5,000 villages can be electrified through wind energy in Sindh, Balochistan and Northern Areas.

The Government of Pakistan established the Alternative Energy Development Board in 2003 to create an environment in the country that is conducive to investment from the private sector in renewable energy.

Besides, AEDB the Irrigation and Power Departments of Punjab and Khyber Pakhtunkhwa are actively involved in development of small hydel power projects. The Provincial/AJ&K Organizations which are involved in development of small hydropower projects are as under: i) Pakhtunkhwa Energy Development Organization (PEDO) ii) Punjab Power Development Board (PPDB) iii) Irrigation Power Development Board, Sindh iv) AJK Hydro Electric Board (AJKHEB) and AJK Private Power Cell v) Northern Area Public Works Department

The details of the project undertaken by PEDO and PPDB are included in this report. At present, the share of wind energy in the national grid of the country is non-existent as against a wind power potential of 50,000 MW in the country.

11.7 Available Power Generation Capacity Capability of thermal generation units varies due to their age, auxiliary consumption, fuel (gas) availability and site conditions. The availability of different power plants (technology-wise) against their installed capacity recorded during 2014-15 has been collected by the NPCC and K-Electric and is reproduced in following table.

TABLE 33 Installed and Available Capacity (MW) 2010-11 2011-12 2012-13 2013-14 2014-15

PEPCO KEL PEPCO KEL PEPCO KEL PEPCO KEL PEPCO KEL Installed Capacity Thermal 13,463 2,447 13,097 2,872 13,127 2,814 13,290 2,403 13,715 2,326 (GENCOs+IPPs) Nuclear 650 137 650 137 650 137 650 137 650 137 Hydel 6,645 - 6,730 - 6,947 - 7,116 - 7,116 - (WAPDA+IPPs) Wind - - 1 - 50 - 106 - 254 - Total 20,758 2,584 20,478 3,009 20,774 2,951 21,162 2,540 21,735 2,463 Available Capacity Thermal 11,865 1,787 11,151 2,256 11,399 1,862 12,680 1,872 12,845 1,880 (GENCOs+IPPs) Nuclear 615 84 615 80 615 75 615 75 615 75 Hydel Depends on Indents (WAPDA+IPPs) Wind - - 1 - 50 - 106 254 - Total 12,480 1,871 11,767 2,336 12,064 1,937 13,401 1,947 13,714 1,955 Available Percentage of Installed Capacity Thermal 88.13 73.03 85.14 78.55 86.84 66.17 95.41 77.90 93.66 80.83 (GENCOs+IPPs) Nuclear 94.62 61.31 94.62 58.39 94.62 54.74 94.62 54.74 94.62 54.74 Wind - - 100.00 - 100.00 - 100.00 - 100.00 - Total 60.12 72.41 57.46 77.63 58.07 65.64 63.33 76.65 63.10 79.37 Source: NPCC/KEL 129 State of Industry Report 2015

TABLE 34 Ongoing Projects and Expansion Plan of Hydel Power Generation in Khyber Pakhtunkhwa under E&P Department Expected Project Cost (Actual/ S. Capacity Name of Project Commissioning Year Estimated) (Rs. in No. (MW) (Actual/Tentative) Million) Existing on-going Projects: 1 Reshun Hydropower Project, Chitral 4.2 1999 (A) 238 (A) Malakand-III Hydropower Project, 2 81 2009 (A) 6,379.50 (A) Dargai 3 Pehur Hydropower Project, Swabi 18 2010 (A) 862 (A) 4 Shishi Hydropower Project, Chitral 1.87 2010 (A) 286.58 (A) Future up-coming Projects: 1 Daral Hydropower Project, Swat 36.6 2015 (T) 6,958 (E) 2 Ranolia Hydropower Project, Kohistan 17 2015 (T) 4,277 (E) 3 Machai Hydropower Project, Mardan 2.6 2015 (T) 1,198 (E) Feasibility Study of 3 raw sites in 4 965 2017 (T) 1,237 (E) Khyber Pakhtunkhwa. 5 Karora Hydropower Project, Shangla 11 2018 (T) 4,000 (E) 6 Jabori Hydropower Project, Mansehra 10 2018 (T) 3,000 (E) 7 Matiltan Hydropower Project, Swat 84 2019 (T) 22,000 (E) 8 Koto Hydropower Project, Dir 40 2019 (T) 10,000 (E) 9 Lawi Hydropower Project, Chitral 69 2020 (T) 20,308 (E) Construction of 15 Feasible Sites in 10 Khyber Pakhtunkhwa. Feasibility Study 2,249 2021-22 (T) 654,000 (E) of these sites completed in 2014-15. Abbreviations: (A) Actual, (E) Estimated, (T) Tentative Source: Pakhtunkhwa Energy Development Organization, Government of Khyber Pakhtunkhwa, Peshawar

11.8 Investment Plan for Power Generation Projects The investment plan for power generation projects along with other details, for the years to come, as provided by the NTDC and PPIB are produced in the following tables respectively. Further, the investment plan for power generation projects under K-Electric has also been kept separate under table.

TABLE 35 Investment Plan for Public Sector Power Generation Projects (as per approved PC-I) Expected S. Capacity Estimated Cost Name of the Project Commissioning No. (MW) (Million Rupees) Year 1 Golan Gol Hydropower Project 106 2016 28,202.40 2 Tarbela 4th Extension Hydropower Project 1410 2017 83,601.04 3 Keyal Khwar Hydropower Project 128 2019 27,803.01 4 Dasu Hydropower Project (Stage-I) 2160 2024 486,093.30 Mangla Refurbishment and up-gradation 5 310 2024 52,224.31 Hydropower Project 6 Diamer Basha Dam Land Acquisition Project 834,205.00 4500 2024 7 Diamer Basha Dam Project (Lot 1-5) 101,372.00 Source: NTDC

130 State of Industry Report 2015

TABLE 36 Investment Plan for Power Generation Projects (KEL) (2015-16 to 2016-17) Expected Estimated S. Name of the Project Capacity (MW) Commissioning Cost No. Year (US$ Million) KEL’s Own Programme 1 LNG Plant (with Engro) (IPP Model)* 375 (Net) 2018 486 2 Coal Conversion (IPP Model)* 370 (Net) 2018 400 3 700 MW Coal Greenfield (IPP Model)* 645 (Net) 2019 1230 Plan to induct IPPs in KEL system 1 SNPC and SNPC Phase-II 100 (Net) June, 2016 120 2 FPCL 52 (Net) March, 2017 114 * Subject to approval of acceptable tariff by NEPRA and other regulatory approvals. Source: KEL

TABLE 37 Investment Plan for Private Sector Power Generation Projects Estimated Gross Achieved/ S. Investments Name of the Project Capacity Expected Latest Status of the Project No. (Million (MW) COD US$) A: OIL NIL B: PIPELINE QUALITY GAS/DUAL FUEL/LNG i) Project is based on both pipeline quality gas and gas from a dedicated gas field. December, ii) LOS not issued due to the non- 1 Kandra Power Project 120 90 2022 allocation of pipeline quality gas required for commingling of low BTU Kandra gas. C: DEDICATED GAS FIELDS NIL D: HYDEL 2 Patrind Hydropower Project 150 362 March, 2017 Project under construction. 3 Gulpur Hydropower Project 102 323 June, 2019 Project under financial closing. December, Approval of EPC stage tariff by NEPRA 4 Sehra Hydel Project 130 344 2019 is under process. 5 Karot Hydel Project 720 1420 June, 2020 Project under financial closing. Tariff review under consideration by 6 Azad Patan Hydel Project 640 1145 June, 2020 NEPRA.

Suki Kinari Hydropower September, 7 870 1801 Project under financial closing. Project 2021 Sponsors have approached Court of December, 8 Chakothi-Hattian Project 500 983 Law against NEPRA for giving low 2022 tariff. The matter is subjudice.

Lower Palas Valley December, Project under implementation under 9 665 763 Hydropower Project 2022 Public-Private Partnership (PPP) mode.

Lower Spat Gah Hydropower December, Project under implementation under 10 496 697 Project 2022 Public-Private Partnership (PPP) mode. Continued.....

131 State of Industry Report 2015

Estimated Gross Achieved/ S. Investments Name of the Project Capacity Expected Latest Status of the Project No. (Million (MW) COD US$)

Progress is slow due to Law and Order December, 11 Madian Hydropower Project 157 438 situation in the vicinity of project area 2022 and its perception internationally.

Progress is slow due to Law and Order December, 12 Asrit-Kedam Hydel Project 215 406 situation in the vicinity of project area 2022 and its perception internationally.

December, LOI issued on 21st October, 2014. 13 Mahl Hydropower Project 590 885 2023 Feasibility Study is in process.

December, LOS will be issued after fulfillment of 14 Kohala Hydropower Project 1100 2397 2023 pre-requisites by Sponsors.

December, Sponsors are in process of submission 15 Kaigah Hydel Project 548 1565 2024 of feasibility level tariff to NEPRA.

PPIB is in consultation with December, 16 Rajdhani Hydropower Project 132 198 the Government of AJK for the 2024 development of the project.

Athmuqam Hydropower December, EOI for development of project to be 17 350 525 Project 2024 re-advertised shortly.

Turtonas-Uzghor Hydropower December, Proposals received against EOI are 18 58 87 Project 2024 under evaluation process.

Neckeherdm-Paur December, EOI for development of project to be 19 80 120 Hydropower Project 2025 re-advertised shortly. E: COAL Engro Powergen. Project at February, 20 660 957 Project under financial closing. Thar Block-II, Sindh 2017

Shanghai Electric Power December, Project under issuance of Notice of 21 1320 1914 Project at Thar Block-I, Sindh 2017 Proceed (NTP)/LOI.

Salt Range Power Project by December, Project under tariff determination by 22 330 479 CMEC, China 2017 NEPRA.

HUBCO Imported Coal based December, LOI issued, sponsors are in process to 23 1320 1914 Power Project 2017 approach NEPRA for tariff.

Shandong Imported Coal 24 1320 1914 March, 2018 Project under financial closing. based Power Project

Port Qasim Power Project by 25 Sinohydro Resources Limited 1320 1914 June, 2018 Project under financial closing. and Al Mirqab Capital

26 Grange Holding Power Project 163 251 January, 2019 Project under financial closing. Siddiqsons Imported Coal LOI issued, sponsors have approached 27 350 508 March, 2019 based Power Project NEPRA for tariff.

Lucky Electric Imported Coal October, 28 660 957 Project under financial closing. based Power Project 2019 Source: Private Power and Infrastructure Board, Islamabad

132 State of Industry Report 2015

TABLE 38 Detail of Renewable Energy Projects A: Existing Projects (in-operation and under construction) S. Capacity Expected Estimated Cost Name of Project No. (MW) Commissioning year (US$ Million) Wind Technology: 1 FFC Energy Limited 49.50 May, 2013 133.557 2 Zorlu Energy Pakistan Limited 56.40 July, 2013 143.74 Three Gorges First Wind Farm Pakistan (Pvt.) 3 50 November, 2014 130.279 Limited 4 Foundation Wind Energy-II Limited 50 December, 2014 124.907 5 Foundation Wind Energy-I Limited 50 April, 2015 125.899 6 Sapphire Wind Power Company (Pvt.) Limited 49.50 January, 2016 120.00-130.00 7 Metro Power Company (Pvt.) Limited 50 August, 2016 125.236 8 Yunus Energy Limited 50 August, 2016 120.00-130.00 9 Master Wind Energy (Pvt.) Limited 49.50 September, 2016 120.00-130.00 10 Hydrochina Dawood Power (Pvt.) Limited 49.50 September, 2016 120.00-130.00 11 United Energy Pakistan Limited 99 September, 2016 240.00-260.00 12 Tapal Wind Energy (Pvt.) Limited 30 September, 2016 72.00-78.00 13 Tenega Generasi Limited 49.50 September, 2016 120.00-130.00 14 Gul Ahmed Energy Limited 50 September, 2016 120.00-130.00 Solar PV Technology: 15 Quaid-e-Azam Solar Power (Pvt.) Limited 100 July, 2015 151.40 16 Appolo Solar Development Pakistan Limited 100 December, 2016 151.40 17 Best Green Energy Pakistan (Pvt.) Limited 100 December, 2016 151.40 18 Crest Energy Pakistan Limited 100 December, 2016 151.40 Bagasse/Biomass Technology: 19 JDW Sugar Mills Limited (Unit-II) 26.35 June, 2014 Based on 20 JDW Sugar Mills Limited (Unit-III) 26.35 October, 2014 Upfront Tariff 21 RYK Mills Limited 30 March, 2015

B. Future Projects S. Capacity Expected Estimated Cost Name of Project No. (MW) Commissioning year (US$ Million) Wind Technology: 1 Sachal Energy Development (Pvt.) Limited 50 June, 2017 133.918 2 Hawa Holding Limited 50 December, 2017 120.00-130.00 3 China Sunec Energy (Pvt.) Limited 50 December, 2017 120.00-130.00 4 Jhampir Wind Power (Pvt.) Limited 50 December, 2017 120.00-130.00 5 Trident Energy (Pvt.) Limited 10 January, 2018 24.00-26.00 6 Burj Wind Energy (Pvt.) Limited 14 April, 2018 33.60-34.40 Tricon Boston Consulting Corporation (Pvt.) 7 50 April, 2018 120.00-130.00 Limited (A) Tricon Boston Consulting Corporation (Pvt.) 8 50 April, 2018 120.00-130.00 Limited (B) Tricon Boston Consulting Corporation (Pvt.) 9 50 April, 2018 120.00-130.00 Limited (C) Continued..... 133 State of Industry Report 2015

S. Capacity Estimated Cost Name of Project Expected No. (MW) Commissioning year (US$ Million) 10 Hartford Alternative Energy (Pvt.) Limited 50 July, 2018 120.00-130.00 11 Wind Eagle Limited (1) 50 July, 2018 120.00-130.00 12 Wind Eagle Limited (2) 50 July, 2018 13 Western Energy (Pvt.) Limited 50 July, 2018 120.00-130.00 14 Zephyr Power (Pvt.) Limited 50 August, 2018 134.099 15 Titan Wind Power (Pvt.) Limited 10 August, 2018 24.00-26.00 Solar PV Technology: 16 Zonergy (Pvt.) Limited 600 June, 2016 840.00-900.00 17 Access Electric (Pvt.) Limited 10 August, 2016 16.00-19.00 18 Buksh Solar (Pvt.) Limited 10 August, 2016 16.00-19.00 19 Sanjwal Solar Power (Pvt.) Limited 5.04 August, 2016 8.00-9.50 20 Safe Solar Power (Pvt.) Limited 10.28 August, 2016 16.00-19.00 21 Access Solar (Pvt.) Limited 11.52 August, 2016 16.00-19.00 22 Blue Star Hydel (Pvt.) Limited 1 August, 2016 1.562 23 Blue Star Electric (Pvt.) Limited 1 April, 2017 1.562 24 Harappa Solar (Pvt.) Limited 10 June, 2017 14.00-15.00 25 Fauji Foundation 10 August, 2017 14.00-15.00 26 Siddiqsons Energy Limited 50 September, 2017 70.00-75.00 27 Integrated Power Station 50 December, 2017 75.00-78.00 28 Jafri and Associates 50 December, 2017 75.00-78.00 29 Solar Blue (Pvt.) Limited 50 December, 2017 75.00-78.00 30 RE Solar (Pvt.) Limited (1) 20 December, 2017 28.00-30.00 31 RE Solar (Pvt.) Limited (2) 20 December, 2017 28.00-30.00 32 Hanergy Global Solar Asia Pacific Limited (1) 50 May, 2018 70.00-75.00 33 Hanergy Global Solar Asia Pacific Limited (2) 10 May, 2018 14.00-15.00 34 Janpur Energy Limited (1) 10 May, 2018 14.00-15.00 35 Janpur Energy Limited (2) 10 May, 2018 14.00-15.00 36 Nizam Power (Pvt.) Limited (1) 5.65 June, 2018 7.00-8.00 37 Nizam Power (Pvt.) Limited (2) 5.65 June, 2018 7.00-8.00 38 Nizam Power (Pvt.) Limited (3) 11.30 June, 2018 16.00-17.00 Sino Pak Energy Development Company (Pvt.) 39 10 June, 2018 14.00-15.00 Limited 40 Ayan Energy (Pvt.) Limited 50 June, 2018 70.00-75.00 41 Total Energies Nouvelles Ventures 100 December, 2018 140.00-150.00 42 AJ Power (Pvt.) Limited 10 December, 2018 14.00-15.00 43 Adamjee Power Generation (Pvt.) Limited 5 December, 2018 7.00-8.00 44 ET Solar (Pvt.) Limited (1) 25 December, 2018 35.00-38.00 45 ET Solar (Pvt.) Limited (2) 25 December, 2018 35.00-38.00 46 ET Solar (Pvt.) Limited (3) 25 December, 2018 35.00-38.00 47 Crystal Energy (Pvt.) Limited 2 May, 2019 3.50-4.00 48 ACT Solar (Pvt.) Limited 50 May, 2019 70.00-75.00 49 Asia Petroleum 30 June, 2019 42.00-45.00 50 Forshine (Pakistan) 50 June, 2019 70.00-75.00 Continued.....

134 State of Industry Report 2015

S. Capacity Estimated Cost Name of Project Expected No. (MW) Commissioning year (US$ Million) Bagasse /Biomass Technology: 51 Chiniot Power Limited 62.40 2015 52 Hamza Sugar Mill Limited 15 2016 54 Layyah Sugar Mills Limited 41 2016 55 Safina Sugar Mills Limited 20 July, 2016 53 Alliance Sugar Mills Limited 19 2017 Based on 56 Almoiz Industries Limited 36 2017 Upfront Tariff 57 Etihad Power Generation Limited 67 January, 2017 58 Shahtaj Sugar Mills Limited 15 2018 59 Chanar Energy Limited 22 2018 60 RYK Energy Limited 36 2018 Source: Alternative Energy Development Board, Islamabad

C: Proposals of following Projects accepted by AEDB and issuance of LOI: S. Capacity Expected Estimated Cost Name of Project No. (MW) Commissioning year (US$ Million) Wind Technology: 1 Gul Ahmed Energy Limited 50 2019 120.00-130.00 2 Metro Power Company Limited 50 2019 120.00-130.00 3 Electrique (Pvt.) Limited 50 2019 120.00-130.00 4 Shaheen Foundation (PAF) 50 2019 120.00-130.00 5 Emerald Energy Limited 50 2019 120.00-130.00 6 Aleph Systems (SMC-Pvt.) Limited 100 2019 240.00-260.00 7 Wind Energy Limited 50 2019 120.00-130.00 Power China Huadong Engineering 8 50 2019 120.00-130.00 Corporation Limited 9 Indus Wind Energy Limited 50 2019 120.00-130.00 10 NASDA Energy (Pvt.) limited 50 2019 120.00-130.00 11 Green Power (Pvt.) Limited (1) 50 2019 120.00-130.00 12 Green Power (Pvt.) Limited (2) 50 2019 120.00-130.00 13 Trans Atlantic Energy (Pvt.) Limited (1) 50 2019 120.00-130.00 14 Trans Atlantic Energy (Pvt.) Limited (2) 50 2019 120.00-130.00 15 MepconIncemet Energias Renovables 50 2019 120.00-130.00 16 Master Green Energy Limited 100 2019 240.00-260.00 17 Din Energy Limited 50 2019 120.00-130.00 Solar PV Technology: 18 MST Power (Pvt.) Limited 5 2019 7.00-8.00 19 RT Power (Pvt.) Limited 10 2019 14.00-15.00 20 Ravi Renewable Energy 20 2019 28.00-30.00 21 Gran Solar 20 2019 28.00-30.00 22 First Solar (Pvt.) Limited 2 2017 2.80-3.00 23 Pakistan PV Power 01 (Pvt.) Limited 50 2019 70.00-75.00 24 KSJ International FZE 200 2019 280.00-300.00 25 Sapphire Wind Power Company Limited 40 2019 56.00-60.00 Continued..... 135 State of Industry Report 2015

S. Capacity Expected Estimated Cost Name of Project No. (MW) Commissioning year (US$ Million) 26 Gul Ahmed Energy Limited 50 2019 70.00-75.00 27 Metro Solar Power Limited 50 2019 70.00-75.00 28 Master Solar Energy Limited 20 2019 28.00-30.00 29 Uch-II Power (Pvt.) Limited 10 2019 14.00-15.00 30 China Han Power Company Limited (1) 50 2019 70.00-75.00 31 China Han Power Company Limited (2) 200 2019 280.00-300.00 32 Liberty Solar (Pvt.) Limited 50 2019 70.00-75.00 33 Adamjee Power Generation 5 2019 7.00-8.00 34 Conergy 20 2019 28.00-30.00 35 Fotwatio Renewable Ventures 50 2019 70.00-75.00 Bagasse/Biomass Technology: 36 Ansari Powergen Company (Pvt.) Limited 30 2019 37 Bandhi Powergen Company (Pvt.) Limited 30 2019 38 TAY Powergen Company (Pvt.) Limited 30 2019 Based on 39 Faran Sugar Mills Limited 25 2019 Upfront Tariff 40 Shakargarj Mills Limited (1) 40 2019 41 Shakarganj Mills Limited (2) 60 2019 42 Indus Sugar Mills Limited 25 2019 Notes: The expected dates for some of the projects as provided by AEDB do not exactly match with the expansion plans provided by NTDC. For consistency of report the data provided by NTDC has been used in the analysis.

11.9 Economic Load Dispatch System Based on the net heat rates of power plants, the National Power Control Centre, Islamabad decides the operation and load dispatch of power plants in the country except the power plants operated by K-Electric. Merit Order position of power plants in the area of NTDC and K-Electric, during 2014-15 is given in following two tables separately.

TABLE 39 Merit Order for Power Generation Plants (PEPCO System) (Based on the revised RFO and HSD prices effective from 16-06-2015) (Rs./kWh) As on 16th June, 2015 Status in Last Order Fuel O&M Specific Year Merit in Plant Groups Fuel Type Cost Cost Cost Order Merit (16-06-2014) 1 Uch (upto 152.375 GWh) Gas 0.55750 0.23340 0.79090 1 2 Liberty (upto 61.904 GWh) Gas 1.82378 0.31800 2.14178 3 3 Uch (+ 152.375 GWh) Gas 2.33620 0.23340 2.56960 2 4 Uch-II Gas 3.88440 0.14960 4.03400 -- 5 Foundation Power Gas 3.77690 0.35570 4.13260 10 6 GTPS Faisalabad 5-9 Gas 4.19570 0.02500 4.22070 12 7 Guddu 11-13 R. Gas 4.16600 0.06890 4.23490 13 8 FKPCL Gas 3.52630 0.73478 4.26108 5 9 Rousch Gas 4.09025 0.20535 4.29560 14 10 Engro Power Gen. Gas 4.05880 0.31390 4.37270 15 11 HCPC Gas 3.97790 0.48712 4.46502 16 12 Lakhra Coal 4.31019 0.19540 4.50559 4 Continued..... 136 State of Industry Report 2015

th Status in Last Order As on 16 June, 2015 Year Merit in Plant Groups Fuel Type Fuel O&M Specific Order Merit Cost Cost Cost (16-06-2014) 13 Altern (Phase-II) Gas 3.96579 0.65794 4.62373 18 14 Guddu 5-10 R. Gas 4.62880 0.06890 4.69770 19 15 Davis Energy Gas 4.58152 0.49345 5.07497 21 16 GTPS Kotri 3-7 Gas 4.99800 0.08990 5.08790 22 17 Muzaffargarh 4 Gas 5.22010 0.02500 5.24510 23 18 Muzaffargarh 1-3 Gas 5.26700 0.02500 5.29200 24 19 Guddu 3-4 Gas 5.55440 0.06890 5.62330 25 20 Altern (Phase-I) Gas 5.09564 0.65794 5.75358 26 21 Muzaffargarh 5-6 Gas 5.93570 0.02500 5.96070 27 22 Guddu 1-2 Gas 5.95100 0.06890 6.01990 28 23 Jamshoro 2-4 Gas 5.99140 0.13590 6.12730 29 24 NGPS Multan 1-4 Gas 6.89090 0.02500 6.91590 30 25 SPS Faisalabad 1-2 Gas 7.01470 0.02500 7.03970 31 26 GTPS Faisalabad 1-4 Gas 7.50210 0.02500 7.52710 32 27 Orient Power Gas (RLNG) 8.22630 0.20340 8.42970 6 28 Sapphire Electric Gas (RLNG) 8.22640 0.34220 8.56860 7 29 Saif Power Gas (RLNG) 8.22660 0.34600 8.57260 8 30 Halmore Power Gas (RLNG) 8.22680 0.34760 8.57440 9 31 Muzaffargarh 4 Mix (**) 8.81395 0.02500 8.83895 34 32 Muzaffargarh 1-3 Mix (**) 8.89325 0.02500 8.91825 36 33 KAPCO-I Gas (RLNG) 8.85219 0.25854 9.11073 11 34 Guddu 3-4 Mix (**) 9.35555 0.06890 9.42445 37 35 Liberty (+ 61.904 GWh) Gas 9.11888 0.31800 9.43688 33 36 Attock Gen. RFO 8.56070 0.88420 9.44490 42 37 KAPCO-I RFO 9.15710 0.44846 9.60556 40 38 Engro Power Gen. Mix (***) 9.64480 0.31720 9.96200 38 39 KAPCO-II Gas (RLNG) 9.70937 0.30241 10.01178 17 40 Jamshoro 2-4 Mix (**) 9.88310 0.13590 10.01900 39 41 Muzaffargarh 5-6 Mix (**) 10.02245 0.02500 10.04745 41 42 Nishat Power RFO 9.27030 0.87000 10.14030 45 43 GTPS Kotri 1-2 Gas 10.15620 0.08990 10.24610 35 44 Nishat Chunian RFO 9.46180 0.86790 10.32970 44 45 Liberty Power Tech. RFO 9.39460 0.96960 10.36420 43 46 Atlas Power RFO 9.49720 0.87000 10.36720 46 47 KEL RFO 9.94788 0.57397 10.52185 48 48 KAPCO-III Gas (RLNG) 10.04191 0.58291 10.62482 20 49 KAPCO-II RFO 10.05007 0.63127 10.68134 49 50 Japan Power RFO 10.16165 0.54821 10.70986 50 51 HUBCO Narowal RFO 9.96520 0.82570 10.79090 47 52 HUBCO RFO 10.71459 0.18264 10.89723 52 53 SEPCOL RFO 10.07020 0.90242 10.97262 51 Continued.....

137 State of Industry Report 2015

th Status in Last Order As on 16 June, 2015 Year Merit in Plant Groups Fuel Type Fuel O&M Specific Order Merit Cost Cost Cost (16-06-2014) 54 Saba Power RFO 10.96195 0.16184 11.12379 55 55 Lal Pir Power RFO 10.97112 0.16441 11.13553 53 56 Pak Gen. Power RFO 10.97112 0.16441 11.13553 54 57 NGPS Multan 1-4 Mix (**) 11.97715 0.02500 12.00215 56 58 Jamshoro 1 RFO 11.96140 0.13590 12.09730 58 59 SPS Faisalabad 1-2 Mix (**) 12.11960 0.02500 12.14460 57 60 Muzaffargarh 4 RFO 12.40780 0.02500 12.43280 59 61 Muzaffargarh 1-3 RFO 12.51950 0.02500 12.54450 60 62 Guddu 3-4 RFO 13.15670 0.06890 13.22560 61 63 Jamshoro 2-4 RFO 13.77480 0.13590 13.91070 67 64 Muzaffargarh 5-6 RFO 14.10920 0.02500 14.13420 68 65 KAPCO-I HSD 14.28386 0.25997 14.54383 63 66 Orient Power HSD 14.22630 0.33350 14.55980 62 67 Sapphire Electric HSD 14.13190 0.49390 14.62580 64 68 Halmore Power HSD 14.14730 0.50180 14.64910 65 69 Saif Power HSD 14.32970 0.49950 14.82920 66 70 Engro Power Gen. HSD 15.23080 0.32050 15.55130 69 71 KAPCO-II HSD 15.67671 0.34952 16.02623 70 72 GTPS Faisalabad 5-9 HSD 16.75240 0.02500 16.77740 71 73 NGPS Multan 1-4 RFO 17.06340 0.02500 17.08840 73 74 KAPCO-III HSD 16.21305 0.88264 17.09569 72 75 SPS Faisalabad 1-2 RFO 17.22450 0.02500 17.24950 74 76 GTPS Kotri 3-7 HSD 19.63910 0.08990 19.72900 75 77 NGPS Multan 1-4 HSD 29.95310 0.02500 29.97810 76 78 GTPS Kotri 1-2 HSD 39.90720 0.08990 39.99710 77 (**) 50% FO and 50% Gas (***) 50% HSD and 50% Gas Source: National Power Control Centre, Islamabad

TABLE 40 Merit Order for Power Generation Plants (K-Electric System) (Based on the Present Net Heat Rate at 100% Plant Factor) (Rs./kWh) As on 31st December, As on 31st March, As on 30th June, 2015 S. Plant Fuel 2014 2015 No. Groups Type Fuel O&M Total Fuel O&M Total Fuel O&M Total Cost Cost Cost Cost Cost Cost Cost Cost Cost 1 BQPS-II Gas 8,230 1,336 9,566 11,315 1,905 13,220 15,252 2,587 17,839 Korangi 2 Gas 1,874 762 2,636 2,381 1,051 3,432 3,683 1,430 5,113 CCPP 3 SGTPS-II Gas 556 244 800 582 362 944 746 497 1,243 4 KTGTPS-II Gas 1,194 335 1,529 1,418 526 1,944 2,016 781 2,797 5 BQPS-I Gas 4,890 6,268 9,061 1,785 23,209 2,780 28,488 3,700 41,954 6 BQPS-I HFO 16,534 19,440 29,193 Note: The plant on dual fuel will occur at three places; firstly all on Gas, secondly on Mix Fuel (average 50:50 ratio of Gas and FO) and thirdly on FO. Source: KEL

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11.10 Generation Licenses Granted In Pakistan, the generation of electric power for the purpose of sale, is a licensed activity. NEPRA grants generation licence to different power producing companies who wish to sale their electric power to national grid or to sale their electric power production to bulk power consumers. However, there is no need of generation licence for those electric power producers which produce electricity for their self use. The details of up-to-date granted Licenses are given in following tables.

TABLE 41-A List of Generation Licensees (Hydel + Nuclear) S. Installed Name of Company and Location Fuel Type No. Capacity (MW) Hydel (Technology: Hydel) WAPDA Hydro Electric Power Company (Tarbela, Storage Water / Run of 1 17359.96 Mangla, Warsak, Ghazi Barotha, Chashma etc.) River / Canal Malakand-III, Pakhtunkhwa Energy Development 2 Organization (PEDO), Malakand Agency, Khyber 83.70 Run of River/Canal Pakhtunkhwa Blue Star Energy (Pvt.) Limited, District Mardan, Khyber 3 3.021 Run of River/Canal Pakhtunkhwa SK Hydro (Pvt.) Limited, District Manshera, Khyber 4 840.00 Run of River Pakhtunkhwa Canal Fall/ 5 Olympus Energy (Pvt.) Limited, District Gujrat, Punjab 20.0016 Run of River Pehur Hydropower Plant, PEDO, District Swabi, Khyber Canal Fall/ 6 18.00 Pakhtunkhwa Run of River Punjnad Hydropower (Pvt.) Limited, District 7 15.00 Run of River Muzaffargarh, Punjab 8 Rasul Hydropower (Pvt.) Limited, District Jhelum, Punjab 20.0016 Run of River 9 Olympia Hydropower Limited, District Kasur, Punjab 12.60 Run of Canal 10 Alka Power Private Limited, District Hafizabad, Punjab 1.80 Canal Fall 11 Alka Power Private Limited, District Sahiwal, Punjab 3.30 Canal Fall 12 Chenab Energy (Pvt.) Limited, District Sahiwal, Punjab 4.80 Run/Fall of Canal Frontier Mega Structure and Power (Pvt.) Limited, 13 2.40 Run of River District Mansehra, Khyber Pakhtunkhwa SAR Energy (Pvt.) Limited, District Mardan, Khyber 14 1.30 Run of Canal Pakhtunkhwa Reshun Hydropower Plant, PEDO, Reshun Gol, District Canal Fall/ 15 4.20 Chitral, Khyber Pakhtunkhwa Run of River Shishi Hydropower Plant, PEDO, Drosh, District Chitral, Canal Fall/ 16 1.875 Khyber Pakhtunkhwa Run of River Machai Hydropower Plant, PEDO, Machai Canal near Low Head 17 2.60 Village Alo, District Mardan, Khyber Pakhtunkhwa Canal Fall Ranolia Hydropower Plant, PEDO, Ranolia Khwar, District 18 17.00 Run of River Kohistan, Khyber Pakhtunkhwa Karot Power Company (Pvt.) Limited, Village Karot, 19 732.00 Run of River District Rawalpindi, Punjab 20 New Park Energy Limited, District Okara, Punjab 9.00 Canal Fall Continued.....

