state of industry report 2015 - nepra.org.pk of industry... · 1 foreword the power sector is...

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State of Industry Report 2015

STATE OF INDUSTRY REPORT

2015

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CONTENTS

FOREWORD ........................................................................................................................................................ 1

1. OVERVIEW ............................................................................................................................................ 51.1 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 ...................................................................................... 152.1 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) ........................................................................152.4.2 Central Power Generation Company Limited (GENCO-II) ....................................................162.4.3 Northern Power Generation Company Limited (GENCO-III) ...............................................162.4.4 Lakhra Power Generation Company Limited (GENCO-IV) ....................................................162.4.5 Overall Performance of GENCOs ....................................................................................................162.4.6 Independent Power Producers (IPPs) ...........................................................................................172.4.7 Installed versus Dependable Capacity .........................................................................................172.4.8 Manpower to MW Ratio .....................................................................................................................17

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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 .................................................................................. 233.1 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 ...............................................................................................................263.3.2 Engro Powergen Qadirpur Limited................................................................................................263.3.3 Altern Energy Limited .........................................................................................................................263.3.4 TNB Liberty Power Limited ...............................................................................................................263.3.5 Habibullah Coastal Power Company Limited ............................................................................263.3.6 Foundation Power Company (Daharki) Limited .......................................................................263.3.7 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 ................................................................................... 354.1 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 ...................................................................................................................... 415.1 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

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5.10 Integrated Generation, Transmission and Distribution Plans (IGTDPs) ...........................................43

5.10.1 Development of IGTDPs ...................................................................................................................435.10.2 Evaluation/Review of IGTDPs by NEPRA .....................................................................................445.10.3 Recommendations for Resubmission of IGTDPs ......................................................................445.10.4 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 ......................................................................................................... 496.1 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) ............................................516.5.2 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 ...................................................................................................... 637.1 Market Structure ....................................................................................................................................................63

7.2 Creation of Central Power Purchasing Agency - Guarantee Limited (CPPA-G) ............................63

7.3 ModificationinTransmissionLicenceofNTDC .........................................................................................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) .............................................................................................647.7.2 Import of 100 MW (Polan – Gawadar) .........................................................................................647.7.3 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 ....................................................................657.8.2 On-Grid Projects ...................................................................................................................................667.8.3 Off-Grid Applications....... .....................................................................................................................66

8. MISCELLANEOUS ................................................................................................................................ 738.1 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

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9. Energy Sector Overview .................................................................................................................... 779.1 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 ..................................................................................................... 8310.1 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/DeficitinDemandandSupplyduringPeakHours(actualandprojected) ................ 119

11. ELECTRICITY GENERATION ............................................................................................................. 12311.1 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 ......................................................................................................... 15112.1 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 ........................................................................................................... 16513.1 General ...................................................................................................................................................................165

13.2 Function of Distribution Companies ..........................................................................................................166

13.3 Distribution System Performance ................................................................................................................166

14. ELECTRICITY TARIFF......................................................................................................................... 19114.1 Tariff Setting .........................................................................................................................................................191

14.2 Tariff Standards ...................................................................................................................................................191

LIST OF TABLES .............................................................................................................................................. 213

ACRONYMS AND ABBREVIATIONS ............................................................................................................. 215

SOURCE OF INFORMATION .......................................................................................................................... 217

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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, economicandfinancialprogressofthecountryforthepastmanyyears.TheGovernmentofPakistan’s(GoP)efforts for bringing new power generation plants through China-Pakistan Economic Corridor (C-PEC) Agreement reflectstherealizationthatthecountryisindireneedofenergyresourcestosatisfybaseloadrequirements.Similarly, overall generation mix is also planned to have renewable energy projects which will provide necessary diversificationandincreasedenergysecuritytothesector.TheintroductionofRe-GasifiedLiquidNaturalGas(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 evacuationproblemswiththeresultthatthecapacitiesofsomeofthemostefficientplantscannotbeutilizedto 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 deterioratedwhichisreflectedintheincreasednumberoffatalincidentsoverthepreviousyearinmostoftheDISCOs.

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 andAJK.Therecoveriesfromagricultureconnectionsalsoremainasourceofconstantinflowintothecirculardebt 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 NEPRAperformancestandards,thecrisesinK-ElectricterritoryinJune,2015haveprovedotherwise.ThefindingsofNEPRA’sfactfindingteamhavebroughtoutsomerealconcernsaboutthehealthofK-Electricsystem,theseissuesarerequiredtobeaddressedimmediatelywhichneedreasonableinvestmentspecificallyintransmissionand 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.


OVERVIEW 1

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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) ProjectThe 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 requirementsintheoveralldemandprofileofthecountryinthelongrun.Expensiveenergymixhasremainedone 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’ SupportThe 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 generationfacilities. 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 SheddingOwingtooverallmonitoringbytheMinistryofWaterandPowerandrealtimemonitoringofpowerflowsatthefeeder 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 GenerationDue 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)

Source Hydel Coal HSD RFO Gas Nuclear Import Iran Mixed Wind Solar Average

Basket Price2013-14 - 4.05 21.85 15.97 4.81 1.32 9.35 9.31 - - 10.592014-15 - 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 ProjectsThereductionincapitalcostsandtechnological improvementsinrenewableenergyhasreaffirmedNEPRA'sstance that such projects should be inducted with due consideration to these factors. NEPRA, in order to provide incentivestoinvestors,andtobuildtheirconfidenceandwithaviewtointroducingwindtechnologyinthecountry, 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 GENCOsThe performance of GENCOs has been a matter of concern for the regulator and an aggressive monitoring programhasbeeninitiatedforoverseeingGENCOs'regulatoryaffairs.Earlier,alltheGENCOswereadvisedbytheAuthoritytocarryoutperformancetestssothatdegradationintheiroperationalcapabilities,efficienciesand 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 NTDCUnder 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 kVtransformers,90areoverloaded,whichifnotrectifiedareapotentialthreattothereliableoperationofthesystem. It is imperative that NTDC besides strengthening of existing transmission network should ensure timely completionoftheplannedtransmissionrequirementsidentifiedforevacuationofpowerfromtheupcominggeneration projects.

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

Financial Year ending 30th June

NTDC Peak Demand (MW)

Capacity Addition per yearin NTDC System (MW)

Total Installed Capacityper year (MW)

2015 21,701 1,504 22,9282016 23,711 689 23,6172017 24,871 6,643 30,2602018 26,105 9,961 40,2212019 27,408 1,279 41,5002020 28,773 4,580 46,0802021 30,156 2,200 48,280

Source: NTDC

Ifnewgenerationasnotedaboveisaddedtothesystem,itisexpectedthatby2017,negligibledeficitwillbefaced 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 NTDCTo 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

Period of Report

500/220 kV Grids 220/132 kV Grids

Nos. MVA Capacity

Expected COD

*Estimated Cost (Rs. Million) Nos. MVA

CapacityExpected

CODEstimated Cost

(Rs. Million)New Grid Station

2015-16 3 3750 2016-17 20,399 8 5750 2016-17 26,2332016-17 1 1500 2019-20 3,500 - - - -

Extension2015-16 1 430 2016-17 697 - - - -

Addition/Reinforcement of Transformers at Overloaded Grid Stations2015-16 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 ProjectsIt 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.

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1.11 Power Balance of K-Electric SystemThefollowingtableshowsyear-wiseprojectedfiguresofpowerbalancesinrespectofK-Electrici.e.plannedgenerationcapability,projecteddemandgrowthrate,projecteddemandduringpeakhoursandsurplus/deficit:

Financial Year ending

30th June

Generation* Capability as per

K-EL (MW)

KEL's Projected Demand Growth

Rate (%)

KEL's Projected Demand during

Peak hours (MW)

Surplus/ (Deficit) (MW)

2015 2,632 - 3,056 -424

2016 2,752 (including 20 + 100 MW SNPC) 5.00 3,209 -457

2017 2,804 (including 52 MW FPCL) 5.00 3,369 -565

20183,674

(including 450 LNG + 420 Coal Conversion)

5.00 3,538 136

2019 4,374 (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: 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 PlantsInduction 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 DevelopmentThe 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 ReportingThe 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 reflectingthetruepicture.Inviewthereof,itisreiteratedandemphasizedthatallpowersectorentitiesshouldimmediately 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 ReformsThe 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 tosingle-buyer-plusmodeandfinallytoabilateralcontractmarket.Underthestructureofbilateralmarket,theCPPA 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 consideredaLicenseeProposedModification(LPM)byNTDCforrevisioninitstransmissionlicenseandcreationofanewentityasCPPA-G.NEPRAhasapprovedsuchmodification.CreationofCPPA-Gwillhelpprovidingenablingenvironmenttomovefromsinglebuyermodeltosinglebuyerplusmodelandfinallytothebilateralcontract mode.

1.16 Receivables of DISCOsThe 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 DISCOsDISCOs' performance in the area of losses, has been mixed. Certain DISCOs have reported very slightimprovement; 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 DebtCircular debt is still a major issue confronting power sector. One of the contributors of circular debt remained hightransmissionanddistributionlossesinDISCOs.Basedonthecurrentlynotifiedconsumer-endtariffof10th 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 authorityhassetanaveragelosstargetof15.29%for2014-15,whereasDISCOs'reportedlossesforthesameperiod 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-endtariffandtheGoPnotifiedtariffthroughimpositionofTariffRationalizationSurchargeonsomecategories 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 DISCOsAccordingtoNEPRATariffStandardsandProcedureRules,1998determinationofDISCOs'tariffrequiresaveryelaborate procedure to be followed. DISCOs are required to provide extensive information which is generally delayed. Furtherdelaysmayoccurduringnotificationof tariff.Conducting suchproceedingsannuallyhavebeenprovingtobeinefficient.Therefore,tostreamlinetheprocessandtoregulatetherevenuestreamsfortheentitiesinvolvedandfurthertobringin-builtincentivesandefficiency,NEPRAhasdecidedtore-introduceMYTregime. 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-ElectricIt 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 specifically650MW fromNTDCat theirmaximum. It isobserved that reservemarginsperinternational 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.

TheloadingprofileofEHTnetworkduringJune2015,showsthatoutofatotal129powertransformers,45are 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 TariffsUnder 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 thattechnology.Theregime,besidesprovidingpredictabilityandlevelplayingfieldforallinvestors,willalsoallow 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 RegimePakistan 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 introduceafinancialpackagetofacilitatehouseholdconsumersashasbeendoneinthecaseofsolartubewellschemes.

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 kVlines/networksinthespecifiedserviceterritoryofthatDISCOasperprovisionsunderSection20and21ofthe Act. Therefore, no entity can engage in the distribution regime except a DISCO. However, under Section 19

11


of the Act, the Authority granted a Special Purpose Transmission Licence (SPTL) to a private entity to engage in construction,ownership,maintenanceandoperationofspecifictransmissionfacilities(66kVandabove)builtfor 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 RecommendationsIn 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 powergenerationprojects,specificallythroughChina-PakistanEconomicCorridorisensured.

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-sourcingofinefficientserviceindistributionsystemmaybeexploredandconsidered by theDISCOs.

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PERFORMANCE OF GENERATION SECTOR 2

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2. PERFORMANCE OF GENERATION SECTOR

2.1 GeneralTheinstalledgenerationcapacityoftheNTDC'ssystemon30th 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 connectedwithNTDC'ssystemgenerated97,284GWhofenergyduringtheyear2014-15,whileoverthesameperiod during 2013-14, 93,903 GWh were produced; an increase by 3,381 GWh or 3.60%. During July, 2014 to June2015,themajoradditionstoinstalledcapacityofNTDC'ssystemareGuddu(747MW)andNandipur(425MW)thermalpowerplants.Inaddition,320MWhavebeenaddedtoNTDC'ssystemthroughrenewableandalternative energy (Solar, Wind and Bagasse) based power plants during 2014-15.

2.2 Source-wise Installed CapacityThe following table gives additional details of installed capacity and energy generation by different power plantsconnectedwithNTDC'ssystemandcomparisonoflasttwoyears:

SourceInstalled Capacity

(MW)Generation

(GWh)Variation

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 HydropowerIt 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 ThermalOn 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 lastyear.NetelectricalefficiencyofGENCO-Iduring2014-15stoodat28.30%.Withacapacityutilizationof

16


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 annualefficiencyof33.95%andcapacityutilizationofonly32.43%,theoverallperformanceofGENCO-IIhasbeen 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.

ItisobservedthatvariousunitsofGENCO-IIIhaveremainedoff-barsincelongduetotheirpoorefficiencylevels.TheoverallnetefficiencyofGENCO-III isalsovery lowat24.84%.Furthermore,duetovariousmaintenanceissues, 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 isavailableforgeneration,whichalsoisnotbeingfullyutilizedduetoforcedoutagesetc.Withnetefficiencyof17.74%, the overall performance of GENCO-IV has not remained satisfactory.

2.4.5 Overall Performance of GENCOsItisnotedthat,althoughthetotalinstalledcapacityofGENCOs'powerplantshasincreasedby1,172MWduringthe2014-15(includingefficientmachinesatGuddu),ascomparedwiththecapacityof thesepowerstationsduring theyear2013-14, the impactof increasedcapacityofGENCOspowerplants isyet tobe reflected inthe 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 furnaceoilinventoryatthefiveplantssuppliedbyPSO(Muzaffargarh,Jamshoro,KAPCO,HUBCOandNandipur)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.

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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 CapacityThe ratios between the dependable capacity and the installed capacity of the four GENCOs are also noted here:

Ratio of Dependable Capacityand Installed Capacity

GENCO-I(JPCL)

GENCO-II(CPGCL)

GENCO-III(NPGCL)

GENCO-IV(LPGCL)

2013-14 0.81 0.70 0.78 0.20

2014-15 0.81 0.80 0.80 0.20Source: 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 RatioThe 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.

S.No.

Power Plant LocationInstalled Capacity

(MW)No. of

EmployeesManpower

to MW ratio

Capacity Utilization

(%)

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

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2.5 Nuclear (CHASNUPP-I and II)During the year 2014-15, total installed and dependable capacity of Nuclear power plants connected with NTDC'ssystem,arenotedas650MWand615MWrespectively,whicharethesamefortheyear2013-14.Theenergy 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 withNTDC'ssystemhasremainedsatisfactoryduringtheyear2014-15asnomajoroutageisnoted.

2.6 WindDuring2014-15,totalinstalledcapacityofwindpowerplantsconnectedwithNTDC'ssystem,isnotedas256MW, 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 BagasseDuring 2014-15, three new bagasse based power plants (JDW-II, JDW-III and RYKML) have been connected withtheNTDC'ssystemhavingtotalinstalledcapacityof70MW,while,therewasnobagassebasedgeneratingfacility during the year 2013-14. The energy generated by these power plants, during the 2014-15 is noted as 308 GWh.

2.8 SolarDuring2014-15, 100MWoffirst solarpowerproject (Quaid-e-AzamSolar)hasbeenadded to theNTDC'ssystem, contributing 28 GWh.

2.9 K-Electric LimitedAs 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 1,034.79Source: K-Electric Limited

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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 685Source: 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 generationfacilitiesandotherresourcesspecifically650MWfromNTDCattheirmaximum.Itmayalsobenotedthat the contract of power supply between NTDC and K-Electric has already expired, however, the power is still being imported out of necessity.

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PERFORMANCE OF TRANSMISSION SECTOR

PERFORMANCE OF TRANSMISSION SECTOR 3

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3. PERFORMANCE OF TRANSMISSION SECTOR

3.1 GeneralThe 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 22,745Source: 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 TransformersAs discussed earlier, the transmission system is critical for a reliable power supply to DISCOs. The following table showsoverloaded(above80%)transformersat500kVand220kVgridstationsindifferentregionsdefinedbyNTDC. 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.....

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(above 80%)

(above 80%)

Source: NTDC

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

Continued.....

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(above 80%)

Continued.....

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Shikarpur

T-1 220/132 160 700 660 94.29 T-2 220/132 160 700 640 91.43 T-3 220/132 160 700 640 91.43

T.M.K. Road

T-1 220/132 160 700 690 98.57 T-2 220/132 160 700 680 97.14

Khuzdar T-1 220/132 160 700 680 97.14

(above 80%)

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 NetworksIn addition to overloading of EHV transformers, constraints in power dispersal from certain major power plants andqualityissuesinNTDC'ssystemhavealsobeenreported.AsperinformationanddatareportedtoNEPRA,following power plants faced evacuation problems due to transmission constraints.

3.3.1 Uch-II Power (Pvt.) LimitedUch-IIisalowBTUGasfiredpowerplanthavinggrosscapacityof404MWandnetcapacityof375.2MWlocatedat 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 dispersalproblems, 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 LimitedEngro 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 LimitedAltern 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 LimitedThe 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 LimitedThe 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) LimitedAs 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

27


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 efficientsolution.

3.3.7 Nishat Power Limited and Nishat Chunian Power LimitedBoth 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 PlantsThe following table provides yearly additions in the generation capacity as planned under different initiatives by the federal government and private sector:

Sr.No. Name of the Project Location Installed

Capacity (MW)Commissioning

DateAddition during Fiscal Year 2015-16

1 Sapphire Wind Power Company Limited Jhampir, Sindh 49.5 October, 20152 Appolo Solar Development Pakistan

Limited (Zonergy)Lal Sohanra, Cholistan, Punjab

100 December, 2015

3 Best Green Energy Pakistan Limited (Zonergy)

Lal Sohanra, Cholistan, Punjab

100 December, 2015

4 Crest Energy Pakistan Limited (Zonergy) Lal Sohanra, Cholistan, Punjab

100 December, 2016

5 CHASNUPP-III Chashma, KPK 340 March, 2016Addition during Fiscal Year 2016-17

6 Elbel Green Energy Pakistan Limited (Zonergy)


100 July, 2016

7 Flare Solar Development Pakistan Limited (Zonergy)


100 July, 2016

8 Golden Eye Solar Development Pakistan Limited (Zonergy)


100 July, 2016

9 Yunus Energy Limited Jhampir, Sindh 50 July, 201610 Metro Power Company Limited Jhampir, Sindh 50 July, 201611 Tenaga Generasi Limited Gharo/Bhambore/

Kuttikun, Sindh49.5 July, 2016

12 Gul Ahmed Energy Limited Jhampir, Sindh 50 July, 201613 Master Wind Energy Limited Jhampir, Sindh 49.5 July, 201614 HydroChina Dawood Power Limited Gharo/Bhambore/

Kuttikun, Sindh49.5 July, 2016

15 Tapal Wind Jhampir, Sindh 30 July, 201616 United Energy Pakistan Limited Jhampir, Sindh 99 July, 201617 Zephyr Power (Pvt.) Limited Gharo/Bhambore/

Kuttikun, Sindh50 July, 2016

18 Neelum Jhelum Hydel Nauseri/Muzaffarabad, AJK

969 November, 2016

19 CHASNUPP-IV Chashma, KPK 340 December, 201620 High Flying Solar Development Pakistan

Limited (Zonergy)Lal Sohanra, Cholistan, Punjab

100 January, 2017

21 Indigo Solar Development Pakistan Limited (Zonergy)


100 February, 2017

22 King Rider Solar Development Pakistan Limited (Zonergy)


100 February, 2017

23 Tarbela 4th Ext. Project Tarbela, KPK 1,410 March, 201724 Patrind HPP Kunhar River, AJK 147 April, 2017

Continued.....

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Sr.No. Name of the Project Location Installed

Capacity (MW)Commissioning

Date25 LNG Based Plants (Phase-I) Bhikki/Baloki, Punjab 2,400 April, 201726 Solar Power Plants near Chishtian Chishtian, Punjab 300 June, 2017

Addition during Fiscal Year 2017-1827 Keyal Khwar Dasu District, KPK 128 October, 201728 Coal Plant at Sahiwal Sahiwal, Punjab 1,320 December, 201729 Port Qasim Power Plant Port Qasim Karachi,

Sindh1,320 December, 2017

30 Engro Thar Coal (Unit-1) Thar, Sindh 330 December, 201731 Nooriabad Gas Plant Nooriabad ,Sindh 100 December, 201732 Hub Power Company Limited Hub, Balochistan 660 December, 201733 Other Wind Power Plants Jhampir/Gharo/Bhambore/

Kuttikun, Sindh973 December, 2017

34 Engro Thar Coal (Unit-2) Thar, Sindh 330 April, 201835 LNG Based Plants (Phase-II) Haveli Bahadur Shah,

Jhang, Punjab1,200 April, 2018

36 Coal Plant at Salt Range Salt Range, Punjab 300 June, 201837 Tarbela 5th Ext. Project Tarbela, KPK 1,320 June, 201838 Hub Power Company Limited Hub, Balochistan 660 June, 201839 SSRL Thar, Sindh 1,320 June, 2018

Addition during Fiscal Year 2018-1940 Golen Gol HPP Chitral, KPK 106 July, 201841 Siddiqsons Energy Limited Port Qasim, Sindh 350 June, 201942 Lucky Electric Power Company Ltd. Port Qasim, Sindh 660 June, 201943 Grange Holding Arifwala, Punjab 163 June, 2019

Addition during Fiscal Year 2019-2044 CASA Cross Border

Interconnection1,000 July, 2019

45 Gulpur Poonch River Poonch River/Gulpur, AJK

100 October, 2019

46 TPS Jamshoro (Phase-1) Jamshoro, Sindh 660 December, 201947 TPS Jamshoro (Phase-2) Jamshoro, Sindh 660 March, 202048 Dasu HPP-1 7 km upstream of Dasu

Village on Indus River, KPK2,160 June, 2020

Addition during Fiscal Year 2020-2149 Karachi Coastal Power Plant (Unit-1) Karachi, Sindh 1,100 August, 202050 Karachi Coastal Power Plant (Unit-2) Karachi, Sindh 1,100 June, 2021

Addition during Fiscal Year 2021-2251 Suki Kinari HPP Kunhar River/

Mansehra, KPK840 September, 2021

52 Karot HPP Jehlum River, Distt. Rawalpindi, Punjab

720 June, 2022

53 Kotli HPP Poonch River/Kotli, AJK 100 June, 202254 Azad Pattan HPP Jehlum River/Sudhnoti, AJK 640 June, 202255 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 TotalSindh 49.50 477.50 4,373 1,010 1,320 2,200 660 10,090Punjab 300 3,300 2,820 163 0 0 720 8,303Khyber Pakhtunkhwa 340 1,750 1,448 106 3,160 0 840 6,644Balochistan 0 0 1,320 0 0 0 0 1,320AJK 0 1,116 0 0 100 0 740 1,956Total 689.50 6,643.50 9,961 1,279 4,580 2,200 2,960 28,313

Source: NTDC

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3.5 Future NTDC NetworkAs 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 thenewpowergeneration.ThefollowingfigureshowsNTDC'sEHVtransmissionsystemplanneduptoyear2021-22.

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3.6 NTDC Financial PlansNTDC 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

S. No.

DescriptionCompletion

YearNo. of

Projects

EstimatedCost

Financing Arranged

Financing Required

Mil. Rs. Mil. US$ Mil. Rs. Mil. US$ Mil. Rs. Mil. US$

1 Short Term Plan (Ongoing Projects) 2015-16 22 94,249 1,174 89,419 1,127 4,830 47

2Medium Term Plan (Projects Ready for Implementation)

2016-17 21 106,017 1,153 47,373 557 58,664 596

3Long Term Plan(Future Development Projects)

2019-20 21 141,882 1,391 51,000 500 90,882 891

Total 64 342,148 3,718 187,792 2,184 154,356 1,534Source: 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:

S. No.Voltage Level

(kV)Addition in Transformation Capacity (MVA) Addition in

Transmission Line (km)New Augmentation Total

1 500 4500 300 4800 549

2 220 6050 900 6950 687Source: 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 transmissionlinesisalsobeexpectedunderlongtermplanforwhichUS$500millionwillbefinancedbytheWorldBankandJICA.RemainingfinancingrequirementofUS$891millionnotyetarrangedforlongtermplan.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 SystemBased 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

Overhead Lines

220 kV 321 321 323 323 323

132 kV 611 611 611 611 611

66 kV 149 149 149 149 149

Underground Lines

220 kV 17 17 15 15 15

132 kV 150 150 150 150 151

66 kV 0 0 0 0 0Source: K-Electric Limited

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It may be noted that only 2 km of 220 kV overhead transmission lines have been added by K-Electric over the fiveyears,whereastheunderground220kVlineshavebeenreducedby2km.Only7kmof132overheadlinesand 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 Stations

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

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 69Source: 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.

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PERFORMANCE OF DISTRIBUTION SECTOR 4

35


4. PERFORMANCE OF DISTRIBUTION SECTOR

4.1 Constraints in DISCOs’ SystemDISCOs have constraints in their network which restrict their ability to supply power from their 132 kV network to11kVsystem.SuchconstraintsinDISCOs'systemhavetakenthebackseatuptillnow,howevertheseareinfact 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)

DISCOsTotal No. of

Grid StationsTotal No. of Power

Transformers

Total Capacity of Power Transformers

(MVA)

No. of Power Transformers Overloaded (Above 80%)

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 708Source: 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:

Province

11 kV Feeders Distribution TransformersNo. of11 kV

Feeders

No. ofOver-Loaded

Feeders%

No. ofDistribution Transformers

No. ofOver-LoadedTransformers

%

Punjab 5,291 1,465 27.59 441,932 57,672 13.05Sindh 854 198 23.18 71,555 8,961 12.52Khyber Pakhtunkhwa 1,029 526 51.12 75,280 38,792 51.53Balochistan 570 85 14.91 51,886 8,282 15.96Total 7,744 2,274 29.36 640,653 113,707 17.75

Source: DISCOs

4.2 Receivables of DISCOsThe 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:

36


Break-up of Receivables of DISCOs Financial Year ended June, 2015 (Rs. in Billion)

S. No.

CategoryReceivables (FY ended

June, 2014)

July, 2014to June, 2015

Receivables (FY ended

June, 2015)Billing Collection

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 1013.919 894.136 633.119Source: PEPCO

4.3 Transmission and Distribution (T&D) Losses of DISCOsDISCOs'lossesremainedalmostatthesamelevelasforpreviousyear,ratheranumberofDISCOshavereportedhigher losses than earlier years.

DISCOs' Losses (2014-15)PESCO TESCO IESCO GEPCO LESCO FESCO MEPCO HESCO SEPCO QESCO

Targets set by the Authority (%) 26.00 22.31 9.44 9.98 11.75 9.50 15.00 20.50 27.50 17.50

Actual Results of DISCOs (%) 34.81 21.68 9.41 10.72 14.10 11.03 15.50 27.08 38.29 23.10

Source: NEPRA/DISCOs

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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 remainedaround89.16%forthefinancialyear2014-15.

4.4 Circular DebtCircular debt is still a major issue confronting power sector. One of the contributors of circular debt remained hightransmissionanddistributionlossesinDISCOs.Basedonthecurrentlynotifiedconsumer-endtariffof(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 theAuthorityhassetanaveragelosstargetof15.29%forthefinancialyear2014-15,whereasDISCOs'reportedlosses for the same period remained around 18.73%.

4.5 Tariff Differential SubsidyGoP 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-endtariffandtheGoPnotifiedtariffthroughimpositionofTariffRationalizationSurchargeonsomecategories 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 SystemAccording 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:

Year Sept. 2008 2008-09 2009-10 2010-11 2011-12 2012-13 2013-14 2014-15 Total

Addition per year --- 88 93 74 35 20 47 53 410

Total Feeders 1,021 1,109 1,202 1,276 1,311 1,331 1,378 1,431

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,damagetoPoleMountedTransformersandfireincidentsinthegridstations.Suchbehaviorofthe 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 WebsiteThe Authority decided that all DISCOs and K-Electric will upload their Performance Reports on their website, onquarterlybasisforawarenessandinformationofallstakeholdersandtofulfilltherequirementsofdonoragencies. 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.

38


INITIATIVES BY NEPRA 5

41


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 ProjectsNEPRA 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, havingaggregate installedcapacityof430.30MW,wereable toachievefinancial closewithin thespecifieddeadline 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 12.5186Source: NEPRA

5.2 Upfront Tariff for New Bagasse based Co-Generation Power ProjectsIn order to facilitate co-generation power projects, NEPRA announced Upfront Tariff for new bagasse based co-generation power projects on 29thMay,2013whichwassubsequentlymodifiedon28th August, 2013.

Upon expiry of applicability period on 28th May, 2014, the Authority extended the validity of reference Upfront Tariff up to 28thMay,2015.TheapplicationforacceptanceofUpfrontTarifffiledbyHamzaSugarMillsLimited(15 MW) was processed and the decision was issued on 12th September, 2014.

5.3 Upfront Tariff for Coal Power ProjectsInduction 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, havingoneofthelargestreservesofligniteintheworld,whichisspecificforinvestorsinusingTharCoalbyoffering them relatively more attractive terms.

The Authority announced the following Upfront Tariffs for imported/local coal based power plants on 26th June, 2014forvariouscategoriesfor30yearswhichwasnotifiedvideSRONo.942(I)/2014dated5th October, 2014:

Capacity (MW)

Levelized Tariff (US Cents/kWh)

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 8.0189Source: NEPRA

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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 for30years,notifiedvideSRONo.51(I)/2015dated20th January, 2015:

Capacity (MW)Levelized Tariff (US Cents/kWh)

Local Financing Foreign Financing

330 9.5643 8.5015

660 9.5668 8.3341

1100 9.1368 7.9889Source: NEPRA

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

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

S. No. Company Capacity(MW)

Levelized Tariff(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 863Source: NEPRA

5.5 Upfront Tariff for Solar Power ProjectsNEPRA also approved Upfront Tariff for Solar Power Projects during the year for various categories for 25 years whichwasnotifiedvideSRONo.183(I)/2015dated3rd March, 2015:


North Region South Region

>1≤20MW 15.0279 14.4096

>20≤50MW 14.8953 14.2825

>50≤100MW 14.7588 14.1516Source: 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 ProjectsNEPRA determined the generation tariff in matter of upfront tariff for Small Hydropower Generation Projects upto 25 MW installed capacity on 2nd April, 2015:

43


Levelized Tariff100% Foreign Financing

(Rs./kWh)100% Local Financing

(Rs./kWh)Low Head (1-25 MW) 8.3194 10.8941High Head (1-25 MW) 7.6177 9.9960

Source: NEPRA

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


Local Financing Foreign FinancingLNG HSD LNG HSD

225 10.5541 16.8757 10.1767 16.4983400 9.9604 15.7785 9.5392 15.3572800 9.7797 15.5099 9.3628 15.0930

Source: NEPRA

5.8 Tariff for Short-Term IPPsNEPRA 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 3Tariff (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

Inordertoencourageandpromoterenewableenergy inPakistan,specificallysolarandwind, theAuthoritydecided 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.

44


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 NEPRAThe 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 providedbytheDISCOstoNEPRAaspartoftheirAnnualReportsarenottruereflectionoftheirperformance 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 usedandload-flowstudieshavebeencarriedouttodevelopexpansionplansfor132kVnetworkwhich 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 studieswithout 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 IGTDPsIn 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’sPerformanceStandardIndicesandvoltageprofilesinthearea.

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 villageseveryyearwhichononehandmaynotbefinanciallyviableandwouldcertainlyleadtomorelosses. It is important to include such schemes for review of the Regulator.

45


5.10.3.4 Power Market Survey (PMS) needs to be updated and load growth is also required to be mapped at thesub-divisionlevel.Theloadflowstudieswillprovidethebasisforexpansioninthe132kVsystemalong 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 NEPRAA 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,maintenanceandoperationofspecifictransmissionfacilities(66kVandabove)builtforprovisionof 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, 2015As 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.

Inadditionoftheaboveguidelines,NEPRAformulatedtheinterconnectionguidelineswhichprovideaunifiedapproach about construction of interconnection facilities with the networks of NTDC and DISCOs.

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MONITORING OF THE SECTOR 6

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6. MONITORING OF THE SECTOR

6.1 Visits of DISCOs to Verify/Inspect the Sanctioned Load vis-a-vis Connected LoadDuringthereportedperiod,NEPRAprofessionalsvisiteddifferentDISCOsforverificationofthesanctionedloadviz-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 MonitoringIn 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-ElectricThe 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 gridswerealsocheckedandfieldsurveyswereconducted.Duringthevisit,certaingridstationsofK-Electricwere found in poor conditions lacking proper maintenance.

6.4 Safety Record of Distribution CompaniesThesafetyaspectisconsideredasoneofthemostimportantparametersforjudgingDISCOs'performance.Thefollowing 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.

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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 4Source: DISCOs

6.5 Annual Performance Report (APR) of NTDCAs 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 fiveyearsi.e.from2010-11to2014-15.

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 voltagelimitsrevealthevoltageprofilefor220kVSibbiandKhuzdarGridStationsremainedaslowas180kVand 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.

0

5

10

15

20

25

30

35

40

45

50

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

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

DISCO-wise Number of Safety Accidents

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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

Normal

Islamabad 14,081 13,413 24,065 22,539 30,165

Lahore 20,570 44,172 57,363 55,990 68,552

Multan 713 182 1,660 1,560 1,439

Hyderabad 17,014 20,754 26,347 43,973 28,958

N-1

Islamabad 4,677 1,788 3,215 2,906 1,914

Lahore 1,878 5,980 7,730 11,545 11,684

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 92,530 130,046 140,612 149,381Source: NTDC

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

0

25,000

50,000

75,000

100,000

125,000

150,000

Region-wise Voltage Variations Violating Prescribed Criteria [Nos.]

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

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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 32,079Source: 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


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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 1,439Source: 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


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6.5.2 System FrequencyThe 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 Hertzto58.63HertzPrimafaciecontraveningRule8ofthePSTR,2005.Thefollowingtablesandfiguresshowthesystemfrequencyprofile.

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

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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

6.6 Annual Performance Report (APR) of K-ElectricThe 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 PerformanceStandardsTransmissionRules(PSTR,)2005.ThefollowingtablesandfiguresshowK-Electricsystemfrequencyprofilealongwithacomparisonwiththeprecedingyears.

NTDC Lowest System Frequency

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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 49.32Source: K-Electric

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 50.52Source: K-Electric

50.00

50.50

51.00

51.50

52.00KE Highest System Frequency

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

57


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 SystemThefollowingtableandfiguresshowtheenergynotservedintheK-Electricsystemforthelastfiveyearsi.e.from 2010-11 to 2014-15.

S. No. Name of CircuitYear-wise Overall System Energy Not Served (MWh)

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

46.00

46.50

47.00

47.50

48.00

48.50

49.00

49.50KE Lowest System Frequency

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

Continued.....

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S. No. Name of CircuitYear-wise Overall System Energy Not Served (MWh)

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 5,460Source: K-Electric

6.8 Frequent Tripping of Transmission and Grid System in NTDCDuringthereportedperiod,NTDC'sinvestmentsandO&Mexpenditureoverlastfiveyearswereevaluatedtoknowitspriorities.Specifically,informationwasobtainedtoconfirmthatNTDCinvestedonthosegridswhereheavy 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'sfollowinggridstationsofIslamabadRegiontomonitortheprecautionarymeasurestakenbyNTDCinthis regard:

220 kV Burhan Grid Station November 13, 2014220 kV University Grid Station November 14, 2014500 kV Rawat Grid Station November 14, 2014

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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 NTDCDuring 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) 2009The 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 CodeNTDC 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 inductionandabsorptionofrenewableenergyprojects,specificallywindandsolarsothatthereisnoadverseeffectontheoperationandperformanceofNationalGrid.However,thedelayedfinalizationofthestudybyNTDC is hindering further progress in this area.

6.12 Implementation of Distribution CodeFor 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.

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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 CodeAs 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 firstdraftofPowerSafetyCodeforTransmissionandDistributionLicenseeswasuploadedonNEPRA’swebsiteandsenttoalltheconcernedstakeholdersaswellfortheircommentsbeforefinalizingit.