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S. Installed Name of Company and Location Fuel Type No. Capacity (MW) Karimi Energy (Pvt.) Limited, District Haripur, Khyber 21 3.60 Canal Fall/Run of River Pakhtunkhwa Muntaha Power (Pvt.) Limited, District Muzaffargarh, Canal Fall/ 22 2.60 Punjab Run of River Marala Hydropower Project, Punjab Power Development Canal Fall/ 23 8.088 Company Limited (PPDCL), District Sialkot, Punjab Run of River Pakpattan Hydropower Project, PPDCL, District Canal Fall/ 24 3.01 Pakpattan, Punjab Run of River Deg-Outfall Hydropower Project, PPDCL, District Low Head 25 4.268 Sheikhpura, Punjab Canal Fall Chianwali Hydropower Project, PPDCL, District Low Head 26 5.674 Gujranwala, Punjab Canal Fall Nuclear (Technology: Pressurized Heavy Water Reactor) Chashma Nuclear Power Plant (Unit-1), 1 325.00 Uranium Chashma Barrage, District Mianwali, Punjab 2 Karachi Nuclear Power Plant, District Karachi, Sindh 137.00 Uranium Chashma Nuclear Power Plant (Unit-2), 3 325.00 Uranium Chashma Barrage, District Mianwali, Punjab Note: Shaded area indicate licenses issued in 2014-15. Source: National Electric Power Regulatory Authority, Islamabad

TABLE 41-B List of Generation Licensees (Wind + Solar + Bagasse/Biomass) Installed S. No. Name of Company and Location Capacity Fuel Type Technology (MW) Wind Power Projects under Renewable Energy Policy 2006 1 New Park Energy Limited, Mirpur Sakro, Thatta, Sindh 49.50 Wind Wind Turbine 2 Foundation Wind Energy-II (Pvt.) Limited, Thatta, Sindh 50.00 Wind Wind Turbine 3 Milergo Pakistan Limited, Thatta, Sindh 250.00 Wind Wind Turbine 4 Tenaga Generasi Limited, Thatta, Sindh 49.50 Wind Wind Turbine 5 HydroChina Dawood Power (Pvt.) Limited, Thatta, Sindh 49.50 Wind Wind Turbine 6 Zorlu Enerji Pakistan Limited, Jhampir, Thatta, Sindh 56.40 Wind Wind Turbine 7 SUNEC Wind Power Generation (Pvt.) Limited, Chakwal, Punjab 2.40 Wind Wind Turbine 8 Arabian Sea Wind Energy (Pvt.) Limited, Thatta, Sindh 49.50 Wind Wind Turbine 9 FFC Energy Limited, Jhampir, Thatta, Sindh 49.50 Wind Wind Turbine Three Gorges First Wind Firm Pakistan (Pvt.) Limited, Thatta, 10 49.50 Wind Wind Turbine Sindh 11 Foundation Wind Energy-I Limited, Thatta, Sindh 50.00 Wind Wind Turbine 12 Gul Ahmed Wind Power Limited, Jhampir, Thatta, Sindh 50.00 Wind Wind Turbine 13 Metro Power Company Limited, Jhampir, Thatta, Sindh 50.00 Wind Wind Turbine 14 Master Wind Energy Limited, Thatta, Sindh 49.50 Wind Wind Turbine 15 Yunus Energy Limited, Jhampir, Thatta, Sindh 50.00 Wind Wind Turbine 16 Zephyr Power (Pvt.) Limited, Mirpur Sakro, Thatta, Sindh 49.50 Wind Wind Turbine 17 Sapphire Wind Power Company Limited, Jhampir, Thatta, Sindh 49.50 Wind Wind Turbine Pakistan Wind Energy Generation (Pvt.) Limited, Jhampir, Thatta, 18 4.80 Wind Wind Turbine Sindh Sachal Energy Development (Pvt.) Limited, Jhampir, Thatta, 19 49.50 Wind Wind Turbine Sindh Continued..... 140 State of Industry Report 2015

Installed S. No. Name of Company and Location Capacity Fuel Type Technology (MW) 20 Finergy (Pvt.) Limited, Jhampir, Thatta, Sindh 49.60 Wind Wind Turbine 21 UEP Wind Power (Pvt.) Limited, Jhampir, Thatta, Sindh 99.00 Wind Wind Turbine 22 Tapal Wind Energy (Pvt.) Limited, Jhampir, Thatta, Sindh 30.00 Wind Wind Turbine 23 Hawa Energy (Pvt.) Limited, Nooriabad, Thatta, Sindh 49.60 Wind Wind Turbine 24 NBT Wind Power Pakistan-II (Pvt.) Limited, Thatta, Sindh 249.60 Wind Wind Turbine 25 NBT Wind Power Pakistan-III (Pvt.) Limited, Thatta, Sindh 250.00 Wind Wind Turbine 26 Jhimpir Power (Pvt.) Limited, Thatta, Sindh 49.60 Wind Wind Turbine 27 Titan Energy Pakistan (Pvt.) Limited, Nooriabad, Thatta, Sindh 9.00 Wind Wind Turbine 28 China Sunec Energy (Pvt.) Limited, Nooriabad, Thatta, Sindh 49.50 Wind Wind Turbine Solar Power Projects under Renewable Energy Policy 2006 DACC Power Generation Company (Pvt.) Limited, Bhawalpur, 1 50.00 P.V Cell P.V Cell Punjab 2 Sanjwal Solar Power (Pvt.) Limited, Sanjwal, Attock, Punjab 5.04 P.V Cell P.V Cell 3 Access Solar (Pvt.) Limited, Hattar, Punjab 11.52 P.V Cell P.V Cell 4 Buksh Energy (Pvt.) Limited, Bahawalnagar, Punjab 11.664 P.V Cell P.V Cell 5 Access Electric (Pvt.) Limited, Jehlum, Punjab 10.00 P.V Cell P.V Cell 6 Quaid-e-Azam Solar Power (Pvt.) Limited, Bahawalpur, Punjab 100.00 P.V Cell P.V Cell 7 Safe Solar Power (Pvt.) Limited, Bahawalpur, Punjab 10.2816 P.V Cell P.V Cell 8 Roshan Power (Pvt.) Limited, Kasur, Punjab 11.00 P.V Cell P.V Cell 9 First Solar (Pvt.) Limited, Chakwal, Punjab 2.0166 P.V Cell P.V Cell 10 Blue Star Hydel (Pvt.) Limited, Jhelum, Punjab 1.00 P.V Cell P.V Cell 11 Blue Star Electric (Pvt.) Limited, Jhelum, Punjab 1.00 P.V Cell P.V Cell 12 Ramzan Energy Limited, Chiniot, Punjab 1.52 P.V Cell P.V Cell 13 Crest Energy Pakistan Limited, Bahawalpur, Punjab 100.00 P.V Cell P.V Cell Appolo Solar Development Pakistan Limited, Bahawalpur, 14 100.00 P.V Cell P.V Cell Punjab 15 Best Green Energy Pakistan Limited, Bahawalpur, Punjab 100.00 P.V Cell P.V Cell Bagasse/Biomass Power Projects under Renewable Energy Policy 2006 1 SSJD Bioenergy Limited, Mirpur Khas, Sindh 12.00 Bagasse Bagasse 2 Lumen Energia (Pvt.) Limited, Jhang, Punjab 12.00 Biomass Steam Turbine 3 Shakarganj Mills Limited-II, Jhang, Punjab 12.00 Bagasse +FO Steam Turbine 4 Pak Ethanol (Pvt.) Limited, Tando Muhammad Khan, Sindh 9.132 Biogas Gas Engine Bagasse 5 JDW Sugar Mills Limited, Rahim Yar Khan, Punjab 26.35 Steam Turbine +Biomass Bagasse 6 JDW Sugar Mills Limited, Ghotki, Sindh 26.35 Steam Turbine +Biomass 7 Chiniot Power Limited, Chiniot, Punjab 62.40 Bagasse Steam Turbine 8 RYK Mills Limited, Rahim Yar Khan, Punjab 30.00 Bagasse Steam Turbine 9 Hamza Sugar Mills Limited, Rahim Yar Khan, Punjab 15.00 Bagasse Steam Turbine 10 Alliance Sugar Mills (Pvt.) Limited, Ghotki, Sindh 30.00 Bagasse Steam Turbine Ansari Powergen Company (Pvt.) Limited, Tando Muhammad 11 30.00 Bagasse Steam Turbine Khan, Sindh 12 TAY Powergen Company (Pvt.) Limited, Tando Allayar, Sindh 30.00 Bagasse Steam Turbine Bandhi Powergen Company (Pvt.) Limited, Shaheed 13 30.00 Bagasse Steam Turbine Benazirabad, Sindh 14 Etihad Power Generation Limited, RYK, Punjab 74.40 Bagasse Steam Turbine 15 The Thal Industries Corporation Limited, Chiniot, Punjab 20.00 Bagasse Steam Turbine 16 The Thal Industries Corporation Limited, Layyah, Punjab 41.00 Bagasse Steam Turbine 17 Almoiz Industries Limited, Mianwali, Punjab 36.00 Bagasse Steam Turbine Note: Shaded area indicate licenses issued in 2014-15. Source: National Electric Power Regulatory Authority, Islamabad

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TABLE 41-C List of Generation Licensees (SPPs, CPPs, IGCs, N-CPPs, DGPs, STIPPs and other IPPs)

Installed Technology-wise S. Name of Company and Location Capacity Fuel Type Capacity (MW) No. (MW) Technology Capacity Small Power Producers (SPPs) ICI Pakistan PowerGen Limited, Sheikhupura, 1 14.00 HFO DE 14.00 Punjab Sapphire Power Generation Limited, 2 56.80 HFO+Gas DE+GE 52.20+4.60 Sheikhupura, Punjab 3 Crescent Powertec Limited, Shahkot, Punjab 10.60 HFO DE 10.60 Ellcot Spinning Mills Limited, Kotri (Sindh), 4 21.96 HFO+ HSD DE 13.80+8.16 Kasur and Sheikhupura (Punjab) Mahmood Textile Mills Limited, Muzaffargarh, 5 15.05 FO+Gas DE+GE 9.20+5.85 Punjab Gulistan Power Generation Limited, HSD+HFO 11.82+4.68 6 20.945 DE+GE Sheikhupura, Kasur (Punjab) & Kotri (Sindh) +Gas +4.45

17.88+5.85 7 Kohinoor Mills Limited, Kasur, Punjab 31.23 HSD+HFO+Gas DE+GE +7.50 Monnoo Energy Limited, Monnoopur, 8 4.60 HFO DE 4.60 Sheikhupura, Punjab DS Power Limited, Bhikki, Sheikhupura, 9 1.98 HFO DE 1.98 Punjab 10 Sitara Energy Limited, Faisalabad, Punjab 87.82 HFO+Gas DE+GE 51.62+36.20 Bhanero Energy Limited, Kotri and 11 37.33 HFO+Gas DE+GE 3.635+33.695 Sheikhupura Quetta Textile Mills Limited, Kotri (Sindh) & 12 30.806 HFO+Gas DE+GE 8.1+22.706 Bhai Pheru (Punjab) 13 Ideal Energy Limited, Faisalabad, Punjab 11.82 HFO DE 11.82 Genertech Pakistan Limited, Bhai Pheru, 14 27.52 HFO DE 27.52 Punjab Kohinoor Power Company Limited, Faisalabad 15 15.24 HFO DE 10.16+5.08 & Kasur, Punjab 16 Ghazi Power Limited, Lahore, Punjab 20.82 HFO DE 20.82 Crescent Bahuman Limited, Hafizabad, 17 23.03 HFO+ HSD +Gas DE 23.03 Punjab 18 Zeeshan Energy Limited, Faisalabad, Punjab 6.90 HFO DE 6.90

19 Ibrahim Fibers Limited, Faisalabad, Punjab 58.30 HFO+ HSD +Gas RE 58.30

Captive Power Producers (CPPs) 1 Shakarganj Mills Limited, Jhang, Punjab 8.512 Biogas GT 8.512 Prosperity Weaving Mills Limited, 2 6.90 HFO DE 6.90 Sheikhupura, Punjab Almoiz Industries Limited, Dera Ismail Khan, 3 43.60 Bagasse +FO ST 43.60 Khyber Pakhtunkhwa 4 Roomi Fabrics Limited, Multan, Punjab 15.87 Gas GE 15.87 5 Din Textile Mills Limited, Kasur, Punjab 9.68 HSD+ FO+Gas DE+GE +ST 5.18+4.50 6 Pakistan Steel Mills Limited, Karachi, Sindh 165.00 Gas ST 165.00 7 Nishat Mills Limited, Bhikki, Punjab 128.241 HSD+ FO+Gas DE+GE +ST 128.241 8 Indus Sugar Mills Limited, Rajanpur, Punjab 11.00 Bagasse +FO ST 11.00 Continued..... 142 State of Industry Report 2015

Installed Technology-wise S. Name of Company and Location Capacity Fuel Type Capacity (MW) No. (MW) Technology Capacity 9 Colony Mills Limited, Multan, Punjab 36.132 Gas GE 36.132 10 Colony Mills Limited, Multan, Punjab 28.00 Bagasse +FO ST 28.00 11 Mekotex (Pvt.) Limited, Kotri, Dadu, Sindh 5.01 Gas GE 5.01 12 Brothers Sugar Mills Limited, Kasur, Punjab 13.00 Bagasse +FO ST 13.00 Al-Noor Sugar Mills Limited, Shaheed 13 36.80 Bagasse +FO ST 36.80 Benazirabad, Sindh SUNEC Wind Power Generation (Pvt.) Limited, 14 0.05 Wind WT 0.05 Chakwal, Punjab Shadman Cotton Mills Limited, Nankana, 15 9.25 Gas+ Diesel GE+DE 4.65+4.6 Punjab Agar Textiles Mills (Pvt.) Limited, Jamshoro, 16 16.185 Gas GE 16.185 Sindh 17 RYK Mills Limited, Rahim Yar Khan, Punjab 18.00 Bagasse +FO ST 18.00 Sheikhoo Sugar Mills Limited, Muzaffargarh, 18 18.00 Bagasse +FO ST 12.00 Punjab Hi-Tech Pipe & Engineering Industries, 19 3.78 Gas GE 3.78 Jamshoro, Sindh Ashraf Sugar Mills Limited, Bahawalpur, 20 24.50 Bagasse +FO ST 24.50 Punjab 21 Al-Abbas Sugar Mills Limited, Thatta, Sindh 15.00 Imported Coal ST 15.00 The Thal Industries Corporation Limited, 22 30.70 Bagasse +FO ST 30.70 Layyah, Punjab 23 International Steel Limited, Karachi, Sindh 19.316 Gas GE+ST 18.066 +1.250 International Industries Limited, Karachi, 24 4.38 Gas GE 4.38 Sindh Hamza Sugar Mills Limited, Rahim Yar Khan, 25 23.60 Bagasse +FO ST 23.60 Sindh 26 Tuwairqi Steel Mills Limited, Karachi, Sindh 38.948 Gas GT+ST 26.948+12.00 Eithad Sugar Mills Limited, Rahim Yar Khan, 27 22.00 Bagasse +FO ST 22.00 Punjab Deharki Sugar Mills (Pvt.) Limited, Ghotki, 28 18.00 Bagasse +FO ST 18.00 Sindh Tando Allayar Sugar Mills (Pvt.) Limited, Tano 29 12.00 Bagasse +FO ST 12.00 Allahyar, Sindh Pakistan Engineering Council, Islamabad, 30 0.356 P.V Cell P.V Cell 0.356 Federal Capital Territory 31 Ittefaq Sugar Mills Limited, Pakpattan, Punjab 11.00 Bagasse +FO ST 11.00 32 Digri Sugar Mills Limited, Mirpur Khan, Sindh 6.00 Bagasse +FO ST 6.00 33 Salim Yarn Mills (Pvt.) Limited, Kotri, Sindh 2.70 Gas ST 2.70 Engro Powergen. Qadirpur Limited, Ghotki, 34 0.36 Solar Power P.V Cell 0.36 Sindh 35 Fatima Sugar Mills Limited, Kot Addu, Punjab 120.00 Bagasse +FO ST 120.00 Bandhi Sugar Mills (Pvt.) Limited, Shaheed 36 12.00 Bagasse +FO ST 12.00 Benazirabad, Sindh Kamalia Sugar Mills Limited, Toba Tek Singh, 37 17.00 Bagasse +FO ST 17.00 Punjab Gadoon Textile Mills Limited, Swabi, Khyber 38 56.47 HFO+ Gas RE 56.47 Pakhtunkhwa 39 Ramzan Sugar Mills Limited, Chiniot, Punjab 12.00 Bagasse +FO ST 12.00 40 Lotte Powergen (Pvt.) Limited, Karachi, Sindh 48.10 Gas ST 48.10 41 Noon Sugar Mills Limited, Sargodha, Punjab 14.80 Bagasse ST 14.80 Continued..... 143 State of Industry Report 2015

Installed Technology-wise S. Name of Company and Location Capacity Fuel Type Capacity (MW) No. (MW) Technology Capacity Bahria Town Electric Supply Company (Pvt.) 42 10.00 Coal Water Slurry DE 10.00 Limited, Rawalpindi, Punjab 43 Fatima Energy Limited, Muzaffargarh, Punjab 120.00 Bagasse +Biomass ST 120.00 Faran Sugar Mills Limited, Tando Muhammad 44 13.00 Biomass+FO ST 13.00 Khan, Sindh Chambar Sugar Mills (Pvt.) Limited, Tando 45 5.00 Bagasse +FO ST 5.00 Allahyar, Sindh Fimcotex Industries (Pvt.) Limited, Jamshoro, 46 35.538 Gas GE+ST 32.838+2.70 Sindh Thal Industries Corporation Limited 47 (for Safina Sugar Mills Limited - Plant I), 11.00 Bagasse ST 11.00 Chiniot, Punjab Ranipur Sugar Mills (Pvt.) Limited, Khairpur, 48 25.50 Bagasse ST 25.50 Sindh 49 Unicol Limited, Mirpur Khas, Sindh 6.60 Bagasse ST 6.60 Lucky Cement Limited, Lakki Marwat, Khyber Waste Heat Recovery Steam 50 16.00 Based Thermal Power 16.00 Pakhtunkhwa Station Generators Alliance Sugar Mills (Pvt.) Limited, Ghotki, 51 13.50 Bagasse ST 13.50 Sindh Habib Sugar Mills Limited, Benazirabad, 52 13.50 Bagasse ST 13.50 Sindh Mehran Sugar Mills Limited, Tando Allahyar, 53 14.06 Bagasse ST 14.06 Sindh 54 Shahmurad Sugar Mills Limited, Thatta, Sindh 15.25 Bagasse ST 15.25 55 Sanghar Sugar Mills Limited, Sanghar, Sindh 13.50 Bagasse ST 13.50 Mirpurkhas Sugar Mills Limited, Mirpurkhas, 56 8.50 Bagasse ST 8.50 Sindh Isolated Generation Companies (IGCs) Engro Polymer and Chemicals Limited, 1 79.02 HSD+ Gas GT 5.20 Karachi, Sindh Olympia Power Generation (Pvt.) Limited, 2 5.88 Gas GE 5.88 Karachi, Sindh 3 Lucky Energy (Pvt.) Limited, Karachi, Sindh 46.57 Gas GE 46.57 Nadeem Power Generation Limited, Karachi, 4 2.805 Gas GE 2.805 Sindh Shakarganj Energy (Pvt.) Limited, Jhang, 5 31.50 Bagasse+FO ST 31.50 Punjab Asia Generation (Pvt.) Limited, SITE & Kemari 6 11.10 Gas GE 11.10 Town, Karachi Innovative Energy Solutions Limited, Karachi, 7 8.031 Gas GE 8.031 Sindh 8 Aquagen (Pvt.) Limited, Karachi, Sindh 7.357 Gas GE 7.357 Port Qasim Electric Power Company (Pvt.) 9 1320.00 Imported Coal ST 2x660.00 Limited, Karachi, Sindh New Captive Power Plants (N-CPPs) 1 Dadu Energy (Pvt.) Limited, Dadu, Sindh 49.448 Gas GE+ST 46.648+2.80 Omni Power (Pvt.) Limited, Tando Muhammad 2 14.128 Gas GE+ST 13.328+0.80 Khan, Sindh Shikarpur Power (Pvt.) Limited Shikarpur, 3 17.66 Gas GE+ST 16.66+1.00 Sindh 4 Naudero Energy (Pvt.) Limited, Larkana, Sindh 17.66 Gas GE+ST 16.66+2.00 5 Anoud Textile Mills Limited, Jamshoro, Sindh 11.70 Gas GE 11.70

Continued..... 144 State of Industry Report 2015

Installed Technology-wise S. Name of Company and Location Capacity Fuel Type Capacity (MW) No. (MW) Technology Capacity 6 Lucky Cement Limited, Karachi, Sindh 29.73 Gas GE 29.73 7 Galaxy Textile Mills Limited, Jhang, Punjab 13.396 Gas GE 13.396 8 Thatta Power (Pvt.) Limited, Thatta, Sindh 45.984 Gas GE+ST 39.984+6.00 Hi-Tech Pipe & Engineering Industries, 9 15.00 Gas GT 12.00+3.00 Jamshoro, Sindh Distributed Generation Plants (DGPs) Anoud Power Generation Limited, Karachi, 1 30.95 FO+Gas DG+GE 23.84+7.11 Sindh 2 FFBL Power Company Limited, Karachi, Sindh 118.00 Coal+Gas ST 118.00 Short-Term Independent Power Producers (STIPPs) Gulf Powergen (Pvt.) Limited, Gujranwala, 1 83.84 RFO RE 83.84 Punjab Reshma Power Generation (Pvt.) Limited, 2 96.96 RFO RE 96.96 Kasur, Punjab Other IPPs 1 K-Energy (Pvt.) Limited, Karachi, Sindh 421.90 Imported Coal ST 2x210.95 GE = Gas Engines FO = Furnace Oil DE = Diesel Engines RE = Reciprocating Engines ST = Steam Turbines GT = Gas Turbines WT = Wind Turbines CB = Conventional Boiler Note: Shaded area indicate licenses issued in 2014-15. Source: National Electric Power Regulatory Authority, Islamabad

TABLE 41-D List of Public and Private Sector Power Generation Licensees Installed S. Date of Licence Company Capacity Fuel Type Technology No. (Issued+Valid Until) (MW) Generation Licence Granted to Public Sector Companies Jamshoro Power Generation Issued 01-07-2002 Gas+RFO 1 2344.00* GTs+STs Company Limited (GENCO-I) Valid until 30-06-2021 +Coal Central Power Generation Company Issued 01-07-2002 2 2431.70** Gas+RFO GTs+STs Limited (GENCO-II) Valid until 30-06-2017 Northern Power Generation Issued 01-07-2002 3 1726.00*** Gas+RFO GTs+STs Company Limited (GENCO-III) Valid until 30-06-2027 Lakhra Power Generation Company Issued 18-02-2005 Coal+RFO 4 150.00 STs Limited (GENCO-IV) Valid until 17-02-2020 +DO Generation Licence Granted to Private Sector Companies Issued 18-11-2002 1 K-Electric Limited (KEL) 2359.00 Gas+RFO GTs+STs Valid until 17-11-2027 *Include 2x660 MW Coal Power Project under implementation. **Include 747 MW of CCPP at TPS Guddu. ***NGPS Multan Power Plant has been excluded on expiry of its useful life. Source: National Electric Power Regulatory Authority, Islamabad

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TABLE 41-E List of Generation Licensees (IPPs under Power Policy 1994)

Installed Technology-wise Capacity S. Name of Company and Location Capacity Fuel Type (MW) No. (MW) Technology Capacity Fauji Kabirwala Power Company Limited, 1* 170 Gas GT+ST 96+74 Khanewal, Punjab 2* TNB Liberty Power Limited, Daharki, Sindh 235 Gas GT+ST 156+79 Habibullah Coastal Power Company (Pvt.) 3* 140 Gas GT+ST 111+29 Limited, Sheikh Manda, Balochistan Uch Power Limited, Murad Jamali, 4* 586 Gas GT+ST 390+196 Naseerabad, Balochistan Rousch (Pakistan) Power Limited, Sidhnai, 5* 450 Gas GT+ST 304+146 Khanewal, Punjab 6 Altern Energy Limited, Fateh Jang, Punjab 14 Gas GE 14 7* Kohinoor Energy Limited, Raiwind, Punjab 131 FO DE+ST 125+6 Lal Pir Power (Pvt.) Limited, Mehmood Kot, 8 362 FO ST 362 Muzaffargarh, Punjab Pak Gen. Power (Pvt.) Limited, Mehmood 9 365 FO ST 365 Kot, Muzaffargarh, Punjab Saba Power Company Limited, 10 136 FO ST 136 Farooqabad, Sheikhupura, Punjab The Hub Power Company Limited, Hub, 11 1292 FO ST 1292 Lasbela, Balochistan** Southern Electric Power, Raiwind, Lahore, 12 117 RFO DE 117 Punjab 13 Japan Power Generation, Raiwind, Punjab 135.6 RFO DE 135.6 Gul Ahmed Energy (Pvt.) Limited, Karachi, 14 136.17 RFO DE 136.17 Sindh 15 Tapal Energy (Pvt.) Limited, Karachi, Sindh 126 RFO DE 126 Kot Addu Power Company, Kot Addu, Gas+FO 16* 1600 GT+ST 1021+579 Muzaffargarh, Punjab** +HSD 17 Davis Energen (Pvt.) Limited, Jhang, Punjab 12.16 Gas GE 12.16 * Combined Cycle technology is being used in these plants. ** Prior to 1994 Power Policy Source: National Electric Power Regulatory Authority, Islamabad

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TABLE 41-F List of Generation Licensees (IPPs under Power Policy 2002)

Installed Technology-wise Capacity S. (MW) No. Name of Company and Location Capacity Fuel Type (MW) Technology Capacity 1 DHA Cogen Limited, Karachi, Sindh 94.00 Gas GT+ST 67+27 2 Star Power Generation Limited, Daharki, Sindh 133.515 Gas GT+ST 88.244+45.271 Orient Power Company (Pvt.) Limited, Balloki, 3 Punjab 225.00 Gas GT+ST 151+74 4 Saif Power Limited, Sahiwal, Punjab 225.00 Gas+HSD GT+ST 152+73 Sapphire Electric Power Company Limited, 5 Sheikhupura, Punjab 235.00 Gas+HSD GT+ST 152+83 6 Attock Gen Limited, Rawalpindi, Punjab 165.285 FO+HSD DG+ST 153.275+12.01 Halmore Power Generation Company (Pvt.) 7 Limited, Bhikki, Punjab 225.00 Gas+HSD GT+ST 150+75 Foundation Power Company (Daharki) Limited, 8 Daharki, Sindh 179.05 Gas+HSD GT+ST 114.9+64.15

9 Atlas Power (Pvt.) Limited, Sheikhupura, Punjab 224.35 RFO+LDO RE+ST 207.9+16.45

10 Gujranwala Energy Limited, Gujranwala, Punjab 201.451 HSFO+HSD RE+ST 187.836+13.615 11 Eastern Power Company Limited, Pasroor, Punjab 152.475 FO+HSD RE+ST 143.975+8.5 Engro Power Gen. Qadirpur Limited, Qadirpur, 12 Sindh 226.52 Gas+HSD GT+ST 127+100 13 Nishat Chunian Power Limited, Kasur, Punjab 202.179 RFO+HSD RE+ST 187.836+14.343 14 Nishat Power Limited, Kasur, Punjab 202.179 RFO+HSD RE+ST 187.836+14.343 Intergen (Pvt.) Limited, Lachi, Kohat, Khyber 15 Pakhtunkhwa 165.285 HSFO+HSD RE+ST 153.684+11.60 The Hub Power Company Limited (Narowal 16 Project), Narowal, Punjab 224.79 RFO+LDO RE+ST 207.9+16.89 17 Green Electric (Pvt.) Limited, Dadu, Sindh 188.00 Gas+HSD GT+ST 126+62 18 Liberty Power Tech Limited, Faisalabad, Punjab 202.179 RFO+HSD RE+ST 187.836+14.343 19 Grange Power Limited, Pakpattan, Punjab 163.353 Gas GT+ST 109+54.353 20 First Tri-Star Modaraba, Karachi, Sindh 110.00 Gas+HSD GT+ST 80+30 Uch-II Power (Pvt.) Limited, Naseerabad, 21 Balochistan 404.00 Gas GT+ST 267.54+136.46

22 Radian Energy Power Generation Company (Pvt.) 164.368 RFO+LFO RE+ST 153.684+10.684 Limited, Faisalabad, Punjab Engro Powergen Thar (Pvt.) Limited, Tharparker, Indigenous 23 Sindh 660.00 Coal ST+CB 2x330 Indigenous 24 CMEC Power (Pvt.) Limited, Jhelum Punjab 330.00 Coal ST+CB 330.00 Huaneng Shandong Ruyi (Pakistan) Energy (Pvt.) Imported 25 Limited, Sahiwal, Punjab 1320.00 Coal ST+CB 1320.00 Note: Shaded area indicate licenses issued in 2014-15. Source: National Electric Power Regulatory Authority, Islamabad

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TABLE 41-G List of Transmission and Distribution Licensees Date of S. Number of Consumers Licence Valid Company Licence No. (as on 30th June, 2015) Until Issued Transmission Licence Granted to Public Companies National Transmission and Dispatch 1 --- 31-12-2002 30-12-2032 Company Limited Transmission Licence Granted to Private Companies 1 K-Electric Limited --- 11-06-2010 10-06-2030 Distribution Licence Granted to Public Sector Companies Peshawar Electric Supply Company 1 2,956,567 30-04-2002 29-04-2022 Limited Tribal Areas Electricity Supply Company 2 441,562 12-08-2013 11-08-2033 Limited Islamabad Electric Supply Company 3 2,462,167 02-11-2001 01-11-2021 Limited Gujranwala Electric Power Company 4 2,923,493 23-04-2002 22-04-2022 Limited 5 Lahore Electric Supply Company Limited 3,909,862 01-04-2002 31-03-2022 Faisalabad Electric Supply Company 6 3,445,357 02-03-2002 01-03-2022 Limited 7 Multan Electric Power Company Limited 5,116,072 25-04-2002 24-04-2022 Hyderabad Electric Supply Company 8 976,888 23-04-2002 22-04-2022 Limited 9 Sukkur Electric Supply Company Limited 722,392 18-08-2011 17-08-2031 10 Quetta Electric Supply Company Limited 564,887 30-04-2002 29-04-2022 Distribution Licence Granted to Private Sector Companies 1 K-Electric Limited 2,158,290 21-07-2003 20-07-2023 2 Bahria Town (Pvt.) Limited 16,879 24-11-2010 23-11-2030 Distribution Licence Granted to Small Power Producers 1 Monnoo Energy Limited 3 20-10-2006 07-12-2016 2 Sapphire Power Generation Limited 8 20-10-2006 26-08-2016 3 Sitara Energy Limited 16 20-10-2006 01-01-2017 4 Gulistan Power Gen. Limited 4 20-10-2006 15-11-2016 5 Mahmood Textile Mills Limited 1 14-11-2006 21-10-2016 6 Kohinoor Mills Limited 1 14-11-2006 07-12-2016 7 Quetta Textile Mills Limited 3 14-11-2006 31-01-2017 8 Ibrahim Fibers (Pvt.) Limited 3 22-07-2008 30-12-2021 9 Crescent Powertec Limited 3 18-12-2008 21-10-2016 Distribution Licence Granted to Captive Power Producers 1 Engro Chemical Pakistan Limited Self Consumption 22-07-2009 21-07-2029 Source: National Electric Power Regulatory Authority, Islamabad

148 ELECTRICITY TRANSMISSION 12

State of Industry Report 2015

12. ELECTRICITY TRANSMISSION 12.1 General In Pakistan, there are two companies which are, presently engaged, in the business of electric power transmission. One is National Transmission and Dispatch Company Limited and the other is K-Electric Limited. NTDC is the National Grid Company of Pakistan and is, exclusively, responsible for electric power transmission in whole country except for the area served by K-Electric. NTDC is a public sector company and came into existence as a result of restructuring of WAPDA in 1998 and then has succeeded in obtaining a transmission licence by NEPRA in 2002. NTDC is responsible for overall reliability, planning and coordination of the electricity in Pakistan except the area under K-Electric. At present, NTDC owns a network of 500 kV, 220 kV and some 132 kV (links) transmission lines and grid stations in its network.

Besides NTDC, the other company which is engaged in electric power transmission business of Pakistan is K-Electric. K-Electric is a vertically integrated company operating in private sector. Earlier the company was in public sector and responsible for generation, transmission and distribution of electric power in its area. Later- on, K-Electric was privatized as a single vertically integrated electric power utility. K-Electric, at present, has three separate licenses; one for their generation businesses, second is for the distribution of electricity in its designated area and third is for their transmission network. The transmission network of K-Electric is connected to the national grid of the country by 220 kV and 132 kV links.

The statistics of electricity imported and exported by NTDC for the years 2010-11 to 2014-15 is shown in following table.

TABLE 42 Electricity Import and Export by NTDC (GWh) Country/Agency 2010-11 2011-12 2012-13 2013-14 2014-15 Electricity Import Iran 269 296 375 419 443 KEL 26 0 0 0 0 Total Electricity Imported 295 296 375 419 443 Electricity Export KEL 5,449 5,684 5,463 5,441 5,427 Any other Country/Region 10 43 0 0 0 Total Electricity Exported 5,459 5,727 5,463 5,441 5,427 Source: NTDC

12.2 Transmission Lines and Grid Stations with NTDC The integrated transmission system of NTDC comprises of 500 kV and 220 kV transmission lines and grid stations. The status of transmission lines and grid stations, at the end of fiscal years from 2011 to 2015, owned and operated by NTDC is mentioned in following table.

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Figure 42: Electricity Import and Export by NTDC (GWh)

6,000

5,000

4,000

3,000

2,000

1,000

- 2010-11 2011-12 2012-13 2013-14 2014-15

Total Electricity Imported Total Electricity Exported

TABLE 43 Transmission Lines and Grid Stations with NTDC A: Transmission Lines Total Transmission Lines and As on 500 kV 220 kV No. of Circuits 30th June No. of Circuits Total km No. of Circuits Total km No. of Circuits Total km 2011 30 5,078 114 7,427 144 12,505 2012 30 5,078 121 7,948 151 13,026 2013 30 5,144 124 8,358 154 13,502 2014 30 5,183 124 9,104 154 14,287 2015 30 5,197 124 9,814 154 15,011 B: Grid Stations

500/220 kV 220/132 kV Total No. of Grid Stations and As on MVA Capacity th 30 June No. of Grid No. of Grid MVA Total No. of Total MVA Station MVA Capacity Station Capacity Grid Station Capacity 2011 12 14,850 27 16,494 39 31,344 2012 12 14,850 29 18,044 41 32,894 2013 12 15,750 29 18,231 41 33,981 2014 13 17,400 35 21,030 48 38,430 2015 13 18,624 37 24,063 50 42,687 Source: NTDC

12.3 Transmission Losses When power is transmitted through power carrier lines, some power is “lost” as dissipated heat, during transmission. Technically it is not possible to eliminate such losses however such losses can be reduced by transmitting electric power to higher voltages. The history of transmission losses of NTDC system for the years 2010-11 to 2014-15 are mentioned in following table.

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TABLE 44 Unit Received, Delivered and Transmission Losses in NTDC System (GWh) Unit 2010-11 2011-12 2012-13 2013-14 2014-15 Unit Received by NTDC GWh 90,575.00 88,987.00 87,080.00 95,566.00 97,474.00 Unit Delivered by NTDC GWh 87,835.00 86,479.00 84,424.00 92,868.00 94,909.00 Unit Losses GWh 2,740.00 2,508.00 2,656.00 2,698.00 2,565.00 (Transmission) % 3.03 2.82 3.05 2.82 2.63 Source: NTDC

12.4 Utilization of Transmission Lines and Power Transformers Appropriate utilization of transmission lines and power transformers in any electric power system is important and has a very significant impact both technically as well as financially. The position of utilization of transmission lines in the NTDC’s network is mentioned in following table.

TABLE 45 Utilization of Transmission Lines and Power Transformers in NTDC System A: Loading Status of Transmission Lines 2010-11 2011-12 2012-13 2013-14 2014-15 Overloaded Transmission Lines/Circuits 500 kV 0 0 0 0 2 (Nos.) 220 kV 3 23 35 25 32 Underutilized Transmission Lines/ 500 kV 4 34 34 34 30 Circuits (Nos.) 220 kV 25 85 78 95 74 B: Loading Status of Power Transformers 2010-11 2011-12 2012-13 2013-14 2014-15 500 kV 7 5 4 5 5 Overloaded Power Transformers (Nos.) 220 kV 25 58 56 63 47 Underutilized Power Transformers 500 kV 6 29 30 26 22 (Nos.) 220 kV 23 33 54 55 43 Source: NTDC

TABLE 46 Transmission Lines Tripping in PEPCO and K-Electric System PEPCO System Planned Outages Forced Outages Year 500 kV 220 kV 500 kV 220 kV No. of Outages 145 528 113 268 2010-11 Total duration in minutes 62066 219749 227048 428970 Maximum duration of any single outage (Minutes) 6501 12383 6501 111825 No. of Outages 176 499 47 267 2011-12 Total duration in minutes 76684 233631 15836 111566 Maximum duration of any single outage (Minutes) 3470 9921 7718 16045 No. of Outages 346 679 78 248 2012-13 Total duration in minutes 152515 257849 91819 263021 Maximum duration of any single outage (Minutes) 3503 4983 56334 26281 No. of Outages 344 665 90 265 2013-14 Total duration in minutes 165426 264682 113460 101493 Maximum duration of any single outage (Minutes) 14584 9566 41771 37339 No. of Outages 469 777 76 250 2014-15 Total duration in minutes 267263 230783 85656 727395 Maximum duration of any single outage (Minutes) 3729 1990 12347 244003 Continued..... 153 State of Industry Report 2015

KEL System Planned Outages Forced Outages Year 220 kV 132 kV 220 kV 132 kV No. of Outages 263 666 60 519 2010-11 Total duration in minutes 11898 252539 16275 149411 Maximum duration of any single outage (Minutes) 5672 n.p. 2853 n.p. No. of Outages 259 786 17 519 2011-12 Total duration in minutes 113242 275553 2672 154545 Maximum duration of any single outage (Minutes) 6177 3240 613 29545 No. of Outages 269 688 87 412 2012-13 Total duration in minutes 104550 234084 34298 76641 Maximum duration of any single outage (Minutes) 6186 10910 16885 2245 No. of Outages 252 660 79 359 2013-14 Total duration in minutes 99767 219884 21423 85754 Maximum duration of any single outage (Minutes) 1266 1081 1807 4368 No. of Outages n.p. 12 n.p. 39 2014-15 Total duration in minutes n.p. 3662 n.p. 5190 Maximum duration of any single outage (Minutes) n.p. 849 n.p. 631 Source: NTDC / KEL

12.5 Investment Plan - NTDC System Being National Grid Company of the country, NTDC is solely responsible for overall reliability, planning and coordination of the electricity transmission in Pakistan except, the area under K-Electric. Further, NTDC is solely responsible to provide interconnection arrangement to evacuate power from up-coming power projects in the country. To discharge its responsibility NTDC has prepared an investment plan for improvement of its transmission network and grid stations. Table shows that Grid Station and Transmission Expansion Plans of NTDC.

TABLE 47 Grid Station Expansion Plan of NTDC 500/220 kV Grids 220/132 kV Grids Period of *Estimated Estimated Report Nos. MVA Expected Cost Nos. MVA Expected Cost Capacity COD (Rs. Million) Capacity COD (Rs. Million) New Grid Station 2015-16 3 3750 2016-17 20,399 8 5750 2016-17 26,233 2016-17 1 1500 2019-20 3,500 - - - - Extension 2015-16 1 430 2016-17 697 - - - - Addition/Reinforcement of Transformers at Overloaded Grid Stations 2015-16 1 0 2016-17 1,413 - - - - 2016-17 ------2017-18 - - - - 6 3000 2019-20 16,400 * The cost of 500/220 kV Grid Stations also include the cost of 220/132 kV Transformers. Source: NTDC

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TABLE 48 Power Sector Investment Plan for NTDC Transmission Lines (as per approved PC-I)

Transmission Lines Estimated S. Capacity Expected Completion Name of Project Cost No. Voltage Line Length (MVA) Date Level (kV) (km) (Million Rs.) 1 T.T. Singh 220 2 750 2015 1,759 2 Rahim Yar Khan 500 60 1700 2015 4,936 3 Dera Murad Jamali 220 5 260 June, 2015 880 4 Gujrat 220 4 750 December, 2015 1,966 5 Ghazi Road 220 80 480 December, 2015 2,592 6 Chistian 220 65 500 December, 2015 2,633 7 SVC at NKLP --- -- 450 December, 2015 2,087 8 Lahore 500 130 1500 December, 2015 12,664 9 Quetta --- -- 450 December, 2015 2,087 10 Shikarpur 500 84 1200 December, 2015 8,085 11 Nowshehra 220 10 750 2015-16 1,876 12 Lalian 220 8 750 2015-16 1,581 13 Mansehra 220 1 50 2015-16 905 14 Dera Ismail Khan 220 100 500 2015-16 3,744 15 Augmentation of Existing Grid Stations: (i) Rawat 500 - 750 (ii) Sheikh Muhammadi 220 - 1000 (iii) Burhan 220 - 1000 (iv) Bund Road 220 - 1000 December, 2015 3900 (v) Mardan 220 - 500 (vi) Bahawalpur 220 - 500 (vii) Quetta Industrial 220 - 500 Source: NTDC

TABLE 49 Interconnection Arrangement to Evacuate Power from up-coming (Public and Private Sector) Power Projects Plant S. Name of Power Expected Capacity Proposed Transmission Scheme No. Project COD (MW) 220 kV Chashma Nuclear - Bannu D/C T/L (125 km) Power Dispersal from Chashma Nuclear 220 kV D/C T/L for in/out of existing C1 and C2 at C3 and C4 (2 1 2x340 2015-16 Power Project (C3 and km) C4) Extension at 220 kV Bannu 500 kV Guddu-Muzaffargarh S/C T/L (256 km) Power Dispersal from Two 500 kV T/L for in/out of 500 kV Guddu-Multan S/C T/L at 2 747 2015-16 747 CCPP at Guddu 500 kV Muzaffargarh (10 km) Extension at 500 kV Muzaffargarh 220 kV Uch-II - Sibbi D/C T/L (125 km) 220 kV D/C T/L for in/out of 200 kV existing Uch-I to Shikarpur Power Dispersal from 3 404 2015-16 New S/C T/L at Uch-II (0.5 km) Uch-II Reconductoring of 220 kV T/L Uch-I to Uch-II (I km) Extension at 220 kV Sibbi Substation Continued.....

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Plant S. Name of Power Expected Capacity Proposed Transmission Scheme No. Project COD (MW) 3rd Circuit (for Power 500 kV Jamshoro-Moro-RYK S/C T/L (535 km) Evacuation from 500 kV Moro-Dadu S/C T/L (55 km) 2x660 MW Coal Fired 4 2270 2015-16 PPs at Jamshoro and 500 kV Switching Station at Moro Dispersal of Wind Power) Extension at 500 kV Jamshoro, Dadu and RYK Grid Stations 500 kV D/C T/L from Neelum Jhelum to Domali (145 km) 500 kV D/C T/L from Domali to 500 kV Gujranwala Grid Station (130 km) Power Dispersal from Extension at 500 kV Gujranwala (two lines bays with 3x37 MVA Neelum Jhelum, Azad 969+650+ 5 2015-16 Shunt Reactors) Pattan and Karot 720=2339 Hydropower Projects 500 kV D/C T/L for in/out of 500 kV Neelum Jhelum Gujranwala S/C at Azad Pattan (5 km) 500 kV D/C T/L for in/out of 500 kV Neelum Jhelum Gujranwala S/C at Karot (5 km) 100 2014-15 Phase I: 132 kV D/C T/Ls (4 km) 300 2014-15 Phase II: 132 kV D/C T/Ls (52 km) Phase III: 220 kV Grid Station at Lal-Suhanra with 3x250 MVA, Evacuation of Power 220/132 kV transformers along with allied equipment and from 1000 MW Quaid- 6 accessories e-Azam Solar Park at Lal-Suhanra 600 2015-16 220 kV D/C T/L from 220 kV Lal-Suhanra to 220 kV Bahawalpur (40 km) Three 132 kV D/C T/Ls on Rail Conductor form Solar Projects Sites to 220 kV Grid Station at Lal-Suhanra (8 km each) Phase I: 132 kV Jhimpir New Collector Substation 330 2015-16 132 kV D/C T/Lines (107 km) Phase II: Upgradation of 132 kV Jhimpir Substation to 220 kV Evacuation of Power Substation (3x250 MVA) from Wind Power 7 Projects at Jhimpir 220 kV Gas Insulated Substation (GIS) at Gharo (2x250 MVA) 620 2016-17 and Gharo Wind 220 kV D/C T/Lines (155 km) Clusters 132 kV D/C T/Lines (85 km) Addition of 450 MVA, 500/220 kV T/F at 500 kV Jamshoro 500 2016-17 Phase III: 220 kV D/C Line (10 km) Power Dispersal from 500 kV Thar - Matiari D/C T/L (250 km) 8 Thar Coal based 1200 2016-17 Power Plant 500 kV Switching Station at Matiari Evacuation of Power In/Out of existing 500 kV Lahore-Gatti Singh Circuit at 500 kV 9 from 1200 MW LNG 1200 2016-17 Switchyard of Bhikki Power Plant (3 km) Based PP at Bhikki 500 kV Double Circuit T/L from Balloki Power Project to Lahore Evacuation of Power South Grid Station (40 km) 10 from 1200 MW LNG 1200 2016-17 Addition of 1x750 MVA 500/220 kV Transformer along with allied Based PP at Bhikki equipment and two 500 kV line baysat 500 kV Lahore South Grid Station Evacuation of Power In/Out of 500 kV D/C T/L from Muzaffargarh-Gatti at HB Shah from 1200 MW LNG (3 km) 11 1200 2016-17 Based PP at Jhnag (Haveli Bahadur Shah) In/Out of 500 kV Multan-Gatti D/C T/L at HB Shah (25 km) Evacuation of Power 500 kV D/C T/L from Bin Qasim Power Plant to Matiari Switching 12 from 1320 MW Bin 1320 2016-17 Station (180 km) Qasim Project Continued.....

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Plant S. Name of Power Expected Capacity Proposed Transmission Scheme No. Project COD (MW) Evacuation of Power 500 kV D/C T/L from Hub Power Plant to Matiari Switching 13 from 1320 MW Hub 11320 2016-17 Station (220 km) Power Company Ltd. Evacuation of Power from 300 MW Coal 14 300 2016-17 132 kV D/C T/L (80 km) Fired Power Plant at Pind Dadin Khan Evacuation of Power from 1320 MW 15 1320 2016-17 In/Out of Yousafwala-Lahore 500 kV D/C T/L at Sahiwal (0.5 km) Imported Coal Based Power Plant at Sahiwal Evacuation of Power 16 from 147 MW Patrind 147 2016-17 132 kV T/L (70 km) HPP Replacement of Existing Tarbela-Burhan D/C T/L (35.1 km) Evacuation of Power Replacement of Existing 220 kV Tarbela-Burhan-ISPR D/C T/L 17 from Tarbela 4th 1410 2016-17 (62.5 km) Extension In/Out of one Circuit of 220 kV Mansehra-ISPR D/C T/L (40 km) Evacuation of Power 18 from Tarbela 5th 1320 2017-18 500 kV D/C T/L (77 km) Extension Evacuation of Power 500 kV D/C T/L from Siddiqsons to South 500 kV Substation (32 19 from Siddiqsons 350 2018-19 km) Limited Evacuation of Power 500 kV D/C T/L for In/Out of Siddiqsons - South 500 kV 20 from Lucky Electric 660 2018-19 Substation (32 km) Power Company Ltd. Evacuation of Power 21 2160 2019-20 500 kV D/C T/L (615 km) from Dasu HPP Evacuation of Power 22 840 2019-20 500 kV D/C T/L (615 km) from Suki Kinari HPP Source: NTDC

12.6 Transmission Lines and Grid Stations with K-Electric The K-Electric was a vertically integrated public limited company, which was responsible for generation, transmission and distribution of electric power in the area of Karachi City and its suburb. Later-on, in year 2005, it was privatized with same function of generation, transmission and distribution of electric power in its area under separate licenses. K-Electric system is connected to the national grid of the country by 220 kV and 132 kV links. The statistics and investment/expansion plans in respect of K-Electric transmission lines and grid stations are given in the following tables:

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TABLE 50 Transmission Lines and Grid Stations with K-Electric 2010-11 2011-12 2012-13 2013-14 2014-15 Length of Transmission Lines in km 220 kV 321 321 323 323 323 Overhead 132 kV 611 611 611 611 611 Lines 66 kV 149 149 149 149 149 220 kV 17 17 15 15 15 Underground 132 kV 150 150 150 150 151 Lines 66 kV 0 0 0 0 0 Number of Grid Stations in KEL Transmission System 2010-11 2011-12 2012-13 2013-14 2014-15 No. MVA No. MVA No. MVA No. MVA No. MVA 220 kV 7 3000 7 3000 7 3000 7 3000 7 3000 KEL’s Owned 132 kV 50 n.p. 51 n.p. 52 4611 53 4679 54 4732 Grid Stations 66 kV 3 n.p. 3 n.p. 3 60 3 60 3 69 Consumers 220 kV 1 40 1 40 1 40 1 80 1 80 Owned 132 kV 5 n.a. 8 n.a. 9 n.a. 9 452 9 452 Grid Stations 66 kV 0 0 0 0 0 0 0 0 0 0 Total No. of Grid 66 3040 70 3040 72 7711 73 8271 74 8333 Stations Source: KEL

TABLE 51 Transmission/Sub-Transmission Losses in K-Electric System (GWh) 2010-11 2011-12 2012-13 2013-14 2014-15 Total Units Purchased by KEL 7,632.14 7,229.71 7,257.00 7,282.00 7,496.00 Total Units Generated by KEL 7,826.27 8,029.00 8,567.00 8,709.00 9,319.00 (Gross) Auxiliary Consumption in KEL 591.62 636.00 665.00 658.00 704.00 Plant Unit Sent Out – KEL 7,234.65 7,393.00 7,902.00 8,051.00 8,615.00 Units Available for Distribution 14,866.79 14,622.71 15,159.00 15,333.00 16,111.00 Units Sold 10,071.27 10,279.00 10,942.00 11,453.00 12,294.00 T&D Losses (GWh) 4,795.52 4,343.71 4,217.00 3,880.00 3,817.00 Energy Auxiliary Losses (%) 7.56 7.92 7.76 7.56 7.55 Losses T&D Losses (%) 32.26 29.71 27.82 25.30 23.69 Source: KEL

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Figure 51. Units Available, Units Sold and T&D Losses (GWh)

2014-15

2013-14

2012-13

2011-12

2010-11

0 2000 4000 6000 8000 10000 12000 14000 16000 18000

Units Available for Distribution Units Sold T&D Losses (GWh)

TABLE 52 Amount Injected (in million Rs.) to Reinforce/ Expand 220 and 132 kV Transmission System of K-Electric 2013-14 2014-15 Description FC LC Total FC LC Total Grid Stations - - 671.00 - - 1568.00 Transmission - - 405.00 - - 425.00 and SCADA Reinforcement ------Others - - 67.00 - - 30.00 Total - - 1143.00 - - 2023.00 Investment Plan in Transmission Line (220 and 132 kV) (in million US$) of K-Electric 2015-16 2016-17 Description FC LC Total FC LC Total Grid Stations - - 37.60 - - 48.00 Transmission - - 60.70 - - 71.00 SCADA - - 9.70 - - 11.70 Reinforcement - - 18.20 - - 29.10 Total - - 126.20 - - 159.80 FC: Foreign Currency converted into equivalent US$ to Euro (1 Euro=US$ 1.107) LC: Local Currency converted into equivalent US$ with current US$ to Rupee Rate (1 US$=PkRs. 102) Source: KEL

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Table 53 Loading Position of 500 kV Grid Stations of NTDC (2014-15) Name of NTDC Name of Region and No. of Power Voltage Capacity of Loading Grid Station Name of Transformer Level (kV) Transformer Position (%) DISCO (MVA) T-1 500/220 450 76.21 Islamabad Rawat (IESCO/GEPCO) T-2 500/220 450 76.21 T-3 500/220 450 76.21 T-1 500/220 450 77.05 Sheikh Muhammadi Islamabad T-2 500/220 450 77.05 Peshawar (TESCO/PESCO) T-9 500/220 450 77.05 T-1 500/220 600 55.24 Nokhar Lahore (GEPCO) T-2 500/220 600 55.24 T-1 500/220 450 84.67 Lahore T-2 500/220 450 86.03 Gatti (FESCO/GEPCO/ LESCO/MEPCO) T-3 500/220 450 82.22 T-4 500/220 450 82.22 T-1 500/220 600 81.59 T-2 500/220 600 81.59 Sheikhupura Lahore (LESCO) T-3 500/220 600 81.59 T-4 500/220 600 81.59 T-1 500/220 450 72.99 Multan Multan (MEPCO) T-2 500/220 450 72.99 T-1 500/220 600 41.27 Muzafargarh Multan (MEPCO) T-2 500/220 600 39.37 T-1 500/220 600 61.59 Yousafwala Multan (MEPCO/LESCO) T-2 500/220 600 61.59 Proper meters Multan T-1 500/220 600 not installed D.G. Khan (MEPCO) T-2 500/220 600 PTW T-2 500/220 450 51.65 Dadu Hyderabad (HESCO/SEPCO) T-4 500/220 450 49.11 T-1 500/220 450 24.13 Hyderabad Guddu (SEPCO/QESCO/ T-2 500/220 450 24.13 MEPCO) T-3 500/220 450 24.13 T-1 500/220 600 62.22 NKI Hyderabad (HESCO/K-EL) T-2 500/220 600 62.22 T-1 500/220 450 45.72 Jamshoro Hyderabad (HESCO/K-EL) T-2 500/220 450 45.72 Source: NTDC

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Table 54 Loading Position of 220 kV Grid Stations of NTDC (2014-15) Name of NTDC Capacity of Name of Region and No. of Power Voltage Transformer Loading Grid Station Name of DISCO Transformer Level (kV) (MVA) Position (%) T-1 220/132 160 91.43 Burhan Islamabad T-4 220/132 160 91.43 (IESCO/LESCO) T-2 220/132 160 80.00 T-3 220/132 250 82.19 T-1 220/132 160 81.43 Islamabad Bannu (PESCO/TESCO) T-2 220/132 160 81.43 T-5 220/132 160 60.00 T-1 220/132 160 90.14 Daud Khail Islamabad (IESCO/FESCO) T-2 220/132 160 90.14 T-1 220/132 250 97.72 Islamabad Mardan (PESCO) T-2 220/132 160 100.29 T-3 220/132 160 88.71 T-1 220/132 160 97.14 Islamabad Sangjani (IESCO) T-2 220/132 160 97.14 T-3 220/132 160 84.29 T-1 220/132 160 81.86 T-2 220/132 160 81.86 Islamabad Shahi Bagh (PESCO/TESCO) T-3 220/132 160 81.86 Shifted for T-4 220/132 160 Repair T-1 220/132 250 85.39 University Islamabad (IESCO) T-2 220/132 250 18.26 T-1 220/132 250 102.28 Lahore NKLP Lahore (LESCO) T-2 220/132 250 105.02 T-3 220/132 250 105.02 T-1 220/132 250 93.15 Lahore Ravi Lahore (LESCO) T-2 220/132 250 76.71 T-3 220/132 250 76.71 T-1 220/132 160 92.86 T-2 220/132 160 92.86 Sarfraz Nagar Lahore (LESCO) T-3 220/132 160 92.86 T-4 220/132 160 92.86 T-1 220/132 160 75.71 Lahore Sialkot (GEPCO) T-2 220/132 160 75.71 T-3 220/132 160 75.71 T-1 220/132 160 92.86 Kala Shah Lahore Kaku (GEPCO/LESCO) T-2 220/132 160 92.86 T-3 220/132 160 92.86 T-1 220/132 250 65.30 T-2 220/132 250 74.89 Band Road Lahore (LESCO) T-3 220/132 250 65.30 T-4 220/132 250 74.89 T-1 220/132 160 90.00 Lahore Shalamar (LESCO) T-2 220/132 160 86.71 T-3 220/132 160 86.71 T-1 220/132 160 94.29 T-2 220/132 160 78.57 Ghakkar Lahore (GEPCO) T-3 220/132 160 102.86 T-4 220/132 160 94.29 T-1 220/132 160 82.86 Lahore WAPDA Town (LESCO) T-2 220/132 160 82.86 T-3 220/132 160 82.86 Continued..... 161 State of Industry Report 2015

Name of NTDC Capacity of Name of Region and No. of Power Voltage Transformer Loading Grid Station Name of DISCO Transformer Level (kV) (MVA) Position (%) GZR Lahore (LESCO) T-1 220/132 250 82.19 T-1 220/132 160 91.14 T-2 220/132 160 91.43 Jaranwala Lahore (FESCO) T-3 220/132 160 88.29 T-4 220/132 160 100.00 T-1 220/132 160 104.29 Lahore Ludewala (FESCO) T-2 220/132 160 104.29 T-3 220/132 160 104.29 T-4 220/132 60/63.5 92.20 Nishatabad Lahore (FESCO) T-5 220/132 160 95.00 T-1 220/132 160 91.43 Sammundari Lahore Road (FESCO) T-2 220/132 160 109.29 T-3 220/132 160 109.29 Toba Take Lahore Singh (FESCO) T-1 220/132 250 106.85 T-1 220/132 160 91.43 Bahawalpur Multan T-2 220/132 250 95.16 (MEPCO) T-3 220/132 250 95.16 T-1 220/132 160 101.43 Multan Vehari (MEPCO) T-2 220/132 160 101.43 T-3 220/132 160 102.86 T-1 220/132 160 57.14 Muzafargarh Multan (MEPCO) T-2 220/132 160 57.14 T-1 220/132 250 61.19 Okara Multan T-2 220/132 250 (LESCO) Not Energized T-3 220/132 250 T-1 220/132 160 Not Energized Kasswal Multan (MEPCO) T-2 220/132 160 111.43 T-1 220/132 160 90.00 Hyderabad Hala Road (HESCO) T-2 220/132 160 90.00 T-3 220/132 160 92.86 T-1 220/132 160 74.29 Quetta Hyderabad Industrial (QESCO) T-2 220/132 160 74.29 T-3 220/132 160 71.43 T-1 220/132 160 77.43 Sibbi Hyderabad (QESCO) T-2 220/132 160 77.43 T-1 220/132 160 94.29 Hyderabad Shikarpur (SEPCO) T-2 220/132 160 91.43 T-3 220/132 160 91.43 T-1 220/132 160 98.57 TMK Road Hyderabad (HESCO) T-2 220/132 160 97.14 T-1 220/132 250 56.62 Daharki Hyderabad (SEPCO) T-2 220/132 160 52.86 T-1 220/132 250 77.63 Rohri Hyderabad (SEPCO) T-2 220/132 250 29.22 T-1 220/132 160 97.14 Khuzdar Hyderabad (QESCO) T-2 220/132 160 48.57 T-1 220/132 250 Not Energized Loralai Hyderabad (QESCO) T-2 220/132 250 56.62 Source: NTDC

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State of Industry Report 2015

13. ELECTRICITY DISTRIBUTION 13.1 General Presently there are ten distribution companies in public sector, which are distributing electric power to end- consumers in Pakistan except the area served by K-Electric. In the area of Karachi City and its suburbs, K-Electric is solely responsible for distributing of electric power to end-consumers under a separate distribution licence granted by NEPRA. In addition to ten public sector Distribution Companies and two private sector Distribution Companies, NEPRA so far has granted nine distribution licenses to Small Power Producers and one distribution licence to Captive Power Producer for supply of electric power to designated BPCs. The List of distribution licence granted by NEPRA is given in following table.

TABLE 55 List of Licenses Issued to Distribution Companies Number of S. Date of Licence Licence Valid Company Consumers (as on No. Issued Until 30th June, 2015) Distribution Companies working in Public Sector 1 Peshawar Electric Supply Company Limited 2,956,567 30-04-2002 29-04-2022 Tribal Areas Electricity Supply Company 2 441,562 12-08-2013 11-08-2033 Limited 3 Islamabad Electric Supply Company Limited 2,462,167 02-11-2001 01-11-2021 4 Gujranwala Electric Power Company Limited 2,923,493 23-04-2002 22-04-2022 5 Lahore Electric Supply Company Limited 3,909,862 01-04-2002 31-03-2022 6 Faisalabad Electric Supply Company Limited 3,445,357 02-03-2002 01-03-2022 7 Multan Electric Power Company Limited 5,116,072 25-04-2002 24-04-2022 8 Hyderabad Electric Supply Company Limited 976,888 23-04-2002 22-04-2022 9 Sukkur Electric Supply Company Limited 722,392 18-08-2011 17-08-2031 10 Quetta Electric Supply Company Limited 564,887 30-04-2002 29-04-2022 Distribution Companies working in Private Sector 1 K-Electric Limited 2,158,290 21-07-2003 20-07-2023 2 Bahria Town (Pvt.) Limited 16,879 24-11-2010 23-11-2030 Distribution Licence Granted to Small Power Producers 1 Monnoo Energy Limited 3 20-10-2006 07-12-2016 2 Sapphire Power Generation Limited 8 20-10-2006 26-08-2016 3 Sitara Energy Limited 16 20-10-2006 01-01-2017 4 Gulistan Power Generation Limited 4 20-10-2006 15-11-2016 5 Mahmood Textile Mills Limited 1 14-11-2006 21-10-2016 6 Kohinoor Mills Limited 1 14-11-2006 07-12-2016 7 Quetta Textile Mills Limited 3 14-11-2006 31-01-2017 8 Ibrahim Fibers (Pvt.) Limited 3 22-07-2008 30-12-2021 9 Crescent Powertec Limited 3 18-12-2008 21-10-2016 Distribution Licence Granted to Captive Power Producers 1 Engro Chemical Pakistan Limited Self Consumption 22-07-2009 21-07-2029 Source: National Electric Power Regulatory Authority

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TABLE 56 Service Area of Distribution Companies Service Area DISCO Service Area (Sq. km) PESCO 77,474 Whole Province of Khyber Pakhtunkhwa, except tribal areas Federally Administrated Tribal Areas (FATA) (comprising of Bajaur, Mohmand, Khyber, Ourakzai, Kurrum, North Wazirstan, South Wazirstan TESCO 27,220 agencies) and Frontier Regions (FRs) (i.e. FR Peshawar, FR Kohat, FR Bannu, FR Lakhi, FR Tank and FR DI Khan IESCO 23,160 Federal Capital Islamabad, Rawalpindi, Attock, Jhelum, Chakwal GEPCO 17,207 Gujranwala, Sialkot, Mandi Bahauddin, Hafizabad, Narowal, Gujrat LESCO 19,064 Lahore, Sheikhupura, Kasur, Okara, Nankana Faisalabad, Sargodha, Khushab, Jhang, Toba Tek Singh, Bhalwal, Mianwali, FESCO 36,122 Bhakkar Multan, Rahim Yar Khan, Khanewal, Sahiwal, Pakpattan, Vehari, MEPCO 105,505 Muzaffargarh, Dera Ghazi Khan, Leiah, Rajan Pur, Bahawalpur, Lodhran, Bahawalnagar All Province of Sindh except Karachi, Sukkur, Ghotki, Khairpur, Kashmore, Kandhkot, Jacobabad, Shikarpur, Larkana, Kambar, Shahdadkot, Dadu and HESCO 81,087 some portions of Jamshoro, Naushehro Feroz, Shaheed Benazirabad and Rahimyar Khan Sukkur, Ghotki, Khairpur, Kashmore, Kandhkot, Jacobabad, Shikarpur, SEPCO 56,300 Larkana, Kambar, Shahdadkot, Dadu and some portions of Jamshoro, Naushehro Feroz, Shaheed Benazirabad and Rahimyar Khan Whole Province of Balochistan, except Lasbela where K-Electric is QESCO 334,616 responsible for distribution of power K-Electric Entire Karachi and its suburbs upto Dhabeji and Gharo in Sindh and over 6,500 Limited Hub, Uthal, Vindhar and Bela in Balochistan Source: National Electric Power Regulatory Authority

13.2 Function of Distribution Companies The distribution companies in Pakistan are responsible for channeling electricity from the transmission substations below 220 kV to the consumers at different distribution voltages. The end users are classified as residential, commercial, industrial, agriculture, street lights etc. The distribution network is composed of lines and grid stations of 132 kV and lower voltage capacities, and each distribution company is responsible for constructing, operating, and maintaining the power distribution facilities within its dedicated geographic area. The overall distribution system, especially in urban areas, is overstressed and needs to be upgraded, augmented, and expanded.

13.3 Distribution System Performance The continuity of supply is one of the most important indicators to measure the performance of any Distribution Company. Besides other, the following three indicators are commonly used to monitor the system performance of DISCOs, in respect of supply reliability and quality of supply. The indicators are listed as under:

Total annual number of all Consumer Power Supply Interruptions System Average Interruption = Frequency Index (SAIFI) Total number of consumers served by the distribution company in a given year

System Average Interruption = Aggregate sum of all Consumer Power Supply Interruption durations in minutes Duration Index (SAIDI) Total number of consumers served by the distribution company in a given year

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A comparison of SAIFI and SAIDI in respect of all DISCOs of the country, for the year 2010-11 to 2014-15, has been carried out and is included in this report. Pursuant to NEPRA, Performance Standards (Distribution) Rules, 2005 a Distribution Company shall ensure that the SAIFI and SAIDI does not exceed thirteen (13) and fourteen (14) in numbers and minutes, respectively.

TABLE 57 Comparison of SAIFI and SAIDI of all Distribution Companies DISCO 2010-11 2011-12 2012-13 2013-14 2014-15 PESCO 2459330 2542747 2530655 2588473 2618779 TESCO - - - 390723 384031 IESCO 2094299 2206006 2260203 2342241 2423317 GEPCO 2500268 2608374 2568859 2736688 2812997 LESCO 2959110 3052299 3164986 3286668 3432160 Total Number FESCO 2996549 3278533 3214275 3288932 2445562 of Consumers MEPCO 4095946 4290373 4535062 4693061 4989020 (Nos.) HESCO 1539637 883335 915805 952296 976923 SEPCO - 643197 687045 711727 721087 QESCO 487620 503158 516327 535145 561280 K-EL 2370738 2388579 2385100 2358357 2317947 BTPL 6756 8845 11838 15636 16879 Total 21510253 22405446 22790155 23899947 23699982 PESCO 587275327 821123054 864386357 819134634 825967981 TESCO - - - 49458 36879 IESCO 857621 1305999 1391792 120949 86134 GEPCO 63230504 72435349 69726399 28804296 29294902 Total Annual LESCO 116264697 89713568 160058187 256478823 180162181 Number of FESCO 115742546 194766923 182579281 116444302 160355190 Consumer MEPCO 759867592 795001382 678829469 945813581 886095371 Power Supply HESCO 2311912695 680501756 668882208 218961910 197662324 Interruptions SEPCO - 219610030 2870251802 178978331 164384407 QESCO 80445210 78537463 79422810 77573236 63193661 K-EL 82737192 77612818 74576586 58293812 51478645 BTPL 8291 116 40510 105 81 PESCO 48044522020 71677299240 74832413870 72339031400 73155560030 TESCO - - - 819028 508279 IESCO 47380746 82736301 78663777 3886042 2411513 Aggregate sum GEPCO 792887713 760565671 676186878 35971518 37129560 LESCO 10266206977 7968880969 14608740454 15643260013 10331785985 of all Consumer FESCO 63649624760 4331500066 4019965724 3739602394 9243009119 Power Supply MEPCO 65110006031 689654325 58111790700 83088717833 78216126150 Interruptions HESCO 1594389070 21191991580 19419312750 15883027060 10397137520 (Duration in SEPCO - 11727318040 3297761640 1738562122 1544108334 Minutes) QESCO 6543784521 6445823719 6523770172 6351140612 4213425000 K-EL 5195969221 4438509649 4270360371 3526349005 3083517500 BTPL 339306 14658 81454 12303 12107 Total 201245110365 129314294218 185839047790 202350379330 190224731097 PESCO 238.79 323.00 341.57 316.45 315.40 TESCO - - - 0.12 0.10 System Average IESCO 0.41 0.59 0.62 0.05 0.04 GEPCO 25.29 27.77 27.14 10.53 10.41 Interruption LESCO 39.29 29.39 50.57 78.04 52.49 Frequency FESCO 38.63 59.39 56.80 35.40 46.54 Index (SAIFI), MEPCO 185.52 185.29 149.68 201.53 177.61 Power Supply HESCO 1501.62 770.28 730.38 229.93 202.33 Interruptions per SEPCO - 341.43 4177.68 251.48 227.96 consumer per year QESCO 164.98 156.08 153.82 144.95 112.58 K-EL 34.90 32.49 31.27 24.71 22.21 BTPL 1.23 0.01 3.42 0.006 0.0095 PESCO 19535.60 28189.00 29570.37 27946.60 27934.98 TESCO - - - 2.09 1.32 System Average IESCO 22.60 37.49 34.80 1.66 0.10 Interruption GEPCO 317.10 291.58 263.22 13.14 13.20 Duration LESCO 3469.40 2610.78 4615.74 4759.61 3010.29 Index (SAIDI), FESCO 21241.00 1320.98 1250.66 1137.02 2682.58 Power Supply MEPCO 15896.20 16073.48 12813.89 17704.58 15677.65 HESCO 1035.60 23990.80 21204.64 16678.66 10642.74 Interruptions SEPCO - 18233.00 4799.92 2442.73 2141.36 Durations QESCO 13419.80 12810.68 12634.96 11868.07 7506.81 K-EL 2191.70 1857.97 1790.43 1495.25 1330.30 BTPL 50.20 1.60 6.90 0.78 1.43 Source: Distribution Companies / NEPRA

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System Average Interruption Frequency Index Power Supply Interruptions per Consumer per Year

4500 4000 3500 3000

2500 2000 1500 1000

500 0

2010-11 2011-12 2012-13 2013-14 2014-15

System Average Interruption Duration Index Power Supply Interruptions Durations

30000.00

25000.00

20000.00

15000.00

10000.00

5000.00

0.00

2010-11 2011-12 2012-13 2013-14 2014-15

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TABLE 58 Peak Demand of Distribution Companies (MW) DISCO 2010-11 2011-12 2012-13 2013-14 2014-15 PESCO 2787 3271 2946 2746 2798 Peak Demand Growth Rate over Last Year -3.83 17.37 -9.94 -6.79 1.89 TESCO 895 912 824 653 560 Peak Demand Growth Rate over Last Year 13.72 1.90 -9.65 -20.75 -14.24 IESCO 2087 2095 2325 2565 2347 Peak Demand Growth Rate over Last Year 43.24 0.38 10.98 10.32 -8.50 GEPCO 1870 1994 2029 2190 2386 Peak Demand Growth Rate over Last Year 3.14 6.63 1.76 7.93 8.95 LESCO 4006 4062 4787 4588 5021 Peak Demand Growth Rate over Last Year 2.30 1.40 17.85 -4.16 9.44 FESCO 2538 2812 2747 2959 3091 Peak Demand Growth Rate over Last Year 10.44 10.80 -2.31 7.72 4.46 MEPCO 2949 3022 3360 3570 2892 Peak Demand Growth Rate over Last Year -1.90 2.48 11.18 6.25 -18.99 HESCO 1997 1166 1055 1216 1167 Peak Demand Growth Rate over Last Year 11.13 -41.61 -9.52 15.26 -4.03 SEPCO - 1183 1280 1288 1357 Peak Demand Growth Rate over Last Year - - 8.20 0.63 5.36 QESCO 1430 1480 1530 1650 1762 Peak Demand Growth Rate over Last Year 8.66 3.50 3.38 7.84 6.79 K-Electric Limited 2591 2596 2778 2929 3056 Peak Demand Growth Rate over Last Year 1.13 0.19 7.01 5.44 4.34 Source: Distribution Companies / KEL

TABLE 59 Category-wise Number of Consumers

As on 30th Public June Domestic Commercial Industrial Agricultural Lighting Bulk Supply Others Total DISCO 2011 2281849 264582 23460 26911 843 873 46 2598564 2012 2361837 271688 28156 23190 972 875 46 2686764 2013 2447438 279479 28965 23228 1013 877 46 2781046

PESCO 2014 2523470 289155 29760 23441 1028 878 46 2867778 2015 2602181 298739 30344 23328 1040 888 47 2956567 2011 399342 28115 4119 8388 0 54 0 440018 2012 399395 28123 4050 8477 0 55 0 440100 2013 400598 28132 4035 8548 0 55 0 441368

TESCO 2014 400600 28202 4081 8548 0 55 0 441486 2015 400613 28217 4101 8576 0 55 0 441562 2011 1809525 308524 12797 7466 1470 815 131 2140728 2012 1882619 318705 13337 7729 1506 831 138 2224865 2013 1952892 329166 13967 7933 1607 842 144 2306551 IESCO 2014 2013135 340925 14534 8052 1659 957 40 2379302 2015 2085256 350989 15048 8192 1674 968 40 2462167 Continued.....