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.

INITIATIVES BY STAKEHOLDERS 7

63


7. INITIATIVES BY STAKEHOLDERS

7.1 Market StructureThe 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 efficiencythroughtransparentsettlementofpowersectorduesandbuildindustrystandardstomanagethepower sector business.

7.3 Modification in Transmission Licence of NTDCPursuant 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.

NTDCsoughtamodificationtotheArticle7and8ofitsTransmissionLicencethroughaLicenseeProposedModification(LPM)forseparatingtheprocurementofpoweronbehalfofDISCOsandthesettlement,fromthenetwork 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.

NEPRAafterfollowingthedueprocessunderitslawhasapprovedmodificationinNTDClicenseandFederalGovernment 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, 2015NEPRA 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 Affairs7.4.2 Accounting Practices and Audit7.4.3 Maintenance of Records

Apreliminarydesignofpowermarketalongwithtimelinestowardsacompetitiveregimeisalsospecifiedinthedocument that will substitute the existing single buyer arrangement in the sector.

64


7.5 PPIB Policy for Private Sector Transmission Projects 2015A 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 decidedtosolicitproposalsfromtheprivatesectorforinvestmentinthefieldofACandDCExtraHighVoltage(EHV) Power Transmission Lines, Substations, and Converter Stations.

7.6 Central Asia-South Asia (CASA-1000) ProjectThe 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). ThisprovidesflexibilityforPakistantoabsorbupto1300MW,shouldAfghanistannotneedtoimportitsentireshare.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 thereshouldbea“MasterAgreement”(MA)andfiveindependentPPAstoestablishthecontractualrelationshipamong the parties.TheMAandPPAsbetweenNTDCandtransmissionentitiesofsellers(TajikistanandKyrgyzstan)werefinalizedinthefirstweekofApril,2015andsignedon24th 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 30yearsandtheTariffatUScents6.25/kWh.ExportDevelopmentBankofIranwillfinance70%andremaining30%willbefinancedbyNTDC’soutofitsownsources.220kVdoublecircuitTransmissionLineand220kVGISgrid 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.

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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 forfinancing theHVDC InterconnectionProject cost in itsown territory (approximatelyUS$265million)sideforthisproject.ThepartiesagreetofinancetheHVDCInterconnectionProjectforPakistaniside(approximately US$ 435 million), as follows:

7.7.3.4 70%which is approximatelyequals toUS$300millionwillbearrangedandfinancedby IranianFinancial Institutions.

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

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

PPAisrequiredtobefinalizedwithTavanirtoinitiatefurtherprogressontheProject.

7.8 Alternative and Renewable Energy DevelopmentsThe GoP is promoting the use of Alternative and Renewable Energy (ARE) technologies in order to diversify itsenergymixsoastoensureEnergySecurity,EconomicBenefits,SocialEquityandEnvironmentalProtection.AlternativeandRenewableEnergieshavethepotentialofbeingastrongcontributorintheenvisageddiversifiedenergy mix. Alternative and Renewable Energy resources are widely and abundantly available in Pakistan that canbeeffectivelyandefficientlyutilizedforpowergeneration.

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 SectorAEDB 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 Identificationofnewcorridors forwindandsolarenergyprojectsdevelopment.Detailedgroundcorrelated 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.

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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 manufacturingfacilityandhasprovidedtowersforthefirstwindprojectinPakistan.CWEhasalsoestablished 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 AREapplications such as solar home systems, solar water pumps etc.

7.8.2 On-Grid ProjectsAEDB 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 ApplicationsAEDB is also promoting the use of RE technologies for distributed generation and off-grid applications. These include:

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• 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. No.

Name of ProjectCapacity

(MW)Expected

Commissioning yearEstimated Cost (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

3 Three Gorges First Wind Farm Pakistan (Pvt.) Limited 50 November, 2014 130.279

4 Foundation Wind Energy-II Limited 50 December, 2014 124.907

5 Foundation Wind Energy-I Limited 50 April, 2015 125.899

6Sapphire 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 151.4

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, 2014Based on

Upfront Tariff20 JDW Sugar Mills Limited (Unit-III) 26.35 October, 2014

21 RYK Mills Limited 30 March, 2015Continued.....

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B: Future Projects

S. No.


(MW)Expected


Wind Technology:1 Sachal Energy Development (Pvt.) Limited 50 June, 2017 133.9182 Hawa Holding Limited 50 December, 2017 120.00-130.003 China Sunec Energy (Pvt.) Limited 50 December, 2017 120.00-130.004 Jhampir Wind Power (Pvt.) Limited 50 December, 2017 120.00-130.005 Trident Energy (Pvt.) Limited 10 January, 2018 24.00-26.006 Burj Wind Energy (Pvt.) Limited 14 April, 2018 33.60-34.40

7 Tricon Boston Consulting Corporation (Pvt.) Limited (A) 50 April, 2018 120.00 -130.00

8 Tricon Boston Consulting Corporation (Pvt.) Limited (B) 50 April 2018 120.00-130.00

9 Tricon Boston Consulting Corporation (Pvt.) Limited (C) 50 April, 2018 120.00 -130.00

10 Hartford Alternative Energy (Pvt.) Limited 50 July, 2018 120.00-130.0011 Wind Eagle Limited (1) 50 July, 2018 120.00-130.0012 Wind Eagle Limited (2) 50 July, 201813 Western Energy (Pvt.) Limited 50 July, 2018 120.00-130.0014 Zephyr Power (Pvt.) Limited 50 August, 2018 134.09915 Titan Wind Power (Pvt.) Limited 10 August, 2018 24.00-26.00

Solar PV Technology:16 Zonergy (Pvt.) Limited 600 June, 2016 840.00-900.0017 Access Electric (Pvt.) Limited 10 August, 2016 16.00-19.0018 Buksh Solar (Pvt.) Limited 10 August, 2016 16.00-19.0019 Sanjwal Solar Power (Pvt.) Limited 5.04 August, 2016 8.00-9.5020 Safe Solar Power (Pvt.) Limited 10.28 August, 2016 16.00-19.0021 Access Solar (Pvt.) Limited 11.52 August, 2016 16.00-19.0022 Blue Star Hydel (Pvt.) Limited 1 August, 2016 1.56223 Blue Star Electric (Pvt.) Limited 1 April, 2017 1.56224 Harappa Solar (Pvt.) Limited 10 June, 2017 14.00-15.0025 Fauji Foundation 10 August, 2017 14.00-15.0026 Siddiqsons Energy Limited 50 September, 2017 70.00-75.0027 Integrated Power Station 50 December, 2017 75.00-78.0028 Jafri and Associates 50 December, 2017 75.00-78.0029 Solar Blue (Pvt.) Limited 50 December, 2017 75.00-78.0030 RE Solar (Pvt.) Limited (1) 20 December, 2017 28.00-30.0031 RE Solar (Pvt.) Limited (2) 20 December, 2017 28.00-30.0032 HanergyGlobalSolarAsiaPacificLimited(1) 50 May, 2018 70.00-75.0033 HanergyGlobalSolarAsiaPacificLimited(2) 10 May, 2018 14.00-15.0034 Janpur Energy Limited (1) 10 May, 2018 14.00-15.0035 Janpur Energy Limited (2) 10 May, 2018 14.00-15.0036 Nizam Power (Pvt.) Limited (1) 5.65 June, 2018 7.00-8.0037 Nizam Power (Pvt.) Limited (2) 5.65 June, 2018 7.00-8.0038 Nizam Power (Pvt.) Limited (3) 11.30 June, 2018 16.00-17.00

Continued.....

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S. No.


(MW)Expected


39 Sino Pak Energy Development Company (Pvt.) Limited 10 June, 2018 14.00-15.00

40 Ayan Energy (Pvt.) Limited 50 June, 2018 70.00-75.0041 Total Energies Nouvelles Ventures 100 December, 2018 140.00-150.0042 AJ Power (Pvt.) Limited 10 December, 2018 14.00-15.0043 Adamjee Power Generation (Pvt.) Limited 5 December, 2018 7.00-8.0044 ET Solar (Pvt.) Limited (1) 25 December, 2018 35.00-38.0045 ET Solar (Pvt.) Limited (2) 25 December, 2018 35.00-38.0046 ET Solar (Pvt.) Limited (3) 25 December, 2018 35.00-38.0047 Crystal Energy (Pvt.) Limited 2 May, 2019 3.50-4.0048 ACT Solar (Pvt.) Limited 50 May, 2019 70.00-75.0049 Asia Petroleum 30 June, 2019 42.00-45.0050 Forshine (Pakistan) 50 June, 2019 70.00-75.00

Bagasse /Biomass Technology:51 Chiniot Power Limited 62.40 2015

Based on Upfront Tariff

52 Hamza Sugar Mill Limited 15 201654 Layyah Sugar Mills Limited 41 201655 SafinaSugarMillsLimited 20 July, 201653 Alliance Sugar Mills Limited 19 201756 Almoiz Industries Limited 36 201757 Etihad Power Generation Limited 67 January, 201758 Shahtaj Sugar Mills Limited 15 201859 Chanar Energy Limited 22 201860 RYK Energy Limited 36 2018

C: Proposals of following Projects accepted by AEDB and issuance of LOI:

S. No.


(MW)Expected


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

8 Power China Huadong Engineering Corporation Limited 50 2019 120.00-130.00

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


13 Trans Atlantic Energy (Pvt.) Limited (1) 50 2019 120.00-130.00

14 Trans Atlantic Energy (Pvt.) Limited (2) 50 2019 120.00-130.00Continued.....

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S. No.


(MW)Expected


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


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


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


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


36 Ansari Powergen Company (Pvt.) Limited 30 2019


37 Bandhi Powergen Company (Pvt.) Limited 30 2019

38 TAY Powergen Company (Pvt.) Limited 30 2019

39 Faran Sugar Mills Limited 25 2019

40 Shakargarj Mills Limited (1) 40 2019

41 Shakarganj Mills Limited (2) 60 2019

42 Indus Sugar Mills Limited 25 2019Notes: 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.

MISCELLANEOUS 8

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8. MISCELLANEOUS

8.1 Promulgation of New Rules/RegulationsThe 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

1 Delay in finalization of Security Documents in thematter of Upfront SolarPower Projects

Ministry of Water and Power

2 Frequent Tripping EHV Transmission and Grid System during Foggy Weather Ministry of Water and Power

3 Delay Caused in Execution of Hydropower Projects due to repeated extensions of Letter of Intents


4 Advisory in the matter of Finalizing PPA ad IA in the stipulated time regarding Solar Power Projects


5 Delay in Finalization of Security Documents in the matter of Upfront Tariff of Solar Power Projects


6 Delay Caused in Execution of Hydropower Projects due to repeated extensions of Letter of Intents


7 Transmission System Breakdown on 24th January, 2015 Ministry of Water and Power

8 Need for Strengthening the Security Measures at Grid Stations/ Switches of Generating Companies


8.3 Consumer AffairsSafeguarding 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 OfficesatalltheProvincialCapitalsinordertofacilitatetheelectricityconsumersforspeedyredressaloftheirgrievances.

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Status of Complaints during the Period 1st July, 2014 to 30th June, 2015NEPRA Head Office

Distribution Company Total ComplaintsReceived/Processed

Total ComplaintsDisposed of/Redressed

UnderProcess

PESCO 104 93 11IESCO 212 198 14GEPCO 111 101 10LESCO 194 176 18FESCO 139 131 8MEPCO 800 761 39HESCO 234 220 14SEPCO 233 218 15QESCO 16 15 1KE 1,540 1,500 40

BTPL 2 2 0

Total 3,585 3,415 170Source: NEPRA

NEPRA Regional Offices

Distribution Company Total Complaints Received/Processed

Total ComplaintsDisposed of/Redressed

UnderProcess

PESCO 91 89 2LESCO 92 86 6FESCO 61 60 1GEPCO 48 48 0MEPCO 95 93 2HESCO 2 2 0SEPCO 1 0 1QESCO 34 15 19KE 23 15 8Total 447 408 39

Source: NEPRA

8.3.1 Achievements/DevelopmentFollowing 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 6complaintsagainstK-ElectricwithrespecttoemailfloatedbyK-Electricregardingexcessivebilling.

ENERGY SECTOR OVERVIEW 9

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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 OilThe balance recoverable reserves of crude oil of the country as on 30th June, 2014 were 371.029 million barrels while theproductionduring2013-14was recordedas31.58millionbarrel.The totaloil refiningcapacityofthe country as on 30th June, 2014 was 18.79 million tonnes per year while the total crude oil processed in the refineriesofthecountrywere11.76milliontonnes.Thetotalimportofthecrudeoilofthecountryduring2013-14 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 GasThe 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 CoalThe 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 SuppliesThe 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.

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TABLE 1Primary Energy Supplies by Source (MTOE)

Fiscal Year

Unit Gas Oil1 LPG2 CoalHydro

Electricity3

Nuclear Electricity3

Imported Electricity4 Total

Annual Growth Rate (%)

2009-10Million

TOE30.81 19.81 0.40 4.62 6.71 0.69 0.06 63.09

0.83% share 48.83 31.39 0.63 7.33 10.63 1.10 0.09 100.00

2010-11Million

TOE30.68 20.67 0.34 4.35 7.59 0.82 0.06 64.52

2.27% share 47.55 32.04 0.53 6.74 11.77 1.27 0.10 100.00

2011-12Million

TOE32.03 19.96 0.32 4.29 6.81 1.26 0.07 64.73

0.32% share 49.49 30.83 0.50 6.62 10.52 1.94 0.10 100.00

2012-13Million

TOE31.14 20.97 0.31 3.86 7.13 1.09 0.09 64.59

-0.21% share 48.22 32.47 0.48 5.98 11.03 1.68 0.14 100.00

2013-14Million

TOE30.96 23.01 0.36 3.59 7.61 1.22 0.10 66.85

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

0.00

3.00

6.00

9.00

12.00

15.00

18.00

21.00

24.00

27.00

30.00

33.00

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

Figure 1. Primary Energy Supplies by Source (MTOE)

Gas Oil LPG Coal Hydro Electricity Nuclear Electricity

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9.5 Final Energy ConsumptionFinal energy is a form of energy available to the user following the conversion from primary energy. Gasoline ordieseloil,purifiedcoal,purifiednaturalgas,electricity,mechanicalenergyaredifferentformsoffinalenergy.Whengoingfromprimaryenergytofinalenergy,therearealwayslossofsomeenergywhichdependsontheefficiencyoftheconversiondevice.Thefinalenergyconsumptionbysourcefrom2009-10to2013-14isgivenin table 2.

TABLE 2Final Energy Consumption by Source (MTOE)

Fiscal Year Unit Gas2 Oil1 LPG Coal2 Electricity3 TotalAnnual Growth Rate (%)

2009-10Million TOE 17.02 10.83 0.58 4.28 6.05 38.77

3.81% share 43.91 27.93 1.49 11.05 15.62 100.00

2010-11Million TOE 16.78 11.25 0.50 4.03 6.28 38.84

0.19% share 43.20 28.97 1.30 10.36 16.17 100.00

2011-12Million TOE 17.62 11.62 0.48 4.06 6.25 40.03

3.05% share 44.02 29.03 1.20 10.14 15.62 100.00

2012-13Million TOE 17.52 12.22 0.53 3.66 6.25 40.18

0.40% share 43.60 30.41 1.31 9.11 15.56 100.00

2013-14Million TOE 16.28 12.72 0.59 3.45 6.79 39.82

-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

0.00

2.00

4.00

6.00

8.00

10.00

12.00

14.00

16.00

18.00

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

Figure 2. Final Energy Consumption by Source (MTOE)

Gas Oil LPG Coal Electricity

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9.6 Fuel Consumption in Power SectorThe 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 3Fuel Consumption for Thermal Power Generation (TOE)

Fiscal Year

Unit GasFurnace

OilDiesel Oil Coal Total

Annual Growth Rate (%)

2009-10TOE 7,106,962 8,339,330 262,499 56,141 15,764,932

3.28% share 45.08 52.90 1.67 0.36 100.00

2010-11TOE 6,493,766 7,827,500 105,160 43,169 14,469,595

-8.22% share 44.88 54.10 0.73 0.30 100.00

2011-12TOE 6,732,876 7,206,839 203,072 46,800 14,189,587

-1.94% share 47.45 50.79 1.43 0.33 100.00

2012-13TOE 7,084,177 7,342,755 218,584 28,204 14,673,720

3.41% share 48.28 50.04 1.49 0.19 100.00

2013-14TOE 6,602,422 8,486,744 304,994 71,902 15,466,062

5.40% share 42.69 54.87 1.97 0.46 100.00

Source: Pakistan Energy Yearbook, HDIP, Islamabad

0.00

5.00

10.00

15.00

20.00

25.00

30.00

35.00

40.00

45.00

50.00

55.00

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

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

Gas Furnace Oil Diesel Oil Coal

10ELECTRICITY SECTOR OVERVIEW

83


10. ELECTRICITY SECTOR OVERVIEW

10.1 Installed CapacityThe 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 4Installed 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

IPPsConnected with PEPCO 8,325 8,312 8,342 8,726 8,726

Connected with KEL 252 252 252 252 252

RPPsConnected with PEPCO 353 0 0 0 0

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 Country

23,342 23,487 23,725 23,728 24,823

Source: PSS/NTDC/KEL

84


TABLE 5Plant-wise Installed Generation Capacity (MW) as on 30th June

Power Station Plant Location Type of Power 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

Gomal Zam South Waziristan 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

0.00

10.00

20.00

30.00

40.00

50.00

60.00

70.00

2011 2012 2013 2014 2015

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

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

Continued.....

85



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

Uch Power Murad Jamali, 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 214Continued.....

86



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

Uch Power-II Murad Jamali, Balochistan GTs+ST 0 0 0 381 381

JDW (II & III) (Bagasse) Rahim Yar Khan, 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 24,823Source: PSS/NTDC/KEL

87


TABLE 6Installed 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 System

20,758 20,478 20,774 21,188 22,360

% Share (Installed Generation Capacity in PEPCO System)

88.93 87.19 87.56 89.30 90.08

Total Installed Generation Capacity in KEL System 2,584 3,009 2,951 2,540 2,463

% Share (Installed Generation Capacity in KEL System) 11.07 12.81 12.44 10.70 9.92

BY SECTOR

Total Installed Generation Capacity in Public Sector

11,951 11,951 12,168 12,142 13,314

% Share (Installed Generation Capacity in Public Sector)

51.20 50.88 51.29 51.17 53.64

Total Installed Generation Capacity in Private Sector

11,391 11,536 11,557 11,586 11,509

% Share (Installed Generation Capacity in Private Sector) 48.80 49.12 48.71 48.83 46.36

Total Installed Generation Capacity in the Country

23,342 23,487 23,725 23,728 24,823

Source: PSS/NTDC/KELNote: See tables 4 and 5 for breakup details.

0.00

15.00

30.00

45.00

60.00

75.00

90.00

2011 2012 2013 2014 2015

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

% Share (Installed Generation Capacity in PEPCO System)

% Share (Installed Generation Capacity in KEL System)

88


TABLE 7Electricity Generation by Type (GWh)

As on 30th June 2010-11 2011-12 2012-13 2013-14 2014-15HYDELWAPDA Hydel 31,685 28,207 29,327 31,204 31,941IPPs Hydel 305 436 706 1,035 1,038Sub-Total 31,990 28,643 30,033 32,239 32,979 % Share (Hydel Electricity Generation) 31.80 28.85 30.44 30.50 30.24THERMALGENCOs with PEPCO 13,018 12,652 12,872 13,016 13,300KEL Own 7,826 8,029 8,567 8,709 9,319

IPPsConnected with PEPCO 41,209 42,222 40,062 43,701 44,638Connected with KEL 1,538 933 1,116 1,380 1,525

RPPsConnected with PEPCO 546 758 0 0 0Connected with KEL 158 0 0 0 0

CPPs/SPPs connected with PEPCO 587 730 1,280 1,108 1,015CPPs/SPPs connected with KEL 287 154 137 168 191Sub-Total 65,169 65,478 64,034 68,082 69,988% Share (Thermal Electricity Generation) 64.79 65.94 64.91 64.41 64.17NUCLEARCHASNUPP (I&II) 2,930 4,413 3,640 4,402 4,996KANUPP 200 459 541 293 353Sub-Total 3,130 4,872 4,181 4,695 5,349 % Share (Nuclear Electricity Generation) 3.11 4.91 4.24 4.44 4.90IMPORTImport from Iran 269 296 375 419 443Import from KEL 26 0 0 0 0Sub-Total 295 296 375 419 443% Share (Imported Electricity Generation) 0.29 0.30 0.38 0.40 0.41WINDWind Power Plants connected with PEPCO 0 6 32 263 300Sub-Total 0 6 32 263 300% Share (Wind Electricity Generation) 0.00 0.01 0.03 0.25 0.27Total Electricity Generation of the Country 100,584 99,295 98,655 105,698 109,059

Source: PSS/NTDC/KEL

0.00

10.00

20.00

30.00

40.00

50.00

60.00

2011 2012 2013 2014 2015

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

% Share (Installed Generation Capacity in Public Sector)

% Share (Installed Generation Capacity in Private Sector)

89


TABLE 8Plant-wise Electricity Generation (GWh)

Power StationPrimary

FuelAlternate

Fuel2010-11 2011-12 2012-13 2013-14 2014-15

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

0.00

10.00

20.00

30.00

40.00

50.00

60.00

70.00

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

Figure 7. Share of Electricity Generation by Type (%)

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

Continued.....

90



FuelAlternate

Fuel2010-11 2011-12 2012-13 2013-14 2014-15

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 1,415Continued.....

91



FuelAlternate

Fuel2010-11 2011-12 2012-13 2013-14 2014-15

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 (IPPs/SPPs/CPPs connected with PEPCO system)

42,342 43,710 41,342 44,809 45,653

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 11,035Continued.....

92



FuelAlternate

Fuel2010-11 2011-12 2012-13 2013-14 2014-15

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 (connected with PEPCO system) (F)

0 6 32 263 300

Grand Total (A+B+C+D+E+F) 100,584 99,295 98,655 105,698 109,059Source: PSS/NTDC/KEL

TABLE 9Electricity 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 PEPCO System

90,549 89,720 88,294 95,148 97,671

% Share (Generation in PEPCO System) 90.02 90.36 89.50 90.02 89.56

Total Electricity Generation in KEL System

10,035 9,575 10,361 10,550 11,388

% Share (Generation in KEL System) 9.98 9.64 10.50 9.98 10.44

BY SECTOR

Total Electricity Generation in Public Sector

47,833 45,731 46,380 48,915 50,590

% Share (Generation in Public Sector) 47.56 46.06 47.01 46.28 46.39

Total Electricity Generation in Private Sector

52,751 53,564 52,275 56,783 58,469

% Share (Generation in Private Sector) 52.44 53.94 52.99 53.72 53.61

Total Electricity Generation of the Country

100,584 99,295 98,655 105,698 109,059

Source: PSS/NTDC/KELNote: See tables 7 and 8 for details and explanations.

93


0.00

10.00

20.00

30.00

40.00

50.00

60.00

70.00

80.00

90.00

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

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

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

0.00

10.00

20.00

30.00

40.00

50.00

60.00

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

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

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

94


TABLE 10Electricity Statistics of K-Electric Limited

Name of Plant Year Units Generated

Auxiliary Consumption Units Sent OutGWh %

1 Units Generated by KEL Own (GWh)

1.1Bin Qasim Thermal Power

Station-I (BQTPS-I)

2010-11 5068.28 435.91 8.60 4632.372011-12 4704.00 414.00 8.80 4290.00

2012-13 3722.00 341.00 9.16 3381.00

2013-14 3765.00 341.00 9.06 3424.00

2014-15 3925.00 360.00 9.17 3565.00

1.2Bin Qasim Thermal Power

Station-II (BQTPS-II)

2011-12 1140.00 102.00 8.95 1038.002012-13 3567.00 239.00 6.70 3328.00

2013-14 3639.00 237.00 6.51 3402.00

2014-15 3907.00 251 6.42 3656.00

1.3Korangi Thermal Power

Station (KTPS)

2010-11 270.51 34.10 12.61 236.412011-12 163.00 20.00 12.27 143.00

2012-13 0.00 2.00 0.00 -2.00

2013-14 0.00 0.00 0.00 0.00

2014-15 0.00 0.00 0.00 0.00

1.4Korangi Town Gas

Turbine Power Station-I (KTGTPS-I)

2010-11 0.61 0.02 3.28 0.592011-12 0.00 0.00 0.00 0.00

2012-13 0.00 0.00 0.00 0.00

2013-14 0.00 0.00 0.00 0.00

2014-15 0.00 0.00 0.00 0.00

1.5Korangi Town Gas Turbine

Power Station-II (KTGTPS-II)

2010-11 675.07 15.13 2.24 659.942011-12 595.00 14.00 2.35 581.00

2012-13 327.00 9.00 2.75 318.00

2013-14 393.00 10.00 2.54 383.00

2014-15 435.00 11.00 2.53 424.00

1.6Site Gas Turbine Power

Station-I (SGTPS-I)

2010-11 0.10 0.01 10.00 0.092011-12 0.00 0.00 0.00 0.00

2012-13 0.00 0.00 0.00 0.00

2013-14 0.00 0.00 0.00 0.00

2014-15 0.00 0.00 0.00 0.00

1.7Site Gas Turbine Power

Station-II (SGTPS-II)

2010-11 586.20 15.06 2.57 571.142011-12 416.00 11.00 2.64 405.00

2012-13 156.00 8.00 5.13 148.00

2013-14 113.00 6.00 5.31 107.00

2014-15 160.00 8.00 5.00 152.00

1.8Korangi Combined Cycle

Power Plant

2010-11 1225.50 91.39 7.46 1134.112011-12 1011.00 75.00 7.42 936.00

2012-13 795.00 66.00 8.30 729.00

2013-14 799.00 64.00 8.01 735.00

2014-15 892.00 74.00 8.30 818.00Continued.....

95


Name of Plant Year Units Generated

Auxiliary Consumption Units Sent OutGWh %

1.9Total Units Generated from KEL's Own Power

Plants

2010-11 7826.27 591.62 7.56 7234.652011-12 8029.00 636.00 7.92 7393.00

2012-13 8567.00 665.00 7.76 7902.00

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 0.002.13 Total 7632.14 7229.71 7257.00 7282.00 7496.00

3Total Units Purchased by KEL including Own Generation (GWh)

15458.41 15258.71 15824.00 15991.00 16815.00

4 Units Available for Distribution (GWh)

14866.79 14622.71 15159.00 15333.00 16111.00

5 Units Sold (GWh) 10071.27 10279.00 10942.00 11453.00 12294.00

6T&D Losses (excluding Auxiliary Consumption)

GWh 4795.52 4343.71 4217.00 3880.00 3817.00

% 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 2014-157.1 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

96


TABLE 11Thermal 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 generation in PEPCO

56.90 42.87 40.24 41.29 40.55

Percentage share to the total thermal generation in the Country

48.33 36.90 34.07 35.07 34.15

FO + HSD** 23,796 32,135 32,357 33,836 34,948


42.98 57.02 59.68 58.51 59.28


36.51 49.08 50.53 49.70 49.93

Coal 66 66 40 112 102


0.12 0.12 0.07 0.19 0.17


0.10 0.10 0.06 0.16 0.15

Sub-Total 55,360 56,362 54,214 57,825 58,953


84.95 86.08 84.66 84.93 84.23

In KEL Area

Gas* 5,578 6,001 6,373 6,892 7,293

Percentage share to the total thermal generation in KEL

56.87 65.83 64.90 67.19 66.09


8.56 9.16 9.95 10.12 10.42

5330.00 (34.99%)

4795.52(32.26%)

4343.71(29.71%)

4217.00(27.82%)

3880.00(25.30%)

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

2011-12 2012-13 2013-14 2014-152010-11

Continued.....

97


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

FO + HSD** 4,188 3,115 3,447 3,365 3,742


42.70 34.17 35.10 32.81 33.91


6.43 4.76 5.38 4.94 5.35

Coal 43 0 0 0 0


0.44 0.00 0.00 0.00 0.00


0.07 0.00 0.00 0.00 0.00

Sub-Total 9,809 9,116 9,820 10,257 11,035


15.05 13.92 15.34 15.07 15.77

In the Country

Gas 37,076 30,162 28,190 30,769 31,196


56.89 46.06 44.02 45.19 44.57

FO + HSD 27,984 35,250 35,804 37,201 38,690


42.94 53.83 55.91 54.64 55.28

Coal 109 66 40 112 102


0.17 0.10 0.06 0.16 0.15

Total 65,169 65,478 64,034 68,082 69,988 * Including generation of SPPs. ** Including generation of CPPs.Source: PSS/NTDC/KEL

TABLE 12Fuel Cost in GENCOs and K-Electric Limited

Fiscal Year ending 30th

June

Cost of Fuel (Rs. in million)

Electricity Generation (GWh)

Cost of Fuel (Paisa/kWh)

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 1,025.69 643.31Source: PSS/NTDC/KEL

98


TABLE 13Fuel 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 M.Tons)

1,882.00 1,542.00 1,741.99 2,325.20 n.p.

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 Generation of Electricity (Rs. Million)

151,260.00 144,251.00 165,065.00 193,334.00 n.p.

Overall Cost of Fuel (Paisa/kWh) 1159.61 1,060.00 1,167.00 1,283.38 1,025.69Source: PSS/NTDC

99


TABLE 14Fuel Consumption and Cost of Generation Data - GENCOs

Power Station YearGen. on Gas

(GWh)

Gas ConsumptionGen. on

FO (GWh)

FO Consumption Total Generation

(GWh)

Cost of Generation (Paisa/kWh)

Total (MMCFT)

Cft/kWh (Average)

(000 M.Ton)

(Kg/kWh)

TPS Jamshoro (GENCO-I)

2010-11 477.00 7,226 13.48 2,020.00 623 0.27 2,497.00 1,258.60

2011-12 67.32 881 11.16 1,377.82 466 0.29 1,445.14 1,839.00

2012-13 151.00 2,105 13.07 1,530.00 462 0.27 1,681.00 1,704.00

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

GTPS Kotri (GENCO-I)

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

2012-13 190.00 6,483 13.06 0.00 - - 190.00 742.00

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

TPS Guddu (GENCO-II)

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 -

2012-13 6,357.00 91,846 - 0.70 0 0.28 6,357.70 -

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

TPS Quetta (Isolated

Generation) (GENCO-II)

2010-11 94.00 1,558 16.25 0.00 - - 94.00 646.23

2011-12 105.41 1,765 16.32 0.00 - - 105.41 773.00

2012-13 97.00 1,744 17.62 0.00 - - 97.00 918.00

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

TPS Muzaffargarh (GENCO-III)

2010-11 16.00 381 20.44 3,613.00 1,124 0.27 3,629.00 1,417.98

2011-12 23.76 312 20.67 3,254.84 954 0.26 3,278.61 1,840.00

2012-13 5.50 326 53.84 4,471.50 1,279 0.26 4,477.00 1,811.00

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

SPS Faisalabad (GENCO-III)

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

2012-13 30.00 0 0.00 0.00 0 0 30.00 0.00

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

NGPS Multan (GENCO-III)

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

2012-13 0.00 0 0.00 0.00 0 0.00 0.00 0.00

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

Power Station YearGen. on FO

(GWh)

FO Consumption Gen. on HSD (GWh)

HSD Consumption Total Generation

(GWh)


(000 M.Ton)

(Kg/kWh)(000

M.Ton)(Kg/kWh)

GTPS Faisalabad (GENCO-III)

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

2012-13 0.00 408 11.51 0.00 0 - 0.00 622.00

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 (GENCO-III)

2014-15 n.p. n.p. n.p. 244.00 n.p. n.p. 244.00 n.p.

Continued.....

100


FBC Lakhara (GENCO-IV)

YearGeneration on Coal

(GWh)Coal Consumption (000 metric tons)

Coal Consumption (kg/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 15Fuel Consumption and Cost of Generation Data - K-Electric Limited

Dual (Gas+Furnace Oil)

Power Station

YearGen. on

Gas (GWh)

Gas ConsumptionGen.

on FO (GWh)

FO ConsumptionTotal

Generation (GWh)

Cost of Generation

(Paisa/kWh)

Total MMCFT

CFT/kWh (Average)

Total (000 M. Tons)

(kg/kWh)

Bin Qasim TPS-I

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

2012-13 1,446 16,299 11.00 2,276 587.00 0.30 3,722 1,250

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

Korangi TPS

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

2012-13 0 0 0.00 0 0.00 0.00 0 0

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 Station

Year Gen. on Gas (GWh)Gas Consumption Cost of Generation

(Paisa/kWh)Total MMCFT CFT/kWh (Average)

BQTPS-II

2011-12 1,139 11,111 9.75 440

2012-13 3,567 31,740 9.00 434

2013-14 3,639 30,333 8.00 454

2014-15 3,907 30,775 7.90 417

Korangi Town GTPS-I

2010-11 1 12 19.92 700

2011-12 0 0 0.00 0

2012-13 0 0 0.00 0

2013-14 0 0 0.00 0

2014-15 0 0 0.00 0

Korangi Town GTPS-II

2010-11 675 7,112 10.53 0

2011-12 595 6,188 10.39 462

2012-13 327 3,452 11.00 505

2013-14 393 4,140 10.50 512

2014-15 435 4,321 9.90 476 Continued.....

101


Gas

Power Station

Year Gen. on Gas (GWh)Gas Consumption Cost of Generation

(Paisa/kWh)Total MMCFT CFT/kWh (Average)

Site GTPS-I

2010-11 0 2 20.49 700

2011-12 0 0 0.00 0

2012-13 0 0 0.00 0

2013-14 0 0 0.00 0

2014-15 0 0 0.00 0

Site GTPS-II

2010-11 586 6,075 10.36 378

2011-12 416 4,311 10.41 440

2012-13 156 1,678 11.00 546

2013-14 113 1,216 10.80 541

2014-15 160 1,659 10.40 490

Korangi CCPP

2010-11 1,226 10,704 8.73 333

2011-12 1,011 8,678 8.59 393

2012-13 795 6,629 8.00 433

2013-14 799 6,961 8.70 487

2014-15 892 7453 8.40 451

Furnace Oil

Power Station

Year Gen. on FO (GWh)

FO ConsumptionCost of Generation

(Paisa/kWh)Total (000 M. Tons)

(kg/kWh)

Gul Ahmed

2010-11 745 n.p. n.p. 1,324

2011-12 452 n.p. n.p. 1,584

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

Tapal Energy

2010-11 793 172.92 n.p. 1,330

2011-12 481 n.p. n.p. 1,512

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. 1435Source: KEL

102


TABLE 16Fuel Consumption and Cost of Generation Data – IPPs

Power Station YearFurnace Oil

Average Fuel Cost (Rs./kWh)

Overall Generation Cost (Rs./kWh)Units Generated

(GWh)Quantity of FO used (M. Tons)

Steam Turbine-RFO

Lal Pir Power

2010-11 1104 260986 13.39 15.682011-12 1787 431390 16.10 18.782012-13 1643 398303 16.46 19.032013-14 2081 495584 16.66 18.882014-15 1663 391215 12.00 14.32

Pak Gen. Power

2010-11 1300 310420 12.19 15.122011-12 1689 408873 15.92 18.992012-13 1936 462041 16.36 18.642013-14 2031 489366 16.81 19.312014-15 1222 289599 14.53 17.06

HUBCO

2010-11 8114 1901299 11.83 14.952011-12 7769 1812055 15.74 18.662012-13 7673 1801653 17.54 19.352013-14 7086 1681641 16.73 18.862014-15 6809 1609458 13.58 15.89

Saba Power

2010-11 244 62269 11.39 17.372011-12 116 30410 15.65 25.122012-13 91 21516 16.98 25.292013-14 129 33261 17.46 22.922014-15 33 8924 16.46 17.63

Engine - RFO

Japan Power

2010-11 371 84109 11.06 12.852011-12 281 64151 14.64 17.582012-13 101 23345 n.p. n.p.2013-14 0 0 0.00 02014-15 0 0 0.00 0

Southern Power

2010-11 466 103056 10.39 14.132011-12 245 54436 14.29 19.682012-13 97 22750 15.19 17.222013-14 0 0 0.00 02014-15 0 0 0.00 0

Kohinoor Energy

2010-11 888 160392 10.78 12.312011-12 727 142004 14.60 16.652012-13 747 140857 13.09 15.862013-14 890 172037 15.65 16.992014-15 877 169389.6 12.05 13.36

Attock Gen.