169 State of Industry Report 2015

As on 30th Public June Domestic Commercial Industrial Agricultural Lighting Bulk Supply Others Total DISCO 2011 2181694 279974 52516 35415 459 131 14 2550203 2012 2258940 287249 54767 37277 477 135 15 2638860 2013 2341686 294733 56838 40645 496 139 15 2734552

GEPCO 2014 2419346 304496 57965 41583 507 141 15 2824053 2015 2506136 313573 60542 42563 514 149 16 2923493 2011 2702503 488264 67895 52025 1853 482 211 3313233 2012 2808748 498334 70341 53750 1909 488 211 3433781 2013 2936951 510604 72699 56140 2076 489 219 3579178

LESCO 2014 3052697 524702 75006 57313 2154 491 223 3712586 2015 3228511 542738 77277 58382 2227 490 237 3909862 2011 2611050 308637 40591 34581 1380 196 101 2996536 2012 2712234 316577 42099 36692 1410 204 103 3109319 2013 2806555 324089 43836 38048 1432 209 104 3214273

FESCO 2014 2870418 332675 45120 38921 1470 215 111 3288930 2015 3012756 344642 46602 39522 1500 218 117 3445357 2011 3707866 403769 45020 67958 1266 401 108 4226388 2012 3888629 416928 46210 70438 1299 407 110 4424021 2013 4116231 433736 48190 74077 1338 411 112 4674095

MEPCO 2014 4278223 455088 49599 75484 1365 420 117 4860296 2015 4508987 476683 51135 77317 1402 428 120 5116072 2011 1243587 246182 23415 26723 876 784 89 1541656 2012 718422 138047 12960 15175 490 310 89 885493 2013 745501 140191 13407 15718 314 494 90 915715

HESCO 2014 777599 143685 13834 16198 322 533 92 952263 2015 798206 146831 14311 16578 332 533 97 976888 2012 552110 111196 11152 12169 393 479 58 687557 2013 561212 112391 11489 12295 409 488 18 698302 2014 572945 114072 11846 12408 410 497 18 712196 SEPCO 2015 581305 115574 12094 12484 412 504 19 722392 2011 384136 93177 3254 21136 239 210 4 502156 2012 394843 95830 3321 21390 240 220 4 515848 2013 403848 98291 3423 24483 242 229 4 530520

QESCO 2014 414231 102089 3549 28630 243 234 4 548980 2015 423876 105721 3662 31139 247 238 4 564887 2011 1632604 452667 20595 2233 57 1464 3 2109623 2012 1659766 456537 20537 2536 67 423 3 2139869 2013 1660768 452329 20462 2616 66 367 1 2136609 Limited

K-Electric 2014 1650034 438150 20464 2410 74 202 2 2111336 2015 1695782 439130 20613 2488 77 198 2 2158290 2011 17321552 2421224 273067 280603 8386 3946 704 20309482 2012 17977777 2482677 286393 286287 8696 4004 774 21046608 2013 18712912 2550812 296849 301115 8927 4233 752 21875600

System 2014 19322664 2635089 305294 310578 9158 4421 666 22587870

Total in PEPCO in PEPCO Total 2015 20147827 2723707 315116 318081 9348 4471 697 23519247 Source: Distribution Companies / KEL

170 State of Industry Report 2015

TABLE 60 Category-wise Sanctioned Load (MW) As on 30th Domestic Commercial Industrial Agricultural Public Lighting Bulk Supply Others Total

DISCO June 2011 2808 562 1013 247 60 227 4 4921 2012 2968 582 1162 168 61 227 4 5172 2013 3119 601 1209 169 59 228 4 5389

PESCO 2014 3271 630 1278 170 59 230 4 5642 2015 3427 659 1328 170 55 244 4 5887 2011 751 34 820 890 0 4 0 2499 2012 752 34 800 920 0 4 0 2510 2013 754 34 810 920 0 4 0 2522

TESCO 2014 754 35 860 920 0 4 0 2573 2015 754 35 960 930 0 4 0 2683 2011 3162 843 846 76 98 427 261 5713 2012 3298 922 875 80 99 432 269 5975 2013 3452 960 912 84 99 459 283 6248

IESCO 2014 3575 1005 942 86 99 469 289 6466 2015 3723 1043 970 89 99 483 290 6698 2011 2959 551 1270 255 34 65 1 5135 2012 3096 570 1327 266 34 67 1 5361 2013 3237 590 1390 286 34 67 1 5605

GEPCO 2014 3380 616 1446 291 34 70 1 5838 2015 3543 647 1528 297 34 89 1 6139 2011 4011 1269 3207 534 108 174 40 9343 2012 4183 1313 3385 549 109 177 38 9754 2013 4399 1367 3547 572 112 178 40 10215

LESCO 2014 4606 1420 3767 584 113 176 40 10706 2015 4912 1482 3915 596 112 179 42 11238 2011 6287 645 1442 390 10 122 6 8902 2012 6529 671 1533 421 10 134 6 9304 2013 6758 699 1681 433 10 137 6 9724

FESCO 2014 6923 730 1774 445 11 150 6 10039 2015 7290 768 1901 451 11 187 7 10615 2011 5008 747 1819 1026 14 79 22 8715 2012 5288 785 1893 1074 15 82 23 9160 2013 5646 828 2008 1142 15 87 23 9748

MEPCO 2014 5916 878 2118 1168 15 99 23 10219 2015 6292 917 2194 1195 15 105 24 10743 2011 1543 410 896 360 35 82 12 3338 2012 965 245 623 209 25 35 8 2110 2013 998 251 695 216 36 25 8 2228

HESCO 2014 1037 260 737 226 44 26 8 2337 2015 1065 269 777 229 45 26 8 2420 2012 610 176 327 160 12 50 2 1337 2013 610 176 327 160 12 50 2 1337 2014 638 185 357 176 12 52 2 1422 SEPCO 2015 655 192 363 179 12 52 2 1455 2011 578 154 136 562 5 47 0 1482 2012 591 158 139 569 5 49 0 1511 2013 605 163 144 662 5 50 0 1629

QESCO 2014 618 168 151 789 5 52 0 1783 2015 630 174 158 864 5 52 0 1885 2011 2744 872 1620 30 0 525 0 5791 2012 2922 1082 1691 32 1 234 0 5962 2013 3393 1481 1968 82 7 270 0 7201

Limited 2014 3741 1504 1544 37 1 123 0 6950 K-Electric 2015 4008 1579 1674 40 1 135 0 7437 2011 27107 5215 11449 4340 364 1227 346 50048 2012 28280 5456 12065 4416 371 1256 350 52194 2013 29577 5669 12722 4644 382 1284 367 54646 PEPCO PEPCO System Total in Total 2014 30718 5928 13430 4854 392 1328 374 57024 2015 32292 6187 14094 5000 389 1422 378 59763 Source: Distribution Companies / KEL

171 State of Industry Report 2015

TABLE 61 Category-wise Electricity Sold (GWh)

Public Bulk Year Domestic Commercial Industrial Agricultural Lighting Supply Others Total DISCO 2010-11 4041 527 1562 291 21 533 2 6976 2011-12 4048 553 1777 142 21 518 2 7062 2012-13 4048 550 1889 111 20 541 2 7162

PESCO 2013-14 4205 622 1989 100 14 539 3 7471 2014-15 4297 654 2020 93 14 520 2 7599 2010-11 1536 15 91 84 0 9 0 1735 2011-12 1295 14 78 72 0 7 0 1466 2012-13 1185 9 42 52 0 6 0 1294

TESCO 2013-14 1225 10 63 59 0 7 0 1364 2014-15 973 6 63 52 0 7 0 1101 2010-11 3367 896 1561 90 93 636 1031 7674 2011-12 3294 869 1640 86 76 663 909 7537 2012-13 3410 862 1656 87 76 1668 4 7763

IESCO 2013-14 3681 894 1644 93 78 1798 4 8192 2014-15 3704 844 1671 93 76 1755 4 8147 2010-11 3632 429 1783 319 8 268 1 6439 2011-12 3444 396 1741 328 6 261 1 6178 2012-13 3281 361 1704 301 6 267 1 5920

GEPCO 2013-14 3860 399 1966 304 6 292 1 6828 2014-15 3987 405 2077 285 6 293 1 7055 2010-11 5900 1225 6036 1062 96 416 5 14741 2011-12 5657 1165 6120 1008 98 415 5 14467 2012-13 5566 1115 6062 1009 101 427 5 14285

LESCO 2013-14 6278 1215 6773 1127 103 446 7 15948 2014-15 6550 1235 6888 1084 94 469 8 16328 2010-11 3923 499 3079 848 7 236 6 8596 2011-12 3790 468 3181 857 7 274 4 8580 2012-13 3787 455 3333 717 7 284 4 8586

FESCO 2013-14 4256 483 3804 831 7 296 4 9682 2014-15 4426 492 3972 788 7 317 4 10006 2010-11 4982 612 2302 2105 24 159 6 10189 2011-12 4817 605 2559 1885 19 158 6 10049 2012-13 4939 579 2628 1588 16 156 7 9913

MEPCO 2013-14 5518 640 2991 2090 17 173 8 11437 2014-15 6014 657 3071 1745 16 200 8 11711 2010-11 3128 386 1170 783 101 218 27 5814 2011-12 1717 230 773 519 56 83 3 3381 2012-13 1926 237 775 454 82 48 3 3524

HESCO 2013-14 2074 260 770 446 85 47 3 3685 2014-15 2421 271 760 416 105 43 4 4020 2011-12 1630 164 407 254 73 134 5 2666 2012-13 1670 168 417 257 74 139 2 2726 2013-14 1650 168 417 243 78 145 1 2702 SEPCO 2014-15 1621 181 424 242 71 141 2 2682 2010-11 464 94 114 3265 4 107 0 4048 2011-12 513 98 122 3260 8 86 0 4086 2012-13 510 98 136 2974 5 89 0 3812

QESCO 2013-14 575 102 134 2837 2 94 0 3744 2014-15 573 109 140 3068 3 101 0 3994 2010-11 4257 1043 3447 125 82 955 163 10072 2011-12 4564 1128 3342 134 118 806 188 10280 2012-13 5083 1507 3445 149 111 473 174 10942

Limited 2013-14 5489 1507 3568 160 106 427 197 11454 K-Electric 2014-15 6161 1589 3648 166 110 411 208 12293 2010-11 30972 4682 17699 8847 353 2581 1078 66213 2011-12 30203 4562 18399 8410 363 2598 936 65472 2012-13 30321 4434 18641 7550 387 3623 27 64984 PEPCO PEPCO System Total in Total 2013-14 33322 4793 20551 8129 390 3837 31 71053 2014-15 34566 4853 21085 7866 393 3846 33 72643 Source: Distribution Companies / KEL

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TABLE 62 Total Units Purchased, Sold and Losses

Unit Purchased (GWh) Losses Year Unit Sold Through CPPs, SPPs Total Unit (GWh) DISCO Through NTDC etc. Purchased GWh %age 2010-11 10760 486 11246 6976 4270 37.96 2011-12 10980 50 11030 7062 3968 35.98 2012-13 10814 78 10892 7162 3730 34.25

PESCO 2013-14 11250 51 11301 7471 3829 33.89 2014-15 11657 0 11657 7599 4058 34.81 2010-11 2326 0 2326 1735 591 25.41 2011-12 2071 0 2071 1466 605 29.21 2012-13 1643 0 1643 1294 349 21.25

TESCO 2013-14 1758 0 1758 1364 394 22.41 2014-15 1406 0 1406 1101 305 21.68 2010-11 8509 0 8509 7674 835 9.81 2011-12 8330 0 8330 7537 793 9.52 2012-13 8573 0 8573 7763 810 9.45

IESCO 2013-14 9049 0 9049 8192 857 9.47 2014-15 8993 0 8993 8147 846 9.41 2010-11 7316 0 7316 6439 877 11.99 2011-12 6959 0 6959 6178 782 11.23 2012-13 6633 0 6633 5920 713 10.75

GEPCO 2013-14 7671 0 7671 6828 844 11.00 2014-15 7902 0 7902 7055 847 10.72 2010-11 16995 0 16995 14741 2254 13.26 2011-12 16727 0 16727 14467 2260 13.51 2012-13 16458 0 16458 14285 2173 13.21

LESCO 2013-14 18425 0 18425 15948 2477 13.44 2014-15 19009 0 19009 16328 2681 14.10 2010-11 7522 2163 9685 8596 1089 11.24 2011-12 8725 890 9615 8580 1035 10.76 2012-13 7125 2511 9636 8586 1050 10.89

FESCO 2013-14 7811 3099 10910 9682 1228 11.26 2014-15 11246 0 11246 10006 1240 11.03 2010-11 7889 4559 12448 10189 2260 18.15 2011-12 6939 5517 12456 10049 2407 19.32 2012-13 9157 2790 11947 9913 2034 17.02

MEPCO 2013-14 13981 81 14062 11437 2625 18.66 2014-15 13820 39 13859 11711 2148 15.50 2010-11 8699 86 8785 5814 2971 33.82 2011-12 4431 248 4679 3381 1297 27.73 2012-13 3924 926 4850 3524 1326 27.33

HESCO 2013-14 4605 405 5010 3685 1326 26.46 2014-15 4965 547 5512 4020 1492 27.08 2011-12 2996 1403 4398 2666 1732 39.38 2012-13 4325 181 4506 2726 1780 39.51 2013-14 4129 269 4398 2702 1696 38.56 SEPCO 2014-15 4114 231 4346 2682 1664 38.29 2010-11 5093 19 5112 4048 1064 20.81 2011-12 5147 12 5159 4086 1073 20.80 2012-13 4670 11 4681 3812 869 18.57

QESCO 2013-14 4784 12 4796 3744 1052 21.93 2014-15 5194 0 5194 3994 1200 23.10 2010-11 75109 7313 82422 66213 16210 19.67 2011-12 73305 8119 81424 65472 15952 19.59 2012-13 73322 6497 79819 64984 14835 18.59 PEPCO PEPCO System

Total in Total 2013-14 83463 3916 87380 71053 16327 18.68 2014-15 88306 818 89124 72643 16481 18.49 Unit Purchased (GWh) Losses Unit Sold Year Through CPPs Total Unit (GWh) K-EL Own Through NTDC + Others Purchased GWh %age 2010-11 7826 5449 2183 15458 10072 5386 34.84 2011-12 8029 5684 1546 15259 10280 4979 32.63 2012-13 8567 5463 1794 15824 10942 4882 30.85 2013-14 8709 5441 1841 15991 11454 4537 28.37

K-Electric Limited 2014-15 9319 5427 2069 16815 12293 4522 26.89 Source: Distribution Companies / KEL

173 State of Industry Report 2015

TABLE 63 Units Billed and Amount Realized in DISCOs (2014-15) Public Bulk DISCO Unit Domestic Commercial Industrial Agricultural Lighting Supply Others Total * GWh 4297 654 2020 93 14 520 2 7599 ** Rs. Mln. 45579 14559 35593 1477 199 8483 43 105933 Rs. Mln. 36756 14182 35474 1095 195 5394 43 93140 PESCO *** % 80.64 97.41 99.67 74.11 98.08 63.59 100.04 87.92 * GWh 973 6 63 52 0 7 0 1101 ** Rs. Mln. 13980 201 734 655 0 90 0 15660 Rs. Mln. 10106 62 774 447 0 79 0 11468 TESCO *** % 72.29 31.04 105.45 68.21 0.00 0.00 0.00 73.23 * GWh 3704 844 1671 93 76 1755 4 8147 ** Rs. Mln. 39306 17821 25337 1340 1158 24929 67 109958

IESCO Rs. Mln. 39104 17714 25210 1333 1158 15381 67 99967 *** % 99.49 99.40 99.50 99.48 100.00 61.70 100.00 90.91 * GWh 3987 405 2077 285 6 293 1 7055 ** Rs. Mln. 38704 9478 33990 4028 85 4568 19 90872 Rs. Mln. 38580 9493 32988 4284 110 2714 103 88272 GEPCO *** % 99.68 100.16 97.05 106.35 129.11 59.42 539.63 97.14 * GWh 6550 1235 6888 1084 94 469 8 16328 ** Rs. Mln. 77033 27315 99382 12270 1479 7875 127 225481 Rs. Mln. 75073 26964 93738 11015 1433 7792 47 216062 LESCO *** % 97.46 98.72 94.32 89.78 96.87 98.95 37.01 95.82 * GWh 4426 492 3972 788 7 317 4 10006 ** Rs. Mln. 43259 11167 58430 10236 154 4861 74 128180 Rs. Mln. 42812 11083 58163 11049 145 4878 126 128255 FESCO *** % 98.97 99.25 99.54 107.94 94.24 100.34 171.53 100.06 * GWh 6014 657 3071 1745 16 200 8 11711 ** Rs. Mln. 53915 15104 47208 18722 288 3271 139 138646 Rs. Mln. 53276 15093 46654 22666 333 3407 452 141881 MEPCO *** % 98.81 99.92 48.01 1.78 1184.77 13.81 324.64 102.33 * GWh 2421 271 760 416 105 43 4 4020 ** Rs. Mln. 17180 5818 13458 6597 1834 793 34 45714 Rs. Mln. 9556 5553 12657 5792 1443 225 542 35769 HESCO *** % 55.62 95.44 94.05 87.80 78.68 28.39 1612.15 78.24 * GWh 1621 181 424 242 71 141 2 2682 ** Rs. Mln. 18095 4003 7433 3763 1046 2338 28 36706 Rs. Mln. 7012 3861 6038 2413 204 1681 12 21222 SEPCO *** % 38.75 96.46 81.23 64.11 19.54 71.91 43.49 57.81 * GWh 573 109 140 3068 3 101 0 3994 ** Rs. Mln. 7147 2529 2628 51015 63 1783 1 65166 Rs. Mln. 4046 2363 2558 10395 33 1822 1 21217 QESCO *** % 56.60 93.43 97.32 20.38 51.72 102.19 100.00 32.56 * GWh 6161 1589 3648 166 110 411 208 12293 ** Rs. Mln. 66995 38736 67722 2235 1841 7657 2249 187435 Rs. Mln. 60990 36563 61029 340 1284 7130 2050 169386

Limited *** K-Electric % 91.04 94.39 90.12 15.21 69.74 93.12 0.00 90.37 * GWh 34566 4853 21085 7866 393 3846 33 72643 ** Rs. Mln. 354199 107994 324194 110103 6305 58990 532 962317 Rs. Mln. 316320 106368 314254 70488 5054 43373 1394 857251 PEPCO PEPCO System Total in Total *** % 89.31 98.49 96.93 64.02 80.15 73.53 262.08 89.08 * Unit Billed ** Amount of Billed Units *** Amount Realized and %age Recovery to Billed Amount Source: Distribution Companies / KEL

174 State of Industry Report 2015

TABLE 64 Average Annual Electricity Consumption per Connection (kWh)

Public Bulk Year Domestic Commercial Industrial Agricultural Others Total Lighting Supply DISCO 2010-11 1771 1992 66585 10811 24342 610619 50217 2685 2011-12 1714 2035 63117 6138 21883 592091 48913 2628 2012-13 1654 1967 65215 4790 19961 616990 42609 2575

PESCO 2013-14 1666 2150 66825 4284 13687 614157 56522 2605 2014-15 1651 2188 66567 3970 13625 585023 50638 2570 2010-11 3846 525 22081 10052 0 166667 0 3943 2011-12 3242 498 19259 8494 0 127273 0 3331 2012-13 2958 320 10409 6083 0 109091 0 2932

TESCO 2013-14 3058 355 15437 6902 0 127273 0 3090 2014-15 2429 213 15362 6063 0 127273 0 2493 2010-11 1861 2904 121982 12055 63265 780368 7870229 3585 2011-12 1750 2727 122966 11127 50465 797834 6586957 3388 2012-13 1746 2619 118565 10967 47293 1980998 27778 3366

IESCO 2013-14 1828 2622 113114 11550 47016 1878788 100000 3443 2014-15 1776 2405 111045 11353 45400 1813017 100000 3309 2010-11 1665 1532 33952 9012 16383 2042748 72857 2525 2011-12 1525 1377 31794 8793 13480 1934444 72000 2341 2012-13 1401 1224 29982 7401 11571 1918165 63133 2165

GEPCO 2013-14 1595 1310 33910 7314 11781 2073390 65000 2418 2014-15 1591 1291 34305 6705 12257 1967221 70375 2413 2010-11 2183 2509 88908 20412 51749 863921 25355 4449 2011-12 2014 2338 87007 18750 51200 849570 22180 4213 2012-13 1895 2184 83388 17970 48540 872679 23562 3991

LESCO 2013-14 2057 2316 90299 19655 47734 908024 30762 4296 2014-15 2029 2276 89131 18569 42371 957122 32110 4176 2010-11 1502 1615 75853 24521 4804 1203827 55050 2869 2011-12 1397 1479 75555 23348 4645 1342941 43204 2760 2012-13 1349 1405 76029 18857 4756 1356746 34327 2671

FESCO 2013-14 1483 1451 84311 21340 5020 1378837 37207 2944 2014-15 1469 1428 85228 19933 4960 1452110 37265 2904 2010-11 1344 1515 51136 30968 18973 395312 57037 2411 2011-12 1239 1450 55382 26757 14296 389066 56727 2271 2012-13 1200 1335 54544 21433 12123 378832 60536 2121

MEPCO 2013-14 1290 1407 60295 27688 12637 411024 71538 2353 2014-15 1334 1379 60048 22572 11526 467804 68333 2289 2010-11 2516 1569 49983 29316 115651 277717 301124 3771 2011-12 2390 1666 59658 34217 113776 267161 37079 3818 2012-13 2583 1693 57785 28876 261656 96235 33222 3849

HESCO 2013-14 2667 1812 55672 27527 262516 87298 35217 3869 2014-15 3033 1842 53123 25108 316627 80244 37216 4115 2011-12 2952 1476 36518 20845 185929 278977 87759 3878 2012-13 2975 1492 36256 20909 181760 284488 95556 3904 2013-14 2880 1474 35241 19580 189390 290885 65556 3794 SEPCO 2014-15 2788 1564 35074 19385 171966 280635 87895 3712 2010-11 1208 1005 35120 154468 16653 510286 12500 8061 2011-12 1298 1027 36829 152384 31250 389773 12500 7921 2012-13 1264 992 39623 121486 19959 387991 12500 7185

QESCO 2013-14 1389 996 37825 99092 9177 401496 10000 6821 2014-15 1352 1030 38230 98518 11781 424370 15000 7070 2010-11 2607 2304 167371 55979 1438596 652322 54333333 4774 2011-12 2750 2471 162731 52839 1761194 1905437 62666667 4804 2012-13 3061 3332 168361 56957 1681818 1288828 174000000 5121

Limited 2013-14 3327 3439 174355 66390 1432432 2113861 98500000 5425 K-Electric 2014-15 3633 3619 176976 66720 1428571 2075758 104000000 5696 2010-11 1788 1934 64816 31529 42078 654192 1531605 3260 2011-12 1680 1838 64245 29375 41730 648934 1209483 3111 2012-13 1620 1738 62798 25075 43362 855881 36140 2971 PEPCO PEPCO System

Total in Total 2013-14 1725 1819 67315 26175 42575 867801 47140 3146 2014-15 1716 1782 66913 24730 42074 860120 47369 3089 Source: Distribution Companies / KEL

175 State of Industry Report 2015

TABLE 65 Distribution Losses (voltage category-wise) 2010-11 2011-12 2012-13 2013-14 2014-15 DISCO Losses of GWh % GWh % GWh % GWh % GWh % * 627.90 5.60 600.10 5.40 391.90 3.60 379.50 3.40 379.50 3.30 PESCO ** 3514.30 33.50 3368.24 32.30 3338.60 31.80 3450.10 31.60 3681.10 32.60 *** 4269.51 37.96 3968.49 35.98 3730.35 34.25 3829.47 33.89 4058.39 34.81 * 224.93 2.94 196.03 2.92 52.03 2.86 98.48 5.60 90.06 4.63 TESCO ** 239.19 21.10 474.56 24.50 313.45 19.50 305.65 18.30 230.20 17.30 *** 590.96 25.41 604.78 29.21 349.15 21.25 393.98 22.41 304.80 21.68 * 170.00 2.00 147.00 1.80 151.00 1.80 151.00 1.67 177.00 1.96 IESCO ** 659.00 7.90 644.79 7.90 657.00 7.80 705.00 7.93 669.00 7.54 *** 835.00 9.81 793.00 9.52 810.00 9.45 857.00 9.47 846.00 9.41 * 135.22 1.85 114.00 1.64 103.00 1.55 141.00 1.84 127.00 1.61 GEPCO ** 740.56 10.31 667.33 9.75 610.00 9.35 703.00 9.33 720.00 9.25 *** 877.00 11.99 781.56 11.23 713.18 10.75 843.84 11.00 846.99 10.72 * 30.70 0.20 178.00 0.80 102.80 0.60 145.90 0.80 273.80 1.14 LESCO ** 2223.47 13.10 2117.85 12.80 2070.60 12.70 2330.80 12.80 2407.10 12.80 *** 2254.15 13.26 2260.40 13.51 2173.33 13.21 2476.69 13.44 2680.64 14.10 * 157.92 1.60 107.84 1.10 137.00 1.30 211.87 1.90 n.p. n.p. FESCO ** 931.07 9.80 928.39 9.80 912.46 9.60 1016.30 9.50 n.p. n.p. *** 1088.63 11.24 1034.59 10.76 1049.76 10.89 1228.29 11.26 1240.13 11.03 * 479.76 3.80 465.43 3.65 309.08 2.62 483.76 3.50 417.14 3.00 MEPCO ** 1802.43 15.00 1769.01 14.76 1724.84 14.82 1937.94 14.50 1933.38 14.20 *** 2259.72 18.15 2406.82 19.32 2033.93 17.02 2624.52 18.66 2147.70 15.50 * 360.74 4.13 180.37 3.90 171.87 3.50 163.03 3.30 244.83 4.40 HESCO ** 2572.06 30.70 1116.96 24.80 1153.82 24.70 1162.06 24.00 1247.29 23.70 *** 2970.78 33.82 1297.38 27.73 1325.71 27.33 1325.50 26.46 1492.44 27.08 * - - 193.35 4.24 179.79 3.99 125.07 2.84 113.82 2.62 SEPCO ** - - 1513.24 35.29 1548.69 36.23 1507.07 35.81 1481.54 35.59 *** - - 1732.02 39.38 1780.39 39.51 1695.85 38.56 1664.08 38.29 * 368.77 7.25 335.11 6.50 248.62 5.00 160.48 3.24 75.80 1.40 QESCO ** 666.64 14.10 737.48 15.30 869.13 18.60 1051.51 21.90 1215.20 23.30 *** 1063.90 20.81 1072.99 20.80 869.31 18.57 1051.52 21.93 1199.70 23.10 * - - - 1.53 189.00 1.25 200.00 1.31 226.00 1.40 K-Electric ** - - - 28.60 4028.00 26.90 3678.00 24.30 3590.00 22.60 Limited *** 5386.41 34.84 4978.71 32.63 4882.00 30.85 4537.00 28.37 4522.00 26.89 *132 kV system (including 66 & 33 kV) ** 11 kV and below system ***Overall system Source: Distribution Companies / KEL

176 State of Industry Report 2015

Figure 65: Distribution Losses (%) (2014-15) 40.00 35.00 30.00 25.00 20.00 15.00 10.00 5.00 0.00 PPESCOESCO TESCO IIESCOESCO GEPCO LLESCOESCO FESCO M MEPCOEPCO HESCOS ESEPCOPCO QESCOK-E K-Electriclectric 132 kV system 11 kV and below system Overall system (including 66 & 33 kV)

TABLE 66 Status of Distribution Lines (km)

th Total LT DISCO As on 30 132 kV 66 kV 33 kV 11 kV Total HT Lines June Lines (0.4 kV) 2011 1960 860 311 31698 34829 42932 2012 2033 861 311 32432 35637 43316 PESCO 2013 2080 861 311 33006 36258 43560 2014 2147 841 171 33337 36496 43801 2015 2164 841 171 33337 36513 43957 2011 259 383 805 7347 8794 6378 2012 259 383 805 7347 8794 6378 TESCO 2013 259 383 805 7363 8810 6380 2014 259 383 805 7363 8810 6380 2015 259 383 805 7367 8814 6380 2011 2480 581 153 22547 25761 25164 2012 2605 581 153 23012 26351 25477 IESCO 2013 2702 581 153 23409 26845 25800 2014 2717 581 153 23596 27047 26009 2015 2772 581 153 24272 27778 26145 2011 1969 509 0 20096 22574 16997 2012 1969 509 0 20990 23468 17380 GEPCO 2013 1897 416 0 21971 24284 17955 2014 2054 332 0 22216 24602 18087 2015 2233 447 0 22402 25082 18087 2011 0 0 0 25522 25522 14487 2012 0 0 0 25918 25918 14568 LESCO 2013 2519 0 0 26297 28816 14647 2014 2572 0 0 26657 29229 14730 2015 2252 429 0 26657 29338 14808 2011 1588 1298 0 36204 39090 24217 2012 1658 1296 0 36900 39854 24880 FESCO 2013 1705 1292 0 37644 40641 25429 2014 1844 1260 0 38093 41197 25770 2015 1865 1260 0 38614 41739 25900 2011 2923 1314 0 66223 70460 44592 2012 2937 1314 0 67221 71472 45121 MEPCO 2013 2987 1266 0 68647 72900 45970 2014 3169 1154 0 69453 73776 46251 2015 3286 1154 0 71101 75541 46866 Continued.....