2010-11 1203 218970 11.49 14.362011-12 1172 n.p. 15.29 18.142012-13 1255 n.p. 14.73 17.262013-14 1243 225236 14.87 17.432014-15 1209 222892 15.43 18.21

Atlas Power

2010-11 1484 289469 11.02 14.772011-12 1067 n.p. 14.80 18.242012-13 1383 n.p. 14.90 17.992013-14 1519 294601 13.57 16.382014-15 1462 283960 15.92 19.21

Nishat Power

2010-11 1473 279219 10.83 13.792011-12 1063 n.p. 14.96 18.612012-13 1276 n.p. 15.80 18.912013-14 1464 287997 14.17 16.802014-15 1410 277312 11.07 13.64

Continued.....

103


Power Station YearFurnace Oil



(GWh)Quantity of FO used (M. Tons)

Nishat Chunian

2010-11 1452 256117 11.11 14.372011-12 1073 n.p. 15.02 18.952012-13 1283 n.p. 15.69 18.952013-14 1471 289439 14.12 16.812014-15 1415 278398 11.05 13.77

Liberty Power Tech.

2010-11 997 124767 11.44 13.102011-12 1068 n.p. 14.85 19.322012-13 1438 n.p. 15.07 18.022013-14 1520 298903 14.27 17.062014-15 1515 297916 15.42 18.57

HUBCO Narowal

2010-11 464 61935 11.89 13.322011-12 1321 n.p. 14.86 17.152012-13 820 n.p. 15.22 22.172013-14 1562 308585 14.28 18.332014-15 1418 278760 11.73 16.26

Power Station YearGas



(GWh)Quantity of Gas used (MMBTU)

Gas Engines / Gas Turbine (CCPP)

Altern Energy

2010-11 179 1827204 3.06 5.542011-12 182 1829598 3.99 6.312012-13 194 1759674 5.58 7.482013-14 205 2021299 5.63 7.632014-15 173 1744940 5.37 7.38

Fauji Kabirwala

2010-11 1088 9161323 2.82 5.652011-12 1237 10458701 3.10 5.242012-13 1107 8735108 4.37 5.652013-14 1191 10203547 4.42 5.502014-15 991 8514108 4.62 6.02

Habibullah Coastal

2010-11 811 6692114 2.71 4.892011-12 685 5792294 3.61 6.292012-13 658 5686043 5.26 7.532013-14 670 5734357 4.65 7.402014-15 719 6187693 4.63 7.06

Rousch Power

2010-11 3039 24342820 2.78 4.982011-12 2733 21952366 3.56 6.062012-13 2535 20172645 4.91 5.192013-14 2760 20002297 4.63 5.892014-15 2465 19635093 4.49 7.22

TNB Liberty Power

2010-11 1333 10848976 7.55 10.292011-12 1484 12045461 10.13 13.342012-13 892 7269215 11.02 12.332013-14 943 7640542 17.40 22.522014-15 1218 10004282 12.39 14.66

Uch Power

2010-11 4221 32561224 2.22 5.072011-12 4278 33037265 2.27 5.042012-13 3796 28724603 3.07 5.652013-14 4314 30644390 3.01 5.632014-15 4127 31549804 2.93 5.08

Davis Energen.

2013-14 54 397509 7.14 11.172014-15 70 n.p. 5.20 8.09

Continued.....

104


Power Station

Year

Gas FOHSD

Generation (GWh)

Total Generation

(GWh)


Overall Generation Cost (Rs./

kWh)

Units Generated

(GWh)

Quantity of Gas used (MMBTU)

Units Generated

(GWh)

Quantity of FO used (M.Tons)

Dual Fuel

KAPCO

2010-11 446 4332015 5175 1056863 68 5689 10.08 15.21

2011-12 414 4228212 5629 1156728 22 6065 13.57 19.01

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

Power Station Year

GasHSD

Generation (GWh)

Total Generation

(GWh)


Overall Generation Cost (Rs./

kWh)

Units Generated

(GWh)

Quantity of Gas used (MMBTU)

Sapphire Electric

2010-11 705 5427189 137 842 4.00 6.49

2011-12 404 n.p. 467 871 12.12 16.62

2012-13 369 n.p. 509 877 14.20 18.07

2013-14 268 2051567 493 761 15.61 20.95

2014-15 282 2153880 685 967 14.60 19.24

Saif Power

2010-11 1056 7762893 116 1172 4.04 7.33

2011-12 398 n.p. 512 909 12.52 16.52

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

Orient Power

2010-11 983 7311571 107 1090 3.90 6.22

2011-12 487 n.p. 195 682 9.82 14.28

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

Engro Power Gen. Qadirpur

2010-11 1562 15134204 n.p. n.p. 3.09 4.60

2011-12 1742 n.p. 2 1744 4.04 5.84

2012-13 1692 n.p. 2 1693 4.79 6.72

2013-14 1441 11881740 0 1441 5.06 5.37

2014-15 1429 11993204 0 1429 5.06 5.37

Foundation Power

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

2012-13 1380 n.p. n.p. n.p. 4.84 7.14

2013-14 1359 10563546 0 1359 4.91 7.25

2014-15 1305 10421325 18 1322 4.36 7.71

Halmore Power

2011-12 407 n.p. 162 570 8.45 11.48

2012-13 294 n.p. 79 374 8.23 18.42

2013-14 250 n.p. 254 504 6.10 13.66

2014-15 93 n.p. 620 713 9.43 13.98

Uch Power-II2013-14 752 n.p. 0 752 3.45 6.18

2014-15 2415 18014780 0 2415 1.08 1.94Source: PSS/WPPO (NTDC)

105


TABLE 17Auxiliary Consumption and other Factors of Hydel Power Stations

Power Station

YearAuxiliary Consumption Maximum

Load (MW)Load Factor

(%)Capacity

Factor (%)Utilization Factor (%)(GWh) (%)

Tarbela

2010-11 97.44 --- 3594 50.70 103.34 52.39

2011-12 48.30 0.30 3702 43.38 106.44 46.17

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

Mangla

2010-11 118.86 --- 1150 60.26 115.00 69.30

2011-12 133.40 2.80 1120 48.78 112.00 54.64

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

Ghazi Barotha

2010-11 80.68 --- 1450 58.37 100.00 58.37

2011-12 98.56 1.40 1450 55.43 100.00 55.43

2012-13 8.67 0.12 1450 56.41 100.00 56.41

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

Warsak

2010-11 4.19 --- 215 55.09 88.49 48.75

2011-12 0.32 0.00 204 55.31 83.96 46.44

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

Chashma

2010-11 -85.14 --- 184 56.66 100.00 56.66

2011-12 7.95 0.70 184 62.86 100.00 62.86

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

Dargai

2010-11 0.32 --- 19 51.08 92.50 47.25

2011-12 0.37 0.40 17 56.69 85.00 48.18

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

Rasul

2010-11 4.99 --- 19 60.51 86.36 52.26

2011-12 2.93 4.30 16 48.42 72.73 35.21

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

Shadiwal

2010-11 2.60 --- 8 49.12 56.30 27.65

2011-12 0.91 2.80 7 82.55 52.59 41.58

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 22.10Continued.....

106


Power Station



(%)Capacity


Chichoki Malian

2010-11 0.90 --- 8 49.08 60.61 29.75

2011-12 2.25 6.50 8 49.06 60.61 29.74

2012-13 0.40 0.93 8 61.49 60.61 37.27

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

Nandipur

2010-11 0.88 --- 9 54.57 66.67 36.38

2011-12 0.90 2.20 9 55.00 66.67 50.12

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

Kurram Garhi

2010-11 2.10 --- 4 34.29 100.00 34.29

2011-12 0.48 4.40 4 31.05 100.00 31.05

2012-13 0.43 3.01 4 40.78 100.00 40.78

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

Renala

2010-11 0.04 --- 1 40.69 72.73 29.59

2011-12 0.06 2.00 1 41.04 72.72 29.85

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

Chitral

2010-11 0.02 --- 1 39.25 100.00 39.25

2011-12 0.02 0.40 1 38.33 103.80 39.79

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

Khan Khwar

2011-12 3.34 1.90 68 30.38 30.38 28.69

2012-13 1.35 0.00 72 41.24 41.24 41.24

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

Jinnah

2012-13 1.99 0.99 60 38.63 24.02 24.02

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

Allai Khwar

2012-13 0.11 0.05 121 44.34 65.21 44.34

2013-14 0.84 0.18 121 44.45 90.95 44.45

2014-15 0.79 0.17 121 44.19 78.32 43.44

Gomal Zam

2013-14 0.02 0.38 17 16.99 17.80 17.00

2014-15 0.18 2.04 17 31.01 66.00 31.00

Jabban2013-14 0.58 0.77 22 38.37 100.00 38.37

2014-15 0.92 0.76 22 61.85 81.25 76.12

Duber Khwar

2013-14 0.19 0.07 130 65.55 59.71 64.77

2014-15 0.74 0.12 130 53.59 100.00 53.59Source: PSS/NTDC

107


TABLE 18Auxiliary Consumption and other Factors of Public Sector Thermal Power Stations

Power Station YearAuxiliary

Consumption Maximum Load (MW)

Load Factor (%)

Capacity Factor (%)

Utilization Factor (%)

(GWh) (%)

TPS Jamshoro (GENCO-I)

2010-11 306.99 11.46 645 49.49 79.38 43.852011-12 211.21 12.75 510 36.98 60.00 27.002012-13 206.19 10.93 520 41.42 61.18 30.772013-14 345.71 10.47 722 52.07 84.94 53.702014-15 n.p. n.p. n.p. n.p. n.p. n.p.

GTPS Kotri (GENCO-I)

2010-11 19.69 4.17 135 39.89 77.59 37.392011-12 13.81 5.00 108 29.92 62.00 23.002012-13 28.81 5.80 114 49.70 65.52 40.472013-14 10.10 5.64 119 17.13 68.39 14.562014-15 n.p. n.p. n.p. n.p. n.p. n.p.

TPS Guddu (GENCO-II)

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.2012-13 n.p. n.p. n.p. n.p. n.p. n.p.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.

TPS Quetta (Isolated

Generation) (GENCO-II)

2010-11 0.00 n.p. 25 43.68 99.27 39.102011-12 2.40 2.00 25 49.00 71.00 49.002012-13 2.51 2.54 26 43.47 74.29 45.212013-14 2.26 2.67 25 38.57 71.43 38.572014-15 n.p. n.p. n.p. n.p. n.p. n.p.

TPS Muzaffargarh (GENCO-III)

2010-11 478.12 11.64 785 59.73 58.15 43.012011-12 402.62 10.94 865 48.45 64.07 37.932012-13 478.86 9.66 1115 50.74 82.59 50.062013-14 596.52 10.41 1157 56.37 85.70 57.722014-15 n.p. n.p. n.p. n.p. n.p. n.p.

SPS Faisalabad (GENCO-III)

2010-11 24.13 11.60 85 27.94 64.39 24.792011-12 19.71 12.06 72 25.83 54.54 19.372012-13 0.92 0.00 0 0.00 0.00 0.002013-14 7.89 15.25 70 8.42 53.03 5.892014-15 n.p. n.p. n.p. n.p. n.p. n.p.

GTPS Faisalabad (GENCO-III)

2010-11 0.01 n.p. 210 10.55 94.06 10.552011-12 7.03 14.69 92 5.92 37.70 2.592012-13 5.43 15.30 69 5.87 28.28 1.932013-14 16.54 8.39 192 11.70 78.69 10.692014-15 n.p. n.p. n.p. n.p. n.p. n.p.

NGPS Multan (GENCO-III)

2010-11 9.82 16.14 72 9.65 36.92 3.562011-12 9.37 16.84 64 9.90 49.00 11.002012-13 2.04 0.00 0 0.00 0.00 0.002013-14 1.34 0.00 0 0.00 0.00 0.002014-15 n.p. n.p. n.p. n.p. n.p. n.p.

Nandipur (GENCO-III) 2014-15 n.p. n.p. n.p. n.p. n.p. n.p.

FBC Lakhra (GENCO-IV)

2010-11 22.52 25.52 36 27.99 30.00 8.402011-12 30.46 32.00 32 34.14 64.00 36.002012-13 20.97 34.51 40 17.34 80.00 23.122013-14 30.46 19.44 34 52.45 68.00 59.452014-15 n.p. n.p. n.p. n.p. n.p. n.p.

Source: PSS/NTDC

108


TABLE 19Auxiliary Consumption and other Factors of K-Electric and Other Thermal Power Stations

Power Station



(%)Capacity


K-EL

Bin Qasim TPS-I

2010-11 435.91 8.60 1095 52.84 86.90 45.922011-12 414.00 8.80 1040 52.00 42.50 83.002012-13 341.00 9.16 1030 41.00 34.00 82.002013-14 341.00 9.06 890 51.00 51.00 85.002014-15 360.00 9.20 915 n.p. n.p. 71.00

Bin Qasim TPS-II

2011-12 102.00 8.95 529 55.00 23.17 94.002012-13 239.00 6.70 566 74.00 73.00 100.002013-14 237.00 6.51 560 79.00 74.00 100.002014-15 251.00 6.40 548 n.p. n.p. 97.90

Korangi TPS

2010-11 34.10 12.61 70 82.42 24.70 24.702011-12 20.00 12.27 65 93.00 14.86 52.002012-13 2.00 0.00 0 0.00 0.00 0.002013-14 0.00 0.00 0 0.00 0.00 0.002014-15 0.00 0.00 0 0.00 0.00 0.00

Korangi Town

GTPS-I

2010-11 0.02 3.28 17 70.98 81.48 71.422011-12 0.00 0.00 0 0.00 0.00 0.002012-13 0.00 0.00 0 0.00 0.00 0.002013-14 0.00 0.00 0 0.00 0.00 0.002014-15 0.00 0.00 0 0.00 0.00 0.00

Korangi Town

GTPS-II

2010-11 15.13 2.24 88 88.00 87.57 n.p.2011-12 14.00 2.35 88 78.00 77.02 100.002012-13 9.00 2.75 88 54.00 42.00 100.002013-14 10.00 2.54 85 55.00 51.00 94.402014-15 11.00 2.60 85 n.p. n.p. 96.60

Site GTPS-I

2010-11 0.01 10.00 15 82.00 81.48 61.972011-12 0.00 0.00 0 0.00 0.00 0.002012-13 0.00 0.00 0 0.00 0.00 0.002013-14 0.00 0.00 0 0.00 0.00 0.002014-15 0.00 0.00 0 0.00 0.00 0.00

Site GTPS-II

2010-11 15.06 2.57 88 80.00 76.04 n.p.2011-12 11.00 2.64 88 73.00 53.87 100.002012-13 8.00 5.13 88 60.00 20.00 100.002013-14 7.00 5.80 85 58.00 15.00 94.402014-15 8.00 4.70 85 n.p. n.p. 96.60

Korangi CCPP

2010-11 91.39 7.46 203 69.66 63.59 63.592011-12 75.00 7.42 190 66.00 52.29 83.002012-13 66.00 8.30 191 58.00 41.00 87.002013-14 64.00 8.01 196 66.00 41.00 89.002014-15 74.00 8.30 222 n.p. n.p. 89.90

IPPs (Connected with KEL System)

Gul Ahmed

2010-11 21.73 n.p. 128 94.08 66.96 90.882011-12 n.p. n.p. 120 n.p. n.p. n.p.2012-13 n.p. n.p. n.p. n.p. n.p. n.p.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.

Tapal Energy

2010-11 11.04 n.p. 124 73.31 73.31 99.542011-12 n.p. n.p. 117 n.p. n.p. n.p.2012-13 n.p. n.p. n.p. n.p. n.p. n.p.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

109


TABLE 20Auxiliary Consumption and other Factors of Private Sector Thermal Power Stations



Load Factor (%)

Capacity Factor (%)


(GWh) (%)

Lal Pir Power

2010-11 1.28 5.93 351 78.90 36.30 57.602011-12 n.p. 6.40 350 83.80 58.00 58.302012-13 115.27 6.55 350 82.64 53.60 53.602013-14 151.37 6.78 350 79.79 67.87 67.872014-15 123.67 6.92 350 75.66 65.11 65.11

Pak Gen. Power

2010-11 1.01 6.89 344 76.60 42.80 52.912011-12 n.p. 6.54 350 84.20 55.00 55.212012-13 130.94 5.96 350 84.17 63.14 63.142013-14 141.82 6.53 350 80.90 66.25 66.252014-15 95.12 7.22 350 75.14 59.87 59.87

Altern Energy

2010-11 n.p. 3.00 n.p. 96.79 77.00 94.882011-12 n.p. 2.80 27 95.51 78.00 97.472012-13 10.59 5.18 30 93.05 93.90 94.822013-14 10.94 5.06 30 94.50 96.10 94.942014-15 9.04 4.96 30 97.35 96.33 95.04

Fauji Kabirwala

2010-11 30.51 2.83 157 92.25 82.11 87.722011-12 n.p. 2.84 151 96.10 93.10 100.212012-13 32.24 2.83 157 92.68 84.10 98.302013-14 36.03 3.16 157 94.87 89.85 94.992014-15 31.40 2.07 157 94.54 75.91 83.59

Habibullah Coastal

2010-11 20.36 2.55 129 73.13 83.13 85.802011-12 n.p. 2.74 129 60.86 60.40 82.932012-13 n.p. 2.40 129 58.20 57.90 53.652013-14 15.66 2.32 128 70.56 59.56 76.982014-15 17.88 2.40 126 76.49 63.52 86.76

HUBCO

2010-11 453.11 5.29 1,200 77.20 89.10 86.702011-12 n.p. 4.87 1,200 73.70 73.70 69.402012-13 481.64 5.90 1,200 73.00 82.00 89.002013-14 416.21 5.00 1,200 67.40 78.30 86.302014-15 398.00 5.84 1,200 65.00 76.00 83.00

Japan Power

2010-11 17.59 4.71 121 41.00 52.40 48.472011-12 n.p. 4.50 107 38.50 29.90 56.602012-13 n.p. 1.50 107 10.80 10.70 8.542013-14 0.00 0.00 0 0.00 0.00 0.002014-15 0.00 0.00 0 0.00 0.00 0.00

KAPCO

2010-11 171.59 2.90 1,361 48.40 48.30 56.102011-12 n.p. 2.80 1,342 51.50 51.40 58.102012-13 158.00 2.78 1,238 47.00 91.70 51.202013-14 185.00 2.78 1,444 55.10 80.20 68.702014-15 196.00 2.75 1,431 59.00 85.54 69.00

Kohinoor Energy

2010-11 27.46 3.17 124 98.10 81.78 86.722011-12 n.p. 2.80 124 97.30 66.70 72.502012-13 22.00 2.97 124 92.84 66.71 71.092013-14 27.00 2.91 124 94.36 81.89 85.202014-15 26.35 2.92 124 93.80 80.73 84.80

Continued.....

110




Load Factor (%)

Capacity Factor (%)


(GWh) (%)

Rousch Power

2010-11 54.03 1.74 443 90.00 89.57 96.952011-12 n.p. 1.73 395 92.05 78.70 97.392012-13 46.60 1.80 452 72.83 73.45 98.312013-14 48.10 1.71 457 82.13 98.99 81.752014-15 44.88 1.78 450 72.04 91.70 78.90

Saba Power

2010-11 17.04 6.94 126 47.93 22.20 22.312011-12 n.p. 6.73 126 46.80 10.40 10.532012-13 5.63 6.21 134 58.35 7.73 7.732013-14 9.05 6.53 134 46.40 11.76 11.762014-15 2.55 7.20 126 41.59 5.94 5.94

Southern Power

2010-11 15.60 3.43 111 49.74 55.24 53.482011-12 n.p. 2.75 110 27.90 25.20 28.422012-13 n.p. 2.46 110 10.10 9.90 9.462013-14 0.00 0.00 0 0.00 0.00 0.002014-15 0.00 0.00 0 0.00 0.00 0.00

TNB Liberty Power

2010-11 3.20 2.34 219 75.81 71.78 92.482011-12 n.p. 2.05 212 84.80 79.60 86.072012-13 18.78 2.04 207 55.84 48.75 86.312013-14 18.27 1.90 219 53.93 51.07 93.242014-15 24.83 2.00 216 67.44 65.91 91.76

Uch Power

2010-11 70.44 1.67 590 87.40 87.30 87.452011-12 n.p. 1.59 551 88.60 88.20 88.592012-13 61.50 1.62 584 78.61 80.60 98.092013-14 67.73 1.57 591 89.37 90.99 99.092014-15 67.52 1.60 549 85.93 87.08 96.37

Attock Gen.

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. 85.702012-13 29.48 2.29 157 98.42 92.30 100.372013-14 28.86 2.27 157 98.48 91.49 100.412014-15 27.88 2.31 157 98.00 89.00 100.00

Atlas Power

2010-11 54.35 n.p. 215 80.00 80.00 91.002011-12 n.p. n.p. 214 57.00 n.p. n.p.2012-13 46.45 2.48 214 73.67 73.82 77.712013-14 37.66 1.96 215 81.08 81.08 86.682014-15 36.24 1.89 215 78.02 78.02 82.99

Nishat Power

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. 62.102012-13 33.44 2.55 195 83.66 72.76 83.662013-14 39.39 2.62 195 95.30 83.57 95.302014-15 38.88 2.68 195 90.13 80.47 90.13

Liberty Power Tech.

2010-11 15.33 n.p. 196 96.89 93.68 98.082011-12 n.p. n.p. 196 62.20 n.p. 62.202012-13 n.p. n.p. 196 83.70 n.p. n.p.2013-14 32.25 2.10 197 97.70 88.44 90.582014-15 32.07 2.10 197 97.80 88.15 90.27

HUBCO Narowal

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. 70.502012-13 n.p. n.p. 214 43.80 n.p. n.p.2013-14 30.25 1.94 217 83.41 83.41 96.132014-15 25.72 1.81 217 75.71 75.71 88.40

Continued.....

111




Load Factor (%)

Capacity Factor (%)


(GWh) (%)

Nishat Chunian


Sapphire Electric Power


Engro Power Gen. Qadirpur

2010-11 43.81 n.p. n.p. 86.60 93.50 92.602011-12 n.p. n.p. 214 92.40 n.p. 93.102012-13 45.50 2.69 214 89.00 90.13 99.802013-14 39.50 2.75 217 84.56 101.00 84.002014-15 41.00 2.80 217 84.00 91.00 91.00

Saif Power


Orient Power


Foundation Power

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.2012-13 49.98 3.61 193 100.10 92.90 n.p.2013-14 49.55 3.64 200 97.68 92.57 90.122014-15 48.75 3.69 197 96.31 89.97 87.59

Uch Power-II

2013-14 n.p. n.p. n.p. n.p. n.p. n.p.2014-15 59.16 2.38 381 72.56 73.89 79.30

Davis Energen.

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: PSS/NTDC

112


TABLE 21Main 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-diversifiedEnergyDemandof the Country 21,086 21,536 21,605 23,505 n.p.

DiversifiedEnergyDemandofthe Country 20,673 21,114 21,181 23,044 n.p.

2: Consumers (Nos.)

PEPC

O A

rea

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

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

KEL

Are

a

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

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 AreaAuxiliary Consumption (KEL Own) 7.56 7.92 7.76 7.56 7.55

T&D Losses (excluding Auxiliary Consumption) 32.26 29.71 27.82 25.30 23.69

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 systemPopulation (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 consumption (kWh) 441 431 418 445 n.p.

Continued.....

113


2010-11 2011-12 2012-13 2013-14 2014-15Average Sale/ Consumer (kWh) 3,260.18 3,110.80 2,970.62 3,145.62 3,088.67

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 consumption (kWh) 570 586 547 487 523

Average Sale/ Consumer (kWh)

4,774.31 4,804.03 5,121.20 5,425.00 5,695.71

Source: PSS/NTDC/DISCOs/KEL

TABLE 22Category-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


Industrial 17,699 18,399 18,641 20,551 21,085


Agricultural 8,847 8,410 7,550 8,129 7,866




Bulk Supply 2,581 2,598 3,623 3,837 3,846


Others + Traction 1,078 936 27 31 33


Supplied to KEL 5,449 5,684 5,463 5,441 5,427


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


Commercial 1,043 1,128 1,507 1,507 1,589


Industrial 3,447 3,342 3,445 3,568 3,648

Percentage share 34.14 32.51 31.48 31.15 29.68Continued.....

114


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

Agricultural 125 134 149 160 166




Bulk Supply + Others 1,118 994 647 624 619


Supplied to NTDC 26 0 0 0 0


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


Commercial 5,725 5,690 5,941 6,300 6,442


Industrial 21,146 21,741 22,086 24,119 24,733


Agricultural 8,972 8,544 7,699 8,289 8,032




Bulk Supply + Others 4,778 4,528 4,297 4,492 4,498


Total in the Country* 76,285 75,752 75,926 82,507 84,936* excluding supplied to KEL and supplied to NTDCSource: PSS/NTDC/DISCOs/KEL

TABLE 23Category-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)

DomesticConsumers 85.29 85.42 85.54 85.54 85.67

Consumption 43.22 42.45 43.04 43.56 44.28

CommercialConsumers 11.92 11.80 11.66 11.67 11.58

Consumption 6.53 6.41 6.29 6.27 6.22

IndustrialConsumers 1.34 1.36 1.36 1.35 1.34

Consumption 24.70 25.86 26.46 26.87 27.01

AgriculturalConsumers 1.38 1.36 1.38 1.37 1.35

Consumption 12.35 11.82 10.72 10.63 10.08

Public LightingConsumers 0.04 0.04 0.04 0.04 0.04

Consumption 0.49 0.51 0.55 0.51 0.50Continued.....

115


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

Bulk Supply + Traction + Others

Consumers 0.02 0.02 0.02 0.02 0.02

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)


Consumption 42.16 44.40 46.45 47.92 50.12


Consumption 10.33 10.97 13.77 13.16 12.93


Consumption 34.14 32.51 31.48 31.15 29.68


Consumption 1.24 1.30 1.36 1.40 1.35


Consumption 0.81 1.15 1.01 0.93 0.89

Bulk Supply + OthersConsumers 0.07 0.02 0.02 0.01 0.00

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)


Consumption 46.18 45.90 46.63 47.04 47.95


Consumption 7.50 7.51 7.82 7.64 7.59


Consumption 27.72 28.70 29.09 29.23 29.12


Consumption 11.76 11.28 10.14 10.05 9.46


Consumption 0.57 0.63 0.66 0.60 0.59

Bulk Supply + OthersConsumers 0.03 0.02 0.02 0.02 0.02

Consumption 4.85 4.74 5.62 5.41 5.26

TractionConsumers 0.00 0.00 0.00 0.00 0.00

Consumption 1.41 1.24 0.04 0.04 0.04Source: PSS/NTDC/DISCOs/KEL

10.2 Load Pattern and Peak Load HoursThe 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 timinginthesystemisnormallyfrom6PMto10PM.Thehourlyloadfiguresforatypicalworkingandnon-working day in summer and winter, during 2014, are given hereunder.

116


TABLE 24Hourly System Demand (MW)

Hours of the day

Maximum Demand (MW) (January, 2014 - December,

2014)

System Demand for a Typical day in Summer

(January, 2014 - December, 2014)

System Demand for a Typical Day in Winter

(January, 2014 - December, 2014)

Summer (23-07-2014)

Winter (03-01-2014)

Working day (23-07-2014)

Non-working day (20-07-2014)

Working day (03-01-2014)

Non-working day (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

117


10.3 Maximum DemandThe 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 25Maximum 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 of the Country 21,086 21,536 21,605 23,505 n.p.

% change in Maximum Demand 0.96 2.13 0.32 8.79 -

Diversified Energy Demand of the Country 20,673 21,114 21,181 23,044 n.p.

% change in Maximum Demand 0.96 2.13 0.32 8.80 -Source: PSS/NTDC/KEL

-

3,000

6,000

9,000

12,000

15,000

18,000

21,000

24,000

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

Figure 24B. System Demand for a Typical Dayin Summer and Winter (MW)

Working day(23-07-2014)

Non-working day(20-07-2014)

Working day(03-01-2014)

Non-working day(05-01-2014)

118


10.4 Pattern of Electricity ConsumptionThe 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 26Annual Growth Rate of Electricity Consumption

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

A: PEPCO area

DomesticGWh 30,972 30,203 30,321 33,322 34,566

% 5.12 -2.48 0.39 9.90 3.73

CommercialGWh 4,682 4,562 4,434 4,793 4,853

% 4.83 -2.56 -2.82 8.09 1.27

IndustrialGWh 17,699 18,399 18,641 20,551 21,085

% 7.96 3.96 1.32 10.24 2.60

AgriculturalGWh 8,847 8,410 7,550 8,129 7,866

% -7.68 -4.94 -10.22 7.67 -3.24

Public LightingGWh 353 363 387 390 393

% -5.14 2.84 6.67 0.73 0.87

Bulk SupplyGWh 2,581 2,598 3,623 3,837 3,846

% -22.92 0.65 39.43 5.90 0.24

Others + Traction

GWh 1,078 936 27 31 33

% 3494.17 -13.18 -97.10 15.52 5.16

Supplied to KELGWh 5,449 5,684 5,463 5,441 5,427

% 4.63 4.31 -3.88 -0.40 -0.26

Total GWh 71,662 71,156 70,447 76,494 78,070

Percentage change % 4.06 -0.71 -1.00 8.58 2.06

20,559 21,997

22,883 23,425 23,381

2,591 2,596 2,778 2,929 3,056

-

2,500

5,000

7,500

10,000

12,500

15,000

17,500

20,000

22,500

25,000

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

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

PEPCO Area KEL Area

Continued.....

119


2010-11 2011-12 2012-13 2013-14 2014-15B: KEL area

DomesticGWh 4,257 4,564 5,083 5,489 6,161

% 2.14 7.21 11.37 7.99 12.24

CommercialGWh 1,043 1,128 1,507 1,507 1,589

% -4.40 8.15 33.60 0.00 5.44

IndustrialGWh 3,447 3,342 3,445 3,568 3,648

% 1.77 -3.05 3.08 3.57 2.24

AgriculturalGWh 125 134 149 160 166

% 20.19 7.20 11.19 7.38 3.75


% -5.75 43.90 -5.93 -4.50 3.77

Bulk Supply + Others

GWh 1,118 994 647 624 619

% 4.68 -11.09 -34.91 -3.55 -0.80

Supplied to NTDC

GWh 26 0 0 0 0

% 30.00 -100.00 0.00 1.00 2.00

Total GWh 10,098 10,280 10,942 11,454 12,293

Percentage change % 1.74 1.80 6.44 4.68 7.32

C: Country area

DomesticGWh 35,229 34,767 35,404 38,811 40,727

% 4.75 -1.31 1.83 9.62 4.94

CommercialGWh 5,725 5,690 5,941 6,300 6,442

% 3.02 -0.60 4.40 6.04 2.27

IndustrialGWh 21,146 21,741 22,086 24,119 24,733

% 6.90 2.81 1.59 9.20 2.55

AgriculturalGWh 8,972 8,544 7,699 8,289 8,032

% -7.38 -4.77 -9.88 7.66 -3.11


% -5.26 10.58 3.58 -0.44 1.49

Bulk Supply + Others

GWh 3,699 3,592 4,270 4,461 4,465

% -16.25 -2.90 18.86 4.46 0.09

TractionGWh 1,078 936 27 31 33

% 3494.17 -13.18 -97.10 15.52 5.16

Total GWh 81,760 81,436 81,389 87,948 90,363

Percentage change % 3.77 -0.40 -0.06 8.06 2.75

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 systemhavebeen reproduced in the following tables. Further, theprojectedfiguresofplannedgenerationcapacity,demandgrowthrateandsurplus/deficitofelectricpower for theyears tocome, in theNTDCandK-Electric area have also been collected through respective companies and are included in the above stated tables.

120


TABLE 27Surplus/Deficit in Demand and Supply during NTDC’s System Peak Hours

A: Actual Figures


Generation Capability (MW)

Demand During NTDC’s System Peak

Hours (MW)


2011 13,193 18,521 -5,3282012 12,320 18,940 -6,6202013 14,600 18,827 -4,2272014 16,170 20,576 -4,4062015 16,500 21,701 -5,201

B: Projected Figures


Planned Generation Capability as per

NTDC (MW)

NTDC Projected Demand Growth

Rate (%)

NTDC’s Projected Demand during

Peak Hours (MW)

Surplus/ (Deficit)

(MW)2016 17,551 5.98 22,457 -4,9062017 20,641 6.05 23,816 -3,1752018 25,077 5.56 25,140 -632019 29,171 5.17 26,439 2,7322020 31,216 4.86 27,725 3,491

Source: NTDC

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

A: Actual Figures

Financial Year ending 30th

June

Generation Capability (MW)*

Demand During KEL’s System Peak Hours

(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

Financial Year ending 30th

June

Planned Generation Capability as per

KEL (MW)

KEL’s Projected Demand Growth

Rate (%)

KEL’s Projected Demand during

Peak hours (MW)


2016 2,752 (including 20 + 100 MW NPC) 5.00 3,209 -457

2017 2,804 (including 52 MW FPCL) 5.00 3,369 -565

20183,674

(including 450 LNG + 420 Coal Conversion)

5.00 3,538 136

2019 4,374 (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

11ELECTRICITY GENERATION

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11. ELECTRICITY GENERATION

11.1 GeneralPakistan 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 manyvillagesarenotyetelectrified.

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 heavilydependentonimportofoilforitsdomesticenergyrequirementduetolargeamountofoil-firedpowerplants.

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 electricitygenerationincreasedtheutilitiesfinancialburdenparticularlyinforeignexchange.Itisastrongneedof 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 29Energy 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 KELSource: PSS/NTDC

124


11.2 Thermal GenerationMajority 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 thermalpowerplants runningonoilwill increase thecurrentaccountdeficitwhich is alreadyproblemfor thecountry.The importofoil isoneof themainreasonsofcurrentaccountdeficit.Anystrategytocutcurrentaccountdeficitrequirestocutdowntheoilimportsandforthisitisessentialtoreducetheelectricitygeneration through oil. Similarly, the thermal power plants running on natural gas has negative externality. The economiclossresultingfromdeficiencyofnaturalgasduetoexcessiverelianceongasfiredpowergenerationis 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 ConsumptionGas: 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.

-

5,000

10,000

15,000

20,000

25,000

30,000

35,000

40,000

45,000

50,000

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

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

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

125


TABLE 30Thermal 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

IPPsPEPCO Area 41,209 42,222 40,062 43,701 44,638

KEL Area 1,538 933 1,116 1,380 1,525

RPPsPEPCO Area 546 758 0 0 0

KEL Area 158 0 0 0 0

CPPs/SPPsPEPCO Area 587 730 1,280 1,108 1,015

KEL Area 287 154 137 168 191

Total Thermal Generation 65,169 65,478 64,034 68,082 69,988

Thermal Generation using:

Gas

PEPCO Area* 31,498 24,161 21,817 23,877 23,903

KEL Area 5,578 6,001 6,373 6,892 7,293

Total 37,076 30,162 28,190 30,769 31,196

FO and HSD

PEPCO Area** 23,796 32,135 32,357 33,836 34,948

KEL Area 4,188 3,115 3,447 3,365 3,742

Total 27,984 35,250 35,804 37,201 38,690

Coal

PEPCO Area 66 66 40 112 102

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 GenerationWaterflowingintherivershaskineticenergy.Onceitisusedtodrivetheturbineandproduceelectricity,thepower thus generated is called hydel energy. Power produced by the turbines depends on quantity of water flowingperminutesandtheheadofwateravailable.