177 State of Industry Report 2015

th Total LT DISCO As on 30 132 kV 66 kV 33 kV 11 kV Total HT Lines June Lines (0.4 kV) 2011 3876 1725 0 48059 53660 26442 2012 1900 969 0 25414 28283 13745 HESCO 2013 1939 975 0 26196 29110 14132 2014 2067 975 0 26612 29654 14392 2015 2133 975 0 26913 30021 14687 2012 1976 756 0 23098 25830 12991 2013 1887 753 0 23814 26454 13272 SEPCO 2014 1900 753 0 24277 26930 13471 2015 1995 753 0 24277 27025 13471 2011 3054 636 985 29503 34178 12749 2012 3985 636 985 31139 36745 13629 QESCO 2013 4299 491 985 32153 37928 14042 2014 4299 491 985 33425 39200 14373 2015 4299 491 985 33425 39200 14654 2011 761 149 0 n.p. n.p. n.p. 2012 761 149 0 n.p. n.p. n.p. K-Electric 2013 761 149 0 8071 8981 n.p. Limited 2014 761 149 0 8335 9245 17645 2015 761 149 0 8834 9744 n.p. 2011 18109 7306 2254 287199 314868 213958 Total in 2012 19322 7305 2254 293471 322352 217485 PEPCO 2013 22274 7018 2254 300500 332046 221187 System 2014 23028 6770 2114 305029 336941 223264 2015 23258 7314 2114 308365 341051 224955 Source: Distribution Companies / KEL TABLE 67 Feeders Outages Statistics of DISCOs (2014-15)

132 kV Feeders 66 kV Feeders 33 kV Feeders 11 kV Feeders All Feeders Nature of Tripping No. of Duration No. of Duration No. of Duration No. of Duration No. of Duration DISCO Tripping (Min.) Tripping (Min.) Tripping (Min.) Tripping (Min.) Tripping (Min.) Planned 1282 136708 414 20926 3 910 165354 7417268 167053 7575812 Forced 285 68070 142 32397 37 1438 36436 2793641 36900 2895546

PESCO Total 1567 204778 556 53323 40 2348 201790 10210909 203953 10471358 Planned 33 3805 3900 3410 31 2380 2922 28850 6886 38445 Forced 32 2425 35 2845 27 2690 745 24870 839 32830

TESCO Total 65 6230 3935 6255 58 5070 3667 53720 7725 71275 Planned 72 27560 12 1420 21 1016 742160 44529600 742265 44559596 Forced 240 21600 111 9990 241 21690 12782 1046079 13374 1099359 IESCO Total 312 49160 123 11410 262 22706 754942 45575679 755639 45658955 Planned 10 3420 3 720 0 0 1458 207440 1471 207453 Forced 3350 545889 258 17892 0 0 7492 200855 11100 764636

GEPCO Total 3360 545899 3678 17895 720 0 8950 408295 12571 972089 Planned 251 105926 10 3120 0 0 14526 4183920 14787 4292966 Forced 4824 321366 899 72696 0 0 20913 673260 26636 1067322 LESCO Total 5075 427292 909 75816 0 0 35439 4857180 41423 5360288 Planned 239 59204 100 24637 0 0 4007 624800 4346 708641 Forced 95 12422 70 5518 0 0 53312 670197 53477 688137

FESCO Total 334 71626 170 30155 0 0 57319 1294997 57823 1396778 Planned 838 238233 132 77659 0 0 3000 584167 3970 900059 Forced 2034 660760 2472 878057 0 0 138635 1179900 143141 2718717

MEPCO Total 2872 898993 2604 955716 0 0 141635 1764067 147111 3618776 Continued.....

178 State of Industry Report 2015

132 kV Feeders 66 kV Feeders 33 kV Feeders 11 kV Feeders All Feeders Nature of Tripping No. of Duration No. of Duration No. of Duration No. of Duration No. of Duration DISCO Tripping (Min.) Tripping (Min.) Tripping (Min.) Tripping (Min.) Tripping (Min.)

Planned 79 26278 19 5470 0 0 298 72960 396 104708

Forced 516 84995 72 22381 0 0 34040 37440 34628 144816 HESCO Total 595 111273 91 27851 0 0 34338 110400 35024 249524

Planned 230 103501 46 3443 0 0 45091 134795 45367 241739

Forced 163 38951 122 4098 0 0 33234 668776 33519 711825 SEPCO Total 393 142452 168 7541 0 0 78325 803571 78886 953564

Planned 299 64848 299 64848

Forced 0 0 QESCO Total 299 64848 0 0 0 0 0 0 299 64848

Planned 12 3662 0 0 12 3662

Forced 39 5190 0 0 39 5190 Limited K-Electric Total 51 8852 0 0 0 0 0 0 51 8852 Source: Distribution Companies / KEL TABLE 68 Overloaded and Underutilized Distribution Feeders Number of Overloaded Feeders Number of Underutilized Feeders DISCO Year (Above Designed Capacity) (10% Below Designed Capacity) 132 kV 66 kV 33 kV 11 kV 132 kV 66 kV 33 kV 11 kV 2010-11 15 1 1 74 20 4 0 109 2011-12 12 0 0 66 23 3 1 110 2012-13 17 0 0 71 19 2 2 121

PESCO 2013-14 20 0 0 16 15 0 1 72 2014-15 3 1 1 59 6 0 0 59 2010-11 0 0 0 0 0 0 1 3 2011-12 1 2 0 0 3 2 0 73 2012-13 2 2 0 0 2 2 0 72

TESCO 2013-14 2 2 0 0 0 2 0 72 2014-15 2 2 0 0 2 1 0 28 2010-11 11 0 0 23 0 0 0 206 2011-12 11 0 0 30 4 0 0 219 2012-13 11 0 0 35 5 0 0 62 IESCO 2013-14 0 0 0 36 5 0 0 68 2014-15 1 0 0 12 5 0 0 60 2010-11 3 0 0 2 5 0 0 59 2011-12 9 0 0 4 2 0 0 8 2012-13 3 0 0 58 6 1 0 562

GEPCO 2013-14 5 0 0 45 9 1 0 589 2014-15 2 0 0 2 3 0 0 81 Continued.....

179 State of Industry Report 2015

Number of Overloaded Feeders Number of Underutilized Feeders DISCO Year (Above Designed Capacity) (10% Below Designed Capacity) 132 kV 66 kV 33 kV 11 kV 132 kV 66 kV 33 kV 11 kV 2010-11 0 0 0 16 0 0 0 90 2011-12 0 0 0 0 0 0 0 128 2012-13 75 0 0 67 2 0 0 258

LESCO 2013-14 80 0 0 0 19 0 0 0 2014-15 n.p. n.p. n.p. n.p. n.p. n.p. n.p. n.p. 2010-11 2 0 0 117 3 0 0 362 2011-12 0 0 0 126 3 0 0 142 2012-13 3 0 0 142 4 0 0 396

FESCO 2013-14 2 0 0 248 6 0 0 107 2014-15 1 0 0 0 12 0 0 0 2010-11 6 0 0 0 33 10 0 57 2011-12 9 0 0 123 32 10 0 52 2012-13 10 0 0 130 30 7 0 152

MEPCO 2013-14 8 1 0 237 28 6 0 571 2014-15 5 1 0 436 15 0 0 420 2010-11 2 2 0 0 10 2 0 0 2011-12 0 0 0 0 6 1 0 0 2012-13 1 0 0 0 5 0 0 0

HESCO 2013-14 5 0 0 14 8 1 0 51 2014-15 4 0 0 24 10 0 0 47 2011-12 10 1 0 87 2 1 0 23 2012-13 3 1 0 98 7 1 0 31 2013-14 4 2 0 84 5 0 0 52 SEPCO 2014-15 4 1 0 125 4 0 0 21 2010-11 0 0 0 0 0 0 0 8 2011-12 0 0 0 0 0 0 0 8 2012-13 0 0 0 0 0 0 0 8

QESCO 2013-14 0 0 0 0 4 0 0 13 2014-15 0 0 0 0 2 0 0 17 2010-11 n.p. n.p. n.p. n.p. n.p. n.p. n.p. n.p. 2011-12 n.p. n.p. n.p. n.p. n.p. n.p. n.p. n.p. 2012-13 n.p. n.p. n.p. n.p. n.p. n.p. n.p. n.p.

Limited 2013-14 n.p. n.p. n.p. n.p. n.p. n.p. n.p. n.p. K-Electric 2014-15 n.p. n.p. n.p. 25 n.p. n.p. n.p. 69 Source: Distribution Companies / KEL

180 State of Industry Report 2015

TABLE 69 Number of Circles, Divisions, Sub-Divisions and Feeders As on 30th 11 kV DISCO Circles Divisions Sub-Divisions June Feeders 2012 6 32 145 720 2013 6 33 147 754 PESCO 2014 6 33 147 789 2015 6 34 149 841 2012 1 6 18 158 2013 1 6 18 158 TESCO 2014 1 6 18 173 2015 1 6 18 188 2012 5 19 101 836 2013 5 19 105 886 IESCO 2014 5 19 105 966 2015 5 19 108 965 2012 4 23 114 692 2013 4 23 115 705 GEPCO 2014 4 23 115 725 2015 5 24 115 745 2012 7 33 163 1258 2013 7 33 164 1341 LESCO 2014 7 33 164 1437 2015 7 33 164 1540 2012 4 21 118 813 2013 4 21 118 850 FESCO 2014 4 21 118 900 2015 4 24 130 937 2012 8 35 152 925 2013 8 35 154 972 MEPCO 2014 8 35 160 1039 2015 8 35 160 1104 2012 3 14 62 412 2013 3 14 62 442 HESCO 2014 3 14 62 410* 2015 4 15 67 421 2012 3 13 55 378 2013 3 13 55 398 SEPCO 2014 3 13 55 413 2015 3 16 60 433 2012 3 11 41 528 2013 4 12 43 551 QESCO 2014 4 13 44 550 2015 4 14 46 570 2012 44 207 969 6720 Total in 2013 45 209 981 7057 PEPCO System 2014 45 210 988 7402 2015 47 220 1017 7744 As on 30th IBCs VIBCs Feeders June 2012 8 20 1307 K-Electric 2013 17 11 1321 Limited 2014 28 0 1375 2015 28 0 1431 * 32 feeders dismantled due to flood and cyclonic effects. Source: Distribution Companies / KEL

181 State of Industry Report 2015

TABLE 70 Status of Grid Stations (Nos.) As on 132 kV 66 kV 33 kV 30th DISCO Cons. Sub- DISCO Cons. Sub- DISCO Cons. Sub- Total

DISCO June Owned Owned Total Owned Owned Total Owned Owned Total 2011 62 9 71 19 0 19 5 0 5 95 2012 64 9 73 18 0 18 4 0 4 95 2013 65 9 74 17 0 17 4 0 4 95

PESCO 2014 67 9 76 17 0 17 4 0 4 97 2015 67 9 76 17 0 17 4 0 4 97 2011 7 0 7 8 1 9 0 0 0 16 2012 7 0 7 8 0 8 0 0 0 15 2013 7 0 7 8 0 8 0 0 0 15

TESCO 2014 7 0 7 8 0 8 0 0 0 15 2015 7 0 7 8 0 8 0 0 0 15 2011 58 20 78 10 1 11 5 0 5 94 2012 62 20 82 9 1 10 5 0 5 97 2013 66 20 86 7 1 8 5 0 5 99

IESCO 2014 73 20 93 7 1 8 3 0 3 104 2015 78 22 100 4 1 5 3 0 3 108 2011 41 0 41 8 0 8 0 0 0 49 2012 41 0 41 8 0 8 0 0 0 49 2013 41 0 41 8 0 8 0 0 0 49

GEPCO 2014 50 0 50 5 0 5 0 0 0 55 2015 52 0 52 4 0 4 0 0 0 56 2011 81 26 107 8 0 8 0 0 0 115 2012 82 25 107 8 0 8 0 0 0 115 2013 90 26 116 0 0 0 0 0 0 116

LESCO 2014 85 31 116 8 0 8 0 0 0 124 2015 89 34 123 7 0 7 0 0 0 130 2011 55 15 70 26 0 26 0 0 0 96 2012 55 15 70 26 0 26 0 0 0 96 2013 58 16 74 24 0 24 0 0 0 98

FESCO 2014 60 16 76 23 0 23 0 0 0 99 2015 62 18 80 23 0 23 0 0 0 103 2011 78 7 85 27 0 27 0 0 0 112 2012 82 7 89 26 0 26 0 0 0 115 2013 88 8 96 24 0 24 0 0 0 120

MEPCO 2014 92 8 100 22 0 22 0 0 0 122 2015 96 8 104 21 0 21 0 0 0 125 2011 89 6 95 34 1 35 0 0 0 130 2012 47 4 51 22 0 22 0 0 0 73 2013 48 5 53 22 0 22 0 0 0 75

HESCO 2014 52 6 58 19 0 19 0 0 0 77 2015 53 6 59 18 0 18 0 0 0 77 2012 43 0 43 13 0 13 0 0 0 56 2013 46 1 47 13 1 14 0 0 0 61 2014 47 1 48 12 1 13 0 0 0 61 SEPCO 2015 51 1 52 12 1 13 0 0 0 65 2011 52 0 52 10 0 10 26 0 26 88 2012 55 0 55 10 0 10 26 0 26 91 2013 56 0 56 10 0 10 26 0 26 92

QESCO 2014 56 0 56 10 0 10 26 0 26 92 2015 58 0 58 10 0 10 25 0 25 93 2011 50 5 55 3 0 3 0 0 0 58 2012 51 8 59 3 0 3 0 0 0 62 2013 52 9 61 3 0 3 0 0 0 64

Limited 2014 53 9 62 3 0 3 0 0 0 65 K-Electric 2015 54 9 63 3 0 3 0 0 0 66 2011 523 83 606 150 3 153 36 0 36 795 2012 538 80 618 148 1 149 35 0 35 802 2013 565 85 650 133 2 135 35 0 35 820 PEPCO PEPCO System Total in Total 2014 589 91 680 131 2 133 33 0 33 846 2015 613 98 711 124 2 126 32 0 32 869 Source: Distribution Companies / KEL

182 State of Industry Report 2015 - 42 72 70 67 71 78 18 735 129 115 115 Total 8 0 0 0 0 0 0 4 4

0 33 kV 0 9 6 2

99 14 22 20 10 16 66 kV 8

Transformers (above 80%) (above Transformers Power Over-Loaded No. of 42 63 56 61 95 78 65 95 628 107 132 kV - 528.30 Total 4,720.50 2,706.10 2,194.50 2,092.00 6,108.59 4,406.45 3,800.30 4,182.60 4,866.90 30,885.74

56 0.00 0.00 0.00 0.00 0.00 0.00 0.00 30.00 25.50 33 kV

1,948 69.00 109.50 237.40 224.10 383.34 422.45 104.30 184.00 282.50 66 kV Power of Capacity Transformers (MVA) Transformers

28,883 344.30 4,651.50 2,596.60 1,957.10 1,867.90 5,725.25 3,984.00 3,800.30 4,048.30 4,558.90 132 kV TABLE 71 TABLE - 34 129 132 114 114 256 185 149 185 212 1,381 Total 0 0 0 0 0 0 7 0 7

14 33 kV 3

14 24 23 36 39 10 17 29 192 Power No. of Transformers 66 kV

90 91 17 126 118 220 146 149 168 176 1,175 132 kV DISCO’s Power Transformers, Capacities and Loading Positions of Power Transformers Power of Positions and Loading Capacities Transformers, Power DISCO’s Year 2014-15 2014-15 2014-15 2014-15 2014-15 2014-15 2014-15 2014-15 2014-15 2014-15 2014-15 2014-15 IESCO LESCO FESCO DISCO TESCO SEPCO PESCO PEPCO PEPCO QESCO HESCO GEPCO System MEPCO Total in Total Limited K-Electric Source: Distribution Companies / KEL Distribution Source:

183 State of Industry Report 2015

TABLE 72 DISCO’s Number of 11 kV Feeders and Loading Positions of 11 kV Feeders No. of 11 kV Loading Position of 11 kV Feeders (Nos.) DISCO Year Feeders Above 80% Above 90% Above 100% PESCO 2014-15 841 103 146 194 TESCO 2014-15 188 41 42 - IESCO 2014-15 965 63 40 12 GEPCO 2014-15 745 206 116 36 LESCO 2014-15 1,540 124 187 62 FESCO 2014-15 937 110 59 23 MEPCO 2014-15 1,104 114 304 9 HESCO 2014-15 421 15 47 24 SEPCO 2014-15 433 40 45 100 QESCO 2014-15 570 23 17 45 K-Electric 2014-15 1,431 156 69 40 Limited Total in PEPCO 2014-15 7,744 839 1,003 505 System Source: Distribution Companies / KEL

TABLE 73 DISCO’s Number of Distribution Transformers, Capacities and Loading Positions of Distribution Transformers Capacity of Loading Position of Distribution No. of Distribution Transformers (Nos.) DISCO Year Distribution Transformers Above Transformers Above 80% Above 90% (kVA) 100% PESCO 2014-15 58,458 4,461,200 TESCO 2014-15 15,634 1,200,000 IESCO 2014-15 44,811 3,707,000 1,441 958 34 GEPCO 2014-15 58,193 3,587,000 2,597 2,308 1,731 LESCO 2014-15 96,268 7,501,615 19,254 9,627 9,627 FESCO 2014-15 93,292 5,655,690 2,241 847 399 MEPCO 2014-15 149,368 7,392,855 3,965 1,652 991 HESCO 2014-15 34,443 1,687,795 3,986 2,029 1,207 SEPCO 2014-15 35,818 1,899,210 8,872 3,922 1,979 QESCO 2014-15 51,886 2,571,468 4,125 2,350 1,807 K-Electric Limited 2014-15 20,979 6,047,850 468 185 76 Total in PEPCO 2014-15 638,171 39,663,833 46,481 23,693 17,775 System Source: Distribution Companies / KEL

184 State of Industry Report 2015

TABLE 74 Village Electrification in all Distribution Companies Total Number of Percentage of Total Electrified DISCO Year Total Villages Electrified Villages Villages 2011 24667 18927 76.73 2012 25413 19651 77.33 PESCO 2013 26017 20274 77.93 2014 26387 20554 77.89 2015 n.p. n.p...... 2011 522 522 100.00 2012 39 38 97.44 TESCO 2013 39 38 97.44 2014 58 38 65.52 2015 187 93 49.73 2011 1176 988 84.01 2012 1503 1341 89.22 IESCO 2013 2717 2109 77.62 2014 2717 2109 77.62 2015 3144 2323 73.89 2011 9286 8698 93.67 2012 6331 6331 100.00 GEPCO 2013 6804 6804 100.00 2014 6854 6854 100.00 2015 6977 6889 98.74 2011 2886 812 28.14 2012 410 406 99.02 LESCO 2013 3686 2543 68.99 2014 3913 2728 69.72 2015 3913 2859 73.06 2011 20893 19166 91.73 2012 21756 20161 92.67 FESCO 2013 22657 21209 93.61 2014 22930 21505 93.79 2015 23277 21831 93.79 2011 57358 44937 78.34 2012 15092 14954 99.09 MEPCO 2013 21325 19902 93.33 2014 25055 21240 84.77 2015 26310 22287 84.71 2011 46730 29114 62.30 2012 46730 30454 65.17 HESCO 2013 23803 15961 67.05 2014 23803 16424 69.00 2015 23803 17010 71.46 2012 n.p n.p --- 2013 22927 15795 68.89 SEPCO 2014 23263 16189 69.59 2015 23263 16515 70.99 2011 17123 12938 75.56 2012 17123 14863 86.80 QESCO 2013 17123 16016 93.54 2014 23819 17517 73.54 2015 23819 18017 75.64 2011 889 510 57.37 2012 889 563 63.33 K-Electric 2013 889 636 71.54 Limited 2014 889 661 74.35 2015 889 702 78.97 Source: Distribution Companies / K-EL

185 State of Industry Report 2015

TABLE 75 Applications of New Connections Received, Energized and Pending Applications Connection Applications DISCO Year Received (Nos.) Sanctioned (Nos.) Load (kW) Pending (Nos.) 2010-11 112499 83456 221989 29043 2011-12 80824 54701 100239 26123 PESCO 2012-13 80374 89626 169208 -9252 2013-14 106014 82407 188240 23607 2014-15 102861 100773 217731 2088 2010-11 131 63 964 68 2011-12 38 27 212 11 TESCO 2012-13 117 84 1844 33 2013-14 609 63 258 546 2014-15 641 162 2853 479 2010-11 92666 80119 n.p. 12547 2011-12 99516 83992 210900 15524 IESCO 2012-13 103609 85909 219208 17700 2013-14 96265 70856 211278 25409 2014-15 113855 81831 232254 32024 2010-11 122002 96795 315554 25207 2011-12 112162 86764 225697 25398 GEPCO 2012-13 109135 92599 215661 16536 2013-14 105194 94033 205952 11161 2014-15 126534 99735 241546 26799 2010-11 178611 133856 412901 44755 2011-12 166193 115206 411911 50987 LESCO 2012-13 179170 130407 460486 48763 2013-14 215984 146229 491192 69755 2014-15 244111 187150 531864 56961 2010-11 120021 123040 405570 -3019 2011-12 111944 113807 420215 -1863 FESCO 2012-13 146542 96499 252400 50043 2013-14 118884 90352 314228 28532 2014-15 125998 149562 n.p. -23564 2010-11 241676 160843 613292 80833 2011-12 271192 217886 473544 53306 MEPCO 2012-13 265242 238145 506865 27097 2013-14 258882 181169 389886 77713 2014-15 271874 249632 517342 22242 2010-11 24380 23091 41357 1289 2011-12 19072 18234 32156 838 HESCO 2012-13 39289 27918 64599 11371 2013-14 39240 36833 63415 2407 2014-15 21445 24625 83803 -3180 2011-12 7061 5197 11203 1864 2012-13 n.p. n.p. n.p. n.p. SEPCO 2013-14 17165 15609 85220 1556 2014-15 11832 10196 32819 1636 2010-11 13958 11381 19208 2577 2011-12 15113 13449 16737 1664 QESCO 2012-13 13619 11846 59604 1773 2013-14 23848 18460 31048 5388 2014-15 16455 13762 2693 2010-11 83682 36706 155002 46976 2011-12 50163 24898 164934 25265 K-Electric Limited 2012-13 20384 9143 138703 11241 2013-14 12174 10955 280576 1219 2014-15 25242 22266 348310 2976 Source: Distribution Companies / KESC

186 State of Industry Report 2015

TABLE 76 Province-wise Electricity Consumption by Economic Groups of the Country (GWh) Khyber K-Electric Category Year Punjab* Sindh** Balochistan## Total Pakhtunkhwa# Limited 2010-11 21802.99 3128.25 5576.53 464.14 4257.00 35228.91 2011-12 21001.64 3346.56 5342.59 512.50 4564.00 34767.29 Domestic 2012-13 20982.13 3595.27 5233.49 510.46 5083.00 35404.35 2013-14 23593.56 3723.74 5429.75 575.25 5489.00 38811.30 2014-15 24681.41 4042.02 5269.71 573.16 6161.00 40727.30 2010-11 3660.00 386.36 541.79 93.66 1043.00 5724.81 2011-12 3502.84 394.09 566.85 98.40 1128.00 5690.18 Commercial 2012-13 3372.50 405.01 558.68 97.52 1507.00 5940.71 2013-14 3630.77 428.49 631.54 101.70 1507.00 6299.50 2014-15 3633.69 451.21 659.63 108.93 1589.00 6442.46 2010-11 14761.50 1170.36 1653.04 114.28 3447.00 21146.18 2011-12 15241.43 1180.42 1855.12 122.31 3342.00 21741.28 Industrial 2012-13 15383.60 1191.27 1930.94 135.63 3445.00 22086.44 2013-14 17177.22 1187.62 2051.72 134.24 3568.00 24118.80 2014-15 17678.02 1184.43 2082.91 140.00 3648.00 24733.36 2010-11 4423.61 783.41 375.26 3264.83 125.00 8972.11 2011-12 4163.04 772.90 214.35 3259.50 134.00 8543.79 Agricultural 2012-13 3701.78 710.95 163.26 2974.35 149.00 7699.34 2013-14 4444.24 688.83 159.42 2837.00 160.00 8289.49 2014-15 3995.48 658.24 144.61 3067.74 166.00 8032.07 2010-11 227.06 101.31 20.52 3.98 82.00 434.87 2011-12 205.29 128.82 21.27 7.50 118.00 480.88 Public Lighting 2012-13 205.54 156.50 20.22 4.83 111.00 498.09 2013-14 211.42 162.18 14.07 2.23 106.00 495.90 2014-15 200.26 175.97 14.17 2.91 110.00 503.31 2010-11 1714.48 217.73 542.07 107.16 955.00 3536.44 2011-12 1771.05 216.45 525.08 85.75 806.00 3404.33 Bulk Supply 2012-13 2800.63 186.37 547.10 88.85 473.00 4095.95 2013-14 3005.27 191.10 546.23 93.95 427.00 4263.55 2014-15 3033.89 184.21 526.50 101.00 411.00 4256.60 2010-11 1049.09 26.80 2.31 0.05 163.00 1241.25 2011-12 925.45 8.39 2.25 0.05 188.00 1124.14 Traction/ 2012-13 20.46 4.71 1.96 0.05 174.00 201.18 Others 2013-14 24.34 4.42 2.60 0.04 197.00 228.40 2014-15 25.30 5.28 2.38 0.06 208.00 241.02 2010-11 47638.73 5814.22 8711.52 4048.10 10072.00 76284.57 2011-12 46810.74 6047.63 8527.51 4086.01 10280.00 75751.89 Total 2012-13 46466.62 6250.08 8455.65 3811.69 10942.00 75926.04 2013-14 52086.81 6386.38 8835.33 3744.41 11454.00 82506.93 2014-15 53248.05 6701.36 8699.91 3993.80 12293.00 84936.12 * Islamabad Capital Territory is included ** Consumption in K-EL Area is not included # FATA is included ## Area served by K-EL is excluded Source: National Electric Power Regulatory Authority

187 State of Industry Report 2015

TABLE 77 Province-wise Electricity Consumption by Economic Groups of the Country (%) Khyber K-Electric Category Year Punjab* Sindh** Balochistan## Total Pakhtunkhwa# Limited 2010-11 45.77 53.80 64.01 11.47 42.27 46.18 2011-12 44.87 55.34 62.65 12.54 44.40 45.90 Domestic 2012-13 45.16 57.52 61.89 13.39 46.45 46.63 2013-14 45.30 58.31 61.45 15.36 47.92 47.04 2014-15 46.35 60.32 60.57 14.35 50.12 47.95 2010-11 7.68 6.65 6.22 2.31 10.36 7.50 2011-12 7.48 6.52 6.65 2.41 10.97 7.51 Commercial 2012-13 7.26 6.48 6.61 2.56 13.77 7.82 2013-14 6.97 6.71 7.15 2.72 13.16 7.64 2014-15 6.82 6.73 7.58 2.73 12.93 7.59 2010-11 30.99 20.13 18.98 2.82 34.22 27.72 2011-12 32.56 19.52 21.75 2.99 32.51 28.70 Industrial 2012-13 33.11 19.06 22.84 3.56 31.48 29.09 2013-14 32.98 18.60 23.22 3.59 31.15 29.23 2014-15 33.20 17.67 23.94 3.51 29.68 29.12 2010-11 9.29 13.47 4.31 80.65 1.24 11.76 2011-12 8.89 12.78 2.51 79.77 1.30 11.28 Agricultural 2012-13 7.97 11.38 1.93 78.03 1.36 10.14 2013-14 8.53 10.79 1.80 75.77 1.40 10.05 2014-15 7.50 9.82 1.66 76.81 1.35 9.46 2010-11 0.48 1.74 0.24 0.10 0.81 0.57 2011-12 0.44 2.13 0.25 0.18 1.15 0.63 Public 2012-13 0.44 2.50 0.24 0.13 1.01 0.66 Lighting 2013-14 0.41 2.54 0.16 0.06 0.93 0.60 2014-15 0.38 2.63 0.16 0.07 0.89 0.59 2010-11 3.60 3.74 6.22 2.65 9.48 4.64 2011-12 3.78 3.58 6.16 2.10 7.84 4.49 Bulk Supply 2012-13 6.03 2.98 6.47 2.33 4.32 5.39 2013-14 5.77 2.99 6.18 2.51 3.73 5.17 2014-15 5.70 2.75 6.05 2.53 3.34 5.01 2010-11 2.20 0.46 0.03 0.00 1.62 1.63 2011-12 1.98 0.14 0.03 0.00 1.83 1.48 Traction/ 2012-13 0.04 0.08 0.02 0.00 1.59 0.26 Others 2013-14 0.05 0.07 0.03 0.00 1.72 0.28 2014-15 0.05 0.08 0.03 0.00 1.69 0.28 2010-11 100.00 100.00 100.00 100.00 100.00 100.00 2011-12 100.00 100.00 100.00 100.00 100.00 100.00 Total 2012-13 100.00 100.00 100.00 100.00 100.00 100.00 2013-14 100.00 100.00 100.00 100.00 100.00 100.00 2014-15 100.00 100.00 100.00 100.00 100.00 100.00 * Islamabad Capital Territory is included ** Consumption in K-EL Area is not included # FATA is included ## Area served by K-EL is excluded Source: National Electric Power Regulatory Authority

188 ELECTRICITY TARIFF 14

State of Industry Report 2015 14. ELECTRICITY TARIFF The determination of tariff for electric power services is one of the primary responsibilities of NEPRA. NEPRA determines electricity tariff, keeping in view the principles of economic efficiency and service quality according to the prescribed Tariff Standards and Procedure Rules, 1998. Under Section 7 (3) of the NEPRA Act, NEPRA has been expressly conferred the power to determine tariff, rates, charges and other terms and conditions for the supply of electric power services by generation, transmission and distribution companies and to recommend these to the Federal Government for notification.

14.1 Tariff Setting The procedures and standards in accordance with which tariffs are required to be determined, modified or revised are prescribed in the NEPRA (Tariff Standards and Procedure) Rules, 1998.

14.2 Tariff Standards

i) Tariffs should allows licenses the recovery of any and all costs prudently incurred to meet the demonstrated needs of their customers, provided that assessments of licensees’ prudence may not be required where tariffs are set on other than cost-of-service basis, such as formula-based tariffs that are designed to be in place for more than one year; ii) Tariffs should generally be calculated by including a depreciation charge and a rate of return on the capital investment of each licensee commensurate to the earned by other investments of comparable risk; iii) Tariffs should allow licensees a rate of return which promotes continued reasonable investment in equipment and facilities for improved and efficient service; iv) Tariffs should include a mechanism to allow licensees a benefit from, and penalties for failure to achieve, the efficiencies in the cost of providing the service and the quality of service; v) Tariffs should reflect marginal cost principles to the extent feasible, keeping in view the financial stability of the sector; vi) The Authority shall have a preference for competition rather than regulation and shall adopt policies and establish tariffs towards that end; vii) The tariff regime should clearly identify interclass and inter-region subsides and shall provide such subsides transparently if found essential, with a view to minimizing if not eliminating them keeping in view the need for an adequate transition period; viii) Tariffs may be set below the level of cost of providing the service to consumers consuming electric power below the consumption levels determined for the purpose from time to time by the Authority, as long as such tariffs are financially sustainable; ix) Tariffs should, to the extent feasible, reflect the full cost of service to consumer groups with similar service requirements; x) Tariff should take into account Government subsidies or the need for adjustment to finance rural electrification in accordance with the policies of the Government; xi) The application of the tariffs should allow reasonable transition periods for the adjustments of tariffs to meet the standards and other requirements pursuant to the Act including the performance standards, industry standards and the uniform codes of conduct; xii) Tariffs should seek to provide stability and predict ability for customers; and xiii) Tariffs should be comprehensible, free of misinterpretation and shall state explicitly each component thereof.

NEPRA is required to determine electricity tariff so as to protect the interest of the consumers as well as electric power producers/suppliers. Any raise in tariff requested by the producers/ suppliers of electricity has to be allowed or rejected by NEPRA after analyzing all the costs involved in the proposed sale price. For any determination of tariff, the following points are generally considered by NEPRA in addition to other points on case-to-case basis:

191 State of Industry Report 2015

i) Utility should be able to recover its costs with some surplus for capacity expansion or return on equity. ii) The average sale rate should provide for reasonable rate of return.