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 inmaximumhydrogenerationcapacity,duringpastfiveyears,hasbeencollectedfromNPCCandisgiveninthefollowing table.

126


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

Mo

nth

Year Tarbela ManglaGhazi

BarothaWarsak

Chashma Hydel

Jinnah Hydel

Allai Khwar

Khan Khwar

Duber Khwar

Small Hydels

Total

July

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

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

Aug

ust

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

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

Sep

tem

ber

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

2014 3,605 1,115 1,450 150 184 n.p. n.p. n.p. n.p. 81 6,585

Oct

ob

er

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

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

No

vem

ber

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

2014 2,808 1,115 1,450 150 168 n.p. n.p. n.p. n.p. 80 5,771

Dec

emb

er

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

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

Janu

ary

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

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

Feb

ruar

y

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

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.....

127


Mo

nth

Year Tarbela ManglaGhazi

BarothaWarsak

Chashma Hydel

Jinnah Hydel

Allai Khwar

Khan Khwar

Duber Khwar

Small Hydels

Total

Mar

ch2011 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

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

Ap

ril

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

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

May

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

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

June

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

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 PlantsPakistan 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.

128


TABLE 32Nuclear 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

11.6 Renewable EnergyPakistan,likeotherdevelopingcountriesoftheregion,isfacingaseriouschallengeofenergydeficit.Hence,Pakistanisworkingtoexpandtheuseofrenewableenergytohelpbridgethegapofenergydeficiencyinthecountry. 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 canbenefitfromtheseresourcesandcansupplementexistingenergyresourcesaswellascanuseasprimaryenergy 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

-

15,000

30,000

45,000

60,000

75,000

90,000

105,000

120,000

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

3,130 4,872 4,181 4,695 5,349

100,584 99,295 98,655 105,698 109,059

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

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

129


sites available in Coastal Area of Balochistan and some in Northern Areas. Technically the grid can take upto 30-40%ofwindenergy.Mostoftheremotevillagesinthesouthcanbeelectrifiedthroughmicrowindturbines.Morethan5,000villagescanbeelectrifiedthroughwindenergyinSindh,BalochistanandNorthernAreas.

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, Sindhiv) AJK Hydro Electric Board (AJKHEB) and AJK Private Power Cellv) 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 CapacityCapability 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 33Installed and Available Capacity (MW)

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

PEPCO KEL PEPCO KEL PEPCO KEL PEPCO KEL PEPCO KELInstalled Capacity

Thermal (GENCOs+IPPs) 13,463 2,447 13,097 2,872 13,127 2,814 13,290 2,403 13,715 2,326

Nuclear 650 137 650 137 650 137 650 137 650 137 Hydel (WAPDA+IPPs) 6,645 - 6,730 - 6,947 - 7,116 - 7,116 -

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 (GENCOs+IPPs) 11,865 1,787 11,151 2,256 11,399 1,862 12,680 1,872 12,845 1,880

Nuclear 615 84 615 80 615 75 615 75 615 75 Hydel (WAPDA+IPPs) Depends on Indents

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 (GENCOs+IPPs) 88.13 73.03 85.14 78.55 86.84 66.17 95.41 77.90 93.66 80.83

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

130


TABLE 34Ongoing Projects and Expansion Plan of Hydel Power Generation

in Khyber Pakhtunkhwa under E&P Department

S.No.


(MW)

Expected Commissioning Year (Actual/Tentative)

Project Cost (Actual/Estimated) (Rs. in

Million)

Existing on-going Projects:

1 Reshun Hydropower Project, Chitral 4.2 1999 (A) 238 (A)

2Malakand-III Hydropower Project, Dargai

81 2009 (A) 6,379.50 (A)

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)

4Feasibility Study of 3 raw sites in Khyber Pakhtunkhwa.

965 2017 (T) 1,237 (E)

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)

10Construction of 15 Feasible Sites in Khyber Pakhtunkhwa. Feasibility Study of these sites completed in 2014-15.

2,249 2021-22 (T) 654,000 (E)

Abbreviations: (A) Actual, (E) Estimated, (T) TentativeSource: Pakhtunkhwa Energy Development Organization, Government of Khyber Pakhtunkhwa, Peshawar

11.8 Investment Plan for Power Generation ProjectsThe 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 35Investment Plan for Public Sector Power Generation Projects (as per approved PC-I)

S. No.

Name of the ProjectCapacity

(MW)

Expected Commissioning

Year

Estimated Cost (Million Rupees)

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

5Mangla Refurbishment and up-gradation Hydropower Project

310 2024 52,224.31

6 Diamer Basha Dam Land Acquisition Project4500 2024

834,205.00

7 Diamer Basha Dam Project (Lot 1-5) 101,372.00 Source: NTDC

131


TABLE 36Investment Plan for Power Generation Projects (KEL) (2015-16 to 2016-17)

S. No.

Name of the Project Capacity (MW)Expected

Commissioning Year

Estimated Cost

(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 700MWCoalGreenfield(IPPModel)* 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 37Investment Plan for Private Sector Power Generation Projects

S. No.

Name of the ProjectGross

Capacity (MW)

Estimated Investments

(Million US$)

Achieved/ Expected

CODLatest Status of the Project

A: OIL

NIL

B: PIPELINE QUALITY GAS/DUAL FUEL/LNG

1 Kandra Power Project 120 90December, 2022

i) Project is based on both pipeline quality gasandgasfromadedicatedgasfield. ii) LOS not issued due to the non-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 Projectunderfinancialclosing.

4 Sehra Hydel Project 130 344December, 2019

Approval of EPC stage tariff by NEPRA is under process.

5 Karot Hydel Project 720 1420 June, 2020 Projectunderfinancialclosing.

6 Azad Patan Hydel Project 640 1145 June, 2020Tariff review under consideration by NEPRA.

7Suki Kinari Hydropower Project

870 1801 September, 2021 Projectunderfinancialclosing.

8 Chakothi-Hattian Project 500 983December, 2022

Sponsors have approached Court of Law against NEPRA for giving low tariff. The matter is subjudice.

9Lower Palas Valley Hydropower Project

665 763December, 2022

Project under implementation under Public-Private Partnership (PPP) mode.

10Lower Spat Gah Hydropower Project

496 697December, 2022

Project under implementation under Public-Private Partnership (PPP) mode.

Continued.....

132


S. No.

Name of the ProjectGross

Capacity (MW)

Estimated Investments

(Million US$)

Achieved/ Expected

CODLatest Status of the Project

11 Madian Hydropower Project 157 438December, 2022

Progress is slow due to Law and Order situation in the vicinity of project area and its perception internationally.

12 Asrit-Kedam Hydel Project 215 406December, 2022

Progress is slow due to Law and Order situation in the vicinity of project area and its perception internationally.

13 Mahl Hydropower Project 590 885December, 2023

LOI issued on 21st October, 2014. Feasibility Study is in process.

14 Kohala Hydropower Project 1100 2397December, 2023

LOSwillbeissuedafterfulfillmentofpre-requisites by Sponsors.

15 Kaigah Hydel Project 548 1565December, 2024

Sponsors are in process of submission of feasibility level tariff to NEPRA.

16 Rajdhani Hydropower Project 132 198December, 2024

PPIB is in consultation with the Government of AJK for the development of the project.

17Athmuqam Hydropower Project

350 525December, 2024

EOI for development of project to be re-advertised shortly.

18Turtonas-Uzghor Hydropower Project

58 87December, 2024

Proposals received against EOI are under evaluation process.

19Neckeherdm-Paur Hydropower Project

80 120December, 2025

EOI for development of project to be re-advertised shortly.

E: COAL

20Engro Powergen. Project at Thar Block-II, Sindh

660 957February, 2017

Projectunderfinancialclosing.

21Shanghai Electric Power Project at Thar Block-I, Sindh

1320 1914December, 2017

Project under issuance of Notice of Proceed (NTP)/LOI.

22Salt Range Power Project by CMEC, China

330 479December, 2017

Project under tariff determination by NEPRA.

23HUBCO Imported Coal based Power Project

1320 1914December, 2017

LOI issued, sponsors are in process to approach NEPRA for tariff.

24Shandong Imported Coal based Power Project

1320 1914 March, 2018 Projectunderfinancialclosing.

25Port Qasim Power Project by Sinohydro Resources Limited and Al Mirqab Capital

1320 1914 June, 2018 Projectunderfinancialclosing.

26 Grange Holding Power Project 163 251 January, 2019 Projectunderfinancialclosing.

27Siddiqsons Imported Coal based Power Project

350 508 March, 2019LOI issued, sponsors have approached NEPRA for tariff.

28Lucky Electric Imported Coal based Power Project

660 957October, 2019

Projectunderfinancialclosing.

Source: Private Power and Infrastructure Board, Islamabad

133


TABLE 38Detail of Renewable Energy Projects

A: Existing Projects (in-operation and under construction)

S. No.


(MW)Expected


Wind Technology:

1 FFC Energy Limited 49.50 May, 2013 133.557

2 Zorlu Energy Pakistan Limited 56.40 July, 2013 143.74

3Three Gorges First Wind Farm Pakistan (Pvt.) Limited

50 November, 2014 130.279

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


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


19 JDW Sugar Mills Limited (Unit-II) 26.35 June, 2014Based on

Upfront Tariff20 JDW Sugar Mills Limited (Unit-III) 26.35 October, 2014

21 RYK Mills Limited 30 March, 2015

B. Future Projects

S. No.


(MW)Expected


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

7Tricon Boston Consulting Corporation (Pvt.) Limited (A)

50 April, 2018 120.00-130.00

8Tricon Boston Consulting Corporation (Pvt.) Limited (B)

50 April, 2018 120.00-130.00

9Tricon Boston Consulting Corporation (Pvt.) Limited (C)

50 April, 2018 120.00-130.00

Continued.....

134


S. No.


(MW)Expected


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


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 HanergyGlobalSolarAsiaPacificLimited(1) 50 May, 2018 70.00-75.00

33 HanergyGlobalSolarAsiaPacificLimited(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



39Sino Pak Energy Development Company (Pvt.) Limited

10 June, 2018 14.00-15.00

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



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 70.00-75.00Continued.....

135


S. No.


(MW)Expected


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 SafinaSugarMillsLimited 20 July, 2016

53 Alliance Sugar Mills Limited 19 2017

56 Almoiz Industries Limited 36 2017

57 Etihad Power Generation Limited 67 January, 2017

58 Shahtaj Sugar Mills Limited 15 2018

59 Chanar Energy Limited 22 201860 RYK Energy Limited 36 2018

Source: Alternative Energy Development Board, Islamabad

C: Proposals of following Projects accepted by AEDB and issuance of LOI:

S. No.


(MW)Expected


Wind Technology:


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

8 Power China Huadong Engineering Corporation Limited 50 2019 120.00-130.00

9 Indus Wind Energy Limited 50 2019 120.00-130.00

10 NASDA Energy (Pvt.) limited 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


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 56.00-60.00Continued.....

136


S. No.


(MW)Expected



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



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


36 Ansari Powergen Company (Pvt.) Limited 30 2019


37 Bandhi Powergen Company (Pvt.) Limited 30 2019

38 TAY Powergen Company (Pvt.) Limited 30 2019

39 Faran Sugar Mills Limited 25 2019

40 Shakargarj Mills Limited (1) 40 2019

41 Shakarganj Mills Limited (2) 60 2019

42 Indus Sugar Mills Limited 25 2019Notes: 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 SystemBased 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 39Merit Order for Power Generation Plants (PEPCO System)

(Based on the revised RFO and HSD prices effective from 16-06-2015) (Rs./kWh)

Order in

MeritPlant Groups Fuel Type

As on 16th June, 2015 Status in Last Year Merit

Order (16-06-2014)

FuelCost

O&MCost

Specific Cost

1 Uch (upto 152.375 GWh) Gas 0.55750 0.23340 0.79090 12 Liberty (upto 61.904 GWh) Gas 1.82378 0.31800 2.14178 33 Uch (+ 152.375 GWh) Gas 2.33620 0.23340 2.56960 24 Uch-II Gas 3.88440 0.14960 4.03400 --5 Foundation Power Gas 3.77690 0.35570 4.13260 106 GTPS Faisalabad 5-9 Gas 4.19570 0.02500 4.22070 127 Guddu 11-13 R. Gas 4.16600 0.06890 4.23490 138 FKPCL Gas 3.52630 0.73478 4.26108 59 Rousch Gas 4.09025 0.20535 4.29560 14

10 Engro Power Gen. Gas 4.05880 0.31390 4.37270 1511 HCPC Gas 3.97790 0.48712 4.46502 1612 Lakhra Coal 4.31019 0.19540 4.50559 4

Continued.....

137


Order in



Order (16-06-2014)

FuelCost

O&MCost

Specific Cost

13 Altern (Phase-II) Gas 3.96579 0.65794 4.62373 1814 Guddu 5-10 R. Gas 4.62880 0.06890 4.69770 1915 Davis Energy Gas 4.58152 0.49345 5.07497 2116 GTPS Kotri 3-7 Gas 4.99800 0.08990 5.08790 2217 Muzaffargarh 4 Gas 5.22010 0.02500 5.24510 2318 Muzaffargarh 1-3 Gas 5.26700 0.02500 5.29200 2419 Guddu 3-4 Gas 5.55440 0.06890 5.62330 2520 Altern (Phase-I) Gas 5.09564 0.65794 5.75358 2621 Muzaffargarh 5-6 Gas 5.93570 0.02500 5.96070 2722 Guddu 1-2 Gas 5.95100 0.06890 6.01990 2823 Jamshoro 2-4 Gas 5.99140 0.13590 6.12730 2924 NGPS Multan 1-4 Gas 6.89090 0.02500 6.91590 3025 SPS Faisalabad 1-2 Gas 7.01470 0.02500 7.03970 3126 GTPS Faisalabad 1-4 Gas 7.50210 0.02500 7.52710 3227 Orient Power Gas (RLNG) 8.22630 0.20340 8.42970 628 Sapphire Electric Gas (RLNG) 8.22640 0.34220 8.56860 729 Saif Power Gas (RLNG) 8.22660 0.34600 8.57260 830 Halmore Power Gas (RLNG) 8.22680 0.34760 8.57440 931 Muzaffargarh 4 Mix (**) 8.81395 0.02500 8.83895 3432 Muzaffargarh 1-3 Mix (**) 8.89325 0.02500 8.91825 3633 KAPCO-I Gas (RLNG) 8.85219 0.25854 9.11073 1134 Guddu 3-4 Mix (**) 9.35555 0.06890 9.42445 3735 Liberty (+ 61.904 GWh) Gas 9.11888 0.31800 9.43688 3336 Attock Gen. RFO 8.56070 0.88420 9.44490 4237 KAPCO-I RFO 9.15710 0.44846 9.60556 4038 Engro Power Gen. Mix (***) 9.64480 0.31720 9.96200 3839 KAPCO-II Gas (RLNG) 9.70937 0.30241 10.01178 1740 Jamshoro 2-4 Mix (**) 9.88310 0.13590 10.01900 3941 Muzaffargarh 5-6 Mix (**) 10.02245 0.02500 10.04745 4142 Nishat Power RFO 9.27030 0.87000 10.14030 4543 GTPS Kotri 1-2 Gas 10.15620 0.08990 10.24610 3544 Nishat Chunian RFO 9.46180 0.86790 10.32970 4445 Liberty Power Tech. RFO 9.39460 0.96960 10.36420 4346 Atlas Power RFO 9.49720 0.87000 10.36720 4647 KEL RFO 9.94788 0.57397 10.52185 4848 KAPCO-III Gas (RLNG) 10.04191 0.58291 10.62482 2049 KAPCO-II RFO 10.05007 0.63127 10.68134 4950 Japan Power RFO 10.16165 0.54821 10.70986 5051 HUBCO Narowal RFO 9.96520 0.82570 10.79090 4752 HUBCO RFO 10.71459 0.18264 10.89723 5253 SEPCOL RFO 10.07020 0.90242 10.97262 51

Continued.....

138


Order in



Order (16-06-2014)

FuelCost

O&MCost

Specific Cost

54 Saba Power RFO 10.96195 0.16184 11.12379 55

55 Lal Pir Power RFO 10.97112 0.16441 11.13553 5356 Pak Gen. Power RFO 10.97112 0.16441 11.13553 5457 NGPS Multan 1-4 Mix (**) 11.97715 0.02500 12.00215 5658 Jamshoro 1 RFO 11.96140 0.13590 12.09730 5859 SPS Faisalabad 1-2 Mix (**) 12.11960 0.02500 12.14460 5760 Muzaffargarh 4 RFO 12.40780 0.02500 12.43280 5961 Muzaffargarh 1-3 RFO 12.51950 0.02500 12.54450 6062 Guddu 3-4 RFO 13.15670 0.06890 13.22560 6163 Jamshoro 2-4 RFO 13.77480 0.13590 13.91070 6764 Muzaffargarh 5-6 RFO 14.10920 0.02500 14.13420 6865 KAPCO-I HSD 14.28386 0.25997 14.54383 6366 Orient Power HSD 14.22630 0.33350 14.55980 6267 Sapphire Electric HSD 14.13190 0.49390 14.62580 6468 Halmore Power HSD 14.14730 0.50180 14.64910 6569 Saif Power HSD 14.32970 0.49950 14.82920 6670 Engro Power Gen. HSD 15.23080 0.32050 15.55130 6971 KAPCO-II HSD 15.67671 0.34952 16.02623 7072 GTPS Faisalabad 5-9 HSD 16.75240 0.02500 16.77740 7173 NGPS Multan 1-4 RFO 17.06340 0.02500 17.08840 7374 KAPCO-III HSD 16.21305 0.88264 17.09569 7275 SPS Faisalabad 1-2 RFO 17.22450 0.02500 17.24950 7476 GTPS Kotri 3-7 HSD 19.63910 0.08990 19.72900 7577 NGPS Multan 1-4 HSD 29.95310 0.02500 29.97810 7678 GTPS Kotri 1-2 HSD 39.90720 0.08990 39.99710 77

(**) 50% FO and 50% Gas (***) 50% HSD and 50% GasSource: National Power Control Centre, Islamabad

TABLE 40Merit Order for Power Generation Plants (K-Electric System)

(Based on the Present Net Heat Rate at 100% Plant Factor) (Rs./kWh)

S. No.

Plant Groups

Fuel Type

As on 31st December, 2014

As on 31st March, 2015

As on 30th June, 2015

Fuel Cost

O&M Cost

Total Cost

Fuel Cost

O&M Cost

Total Cost

Fuel Cost

O&M Cost

Total Cost

1 BQPS-II Gas 8,230 1,336 9,566 11,315 1,905 13,220 15,252 2,587 17,839

2Korangi CCPP

Gas 1,874 762 2,636 2,381 1,051 3,432 3,683 1,430 5,113

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 1,785 23,209

6,268 2,780 28,488

9,061 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

139


11.10 Generation Licenses GrantedIn 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-AList of Generation Licensees (Hydel + Nuclear)

S. No.

Name of Company and LocationInstalled

Capacity (MW)Fuel Type

Hydel (Technology: Hydel)

1WAPDA Hydro Electric Power Company (Tarbela, Mangla, Warsak, Ghazi Barotha, Chashma etc.)

17359.96Storage Water / Run of

River / Canal

2Malakand-III, Pakhtunkhwa Energy Development Organization (PEDO), Malakand Agency, Khyber Pakhtunkhwa

83.70 Run of River/Canal

3Blue Star Energy (Pvt.) Limited, District Mardan, Khyber Pakhtunkhwa

3.021 Run of River/Canal

4SK Hydro (Pvt.) Limited, District Manshera, Khyber Pakhtunkhwa

840.00 Run of River

5 Olympus Energy (Pvt.) Limited, District Gujrat, Punjab 20.0016Canal Fall/

Run of River

6Pehur Hydropower Plant, PEDO, District Swabi, Khyber Pakhtunkhwa

18.00Canal Fall/

Run of River

7Punjnad Hydropower (Pvt.) Limited, District Muzaffargarh, Punjab

15.00 Run of River

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 AlkaPowerPrivateLimited,DistrictHafizabad,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

13Frontier Mega Structure and Power (Pvt.) Limited, District Mansehra, Khyber Pakhtunkhwa

2.40 Run of River

14SAR Energy (Pvt.) Limited, District Mardan, Khyber Pakhtunkhwa

1.30 Run of Canal

15Reshun Hydropower Plant, PEDO, Reshun Gol, District Chitral, Khyber Pakhtunkhwa

4.20Canal Fall/

Run of River

16Shishi Hydropower Plant, PEDO, Drosh, District Chitral, Khyber Pakhtunkhwa

1.875Canal Fall/

Run of River

17Machai Hydropower Plant, PEDO, Machai Canal near Village Alo, District Mardan, Khyber Pakhtunkhwa

2.60Low Head Canal Fall

18Ranolia Hydropower Plant, PEDO, Ranolia Khwar, District Kohistan, Khyber Pakhtunkhwa

17.00 Run of River

19Karot Power Company (Pvt.) Limited, Village Karot, District Rawalpindi, Punjab

732.00 Run of River

20 New Park Energy Limited, District Okara, Punjab 9.00 Canal FallContinued.....

140


S. No.

Name of Company and LocationInstalled

Capacity (MW)Fuel Type

21Karimi Energy (Pvt.) Limited, District Haripur, Khyber Pakhtunkhwa

3.60 Canal Fall/Run of River

22Muntaha Power (Pvt.) Limited, District Muzaffargarh, Punjab

2.60Canal Fall/

Run of River

23Marala Hydropower Project, Punjab Power Development Company Limited (PPDCL), District Sialkot, Punjab

8.088Canal Fall/

Run of River

24Pakpattan Hydropower Project, PPDCL, District Pakpattan, Punjab

3.01Canal Fall/

Run of River

25Deg-Outfall Hydropower Project, PPDCL, District Sheikhpura, Punjab


26Chianwali Hydropower Project, PPDCL, District Gujranwala, Punjab


Nuclear (Technology: Pressurized Heavy Water Reactor)

1Chashma Nuclear Power Plant (Unit-1), Chashma Barrage, District Mianwali, Punjab

325.00 Uranium

2 Karachi Nuclear Power Plant, District Karachi, Sindh 137.00 Uranium

3Chashma Nuclear Power Plant (Unit-2), Chashma Barrage, District Mianwali, Punjab

325.00 Uranium

Note: Shaded area indicate licenses issued in 2014-15.Source: National Electric Power Regulatory Authority, Islamabad

TABLE 41-BList of Generation Licensees (Wind + Solar + Bagasse/Biomass)

S. No. Name of Company and LocationInstalled Capacity

(MW)Fuel Type Technology

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

10 Three Gorges First Wind Firm Pakistan (Pvt.) Limited, Thatta, Sindh 49.50 Wind Wind Turbine

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

18 Pakistan Wind Energy Generation (Pvt.) Limited, Jhampir, Thatta, Sindh 4.80 Wind Wind Turbine

19 Sachal Energy Development (Pvt.) Limited, Jhampir, Thatta, Sindh 49.50 Wind Wind Turbine

Continued.....

141


S. No. Name of Company and LocationInstalled Capacity


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

1 DACC Power Generation Company (Pvt.) Limited, Bhawalpur, Punjab 50.00 P.V Cell P.V Cell

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

14 Appolo Solar Development Pakistan Limited, Bahawalpur, Punjab 100.00 P.V Cell P.V Cell

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

5 JDW Sugar Mills Limited, Rahim Yar Khan, Punjab 26.35 Bagasse +Biomass Steam Turbine

6 JDW Sugar Mills Limited, Ghotki, Sindh 26.35 Bagasse +Biomass Steam Turbine

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

11 Ansari Powergen Company (Pvt.) Limited, Tando Muhammad Khan, Sindh 30.00 Bagasse Steam Turbine

12 TAY Powergen Company (Pvt.) Limited, Tando Allayar, Sindh 30.00 Bagasse Steam Turbine

13 Bandhi Powergen Company (Pvt.) Limited, Shaheed Benazirabad, Sindh 30.00 Bagasse Steam Turbine

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 TurbineNote: Shaded area indicate licenses issued in 2014-15.Source: National Electric Power Regulatory Authority, Islamabad

142


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

S. No.

Name of Company and LocationInstalled Capacity

(MW)Fuel Type

Technology-wise Capacity (MW)

Technology Capacity

Small Power Producers (SPPs)

1ICI Pakistan PowerGen Limited, Sheikhupura, Punjab

14.00 HFO DE 14.00

2Sapphire Power Generation Limited, Sheikhupura, Punjab

56.80 HFO+Gas DE+GE 52.20+4.60

3 Crescent Powertec Limited, Shahkot, Punjab 10.60 HFO DE 10.60

4Ellcot Spinning Mills Limited, Kotri (Sindh), Kasur and Sheikhupura (Punjab)

21.96 HFO+ HSD DE 13.80+8.16

5Mahmood Textile Mills Limited, Muzaffargarh, Punjab

15.05 FO+Gas DE+GE 9.20+5.85

6Gulistan Power Generation Limited, Sheikhupura, Kasur (Punjab) & Kotri (Sindh)

20.945HSD+HFO

+GasDE+GE

11.82+4.68 +4.45

7 Kohinoor Mills Limited, Kasur, Punjab 31.23 HSD+HFO+Gas DE+GE17.88+5.85

+7.50

8Monnoo Energy Limited, Monnoopur, Sheikhupura, Punjab

4.60 HFO DE 4.60

9DS Power Limited, Bhikki, Sheikhupura, Punjab

1.98 HFO DE 1.98

10 Sitara Energy Limited, Faisalabad, Punjab 87.82 HFO+Gas DE+GE 51.62+36.20

11Bhanero Energy Limited, Kotri and Sheikhupura

37.33 HFO+Gas DE+GE 3.635+33.695

12Quetta Textile Mills Limited, Kotri (Sindh) & Bhai Pheru (Punjab)

30.806 HFO+Gas DE+GE 8.1+22.706

13 Ideal Energy Limited, Faisalabad, Punjab 11.82 HFO DE 11.82

14Genertech Pakistan Limited, Bhai Pheru, Punjab

27.52 HFO DE 27.52

15Kohinoor Power Company Limited, Faisalabad & Kasur, Punjab

15.24 HFO DE 10.16+5.08

16 Ghazi Power Limited, Lahore, Punjab 20.82 HFO DE 20.82

17CrescentBahumanLimited,Hafizabad,Punjab

23.03 HFO+ HSD +Gas DE 23.03

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

2Prosperity Weaving Mills Limited, Sheikhupura, Punjab

6.90 HFO DE 6.90

3Almoiz Industries Limited, Dera Ismail Khan, Khyber Pakhtunkhwa

43.60 Bagasse +FO ST 43.60

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 11.00Continued.....

143


S. No.


(MW)Fuel Type


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

13Al-Noor Sugar Mills Limited, Shaheed Benazirabad, Sindh


14SUNEC Wind Power Generation (Pvt.) Limited, Chakwal, Punjab

0.05 Wind WT 0.05

15Shadman Cotton Mills Limited, Nankana, Punjab

9.25 Gas+ Diesel GE+DE 4.65+4.6

16Agar Textiles Mills (Pvt.) Limited, Jamshoro, Sindh

16.185 Gas GE 16.185

17 RYK Mills Limited, Rahim Yar Khan, Punjab 18.00 Bagasse +FO ST 18.00

18Sheikhoo Sugar Mills Limited, Muzaffargarh, Punjab


19Hi-Tech Pipe & Engineering Industries, Jamshoro, Sindh

3.78 Gas GE 3.78

20Ashraf Sugar Mills Limited, Bahawalpur, Punjab


21 Al-Abbas Sugar Mills Limited, Thatta, Sindh 15.00 Imported Coal ST 15.00

22The Thal Industries Corporation Limited, Layyah, Punjab


23 International Steel Limited, Karachi, Sindh 19.316 Gas GE+ST 18.066 +1.250

24International Industries Limited, Karachi, Sindh

4.38 Gas GE 4.38

25Hamza Sugar Mills Limited, Rahim Yar Khan, Sindh


26 Tuwairqi Steel Mills Limited, Karachi, Sindh 38.948 Gas GT+ST 26.948+12.00

27Eithad Sugar Mills Limited, Rahim Yar Khan, Punjab


28Deharki Sugar Mills (Pvt.) Limited, Ghotki, Sindh


29Tando Allayar Sugar Mills (Pvt.) Limited, Tano Allahyar, Sindh


30Pakistan Engineering Council, Islamabad, Federal Capital Territory

0.356 P.V Cell P.V Cell 0.356

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

34Engro Powergen. Qadirpur Limited, Ghotki, Sindh

0.36 Solar Power P.V Cell 0.36

35 Fatima Sugar Mills Limited, Kot Addu, Punjab 120.00 Bagasse +FO ST 120.00

36Bandhi Sugar Mills (Pvt.) Limited, Shaheed Benazirabad, Sindh


37Kamalia Sugar Mills Limited, Toba Tek Singh, Punjab


38Gadoon Textile Mills Limited, Swabi, Khyber Pakhtunkhwa

56.47 HFO+ Gas RE 56.47

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.....

144


S. No.


(MW)Fuel Type


Technology Capacity

42Bahria Town Electric Supply Company (Pvt.) Limited, Rawalpindi, Punjab

10.00 Coal Water Slurry DE 10.00

43 Fatima Energy Limited, Muzaffargarh, Punjab 120.00 Bagasse +Biomass ST 120.00

44Faran Sugar Mills Limited, Tando Muhammad Khan, Sindh

13.00 Biomass+FO ST 13.00

45Chambar Sugar Mills (Pvt.) Limited, Tando Allahyar, Sindh


46Fimcotex Industries (Pvt.) Limited, Jamshoro, Sindh

35.538 Gas GE+ST 32.838+2.70

47Thal Industries Corporation Limited (forSafinaSugarMillsLimited-PlantI),Chiniot, Punjab

11.00 Bagasse ST 11.00

48Ranipur Sugar Mills (Pvt.) Limited, Khairpur, Sindh


49 Unicol Limited, Mirpur Khas, Sindh 6.60 Bagasse ST 6.60

50Lucky Cement Limited, Lakki Marwat, Khyber Pakhtunkhwa

16.00Waste Heat Recovery Based Thermal Power

Station

Steam Generators

16.00

51Alliance Sugar Mills (Pvt.) Limited, Ghotki, Sindh


52Habib Sugar Mills Limited, Benazirabad, Sindh


53Mehran Sugar Mills Limited, Tando Allahyar, 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

56Mirpurkhas Sugar Mills Limited, Mirpurkhas, Sindh


Isolated Generation Companies (IGCs)

1Engro Polymer and Chemicals Limited, Karachi, Sindh

79.02 HSD+ Gas GT 5.20

2Olympia Power Generation (Pvt.) Limited, Karachi, Sindh

5.88 Gas GE 5.88

3 Lucky Energy (Pvt.) Limited, Karachi, Sindh 46.57 Gas GE 46.57

4Nadeem Power Generation Limited, Karachi, Sindh

2.805 Gas GE 2.805

5Shakarganj Energy (Pvt.) Limited, Jhang, Punjab

31.50 Bagasse+FO ST 31.50

6Asia Generation (Pvt.) Limited, SITE & Kemari Town, Karachi

11.10 Gas GE 11.10

7Innovative Energy Solutions Limited, Karachi, Sindh

8.031 Gas GE 8.031

8 Aquagen (Pvt.) Limited, Karachi, Sindh 7.357 Gas GE 7.357

9Port Qasim Electric Power Company (Pvt.) Limited, Karachi, Sindh

1320.00 Imported Coal ST 2x660.00

New Captive Power Plants (N-CPPs)

1 Dadu Energy (Pvt.) Limited, Dadu, Sindh 49.448 Gas GE+ST 46.648+2.80

2Omni Power (Pvt.) Limited, Tando Muhammad Khan, Sindh

14.128 Gas GE+ST 13.328+0.80

3Shikarpur Power (Pvt.) Limited Shikarpur, Sindh

17.66 Gas GE+ST 16.66+1.00

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.....

145


S. No.


(MW)Fuel Type


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

9Hi-Tech Pipe & Engineering Industries, Jamshoro, Sindh

15.00 Gas GT 12.00+3.00

Distributed Generation Plants (DGPs)

1Anoud Power Generation Limited, Karachi, Sindh

30.95 FO+Gas DG+GE 23.84+7.11

2 FFBL Power Company Limited, Karachi, Sindh 118.00 Coal+Gas ST 118.00

Short-Term Independent Power Producers (STIPPs)

1Gulf Powergen (Pvt.) Limited, Gujranwala, Punjab

83.84 RFO RE 83.84

2Reshma Power Generation (Pvt.) Limited, Kasur, Punjab

96.96 RFO RE 96.96

Other IPPs

1 K-Energy (Pvt.) Limited, Karachi, Sindh 421.90 Imported Coal ST 2x210.95GE = Gas Engines FO = Furnace OilDE = Diesel Engines RE = Reciprocating EnginesST = Steam Turbines GT = Gas TurbinesWT = Wind Turbines CB = Conventional BoilerNote: Shaded area indicate licenses issued in 2014-15.Source: National Electric Power Regulatory Authority, Islamabad

TABLE 41-DList of Public and Private Sector Power Generation Licensees

S. No.

CompanyDate of Licence

(Issued+Valid Until)

Installed Capacity


Generation Licence Granted to Public Sector Companies

1 Jamshoro Power Generation Company Limited (GENCO-I)

Issued 01-07-2002 Valid until 30-06-2021

2344.00*Gas+RFO

+CoalGTs+STs

2Central Power Generation Company Limited (GENCO-II)


2431.70** Gas+RFO GTs+STs

3Northern Power Generation Company Limited (GENCO-III)


1726.00*** Gas+RFO GTs+STs

4Lakhra Power Generation Company Limited (GENCO-IV)


150.00Coal+RFO

+DOSTs

Generation Licence Granted to Private Sector Companies

1 K-Electric Limited (KEL)Issued 18-11-2002

Valid until 17-11-20272359.00 Gas+RFO GTs+STs

*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

146


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

S. No.


(MW)Fuel Type


Technology Capacity

1*Fauji Kabirwala Power Company Limited, Khanewal, Punjab

170 Gas GT+ST 96+74

2* TNB Liberty Power Limited, Daharki, Sindh 235 Gas GT+ST 156+79

3*Habibullah Coastal Power Company (Pvt.) Limited, Sheikh Manda, Balochistan

140 Gas GT+ST 111+29

4*Uch Power Limited, Murad Jamali, Naseerabad, Balochistan

586 Gas GT+ST 390+196

5*Rousch (Pakistan) Power Limited, Sidhnai, Khanewal, Punjab

450 Gas GT+ST 304+146

6 Altern Energy Limited, Fateh Jang, Punjab 14 Gas GE 14

7* Kohinoor Energy Limited, Raiwind, Punjab 131 FO DE+ST 125+6

8Lal Pir Power (Pvt.) Limited, Mehmood Kot, Muzaffargarh, Punjab

362 FO ST 362

9Pak Gen. Power (Pvt.) Limited, Mehmood Kot, Muzaffargarh, Punjab

365 FO ST 365

10Saba Power Company Limited, Farooqabad, Sheikhupura, Punjab

136 FO ST 136

11The Hub Power Company Limited, Hub, Lasbela, Balochistan**

1292 FO ST 1292

12Southern Electric Power, Raiwind, Lahore, Punjab

117 RFO DE 117

13 Japan Power Generation, Raiwind, Punjab 135.6 RFO DE 135.6

14Gul Ahmed Energy (Pvt.) Limited, Karachi, Sindh

136.17 RFO DE 136.17

15 Tapal Energy (Pvt.) Limited, Karachi, Sindh 126 RFO DE 126

16*Kot Addu Power Company, Kot Addu, Muzaffargarh, Punjab**

1600Gas+FO +HSD

GT+ST 1021+579

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 PolicySource: National Electric Power Regulatory Authority, Islamabad

147


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

S. No. Name of Company and Location

Installed Capacity

(MW)Fuel Type


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

3 Orient Power Company (Pvt.) Limited, Balloki, Punjab 225.00 Gas GT+ST 151+74

4 Saif Power Limited, Sahiwal, Punjab 225.00 Gas+HSD GT+ST 152+73

5 Sapphire Electric Power Company Limited, 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

7 Halmore Power Generation Company (Pvt.) Limited, Bhikki, Punjab 225.00 Gas+HSD GT+ST 150+75

8 Foundation Power Company (Daharki) Limited, 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

12 Engro Power Gen. Qadirpur Limited, Qadirpur, 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

15 Intergen (Pvt.) Limited, Lachi, Kohat, Khyber Pakhtunkhwa 165.285 HSFO+HSD RE+ST 153.684+11.60

16 The Hub Power Company Limited (Narowal 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

21 Uch-II Power (Pvt.) Limited, Naseerabad, Balochistan 404.00 Gas GT+ST 267.54+136.46

22 Radian Energy Power Generation Company (Pvt.) Limited, Faisalabad, Punjab 164.368 RFO+LFO RE+ST 153.684+10.684

23 Engro Powergen Thar (Pvt.) Limited, Tharparker, Sindh 660.00 Indigenous

Coal ST+CB 2x330

24 CMEC Power (Pvt.) Limited, Jhelum Punjab 330.00 Indigenous Coal ST+CB 330.00

25 Huaneng Shandong Ruyi (Pakistan) Energy (Pvt.) Limited, Sahiwal, Punjab 1320.00 Imported

Coal ST+CB 1320.00

Note: Shaded area indicate licenses issued in 2014-15.Source: National Electric Power Regulatory Authority, Islamabad

148


TABLE 41-GList of Transmission and Distribution Licensees

S. No.

CompanyNumber of Consumers (as on 30th June, 2015)

Date of Licence Issued

Licence Valid Until

Transmission Licence Granted to Public Companies

1National Transmission and Dispatch Company Limited

--- 31-12-2002 30-12-2032

Transmission Licence Granted to Private Companies

1 K-Electric Limited --- 11-06-2010 10-06-2030

Distribution Licence Granted to Public Sector Companies

1Peshawar Electric Supply Company Limited

2,956,567 30-04-2002 29-04-2022

2Tribal Areas Electricity Supply Company Limited

441,562 12-08-2013 11-08-2033

3Islamabad Electric Supply Company Limited

2,462,167 02-11-2001 01-11-2021

4Gujranwala 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

6Faisalabad 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

8Hyderabad 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 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 21-07-2029Source: National Electric Power Regulatory Authority, Islamabad

12 ELECTRICITY TRANSMISSION

151


12. ELECTRICITY TRANSMISSION

12.1 GeneralIn 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 42Electricity 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 NTDCThe integrated transmission system of NTDC comprises of 500 kV and 220 kV transmission lines and grid stations.Thestatusoftransmissionlinesandgridstations,attheendoffiscalyearsfrom2011to2015,ownedand operated by NTDC is mentioned in following table.

152


TABLE 43Transmission Lines and Grid Stations with NTDC

A: Transmission Lines

As on 30th June

500 kV 220 kV Total Transmission Lines and No. of Circuits

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

As on 30th June

500/220 kV 220/132 kV Total No. of Grid Stations and MVA Capacity

No. of Grid Station MVA Capacity No. of Grid

StationMVA

CapacityTotal No. of Grid Station

Total MVA 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 LossesWhen 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.

-

1,000

2,000

3,000

4,000

5,000

6,000

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

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

Total Electricity Imported Total Electricity Exported

153


TABLE 44Unit 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 (Transmission)

GWh 2,740.00 2,508.00 2,656.00 2,698.00 2,565.00

% 3.03 2.82 3.05 2.82 2.63 Source: NTDC

12.4 Utilization of Transmission Lines and Power TransformersAppropriate utilization of transmission lines and power transformers in any electric power system is important andhasaverysignificantimpactbothtechnicallyaswellasfinancially.Thepositionofutilizationoftransmissionlines in the NTDC’s network is mentioned in following table.

TABLE 45Utilization 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 (Nos.)

500 kV 0 0 0 0 2220 kV 3 23 35 25 32

Underutilized Transmission Lines/Circuits (Nos.)

500 kV 4 34 34 34 30220 kV 25 85 78 95 74

B: Loading Status of Power Transformers 2010-11 2011-12 2012-13 2013-14 2014-15

Overloaded Power Transformers (Nos.)500 kV 7 5 4 5 5220 kV 25 58 56 63 47

Underutilized Power Transformers (Nos.)

500 kV 6 29 30 26 22220 kV 23 33 54 55 43

Source: NTDC

TABLE 46Transmission Lines Tripping in PEPCO and K-Electric System

PEPCO System

YearPlanned Outages Forced Outages500 kV 220 kV 500 kV 220 kV

2010-11No. of Outages 145 528 113 268Total duration in minutes 62066 219749 227048 428970Maximum duration of any single outage (Minutes) 6501 12383 6501 111825





Continued.....

154


KEL System

YearPlanned Outages Forced Outages220 kV 132 kV 220 kV 132 kV

2010-11No. of Outages 263 666 60 519Total duration in minutes 11898 252539 16275 149411Maximum duration of any single outage (Minutes) 5672 n.p. 2853 n.p.




2014-15No. of Outages n.p. 12 n.p. 39Total duration in minutes n.p. 3662 n.p. 5190Maximum duration of any single outage (Minutes) n.p. 849 n.p. 631

Source: NTDC / KEL

12.5 Investment Plan - NTDC SystemBeing 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 47Grid Station Expansion Plan of NTDC

Period of Report

500/220 kV Grids 220/132 kV Grids

Nos. MVA Capacity

Expected COD

*Estimated Cost

(Rs. Million)Nos. MVA

CapacityExpected

COD

Estimated Cost

(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

155


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

S. No.

Name of ProjectTransmission Lines

Capacity (MVA)

Expected Completion Date

Estimated Cost

(Million Rs.)Voltage

Level (kV)Line Length

(km)

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

December, 2015 3900

(ii) Sheikh Muhammadi 220 - 1000

(iii) Burhan 220 - 1000

(iv) Bund Road 220 - 1000

(v) Mardan 220 - 500

(vi) Bahawalpur 220 - 500

(vii) Quetta Industrial 220 - 500Source: NTDC

TABLE 49Interconnection Arrangement to Evacuate Power from up-coming

(Public and Private Sector) Power Projects

S. No.

Name of Power Project

Plant Capacity

(MW)

Expected COD Proposed Transmission Scheme

1

Power Dispersal from Chashma Nuclear Power Project (C3 and C4)

2x340 2015-16

220 kV Chashma Nuclear - Bannu D/C T/L (125 km)

220 kV D/C T/L for in/out of existing C1 and C2 at C3 and C4 (2 km)

Extension at 220 kV Bannu

2 Power Dispersal from 747 CCPP at Guddu 747 2015-16

500 kV Guddu-Muzaffargarh S/C T/L (256 km)

Two 500 kV T/L for in/out of 500 kV Guddu-Multan S/C T/L at 500 kV Muzaffargarh (10 km)

Extension at 500 kV Muzaffargarh

3 Power Dispersal from Uch-II 404 2015-16

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 New S/C T/L at Uch-II (0.5 km)

Reconductoring of 220 kV T/L Uch-I to Uch-II (I km)

Extension at 220 kV Sibbi SubstationContinued.....

156


S. No.


Plant Capacity

(MW)


4

3rd Circuit (for Power Evacuation from 2x660 MW Coal Fired PPs at Jamshoro and Dispersal of Wind Power)

2270 2015-16

500 kV Jamshoro-Moro-RYK S/C T/L (535 km)

500 kV Moro-Dadu S/C T/L (55 km)

500 kV Switching Station at Moro

Extension at 500 kV Jamshoro, Dadu and RYK Grid Stations

5

Power Dispersal from Neelum Jhelum, Azad Pattan and Karot Hydropower Projects

969+650+ 720=2339 2015-16

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)

Extension at 500 kV Gujranwala (two lines bays with 3x37 MVA Shunt Reactors)

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)

6

Evacuation of Power from 1000 MW Quaid-e-Azam Solar Park at Lal-Suhanra

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)

600 2015-16

Phase III: 220 kV Grid Station at Lal-Suhanra with 3x250 MVA, 220/132 kV transformers along with allied equipment and accessories

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)

7

Evacuation of Power from Wind Power Projects at Jhimpir and Gharo Wind Clusters

330 2015-16Phase I: 132 kV Jhimpir New Collector Substation

132 kV D/C T/Lines (107 km)

620 2016-17

Phase II: Upgradation of 132 kV Jhimpir Substation to 220 kV Substation (3x250 MVA)

220 kV Gas Insulated Substation (GIS) at Gharo (2x250 MVA)



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)

8Power Dispersal from Thar Coal based Power Plant

1200 2016-17500 kV Thar - Matiari D/C T/L (250 km)

500 kV Switching Station at Matiari

9Evacuation of Power from 1200 MW LNG Based PP at Bhikki

1200 2016-17 In/Out of existing 500 kV Lahore-Gatti Singh Circuit at 500 kV Switchyard of Bhikki Power Plant (3 km)

10Evacuation of Power from 1200 MW LNG Based PP at Bhikki

1200 2016-17

500 kV Double Circuit T/L from Balloki Power Project to Lahore South Grid Station (40 km)

Addition of 1x750 MVA 500/220 kV Transformer along with allied equipment and two 500 kV line baysat 500 kV Lahore South Grid Station

11

Evacuation of Power from 1200 MW LNG Based PP at Jhnag (Haveli Bahadur Shah)

1200 2016-17

In/Out of 500 kV D/C T/L from Muzaffargarh-Gatti at HB Shah (3 km)

In/Out of 500 kV Multan-Gatti D/C T/L at HB Shah (25 km)

12Evacuation of Power from 1320 MW Bin Qasim Project

1320 2016-17 500 kV D/C T/L from Bin Qasim Power Plant to Matiari Switching Station (180 km)

Continued.....

157


S. No.


Plant Capacity

(MW)


13Evacuation of Power from 1320 MW Hub Power Company Ltd.

11320 2016-17 500 kV D/C T/L from Hub Power Plant to Matiari Switching Station (220 km)

14

Evacuation of Power from 300 MW Coal Fired Power Plant at Pind Dadin Khan

300 2016-17 132 kV D/C T/L (80 km)

15

Evacuation of Power from 1320 MW Imported Coal Based Power Plant at Sahiwal

1320 2016-17 In/Out of Yousafwala-Lahore 500 kV D/C T/L at Sahiwal (0.5 km)

16Evacuation of Power from 147 MW Patrind HPP

147 2016-17 132 kV T/L (70 km)

17Evacuation of Power from Tarbela 4th Extension

1410 2016-17

Replacement of Existing Tarbela-Burhan D/C T/L (35.1 km)

Replacement of Existing 220 kV Tarbela-Burhan-ISPR D/C T/L (62.5 km)

In/Out of one Circuit of 220 kV Mansehra-ISPR D/C T/L (40 km)

18Evacuation of Power from Tarbela 5th Extension

1320 2017-18 500 kV D/C T/L (77 km)

19Evacuation of Power from Siddiqsons Limited

350 2018-19 500 kV D/C T/L from Siddiqsons to South 500 kV Substation (32 km)

20Evacuation of Power from Lucky Electric Power Company Ltd.

660 2018-19 500 kV D/C T/L for In/Out of Siddiqsons - South 500 kV Substation (32 km)

21 Evacuation of Power from Dasu HPP 2160 2019-20 500 kV D/C T/L (615 km)

22 Evacuation of Power from Suki Kinari HPP 840 2019-20 500 kV D/C T/L (615 km)

Source: NTDC

12.6 Transmission Lines and Grid Stations with K-ElectricThe 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:

158


TABLE 50Transmission Lines and Grid Stations with K-Electric

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

Length of Transmission Lines in km

Overhead Lines

220 kV 321 321 323 323 323

132 kV 611 611 611 611 611

66 kV 149 149 149 149 149

Underground Lines

220 kV 17 17 15 15 15

132 kV 150 150 150 150 151

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

KEL’s Owned Grid Stations

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

Consumers Owned Grid Stations

220 kV 1 40 1 40 1 40 1 80 1 80

132 kV 5 n.a. 8 n.a. 9 n.a. 9 452 9 452

66 kV 0 0 0 0 0 0 0 0 0 0

Total No. of Grid Stations

66 3040 70 3040 72 7711 73 8271 74 8333

Source: KEL

TABLE 51Transmission/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 (Gross)

7,826.27 8,029.00 8,567.00 8,709.00 9,319.00

Auxiliary Consumption in KEL Plant

591.62 636.00 665.00 658.00 704.00

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

Energy Losses

T&D Losses (GWh) 4,795.52 4,343.71 4,217.00 3,880.00 3,817.00

Auxiliary Losses (%) 7.56 7.92 7.76 7.56 7.55

T&D Losses (%) 32.26 29.71 27.82 25.30 23.69Source: KEL

159


TABLE 52

Amount Injected (in million Rs.) to Reinforce/ Expand 220 and 132 kV Transmission System of K-Electric

Description2013-14 2014-15

FC LC Total FC LC Total

Grid Stations - - 671.00 - - 1568.00

Transmission and SCADA

- - 405.00 - - 425.00

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

Description2015-16 2016-17

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 - - 159.80FC: 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

0 2000 4000 6000 8000 10000 12000 14000 16000 18000

2010-11

2011-12

2012-13

2013-14

2014-15

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

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

160


Table 53Loading Position of 500 kV Grid Stations of NTDC (2014-15)

Name of Grid Station

Name of NTDC Region and

Name of DISCO

No. of Power Transformer

Voltage Level (kV)

Capacity of Transformer

(MVA)

Loading Position (%)

Rawat Islamabad (IESCO/GEPCO)

T-1 500/220 450 76.21

T-2 500/220 450 76.21

T-3 500/220 450 76.21

Sheikh Muhammadi

Peshawar

Islamabad (TESCO/PESCO)

T-1 500/220 450 77.05

T-2 500/220 450 77.05

T-9 500/220 450 77.05

Nokhar Lahore (GEPCO)

T-1 500/220 600 55.24

T-2 500/220 600 55.24

GattiLahore

(FESCO/GEPCO/ LESCO/MEPCO)

T-1 500/220 450 84.67

T-2 500/220 450 86.03

T-3 500/220 450 82.22

T-4 500/220 450 82.22

Sheikhupura Lahore (LESCO)

T-1 500/220 600 81.59

T-2 500/220 600 81.59

T-3 500/220 600 81.59

T-4 500/220 600 81.59

Multan Multan (MEPCO)

T-1 500/220 450 72.99

T-2 500/220 450 72.99

Muzafargarh Multan (MEPCO)

T-1 500/220 600 41.27

T-2 500/220 600 39.37

Yousafwala Multan (MEPCO/LESCO)

T-1 500/220 600 61.59

T-2 500/220 600 61.59

D.G. Khan Multan (MEPCO)

T-1 500/220 600 Proper meters not installed

T-2 500/220 600 PTW

Dadu Hyderabad (HESCO/SEPCO)

T-2 500/220 450 51.65

T-4 500/220 450 49.11

GudduHyderabad

(SEPCO/QESCO/ MEPCO)

T-1 500/220 450 24.13

T-2 500/220 450 24.13

T-3 500/220 450 24.13

NKI Hyderabad (HESCO/K-EL)

T-1 500/220 600 62.22

T-2 500/220 600 62.22

Jamshoro Hyderabad (HESCO/K-EL)

T-1 500/220 450 45.72

T-2 500/220 450 45.72Source: NTDC

161


Table 54Loading Position of 220 kV Grid Stations of NTDC (2014-15)



Name of DISCO


Voltage Level (kV)


(MVA)


Burhan Islamabad (IESCO/LESCO)

T-1 220/132 160 91.43T-4 220/132 160 91.43T-2 220/132 160 80.00T-3 220/132 250 82.19

Bannu Islamabad (PESCO/TESCO)

T-1 220/132 160 81.43T-2 220/132 160 81.43T-5 220/132 160 60.00

Daud Khail Islamabad (IESCO/FESCO)

T-1 220/132 160 90.14T-2 220/132 160 90.14

Mardan Islamabad (PESCO)

T-1 220/132 250 97.72T-2 220/132 160 100.29T-3 220/132 160 88.71

Sangjani Islamabad (IESCO)

T-1 220/132 160 97.14T-2 220/132 160 97.14T-3 220/132 160 84.29

Shahi Bagh Islamabad (PESCO/TESCO)

T-1 220/132 160 81.86T-2 220/132 160 81.86T-3 220/132 160 81.86

T-4 220/132 160 Shifted for Repair

University Islamabad (IESCO)

T-1 220/132 250 85.39T-2 220/132 250 18.26

NKLP Lahore Lahore (LESCO)

T-1 220/132 250 102.28T-2 220/132 250 105.02T-3 220/132 250 105.02

Ravi Lahore Lahore (LESCO)

T-1 220/132 250 93.15T-2 220/132 250 76.71T-3 220/132 250 76.71

Sarfraz Nagar Lahore (LESCO)

T-1 220/132 160 92.86T-2 220/132 160 92.86T-3 220/132 160 92.86T-4 220/132 160 92.86

Sialkot Lahore (GEPCO)

T-1 220/132 160 75.71T-2 220/132 160 75.71T-3 220/132 160 75.71

Kala Shah Kaku

Lahore (GEPCO/LESCO)

T-1 220/132 160 92.86T-2 220/132 160 92.86T-3 220/132 160 92.86

Band Road Lahore (LESCO)

T-1 220/132 250 65.30T-2 220/132 250 74.89T-3 220/132 250 65.30T-4 220/132 250 74.89

Shalamar Lahore (LESCO)

T-1 220/132 160 90.00T-2 220/132 160 86.71T-3 220/132 160 86.71

Ghakkar Lahore (GEPCO)

T-1 220/132 160 94.29T-2 220/132 160 78.57T-3 220/132 160 102.86T-4 220/132 160 94.29

WAPDA Town Lahore(LESCO)

T-1 220/132 160 82.86T-2 220/132 160 82.86T-3 220/132 160 82.86

Continued.....

162




Name of DISCO


Voltage Level (kV)


(MVA)


GZR Lahore (LESCO) T-1 220/132 250 82.19

Jaranwala Lahore (FESCO)

T-1 220/132 160 91.14T-2 220/132 160 91.43T-3 220/132 160 88.29T-4 220/132 160 100.00

Ludewala Lahore (FESCO)

T-1 220/132 160 104.29T-2 220/132 160 104.29T-3 220/132 160 104.29

Nishatabad Lahore (FESCO)

T-4 220/132 60/63.5 92.20T-5 220/132 160 95.00

Sammundari Road

Lahore (FESCO)

T-1 220/132 160 91.43T-2 220/132 160 109.29T-3 220/132 160 109.29

Toba Take Singh

Lahore(FESCO) T-1 220/132 250 106.85

Bahawalpur Multan (MEPCO)

T-1 220/132 160 91.43T-2 220/132 250 95.16T-3 220/132 250 95.16

Vehari Multan (MEPCO)

T-1 220/132 160 101.43T-2 220/132 160 101.43T-3 220/132 160 102.86

Muzafargarh Multan (MEPCO)

T-1 220/132 160 57.14T-2 220/132 160 57.14

Okara Multan (LESCO)

T-1 220/132 250 61.19T-2 220/132 250

Not EnergizedT-3 220/132 250

Kasswal Multan (MEPCO)

T-1 220/132 160 Not EnergizedT-2 220/132 160 111.43

Hala Road Hyderabad (HESCO)

T-1 220/132 160 90.00T-2 220/132 160 90.00T-3 220/132 160 92.86

Quetta Industrial

Hyderabad (QESCO)

T-1 220/132 160 74.29T-2 220/132 160 74.29T-3 220/132 160 71.43

Sibbi Hyderabad (QESCO)

T-1 220/132 160 77.43T-2 220/132 160 77.43

Shikarpur Hyderabad (SEPCO)

T-1 220/132 160 94.29T-2 220/132 160 91.43T-3 220/132 160 91.43

TMK Road Hyderabad (HESCO)

T-1 220/132 160 98.57T-2 220/132 160 97.14

Daharki Hyderabad (SEPCO)

T-1 220/132 250 56.62T-2 220/132 160 52.86

Rohri Hyderabad (SEPCO)

T-1 220/132 250 77.63T-2 220/132 250 29.22

Khuzdar Hyderabad (QESCO)

T-1 220/132 160 97.14T-2 220/132 160 48.57

Loralai Hyderabad (QESCO)

T-1 220/132 250 Not EnergizedT-2 220/132 250 56.62

Source: NTDC

13ELECTRICITY DISTRIBUTION

165


13. ELECTRICITY DISTRIBUTION

13.1 GeneralPresently 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 55List of Licenses Issued to Distribution Companies

S. No.

CompanyNumber of

Consumers (as on 30th June, 2015)

Date of Licence Issued

Licence Valid Until

Distribution Companies working in Public Sector

1 Peshawar Electric Supply Company Limited 2,956,567 30-04-2002 29-04-2022

2Tribal Areas Electricity Supply Company Limited

441,562 12-08-2013 11-08-2033

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 21-07-2029Source: National Electric Power Regulatory Authority

166


TABLE 56Service Area of Distribution Companies

DISCOService Area

(Sq. km)Service Area

PESCO 77,474 Whole Province of Khyber Pakhtunkhwa, except tribal areas

TESCO 27,220

Federally Administrated Tribal Areas (FATA) (comprising of Bajaur, Mohmand, Khyber, Ourakzai, Kurrum, North Wazirstan, South Wazirstan 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,MandiBahauddin,Hafizabad,Narowal,Gujrat

LESCO 19,064 Lahore, Sheikhupura, Kasur, Okara, Nankana

FESCO 36,122 Faisalabad, Sargodha, Khushab, Jhang, Toba Tek Singh, Bhalwal, Mianwali, Bhakkar

MEPCO 105,505 Multan, Rahim Yar Khan, Khanewal, Sahiwal, Pakpattan, Vehari, Muzaffargarh, Dera Ghazi Khan, Leiah, Rajan Pur, Bahawalpur, Lodhran, Bahawalnagar

HESCO 81,087

All Province of Sindh except Karachi, Sukkur, Ghotki, Khairpur, Kashmore, Kandhkot, Jacobabad, Shikarpur, Larkana, Kambar, Shahdadkot, Dadu and some portions of Jamshoro, Naushehro Feroz, Shaheed Benazirabad and Rahimyar Khan

SEPCO 56,300 Sukkur, Ghotki, Khairpur, Kashmore, Kandhkot, Jacobabad, Shikarpur, Larkana, Kambar, Shahdadkot, Dadu and some portions of Jamshoro, Naushehro Feroz, Shaheed Benazirabad and Rahimyar Khan

QESCO 334,616 Whole Province of Balochistan, except Lasbela where K-Electric is responsible for distribution of power

K-Electric Limited

6,500 Entire Karachi and its suburbs upto Dhabeji and Gharo in Sindh and over Hub, Uthal, Vindhar and Bela in Balochistan

Source: National Electric Power Regulatory Authority

13.2 Function of Distribution CompaniesThe 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 classifiedas 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 PerformanceThe 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:

System Average Interruption Frequency Index (SAIFI) =

Total annual number of all Consumer Power Supply InterruptionsTotal number of consumers served by the distribution company in a given year

System Average Interruption Duration Index (SAIDI) = Aggregate sum of all Consumer Power Supply Interruption durations in minutes

Total number of consumers served by the distribution company in a given year

167


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 57Comparison of SAIFI and SAIDI of all Distribution Companies

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

Total Number of Consumers

(Nos.)

PESCO 2459330 2542747 2530655 2588473 2618779TESCO - - - 390723 384031IESCO 2094299 2206006 2260203 2342241 2423317GEPCO 2500268 2608374 2568859 2736688 2812997LESCO 2959110 3052299 3164986 3286668 3432160FESCO 2996549 3278533 3214275 3288932 2445562MEPCO 4095946 4290373 4535062 4693061 4989020HESCO 1539637 883335 915805 952296 976923SEPCO - 643197 687045 711727 721087QESCO 487620 503158 516327 535145 561280

K-EL 2370738 2388579 2385100 2358357 2317947BTPL 6756 8845 11838 15636 16879Total 21510253 22405446 22790155 23899947 23699982

Total Annual Number of Consumer

Power Supply Interruptions


K-EL 82737192 77612818 74576586 58293812 51478645BTPL 8291 116 40510 105 81

Aggregate sum of all Consumer Power Supply Interruptions (Duration in

Minutes)


K-EL 5195969221 4438509649 4270360371 3526349005 3083517500BTPL 339306 14658 81454 12303 12107Total 201245110365 129314294218 185839047790 202350379330 190224731097

System Average Interruption Frequency

Index (SAIFI), Power Supply

Interruptions per consumer per year

PESCO 238.79 323.00 341.57 316.45 315.40TESCO - - - 0.12 0.10IESCO 0.41 0.59 0.62 0.05 0.04GEPCO 25.29 27.77 27.14 10.53 10.41LESCO 39.29 29.39 50.57 78.04 52.49FESCO 38.63 59.39 56.80 35.40 46.54MEPCO 185.52 185.29 149.68 201.53 177.61HESCO 1501.62 770.28 730.38 229.93 202.33SEPCO - 341.43 4177.68 251.48 227.96QESCO 164.98 156.08 153.82 144.95 112.58

K-EL 34.90 32.49 31.27 24.71 22.21BTPL 1.23 0.01 3.42 0.006 0.0095

System Average Interruption

Duration Index (SAIDI), Power Supply Interruptions

Durations

PESCO 19535.60 28189.00 29570.37 27946.60 27934.98TESCO - - - 2.09 1.32IESCO 22.60 37.49 34.80 1.66 0.10GEPCO 317.10 291.58 263.22 13.14 13.20LESCO 3469.40 2610.78 4615.74 4759.61 3010.29FESCO 21241.00 1320.98 1250.66 1137.02 2682.58MEPCO 15896.20 16073.48 12813.89 17704.58 15677.65HESCO 1035.60 23990.80 21204.64 16678.66 10642.74SEPCO - 18233.00 4799.92 2442.73 2141.36QESCO 13419.80 12810.68 12634.96 11868.07 7506.81

K-EL 2191.70 1857.97 1790.43 1495.25 1330.30BTPL 50.20 1.60 6.90 0.78 1.43

Source: Distribution Companies / NEPRA

168


0

500

1000

1500

2000

2500

3000

3500

4000

4500

System Average Interruption Frequency IndexPower Supply Interruptions per Consumer per Year

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

0.00

5000.00

10000.00

15000.00

20000.00

25000.00

30000.00

System Average Interruption Duration IndexPower Supply Interruptions Durations

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

169


TABLE 58Peak 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 4.34Source: Distribution Companies / KEL

TABLE 59 Category-wise Number of Consumers

DIS

CO

As on 30th June Domestic Commercial Industrial Agricultural Public

Lighting Bulk Supply Others Total

PES

CO

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

2014 2523470 289155 29760 23441 1028 878 46 2867778

2015 2602181 298739 30344 23328 1040 888 47 2956567

TES

CO

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

2014 400600 28202 4081 8548 0 55 0 441486

2015 400613 28217 4101 8576 0 55 0 441562

IESC

O

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

2014 2013135 340925 14534 8052 1659 957 40 2379302

2015 2085256 350989 15048 8192 1674 968 40 2462167Continued.....

170


DIS

CO

As on 30th June Domestic Commercial Industrial Agricultural Public

Lighting Bulk Supply Others TotalG

EPC

O

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

2014 2419346 304496 57965 41583 507 141 15 2824053

2015 2506136 313573 60542 42563 514 149 16 2923493

LESC

O

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

2014 3052697 524702 75006 57313 2154 491 223 3712586

2015 3228511 542738 77277 58382 2227 490 237 3909862

FESC

O

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

2014 2870418 332675 45120 38921 1470 215 111 3288930

2015 3012756 344642 46602 39522 1500 218 117 3445357

MEP

CO

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

2014 4278223 455088 49599 75484 1365 420 117 4860296

2015 4508987 476683 51135 77317 1402 428 120 5116072

HES

CO

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

2014 777599 143685 13834 16198 322 533 92 952263

2015 798206 146831 14311 16578 332 533 97 976888

SEP

CO

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

2015 581305 115574 12094 12484 412 504 19 722392

QES

CO

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

2014 414231 102089 3549 28630 243 234 4 548980

2015 423876 105721 3662 31139 247 238 4 564887

K-E

lect

ric

Lim

ited

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

2014 1650034 438150 20464 2410 74 202 2 2111336

2015 1695782 439130 20613 2488 77 198 2 2158290

Tota

l in

PEP

CO

Sy

stem

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

2014 19322664 2635089 305294 310578 9158 4421 666 22587870

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

171


TABLE 60Category-wise Sanctioned Load (MW)

DIS

CO As on

30th June

Domestic Commercial Industrial Agricultural Public Lighting Bulk Supply Others TotalP

ESC

O

2011 2808 562 1013 247 60 227 4 49212012 2968 582 1162 168 61 227 4 51722013 3119 601 1209 169 59 228 4 53892014 3271 630 1278 170 59 230 4 56422015 3427 659 1328 170 55 244 4 5887

TES

CO

2011 751 34 820 890 0 4 0 24992012 752 34 800 920 0 4 0 25102013 754 34 810 920 0 4 0 25222014 754 35 860 920 0 4 0 25732015 754 35 960 930 0 4 0 2683

IESC

O

2011 3162 843 846 76 98 427 261 57132012 3298 922 875 80 99 432 269 59752013 3452 960 912 84 99 459 283 62482014 3575 1005 942 86 99 469 289 64662015 3723 1043 970 89 99 483 290 6698

GEP

CO

2011 2959 551 1270 255 34 65 1 51352012 3096 570 1327 266 34 67 1 53612013 3237 590 1390 286 34 67 1 56052014 3380 616 1446 291 34 70 1 58382015 3543 647 1528 297 34 89 1 6139

LESC

O

2011 4011 1269 3207 534 108 174 40 93432012 4183 1313 3385 549 109 177 38 97542013 4399 1367 3547 572 112 178 40 102152014 4606 1420 3767 584 113 176 40 107062015 4912 1482 3915 596 112 179 42 11238

FESC

O

2011 6287 645 1442 390 10 122 6 89022012 6529 671 1533 421 10 134 6 93042013 6758 699 1681 433 10 137 6 97242014 6923 730 1774 445 11 150 6 100392015 7290 768 1901 451 11 187 7 10615

MEP

CO

2011 5008 747 1819 1026 14 79 22 87152012 5288 785 1893 1074 15 82 23 91602013 5646 828 2008 1142 15 87 23 97482014 5916 878 2118 1168 15 99 23 102192015 6292 917 2194 1195 15 105 24 10743

HES

CO

2011 1543 410 896 360 35 82 12 33382012 965 245 623 209 25 35 8 21102013 998 251 695 216 36 25 8 22282014 1037 260 737 226 44 26 8 23372015 1065 269 777 229 45 26 8 2420

SEP

CO

2012 610 176 327 160 12 50 2 13372013 610 176 327 160 12 50 2 13372014 638 185 357 176 12 52 2 14222015 655 192 363 179 12 52 2 1455

QES

CO

2011 578 154 136 562 5 47 0 14822012 591 158 139 569 5 49 0 15112013 605 163 144 662 5 50 0 16292014 618 168 151 789 5 52 0 17832015 630 174 158 864 5 52 0 1885

K-E

lect

ric

Lim

ited

2011 2744 872 1620 30 0 525 0 57912012 2922 1082 1691 32 1 234 0 59622013 3393 1481 1968 82 7 270 0 72012014 3741 1504 1544 37 1 123 0 69502015 4008 1579 1674 40 1 135 0 7437

Tota

l in

P

EPC

O

Syst

em

2011 27107 5215 11449 4340 364 1227 346 500482012 28280 5456 12065 4416 371 1256 350 521942013 29577 5669 12722 4644 382 1284 367 546462014 30718 5928 13430 4854 392 1328 374 570242015 32292 6187 14094 5000 389 1422 378 59763

Source: Distribution Companies / KEL

172


TABLE 61Category-wise Electricity Sold (GWh)

DIS

CO

Year Domestic Commercial Industrial Agricultural Public Lighting

Bulk Supply Others Total

PES

CO

2010-11 4041 527 1562 291 21 533 2 69762011-12 4048 553 1777 142 21 518 2 70622012-13 4048 550 1889 111 20 541 2 71622013-14 4205 622 1989 100 14 539 3 74712014-15 4297 654 2020 93 14 520 2 7599

TES

CO

2010-11 1536 15 91 84 0 9 0 17352011-12 1295 14 78 72 0 7 0 14662012-13 1185 9 42 52 0 6 0 12942013-14 1225 10 63 59 0 7 0 13642014-15 973 6 63 52 0 7 0 1101

IESC

O

2010-11 3367 896 1561 90 93 636 1031 76742011-12 3294 869 1640 86 76 663 909 75372012-13 3410 862 1656 87 76 1668 4 77632013-14 3681 894 1644 93 78 1798 4 81922014-15 3704 844 1671 93 76 1755 4 8147

GEP

CO

2010-11 3632 429 1783 319 8 268 1 64392011-12 3444 396 1741 328 6 261 1 61782012-13 3281 361 1704 301 6 267 1 59202013-14 3860 399 1966 304 6 292 1 68282014-15 3987 405 2077 285 6 293 1 7055

LESC

O

2010-11 5900 1225 6036 1062 96 416 5 147412011-12 5657 1165 6120 1008 98 415 5 144672012-13 5566 1115 6062 1009 101 427 5 142852013-14 6278 1215 6773 1127 103 446 7 159482014-15 6550 1235 6888 1084 94 469 8 16328

FESC

O

2010-11 3923 499 3079 848 7 236 6 85962011-12 3790 468 3181 857 7 274 4 85802012-13 3787 455 3333 717 7 284 4 85862013-14 4256 483 3804 831 7 296 4 96822014-15 4426 492 3972 788 7 317 4 10006

MEP

CO

2010-11 4982 612 2302 2105 24 159 6 101892011-12 4817 605 2559 1885 19 158 6 100492012-13 4939 579 2628 1588 16 156 7 99132013-14 5518 640 2991 2090 17 173 8 114372014-15 6014 657 3071 1745 16 200 8 11711

HES

CO

2010-11 3128 386 1170 783 101 218 27 58142011-12 1717 230 773 519 56 83 3 33812012-13 1926 237 775 454 82 48 3 35242013-14 2074 260 770 446 85 47 3 36852014-15 2421 271 760 416 105 43 4 4020

SEP

CO

2011-12 1630 164 407 254 73 134 5 26662012-13 1670 168 417 257 74 139 2 27262013-14 1650 168 417 243 78 145 1 27022014-15 1621 181 424 242 71 141 2 2682

QES

CO

2010-11 464 94 114 3265 4 107 0 40482011-12 513 98 122 3260 8 86 0 40862012-13 510 98 136 2974 5 89 0 38122013-14 575 102 134 2837 2 94 0 37442014-15 573 109 140 3068 3 101 0 3994

K-E

lect

ric

Lim

ited

2010-11 4257 1043 3447 125 82 955 163 100722011-12 4564 1128 3342 134 118 806 188 102802012-13 5083 1507 3445 149 111 473 174 109422013-14 5489 1507 3568 160 106 427 197 114542014-15 6161 1589 3648 166 110 411 208 12293

Tota

l in

P

EPC

O

Syst

em

2010-11 30972 4682 17699 8847 353 2581 1078 662132011-12 30203 4562 18399 8410 363 2598 936 654722012-13 30321 4434 18641 7550 387 3623 27 649842013-14 33322 4793 20551 8129 390 3837 31 710532014-15 34566 4853 21085 7866 393 3846 33 72643


173


TABLE 62Total Units Purchased, Sold and Losses

DIS

CO

YearUnit Purchased (GWh)

Unit Sold (GWh)

Losses

Through NTDC Through CPPs, SPPs etc.