TABLE 78 NEPRA’s Monthly Fuel Price Adjustments in respect of DISCOs PESCO TESCO IESCO GEPCO LESCO FESCO MEPCO HESCO SEPCO QESCO Month Increase/(Decrease) Rs./kWh July, 2014 0.43 0.43 0.43 0.43 0.43 0.43 0.43 0.43 0.43 0.43 August, 2014 (0.30) (0.30) (0.30) (0.30) (0.30) (0.30) (0.30) (0.30) (0.30) (0.30) September, 2014 0.52 0.52 0.52 0.52 0.52 0.52 0.52 0.52 0.52 0.52 October, 2014 (0.48) (0.48) (0.48) (0.48) (0.48) (0.48) (0.48) (0.48) (0.48) (0.48) November, 2014 (2.97) (2.97) (2.97) (2.97) (2.97) (2.97) (2.97) (2.97) (2.97) (2.97) December, 2014 (3.24) (3.24) (3.24) (3.24) (3.24) (3.24) (3.24) (3.24) (3.24) (3.24) January, 2015 (2.08) (2.08) (2.08) (2.08) (2.08) (2.08) (2.08) (2.08) (2.08) (2.08) February, 2015 (4.43) (4.43) (4.43) (4.43) (4.43) (4.43) (4.43) (4.43) (4.43) (4.43) March, 2015 (3.62) (3.62) (3.62) (3.62) (3.62) (3.62) (3.62) (3.62) (3.62) (3.62) April, 2015 (1.86) (1.86) (1.86) (1.86) (1.86) (1.86) (1.86) (1.86) (1.86) (1.86) May, 2015 (2.69) (2.69) (2.69) (2.69) (2.69) (2.69) (2.69) (2.69) (2.69) (2.69) June, 2015 (2.20) (2.20) (2.20) (2.20) (2.20) (2.20) (2.20) (2.20) (2.20) (2.20) Source: National Electric Power Regulatory Authority, Islamabad

192 State of Industry Report 2015 4.00 4.00 12.50 15.00 15.00 17.00 19.00 19.00 13.00 19.00 15.00 19.00 13.00 14.50 19.00 13.00 19.00 12.80 19.00 12.70 19.00 15.00 14.50 QESCO Continued..... 4.00 11.00 13.52 13.52 16.00 19.00 19.00 13.00 19.00 15.00 19.00 13.00 14.50 19.00 13.00 14.00 19.00 12.80 19.00 12.70 19.00 15.00 14.50 SEPCO 9.79 9.80 4.00 14.00 14.00 15.00 16.00 16.00 10.20 15.00 13.00 16.00 10.20 12.50 16.00 10.20 12.00 16.00 10.00 16.00 16.00 13.00 12.50 HESCO 9.52 4.00 12.00 12.00 15.00 16.00 16.00 10.50 16.00 14.00 16.00 10.50 13.50 16.00 10.50 13.00 16.00 10.30 16.00 10.20 16.00 14.00 13.50 MEPCO 9.00 9.60 9.50 4.00 10.20 10.20 14.00 16.00 16.00 10.00 15.00 14.50 16.00 10.00 13.00 16.00 10.00 12.50 16.00 16.00 16.00 13.50 13.00 FESCO 9.25 9.50 9.50 9.50 9.30 9.10 4.00 11.00 11.00 13.33 15.00 15.00 16.00 12.00 15.00 12.00 15.00 11.50 15.00 15.00 15.00 12.50 12.00 LESCO Variable Charges (Rs./kWh) Charges Variable 4.00 11.82 14.00 14.00 17.00 19.00 19.00 13.00 19.00 15.00 19.00 13.00 14.50 19.00 13.00 14.00 19.00 12.80 19.00 12.70 19.00 15.00 14.50 GEPCO TABLE 79 TABLE 9.00 9.25 9.25 9.25 9.05 8.85 4.00 11.00 11.00 13.00 15.00 15.00 15.00 12.00 15.00 12.00 15.00 11.50 15.00 15.00 15.00 12.50 12.00 IESCO 4.00 14.30 17.30 17.30 18.00 19.00 19.00 14.50 19.00 17.00 19.00 14.50 15.00 19.00 14.50 14.50 19.00 14.30 19.00 14.20 19.00 15.50 15.00 TESCO Comparison of Proposed NEPRA Tariff (2014-15) NEPRA Tariff Proposed of Comparison 4.00 12.50 16.50 16.50 17.90 19.00 19.00 13.30 19.00 15.00 19.00 13.30 14.50 19.00 13.30 14.00 19.00 13.10 19.00 13.00 19.00 15.00 14.50 PESCO * 400.00 400.00 400.00 400.00 380.00 400.00 PARTICULARS RESIDENTIAL less than 5 kW For Sanctioned Load 50 Units Up to For Consumption exceeding 50 Units For Consumption exceeding 01-100 Units 101-200 Units 201-300 Units 301-700 Units Above 700 Units Above For Sanctioned Load 5 kW and above For Sanctioned Load - Peak Use (TOU) Time of Time of Use (TOU) - Off- Use (TOU) Time of Peak COMMERCIAL less For Sanctioned Load than 5 kW For Sanctioned Load 5 kW and above For Sanctioned Load Regular Time of Use (TOU) - Peak Use (TOU) Time of Time of Use (TOU) - Off- Use (TOU) Time of Peak B1 less than 5 kW (at 400/230 Volts) B1 Peak B1 Peak B1 Off-Peak B2 5-500 kW (at 400 Volts) B2 - TOU (Peak) B2 - TOU B2 - TOU (Off-Peak) B2 - TOU B3 - TOU (Peak) B3 - TOU B3 - TOU (Off-Peak) B3 - TOU B4 - TOU (Peak) B4 - TOU BULK SUPPLY C1 (a) Supply at 400 Volts 5 kW) (up to C1 (b) Supply at 400 Volts C1 (b) Supply at 400 Volts 5 kW) (exceeding

193 State of Industry Report 2015

19.00 13.00 14.30 19.00 12.80 14.20 19.00 12.70 15.20 19.00 12.70 14.70 19.00 12.70 14.00 14.00 QESCO

19.00 13.00 14.30 19.00 12.80 14.20 19.00 12.70 15.50 19.00 12.70 15.00 19.00 12.70 14.00 14.00 SEPCO

9.80 9.80 9.80 16.00 10.20 12.30 16.00 10.00 12.20 16.00 12.50 16.00 12.00 16.00 14.00 14.00 HESCO

16.00 10.50 13.30 16.00 10.30 13.20 16.00 10.20 13.50 16.00 10.20 13.00 16.00 10.20 14.00 14.00 14.00 MEPCO

9.60 9.50 9.50 9.50 16.00 10.00 12.80 16.00 12.70 16.00 13.00 16.00 12.50 16.00 14.00 14.00 FESCO

9.50 9.30 9.10 9.10 9.10 15.00 11.80 15.00 11.70 15.00 12.00 15.00 11.50 15.00 14.00 14.00 14.00 LESCO Variable Charges (Rs./kWh) Charges Variable

19.00 13.00 14.30 19.00 12.80 14.20 19.00 12.70 14.50 19.00 12.70 14.00 19.00 12.70 14.00 19.00 12.70 14.00 14.00 GEPCO

9.25 9.05 8.85 8.85 8.85 8.85 15.00 11.80 15.00 11.70 15.00 12.00 15.00 11.50 15.00 11.24 15.00 14.00 14.00 14.00 IESCO

19.00 14.50 14.80 19.00 14.30 14.70 19.00 14.20 15.00 19.00 14.20 14.50 19.00 14.20 15.00 15.00 TESCO

19.00 13.30 14.30 19.00 13.10 14.20 19.00 13.00 14.50 19.00 13.00 14.00 19.00 13.00 14.00 19.00 13.30 14.00 14.00 PESCO * 400.00 380.00 380.00 360.00 360.00 200.00 200.00 200.00 360.00 360.00 PARTICULARS Time of Use (TOU) - Peak Use (TOU) Time of Time of Use (TOU) - Off- Use (TOU) Time of Peak C2 Supply at 11 kV Time of Use (TOU) - Peak Use (TOU) Time of Time of Use (TOU) - Off- Use (TOU) Time of Peak C3 Supply above 11 kV C3 Supply above Time of Use (TOU) - Peak Use (TOU) Time of Time of Use (TOU) - Off- Use (TOU) Time of Peak AGRICULTURAL SCARP Time of Use (TOU) - Peak Use (TOU) Time of Time of Use (TOU) - Off- Use (TOU) Time of Peak Agricultural Tube-wells Time of Use (TOU) - Peak Use (TOU) Time of Time of Use (TOU) - Off- Use (TOU) Time of Peak PUBLIC LIGHTING RESIDENTIAL COLONIES RESIDENTIAL COLONIES TO ATTACHED. INDUSTRIES Railway Traction Special Contracts - AJ&K Time of Use (TOU) - Peak Use (TOU) Time of Time of Use (TOU) - Off- Use (TOU) Time of Peak Special Contracts - Rawat Lab.* * Fixed Charges (Rs./kW/Month) * Fixed Islamabad Authority, Regulatory Power National Electric Source:

194 State of Industry Report 2015

2.00 8.11 5.79 18.00 12.10 18.00 12.20 18.00 12.29 14.00 12.50 14.50 18.00 18.00 12.50 18.00 16.00 12.50 18.00 18.00 16.00 10.20 **** Continued.....

360 380 400 400 400 400 *** 10-06-2015** with effect from

2.00 8.11 5.79 18.00 12.10 18.00 12.20 18.00 12.30 12.50 18.00 14.50 14.00 18.00 12.50 18.00 16.00 12.50 18.00 18.00 16.00 12.09 ****

360 380 400 400 400 400 01-10-2014* *** with effect from

2.00 8.11 5.79 12.10 12.20 12.30 14.00 12.50 18.00 18.00 18.00 12.50 18.00 14.50 16.00 18.00 18.00 12.50 18.00 18.00 16.00 12.09 ****

360 380 400 400 400 400 11-10-2013 *** with effect from

8.22 8.11 5.79 12.10 12.20 12.30 14.00 18.00 18.00 18.00 12.50 18.00 14.50 12.50 16.00 18.00 18.00 13.99 15.07 12.33 2.00 ****

360 380 400 400 400 400 *** except PESCO PESCO except w.e.f 05-08-2013 w.e.f

7.46 7.75 8.01 9.14 8.01 8.22 9.72 8.22 2.00 8.11 5.79 12.37 12.68 12.77 13.99 10.51 13.20 14.77 13.99 15.07 12.33 **** TABLE 80 TABLE

from 360 380 400 400 400 400 *** with effect 16-05-2012

5.97 6.25 6.50 6.70 7.59 6.50 8.90 8.14 6.70 1.87 6.86 4.54 10.69 10.99 11.08 12.25 11.49 13.00 12.25 13.29 10.65 ****

343 356 367 367 367 367 06-05-2011 *** Statement of GOP Applicable (Notified) Tariff of Statement with effect from

5.97 6.25 6.50 6.70 7.59 6.50 8.90 8.14 6.70 1.87 6.73 4.45 10.69 10.99 11.08 12.25 11.49 13.00 12.25 13.29 10.65 ****

336 349 360 360 360 360 15-03-2011 ***

with effect from PARTICULARS B4 - TOU (Off-Peak) B4 - TOU B3 - TOU (Off-Peak) B3 - TOU 132 kV (at 66 kV, (Peak) B4 - TOU and above) B2 - TOU (Off-Peak) B2 - TOU 5000 kW (up to (Peak) B3 - TOU 33 kV) at 11 kV, B2 - TOU (Peak) B2 - TOU B1 - TOU (Off-Peak) B1 - TOU B2 25-500 kW (at 400 Volts) (Peak) B1 - TOU Time of Use (TOU) - Off-Peak Use (TOU) Time of INDUSTRIAL 25 kW (at 400/230 B1 up to Volts) 5 kW and above For Sanctioned Load Regular - Peak Use (TOU) Time of COMMERCIAL less than For Sanctioned Load 5 kW Time of Use (TOU) - Off-Peak Use (TOU) Time of For Sanctioned Load 5 kW and above For Sanctioned Load - Peak Use (TOU) Time of Above 700 Units Above 301-700 Units Up to 50 Units Up to 201-300 Units 101-200 Units RESIDENTIAL less than 5 kW For Sanctioned Load 50 Units For Consumption exceeding 01-100 Units

195 State of Industry Report 2015 8.85 8.85 15.00 12.20 18.00 12.22 15.00 15.00 15.00 15.00 10.35 12.20 12.00 11.50 18.00 12.30 14.20 18.00 12.50 14.30 18.00 15.00 14.50 ****

360 360 200 200 360 200 380 360 400 380 400 *** 10-06-2015** with effect from 15.00 12.20 18.00 12.22 15.00 15.00 17.00 10.35 15.00 11.51 10.35 12.20 13.01 10.00 18.00 12.30 14.20 18.00 12.50 14.30 18.00 15.00 14.50 ****

360 360 200 200 360 200 380 360 400 380 400 01-10-2014* *** with effect from 12.20 15.00 12.22 18.00 15.00 10.35 15.00 10.35 17.00 15.00 12.20 10.00 10.35 13.01 12.30 14.20 18.00 12.50 14.30 18.00 14.50 18.00 15.00 ****

360 360 200 200 360 200 380 360 400 380 400 11-10-2013 *** with effect from

6.77 12.20 10.00 12.30 14.20 18.00 12.50 14.30 18.00 14.50 18.00 15.00 8.00 11.50 12.20 18.00 12.22 11.00 12.92 13.73 13.00 ****

360 360 200 200 360 380 360 400 380 400 *** except PESCO PESCO except w.e.f 05-08-2013 w.e.f

7.92 5.63 8.00 6.77 7.35 7.75 8.01 11.50 13.30 11.00 12.92 13.73 10.00 13.00 10.10 12.18 10.25 12.60 10.35 13.01 11.55 ****

from 360 360 200 120 360 360 380 380 400 400 *** with effect 16-05-2012

8.75 6.41 4.21 9.96 4.55 8.47 5.31 5.87 8.51 6.25 8.65 6.50 8.75 9.90 11.59 11.22 12.00 10.11 10.51 10.91 11.31 **** **** Variable Charges (Rs./kWh) **** Variable

343 343 200 105 343 343 356 356 367 367 06-05-2011 *** with effect from

8.75 6.41 4.21 9.96 4.55 5.31 8.47 5.87 8.51 6.25 8.65 6.50 8.75 9.90 11.59 11.22 12.00 10.11 10.51 10.91 11.31 ****

323 323 200 103 336 336 349 349 360 360 15-03-2011 *** with effect from PARTICULARS Special Contracts - Rawat Lab. Time of Use (TOU) - Off-Peak Use (TOU) Time of Time of Use (TOU) - Peak Use (TOU) Time of Special Contracts - AJ&K RAILWAY TRACTION RAILWAY Time of Use (TOU) - Off-Peak Use (TOU) Time of - AT RESIDENTIAL COLONIES INDUSTRIES TO TACHED SCARP 5 kW and above - Peak Use (TOU) Time of Time of Use (TOU) - Off-Peak Use (TOU) Time of PUBLIC LIGHTING AGRICULTURAL SCARP Agricultural Tube-wells Agricultural 5 kW and above - Peak Use (TOU) Time of Time of Use (TOU) - Off-Peak Use (TOU) Time of C3 Supply above 11 kV C3 Supply above - Peak Use (TOU) Time of Time of Use (TOU) - Off-Peak Use (TOU) Time of C2 Supply at 11 kV - Peak Use (TOU) Time of Time of Use (TOU) - Off-Peak Use (TOU) Time of C1 (b) Supply at 400 Volts - 5 kW C1 (b) Supply at 400 Volts and above - Peak Use (TOU) Time of BULK SUPPLY - less C1 (a) Supply at 400 Volts than 5 kW * GOP Tariff with effect from 01-10-2014 also includes an amount of surcharge to be deposited in UOF. ** GOP Tariff with effect from 10-06-2015 also includes an amount of Tariff effect from 10-06-2015 also includes an amount Tariff with ** GOP in UOF. to be deposited of surcharge from 01-10-2014 also includes an amount with effect * GOP Tariff Charges (Rs./kW/Month) Surcharge. *** Fixed Rationalization Source: National Electric Power Regulatory Authority, Islamabad Authority, Regulatory Power National Electric Source:

196 State of Industry Report 2015

TABLE 81 Comparative Tariff Statement of Peshawar Electric Supply Company Limited (PESCO) 2010-11 2011-12 2012-13 2013-14 2014-15 PARTICULARS * ** * ** * ** * ** * ** RESIDENTIAL For Sanctioned Load less than 5 kW Up to 50 Units 2.00 3.00 4.00 4.00 4.00 For Consumption exceeding 50 Units 01-100 Units 9.50 11.15 15.00 13.00 12.50 101-200 Units 16.24 16.50 201-300 Units 11.00 15.50 16.50 16.24 16.50 301-700 Units 12.50 17.50 18.50 17.90 17.90 Above 700 Units 14.50 19.50 20.50 19.00 19.00 For Sanctioned Load 5 kW and above Time of Use (TOU) - Peak 13.00 19.50 20.50 19.00 19.00 Time of Use (TOU) - Off-Peak 7.50 11.50 15.50 13.30 13.30 COMMERCIAL For Sanctioned Load less than 5 kW 14.50 19.50 20.50 19.00 19.00 For Sanctioned Load 5 kW and above Regular 400.00 12.00 400.00 17.00 400.00 19.00 400.00 16.00 400.00 15.00 Time of Use (TOU) - Peak 12.50 19.50 20.50 19.00 19.00 Time of Use (TOU) - Off-Peak 400.00 7.00 400.00 11.50 400.00 15.50 400.00 13.30 400.00 13.30 INDUSTRIAL B1 Less than 5 kW (at 400/230 Volts) 10.50 15.50 17.00 15.50 14.50 B1 Peak 19.50 20.50 19.00 19.00 B1 Off-Peak 11.50 15.50 13.30 13.30 B2 5-500 kW (at 400 Volts) 400.00 9.50 400.00 14.50 400.00 16.50 400.00 15.00 400.00 14.00 B2 - TOU (Peak) 12.50 19.50 20.50 19.00 19.00 B2 - TOU (Off-Peak) 400.00 7.00 400.00 11.40 400.00 15.30 400.00 13.10 400.00 13.10 B3 - TOU (Peak) (up to 5000 kW at 11 12.25 19.50 20.50 19.00 19.00 kV, 33 kV) B3 - TOU (Off-Peak) 380.00 6.75 380.00 11.30 380.00 15.20 380.00 13.00 380.00 13.00 B4 - TOU (Peak) (at 66 kV, 132 kV and 12.00 19.50 20.50 19.00 19.00 above) B4 - TOU (Off-Peak) 360.00 6.50 360.00 11.20 360.00 15.10 360.00 12.90 360.00 12.90 BULK SUPPLY C1 (a) Supply at 400 Volts - less than 11.00 16.50 17.50 16.00 15.00 5 kW C1 (b) Supply at 400 Volts - 5 kW and 400.00 10.00 400.00 15.50 400.00 16.50 400.00 15.50 400.00 14.50 above Time of Use (TOU) - Peak 12.50 19.50 20.50 19.00 19.00 Time of Use (TOU) - Off-Peak 400.00 7.00 400.00 11.40 400.00 15.50 400.00 13.30 400.00 13.30 C2 Supply at 11 kV 380.00 9.75 380.00 15.25 380.00 16.30 380.00 15.30 380.00 14.30 Time of Use (TOU) - Peak 12.25 19.50 20.50 19.00 19.00 Time of Use (TOU) - Off-Peak 380.00 6.75 380.00 11.30 380.00 15.40 380.00 13.10 380.00 13.10 C3 Supply above 11 kV 360.00 9.50 360.00 15.00 360.00 16.20 360.00 15.20 360.00 14.20 Time of Use (TOU) - Peak 12.00 19.50 20.50 19.00 19.00 Time of Use (TOU) - Off-Peak 360.00 6.50 360.00 11.20 360.00 15.30 360.00 13.00 360.00 13.00 AGRICULTURAL SCAPR 11.00 14.30 17.00 15.50 14.50 Time of Use (TOU) - Peak 19.00 19.00 Time of Use (TOU) - Off-Peak 200.00 13.00 200.00 13.00 Agricultural Tube-wells 200.00 8.00 200.00 13.30 200.00 16.50 200.00 15.00 200.00 14.00 Time of Use (TOU) - Peak 12.50 19.50 20.50 19.00 19.00 Time of Use (TOU) - Off-Peak 200.00 6.00 200.00 11.00 200.00 15.30 200.00 13.00 200.00 13.00 PUBLIC LIGHTING 13.00 16.40 15.85 15.00 14.00 RESIDENTIAL COLONIES ATT. TO 13.00 16.40 15.00 15.00 14.00 INDUSTRIES Special Contracts - AJ&K 360.00 9.75 360.00 13.50 360.00 16.16 360.00 14.38 360.00 14.00 Time of Use (TOU) - Peak 12.00 19.50 20.50 19.00 19.00 Time of Use (TOU) - Off-Peak 360.00 6.50 360.00 11.00 360.00 15.30 360.00 13.00 360.00 13.30 * Fixed Charges (Rs./kW/Month) **Variable Charges (Rs./kWh) Source: National Electric Power Regulatory Authority, Islamabad 197 State of Industry Report 2015

TABLE 82 Comparative Tariff Statement of Tribal Area Electric Supply Company Limited (TESCO) 2013-14 2014-15 PARTICULARS Fixed* Variable** Fixed* Variable** RESIDENTIAL For Sanctioned Load less than 5 kW Up to 50 Units 4.00 4.00 For Consumption exceeding 50 Units 01-100 Units 12.70 14.30 101-200 Units 14.50 17.30 201-300 Units 14.50 17.30 301-700 Units 16.50 18.00 Above 700 Units 17.50 19.00 For Sanctioned Load 5 kW and above Time of Use (TOU) - Peak 17.50 19.00 Time of Use (TOU) - Off-Peak 11.50 14.50 COMMERCIAL For Sanctioned Load less than 5 kW 17.50 19.00 For Sanctioned Load 5 kW and above Regular 400.00 15.00 400.00 17.00 Time of Use (TOU) - Peak 17.50 19.00 Time of Use (TOU) - Off-Peak 400.00 11.50 400.00 14.50 INDUSTRIAL B1 Less than 5 kW (at 400/230 Volts) 14.50 15.00 B1 Peak 17.50 19.00 B1 Off-Peak 11.50 14.50 B2 5-500 kW (at 400 Volts) 400.00 14.00 400.00 14.50 B2 - TOU (Peak) 17.50 19.00 B2 - TOU (Off-Peak) 400.00 11.30 400.00 14.30 B3 - TOU (Peak) (up to 5000 kW at 11 kV, 33 kV) 17.50 19.00 B3 - TOU (Off-Peak) 380.00 11.20 380.00 14.20 B4 - TOU (Peak) (at 66 kV, 132 kV and above) 17.50 19.00 B4 - TOU (Off-Peak) 360.00 11.10 360.00 14.10 BULK SUPPLY C1 (a) Supply at 400 Volts - less than 5 kW 15.00 15.50 C1 (b) Supply at 400 Volts - 5 kW and above 400.00 14.50 400.00 15.00 Time of Use (TOU) - Peak 17.50 19.00 Time of Use (TOU) - Off-Peak 400.00 11.50 400.00 14.50 C2 Supply at 11 kV 380.00 14.30 380.00 14.80 Time of Use (TOU) - Peak 17.50 19.00 Time of Use (TOU) - Off-Peak 380.00 11.30 380.00 14.30 C3 Supply above 11 kV 360.00 14.20 360.00 14.70 Time of Use (TOU) - Peak 17.50 19.00 Time of Use (TOU) - Off-Peak 360.00 11.20 360.00 14.20 AGRICULTURAL SCARP 13.50 15.00 Time of Use (TOU) - Peak 17.50 19.00 Time of Use (TOU) - Off-Peak 200.00 11.20 200.00 14.20 Agricultural Tube-wells 200.00 12.97 200.00 14.50 Time of Use (TOU) - Peak 17.50 19.00 Time of Use (TOU) - Off-Peak 200.00 11.20 200.00 14.20 PUBLIC LIGHTING 15.00 15.00 RESIDENTIAL COLONIES ATT. TO INDUSTRIES 15.00 15.00 * Fixed Charges (Rs./kW/Month) ** Variable Charges (Rs./kWh) Source: National Electric Power Regulatory Authority, Islamabad

198 State of Industry Report 2015

TABLE 83 Comparative Tariff Statement of Islamabad Electric Supply Company Limited (IESCO) 2010-11 2011-12 2012-13 2013-14 2014-15 PARTICULARS * ** * ** * ** * ** * ** RESIDENTIAL For Sanctioned Load less than 5 kW Up to 50 Units 2.00 3.00 4.00 4.00 4.00 For Consumption exceeding 50 Units 01-100 Units 6.27 8.70 11.00 10.50 9.00 101-200 Units 12.50 11.00 201-300 Units 7.20 10.20 15.00 12.50 11.00 301-700 Units 10.65 14.00 17.00 15.00 13.00 Above 700 Units 13.30 16.50 18.00 17.50 15.00 For Sanctioned Load 5 kW and above Time of Use (TOU) - Peak 12.25 15.50 18.00 17.50 15.00 Time of Use (TOU) - Off-Peak 6.70 9.10 12.50 11.50 9.25 COMMERCIAL For Sanctioned Load less than 13.00 16.50 18.00 17.50 15.00 5 kW For Sanctioned Load 5 kW and above Regular 400.00 8.14 400.00 11.00 400.00 16.00 400.00 15.00 400.00 12.00 Time of Use (TOU) - Peak 11.49 15.00 18.00 17.50 15.00 Time of Use (TOU) - Off-Peak 400.00 6.50 400.00 9.30 400.00 12.50 400.00 11.50 400.00 9.25 INDUSTRIAL B1 Less than 5 kW (at 400/230 8.90 11.70 14.50 14.50 12.00 Volts) B1 Peak 15.50 18.00 17.50 15.00 B1 Off-Peak 9.10 12.50 11.50 9.25 B2 5-500 kW (at 400 Volts) 400.00 7.59 400.00 10.30 400.00 14.00 400.00 14.00 400.00 11.50 B2 - TOU (Peak) 11.08 14.30 18.00 17.50 15.00 B2 - TOU (Off-Peak) 400.00 6.50 400.00 9.00 400.00 12.30 400.00 11.30 400.00 9.05 B3 - TOU (Peak) (up to 5000 kW 10.99 14.10 18.00 17.50 15.00 at 11 kV, 33 kV) B3 - TOU (Off-Peak) 380.00 6.25 380.00 8.90 380.00 12.20 380.00 11.20 380.00 8.85 B4 - TOU (Peak) (at 66 kV, 132 kV 10.69 13.90 18.00 17.50 15.00 and above) B4 - TOU (Off-Peak) 360.00 5.97 360.00 8.80 360.00 12.10 360.00 11.10 360.00 8.75 BULK SUPPLY C1 (a) Supply at 400 Volts - less 9.90 12.50 15.00 15.00 12.50 than 5 kW C1 (b) Supply at 400 Volts - 5 kW 400.00 8.75 400.00 11.50 400.00 14.50 400.00 14.50 400.00 12.00 and above Time of Use (TOU) - Peak 11.31 14.30 18.00 17.50 15.00 Time of Use (TOU) - Off-Peak 400.00 6.50 400.00 9.00 400.00 12.50 400.00 11.50 400.00 9.25 C2 Supply at 11 kV 380.00 8.65 380.00 11.30 380.00 14.30 380.00 14.30 380.00 11.80 Time of Use (TOU) - Peak 10.91 14.10 18.00 17.50 15.00 Time of Use (TOU) - Off-Peak 380.00 6.25 380.00 8.90 380.00 12.30 380.00 11.30 380.00 9.05 C3 Supply above 11 kV 360.00 8.51 360.00 11.10 360.00 14.20 360.00 14.20 360.00 11.70 Time of Use (TOU) - Peak 10.51 13.90 18.00 17.50 15.00 Time of Use (TOU) - Off-Peak 360.00 5.87 360.00 8.80 360.00 12.20 360.00 11.20 360.00 8.85 AGRICULTURAL SCARP 8.47 11.20 14.50 14.50 12.00 Time of Use (TOU) - Peak 17.50 15.00 Time of Use (TOU) - Off-Peak 200.00 11.20 200.00 8.85 Agricultural Tube-wells 200.00 5.31 200.00 8.00 200.00 14.00 200.00 14.00 200.00 11.50 Time of Use (TOU) - Peak 10.11 13.00 18.00 17.50 15.00 Time of Use (TOU) - Off-Peak 200.00 4.55 200.00 8.00 200.00 12.20 200.00 11.20 200.00 8.85 PUBLIC LIGHTING 12.00 15.00 15.00 15.00 14.00 RESIDENTIAL COLONIES ATT. 11.22 14.00 15.00 15.00 14.00 TO INDUSTRIES Special Contracts - AJ&K 360.00 6.65 360.00 9.60 360.00 12.22 360.00 14.38 360.00 11.24 Time of Use (TOU) - Peak 11.59 15.00 18.00 17.50 15.00 Time of Use (TOU) - Off-Peak 360.00 6.41 360.00 9.00 360.00 12.20 360.00 11.20 360.00 8.85 Special Contract - Rawat Lab. 8.75 11.50 15.00 15.00 14.00 * Fixed Charges (Rs./kW/Month) ** Variable Charges (Rs./kWh) Source: National Electric Power Regulatory Authority, Islamabad

199 State of Industry Report 2015

TABLE 84 Comparative Tariff Statement of Gujranwala Electric Power Company Limited (GEPCO) 2010-11 2011-12 2012-13 2013-14 2014-15 PARTICULARS * ** * ** * ** * ** * ** RESIDENTIAL For Sanctioned Load less than 5 kW Up to 50 Units 2.00 3.00 4.00 4.00 4.00 For Consumption exceeding 50 Units 01-100 Units 8.25 9.50 12.10 13.26 11.82 101-200 Units 16.90 14.00 201-300 Units 10.00 13.55 15.00 16.90 14.00 301-700 Units 11.50 15.50 17.00 17.90 17.00 Above 700 Units 13.70 16.50 19.00 19.00 19.00 For Sanctioned Load 5 kW and above Time of Use (TOU) - Peak 12.25 15.00 19.00 19.00 19.00 Time of Use (TOU) - Off-Peak 6.75 9.50 12.50 13.50 13.00 COMMERCIAL For Sanctioned Load less 14.35 17.50 18.00 19.00 19.00 than 5 kW For Sanctioned Load 5 kW and above Regular 400.00 11.50 400.00 14.50 400.00 16.00 400.00 16.00 400.00 15.00 Time of Use (TOU) - Peak 12.00 15.00 19.00 19.00 19.00 Time of Use (TOU) - Off-Peak 400.00 6.50 400.00 9.50 400.00 12.50 400.00 13.50 400.00 13.00 INDUSTRIAL B1 Less than 5 kW (at 8.90 12.00 15.50 15.50 14.50 400/230 Volts) B1 Peak 15.00 19.00 19.00 19.00 B1 Off-Peak 9.50 12.50 13.50 13.00 B2 5-500 kW (at 400 Volts) 400.00 7.59 400.00 10.50 400.00 15.00 400.00 15.00 400.00 14.00 B2 - TOU (Peak) 11.08 15.00 19.00 19.00 19.00 B2 - TOU (Off-Peak) 400.00 6.50 400.00 9.30 400.00 12.30 400.00 13.30 400.00 12.80 B3 - TOU (Peak) (up to 5000 10.99 14.70 19.00 19.00 19.00 kW at 11 kV, 33 kV) B3 - TOU (Off-Peak) 380.00 6.25 380.00 9.20 380.00 12.20 380.00 13.20 380.00 12.70 B4 - TOU (Peak) (at 66 kV, 10.69 14.50 19.00 19.00 19.00 132 kV and above) B4 - TOU (Off-Peak) 360.00 5.97 360.00 9.10 360.00 12.10 360.00 13.10 360.00 12.60 BULK SUPPLY C1 (a) Supply at 400 Volts - 9.90 13.00 15.00 16.00 15.00 less than 5 kW C1 (b) Supply at 400 Volts - 5 400.00 8.75 400.00 11.50 400.00 14.50 400.00 15.50 400.00 14.50 kW and above Time of Use (TOU) - Peak 11.31 15.00 19.00 19.00 19.00 Time of Use (TOU) - Off-Peak 400.00 6.50 400.00 9.30 400.00 12.50 400.00 13.50 400.00 13.00 C2 Supply at 11 kV 380.00 8.65 380.00 11.40 380.00 14.40 380.00 15.30 380.00 14.30 Time of Use (TOU) - Peak 10.91 14.70 19.00 19.00 19.00 Time of Use (TOU) - Off-Peak 380.00 6.25 380.00 9.20 380.00 12.30 380.00 13.30 380.00 12.80 C3 Supply above 11 kV 360.00 8.51 360.00 11.30 360.00 14.30 360.00 15.20 360.00 14.20 Time of Use (TOU) - Peak 10.51 14.50 19.00 19.00 19.00 Time of Use (TOU) - Off-Peak 360.00 5.87 360.00 9.10 360.00 12.20 360.00 13.20 360.00 12.70 AGRICULTURAL SCARP 8.47 11.00 15.50 15.50 14.50 Time of Use (TOU) - Peak 19.00 19.00 Time of Use (TOU) - Off-Peak 200.00 13.20 200.00 12.70 Agricultural Tube-wells 200.00 5.31 200.00 9.50 200.00 15.00 200.00 15.00 200.00 14.00 Time of Use (TOU) - Peak 10.11 14.50 19.00 19.00 19.00 Time of Use (TOU) - Off-Peak 200.00 4.55 200.00 9.10 200.00 12.20 200.00 13.20 200.00 12.70 PUBLIC LIGHTING 12.00 15.00 15.00 15.00 14.00 RESIDENTIAL COLONIES 11.22 14.25 15.00 15.00 14.00 ATT. TO INDUSTRIES Special Contracts - AJ&K 360.00 8.75 360.00 13.00 360.00 13.33 360.00 15.00 360.00 14.00 Time of Use (TOU) - Peak 11.59 14.50 19.00 19.00 19.00 Time of Use (TOU) - Off-Peak 360.00 6.41 360.00 9.10 360.00 12.20 360.00 13.20 360.00 12.70 * Fixed Charges (Rs./kW/Month) ** Variable Charges (Rs./kWh) Source: National Electric Power Regulatory Authority, Islamabad 200 State of Industry Report 2015 TABLE 85 Comparative Tariff Statement of Lahore Electric Supply Company Limited (LESCO) 2010-11 2011-12 2012-13 2013-14 2014-15 PARTICULARS * ** * ** * ** * ** * ** For Sanctioned Load less than 5 kW Up to 50 Units 2.00 3.00 4.00 4.00 4.00 For Consumption exceeding 50 Units 01-100 Units 6.85 9.27 11.09 10.00 9.25 101-200 Units 12.33 11.00 201-300 Units 8.30 10.50 14.00 12.33 11.00 301-700 Units 10.65 13.50 17.00 15.00 13.33 Above 700 Units 13.29 15.50 18.00 17.50 15.00 For Sanctioned Load 5 kW and above Time of Use (TOU) - Peak 12.25 15.00 18.00 17.50 15.00 Time of Use (TOU) - Off-Peak 6.70 9.50 12.50 11.50 9.50 COMMERCIAL For Sanctioned Load less than 13.00 15.00 18.00 17.50 16.00 5 kW For Sanctioned Load 5 kW and above Regular 400.00 10.45 400.00 14.50 400.00 16.00 400.00 15.00 400.00 12.00 Time of Use (TOU) - Peak 11.49 15.00 18.00 17.50 15.00 Time of Use (TOU) - Off-Peak 400.00 6.50 400.00 9.50 400.00 12.50 400.00 11.50 400.00 9.50 INDUSTRIAL B1 Less than 5 kW (at 400/230 8.90 11.50 14.50 14.50 12.00 Volts) B1 Peak 15.00 18.00 17.50 15.00 B1 Off-Peak 9.50 12.50 11.50 9.50 B2 5-500 kW (at 400 Volts) 400.00 7.59 400.00 10.00 400.00 14.00 400.00 14.00 400.00 11.50 B2 - TOU (Peak) 11.08 15.00 18.00 17.50 15.00 B2 - TOU (Off-Peak) 400.00 6.50 400.00 9.30 400.00 12.30 400.00 11.30 400.00 9.30 B3 - TOU (Peak) (up to 5000 kW 10.99 14.70 18.00 17.50 15.00 at 11 kV, 33 kV) B3 - TOU (Off-Peak) 380.00 6.25 380.00 9.20 380.00 12.20 380.00 11.20 380.00 9.10 B4 - TOU (Peak) (at 66 kV, 132 10.69 14.50 18.00 17.50 15.00 kV and above) B4 - TOU (Off-Peak) 360.00 5.97 360.00 9.10 360.00 12.10 360.00 11.10 360.00 9.00 BULK SUPPLY C1 (a) Supply at 400 Volts - less 9.90 12.00 15.00 15.00 12.50 than 5 kW C1 (b) Supply at 400 Volts - 5 400.00 8.75 400.00 11.00 400.00 14.50 400.00 14.50 400.00 12.00 kW and above Time of Use (TOU) - Peak 11.31 15.00 18.00 17.50 15.00 Time of Use (TOU) - Off-Peak 400.00 6.50 400.00 9.30 400.00 12.50 400.00 11.50 400.00 9.50 C2 Supply at 11 kV 380.00 8.65 380.00 11.00 380.00 14.30 380.00 14.30 380.00 11.80 Time of Use (TOU) - Peak 10.91 14.70 18.00 17.50 15.00 Time of Use (TOU) - Off-Peak 380.00 6.25 380.00 9.20 380.00 12.30 380.00 11.30 380.00 9.30 Time of Use (TOU) - Peak 10.51 14.50 18.00 17.50 15.00 Time of Use (TOU) - Off-Peak 360.00 5.87 360.00 9.10 360.00 12.20 360.00 11.20 360.00 9.10 AGRICULTURAL SCARP 8.47 10.00 14.50 14.50 12.00 Time of Use (TOU) - Peak 17.50 15.00 Time of Use (TOU) - Off-Peak 200.00 11.20 200.00 9.10 Agricultural Tube-wells 200.00 5.31 200.00 8.00 200.00 14.00 200.00 14.00 200.00 11.50 Time of Use (TOU) - Peak 10.11 14.50 18.00 17.50 15.00 Time of Use (TOU) - Off-Peak 200.00 4.55 200.00 9.10 200.00 12.20 200.00 11.20 200.00 9.10 PUBLIC LIGHTING 12.00 14.50 15.00 15.00 14.00 RESIDENTIAL COLONIES ATT. 11.22 13.50 15.00 15.00 14.00 TO INDUSTRIES RAILWAY TRACTION 9.96 12.50 15.00 15.00 14.00 * Fixed Charges (Rs./kW/Month) ** Variable Charges (Rs./kWh) Source: National Electric Power Regulatory Authority, Islamabad