Total Unit Purchased GWh %age

PES

CO

2010-11 10760 486 11246 6976 4270 37.962011-12 10980 50 11030 7062 3968 35.982012-13 10814 78 10892 7162 3730 34.252013-14 11250 51 11301 7471 3829 33.892014-15 11657 0 11657 7599 4058 34.81

TES

CO

2010-11 2326 0 2326 1735 591 25.412011-12 2071 0 2071 1466 605 29.212012-13 1643 0 1643 1294 349 21.252013-14 1758 0 1758 1364 394 22.412014-15 1406 0 1406 1101 305 21.68

IESC

O

2010-11 8509 0 8509 7674 835 9.812011-12 8330 0 8330 7537 793 9.522012-13 8573 0 8573 7763 810 9.452013-14 9049 0 9049 8192 857 9.472014-15 8993 0 8993 8147 846 9.41

GEP

CO

2010-11 7316 0 7316 6439 877 11.992011-12 6959 0 6959 6178 782 11.232012-13 6633 0 6633 5920 713 10.752013-14 7671 0 7671 6828 844 11.002014-15 7902 0 7902 7055 847 10.72

LESC

O

2010-11 16995 0 16995 14741 2254 13.262011-12 16727 0 16727 14467 2260 13.512012-13 16458 0 16458 14285 2173 13.212013-14 18425 0 18425 15948 2477 13.442014-15 19009 0 19009 16328 2681 14.10

FESC

O

2010-11 7522 2163 9685 8596 1089 11.242011-12 8725 890 9615 8580 1035 10.762012-13 7125 2511 9636 8586 1050 10.892013-14 7811 3099 10910 9682 1228 11.262014-15 11246 0 11246 10006 1240 11.03

MEP

CO

2010-11 7889 4559 12448 10189 2260 18.152011-12 6939 5517 12456 10049 2407 19.322012-13 9157 2790 11947 9913 2034 17.022013-14 13981 81 14062 11437 2625 18.662014-15 13820 39 13859 11711 2148 15.50

HES

CO

2010-11 8699 86 8785 5814 2971 33.822011-12 4431 248 4679 3381 1297 27.732012-13 3924 926 4850 3524 1326 27.332013-14 4605 405 5010 3685 1326 26.462014-15 4965 547 5512 4020 1492 27.08

SEP

CO

2011-12 2996 1403 4398 2666 1732 39.382012-13 4325 181 4506 2726 1780 39.512013-14 4129 269 4398 2702 1696 38.562014-15 4114 231 4346 2682 1664 38.29

QES

CO

2010-11 5093 19 5112 4048 1064 20.812011-12 5147 12 5159 4086 1073 20.802012-13 4670 11 4681 3812 869 18.572013-14 4784 12 4796 3744 1052 21.932014-15 5194 0 5194 3994 1200 23.10

Tota

l in

P

EPC

O

Syst

em

2010-11 75109 7313 82422 66213 16210 19.672011-12 73305 8119 81424 65472 15952 19.592012-13 73322 6497 79819 64984 14835 18.592013-14 83463 3916 87380 71053 16327 18.682014-15 88306 818 89124 72643 16481 18.49

K-E

lect

ric

Lim

ited Year

Unit Purchased (GWh)Unit Sold

(GWh)

Losses

K-EL Own Through NTDC Through CPPs + Others

Total Unit Purchased GWh %age

2010-11 7826 5449 2183 15458 10072 5386 34.842011-12 8029 5684 1546 15259 10280 4979 32.632012-13 8567 5463 1794 15824 10942 4882 30.852013-14 8709 5441 1841 15991 11454 4537 28.372014-15 9319 5427 2069 16815 12293 4522 26.89


174


TABLE 63Units Billed and Amount Realized in DISCOs (2014-15)

DISCO Unit Domestic Commercial Industrial Agricultural Public Lighting

Bulk Supply Others Total

PES

CO

* 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

% 80.64 97.41 99.67 74.11 98.08 63.59 100.04 87.92

TES

CO

* 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

% 72.29 31.04 105.45 68.21 0.00 0.00 0.00 73.23

IESC

O

* GWh 3704 844 1671 93 76 1755 4 8147

** Rs. Mln. 39306 17821 25337 1340 1158 24929 67 109958

***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

GEP

CO

* 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

% 99.68 100.16 97.05 106.35 129.11 59.42 539.63 97.14

LESC

O

* 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

% 97.46 98.72 94.32 89.78 96.87 98.95 37.01 95.82

FESC

O

* 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

% 98.97 99.25 99.54 107.94 94.24 100.34 171.53 100.06

MEP

CO

* 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

% 98.81 99.92 48.01 1.78 1184.77 13.81 324.64 102.33

HES

CO

* 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

% 55.62 95.44 94.05 87.80 78.68 28.39 1612.15 78.24

SEP

CO

* 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

% 38.75 96.46 81.23 64.11 19.54 71.91 43.49 57.81

QES

CO

* 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

% 56.60 93.43 97.32 20.38 51.72 102.19 100.00 32.56

K-E

lect

ric

Lim

ited

* 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

% 91.04 94.39 90.12 15.21 69.74 93.12 0.00 90.37

Tota

l in

P

EPC

O

Syst

em

* 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

% 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 AmountSource: Distribution Companies / KEL

175


TABLE 64Average Annual Electricity Consumption per Connection (kWh)

DIS

CO

Year Domestic Commercial Industrial AgriculturalPublic

LightingBulk

SupplyOthers Total

PES

CO

2010-11 1771 1992 66585 10811 24342 610619 50217 26852011-12 1714 2035 63117 6138 21883 592091 48913 26282012-13 1654 1967 65215 4790 19961 616990 42609 25752013-14 1666 2150 66825 4284 13687 614157 56522 26052014-15 1651 2188 66567 3970 13625 585023 50638 2570

TES

CO

2010-11 3846 525 22081 10052 0 166667 0 39432011-12 3242 498 19259 8494 0 127273 0 33312012-13 2958 320 10409 6083 0 109091 0 29322013-14 3058 355 15437 6902 0 127273 0 30902014-15 2429 213 15362 6063 0 127273 0 2493

IESC

O

2010-11 1861 2904 121982 12055 63265 780368 7870229 35852011-12 1750 2727 122966 11127 50465 797834 6586957 33882012-13 1746 2619 118565 10967 47293 1980998 27778 33662013-14 1828 2622 113114 11550 47016 1878788 100000 34432014-15 1776 2405 111045 11353 45400 1813017 100000 3309

GEP

CO

2010-11 1665 1532 33952 9012 16383 2042748 72857 25252011-12 1525 1377 31794 8793 13480 1934444 72000 23412012-13 1401 1224 29982 7401 11571 1918165 63133 21652013-14 1595 1310 33910 7314 11781 2073390 65000 24182014-15 1591 1291 34305 6705 12257 1967221 70375 2413

LESC

O

2010-11 2183 2509 88908 20412 51749 863921 25355 44492011-12 2014 2338 87007 18750 51200 849570 22180 42132012-13 1895 2184 83388 17970 48540 872679 23562 39912013-14 2057 2316 90299 19655 47734 908024 30762 42962014-15 2029 2276 89131 18569 42371 957122 32110 4176

FESC

O

2010-11 1502 1615 75853 24521 4804 1203827 55050 28692011-12 1397 1479 75555 23348 4645 1342941 43204 27602012-13 1349 1405 76029 18857 4756 1356746 34327 26712013-14 1483 1451 84311 21340 5020 1378837 37207 29442014-15 1469 1428 85228 19933 4960 1452110 37265 2904

MEP

CO

2010-11 1344 1515 51136 30968 18973 395312 57037 24112011-12 1239 1450 55382 26757 14296 389066 56727 22712012-13 1200 1335 54544 21433 12123 378832 60536 21212013-14 1290 1407 60295 27688 12637 411024 71538 23532014-15 1334 1379 60048 22572 11526 467804 68333 2289

HES

CO

2010-11 2516 1569 49983 29316 115651 277717 301124 37712011-12 2390 1666 59658 34217 113776 267161 37079 38182012-13 2583 1693 57785 28876 261656 96235 33222 38492013-14 2667 1812 55672 27527 262516 87298 35217 38692014-15 3033 1842 53123 25108 316627 80244 37216 4115

SEP

CO

2011-12 2952 1476 36518 20845 185929 278977 87759 38782012-13 2975 1492 36256 20909 181760 284488 95556 39042013-14 2880 1474 35241 19580 189390 290885 65556 37942014-15 2788 1564 35074 19385 171966 280635 87895 3712

QES

CO

2010-11 1208 1005 35120 154468 16653 510286 12500 80612011-12 1298 1027 36829 152384 31250 389773 12500 79212012-13 1264 992 39623 121486 19959 387991 12500 71852013-14 1389 996 37825 99092 9177 401496 10000 68212014-15 1352 1030 38230 98518 11781 424370 15000 7070

K-E

lect

ric

Lim

ited

2010-11 2607 2304 167371 55979 1438596 652322 54333333 47742011-12 2750 2471 162731 52839 1761194 1905437 62666667 48042012-13 3061 3332 168361 56957 1681818 1288828 174000000 51212013-14 3327 3439 174355 66390 1432432 2113861 98500000 54252014-15 3633 3619 176976 66720 1428571 2075758 104000000 5696

Tota

l in

P

EPC

O

Syst

em

2010-11 1788 1934 64816 31529 42078 654192 1531605 32602011-12 1680 1838 64245 29375 41730 648934 1209483 31112012-13 1620 1738 62798 25075 43362 855881 36140 29712013-14 1725 1819 67315 26175 42575 867801 47140 31462014-15 1716 1782 66913 24730 42074 860120 47369 3089


176


TABLE 65Distribution Losses (voltage category-wise)

DISCO Lossesof

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

GWh % GWh % GWh % GWh % GWh %

PESCO

* 627.90 5.60 600.10 5.40 391.90 3.60 379.50 3.40 379.50 3.30

** 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

TESCO

* 224.93 2.94 196.03 2.92 52.03 2.86 98.48 5.60 90.06 4.63

** 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

IESCO

* 170.00 2.00 147.00 1.80 151.00 1.80 151.00 1.67 177.00 1.96

** 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

GEPCO

* 135.22 1.85 114.00 1.64 103.00 1.55 141.00 1.84 127.00 1.61

** 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

LESCO

* 30.70 0.20 178.00 0.80 102.80 0.60 145.90 0.80 273.80 1.14

** 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

FESCO

* 157.92 1.60 107.84 1.10 137.00 1.30 211.87 1.90 n.p. n.p.

** 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

MEPCO

* 479.76 3.80 465.43 3.65 309.08 2.62 483.76 3.50 417.14 3.00

** 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

HESCO

* 360.74 4.13 180.37 3.90 171.87 3.50 163.03 3.30 244.83 4.40

** 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

SEPCO

* - - 193.35 4.24 179.79 3.99 125.07 2.84 113.82 2.62

** - - 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

QESCO

* 368.77 7.25 335.11 6.50 248.62 5.00 160.48 3.24 75.80 1.40

** 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

K-Electric Limited

* - - - 1.53 189.00 1.25 200.00 1.31 226.00 1.40

** - - - 28.60 4028.00 26.90 3678.00 24.30 3590.00 22.60

*** 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 systemSource: Distribution Companies / KEL

177


TABLE 66Status of Distribution Lines (km)

DISCO As on 30th June 132 kV 66 kV 33 kV 11 kV Total HT

Lines

Total LTLines

(0.4 kV)

PESCO

2011 1960 860 311 31698 34829 429322012 2033 861 311 32432 35637 433162013 2080 861 311 33006 36258 435602014 2147 841 171 33337 36496 438012015 2164 841 171 33337 36513 43957

TESCO

2011 259 383 805 7347 8794 63782012 259 383 805 7347 8794 63782013 259 383 805 7363 8810 63802014 259 383 805 7363 8810 63802015 259 383 805 7367 8814 6380

IESCO

2011 2480 581 153 22547 25761 251642012 2605 581 153 23012 26351 254772013 2702 581 153 23409 26845 258002014 2717 581 153 23596 27047 260092015 2772 581 153 24272 27778 26145

GEPCO

2011 1969 509 0 20096 22574 169972012 1969 509 0 20990 23468 173802013 1897 416 0 21971 24284 179552014 2054 332 0 22216 24602 180872015 2233 447 0 22402 25082 18087

LESCO

2011 0 0 0 25522 25522 144872012 0 0 0 25918 25918 145682013 2519 0 0 26297 28816 146472014 2572 0 0 26657 29229 147302015 2252 429 0 26657 29338 14808

FESCO

2011 1588 1298 0 36204 39090 242172012 1658 1296 0 36900 39854 248802013 1705 1292 0 37644 40641 254292014 1844 1260 0 38093 41197 257702015 1865 1260 0 38614 41739 25900

MEPCO

2011 2923 1314 0 66223 70460 445922012 2937 1314 0 67221 71472 451212013 2987 1266 0 68647 72900 459702014 3169 1154 0 69453 73776 462512015 3286 1154 0 71101 75541 46866

0.00

5.00

10.00

15.00

20.00

25.00

30.00

35.00

40.00

PESCO IESCO LESCO MEPCO SEPCO K-Electric

Figure 65: Distribution Losses (%) (2014-15)

132 kV system(including 66 & 33 kV)

11 kV and below system Overall system

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

Continued.....

178


DISCO As on 30th June 132 kV 66 kV 33 kV 11 kV Total HT

Lines

Total LTLines

(0.4 kV)

HESCO

2011 3876 1725 0 48059 53660 264422012 1900 969 0 25414 28283 137452013 1939 975 0 26196 29110 141322014 2067 975 0 26612 29654 143922015 2133 975 0 26913 30021 14687

SEPCO

2012 1976 756 0 23098 25830 129912013 1887 753 0 23814 26454 132722014 1900 753 0 24277 26930 134712015 1995 753 0 24277 27025 13471

QESCO

2011 3054 636 985 29503 34178 127492012 3985 636 985 31139 36745 136292013 4299 491 985 32153 37928 140422014 4299 491 985 33425 39200 143732015 4299 491 985 33425 39200 14654

K-Electric Limited

2011 761 149 0 n.p. n.p. n.p.2012 761 149 0 n.p. n.p. n.p.2013 761 149 0 8071 8981 n.p.2014 761 149 0 8335 9245 176452015 761 149 0 8834 9744 n.p.

Total in PEPCO System

2011 18109 7306 2254 287199 314868 2139582012 19322 7305 2254 293471 322352 2174852013 22274 7018 2254 300500 332046 2211872014 23028 6770 2114 305029 336941 2232642015 23258 7314 2114 308365 341051 224955


TABLE 67Feeders Outages Statistics of DISCOs (2014-15)

DIS

CO Nature of

Tripping

132 kV Feeders 66 kV Feeders 33 kV Feeders 11 kV Feeders All Feeders

No. of Tripping

Duration (Min.)

No. of Tripping

Duration (Min.)

No. of Tripping

Duration (Min.)

No. of Tripping

Duration (Min.)

No. of Tripping

Duration (Min.)

PES

CO

Planned 1282 136708 414 20926 3 910 165354 7417268 167053 7575812

Forced 285 68070 142 32397 37 1438 36436 2793641 36900 2895546

Total 1567 204778 556 53323 40 2348 201790 10210909 203953 10471358

TES

CO

Planned 33 3805 3900 3410 31 2380 2922 28850 6886 38445

Forced 32 2425 35 2845 27 2690 745 24870 839 32830

Total 65 6230 3935 6255 58 5070 3667 53720 7725 71275

IESC

O

Planned 72 27560 12 1420 21 1016 742160 44529600 742265 44559596

Forced 240 21600 111 9990 241 21690 12782 1046079 13374 1099359

Total 312 49160 123 11410 262 22706 754942 45575679 755639 45658955

GEP

CO Planned 10 3420 3 720 0 0 1458 207440 1471 207453

Forced 3350 545889 258 17892 0 0 7492 200855 11100 764636

Total 3360 545899 3678 17895 720 0 8950 408295 12571 972089

LESC

O

Planned 251 105926 10 3120 0 0 14526 4183920 14787 4292966

Forced 4824 321366 899 72696 0 0 20913 673260 26636 1067322

Total 5075 427292 909 75816 0 0 35439 4857180 41423 5360288

FESC

O

Planned 239 59204 100 24637 0 0 4007 624800 4346 708641

Forced 95 12422 70 5518 0 0 53312 670197 53477 688137

Total 334 71626 170 30155 0 0 57319 1294997 57823 1396778

MEP

CO Planned 838 238233 132 77659 0 0 3000 584167 3970 900059

Forced 2034 660760 2472 878057 0 0 138635 1179900 143141 2718717

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

179


DIS

CO Nature of

Tripping

132 kV Feeders 66 kV Feeders 33 kV Feeders 11 kV Feeders All Feeders

No. of Tripping

Duration (Min.)

No. of Tripping

Duration (Min.)

No. of Tripping

Duration (Min.)

No. of Tripping

Duration (Min.)

No. of Tripping

Duration (Min.)

HES

CO

Planned 79 26278 19 5470 0 0 298 72960 396 104708

Forced 516 84995 72 22381 0 0 34040 37440 34628 144816

Total 595 111273 91 27851 0 0 34338 110400 35024 249524

SEP

CO

Planned 230 103501 46 3443 0 0 45091 134795 45367 241739

Forced 163 38951 122 4098 0 0 33234 668776 33519 711825

Total 393 142452 168 7541 0 0 78325 803571 78886 953564

QES

CO

Planned 299 64848 299 64848

Forced 0 0

Total 299 64848 0 0 0 0 0 0 299 64848

K-E

lect

ric

Lim

ited

Planned 12 3662 0 0 12 3662

Forced 39 5190 0 0 39 5190

Total 51 8852 0 0 0 0 0 0 51 8852


TABLE 68Overloaded and Underutilized Distribution Feeders

DISCO YearNumber of Overloaded Feeders

(Above Designed Capacity)Number of Underutilized Feeders (10% Below Designed Capacity)

132 kV 66 kV 33 kV 11 kV 132 kV 66 kV 33 kV 11 kV

PES

CO

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

2013-14 20 0 0 16 15 0 1 72

2014-15 3 1 1 59 6 0 0 59

TES

CO

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

2013-14 2 2 0 0 0 2 0 72

2014-15 2 2 0 0 2 1 0 28

IESC

O

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

2013-14 0 0 0 36 5 0 0 68

2014-15 1 0 0 12 5 0 0 60

GEP

CO

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

2013-14 5 0 0 45 9 1 0 589

2014-15 2 0 0 2 3 0 0 81Continued.....

180


DISCO YearNumber of Overloaded Feeders

(Above Designed Capacity)Number of Underutilized Feeders (10% Below Designed Capacity)

132 kV 66 kV 33 kV 11 kV 132 kV 66 kV 33 kV 11 kVLE

SCO

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

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.

FESC

O

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

2013-14 2 0 0 248 6 0 0 107

2014-15 1 0 0 0 12 0 0 0

MEP

CO

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

2013-14 8 1 0 237 28 6 0 571

2014-15 5 1 0 436 15 0 0 420

HES

CO

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

2013-14 5 0 0 14 8 1 0 51

2014-15 4 0 0 24 10 0 0 47

SEP

CO

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

2014-15 4 1 0 125 4 0 0 21

QES

CO

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

2013-14 0 0 0 0 4 0 0 13

2014-15 0 0 0 0 2 0 0 17

K-E

lect

ric

Lim

ited





2014-15 n.p. n.p. n.p. 25 n.p. n.p. n.p. 69Source: Distribution Companies / KEL

181


TABLE 69Number of Circles, Divisions, Sub-Divisions and Feeders

DISCO As on 30th June Circles Divisions Sub-Divisions 11 kV

Feeders

PESCO

2012 6 32 145 7202013 6 33 147 7542014 6 33 147 7892015 6 34 149 841

TESCO

2012 1 6 18 1582013 1 6 18 1582014 1 6 18 1732015 1 6 18 188

IESCO

2012 5 19 101 8362013 5 19 105 8862014 5 19 105 9662015 5 19 108 965

GEPCO

2012 4 23 114 6922013 4 23 115 7052014 4 23 115 7252015 5 24 115 745

LESCO

2012 7 33 163 12582013 7 33 164 13412014 7 33 164 14372015 7 33 164 1540

FESCO

2012 4 21 118 8132013 4 21 118 8502014 4 21 118 9002015 4 24 130 937

MEPCO

2012 8 35 152 9252013 8 35 154 9722014 8 35 160 10392015 8 35 160 1104

HESCO

2012 3 14 62 4122013 3 14 62 4422014 3 14 62 410*2015 4 15 67 421

SEPCO

2012 3 13 55 3782013 3 13 55 3982014 3 13 55 4132015 3 16 60 433

QESCO

2012 3 11 41 5282013 4 12 43 5512014 4 13 44 5502015 4 14 46 570


2012 44 207 969 67202013 45 209 981 70572014 45 210 988 74022015 47 220 1017 7744

As on 30th June IBCs VIBCs Feeders

K-Electric Limited

2012 8 20 13072013 17 11 13212014 28 0 13752015 28 0 1431

* 32 feeders dismantled due to flood and cyclonic effects.Source: Distribution Companies / KEL

182


TABLE 70Status of Grid Stations (Nos.)

DIS

CO As on

30th June

132 kV 66 kV 33 kVTotalDISCO

OwnedCons.

OwnedSub-Total

DISCO Owned

Cons. Owned

Sub-Total

DISCO Owned

Cons. Owned

Sub-Total

PES

CO

2011 62 9 71 19 0 19 5 0 5 952012 64 9 73 18 0 18 4 0 4 952013 65 9 74 17 0 17 4 0 4 952014 67 9 76 17 0 17 4 0 4 972015 67 9 76 17 0 17 4 0 4 97

TES

CO

2011 7 0 7 8 1 9 0 0 0 162012 7 0 7 8 0 8 0 0 0 152013 7 0 7 8 0 8 0 0 0 152014 7 0 7 8 0 8 0 0 0 152015 7 0 7 8 0 8 0 0 0 15

IESC

O

2011 58 20 78 10 1 11 5 0 5 942012 62 20 82 9 1 10 5 0 5 972013 66 20 86 7 1 8 5 0 5 992014 73 20 93 7 1 8 3 0 3 1042015 78 22 100 4 1 5 3 0 3 108

GEP

CO

2011 41 0 41 8 0 8 0 0 0 492012 41 0 41 8 0 8 0 0 0 492013 41 0 41 8 0 8 0 0 0 492014 50 0 50 5 0 5 0 0 0 552015 52 0 52 4 0 4 0 0 0 56

LESC

O

2011 81 26 107 8 0 8 0 0 0 1152012 82 25 107 8 0 8 0 0 0 1152013 90 26 116 0 0 0 0 0 0 1162014 85 31 116 8 0 8 0 0 0 1242015 89 34 123 7 0 7 0 0 0 130

FESC

O

2011 55 15 70 26 0 26 0 0 0 962012 55 15 70 26 0 26 0 0 0 962013 58 16 74 24 0 24 0 0 0 982014 60 16 76 23 0 23 0 0 0 992015 62 18 80 23 0 23 0 0 0 103

MEP

CO

2011 78 7 85 27 0 27 0 0 0 1122012 82 7 89 26 0 26 0 0 0 1152013 88 8 96 24 0 24 0 0 0 1202014 92 8 100 22 0 22 0 0 0 1222015 96 8 104 21 0 21 0 0 0 125

HES

CO

2011 89 6 95 34 1 35 0 0 0 1302012 47 4 51 22 0 22 0 0 0 732013 48 5 53 22 0 22 0 0 0 752014 52 6 58 19 0 19 0 0 0 772015 53 6 59 18 0 18 0 0 0 77

SEP

CO

2012 43 0 43 13 0 13 0 0 0 562013 46 1 47 13 1 14 0 0 0 612014 47 1 48 12 1 13 0 0 0 612015 51 1 52 12 1 13 0 0 0 65

QES

CO

2011 52 0 52 10 0 10 26 0 26 882012 55 0 55 10 0 10 26 0 26 912013 56 0 56 10 0 10 26 0 26 922014 56 0 56 10 0 10 26 0 26 922015 58 0 58 10 0 10 25 0 25 93

K-E

lect

ric

Lim

ited

2011 50 5 55 3 0 3 0 0 0 582012 51 8 59 3 0 3 0 0 0 622013 52 9 61 3 0 3 0 0 0 642014 53 9 62 3 0 3 0 0 0 652015 54 9 63 3 0 3 0 0 0 66

Tota

l in

P

EPC

O

Syst

em

2011 523 83 606 150 3 153 36 0 36 7952012 538 80 618 148 1 149 35 0 35 8022013 565 85 650 133 2 135 35 0 35 8202014 589 91 680 131 2 133 33 0 33 8462015 613 98 711 124 2 126 32 0 32 869


183


TAB

LE 7

1D

ISC

O’s

Po

wer

Tra

nsf

orm

ers,

Cap

acit

ies

and

Lo

adin

g P

osi

tio

ns

of

Po

wer

Tra

nsf

orm

ers

DIS

CO

Year

No

. of

Po

wer

Tr

ansf

orm

ers

Cap

acit

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184


TABLE 72DISCO’s Number of 11 kV Feeders and Loading Positions of 11 kV Feeders

DISCO YearNo. of 11 kV

FeedersLoading Position of 11 kV Feeders (Nos.)

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 Limited

2014-15 1,431 156 69 40


2014-15 7,744 839 1,003 505


TABLE 73DISCO’s Number of Distribution Transformers, Capacities and

Loading Positions of Distribution Transformers

DISCO YearNo. of

Distribution Transformers

Capacity of Distribution Transformers

(kVA)

Loading Position of Distribution Transformers (Nos.)

Above 80% Above 90% Above 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

System 2014-15 638,171 39,663,833 46,481 23,693 17,775


185


TABLE 74Village Electrification in all Distribution Companies

DISCO Year Total Number of Villages Total Villages Electrified Percentage of Total Electrified

Villages

PESCO

2011 24667 18927 76.732012 25413 19651 77.332013 26017 20274 77.932014 26387 20554 77.892015 n.p. n.p. ......

TESCO

2011 522 522 100.002012 39 38 97.442013 39 38 97.442014 58 38 65.522015 187 93 49.73

IESCO

2011 1176 988 84.012012 1503 1341 89.222013 2717 2109 77.622014 2717 2109 77.622015 3144 2323 73.89

GEPCO

2011 9286 8698 93.672012 6331 6331 100.002013 6804 6804 100.002014 6854 6854 100.002015 6977 6889 98.74

LESCO

2011 2886 812 28.142012 410 406 99.022013 3686 2543 68.992014 3913 2728 69.722015 3913 2859 73.06

FESCO

2011 20893 19166 91.732012 21756 20161 92.672013 22657 21209 93.612014 22930 21505 93.792015 23277 21831 93.79

MEPCO

2011 57358 44937 78.342012 15092 14954 99.092013 21325 19902 93.332014 25055 21240 84.772015 26310 22287 84.71

HESCO

2011 46730 29114 62.302012 46730 30454 65.172013 23803 15961 67.052014 23803 16424 69.002015 23803 17010 71.46

SEPCO

2012 n.p n.p ---2013 22927 15795 68.892014 23263 16189 69.592015 23263 16515 70.99

QESCO

2011 17123 12938 75.562012 17123 14863 86.802013 17123 16016 93.542014 23819 17517 73.542015 23819 18017 75.64

K-Electric Limited

2011 889 510 57.372012 889 563 63.332013 889 636 71.542014 889 661 74.352015 889 702 78.97

Source: Distribution Companies / K-EL

186


TABLE 75Applications of New Connections Received, Energized and Pending

DISCO Year Applications Received (Nos.)

Connection Applications Pending (Nos.)Sanctioned (Nos.) Load (kW)

PESCO

2010-11 112499 83456 221989 290432011-12 80824 54701 100239 261232012-13 80374 89626 169208 -92522013-14 106014 82407 188240 236072014-15 102861 100773 217731 2088

TESCO

2010-11 131 63 964 682011-12 38 27 212 112012-13 117 84 1844 332013-14 609 63 258 5462014-15 641 162 2853 479

IESCO

2010-11 92666 80119 n.p. 125472011-12 99516 83992 210900 155242012-13 103609 85909 219208 177002013-14 96265 70856 211278 254092014-15 113855 81831 232254 32024

GEPCO

2010-11 122002 96795 315554 252072011-12 112162 86764 225697 253982012-13 109135 92599 215661 165362013-14 105194 94033 205952 111612014-15 126534 99735 241546 26799

LESCO

2010-11 178611 133856 412901 447552011-12 166193 115206 411911 509872012-13 179170 130407 460486 487632013-14 215984 146229 491192 697552014-15 244111 187150 531864 56961

FESCO

2010-11 120021 123040 405570 -30192011-12 111944 113807 420215 -18632012-13 146542 96499 252400 500432013-14 118884 90352 314228 285322014-15 125998 149562 n.p. -23564

MEPCO

2010-11 241676 160843 613292 808332011-12 271192 217886 473544 533062012-13 265242 238145 506865 270972013-14 258882 181169 389886 777132014-15 271874 249632 517342 22242

HESCO

2010-11 24380 23091 41357 12892011-12 19072 18234 32156 8382012-13 39289 27918 64599 113712013-14 39240 36833 63415 24072014-15 21445 24625 83803 -3180

SEPCO

2011-12 7061 5197 11203 18642012-13 n.p. n.p. n.p. n.p.2013-14 17165 15609 85220 15562014-15 11832 10196 32819 1636

QESCO

2010-11 13958 11381 19208 25772011-12 15113 13449 16737 16642012-13 13619 11846 59604 17732013-14 23848 18460 31048 53882014-15 16455 13762 2693

K-Electric Limited

2010-11 83682 36706 155002 469762011-12 50163 24898 164934 252652012-13 20384 9143 138703 112412013-14 12174 10955 280576 12192014-15 25242 22266 348310 2976

Source: Distribution Companies / KESC

187


TABLE 76Province-wise Electricity Consumption by Economic Groups of the Country (GWh)

Category Year Punjab* Sindh** Khyber

Pakhtunkhwa# Balochistan## K-Electric

Limited Total

Domestic

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

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

Commercial

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

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

Industrial

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

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

Agricultural

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

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

Public Lighting

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

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

Bulk Supply

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

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

Traction/ Others

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

2012-13 20.46 4.71 1.96 0.05 174.00 201.18

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

Total

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

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 excludedSource: National Electric Power Regulatory Authority

188


TABLE 77Province-wise Electricity Consumption by Economic Groups of the Country (%)

Category Year Punjab* Sindh** Khyber

Pakhtunkhwa# Balochistan## K-Electric

Limited Total

Domestic

2010-11 45.77 53.80 64.01 11.47 42.27 46.182011-12 44.87 55.34 62.65 12.54 44.40 45.902012-13 45.16 57.52 61.89 13.39 46.45 46.632013-14 45.30 58.31 61.45 15.36 47.92 47.042014-15 46.35 60.32 60.57 14.35 50.12 47.95

Commercial

2010-11 7.68 6.65 6.22 2.31 10.36 7.502011-12 7.48 6.52 6.65 2.41 10.97 7.512012-13 7.26 6.48 6.61 2.56 13.77 7.822013-14 6.97 6.71 7.15 2.72 13.16 7.642014-15 6.82 6.73 7.58 2.73 12.93 7.59

Industrial

2010-11 30.99 20.13 18.98 2.82 34.22 27.722011-12 32.56 19.52 21.75 2.99 32.51 28.702012-13 33.11 19.06 22.84 3.56 31.48 29.092013-14 32.98 18.60 23.22 3.59 31.15 29.232014-15 33.20 17.67 23.94 3.51 29.68 29.12

Agricultural

2010-11 9.29 13.47 4.31 80.65 1.24 11.762011-12 8.89 12.78 2.51 79.77 1.30 11.282012-13 7.97 11.38 1.93 78.03 1.36 10.142013-14 8.53 10.79 1.80 75.77 1.40 10.052014-15 7.50 9.82 1.66 76.81 1.35 9.46

Public Lighting

2010-11 0.48 1.74 0.24 0.10 0.81 0.572011-12 0.44 2.13 0.25 0.18 1.15 0.632012-13 0.44 2.50 0.24 0.13 1.01 0.662013-14 0.41 2.54 0.16 0.06 0.93 0.602014-15 0.38 2.63 0.16 0.07 0.89 0.59

Bulk Supply

2010-11 3.60 3.74 6.22 2.65 9.48 4.642011-12 3.78 3.58 6.16 2.10 7.84 4.492012-13 6.03 2.98 6.47 2.33 4.32 5.392013-14 5.77 2.99 6.18 2.51 3.73 5.172014-15 5.70 2.75 6.05 2.53 3.34 5.01

Traction/ Others

2010-11 2.20 0.46 0.03 0.00 1.62 1.632011-12 1.98 0.14 0.03 0.00 1.83 1.482012-13 0.04 0.08 0.02 0.00 1.59 0.262013-14 0.05 0.07 0.03 0.00 1.72 0.282014-15 0.05 0.08 0.03 0.00 1.69 0.28

Total

2010-11 100.00 100.00 100.00 100.00 100.00 100.002011-12 100.00 100.00 100.00 100.00 100.00 100.002012-13 100.00 100.00 100.00 100.00 100.00 100.002013-14 100.00 100.00 100.00 100.00 100.00 100.002014-15 100.00 100.00 100.00 100.00 100.00 100.00

* Islamabad Capital Territory is included ** Consumption in K-EL Area is not included# FATA is included ## Area served by K-EL is excludedSource: National Electric Power Regulatory Authority

14ELECTRICITY TARIFF

191


14. ELECTRICITY TARIFF

The determination of tariff for electric power services is one of the primary responsibilities of NEPRA. NEPRA determineselectricitytariff,keepinginviewtheprinciplesofeconomicefficiencyandservicequalityaccordingto 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 thesetotheFederalGovernmentfornotification.

14.1 Tariff SettingTheproceduresand standards inaccordancewithwhich tariffs are required tobedetermined,modifiedorrevised 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 equipmentandfacilitiesforimprovedandefficientservice;

iv) Tariffsshould includeamechanismtoallow licenseesabenefit from,andpenalties for failure toachieve,theefficienciesinthecostofprovidingtheserviceandthequalityofservice;

v) Tariffsshouldreflectmarginalcostprinciples totheextent feasible,keeping inviewthefinancialstability 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, aslongassuchtariffsarefinanciallysustainable;

ix) Tariffsshould,totheextentfeasible,reflectthefullcostofservicetoconsumergroupswithsimilarservice requirements;

x) TariffshouldtakeintoaccountGovernmentsubsidiesortheneedforadjustmenttofinanceruralelectrificationinaccordancewiththepoliciesoftheGovernment;

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; andxiii) 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:

192


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 78NEPRA’s Monthly Fuel Price Adjustments in respect of DISCOs

MonthPESCO TESCO IESCO GEPCO LESCO FESCO MEPCO HESCO SEPCO QESCO

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

193


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13.0

0 9.