201 State of Industry Report 2015 TABLE 86 Comparative Tariff Statement of Faisalabad Electric Supply Company Limited (FESCO) 2010-11 2011-12 2012-13 2013-14 2014-15 PARTICULARS * ** * ** * ** * ** * ** RESIDENTIAL For Sanctioned Load less than 5 kW Up to 50 Units 2.00 3.00 4.00 4.00 4.00 For Consumption exceeding 50 Units 01-100 Units 7.25 9.60 12.57 11.09 9.00 101-200 Units 14.00 10.20 201-300 Units 9.00 13.00 15.50 14.00 10.20 301-700 Units 10.75 15.50 17.50 15.00 14.00 Above 700 Units 13.50 16.50 19.50 17.50 16.00 For Sanctioned Load 5 kW and above Time of Use (TOU) - Peak 12.25 15.00 19.50 17.50 16.00 Time of Use (TOU) - Off-Peak 6.70 9.50 12.90 11.50 10.00 COMMERCIAL For Sanctioned Load less than 5 kW 13.00 17.00 19.50 17.50 15.00 For Sanctioned Load 5 kW and above Regular 400.00 11.50 400.00 14.50 400.00 16.00 400.00 15.00 400.00 14.50 Time of Use (TOU) - Peak 12.00 15.00 19.50 17.50 16.00 Time of Use (TOU) - Off-Peak 400.00 6.50 400.00 9.50 400.00 12.90 400.00 11.50 400.00 10.00 INDUSTRIAL B1 Less than 5 kW (at 400/230 Volts) 8.90 12.00 15.50 14.50 13.00 B1 Peak 15.00 19.50 17.50 16.00 B1 Off-Peak 9.50 12.90 11.50 10.00 B2 5-500 kW (at 400 Volts) 400.00 7.59 400.00 11.00 400.00 15.00 400.00 14.00 400.00 12.50 B2 - TOU (Peak) 11.08 15.00 19.50 17.50 16.00 B2 - TOU (Off-Peak) 400.00 6.50 400.00 9.30 400.00 12.70 400.00 11.30 400.00 9.60 B3 - TOU (Peak) (up to 5000 kW at 11 kV, 33 kV) 10.99 14.70 19.50 17.50 16.00 B3 - TOU (Off-Peak) 380.00 6.25 380.00 9.20 380.00 12.60 380.00 11.20 380.00 9.50 B4 - TOU (Peak) (at 66 kV, 132 kV and above) 10.69 14.50 19.50 17.50 16.00 B4 - TOU (Off-Peak) 360.00 5.97 360.00 9.10 360.00 12.50 360.00 11.10 360.00 9.40 BULK SUPPLY C1 (a) Supply at 400 Volts - less than 5 kW 9.90 13.00 15.00 15.00 13.50 C1 (b) Supply at 400 Volts - 5 kW and above 400.00 8.75 400.00 11.50 400.00 14.50 400.00 14.50 400.00 13.00 Time of Use (TOU) - Peak 11.31 15.00 19.50 17.50 16.00 Time of Use (TOU) - Off-Peak 400.00 6.50 400.00 9.30 400.00 12.90 400.00 11.50 400.00 10.00 C2 Supply at 11 kV 380.00 8.65 380.00 11.40 380.00 14.40 380.00 14.30 380.00 12.80 Time of Use (TOU) - Peak 10.91 14.70 19.50 17.50 16.00 Time of Use (TOU) - Off-Peak 380.00 6.25 380.00 9.20 380.00 12.80 380.00 11.30 380.00 9.60 C3 Supply above 11 kV 360.00 8.51 360.00 11.30 360.00 14.30 360.00 14.20 360.00 12.70 Time of Use (TOU) - Peak 10.51 14.50 19.50 17.50 16.00 Time of Use (TOU) - Off-Peak 360.00 5.87 360.00 9.10 360.00 12.70 360.00 11.20 360.00 9.50 AGRICULTURAL SCARP 8.50 11.00 15.50 14.50 13.00 Time of Use (TOU) - Peak 17.50 16.00 Time of Use (TOU) - Off-Peak 200.00 11.20 200.00 9.50 Agricultural Tube-wells 200.00 6.00 200.00 9.50 200.00 15.00 200.00 14.00 200.00 12.50 Time of Use (TOU) - Peak 10.11 14.50 19.50 17.50 16.00 Time of Use (TOU) - Off-Peak 200.00 4.55 200.00 9.10 200.00 12.70 200.00 11.20 200.00 9.50 PUBLIC LIGHTING 12.00 15.00 16.00 15.00 14.00 RESIDENTIAL COLONIES ATT. TO 11.22 14.00 16.00 15.00 14.00 INDUSTRIES * Fixed Charges (Rs./kW/Month) ** Variable Charges (Rs./kWh) Source: National Electric Power Regulatory Authority, Islamabad

202 State of Industry Report 2015 TABLE 87 Comparative Tariff Statement of Multan Electric Power Company Limited (MEPCO) 2010-11 2011-12 2012-13 2013-14 2014-15 PARTICULARS * ** * ** * ** * ** * ** RESIDENTIAL For Sanctioned Load less than 5 kW Up to 50 Units 2.00 3.00 4.00 4.00 4.00 For Consumption exceeding 50 Units 01-100 Units 8.00 10.00 13.50 13.00 9.52 101-200 Units 16.90 12.00 201-300 Units 10.25 14.50 15.65 16.90 12.00 301-700 Units 12.50 16.40 17.65 17.90 15.00 Above 700 Units 14.00 18.00 19.50 19.00 16.00 For Sanctioned Load 5 kW and above Time of Use (TOU) - Peak 13.50 17.00 19.50 19.00 16.00 Time of Use (TOU) - Off-Peak 7.50 10.00 14.00 13.30 10.50 COMMERCIAL For Sanctioned Load less than 5 kW 15.50 18.50 19.50 19.00 16.00 For Sanctioned Load 5 kW and above Regular 400.00 12.00 400.00 16.00 400.00 16.00 400.00 16.00 400.00 14.00 Time of Use (TOU) - Peak 13.00 17.00 19.50 19.00 16.00 Time of Use (TOU) - Off-Peak 400.00 7.00 400.00 10.00 400.00 14.00 400.00 13.30 400.00 10.50 INDUSTRIAL B1 Less than 5 kW (at 400/230 Volts) 10.00 13.00 15.50 15.50 13.50 B1 Peak 17.00 19.50 19.00 16.00 B1 Off-Peak 10.00 14.00 13.30 10.50 B2 5-500 kW (at 400 Volts) 400.00 8.50 400.00 11.50 400.00 15.00 400.00 15.00 400.00 13.00 B2 - TOU (Peak) 13.00 16.00 19.50 19.00 16.00 B2 - TOU (Off-Peak) 400.00 7.00 400.00 9.70 400.00 13.80 400.00 13.10 400.00 10.30 B3 - TOU (Peak) (up to 5000 kW at 11 kV, 33 kV) 12.75 15.70 19.50 19.00 16.00 B3 - TOU (Off-Peak) 380.00 6.75 380.00 9.60 380.00 13.70 380.00 13.00 380.00 10.20 B4 - TOU (Peak) (at 66 kV, 132 kV and above) 12.50 15.50 19.50 19.00 16.00 B4 - TOU (Off-Peak) 360.00 6.50 360.00 9.50 360.00 13.60 360.00 12.90 360.00 10.10 BULK SUPPLY C1 (a) Supply at 400 Volts - less than 5 kW 10.50 14.00 15.00 16.00 14.00 C1 (b) Supply at 400 Volts - 5 kW and above 400.00 9.50 400.00 12.50 400.00 14.50 400.00 15.50 400.00 13.50 Time of Use (TOU) - Peak 13.00 16.00 19.50 19.00 16.00 Time of Use (TOU) - Off-Peak 400.00 7.00 400.00 9.70 400.00 14.00 400.00 13.30 400.00 10.50 C2 Supply at 11 kV 380.00 9.25 380.00 12.40 380.00 14.40 380.00 15.30 380.00 13.30 Time of Use (TOU) - Peak 12.75 15.70 19.50 19.00 16.00 Time of Use (TOU) - Off-Peak 380.00 6.75 380.00 9.60 380.00 13.90 380.00 13.10 380.00 10.30 C3 Supply above 11 kV 360.00 9.00 360.00 12.30 360.00 14.30 360.00 15.20 360.00 13.20 Time of Use (TOU) - Peak 12.50 15.50 19.50 19.00 16.00 Time of Use (TOU) - Off-Peak 360.00 6.50 360.00 9.50 360.00 13.80 360.00 13.00 360.00 10.20 AGRICULTURAL SCARP 10.50 12.00 15.50 15.50 13.50 Time of Use (TOU) - Peak 19.00 16.00 Time of Use (TOU) - Off-Peak 200.00 13.00 200.00 10.20 Agricultural Tube-wells 200.00 7.00 200.00 10.00 200.00 15.00 200.00 15.00 200.00 13.00 Time of Use (TOU) - Peak 13.00 15.50 19.50 19.00 16.00 Time of Use (TOU) - Off-Peak 200.00 6.00 200.00 9.50 200.00 13.80 200.00 13.00 200.00 10.20 PUBLIC LIGHTING 13.00 15.50 16.00 15.00 14.00 RESIDENTIAL COLONIES ATT. TO 13.00 15.00 16.00 15.00 14.00 INDUSTRIES RAILWAY TRACTION 10.00 11.00 16.00 15.00 14.00 * Fixed Charges (Rs./kW/Month) ** Variable Charges (Rs./kWh) Source: National Electric Power Regulatory Authority, Islamabad

203 State of Industry Report 2015

TABLE 88 Comparative Tariff Statement of Hyderabad Electric Supply Company Limited (HESCO) 2010-11 2011-12 2012-13 2013-14 2014-15 PARTICULARS * ** * ** * ** * ** * ** RESIDENTIAL For Sanctioned Load less than 5 kW Up to 50 Units 2.00 3.00 4.00 4.00 4.00 For Consumption exceeding 50 Units 01-100 Units 9.00 10.00 15.00 11.06 9.79 101-200 Units 12.50 14.00 201-300 Units 12.75 15.00 17.24 12.50 14.00 301-700 Units 14.00 17.00 18.50 15.50 15.00 Above 700 Units 15.00 19.00 20.50 17.50 16.00 For Sanctioned Load 5 kW and above Time of Use (TOU) - Peak 14.00 19.00 20.50 17.50 16.00 Time of Use (TOU) - Off-Peak 7.50 11.00 15.50 11.50 10.20 COMMERCIAL For Sanctioned Load less than 5 kW 15.00 16.00 20.50 17.50 15.00 For Sanctioned Load 5 kW and above Regular 14.00 400.00 15.00 400.00 19.00 400.00 15.00 400.00 13.00 Time of Use (TOU) - Peak 14.00 19.00 20.50 17.50 16.00 Time of Use (TOU) - Off-Peak 7.50 400.00 11.00 400.00 15.50 400.00 11.50 400.00 10.20 INDUSTRIAL B1 Less than 5 kW (at 400/230 Volts) 10.00 14.00 17.00 14.50 12.50 B1 Peak 19.00 20.50 17.50 16.00 B1 Off-Peak 11.00 15.50 11.50 10.20 B2 5-500 kW (at 400 Volts) 400.00 9.50 400.00 13.00 400.00 16.50 400.00 14.00 400.00 12.00 B2 - TOU (Peak) 14.00 19.00 20.50 17.50 16.00 B2 - TOU (Off-Peak) 400.00 7.50 400.00 10.50 400.00 15.30 400.00 11.30 400.00 10.00 B3 - TOU (Peak) (up to 5000 kW at 11 kV, 33 kV) 13.90 19.00 20.50 17.50 16.00 B3 - TOU (Off-Peak) 380.00 7.00 380.00 10.25 380.00 15.20 380.00 11.20 380.00 9.80 B4 - TOU (Peak) (at 66 kV, 132 kV and above) 13.80 19.00 20.50 17.50 16.00 B4 - TOU (Off-Peak) 360.00 6.50 360.00 10.00 360.00 15.10 360.00 11.10 360.00 9.70 BULK SUPPLY C1 (a) Supply at 400 Volts - less than 5 kW 10.75 14.50 17.50 15.00 13.00 C1 (b) Supply at 400 Volts - 5 kW and above 400.00 10.25 400.00 13.50 400.00 16.50 400.00 14.50 400.00 12.50 Time of Use (TOU) - Peak 14.00 19.00 20.50 17.50 16.00 Time of Use (TOU) - Off-Peak 400.00 7.50 400.00 10.50 400.00 15.50 400.00 11.50 400.00 10.20 C2 Supply at 11 kV 380.00 10.15 380.00 13.25 380.00 16.30 380.00 14.30 380.00 12.30 Time of Use (TOU) - Peak 13.90 19.00 20.50 17.50 16.00 Time of Use (TOU) - Off-Peak 380.00 7.40 380.00 10.25 380.00 15.40 380.00 11.30 380.00 10.00 C3 Supply above 11 kV 360.00 10.05 360.00 13.00 360.00 16.20 360.00 14.20 360.00 12.20 Time of Use (TOU) - Peak 13.80 19.00 20.50 17.50 16.00 Time of Use (TOU) - Off-Peak 360.00 7.30 360.00 10.00 360.00 15.30 360.00 11.20 360.00 9.80 AGRICULTURAL SCARP 12.00 14.00 17.00 14.50 12.50 Time of Use (TOU) - Peak 17.50 16.00 Time of Use (TOU) - Off-Peak 200.00 11.20 200.00 9.80 Agricultural Tube-wells 200.00 7.50 200.00 10.10 200.00 16.50 200.00 14.00 200.00 12.00 Time of Use (TOU) - Peak 14.00 19.00 20.50 17.50 16.00 Time of Use (TOU) - Off-Peak 200.00 5.00 200.00 8.00 200.00 15.30 200.00 11.20 200.00 9.80 PUBLIC LIGHTING 13.00 16.50 17.00 15.00 14.00 RESIDENTIAL COLONIES ATT. TO INDUSTRIES 13.00 16.50 17.00 15.00 14.00 * Fixed Charges (Rs./kW/Month) ** Variable Charges (Rs./kWh) Source: National Electric Power Regulatory Authority, Islamabad

204 State of Industry Report 2015

TABLE 89 Comparative Tariff Statement of Sukkur Electric Supply Company Limited (SEPCO) 2011-12 2012-13 2013-14 2014-15 PARTICULARS * ** * ** * ** * ** RESIDENTIAL For Sanctioned Load less than 5 kW Up to 50 Units 3.00 4.00 4.00 4.00 For Consumption exceeding 50 Units 01-100 Units 11.13 15.00 10.50 11.00 101-200 Units 12.50 13.52 201-300 Units 15.00 16.00 12.50 13.52 301-700 Units 17.00 17.00 15.50 16.00 Above 700 Units 19.00 20.00 17.50 19.00 For Sanctioned Load 5 kW and above Time of Use (TOU) - Peak 19.00 20.00 17.50 19.00 Time of Use (TOU) - Off-Peak 11.50 15.50 11.50 13.00 COMMERCIAL For Sanctioned Load less than 5 kW 16.00 20.00 17.50 19.00 For Sanctioned Load 5 kW and above Regular 400.00 15.00 400.00 19.00 400.00 15.00 400.00 15.00 Time of Use (TOU) - Peak 19.00 20.00 17.50 19.00 Time of Use (TOU) - Off-Peak 400.00 11.50 400.00 15.50 400.00 11.50 400.00 13.00 INDUSTRIAL B1 Less than 5 kW (at 400/230 Volts) 14.00 17.00 14.50 14.50 B1 Peak 19.00 20.00 17.50 19.00 B1 Off-Peak 11.50 15.50 11.50 13.00 B2 5-500 kW (at 400 Volts) 400.00 13.00 400.00 16.50 400.00 14.00 400.00 14.00 B2 - TOU (Peak) 19.00 20.00 17.50 19.00 B2 - TOU (Off-Peak) 400.00 11.00 400.00 15.30 400.00 11.30 400.00 12.80 B3 - TOU (Peak) (up to 5000 kW at 11 kV, 33 kV) 19.00 20.00 17.50 19.00 B3 - TOU (Off-Peak) 380.00 10.50 380.00 15.20 380.00 11.20 380.00 12.70 B4 - TOU (Peak) (at 66 kV, 132 kV and above) 19.00 20.00 17.50 19.00 B4 - TOU (Off-Peak) 360.00 10.25 360.00 15.10 360.00 11.10 360.00 12.60 BULK SUPPLY C1 (a) Supply at 400 Volts - less than 5 kW 14.50 17.50 15.00 15.00 C1 (b) Supply at 400 Volts - 5 kW and above 400.00 13.50 400.00 16.50 400.00 14.50 400.00 14.50 Time of Use (TOU) - Peak 19.00 20.00 17.50 19.00 Time of Use (TOU) - Off-Peak 400.00 11.00 400.00 15.50 400.00 11.50 400.00 13.00 C2 Supply at 11 kV 380.00 13.25 380.00 16.30 380.00 14.30 380.00 14.30 Time of Use (TOU) - Peak 19.00 20.00 17.50 19.00 Time of Use (TOU) - Off-Peak 380.00 10.50 380.00 15.40 380.00 11.30 380.00 12.80 C3 Supply above 11 kV 360.00 13.00 360.00 16.20 360.00 14.20 360.00 14.20 Time of Use (TOU) - Peak 19.00 20.00 17.50 19.00 Time of Use (TOU) - Off-Peak 360.00 10.25 360.00 15.30 360.00 11.20 360.00 12.70 AGRICULTURAL SCARP 14.00 17.00 13.60 15.50 Time of Use (TOU) - Peak 17.50 19.00 Time of Use (TOU) - Off-Peak 200.00 11.20 200.00 12.70 Agricultural Tube-wells 200.00 10.50 200.00 16.50 200.00 13.00 200.00 15.00 Time of Use (TOU) - Peak 19.00 20.00 17.50 19.00 Time of Use (TOU) - Off-Peak 200.00 8.00 200.00 15.30 200.00 11.20 200.00 12.70 PUBLIC LIGHTING 16.50 15.90 15.00 14.00 RESIDENTIAL COLONIES ATT. TO INDUSTRIES 16.50 15.90 15.00 14.00 * Fixed Charges (Rs./kW/Month) ** Variable Charges (Rs./kWh) Source: National Electric Power Regulatory Authority, Islamabad 205 State of Industry Report 2015

TABLE 90 Comparative Tariff Statement of Quetta Electric Supply Company Limited (QESCO) 2010-11 2011-12 2012-13 2013-14 2014-15 PARTICULARS * ** * ** * ** * ** * ** RESIDENTIAL For Sanctioned Load less than 5 kW Up to 50 Units 2.00 3.00 4.00 4.00 4.00 For Consumption exceeding 50 Units 01-100 Units 9.50 10.00 11.00 10.50 12.50 101-200 Units 12.50 15.00 201-300 Units 11.90 13.20 14.00 12.50 15.00 301-700 Units 13.25 14.30 16.00 15.00 17.00 Above 700 Units 15.25 16.50 18.00 17.50 19.00 For Sanctioned Load 5 kW and above Time of Use (TOU) - Peak 15.50 16.00 18.00 17.50 19.00 Time of Use (TOU) - Off-Peak 7.50 9.00 12.50 11.50 13.00 COMMERCIAL For Sanctioned Load less than 5 kW 15.25 17.00 18.00 17.50 19.00 For Sanctioned Load 5 kW and above Regular 400.00 14.00 400.00 15.00 400.00 16.00 400.00 15.00 400.00 15.00 Time of Use (TOU) - Peak 15.50 16.50 18.00 17.50 19.00 Time of Use (TOU) - Off-Peak 400.00 7.00 400.00 8.00 400.00 12.50 400.00 11.50 400.00 13.00 INDUSTRIAL B1 Less than 5 kW (at 400/230 Volts) 10.00 11.50 14.50 14.50 14.50 B1 Peak 16.00 18.00 17.50 19.00 B1 Off-Peak 9.00 12.50 11.50 13.00 B2 5-500 kW (at 400 Volts) 400.00 9.00 400.00 10.50 400.00 14.00 400.00 14.00 400.00 14.00 B2 - TOU (Peak) 15.50 16.60 18.00 17.50 19.00 B2 - TOU (Off-Peak) 400.00 7.00 400.00 8.60 400.00 12.30 400.00 11.30 400.00 12.80 B3 - TOU (Peak) (up to 5000 kW at 15.40 16.50 18.00 17.50 19.00 11 kV, 33 kV) B3 - TOU (Off-Peak) 380.00 6.90 380.00 8.40 380.00 12.20 380.00 11.20 380.00 12.70 B4 - TOU (Peak) (at 66 kV, 132 kV 15.30 16.40 18.00 17.50 19.00 and above) B4 - TOU (Off-Peak) 360.00 6.80 360.00 8.20 360.00 12.10 360.00 11.10 360.00 12.60 BULK SUPPLY C1 (a) Supply at 400 Volts - less than 10.50 11.50 15.00 15.00 15.00 5 kW C1 (b) Supply at 400 Volts - 5 kW 400.00 9.50 400.00 10.50 400.00 14.50 400.00 14.50 400.00 14.50 and above Time of Use (TOU) - Peak 15.50 16.60 18.00 17.50 19.00 Time of Use (TOU) - Off-Peak 400.00 7.00 400.00 8.60 400.00 12.50 400.00 11.50 400.00 13.00 C2 Supply at 11 kV 380.00 9.40 380.00 10.40 380.00 14.30 380.00 14.30 380.00 14.30 Time of Use (TOU) - Peak 15.40 16.50 18.00 17.50 19.00 Time of Use (TOU) - Off-Peak 380.00 6.90 380.00 8.40 380.00 12.30 380.00 11.30 380.00 12.80 C3 Supply above 11 kV 360.00 9.30 360.00 10.30 360.00 14.20 360.00 14.20 360.00 14.20 Time of Use (TOU) - Peak 15.30 16.40 18.00 17.50 19.00 Time of Use (TOU) - Off-Peak 360.00 6.80 360.00 8.20 360.00 12.20 360.00 11.20 360.00 12.70 AGRICULTURAL SCARP 12.00 13.00 13.01 14.00 15.20 Time of Use (TOU) - Peak 17.50 19.00 Time of Use (TOU) - Off-Peak 200.00 11.20 200.00 12.70 Agricultural Tube-wells 200.00 10.65 200.00 11.50 200.00 11.51 200.00 13.61 200.00 14.70 Time of Use (TOU) - Peak 15.50 16.50 17.00 17.50 19.00 Time of Use (TOU) - Off-Peak 200.00 7.00 200.00 8.00 200.00 10.00 200.00 11.20 200.00 12.70 PUBLIC LIGHTING 13.00 14.00 15.00 15.00 14.00 RESIDENTIAL COLONIES ATT. TO 13.00 14.00 15.00 15.00 14.00 INDUSTRIES * Fixed Charges (Rs./kW/Month) ** Variable Charges (Rs./kWh) Source: National Electric Power Regulatory Authority, Islamabad

206 State of Industry Report 2015 ------0.11 0.03 3.01 5.15 0.46 1.38 0.47 4.50 4.82 8.23 1.19 10.03 33.57 32.66 23.17 17.14 12.54 25.93 102.27 442.56 457.84 460.21 4,439.90 2,916.25 4,995.40 1,333.87 5,952.19 Total 32,562.64 22,478.42 49,993.74 10,974.64 31,680.62 397,179.39 108,351.31 ------9.08 0.09 0.14 1.28 4.34 0.35 0.80 0.53 4.50 5.70 6.24 1.18 10.20 34.87 52.89 13.95 79.14 40.02 40.84 25.03 27.42 15.63 10.93 355.72 126.95 430.99 509.26 493.88 3,972.81 2,484.22 2,722.00 1,983.77 June 27,147.06 15,517.24 ------0.13 1.20 4.66 0.45 0.88 0.81 9.93 5.57 6.47 1.18 10.20 42.74 77.49 11.98 84.40 35.35 28.68 27.84 13.89 435.93 114.24 445.33 526.46 545.82 May 3,377.71 2,740.55 2,659.95 1,586.45 27,205.92 14,823.07 ------0.18 5.06 5.88 0.52 1.59 0.72 4.50 9.87 5.18 6.40 1.18 13.12 10.20 38.44 52.54 20.06 59.03 39.23 26.76 13.86 392.05 371.20 431.98 116.96 510.44 748.47 1,472.75 2,880.22 1,964.31 5,144.20 April 28,417.82 10,178.80 ------7.58 0.12 4.63 6.91 0.50 2.11 0.51 4.50 9.73 4.57 7.87 1.18 10.20 32.81 33.29 20.86 34.12 38.84 25.53 13.82 302.84 451.96 138.07 334.65 534.22 1,364.16 2,540.72 1,669.67 7,622.82 1,087.23 4,184.18 March 24,709.88 ------0.31 1.80 6.99 0.48 2.01 0.63 4.50 8.40 4.90 8.33 1.18 18.35 10.20 28.12 36.81 33.40 82.55 33.00 21.38 15.53 105.64 409.49 117.52 286.87 484.01 979.12 Feb. 1,957.18 1,933.36 1,252.60 6,133.95 1,640.07 16,236.47 ------1.56 0.03 9.42 5.65 7.02 0.48 2.10 0.53 4.50 4.28 8.22 1.17 10.20 29.97 32.97 13.09 45.37 23.32 14.92 10.27 582.87 349.58 130.05 305.73 809.87 410.02 Jan. 2,806.66 1,442.89 6,168.47 1,068.98 8,695.44 28,822.30 ------0.21 0.78 5.67 0.46 1.92 0.44 4.50 3.66 8.65 1.18 10.20 14.47 31.31 29.97 52.70 28.11 39.18 23.22 65.09 19.08 12.20 384.92 130.05 319.41 455.08 Dec. 1,907.41 2,658.56 1,575.33 5,765.88 1,124.56 1,005.68 TABLE 91 TABLE 32,436.85 ------9.90 0.23 5.07 0.08 6.52 0.52 1.53 0.21 4.50 4.16 9.70 1.18 15.34 34.44 13.85 43.45 20.94 26.53 69.03 13.86 433.65 101.61 340.98 512.48 985.54 Nov. 2,891.91 1,394.06 1,766.01 7,349.69 19,319.19 ------9.90 0.12 0.00 2.95 4.85 0.49 1.42 0.14 4.50 0.56 4.49 9.11 1.19 40.75 11.41 38.47 33.40 18.30 20.31 15.64 245.48 403.42 118.08 403.44 478.19 Oct. 3,202.84 2,780.61 1,523.65 6,841.71 4,984.67 1,075.53 43,489.67 ------9.80 7.85 0.09 3.51 4.73 0.44 1.16 0.35 4.50 4.30 9.10 1.18 40.21 31.59 38.71 30.46 20.56 35.34 20.20 15.66 320.17 432.03 105.45 394.08 510.54 959.58 Sept. 3,532.44 2,779.77 1,876.14 8,069.95 6,467.64 Monthly Source-wise Power Sent Out and Fuel Cost (2014-15) Power Monthly Source-wise 43,518.28 ------9.80 4.70 0.05 2.94 4.22 0.42 1.03 0.36 4.50 4.89 8.97 1.18 43.26 37.21 41.42 31.30 18.28 21.14 20.60 15.74 303.58 435.93 106.48 423.97 514.71 954.93 Aug. 4,282.93 3,236.65 1,889.98 9,233.57 6,254.31 50,933.01 ------9.80 0.10 3.72 3.73 0.44 1.02 0.46 4.50 4.98 8.97 1.31 10.11 45.47 20.87 45.62 47.84 36.61 33.28 20.63 15.95 385.50 386.12 106.06 447.10 506.78 950.98 July 3,790.63 3,445.24 2,135.88 8,047.33 54,942.94 10,646.17 % % % % % % % % % % GWh GWh GWh GWh GWh GWh GWh GWh GWh GWh Mln.Rs. Mln.Rs. Mln.Rs. Mln.Rs. Mln.Rs. Mln.Rs. Mln.Rs. Mln.Rs. Mln.Rs. Mln.Rs. Rs./kWh Rs./kWh Rs./kWh Rs./kWh Rs./kWh Rs./kWh Rs./kWh Rs./kWh Rs./kWh Rs./kWh

National Electric Power Regulatory Authority, Islamabad Authority, Regulatory Power National Electric Generation Generation Generation Generation Generation Generation Generation Generation Generation Generation Fuel Cost Fuel Cost Fuel Cost Fuel Cost Fuel Cost Fuel Cost Fuel Cost Fuel Cost Fuel Cost Fuel Cost

Iran Iran Power Power

Hydel Hydel Coal HSD RFO Gas Nuclear Mixed

Import Import Wind Solar Source: Source:

207 State of Industry Report 2015

------3.41 6.15 6.60 0.70 9.51 8.80 4.64 4.64 4.64 4.64 4.45 4.45 (0.45) 56.26 21.68 46.55 112.08 499.84 488.23 44,528 651.90 351.84 351.84 1,651.61 (295.58) June ------

6.37 6.60 8.29 8.80 9.67 4.64 4.64 4.64 4.64 4.45 4.45 (0.23) (0.07) (0.51) 93.12 45.63 471.09 488.23 41,890 677.77 (24.24) May 1,627.66 (394.47) (154.15) (240.31) (240.31) ------

0.75 7.35 6.60 8.47 8.80 1.54 4.64 4.64 4.64 4.64 4.45 4.45 (0.05) (0.33) 96.66 33.25 25.06 385.15 488.23 38,765 365.93 655.41 492.96 April 1,460.41 (127.03) (127.03) ------

6.60 7.12 8.80 0.33 4.64 4.64 4.64 4.64 4.45 4.45 (0.52) (0.07) (1.24) 36.13 10.04 14.50 231.80 488.23 41,618 650.69 (51.52) 1,217.87 (627.42) (340.33) (287.08) (287.08) March ------

5.27 7.12 6.76 2.96 4.64 4.64 4.64 4.64 4.45 4.45 (1.86) (0.07) (3.28) 54.82 10.04 22.15 990.45 189.19 488.23 36,571 578.81 (1,696.03) Feb. (1,074.84) (171.24) (621.19) (621.19) ------

1.84 8.96 7.12 7.55 1.48 4.64 4.64 9.99 4.64 4.64 4.45 4.45 (0.07) (2.49) 12.46 99.88 10.04 80.55 488.23 37,242 814.22 577.43 Jan. 1,010.82 (248.56) (248.56) 1,062.78 ------

7.12 8.67 0.52 4.64 4.64 4.64 4.64 4.45 4.45 (1.54) (0.07) (2.50) 19.62 12.54 10.04 10.50 138.13 488.23 47,146 573.77 Dec. 1,061.60 (1,230.49) (115.91) (885.60) (344.88) (344.88) ------

6.11 8.67 9.56 4.64 4.64 4.64 4.64 4.45 4.45 (2.56) (0.07) (2.97) 66.92 12.54 10.03 36.30 179.46 488.23 54,578 597.57 Nov. (1,530.34) 1,216.84 (2,064.19) (169.64) (533.86) (533.86) ------

8.39 8.67 9.42 4.64 4.64 4.64 4.64 4.45 4.45 TABLE 92 TABLE (0.27) (0.07) (3.12) 84.13 12.54 24.28 48.57 290.76 488.23 65,632 625.45 Oct. (75.87) 1,422.75 (907.61) (907.61) (171.81) (1,079.42) - - - -

8.67 9.21 0.24 4.64 4.89 4.64 4.89 4.45 4.69 (0.55) (0.07) (0.26) (0.26) (0.25) 79.52 12.29 12.54 18.26 48.12 54.06 90.65 373.62 488.23 68,499 635.55 (4.68) (19.74) (19.56) (12.34) Sept. 1,483.59 (292.84) (346.90) - - - -

8.51 9.21 4.64 4.89 4.64 4.89 4.45 4.69 (0.70) (0.07) (2.03) (0.26) (0.26) (0.25) 83.19 12.29 10.26 26.70 51.04 380.16 488.23 64,359 647.79 (6.85) (83.85) (20.46) (13.09) Aug. 1,511.13 (812.69) (772.29) (454.45) (1,267.14) - - - -