50

10.0

0 10

.50

10.2

0 13

.00

13.0

0 B2

5-5

00 k

W (a

t 40

0 Vo

lts)

400.

0014

.00

14.5

0 11

.50

14.0

0 11

.50

12.5

0 13

.00

12.0

0 14

.00

4.00

B2

- T

OU

(Pea

k)19

.00

19.0

0 15

.00

19.0

0 15

.00

16.0

0 16

.00

16.0

0 19

.00

19.0

0 B2

- T

OU

(Off-

Peak

)40

0.00

13.1

0 14

.30

9.05

12

.80

9.30

9.

60

10.3

0 10

.00

12.8

0 12

.80

B3 -

TO

U (P

eak)

19.0

0 19

.00

15.0

0 19

.00

15.0

0 16

.00

16.0

0 16

.00

19.0

0 19

.00

B3 -

TO

U (O

ff-Pe

ak)

380.

0013

.00

14.2

0 8.

85

12.7

0 9.

10

9.50

10

.20

9.80

12

.70

12.7

0 B4

- T

OU

(Pea

k)19

.00

19.0

0 15

.00

19.0

0 15

.00

16.0

0 16

.00

16.0

0 19

.00

19.0

0 B

ULK

SU

PP

LYC

1 (a

) Sup

ply

at

400

Volt

s (u

p t

o 5

kW

)15

.00

15.5

0 12

.50

15.0

0 12

.50

13.5

0 14

.00

13.0

0 15

.00

15.0

0

C1

(b) S

upp

ly a

t 40

0 Vo

lts

(exc

eed

ing

5 k

W)

400.

0014

.50

15.0

0 12

.00

14.5

0 12

.00

13.0

0 13

.50

12.5

0 14

.50

14.5

0 Co

ntin

ued.

....

194


PAR

TIC

ULA

RS

*P

ESC

OT

ESC

OIE

SCO

GEP

CO

LESC

OFE

SCO

MEP

CO

HES

CO

SEP

CO

QES

CO

Var

iab

le C

har

ges

(R

s./k

Wh

) Ti

me

of U

se (T

OU

) - P

eak

19.0

0 19

.00

15.0

0 19

.00

15.0

0 16

.00

16.0

0 16

.00

19.0

0 19

.00

Tim

e of

Use

(TO

U) -

Off-

Peak

400.

0013

.30

14.5

0 9.

25

13.0

0 9.

50

10.0

0 10

.50

10.2

0 13

.00

13.0

0

C2

Sup

ply

at

11 k

V38

0.00

14.3

0 14

.80

11.8

0 14

.30

11.8

0 12

.80

13.3

0 12

.30

14.3

0 14

.30

Tim

e of

Use

(TO

U) -

Pea

k19

.00

19.0

0 15

.00

19.0

0 15

.00

16.0

0 16

.00

16.0

0 19

.00

19.0

0 Ti

me

of U

se (T

OU

) - O

ff-Pe

ak38

0.00

13.1

0 14

.30

9.05

12

.80

9.30

9.

60

10.3

0 10

.00

12.8

0 12

.80

C3

Sup

ply

ab

ove

11

kV36

0.00

14.2

0 14

.70

11.7

0 14

.20

11.7

0 12

.70

13.2

0 12

.20

14.2

0 14

.20

Tim

e of

Use

(TO

U) -

Pea

k19

.00

19.0

0 15

.00

19.0

0 15

.00

16.0

0 16

.00

16.0

0 19

.00

19.0

0 Ti

me

of U

se (T

OU

) - O

ff-Pe

ak36

0.00

13.0

0 14

.20

8.85

12

.70

9.10

9.

50

10.2

0 9.

80

12.7

0 12

.70

AG

RIC

ULT

UR

AL

SCA

RP

14.5

0 15

.00

12.0

0 14

.50

12.0

0 13

.00

13.5

0 12

.50

15.5

0 15

.20

Tim

e of

Use

(TO

U) -

Pea

k19

.00

19.0

0 15

.00

19.0

0 15

.00

16.0

0 16

.00

16.0

0 19

.00

19.0

0 Ti

me

of U

se (T

OU

) - O

ff-Pe

ak20

0.00

13.0

0 14

.20

8.85

12

.70

9.10

9.

50

10.2

0 9.

80

12.7

0 12

.70

Ag

ricu

ltur

al T

ube-

wel

ls20

0.00

14.0

0 14

.50

11.5

0 14

.00

11.5

0 12

.50

13.0

0 12

.00

15.0

0 14

.70

Tim

e of

Use

(TO

U) -

Pea

k19

.00

19.0

0 15

.00

19.0

0 15

.00

16.0

0 16

.00

16.0

0 19

.00

19.0

0 Ti

me

of U

se (T

OU

) - O

ff-Pe

ak20

0.00

13.0

0 14

.20

8.85

12

.70

9.10

9.

50

10.2

0 9.

80

12.7

0 12

.70

PU

BLI

C L

IGH

TIN

G14

.00

15.0

0 14

.00

14.0

0 14

.00

14.0

0 14

.00

14.0

0 14

.00

14.0

0 R

ESID

ENT

IAL

CO

LON

IES

AT

TAC

HED

. TO

IN

DU

STR

IES

14.0

0 15

.00

14.0

0 14

.00

14.0

0 14

.00

14.0

0 14

.00

14.0

0 14

.00

Rai

lway

Tra

ctio

n

14

.00

14

.00

Sp

ecia

l Co

ntra

cts

- A

J&K

360.

0014

.00

11

.24

14.0

0

Ti

me

of U

se (T

OU

) - P

eak

19.0

0

15.0

0 19

.00

Tim

e of

Use

(TO

U) -

Off-

Peak

360.

0013

.30

8.

85

12.7

0

Spec

ial C

ont

ract

s -

Raw

at

Lab

.*

14

.00

* Fi

xed

Char

ges (

Rs./

kW/M

onth

)So

urce

: Nati

onal

Ele

ctric

Pow

er R

egul

ator

y Au

thor

ity, I

slam

abad

195


TAB

LE 8

0St

atem

ent

of

GO

P A

pp

lica

ble

(N

oti

fied

) Ta

riff

PAR

TIC

ULA

RS

wit

h e

ffec

t fr

om

15

-03-

2011

w

ith

eff

ect

fro

m

06-0

5-20

11

wit

h e

ffec

t fr

om

16

-05-

2012

w.e

.f 0

5-08

-201

3 ex

cep

t P

ESC

O

wit

h e

ffec

t fr

om

11

-10-

2013

w

ith

eff

ect

fro

m

01-1

0-20

14*

wit

h e

ffec

t fr

om

10

-06-

2015

**

***

****

***

****

***

****

***

****

***

****

***

****

***

****

RES

IDEN

TIA

L

For

Sanc

tio

ned

Loa

d le

ss t

han

5 kW

2.

00

2.

00

2.00

Up

to

50

Uni

ts

1.87

1.87

2.00

2.00

For

Co

nsum

pti

on

exce

edin

g 5

0 U

nits

01-1

00 U

nits

4.

45

4.

54

5.

79

5.

79

5.

79

5.

79

5.79

101-

200

Uni

ts

8.11

8.11

8.

11

201-

300

Uni

ts

6.73

6.86

8.11

8.11

12.0

9

12.0

9

10.2

0

301-

700

Uni

ts

10.6

5

10.6

5

12.3

3

12.3

3

16.0

0

16.0

0

16.0

0

Ab

ove

700

Uni

ts

13.2

9

13.2

9

15.0

7

15.0

7

18.0

0

18.0

0

18.0

0

For

Sanc

tio

ned

Loa

d 5

kW

and

ab

ove

Tim

e of

Use

(TO

U) -

Pea

k

12.2

5

12.2

5

13.9

9

13.9

9

18.0

0

18.0

0

18.0

0

Tim

e of

Use

(TO

U) -

Off-

Peak

6.

70

6.

70

8.

22

8.

22

12

.50

12

.50

12

.50

CO

MM

ERC

IAL

For

Sanc

tio

ned

Loa

d le

ss t

han

5 kW

13

.00

13

.00

14

.77

18

.00

18

.00

18

.00

18

.00

For

Sanc

tio

ned

Loa

d 5

kW

and

ab

ove

Reg

ular

360

8.14

36

7 8.

14

400

9.72

40

0 16

.00

400

16.0

0 40

0 16

.00

400

16.0

0

Tim

e of

Use

(TO

U) -

Pea

k

11.4

9

11.4

9

13.2

0

18.0

0

18.0

0

18.0

0

18.0

0

Tim

e of

Use

(TO

U) -

Off-

Peak

360

6.50

36

7 6.

50

400

8.01

40

0 12

.50

400

12.5

0 40

0 12

.50

400

12.5

0

IND

UST

RIA

L

B1 u

p t

o 2

5 kW

(at

400/

230

Volt

s)

8.90

8.90

10.5

1

14.5

0

14.5

0

14.5

0

14.5

0

B2 2

5-50

0 kW

(at

400

Volt

s)36

0 7.

59

367

7.59

40

0 9.

14

400

14.0

0 40

0 14

.00

400

14.0

040

0 18

.00

B1 -

TO

U (P

eak)

12

.25

12

.25

13

.99

18

.00

18

.00

18

.00

12

.50

B1 -

TO

U (O

ff-Pe

ak)

6.

70

6.

70

8.

22

12

.50

12

.50

12

.50

14

.00

B2 -

TO

U (P

eak)

11

.08

11

.08

12

.77

18

.00

18

.00

18

.00

18

.00

B2 -

TO

U (O

ff-Pe

ak)

360

6.50

36

7 6.

50

400

8.01

40

0 12

.30

400

12.3

0 40

0 12

.30

400

12.2

9

B3 -

TO

U (P

eak)

(up

to

500

0 kW

at

11

kV, 3

3 kV

)

10.9

9

10.9

9

12.6

8

18.0

0

18.0

0

18.0

0

18.0

0

B3 -

TO

U (O

ff-Pe

ak)

349

6.25

35

6 6.

25

380

7.75

38

0 12

.20

380

12.2

0 38

0 12

.20

380

12.2

0

B4 -

TO

U (P

eak)

(at

66 k

V, 1

32 k

V

and

ab

ove

)

10.6

9

10.6

9

12.3

7

18.0

0

18.0

0

18.0

0

18.0

0

B4 -

TO

U (O

ff-Pe

ak)

336

5.97

34

3 5.

97

360

7.46

36

0 12

.10

360

12.1

0 36

0 12

.10

360

12.1

0 Co

ntin

ued.

....

196


PAR

TIC

ULA

RS

wit

h e

ffec

t fr

om

15

-03-

2011

w

ith

eff

ect

fro

m

06-0

5-20

11

wit

h e

ffec

t fr

om

16

-05-

2012

w.e

.f 0

5-08

-201

3 ex

cep

t P

ESC

O

wit

h e

ffec

t fr

om

11

-10-

2013

w

ith

eff

ect

fro

m

01-1

0-20

14*

wit

h e

ffec

t fr

om

10

-06-

2015

****

***

****

***

****

***

****

***

****

***

****

***

****

***

**B

ULK

SU

PP

LY

C1

(a) S

upp

ly a

t 40

0 Vo

lts

- le

ss

than

5 k

W

9.90

9.90

11.5

5

15.0

0

15.0

0

15.0

0

15.0

0

C1

(b) S

upp

ly a

t 40

0 Vo

lts

- 5

kW

and

ab

ove

360

8.75

36

7 8.

75

400

10.3

5 40

0 14

.50

400

14.5

0 40

0 14

.50

400

14.5

0

Tim

e of

Use

(TO

U) -

Pea

k

11.3

1

11.3

1

13.0

1

18.0

0

18.0

0

18.0

0

18.0

0

Tim

e of

Use

(TO

U) -

Off-

Peak

360

6.50

36

7 6.

50

400

8.01

40

0 12

.50

400

12.5

0 40

0 12

.50

400

12.5

0

C2

Sup

ply

at

11 k

V34

9 8.

65

356

8.65

38

0 10

.25

380

14.3

0 38

0 14

.30

380

14.3

038

0 14

.30

Tim

e of

Use

(TO

U) -

Pea

k

10.9

1

10.9

1

12.6

0

18.0

0

18.0

0

18.0

0

18.0

0

Tim

e of

Use

(TO

U) -

Off-

Peak

349

6.25

35

6 6.

25

380

7.75

38

0 12

.30

380

12.3

0 38

0 12

.30

380

12.3

0

C3

Sup

ply

ab

ove

11

kV33

6 8.

51

343

8.51

36

0 10

.10

360

14.2

0 36

0 14

.20

360

14.2

036

0 14

.20

Tim

e of

Use

(TO

U) -

Pea

k

10.5

1

10.5

1

12.1

8

18.0

0

18.0

0

18.0

0

18.0

0

Tim

e of

Use

(TO

U) -

Off-

Peak

336

5.87

34

3 5.

87

360

7.35

36

0 12

.20

360

12.2

0 36

0 12

.20

360

12.2

0

AG

RIC

ULT

UR

AL

SCA

RP

8.

47

8.

47

10

.00

10

.00

13

.01

13

.01

12

.00

Ag

ricu

ltur

al T

ube-

wel

ls10

3 5.

31

105

5.31

12

0 6.

77

200

6.77

20

0 10

.35

200

11.5

120

0 15

.00

SCA

RP

5 k

W a

nd

ab

ove

Tim

e of

Use

(TO

U) -

Pea

k

17.0

0

17.0

0

8.8

5

Tim

e of

Use

(TO

U) -

Off-

Peak

200

10.0

0 20

0 10

.00

200

11.5

0

Ag

ricu

ltu

ral

5 kW

an

d a

bo

ve

Tim

e of

Use

(TO

U) -

Pea

k

10.1

1

10.1

1

13.0

0

13.0

0

10.3

5

10.3

5

10.3

5

Tim

e of

Use

(TO

U) -

Off-

Peak

200

4.55

20

0 4.

55

200

8.00

20

0 8.

00

200

10.3

5 20

0 10

.35

200

8.8

5

PU

BLI

C L

IGH

TIN

G

12.0

0

12.0

0

13.7

3

13.7

3

15.0

0

15.0

0

15.0

0

RES

IDEN

TIA

L C

OLO

NIE

S A

T-

TAC

HED

TO

IN

DU

STR

IES

11

.22

11

.22

12

.92

12

.92

15

.00

15

.00

15

.00

RA

ILW

AY

TR

AC

TIO

N

9.96

9.96

11.0

0

11.0

0

15.0

0

15.0

0

15.0

0

Spec

ial

Co

ntr

acts

- A

J&K

323

4.21

34

3 4.

21

360

5.63

36

0 12

.22

360

12.2

2 36

0 12

.22

360

12.2

2

Tim

e of

Use

(TO

U) -

Pea

k

11.5

9

11.5

9

13.3

0

18.0

0

18.0

0

18.0

0

18.0

0

Tim

e of

Use

(TO

U) -

Off-

Peak

323

6.41

34

3 6.

41

360

7.92

36

0 12

.20

360

12.2

0 36

0 12

.20

360

12.2

0

Spec

ial

Co

ntr

acts

- R

awat

Lab

.

8.75

8.75

11.5

0

11.5

0

15.0

0

15.0

0

15.0

0 *

GO

P Ta

riff w

ith e

ffect

from

01-

10-2

014

also

incl

udes

an

amou

nt o

f sur

char

ge to

be

depo

sited

in U

OF.

**

GO

P Ta

riff w

ith e

ffect

from

10-

06-2

015

also

incl

udes

an

amou

nt o

f Tar

iff

Ratio

naliz

ation

Sur

char

ge.

***

F

ixed

Cha

rges

(Rs.

/kW

/Mon

th)

****

Va

riabl

e Ch

arge

s (Rs

./kW

h)

So

urce

: Nati

onal

Ele

ctric

Pow

er R

egul

ator

y Au

thor

ity, I

slam

abad

197


TABLE 81Comparative Tariff Statement of Peshawar Electric Supply Company Limited (PESCO)

PARTICULARS2010-11 2011-12 2012-13 2013-14 2014-15

* ** * ** * ** * ** * **RESIDENTIALFor Sanctioned Load less than 5 kW

Up to 50 Units 2.00 3.00 4.00 4.00 4.00

For Consumption exceeding 50 Units01-100 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 aboveTime 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 COMMERCIALFor Sanctioned Load less than 5 kW 14.50 19.50 20.50 19.00 19.00 For Sanctioned Load 5 kW and aboveRegular 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 INDUSTRIALB1 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 kV, 33 kV)

12.25 19.50 20.50 19.00 19.00

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 above)

12.00 19.50 20.50 19.00 19.00

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 SUPPLYC1 (a) Supply at 400 Volts - less than 5 kW

11.00 16.50 17.50 16.00 15.00

C1 (b) Supply at 400 Volts - 5 kW and above

400.00 10.00 400.00 15.50 400.00 16.50 400.00 15.50 400.00 14.50

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 AGRICULTURALSCAPR 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 INDUSTRIES

13.00 16.40 15.00 15.00 14.00

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

198


TABLE 82Comparative Tariff Statement of Tribal Area Electric Supply Company Limited (TESCO)

PARTICULARS2013-14 2014-15

Fixed* Variable** Fixed* Variable**RESIDENTIALFor Sanctioned Load less than 5 kWUp to 50 Units 4.00 4.00 For Consumption exceeding 50 Units01-100 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 aboveTime of Use (TOU) - Peak 17.50 19.00 Time of Use (TOU) - Off-Peak 11.50 14.50 COMMERCIALFor Sanctioned Load less than 5 kW 17.50 19.00 For Sanctioned Load 5 kW and aboveRegular 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 INDUSTRIALB1 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 SUPPLYC1 (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 AGRICULTURALSCARP 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

199


TABLE 83Comparative Tariff Statement of Islamabad Electric Supply Company Limited (IESCO)

PARTICULARS2010-11 2011-12 2012-13 2013-14 2014-15

* ** * ** * ** * ** * **RESIDENTIALFor Sanctioned Load less than 5 kWUp to 50 Units 2.00 3.00 4.00 4.00 4.00 For Consumption exceeding 50 Units01-100 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 aboveTime 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 COMMERCIALFor Sanctioned Load less than 5 kW

13.00 16.50 18.00 17.50 15.00

For Sanctioned Load 5 kW and aboveRegular 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 INDUSTRIALB1 Less than 5 kW (at 400/230 Volts)

8.90 11.70 14.50 14.50 12.00

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 at 11 kV, 33 kV)

10.99 14.10 18.00 17.50 15.00

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 and above)

10.69 13.90 18.00 17.50 15.00

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 SUPPLYC1 (a) Supply at 400 Volts - less than 5 kW

9.90 12.50 15.00 15.00 12.50

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 12.00

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. TO INDUSTRIES

11.22 14.00 15.00 15.00 14.00

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


200


TABLE 84Comparative Tariff Statement of Gujranwala Electric Power Company Limited (GEPCO)

PARTICULARS2010-11 2011-12 2012-13 2013-14 2014-15

* ** * ** * ** * ** * **RESIDENTIALFor Sanctioned Load less than 5 kWUp to 50 Units 2.00 3.00 4.00 4.00 4.00 For Consumption exceeding 50 Units01-100 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 aboveTime 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 COMMERCIALFor Sanctioned Load less than 5 kW 14.35 17.50 18.00 19.00 19.00

For Sanctioned Load 5 kW and aboveRegular 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 INDUSTRIALB1 Less than 5 kW (at 400/230 Volts) 8.90 12.00 15.50 15.50 14.50

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 kW at 11 kV, 33 kV) 10.99 14.70 19.00 19.00 19.00

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, 132 kV and above) 10.69 14.50 19.00 19.00 19.00

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 SUPPLYC1 (a) Supply at 400 Volts - less than 5 kW 9.90 13.00 15.00 16.00 15.00

C1 (b) Supply at 400 Volts - 5 kW and above 400.00 8.75 400.00 11.50 400.00 14.50 400.00 15.50 400.00 14.50

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 AGRICULTURALSCARP 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 ATT. TO INDUSTRIES 11.22 14.25 15.00 15.00 14.00

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


201


TABLE 85Comparative Tariff Statement of Lahore Electric Supply Company Limited (LESCO)

PARTICULARS2010-11 2011-12 2012-13 2013-14 2014-15

* ** * ** * ** * ** * **For Sanctioned Load less than 5 kWUp to 50 Units 2.00 3.00 4.00 4.00 4.00 For Consumption exceeding 50 Units01-100 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 aboveTime 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 COMMERCIALFor Sanctioned Load less than 5 kW 13.00 15.00 18.00 17.50 16.00

For Sanctioned Load 5 kW and aboveRegular 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 INDUSTRIALB1 Less than 5 kW (at 400/230 Volts) 8.90 11.50 14.50 14.50 12.00





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 AGRICULTURALSCARP 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. TO INDUSTRIES 11.22 13.50 15.00 15.00 14.00

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

202


TABLE 86Comparative Tariff Statement of Faisalabad Electric Supply Company Limited (FESCO)

PARTICULARS2010-11 2011-12 2012-13 2013-14 2014-15* ** * ** * ** * ** * **

RESIDENTIALFor Sanctioned Load less than 5 kWUp to 50 Units 2.00 3.00 4.00 4.00 4.00 For Consumption exceeding 50 Units01-100 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 aboveTime 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 COMMERCIALFor Sanctioned Load less than 5 kW 13.00 17.00 19.50 17.50 15.00 For Sanctioned Load 5 kW and aboveRegular 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 INDUSTRIALB1 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 SUPPLYC1 (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 AGRICULTURALSCARP 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 INDUSTRIES 11.22 14.00 16.00 15.00 14.00


203


TABLE 87Comparative Tariff Statement of Multan Electric Power Company Limited (MEPCO)

PARTICULARS2010-11 2011-12 2012-13 2013-14 2014-15

* ** * ** * ** * ** * **RESIDENTIALFor Sanctioned Load less than 5 kWUp to 50 Units 2.00 3.00 4.00 4.00 4.00 For Consumption exceeding 50 Units01-100 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 aboveTime 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 COMMERCIALFor Sanctioned Load less than 5 kW 15.50 18.50 19.50 19.00 16.00 For Sanctioned Load 5 kW and aboveRegular 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 INDUSTRIALB1 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


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 SUPPLYC1 (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 AGRICULTURALSCARP 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 INDUSTRIES 13.00 15.00 16.00 15.00 14.00

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

204


TABLE 88Comparative Tariff Statement of Hyderabad Electric Supply Company Limited (HESCO)

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

RESIDENTIALFor Sanctioned Load less than 5 kWUp to 50 Units 2.00 3.00 4.00 4.00 4.00 For Consumption exceeding 50 Units01-100 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 aboveTime 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 COMMERCIALFor Sanctioned Load less than 5 kW 15.00 16.00 20.50 17.50 15.00

For Sanctioned Load 5 kW and aboveRegular 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 INDUSTRIALB1 Less than 5 kW (at 400/230 Volts) 10.00 14.00 17.00 14.50 12.50







205


TABLE 89Comparative Tariff Statement of Sukkur Electric Supply Company Limited (SEPCO)

PARTICULARS2011-12 2012-13 2013-14 2014-15

* ** * ** * ** * **RESIDENTIALFor Sanctioned Load less than 5 kWUp to 50 Units 3.00 4.00 4.00 4.00 For Consumption exceeding 50 Units01-100 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 aboveTime 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

COMMERCIALFor Sanctioned Load less than 5 kW 16.00 20.00 17.50 19.00 For Sanctioned Load 5 kW and aboveRegular 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 INDUSTRIALB1 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 SUPPLYC1 (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 AGRICULTURALSCARP 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


206


TABLE 90Comparative Tariff Statement of Quetta Electric Supply Company Limited (QESCO)

PARTICULARS2010-11 2011-12 2012-13 2013-14 2014-15* ** * ** * ** * ** * **

RESIDENTIALFor Sanctioned Load less than 5 kWUp to 50 Units 2.00 3.00 4.00 4.00 4.00 For Consumption exceeding 50 Units01-100 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 aboveTime 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 COMMERCIALFor Sanctioned Load less than 5 kW 15.25 17.00 18.00 17.50 19.00 For Sanctioned Load 5 kW and aboveRegular 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 INDUSTRIALB1 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 11 kV, 33 kV) 15.40 16.50 18.00 17.50 19.00






207


TAB

LE 9

1M

on

thly

So

urc

e-w

ise

Po

wer

Sen

t O

ut

and

Fu

el C

ost

(20

14-1

5)

July

Au

g.

Sep

t.O

ct.

No

v.D

ec.

Jan

.Fe

b.

Mar

chA

pri

lM

ayJu

ne

Tota

l

Hydel

Gen

erat

ion

GW

h 3,

790.

63

4,28

2.93

3,

532.

44

3,20

2.84

2,

891.

91

1,90

7.41

8

09.8

7 1,

957.

18

1,36

4.16

1,

472.

75

3,37

7.71

3,

972.

81

32,5

62.6

4 %

3

6.61

41

.42

38.7

1 3

8.47

4

3.45

28

.11

13.0

9 33

.40

20.8

6 20

.06

35.3

5 4

0.02

3

3.57

Fuel

Co

st

Mln

.Rs.

-

- -

-

- -

-

-

-

-

-

-

-

Rs.

/kW

h -

- -

-

- -

-

-

-

-

-

-

-

Coal

Gen

erat

ion

GW

h 10

.11

4.70

7.

85

0.1

2 1

5.34

14

.47

1.56

18

.35

7.58

13

.12

-

9.0

8 1

02.2

7 %

0

.10

0.05

0.

09

0.0

0 0

.23

0.21

0.

03

0.31

0.

12

0.18

-

0

.09

0.1

1

Fuel

Co

st

Mln

.Rs.

45

.47

21.1

4 35

.34

0.5

6 6

9.03

65

.09

7.02

82

.55

34.1

2 59

.03

-

40.

84

460

.21

Rs.

/kW

h 4

.50

4.50

4.

50

4.5

0 4

.50

4.50

4.

50

4.50

4.

50

4.50

-

4

.50

4.5

0

HSD

Gen

erat

ion

GW

h 38

5.50

3

03.5

8 3

20.1

7 2

45.4

8 5

.07

52.7

0 5

82.8

7 1

05.6

4 3

02.8

4 3

71.2

0 1

14.2

4 12

6.95

2,

916.

25

%

3.7

2 2.

94

3.51

2

.95

0.0

8 0.

78

9.42

1.

80

4.63

5.

06

1.20

1

.28

3.0

1

Fuel

Co

st

Mln

.Rs.

8,

047.

33

6,25

4.31

6,

467.

64

4,98

4.67

-

1,00

5.68

8,

695.

44

1,6

40.0

7 4,

184.

18

5,14

4.20

1,

586.

45

1,98

3.77

49

,993

.74

Rs.

/kW

h 20

.87

20.6

0 20

.20

20.

31

- 19

.08

14.9

2 15

.53

13.8

2 13

.86

13.8

9 1

5.63

1

7.14

RFO

Gen

erat

ion

GW

h 3,

445.

24

3,23

6.65

2,

779.

77

2,78

0.61

1,

394.

06

2,65

8.56

2,

806.

66

1,93

3.36

2,

540.

72

2,88

0.22

2,

740.

55

2,48

4.22

3

1,68

0.62

%

3

3.28

31

.30

30.4

6 3

3.40

2

0.94

39

.18

45.3

7 33

.00

38.8

4 39

.23

28.6

8 2

5.03

3

2.66

Fuel

Co

st

Mln

.Rs.

54

,942

.94

50,9

33.0

1 43

,518

.28

43,4

89.6

7 19

,319

.19

32,4

36.8

5 28

,822

.30

16,2

36.4

7 24

,709

.88

28,4

17.8

2 27

,205

.92

27,1

47.0

6 39

7,17

9.39

R

s./k

Wh

15.

95

15.7

4 15

.66

15.

64

13.

86

12.2

0 10

.27

8.40

9.

73

9.87

9.

93

10.

93

12.

54

Gas

Gen

erat

ion

GW

h 2,

135.

88

1,88

9.98

1,

876.

14

1,52

3.65

1,

766.

01

1,57

5.33

1,

442.

89

1,25

2.60

1,

669.

67

1,96

4.31

2,

659.

95

2,72

2.00

22

,478

.42

%

20.

63

18.2

8 20

.56

18.

30

26.

53

23.2

2 23

.32

21.3

8 25

.53

26.7

6 27

.84

27.

42

23.

17

Fuel

Co

st

Mln

.Rs.

10

,646

.17

9,23

3.57

8,

069.

95

6,84

1.71

7,

349.

69

5,76

5.88

6,

168.

47

6,13

3.95

7,

622.

82

10,1

78.8

0 14

,823

.07

15,5

17.2

4 10

8,35

1.31

R

s./k

Wh

4.9

8 4.

89

4.30

4

.49

4.1

6 3.

66

4.28

4.

90

4.57

5.

18

5.57

5

.70

4.8

2

Nuclear

Gen

erat

ion

GW

h 38

6.12

4

35.9

3 4

32.0

3 4

03.4

2 43

3.65

3

84.9

2 3

49.5

8 4

09.4

9 4

51.9

6 4

31.9

8 4

45.3

3 43

0.99

4

,995

.40

%

3.7

3 4.

22

4.73

4

.85

6.5

2 5.

67

5.65

6.

99

6.91

5.

88

4.66

4

.34

5.1

5

Fuel

Co

st

Mln

.Rs.

50

6.78

5

14.7

1 5

10.5

4 4

78.1

9 51

2.48

4

55.0

8 4

10.0

2 4

84.0

1 5

34.2

2 5

10.4

4 5

26.4

6 50

9.26

5

,952

.19

Rs.

/kW

h 1

.31

1.18

1.

18

1.1

9 1

.18

1.18

1.

17

1.18

1.

18

1.18

1.

18

1.1

8 1

.19

Import Iran

Gen

erat

ion

GW

h 4

5.62

43

.26

40.2

1 4

0.75

3

4.44

31

.31

29.9

7 28

.12

32.8

1 38

.44

42.7

4 3

4.87

4

42.5

6 %

0

.44

0.42

0.

44

0.4

9 0

.52

0.46

0.

48

0.48

0.

50

0.52

0.

45

0.3

5 0

.46

Fuel

Co

st

Mln

.Rs.

44

7.10

4

23.9

7 3

94.0

8 4

03.4

4 34

0.98

3

19.4

1 3

05.7

3 2

86.8

7 3

34.6

5 3

92.0

5 4

35.9

3 35

5.72

4

,439

.90

Rs.

/kW

h 9

.80

9.80

9.

80

9.9

0 9

.90

10.2

0 10

.20

10.2

0 10

.20

10.2

0 10

.20

10.

20

10.

03

Mixed

Gen

erat

ion

GW

h 10

6.06

1

06.4

8 1

05.4

5 1

18.0

8 10

1.61

1

30.0

5 1

30.0

5 1

17.5

2 1

38.0

7 1

16.9

6 84

.40

79.

14

1,3

33.8

7 %

1

.02

1.03

1.

16

1.4

2 1

.53

1.92

2.

10

2.01

2.

11

1.59

0.

88

0.8

0 1

.38

Fuel

Co

st

Mln

.Rs.

95

0.98

9

54.9

3 9

59.5

8 1

,075

.53

985.

54

1,12

4.56

1,

068.

98

979

.12

1,08

7.23

7

48.4

7 5

45.8

2 49

3.88

10

,974

.64

Rs.

/kW

h 8

.97

8.97

9.

10

9.1

1 9

.70

8.65

8.

22

8.33

7.

87

6.40

6.

47

6.2

4 8

.23

Wind Power

Gen

erat

ion

GW

h 4

7.84

37

.21

31.5

9 1

1.41

1

3.85

29

.97

32.9

7 36

.81

33.2

9 52

.54

77.4

9 5

2.89

4

57.8

4 %

0

.46

0.36

0.

35

0.1

4 0

.21

0.44

0.

53

0.63

0.

51

0.72

0.

81

0.5

3 0

.47

Fuel

Co

st

Mln

.Rs.

-

- -

-

- -

-

-

-

-

-

-

-

Rs.

/kW

h -

- -

-

- -

-

-

-

-

-

-

-

Solar Power

Gen

erat

ion

GW

h -

- -

-

- -

-

-

-

-

11.9

8 1

3.95

2

5.93

%

-

- -

-

- -

-

-

-

-

0.13

0

.14

0.0

3

Fuel

Co

st

Mln

.Rs.

-

- -

-

- -

-

-

-

-

-

-

-

Rs.

/kW

h -

- -

-

- -

-

-

-

-

-

-

-

Sour

ce: N

ation

al E

lect

ric P

ower

Reg

ulat

ory

Auth

ority

, Isla

mab

ad

208


TAB

LE 9

2K

-Ele

ctri

c -

Sum

mar

y o

f M

on

thly

Fu

el C

ost

Ad

just

men

t (2

014-

15)

Des

crip

tio

nJu

lyA

ug

.Se

pt.

Oct

.N

ov.

Dec

.Ja

n.

Feb

.M

arch

Ap

ril

May

Jun

eFu

el C

ost

- F

urna

ce O

il (R

s./M

/To

n)64

,882

64

,359

68

,499

65

,632

54

,578

47

,146

3

7,24

2 36

,571

41

,618

38

,765

41

,890

4

4,52

8 Fu

el C

ost

- G

as (R

s./M

MBT

u)48

8.23

48

8.23

48

8.23

48

8.23

48

8.23

48

8.23

4

88.2

3 48

8.23

48

8.23

48

8.23

48

8.23

4

88.2

3 B

in Q

asim

Po

wer

Pla

nt

Wei

ght

ed A

vera

ge

Fuel

Co

st (R

s./k

Wh)

(Ref

.) 1

2.29

1

2.29

1

2.29

1

2.54

1

2.54

1

2.54

1

0.04

1

0.04

1

0.04

8

.80

8.8

0 8

.80

Wei

ght

ed A

vera

ge

Fuel

Co

st (R

s./k

Wh)

Act

ual)

11.

89

10.

26

12.

54

9.4

2 9

.56

10.

04

7.5

5 6

.76

8.8

0 8

.47

8.2

9 9

.51

Diff

eren

ce (R

s./k

Wh)

(0.4

0)(2

.03)

0.2

4 (3

.12)

(2.9

7)(2

.50)

(2.4

9)(3

.28)

(1.2

4)(0

.33)

(0.5

1) 0

.70

Num

ber

of

Uni

ts S

ent

Out

(Mln

./kW

h)46

2.28

38

0.16

37

3.62

29

0.76

17

9.46

13

8.13

9

9.88

18

9.19

23

1.80

38

5.15

47

1.09

4

99.8

4 Fu

el C

ost

Var

iati

on

(Mln

./R

s.)

(184

.93)

(772

.29)

90.

65

(907

.61)

(533

.86)

(344

.88)

(248

.56)

(621

.19)

(287

.08)

(127

.03)

(240

.31)

351

.84

Ko

ran

gi

Th

erm

al P

ow

er S

tati

on

Wei

ght

ed A

vera

ge

Fuel

Co

st (R

s./k

Wh)

(Ref

.)-

- -

- -

- -

- -

- -

-

Wei

ght

ed A

vera

ge

Fuel

Co

st (R

s./k

Wh)

Act

ual)

- -

- -

- -

- -

- -

- -

D

iffer

ence

(Rs.

/kW

h)-

- -

- -

- -

- -

- -

-

Num

ber

of

Uni

ts S

ent

Out

(Mln

./kW

h)(0

.06)

(0.0

7)(0

.07)

(0.0

7)(0

.07)

(0.0

7)(0

.07)

(0.0

7)(0

.07)

(0.0

5)(0

.07)

-

Fuel

Co

st V

aria

tio

n (M

ln./

Rs.