0.04 9.25 9.21 4.64 4.89 4.64 4.89 4.45 4.69 (0.06) (0.40) (0.26) (0.26) (0.25) 78.47 12.29 11.89 34.70 57.28 23.14 462.28 488.23 64,882 624.55 (8.90) (12.86) (19.30) (14.69) July 1,591.83 (204.69) (227.82) (184.93) K-Electric - Summary Monthly Fuel Cost Adjustment (2014-15) of Description National Electric Power Regulatory Authority, Islamabad Authority, Regulatory Power National Electric Fuel Cost Variation (Ps./kWh) Fuel Cost Variation Total Units Sent out (Own Gen.+Power Pur.) Units Sent out (Own Gen.+Power Total Difference (Rs./kWh) Difference Weighted Average Fuel Cost (Rs./kWh) (Actual) Average Weighted Weighted Average Fuel Cost (Rs./kWh) (Ref.) Average Weighted Power Purchases Power Fuel Cost Variation of Own Gen. (Mil./Rs.) of Fuel Cost Variation Fuel Cost Variation (Mln./Rs.) Fuel Cost Variation Number of Units Sent Out (Mln./kWh) Number of Fuel Cost Variation (Mln./Rs.) Fuel Cost Variation Number of Units Sent Out (Mln./kWh) Number of Difference (Rs./kWh) Difference Weighted Average Fuel Cost (Rs./kWh) Actual) Average Weighted Weighted Average Fuel Cost (Rs./kWh) (Ref.) Average Weighted Korangi Thermal Power Station Thermal Power Korangi Fuel Cost Variation (Mln./Rs.) Fuel Cost Variation Number of Units Sent Out (Mln./kWh) Number of Difference (Rs./kWh) Difference Weighted Average Fuel Cost (Rs./kWh) (Ref.) Average Weighted Fuel Cost (Rs./kWh) Actual) Average Weighted Bin Qasim Power Plant Bin Qasim Power Fuel Cost - Gas (Rs./MMBTu) Fuel Cost - Furnace Oil (Rs./M/Ton) Fuel Cost - Furnace Total Fuel Cost Variation (Own Gen.+Power (Own Gen.+Power Fuel Cost Variation Total Pur.) Fuel Cost Variation of Power Pur. (Mil./Rs.) Pur. Power of Fuel Cost Variation Units Purchased Fuel Cost Variation (Mln./Rs.) Fuel Cost Variation Number of Units Sent Out (Mln./kWh) Number of Difference (Rs./kWh) Difference Weighted Average Fuel Cost (Rs./kWh) Actual) Average Weighted Weighted Average Fuel Cost (Rs./kWh) (Ref.) Average Weighted SITE Gas-II Fuel Cost Variation (Mln./Rs.) Fuel Cost Variation Number of Units Sent Out (Mln./kWh) Number of Difference (Rs./kWh) Difference Weighted Average Fuel Cost (Rs./kWh) Actual) Average Weighted Weighted Average Fuel Cost (Rs./kWh) (Ref.) Average Weighted Korangi Gas-II Korangi Difference (Rs./kWh) Difference Weighted Average Fuel Cost (Rs./kWh)(Actual) Average Weighted Weighted Average Fuel Cost (Rs./kWh) (Ref.) Average Weighted Korangi CCPP Korangi Source: Source:

208 State of Industry Report 2015 0.00 0.00 0.00 0.00 4.66 2.17 8.18 4.64 4.64 4.45 9.51 0.00 0.00 46.55 21.68 11.21 50.00 31.96 319.55 112.08 999.71 100.00 215.93 100.58 498.51 499.842 4751.12 5566.13 June 4.6 6.71 4.80 9.67 1.02 9.80 7.39 4.64 4.45 8.29 0.00 0.00 -0.07 -0.01 -0.49 45.63 93.12 49.59 34.79 44.84 471.09 330.44 949.88 100.00 211.66 414.18 3905.92 4576.11 May 4.6 6.71 4.13 1.54 0.19 7.46 7.14 4.64 4.45 8.47 0.00 0.00 -0.05 -0.01 -0.31 33.25 96.66 12.01 47.85 35.83 385.15 288.44 805.00 100.00 154.24 429.91 3262.84 3853.82 April 6.71 2.56 0.33 0.06 6.37 8.03 4.64 1.54 4.64 4.45 8.80 0.00 0.00 -0.07 -0.01 -0.49 14.50 36.13 40.87 50.16 67.25 231.80 284.50 567.19 100.00 160.70 2040.18 2269.18 March 6.71 5.38 2.96 0.72 4.64 4.64 4.45 6.76 0.00 0.00 6.09 -0.07 -0.02 -0.46 22.15 54.82 13.32 45.96 34.64 13.73 189.19 142.59 411.63 100.00 102.72 243.85 1278.20 1638.03 Feb. 6.71 9.99 1.48 2.88 2.31 0.34 4.64 6.87 4.64 4.45 7.55 0.00 0.00 6.97 -0.07 -0.02 -0.47 99.88 12.46 23.05 71.45 46.34 55.44 309.64 433.39 100.00 754.24 862.42 Jan. 6.71 0.52 4.02 2.15 0.11 4.64 2.42 4.64 4.45 0.00 0.00 9.04 -0.07 -0.01 -0.46 10.50 19.62 28.31 65.42 48.69 87.29 10.04 138.13 319.13 487.83 100.00 1386.75 1524.69 Dec. TABLE 93 TABLE 6.71 5.86 1.62 4.64 4.64 4.45 9.56 0.00 0.00 7.61 -0.07 -0.01 -0.45 36.30 10.03 66.92 28.98 52.74 10.81 46.53 179.46 326.63 619.27 100.00 168.38 297.64 Nov. 1715.96 2228.05 6.71 6.09 3.04 4.64 4.64 4.45 9.42 0.00 0.00 7.70 -0.07 -0.01 -0.46 48.57 24.28 84.13 36.47 43.85 10.55 Oct. 290.76 349.64 797.30 100.00 225.27 112.60 374.18 2737.56 3449.15 6.71 5.67 2.15 9.38 4.64 4.64 4.45 0.00 0.00 -0.07 -0.01 -0.50 48.12 18.26 79.52 44.06 38.75 84.71 12.54 10.29 373.62 328.59 848.04 100.00 223.17 353.67 Sept. 4684.03 5345.09 6.71 5.91 3.09 9.64 4.64 4.64 4.45 0.00 0.00 8.56 -0.07 -0.01 -0.47 51.04 26.70 83.19 44.03 37.33 10.26 380.16 322.32 863.35 100.00 236.74 123.86 370.01 Aug. 3901.41 4631.56 K-Electric Own Generation and Fuel Costs (2014-15) - Source-wise 6.71 5.92 3.59 8.11 4.64 4.64 4.45 0.00 9.92 0.00 -0.06 -0.01 -0.42 57.28 34.70 78.47 47.79 34.59 11.89 462.28 334.61 967.28 100.00 265.67 160.95 349.03 July 5498.35 6273.58 % % % % % % % GWh GWh GWh GWh GWh GWh GWh Mln.Rs. Mln.Rs. Mln.Rs. Mln.Rs. Mln.Rs. Mln.Rs. Mln.Rs. Rs./kWh Rs./kWh Rs./kWh Rs./kWh Rs./kWh Rs./kWh Rs./kWh

Fuel Cost Fuel Cost Fuel Cost Fuel Cost Fuel Cost Fuel Cost Fuel Cost

Generation Generation Generation Generation Generation Generation Generation

National Electric Power Regulatory Authority, Islamabad Authority, Regulatory Power National Electric

Qasim Qasim-II Thermal Gas-II Gas-II CCPP

Total

Bin Bin Bin Korangi Korangi SITE Korangi *Energy figures of each power station are worked out on the basis set target of Whole Generation Fleet’s Auxiliary Consumption. of Whole Generation Fleet’s target set out on the basis are worked station figures of each power *Energy by the Authority. as specified out on the basis of Heat Rates is worked station of each power Cost **Fuel with the Authority. is in process Station Power of this as the Heat Rate of Bin Qasim-II is not reflected Cost ***Fuel Rate. of its Heat to non-finalization due Fuel Cost total calculating the for while figures of Bin Qasim-II are not accounted ****Energy Source:

209 State of Industry Report 2015 5.59 0.81 6.63 7.35 2.70 0.12 1.02 1.13 5.86 8.33 7.25 7.25 4.63 83.11 77.60 17.61 70.38 12.75 11.90 55.20 41.12 10.12 10.45 6.146 458.79 651.90 100.00 127.64 841.27 811.01 2124.61 4006.71 June 0.24 7.09 5.98 6.12 0.04 1.05 0.88 1.61 8.09 5.59 6.61 6.61 5.41 8.72 9.63 80.20 74.92 41.51 69.03 11.83 11.05 57.35 33.44 6.372 467.84 677.77 100.00 274.50 699.06 721.43 May 2531.48 4318.87 0.96 7.42 5.57 5.71 0.15 1.13 0.85 6.31 7.01 5.58 6.56 6.56 7.07 8.05 8.89 78.16 75.30 37.46 68.74 11.93 11.49 52.03 31.05 7.352 450.54 655.41 100.00 245.85 629.03 669.48 3184.63 4818.38 April 1.13 7.91 6.09 9.00 6.87 0.17 1.21 0.94 7.29 7.38 5.58 6.44 6.44 6.01 8.27 9.50 6.60 66.04 58.55 44.70 71.66 10.15 58.36 33.97 466.27 650.69 100.00 287.99 546.19 556.10 2804.36 4294.26 March 1.19 7.56 5.61 9.62 5.55 0.21 1.31 0.97 6.91 6.59 5.57 5.82 5.82 4.57 7.26 7.79 5.27 55.69 58.95 32.10 72.17 10.18 49.80 31.25 417.73 578.81 100.00 186.70 404.44 459.21 Feb. 1909.52 3047.82 0.11 9.01 6.05 8.39 6.38 4.66 0.02 1.56 1.05 0.55 6.83 5.60 5.23 5.23 9.28 9.16 8.69 8.96 48.47 36.86 26.93 77.93 61.53 33.85 450.00 577.43 100.00 140.92 443.96 320.44 Jan. 4174.36 5175.62 0.64 9.19 6.18 8.74 7.03 4.29 0.11 1.60 1.08 3.93 8.63 5.58 6.15 6.15 6.29 7.12 50.15 40.36 24.60 77.15 79.29 34.51 11.36 11.49 442.65 573.77 100.00 151.38 569.58 463.71 Dec. 2784.34 4086.74 TABLE 94 TABLE 4.57 8.39 6.28 9.72 7.25 4.93 0.76 1.40 1.05 9.29 5.58 6.09 6.09 4.45 6.11 58.09 43.32 29.44 74.88 27.84 77.96 35.06 12.89 13.58 447.48 597.57 100.00 179.30 748.87 588.19 Nov. 1991.08 3648.30 7.17 8.28 5.94 9.51 7.60 7.13 1.15 1.32 0.95 5.58 6.58 6.58 7.07 8.39 59.48 47.50 44.61 72.34 47.17 87.65 33.17 10.59 14.23 15.64 452.47 625.45 100.00 293.56 846.62 742.77 Oct. 3197.46 5248.40 3.79 8.04 6.30 3.46 0.60 1.26 0.99 5.59 8.43 8.43 6.77 8.67 74.19 68.66 21.96 71.22 11.67 10.80 31.98 88.71 35.23 11.04 14.11 15.40 452.61 635.55 100.00 185.22 Sept. 3062.60 1046.90 1057.09 5507.73 0.18 7.31 7.23 4.78 0.03 1.13 1.12 1.35 5.58 7.46 7.46 6.77 8.51 74.79 66.10 30.99 71.19 11.55 10.20 80.24 40.36 10.98 14.07 14.88 461.18 647.79 100.00 231.21 983.49 Aug. 3124.01 1052.23 5512.90 K-Electric - Source-wise Power Purchases and Fuel Costs (2014-15) Purchases K-Electric Power - Source-wise 1.46 0.29 8.67 6.32 0.23 0.05 1.39 1.01 2.41 5.59 8.40 8.40 7.50 9.25 78.48 70.23 73.51 12.57 11.25 12.25 95.90 35.37 11.06 14.46 15.02 July 459.11 624.55 100.00 3441.13 1134.49 1054.94 5776.49 % % % % % % % % GWh GWh GWh GWh GWh GWh GWh GWh Mln.Rs. Mln.Rs. Mln.Rs. Mln.Rs. Mln.Rs. Mln.Rs. Mln.Rs. Mln.Rs. Rs./kWh Rs./kWh Rs./kWh Rs./kWh Rs./kWh Rs./kWh Rs./kWh Rs./kWh

Fuel Cost Fuel Cost Fuel Cost Fuel Cost Fuel Cost Fuel Cost Fuel Cost Fuel Cost Purchases Purchases Purchases Purchases Purchases Purchases Purchases Purchases

National Electric Power Regulatory Authority, Islamabad Authority, Regulatory Power National Electric Energy Ahmed Power

NTDC KANUPP PASMIC IIL Total

Tapal Tapal Gul Anoud Source: Source:

210 State of Industry Report 2015 - - - - 8.18 4.85 6.15 4.63 6.22 7.25 1.53 2.70 9.97 32.84 67.16 11.74 10.22 62.04 70.38 25.39 17.61 999.71 328.27 671.44 100.00 127.64 100.00 458.79 165.54 651.90 5561.35 3854.24 1707.11 June 4006.71 2124.61 1692.41 June - - - - 7.39 4.93 6.37 5.41 9.12 6.22 6.61 1.20 6.12 8.16 26.13 73.87 11.07 50.70 69.03 23.65 41.51 949.36 248.03 701.33 100.00 274.50 100.00 467.84 160.27 677.77 May 4573.59 2746.24 1827.35 May 4318.87 2531.48 1462.18 - - - - 7.46 4.85 7.35 7.07 8.41 6.03 6.56 1.31 5.71 8.55 31.10 68.90 10.23 51.57 68.74 24.24 37.46 805.00 250.32 554.67 100.00 245.85 100.00 450.54 158.86 655.41 3853.82 2561.76 1292.06 April 4818.38 3184.63 1336.34 April - - - - 8.03 4.94 6.60 6.01 8.78 6.10 6.44 1.44 6.87 9.38 25.43 74.57 10.99 57.19 71.66 20.03 44.70 567.19 144.26 422.93 100.00 684.22 287.99 100.00 466.27 130.34 650.69 2269.18 1584.97 4294.26 2804.36 1144.72 March March - - - - 6.09 9.65 4.93 5.27 4.57 7.49 5.84 5.82 1.53 5.55 8.86 66.10 16.06 83.94 51.75 72.17 20.75 32.10 411.63 345.53 100.00 638.21 999.82 899.85 186.70 100.00 417.73 120.13 578.81 Feb. 1638.03 Feb. 3047.82 1909.52 - - - - 6.97 9.83 4.98 8.96 9.28 8.81 5.94 5.23 1.49 4.66 8.62 50.71 11.70 88.30 51.20 77.93 15.91 91.88 26.93 433.39 382.68 100.00 862.42 498.54 363.88 809.13 140.92 100.00 450.00 577.43 Jan. Jan. 5175.62 4174.36 - - - - 9.04 4.92 7.12 6.29 6.44 6.15 1.63 4.29 9.33 92.25 18.91 81.09 12.45 11.22 60.08 77.15 16.94 97.19 24.60 487.83 395.58 100.00 376.46 151.38 100.00 442.65 573.77 Dec. 1524.69 1148.23 4086.74 2784.34 1090.93 Dec. - - - - 7.61 4.83 6.11 4.45 6.40 6.09 2.20 4.93 85.01 13.73 86.27 14.41 12.96 84.18 74.88 17.99 13.14 29.44 619.27 534.26 100.00 179.30 100.00 447.48 107.51 597.57 Nov. 2228.05 1224.85 1003.20 3648.30 1991.08 1393.74 Nov. TABLE 96 TABLE TABLE 95 TABLE - - - - 7.70 4.90 8.39 7.07 6.78 6.58 2.46 7.13 12.68 87.32 17.33 14.63 72.34 18.07 15.37 44.61 797.30 101.07 696.23 100.00 Oct. 104.27 293.56 100.00 452.47 113.00 625.45 3449.15 1751.24 1697.91 Oct. 5248.40 3197.46 1653.11 - - - - 4.88 8.67 6.77 7.44 8.43 1.93 3.46 25.09 74.91 10.29 18.08 14.58 91.42 71.22 23.40 12.28 21.96 848.04 212.77 635.27 100.00 185.22 100.00 452.61 148.69 635.55 5345.09 3847.63 1497.45 Sept. 5507.73 3062.60 2168.49 Sept. - - - - 8.56 4.92 8.51 6.77 6.76 7.46 18.91 81.09 16.99 1.45 4.78 9.41 14.32 63.62 863.35 163.23 700.11 100.00 71.19 22.57 30.99 231.21 4631.56 2773.49 1858.07 100.00 461.18 146.20 647.79 Aug. 5512.90 3124.01 2094.06 Aug. K-Electric - Fuel-wise Own Generation and Fuel Costs (2014-15) K-Electric - Fuel-wise Power Purchases and Fuel Costs (2014-15) Purchases K-Electric - Fuel-wise Power - - - - 9.92 4.90 26.82 73.18 17.13 9.25 7.50 7.12 8.40 1.44 0.23 8.98 1.46 967.28 259.42 707.86 100.00 14.57 63.96 12.25 73.51 24.82 July 6273.58 4443.58 1830.00 100.00 459.11 155.01 624.55 July 5776.49 3441.13 2259.15 % % % GWh GWh GWh % % % % % % Mln.Rs. Mln.Rs. Mln.Rs. Rs./kWh Rs./kWh Rs./kWh GWh GWh GWh GWh GWh GWh Mln.Rs. Mln.Rs. Mln.Rs. Mln.Rs. Mln.Rs. Mln.Rs. Rs./kWh Rs./kWh Rs./kWh Rs./kWh Rs./kWh Rs./kWh

Fuel Cost Fuel Cost Fuel Cost Generation Generation Generation

Fuel Cost Fuel Cost Fuel Cost Fuel Cost Fuel Cost Fuel Cost

Purchases Purchases Purchases Purchases Purchases Purchases

National Electric Power Regulatory Authority, Islamabad Authority, Regulatory Power National Electric Islamabad Authority, Regulatory Power National Electric Generation

RFO Gas

Total Total NTDC Coal RFO Gas Nuclear Total *Energy Figures of Bin Qasim-II are not accounted for while calculating the Fuel Cost as the Heat Rate of the said Power Station is in process with the Authority. is in process Station the said Power of for while calculating the Fuel Cost as Heat Rate not accounted Bin Qasim-II are of Figures *Energy Source: Source:

211 State of Industry Report 2015

0.81 6.63 7.35 0.00 0.00 0.00 17.61 83.11 77.60 46.55 21.68 27.78 60.53 39.47 458.79 328.27 171.57 319.55 112.08 328.27 651.90 671.44 999.71 June 1651.61

0.24 7.09 5.98 0.00 0.00 9.67 -0.05 41.51 80.20 74.92 45.63 93.12 28.74 58.36 41.64 467.84 248.55 222.51 330.44 248.55 677.77 701.33 949.88 May 1627.66

0.96 7.42 5.57 0.00 0.00 1.54 -0.05 37.46 78.16 75.30 33.25 96.66 30.85 55.12 44.88 450.54 250.32 134.83 288.44 250.32 655.41 554.67 805.00 April 1460.41

1.13 7.91 6.09 0.00 0.00 0.33 -0.07 44.70 66.04 58.55 87.55 14.50 36.13 38.29 46.57 53.43 466.27 144.26 284.50 144.26 650.69 422.93 567.19 1217.87 March

1.19 7.56 5.61 0.00 0.00 2.96 -0.07 32.10 55.69 58.95 66.10 22.15 54.82 66.10 42.18 41.56 58.44 417.73 123.08 142.59 Feb. 578.81 345.53 411.63 990.45

0.11 9.01 6.05 0.00 9.99 0.00 1.48 -0.07 26.93 48.47 36.86 50.71 49.18 12.46 50.71 44.52 42.87 57.13 450.00 309.64 577.43 382.68 433.39 Jan. 1010.82

0.64 9.19 6.18 0.00 0.00 0.52 -0.07 24.60 50.15 40.36 92.25 45.87 10.50 19.62 92.25 41.70 45.95 54.05 442.65 319.13 Dec. 573.77 395.58 487.83 1061.60

TABLE 97 TABLE 4.57 8.39 6.28 0.00 0.00 -0.07 29.44 58.09 43.32 85.01 94.45 36.30 10.03 66.92 85.01 36.77 50.89 49.11 447.48 326.63 597.57 534.26 619.27 Nov. 1216.84

7.17 8.28 5.94 0.00 0.00 -0.07 44.61 59.48 47.50 48.57 24.28 84.13 31.80 56.04 43.96 452.47 101.07 189.69 349.64 101.07 Oct. 625.45 696.23 797.30 1422.75 3.79 8.04 0.00 6.30 0.00 0.00 -0.07 21.96 74.19 68.66 48.12 18.26 79.52 30.51 57.16 42.84 452.61 212.77 160.86 328.59 212.77 635.55 635.27 848.04 Sept. 1483.59 0.18 7.31 0.00 7.23 0.00 0.00 -0.07 30.99 74.79 66.10 51.04 26.70 83.19 30.52 57.13 42.87 K-Electric - Source-wise Generation and Power Purchases (2014-15) Purchases K-Electric Generation and Power - Source-wise 461.18 163.23 216.92 322.32 163.23 647.79 700.11 863.35 Aug. 1511.13 1.46 0.29 8.67 0.00 6.32 0.00 0.00 -0.06 78.48 70.23 57.28 34.70 78.47 28.84 60.77 39.23 459.11 259.42 202.85 334.61 259.42 624.55 707.86 967.28 July 1591.83 National Electric Power Regulatory Authority, Islamabad Authority, Regulatory Power National Electric

Power Purchased at Bus Bar (GWh) Purchased Power KANUPP PASMIC Tapal Energy Tapal Gul Ahmed NTDC/WAPDA Anoud Power DHA Cogen. International Industries International Limited Total Power Pur. at Bus Pur. Power Total Bar (GWh) Own Generation Units Sent Out - FO (GWh) Bin Qasim-I Units Sent Out - Gas (GWh) Bin Qasim-I Bin Qasim-II Korangi Thermal Korangi Korangi Gas-I Korangi Korangi Gas-II Korangi SITE Gas-I SITE Gas-II Korangi CCPP Korangi Units S/Out - Gas Total (GWh) Total Units S/Out - FO Total (GWh) Total Units S/Out Total (GWh) Own Gen. Grand Total (GWh) Grand Total % of NTDC in Total NTDC in Total % of Units Sent Out % of Own Gen. in Total Own Gen. in Total % of Units S/Out % of Power Pur. in Pur. Power % of Units S/Out Total Source: Source:

212 State of Industry Report 2015 LIST OF TABLES TABLE 1 Primary Energy Supplies by Source (MTOE) TABLE 2 Final Energy Consumption by Source (MTOE) TABLE 3 Fuel Consumption for Thermal Power Generation (TOE) TABLE 4 Installed Generation Capacity by Type (MW) TABLE 5 Plant-wise Installed Generation Capacity (MW) as on 30th June TABLE 6 Installed Generation Capacity by Systems and by Sectors (MW) TABLE 7 Electricity Generation by Type (GWh) TABLE 8 Plant-wise Electricity Generation (GWh) TABLE 9 Electricity Generation by Systems and by Sectors (GWh) TABLE 10 Electricity Statistics of K-Electric Limited TABLE 11 Thermal Electricity Generation by Fuel (GWh) TABLE 12 Fuel Cost in GENCOs and K-Electric Limited TABLE 13 Fuel Consumption and Cost of Electricity Generation in GENCOs TABLE 14 Fuel Consumption and Cost of Generation Data - GENCOs TABLE 15 Fuel Consumption and Cost of Generation Data - K-Electric Limited TABLE 16 Fuel Consumption and Cost of Generation Data – IPPs TABLE 17 Auxiliary Consumption and other Factors of Hydel Power Stations TABLE 18 Auxiliary Consumption and other Factors of Public Sector Thermal Power Stations TABLE 19 Auxiliary Consumption and other Factors of K-Electric and Other Thermal Power Stations TABLE 20 Auxiliary Consumption and other Factors of Private Sector Thermal Power Stations TABLE 21 Main Electricity Statistics of the Country TABLE 22 Category-wise Energy Sales in PEPCO and K-Electric System (GWh) TABLE 23 Category-wise Consumers and their Electricity Consumption (%) TABLE 24 Hourly System Demand (MW) TABLE 25 Maximum Electricity Demand in the Country (MW) TABLE 26 Annual Growth Rate of Electricity Consumption TABLE 27 Surplus/Deficit in Demand and Supply during NTDC’s System Peak Hours TABLE 28 Surplus/Deficit in Demand and Supply during K-Electric’s System Peak Hours TABLE 29 Energy Generation by Sector and Source (GWh) TABLE 30 Thermal Electricity Generation by Sector and by Fuel (GWh) TABLE 31 Monthly Variation in Maximum Hydel Generating Capability (July, 2010 to June, 2015) (MW) TABLE 32 Nuclear Power Statistics TABLE 33 Installed and Available Capacity (MW) TABLE 34 Ongoing Projects and Expansion Plan of Hydel Power Generation TABLE 35 Investment Plan for Public Sector Power Generation Projects (as per approved PC-I) TABLE 36 Investment Plan for Power Generation Projects (KEL) (2015-16 to 2016-17) TABLE 37 Investment Plan for Private Sector Power Generation Projects TABLE 38 Detail of Renewable Energy Projects TABLE 39 Merit Order for Power Generation Plants (PEPCO System) (16-06-2014) TABLE 40 Merit Order for Power Generation Plants (K-Electric System) TABLE 41-A List of Generation Licensees (Hydel + Nuclear) TABLE 41-B List of Generation Licensees (Wind + Solar + Bagasse/Biomass) TABLE 41-C List of Generation Licensees (SPPs, CPPs, IGCs, N-CPPs, DGPs, STIPPs and other IPPs) TABLE 41-D List of Public and Private Sector Power Generation Licensees TABLE 41-E List of Generation Licensees (IPPs under Power Policy 1994) TABLE 41-F List of Generation Licensees (IPPs under Power Policy 2002) TABLE 41-G List of Transmission and Distribution Licensees TABLE 42 Electricity Import and Export by NTDC (GWh) TABLE 43 Transmission Lines and Grid Stations with NTDC TABLE 44 Unit Received, Delivered and Transmission Losses in NTDC System (GWh) TABLE 45 Utilization of Transmission Lines and Power Transformers in NTDC System TABLE 46 Transmission Lines Tripping in PEPCO and K-Electric System TABLE 47 Grid Station Expansion Plan of NTDC TABLE 48 Power Sector Investment Plan for NTDC Transmission Lines TABLE 49 Interconnection Arrangement to Evacuate Power from up-coming Power Projects

213 State of Industry Report 2015

TABLE 50 Transmission Lines and Grid Stations with K-Electric TABLE 51 Transmission/Sub-Transmission Losses in K-Electric System (GWh) TABLE 52 A: Amount Injected to Reinforce/Expand 220 and 132 kV Transmission System of K-Electric B: Investment Plan in Transmission Line (220 and 132 kV) of K-Electric TABLE 53 Loading Position of 500 kV Grid Stations of NTDC (2014-15) TABLE 54 Loading Position of 220 kV Grid Stations of NTDC (2014-15) TABLE 55 List of Licenses Issued to Distribution Companies TABLE 56 Service Area of Distribution Companies TABLE 57 Comparison of SAIFI and SAIDI of all Distribution Companies TABLE 58 Peak Demand of Distribution Companies (MW) TABLE 59 Category-wise Number of Consumers TABLE 60 Category-wise Sanctioned Load (MW) TABLE 61 Category-wise Electricity Sold (GWh) TABLE 62 Total Units Purchased, Sold and Losses TABLE 63 Units Billed and Amount Realized in DISCOs (2014-15) TABLE 64 Average Annual Electricity Consumption per Connection (kWh) TABLE 65 Distribution Losses (voltage category-wise) TABLE 66 Status of Distribution Lines (km) TABLE 67 Feeders Outages Statistics of DISCOs (2014-15) TABLE 68 Overloaded and Underutilized Distribution Feeders TABLE 69 Number of Circles, Divisions, Sub-Divisions and Feeders TABLE 70 Status of Grid Stations (Nos.) TABLE 71 DISCO’s Power Transformers, Capacities and Loading Positions of Power Transformers TABLE 72 DISCO’s Number of 11 kV Feeders and Loading Positions of 11 kV Feeders TABLE 73 DISCO’s Number of Distribution Transformers, Capacities and Loading Positions of Distribution Transformers TABLE 74 Village Electrification in all Distribution Companies TABLE 75 Applications of New Connections Received, Energized and Pending TABLE 76 Province-wise Electricity Consumption by Economic Groups (GWh) TABLE 77 Province-wise Electricity Consumption by Economic Groups (%) TABLE 78 NEPRA’s Monthly Fuel Price Adjustments in respect of DISCOs TABLE 79 Comparison of Proposed NEPRA Tariff (2014-15) TABLE 80 Statement of GOP Applicable (Notified) Tariff TABLE 81 Comparative Tariff Statement of Peshawar Electric Supply Company Limited (PESCO) TABLE 82 Comparative Tariff Statement of Tribal Area Electric Supply Company Limited (TESCO) TABLE 83 Comparative Tariff Statement of Islamabad Electric Supply Company Limited (IESCO) TABLE 84 Comparative Tariff Statement of Gujranwala Electric Power Company Limited (GEPCO) TABLE 85 Comparative Tariff Statement of Lahore Electric Supply Company Limited (LESCO) TABLE 86 Comparative Tariff Statement of Faisalabad Electric Supply Company Limited (FESCO) TABLE 87 Comparative Tariff Statement of Multan Electric Power Company Limited (MEPCO) TABLE 88 Comparative Tariff Statement of Hyderabad Electric Supply Company Limited (HESCO) TABLE 89 Comparative Tariff Statement of Sukkur Electric Supply Company Limited (SEPCO) TABLE 90 Comparative Tariff Statement of Quetta Electric Supply Company Limited (QESCO) TABLE 91 Monthly Source-wise Power Sent Out and Fuel Cost (2014-15) TABLE 92 K-Electric - Summary of Monthly Fuel Cost Adjustment (2014-15) TABLE 93 K-Electric - Source-wise Own Generation and Fuel Costs (2014-15) TABLE 94 K-Electric - Source-wise Power Purchases and Fuel Costs (2014-15) TABLE 95 K-Electric - Fuel-wise Own Generation and Fuel Costs (2014-15) TABLE 96 K-Electric - Fuel-wise Power Purchases and Fuel Costs (2014-15) TABLE 97 K-Electric - Source-wise Generation and Power Purchases (2014-15)

214 State of Industry Report 2015 ACRONYMS AND ABBREVIATIONS

ADB Asian Development Bank AEDB Alternative Energy Development Board AJKHEB Azad Jammu and Kashmir Hydel Electricity Board AMRS Automated Meter Reading System BPC Bulk Power Consumer BQCCPP Bin Qasim Combined Cycle Power Plant BQTPS Bin Qasim Thermal Power Station BTPL Bahira Town (Pvt.) Limited CCPP Combined Cycle Power Plant CDP Common Delivery Point CHASNUPP Chashma Nuclear Power Plant Ckt Circuit COD Commercial Operation Date CPGCL Central Power Generation Company Limited CPI Consumer Price Index CPP Captive Power Plant CPPA Central Power Purchasing Agency DISCO Distribution Company DOP Development of Power ECC Economic Coordination Committee ECNEC Executive Committee of the National Economic Council EHV Extra High Voltage ELR Energy Loss Reduction FBC Fluidized Bed Combustion FDI Foreign Direct Investment FESCO Faisalabad Electric Supply Company Limited GDP Gross Domestic Product GENCO Generation Company GEPCO Gujranwala Electric Power Company Limited GEs Gas Engines GOP Government of Pakistan GST General Sales Tax GTPS Gas Thermal Power Station GWh Giga Watt – hour HESCO Hyderabad Electric Supply Company Limited HFO Heavy Furnace Oil HPP Hydropower Project HSD High Speed Diesel HVDC High Voltage Direct Current IA Implementation Agreement IBC Integrated Business Centre ICB International Competitive Bidding IESCO Islamabad Electric Supply Company Limited IPP Independent Power Producers JPCL Jamshoro Power Company Limited KANUPP Karachi Nuclear Power Plant KCCPP Korangi Combined Cycle Power Plant KEL K-Electric Limited km Kilometer KTGTPS Korangi Town Gas Turbine Power Station KTPS Korangi Thermal Power Station kV Kilo Volt KVA Kilovolt Ampere kWh Kilowatt – hours 215 State of Industry Report 2015

LESCO Lahore Electric Supply Company Limited LPGCL Lakhra Power Generation Company Limited Ltr. Litre MEPCO Multan Electric Power Company Limited MMBTU Million British Thermal Unit MMCFT Million Cubic Feet MTOE Million Tonees of Oil Equivalent MVA Megavolt Ampere MW Megawatt MWh Megawatt – hour MYT Multi-year Tariff n.a. & n.p. Not available and not provided NCPP New Captive Power Plant NEPRA National Electric Power Regulatory Authority NGC National Grid Company NGPS Natural Gas Power Station NPCC National Power Control Centre NPGCL Northern Power Generation Company Limited NTDC National Transmission and Dispatch Company Limited O&M Operation and Maintenance OCPP Open Cycle Power Plant PAEC Pakistan Atomic Energy Commission PASMIC Pakistan Steel Mills Corporation PEPCO Pakistan Electric Power Company Limited PESCO Peshawar Electric Supply Company Limited PNRA Pakistan Nuclear Regulatory Authority PPA Power Purchase Agreement PPDB Punjab Power Development Board PPIB Private Power and Infrastructure Board PPP Power Purchase Price PSDP Public Sector Development Project QESCO Quetta Electric Supply Company Limited RFO Residue Furnace Oil SCADA Supervisory Control and Data Acquisition SCARP Salinity Control and Reclamation Project SEPCO Sukkur Electric Power Company Limited SGTPS Site Gas Turbine Power Station PHYDO Pakhtunkhwa Hydel Development Organization SPP Small Power Producer SPS Steam Power Station STG Secondary Transmission and Grid ST Steam Turbine SVC Static Var Compensators T&D Transmission and Distribution TCEB Thar Coal and Energy Board TESCO Tribal Area Electricity Supply Company Limited TOD Time of Day TOU Time of Use TPS Thermal Power Station UNDP United Nations Development Program USAID United States Agency for International Development VIBC Virtual Integrated Business Centre WB World Bank WPPO WAPDA Power Privatisation Organization

216 State of Industry Report 2015 SOURCE OF INFORMATION The following sources of information have been used in the compilation of this State of Industry Report 2015: i) Distribution Companies ii) K-Electric Limited iii) National Power Control Centre, NTDC iv) National Transmission and Dispatch Company Limited v) Pakistan Energy Yearbook, Hydrocarbon Development Institute of Pakistan vi) Private Power and Infrastructure Board vii) Alternative Energy Development Board viii) Power System Statistics, Planning Power, NTDC ix) Pakhtunkhwa Energy Development Organization x) Tariff Petitions submitted to NEPRA by Distribution Companies xi) Water and Power Development Authority xii) Others

217 State of Industry Report 2015

218

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