)-

- -

- -

- -

- -

- -

-

Ko

ran

gi

Gas

-II

Wei

ght

ed A

vera

ge

Fuel

Co

st (R

s./k

Wh)

(Ref

.) 4

.89

4.8

9 4

.89

4.6

4 4

.64

4.6

4 4

.64

4.6

4 4

.64

4.6

4 4

.64

4.6

4 W

eig

hted

Ave

rag

e Fu

el C

ost

(Rs.

/kW

h) A

ctua

l) 4

.64

4.6

4 4

.64

4.6

4 4

.64

4.6

4 4

.64

4.6

4 4

.64

4.6

4 4

.64

4.6

4 D

iffer

ence

(Rs.

/kW

h)(0

.26)

(0.2

6)(0

.26)

- -

- -

- -

- -

-

Num

ber

of

Uni

ts S

ent

Out

(Mln

./kW

h) 5

7.28

5

1.04

4

8.12

4

8.57

3

6.30

1

0.50

9

.99

22.

15

14.

50

33.

25

45.

63

46.

55

Fuel

Co

st V

aria

tio

n (M

ln./

Rs.

)(1

4.69

)(1

3.09

)(1

2.34

)-

- -

- -

- -

- -

SI

TE

Gas

-II

Wei

ght

ed A

vera

ge

Fuel

Co

st (R

s./k

Wh)

(Ref

.) 4

.89

4.8

9 4

.89

4.6

4 4

.64

4.6

4 4

.64

4.6

4 4

.64

4.6

4 4

.64

4.6

4 W

eig

hted

Ave

rag

e Fu

el C

ost

(Rs.

/kW

h) A

ctua

l) 4

.64

4.6

4 4

.64

4.6

4 4

.64

4.6

4 4

.64

4.6

4 4

.64

4.6

4 4

.64

4.6

4 D

iffer

ence

(Rs.

/kW

h)(0

.26)

(0.2

6)(0

.26)

- -

- -

- -

- -

-

Num

ber

of

Uni

ts S

ent

Out

(Mln

./kW

h) 3

4.70

2

6.70

1

8.26

2

4.28

1

0.03

0

.52

1.4

8 2

.96

0.3

3 1

.54

9.6

7 2

1.68

Fu

el C

ost

Var

iati

on

(Mln

./R

s.)

(8.

90)

(6.

85)

(4.

68)

- -

- -

- -

- -

-

Ko

ran

gi

CC

PP

Wei

ght

ed A

vera

ge

Fuel

Co

st (R

s./k

Wh)

(Ref

.) 4

.69

4.6

9 4

.69

4.4

5 4

.45

4.4

5 4

.45

4.4

5 4

.45

4.4

5 4

.45

4.4

5 W

eig

hted

Ave

rag

e Fu

el C

ost

(Rs.

/kW

h)(A

ctua

l) 4

.45

4.4

5 4

.45

4.4

5 4

.45

4.4

5 4

.45

4.4

5 4

.45

4.4

5 4

.45

4.4

5 D

iffer

ence

(Rs.

/kW

h)(0

.25)

(0.2

5)(0

.25)

- -

- -

- -

- -

-

Num

ber

of

Uni

ts S

ent

Out

(Mln

./kW

h) 7

8.47

8

3.19

7

9.52

8

4.13

6

6.92

1

9.62

1

2.46

5

4.82

3

6.13

9

6.66

9

3.12

1

12.0

8 Fu

el C

ost

Var

iati

on

(Mln

./R

s.)

(19.

30)

(20.

46)

(19.

56)

- -

- -

- -

- -

-

Fuel

Co

st V

aria

tio

n o

f O

wn

Gen

. (M

il./

Rs.

)(2

27.8

2)(8

12.6

9) 5

4.06

(9

07.6

1)(5

33.8

6)(3

44.8

8)(2

48.5

6)(6

21.1

9)(2

87.0

8)(1

27.0

3)(2

40.3

1) 3

51.8

4 Po

wer

Pu

rch

ases

Wei

ght

ed A

vera

ge

Fuel

Co

st (R

s./k

Wh)

(Ref

.) 9

.21

9.2

1 9

.21

8.6

7 8

.67

8.6

7 7

.12

7.1

2 7

.12

6.6

0 6

.60

6.6

0 W

eig

hted

Ave

rag

e Fu

el C

ost

(Rs.

/kW

h) (A

ctua

l) 9

.25

8.5

1 8

.67

8.3

9 6

.11

7.1

2 8

.96

5.2

7 6

.60

7.3

5 6

.37

6.1

5 D

iffer

ence

(Rs.

/kW

h) 0

.04

(0.7

0)(0

.55)

(0.2

7)(2

.56)

(1.5

4) 1

.84

(1.8

6)(0

.52)

0.7

5 (0

.23)

(0.4

5)U

nits

Pur

chas

ed62

4.55

64

7.79

63

5.55

62

5.45

59

7.57

57

3.77

5

77.4

3 57

8.81

65

0.69

65

5.41

67

7.77

6

51.9

0 Fu

el C

ost

Var

iati

on

of

Po

wer

Pu

r. (

Mil

./R

s.)

23.

14

(454

.45)

(346

.90)

(171

.81)

(1,5

30.3

4)(8

85.6

0)1,

062.

78

(1,0

74.8

4)(3

40.3

3)49

2.96

(1

54.1

5)(2

95.5

8)To

tal F

uel C

ost

Var

iati

on

(Ow

n G

en.+

Pow

er

Pur.)

(204

.69)

(1,2

67.1

4) (2

92.8

4)(1

,079

.42)

(2,0

64.1

9)(1

,230

.49)

814

.22

(1,6

96.0

3) (6

27.4

2)36

5.93

(3

94.4

7) 5

6.26

Tota

l Uni

ts S

ent

out

(Ow

n G

en.+

Pow

er P

ur.)

1,59

1.83

1,

511.

13

1,48

3.59

1,

422.

75

1,21

6.84

1,

061.

60

1,01

0.82

99

0.45

1,

217.

87

1,46

0.41

1,

627.

66

1,65

1.61

Fu

el C

ost

Var

iati

on

(P

s./k

Wh

)(1

2.86

)(8

3.85

)(1

9.74

)(7

5.87

)(1

69.6

4)(1

15.9

1) 8

0.55

(1

71.2

4)(5

1.52

) 2

5.06

(2

4.24

)3.

41

Sour

ce: N

ation

al E

lect

ric P

ower

Reg

ulat

ory

Auth

ority

, Isla

mab

ad

209


TAB

LE 9

3K

-Ele

ctri

c -

Sou

rce-

wis

e O

wn

Gen

erat

ion

an

d F

uel

Co

sts

(201

4-15

)

July

Au

g.

Sep

t.O

ct.

No

v.D

ec.

Jan

.Fe

b.

Mar

chA

pri

lM

ayJu

ne

Bin Qasim

Gen

erat

ion

GW

h46

2.28

380.

1637

3.62

290.

7617

9.46

138.

1399

.88

189.

1923

1.80

385.

1547

1.09

499.

842

%47

.79

44.0

344

.06

36.4

728

.98

28.3

123

.05

45.9

640

.87

47.8

549

.59

50.0

0

Fuel

Co

stM

ln.R

s.54

98.3

539

01.4

146

84.0

327

37.5

617

15.9

613

86.7

575

4.24

1278

.20

2040

.18

3262

.84

3905

.92

4751

.12

Rs.

/kW

h11

.89

10.2

612

.54

9.42

9.56

10.0

47.

556.

768.

808.

478.

299.

51

Bin Qasim-II

Gen

erat

ion

GW

h33

4.61

322.

3232

8.59

349.

6432

6.63

319.

1330

9.64

142.

5928

4.50

288.

4433

0.44

319.

55%

34.5

937

.33

38.7

543

.85

52.7

465

.42

71.4

534

.64

50.1

635

.83

34.7

931

.96

Fuel

Co

stM

ln.R

s.0.

000.

000.

000.

000.

000.

000.

000.

000.

000.

000.

000.

00R

s./k

Wh

0.00

0.00

0.00

0.00

0.00

0.00

0.00

0.00

0.00

0.00

0.00

0.00

Korangi Thermal

Gen

erat

ion

GW

h-0

.06

-0.0

7-0

.07

-0.0

7-0

.07

-0.0

7-0

.07

-0.0

7-0

.07

-0.0

5-0

.07

0.00

%-0

.01

-0.0

1-0

.01

-0.0

1-0

.01

-0.0

1-0

.02

-0.0

2-0

.01

-0.0

1-0

.01

0.00

Fuel

Co

stM

ln.R

s.-0

.42

-0.4

7-0

.50

-0.4

6-0

.45

-0.4

6-0

.47

-0.4

6-0

.49

-0.3

1-0

.49

0.00

Rs.

/kW

h6.

716.

716.

716.

716.

716.

716.

716.

716.

716.

716.

710.

00

Korangi Gas-II

Gen

erat

ion

GW

h57

.28

51.0

448

.12

48.5

736

.30

10.5

09.

9922

.15

14.5

033

.25

45.6

346

.55

%5.

925.

915.

676.

095.

862.

152.

315.

382.

564.

134.

804.

66

Fuel

Co

stM

ln.R

s.26

5.67

236.

7422

3.17

225.

2716

8.38

48.6

946

.34

102.

7267

.25

154.

2421

1.66

215.

93R

s./k

Wh

4.64

4.64

4.64

4.64

4.64

4.64

4.64

4.64

4.64

4.6

4.6

4.64

SITE Gas-II

Gen

erat

ion

GW

h34

.70

26.7

018

.26

24.2

810

.03

0.52

1.48

2.96

0.33

1.54

9.67

21.6

8%

3.59

3.09

2.15

3.04

1.62

0.11

0.34

0.72

0.06

0.19

1.02

2.17

Fuel

Co

stM

ln.R

s.16

0.95

123.

8684

.71

112.

6046

.53

2.42

6.87

13.7

31.

547.

1444

.84

100.

58R

s./k

Wh

4.64

4.64

4.64

4.64

4.64

4.64

4.64

4.64

4.64

4.64

4.64

4.64

Korangi CCPP

Gen

erat

ion

GW

h78

.47

83.1

979

.52

84.1

366

.92

19.6

212

.46

54.8

236

.13

96.6

693

.12

112.

08%

8.11

9.64

9.38

10.5

510

.81

4.02

2.88

13.3

26.

3712

.01

9.80

11.2

1

Fuel

Co

stM

ln.R

s.34

9.03

370.

0135

3.67

374.

1829

7.64

87.2

955

.44

243.

8516

0.70

429.

9141

4.18

498.

51R

s./k

Wh

4.45

4.45

4.45

4.45

4.45

4.45

4.45

4.45

4.45

4.45

4.45

4.45

Total

Gen

erat

ion

GW

h96

7.28

863.

3584

8.04

797.

3061

9.27

487.

8343

3.39

411.

6356

7.19

805.

0094

9.88

999.

71%

100.

0010

0.00

100.

0010

0.00

100.

0010

0.00

100.

0010

0.00

100.

0010

0.00

100.

0010

0.00

Fuel

Co

stM

ln.R

s.62

73.5

846

31.5

653

45.0

934

49.1

522

28.0

515

24.6

986

2.42

1638

.03

2269

.18

3853

.82

4576

.11

5566

.13

Rs.

/kW

h9.

928.

5610

.29

7.70

7.61

9.04

6.97

6.09

8.03

7.46

7.39

8.18

*Ene

rgy

figur

es o

f eac

h po

wer

stati

on a

re w

orke

d ou

t on

the

basis

set t

arge

t of W

hole

Gen

erati

on F

leet

’s Au

xilia

ry C

onsu

mpti

on.

**Fu

el C

ost o

f eac

h po

wer

stati

on is

wor

ked

out o

n th

e ba

sis o

f Hea

t Rat

es a

s spe

cifie

d by

the

Auth

ority

.**

*Fue

l Cos

t of B

in Q

asim

-II is

not

refle

cted

as t

he H

eat R

ate

of th

is Po

wer

Sta

tion

is in

pro

cess

with

the

Auth

ority

. **

**En

ergy

figu

res o

f Bin

Qas

im-II

are

not

acc

ount

ed fo

r whi

le c

alcu

latin

g th

e to

tal F

uel C

ost d

ue to

non

-fina

lizati

on o

f its

Hea

t Rat

e.So

urce

: Nati

onal

Ele

ctric

Pow

er R

egul

ator

y Au

thor

ity, I

slam

abad

210


TAB

LE 9

4K

-Ele

ctri

c -

Sou

rce-

wis

e P

ow

er P

urc

has

es a

nd

Fu

el C

ost

s (2

014-

15)

Ju

lyA

ug

.Se

pt.

Oct

.N

ov.

Dec

.Ja

n.

Feb

.M

arch

Ap

ril

May

Jun

e

NTDC

Purc

hase

sG

Wh

459.

1146

1.18

452.

6145

2.47

447.

4844

2.65

450.

0041

7.73

466.

2745

0.54

467.

8445

8.79

%73

.51

71.1

971

.22

72.3

474

.88

77.1

577

.93

72.1

771

.66

68.7

469

.03

70.3

8

Fuel

Co

stM

ln.R

s.34

41.1

331

24.0

130

62.6

031

97.4

619

91.0

827

84.3

441

74.3

619

09.5

228

04.3

631

84.6

325

31.4

821

24.6

1

Rs.

/kW

h7.

506.

776.

777.

074.

456.

299.

284.

576.

017.

075.

414.

63

Tapal Energy

Purc

hase

sG

Wh

78.4

874

.79

74.1

959

.48

58.0

950

.15

48.4

755

.69

66.0

478

.16

80.2

083

.11

%12

.57

11.5

511

.67

9.51

9.72

8.74

8.39

9.62

10.1

511

.93

11.8

312

.75

Fuel

Co

stM

ln.R

s.11

34.4

910

52.2

310

46.9

084

6.62

748.

8756

9.58

443.

9640

4.44

546.

1962

9.03

699.

0684

1.27

Rs.

/kW

h14

.46

14.0

714

.11

14.2

312

.89

11.3

69.

167.

268.

278.

058.

7210

.12

Gul Ahmed

Purc

hase

sG

Wh

70.2

366

.10

68.6

647

.50

43.3

240

.36

36.8

658

.95

58.5

575

.30

74.9

277

.60

%11

.25

10.2

010

.80

7.60

7.25

7.03

6.38

10.1

89.

0011

.49

11.0

511

.90

Fuel

Co

stM

ln.R

s.10

54.9

498

3.49

1057

.09

742.

7758

8.19

463.

7132

0.44

459.

2155

6.10

669.

4872

1.43

811.

01

Rs.

/kW

h15

.02

14.8

815

.40

15.6

413

.58

11.4

98.

697.

799.

508.

899.

6310

.45

KANUPP

Purc

hase

sG

Wh

1.46

30.9

921

.96

44.6

129

.44

24.6

026

.93

32.1

044

.70

37.4

641

.51

17.6

1

%0.

234.

783.

467.

134.

934.

294.

665.

556.

875.

716.

122.

70

Fuel

Co

stM

ln.R

s.12

.25

231.

2118

5.22

293.

5617

9.30

151.

3814

0.92

186.

7028

7.99

245.

8527

4.50

127.

64

Rs.

/kW

h8.

407.

468.

436.

586.

096.

155.

235.

826.

446.

566.

617.

25

PASMIC

Purc

hase

sG

Wh

0.29

0.18

3.79

7.17

4.57

0.64

0.11

1.19

1.13

0.96

0.24

0.81

%0.

050.

030.

601.

150.

760.

110.

020.

210.

170.

150.

040.

12

Fuel

Co

stM

ln.R

s.2.

411.

3531

.98

47.1

727

.84

3.93

0.55

6.91

7.29

6.31

1.61

5.86

Rs.

/kW

h8.

407.

468.

436.

586.

096.

155.

235.

826.

446.

566.

617.

25

Anoud Power

Purc

hase

sG

Wh

8.67

7.31

8.04

8.28

8.39

9.19

9.01

7.56

7.91

7.42

7.09

6.63

%1.

391.

131.

261.

321.

401.

601.

561.

311.

211.

131.

051.

02

Fuel

Co

stM

ln.R

s.95

.90

80.2

488

.71

87.6

577

.96

79.2

961

.53

49.8

058

.36

52.0

357

.35

55.2

0

Rs.

/kW

h11

.06

10.9

811

.04

10.5

99.

298.

636.

836.

597.

387.

018.

098.

33

IIL

Purc

hase

sG

Wh

6.32

7.23

6.30

5.94

6.28

6.18

6.05

5.61

6.09

5.57

5.98

7.35

%1.

011.

120.

990.

951.

051.

081.

050.

970.

940.

850.

881.

13

Fuel

Co

stM

ln.R

s.35

.37

40.3

635

.23

33.1

735

.06

34.5

133

.85

31.2

533

.97

31.0

533

.44

41.1

2

Rs.

/kW

h5.

595.

585.

595.

585.

585.

585.

605.

575.

585.

585.

595.

59

Total

Purc

hase

sG

Wh

624.

5564

7.79

635.

5562

5.45

597.

5757

3.77

577.

4357

8.81

650.

6965

5.41

677.

7765

1.90

%10

0.00

100.

0010

0.00

100.

0010

0.00

100.

0010

0.00

100.

0010

0.00

100.

0010

0.00

100.

00

Fuel

Co

stM

ln.R

s.57

76.4

955

12.9

055

07.7

352

48.4

036

48.3

040

86.7

451

75.6

230

47.8

242

94.2

648

18.3

843

18.8

740

06.7

1

Rs.

/kW

h9.

258.

518.

678.

396.

117.

128.

965.

276.

607.

352

6.37

26.

146

Sour

ce: N

ation

al E

lect

ric P

ower

Reg

ulat

ory

Auth

ority

, Isla

mab

ad

211


TAB

LE 9

5K

-Ele

ctri

c -

Fuel

-wis

e O

wn

Gen

erat

ion

an

d F

uel

Co

sts

(201

4-15

)

July

Au

g.

Sep

t.O

ct.

No

v.D

ec.

Jan

.Fe

b.

Mar

chA

pri

lM

ayJu

ne

Gas

Gen

erat

ion

GW

h70

7.86

700.

1163

5.27

696.

2353

4.26

395.

5838

2.68

345.

5342

2.93

554.

6770

1.33

671.

44%

73.1

881

.09

74.9

187

.32

86.2

781

.09

88.3

083

.94

74.5

768

.90

73.8

767

.16

Fuel

Co

stM

ln.R

s.18

30.0

018

58.0

714

97.4

516

97.9

110

03.2

037

6.46

363.

8899

9.82

684.

2212

92.0

618

27.3

517

07.1

1R

s./k

Wh

4.90

4.92

4.88

4.90

4.83

4.92

4.98

4.93

4.94

4.85

4.93

4.85

RFO

Gen

erat

ion

GW

h25

9.42

163.

2321

2.77

101.

0785

.01

92.2

550

.71

66.1

014

4.26

250.

3224

8.03

328.

27%

26.8

218

.91

25.0

912

.68

13.7

318

.91

11.7

016

.06

25.4

331

.10

26.1

332

.84

Fuel

Co

stM

ln.R

s.44

43.5

827

73.4

938

47.6

317

51.2

412

24.8

511

48.2

349

8.54

638.

2115

84.9

725

61.7

627

46.2

438

54.2

4R

s./k

Wh

17.1

316

.99

18.0

817

.33

14.4

112

.45

9.83

9.65

10.9

910

.23

11.0

711

.74

Total Generation

Gen

erat

ion

GW

h96

7.28

863.

3584

8.04

797.

3061

9.27

487.

8343

3.39

411.

6356

7.19

805.

0094

9.36

999.

71%

100.

0010

0.00

100.

0010

0.00

100.

0010

0.00

100.

0010

0.00

100.

0010

0.00

100.

0010

0.00

Fuel

Co

stM

ln.R

s.62

73.5

846

31.5

653

45.0

934

49.1

522

28.0

515

24.6

986

2.42

1638

.03

2269

.18

3853

.82

4573

.59

5561

.35

Rs.

/kW

h9.

928.

5610

.29

7.70

7.61

9.04

6.97

6.09

8.03

7.46

7.39

8.18

*Ene

rgy

Fig

ures

of

Bin

Qas

im-I

I are

no

t ac

coun

ted

fo

r w

hile

cal

cula

ting

the

Fue

l Co

st a

s th

e H

eat

Rat

e of

the

sai

d P

ow

er S

tati

on

is in

pro

cess

wit

h th

e A

utho

rity

.So

urce

: Nati

onal

Ele

ctric

Pow

er R

egul

ator

y Au

thor

ity, I

slam

abad

TAB

LE 9

6K

-Ele

ctri

c -

Fuel

-wis

e Po

wer

Pu

rch

ases

an

d F

uel

Co

sts

(201

4-15

)

July

Au

g.

Sep

t.O

ct.

No

v.D

ec.

Jan

.Fe

b.

Mar

chA

pri

lM

ayJu

ne

NTDC

Purc

hase

sG

Wh

459.

1146

1.18

452.

6145

2.47

447.

4844

2.65

450.

0041

7.73

466.

2745

0.54

467.

8445

8.79

%73

.51

71.1

971

.22

72.3

474

.88

77.1

577

.93

72.1

771

.66

68.7

469

.03

70.3

8

Fuel

Co

stM

ln.R

s.34

41.1

331

24.0

130

62.6

031

97.4

619

91.0

827

84.3

441

74.3

619

09.5

228

04.3

631

84.6

325

31.4

821

24.6

1R

s./k

Wh

7.50

6.77

6.77

7.07

4.45

6.29

9.28

4.57

6.01

7.07

5.41

4.63

Coal

Purc

hase

sG

Wh

- -

- -

- -

-

-

- -

-

- %

- -

- -

- -

-

-

- -

-

-

Fuel

Co

stM

ln.R

s.-

- -

- -

-

-

- -

-

- -

Rs.

/kW

h-

- -

- -

-

-

- -

-

- -

RFO

Purc

hase

sG

Wh

155.

0114

6.20

148.

6911

3.00

107.

5197

.19

91.8

812

0.13

130.

3415

8.86

160.

2716

5.54

%24

.82

22.5

723

.40

18.0

717

.99

16.9

415

.91

20.7

520

.03

24.2

423

.65

25.3

9

Fuel

Co

stM

ln.R

s.22

59.1

520

94.0

621

68.4

916

53.1

113

93.7

410

90.9

380

9.13

899.

8511

44.7

213

36.3

414

62.1

816

92.4

1R

s./k

Wh

14.5

714

.32

14.5

814

.63

12.9

611

.22

8.81

7.49

8.78

8.41

9.12

10.2

2

Gas

Purc

hase

sG

Wh

8.98

9.41

12.2

815

.37

13.1

49.

338.

628.

869.

388.

558.

169.

97%

1.44

1.45

1.93

2.46

2.20

1.63

1.49

1.53

1.44

1.31

1.20

1.53

Fuel

Co

stM

ln.R

s.63

.96

63.6

291

.42

104.

2784

.18

60.0

851

.20

51.7

557

.19

51.5

750

.70

62.0

4R

s./k

Wh

7.12

6.76

7.44

6.78

6.40

6.44

5.94

5.84

6.10

6.03

6.22

6.22

Nuclear

Purc

hase

sG

Wh

1.46

30.9

921

.96

44.6

129

.44

24.6

026

.93

32.1

044

.70

37.4

641

.51

17.6

1%

0.23

4.78

3.46

7.13

4.93

4.29

4.66

5.55

6.87

5.71

6.12

2.70

Fuel

Co

stM

ln.R

s.12

.25

231.

2118

5.22

293.

5617

9.30

151.

3814

0.92

186.

7028

7.99

245.

8527

4.50

127.

64R

s./k

Wh

8.40

7.46

8.43

6.58

6.09

6.15

5.23

5.82

6.44

6.56

6.61

7.25

Total

Purc

hase

sG

Wh

624.

5564

7.79

635.

5562

5.45

597.

5757

3.77

577.

4357

8.81

650.

6965

5.41

677.

7765

1.90

%10

0.00

100.

0010

0.00

100.

0010

0.00

100.

0010

0.00

100.

0010

0.00

100.

0010

0.00

100.

00

Fuel

Co

stM

ln.R

s.57

76.4

955

12.9

055

07.7

352

48.4

036

48.3

040

86.7

451

75.6

230

47.8

242

94.2

648

18.3

843

18.8

740

06.7

1R

s./k

Wh

9.25

8.51

8.67

8.39

6.11

7.12

8.96

5.27

6.60

7.35

6.37

6.15

Sour

ce: N

ation

al E

lect

ric P

ower

Reg

ulat

ory

Auth

ority

, Isla

mab

ad

212


TAB

LE 9

7K

-Ele

ctri

c -

Sou

rce-

wis

e G

ener

atio

n a

nd

Po

wer

Pu

rch

ases

(20

14-1

5)

July

Au

g.

Sep

t.O

ct.

No

v.D

ec.

Jan

.Fe

b.

Mar

chA

pri

lM

ayJu

ne

Pow

er P

urc

has

ed a

t B

us

Bar

(G

Wh

)

KAN

UPP

1.46

30.9

921

.96

44.6

129

.44

24.6

026

.93

32.1

044

.70

37.4

641

.51

17.6

1

PASM

IC0.

290.

183.

797.

174.

570.

640.

111.

191.

130.

960.

240.

81Ta

pal E

nerg

y78

.48

74.7

974

.19

59.4

858

.09

50.1

548

.47

55.6

966

.04

78.1

680

.20

83.1

1G

ul A

hmed

70.2

366

.10

68.6

647

.50

43.3

240

.36

36.8

658

.95

58.5

575

.30

74.9

277

.60

NTD

C/W

APD

A45

9.11

461.

1845

2.61

452.

4744

7.48

442.

6545

0.00

417.

7346

6.27

450.

5446

7.84

458.

79A

noud

Po

wer

8.67

7.31

8.04

8.28

8.39

9.19

9.01

7.56

7.91

7.42

7.09

6.63

DH

A C

og

en.

0.00

0.00

0.00

In

tern

atio

nal I

ndus

trie

s Li

mit

ed6.

327.

236.

305.

946.

286.

186.

055.

616.

095.

575.

987.

35

Tota

l Po

wer

Pu

r. a

t B

us

Bar

(G

Wh

)62

4.55

647.

7963

5.55

625.

4559

7.57

573.

7757

7.43

578.

8165

0.69

655.

4167

7.77

651.

90

Ow

n G

ener

atio

nU

nit

s Se

nt

Ou

t -

FO (

GW

h)

Bin

Qas

im-I

259.

4216

3.23

212.

7710

1.07

85.0

192

.25

50.7

166

.10

144.

2625

0.32

248.

5532

8.27

Un

its

Sen

t O

ut

- G

as (

GW

h)

Bin

Qas

im-I

202.

8521

6.92

160.

8618

9.69

94.4

545

.87

49.1

812

3.08

87.5

513

4.83

222.

5117

1.57

Bin

Qas

im-I

I33

4.61

322.

3232

8.59

349.

6432

6.63

319.

1330

9.64

142.

5928

4.50

288.

4433

0.44

319.

55Ko

rang

i The

rmal

-0.0

6-0

.07

-0.0

7-0

.07

-0.0

7-0

.07

-0.0

7-0

.07

-0.0

7-0

.05

-0.0

50.

00Ko

rang

i Gas

-I0.

000.

000.

000.

000.

000.

000.

000.

000.

000.

000.

000.

00Ko

rang

i Gas

-II

57.2

851

.04

48.1

248

.57

36.3

010

.50

9.99

22.1

514

.50

33.2

545

.63

46.5

5SI

TE G

as-I

0.00

0.00

0.00

0.00

0.00

0.00

0.00

0.00

0.00

0.00

0.00

0.00

SITE

Gas

-II

34.7

026

.70

18.2

624

.28

10.0

30.

521.

482.

960.

331.

549.

6721

.68

Kora

ngi C

CPP

78.4

783

.19

79.5

284

.13

66.9

219

.62

12.4

654

.82

36.1

396

.66

93.1

211

2.08

Tota

l U

nit

s S/

Ou

t -

Gas

(G

Wh

)70

7.86

700.

1163

5.27

696.

2353

4.26

395.

5838

2.68

345.

5342

2.93

554.

6770

1.33

671.

44

Tota

l U

nit

s S/

Ou

t -

FO

(GW

h)

259.

4216

3.23

212.

7710

1.07

85.0

192

.25

50.7

166

.10

144.

2625

0.32

248.

5532

8.27

Tota

l U

nit

s S/

Ou

t (G

Wh

) O

wn

Gen

.96

7.28

863.

3584

8.04

797.

3061

9.27

487.

8343

3.39

411.

6356

7.19

805.

0094

9.88

999.

71

Gra

nd

To

tal

(GW

h)

1591

.83

1511

.13

1483

.59

1422

.75

1216

.84

1061

.60

1010

.82

990.

4512

17.8

714

60.4

116

27.6

616

51.6

1%

of

NT

DC

in

To

tal

Un

its

Sen

t O

ut

28.8

430

.52

30.5

131

.80

36.7

741

.70

44.5

242

.18

38.2

930

.85

28.7

427

.78

% o

f O

wn

Gen

. in

To

tal

Un

its

S/O

ut

60.7

757

.13

57.1

656

.04

50.8

945

.95

42.8

741

.56

46.5

755

.12

58.3

660

.53

% o

f P

ow

er P

ur.

in

To

tal

Un

its

S/O

ut

39.2

342

.87

42.8

443

.96

49.1

154

.05

57.1

358

.44

53.4

344

.88

41.6

439

.47

Sour

ce: N

ation

al E

lect

ric P

ower

Reg

ulat

ory

Auth

ority

, Isla

mab

ad

213


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 LimitedTABLE 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 StationsTABLE 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 StationsTABLE 20 Auxiliary Consumption and other Factors of Private Sector Thermal Power StationsTABLE 21 Main Electricity Statistics of the CountryTABLE 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 TABLE27 Surplus/DeficitinDemandandSupplyduringNTDC’sSystemPeakHoursTABLE28 Surplus/DeficitinDemandandSupplyduringK-Electric’sSystemPeakHoursTABLE 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 ProjectsTABLE 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 NTDCTABLE 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 NTDCTABLE 48 Power Sector Investment Plan for NTDC Transmission Lines TABLE 49 Interconnection Arrangement to Evacuate Power from up-coming Power Projects

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TABLE 50 Transmission Lines and Grid Stations with K-ElectricTABLE 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-ElectricTABLE 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 CompaniesTABLE 56 Service Area of Distribution CompaniesTABLE 57 Comparison of SAIFI and SAIDI of all Distribution CompaniesTABLE 58 Peak Demand of Distribution Companies (MW)TABLE 59 Category-wise Number of ConsumersTABLE 60 Category-wise Sanctioned Load (MW)TABLE 61 Category-wise Electricity Sold (GWh)TABLE 62 Total Units Purchased, Sold and LossesTABLE 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 FeedersTABLE 69 Number of Circles, Divisions, Sub-Divisions and FeedersTABLE 70 Status of Grid Stations (Nos.)TABLE 71 DISCO’s Power Transformers, Capacities and Loading Positions of Power TransformersTABLE 72 DISCO’s Number of 11 kV Feeders and Loading Positions of 11 kV FeedersTABLE 73 DISCO’s Number of Distribution Transformers, Capacities and Loading Positions of Distribution TransformersTABLE 74 Village Electrification in all Distribution CompaniesTABLE 75 Applications of New Connections Received, Energized and PendingTABLE 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 DISCOsTABLE 79 Comparison of Proposed NEPRA Tariff (2014-15)TABLE 80 Statement of GOP Applicable (Notified) TariffTABLE 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)

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ACRONYMS AND ABBREVIATIONS

ADB Asian Development BankAEDB Alternative Energy Development BoardAJKHEB Azad Jammu and Kashmir Hydel Electricity BoardAMRS Automated Meter Reading SystemBPC Bulk Power ConsumerBQCCPP Bin Qasim Combined Cycle Power PlantBQTPS Bin Qasim Thermal Power StationBTPL Bahira Town (Pvt.) LimitedCCPP Combined Cycle Power PlantCDP Common Delivery PointCHASNUPP Chashma Nuclear Power PlantCkt CircuitCOD Commercial Operation DateCPGCL Central Power Generation Company LimitedCPI Consumer Price IndexCPP Captive Power PlantCPPA Central Power Purchasing AgencyDISCO Distribution CompanyDOP Development of PowerECC Economic Coordination CommitteeECNEC Executive Committee of the National Economic CouncilEHV Extra High VoltageELR Energy Loss ReductionFBC Fluidized Bed CombustionFDI Foreign Direct InvestmentFESCO Faisalabad Electric Supply Company LimitedGDP Gross Domestic ProductGENCO Generation CompanyGEPCO Gujranwala Electric Power Company LimitedGEs Gas EnginesGOP Government of PakistanGST General Sales TaxGTPS Gas Thermal Power StationGWh Giga Watt – hourHESCO Hyderabad Electric Supply Company LimitedHFO Heavy Furnace OilHPP Hydropower ProjectHSD High Speed DieselHVDC High Voltage Direct CurrentIA Implementation AgreementIBC Integrated Business CentreICB International Competitive BiddingIESCO Islamabad Electric Supply Company LimitedIPP Independent Power ProducersJPCL Jamshoro Power Company LimitedKANUPP Karachi Nuclear Power PlantKCCPP Korangi Combined Cycle Power PlantKEL K-Electric Limitedkm KilometerKTGTPS Korangi Town Gas Turbine Power StationKTPS Korangi Thermal Power StationkV Kilo VoltKVA Kilovolt AmperekWh Kilowatt – hours

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LESCO Lahore Electric Supply Company LimitedLPGCL Lakhra Power Generation Company LimitedLtr. LitreMEPCO Multan Electric Power Company LimitedMMBTU Million British Thermal UnitMMCFT Million Cubic FeetMTOE Million Tonees of Oil EquivalentMVA Megavolt AmpereMW MegawattMWh Megawatt – hourMYT Multi-year Tariffn.a. & n.p. Not available and not providedNCPP New Captive Power PlantNEPRA National Electric Power Regulatory AuthorityNGC National Grid CompanyNGPS Natural Gas Power StationNPCC National Power Control CentreNPGCL Northern Power Generation Company LimitedNTDC National Transmission and Dispatch Company LimitedO&M Operation and MaintenanceOCPP Open Cycle Power PlantPAEC Pakistan Atomic Energy CommissionPASMIC Pakistan Steel Mills CorporationPEPCO Pakistan Electric Power Company LimitedPESCO Peshawar Electric Supply Company LimitedPNRA Pakistan Nuclear Regulatory AuthorityPPA Power Purchase AgreementPPDB Punjab Power Development BoardPPIB Private Power and Infrastructure BoardPPP Power Purchase PricePSDP Public Sector Development ProjectQESCO Quetta Electric Supply Company LimitedRFO Residue Furnace OilSCADA Supervisory Control and Data AcquisitionSCARP Salinity Control and Reclamation ProjectSEPCO Sukkur Electric Power Company LimitedSGTPS Site Gas Turbine Power StationPHYDO Pakhtunkhwa Hydel Development OrganizationSPP Small Power ProducerSPS Steam Power StationSTG Secondary Transmission and GridST Steam TurbineSVC Static Var CompensatorsT&D Transmission and DistributionTCEB Thar Coal and Energy BoardTESCO Tribal Area Electricity Supply Company LimitedTOD Time of DayTOU Time of UseTPS Thermal Power StationUNDP United Nations Development ProgramUSAID United States Agency for International DevelopmentVIBC Virtual Integrated Business CentreWB World BankWPPO WAPDA Power Privatisation Organization

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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

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