TARIFF PETITION

F.Y. 2013-14

DISTRIBUTION LICENSE NO.06/DL/2002

2nd August 2013

FINANCE DEPARTMENT

Dated: 02 /08/2013

MULTAN ELECTRIC POWER COMPANY LIMITED

No. /FDM/Tariff/5879

The Registrar, National Electric Power Regulatory Authority, 2"d. Floor OPF Building, Sector G- 5/2, Islamabad.

Subject: TARIFF PETITION — MEPCO (LICENSE # 06/DL/2002

We are enclosing Tariff Petition for the Financial Year 2013-14. It is therefore, requested

to admit attached petition for determination of consumer end tariff of the company for the

financial year 2013-14.

It may please be acknowledged.

DA/ 1. Affidavit in original (one page) 2. Tariff Petition ( Pages)

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Engr.lcOM r sziin Khan Chief Executive Officer

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MULTAN ELECTRIC POWER COMPANY Tel: 061-19210352

061/9210380/2005 Office of the

No. 1° thl /Company : Secy Dated 30-6 Y The Finance Director, MEPCO H/Q Multan.

Sub:- AUTHORIZATION TO CHIEF EXECUTIVE OFFIER TO FILE TARIFF PETITION.

It is informed that the Board of Directors in its 59th Meeting held on July 14, 2009 at MEPCO 1-1/Q Multan has passed the below noted Resolution:-

"Resolved that CEO MEPCO be and is hereby authorized to file Tariff Petition with NEPRA whenever required In future".

Chief Executive

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Affidavit

I lqbal Hussain Khan, Chief Executive Officer, Multan Electric Power Company Limited

(Distribution License # 06/DL/2002) being duly authorized representative/attorney of

Multan Electric Power Company Limited, hereby solemnly affirm and declare that the

contents of the accompanying petition/application No.FDM/Tariff/5879 dated

02 August 2013 including all supporting documents are true and correct to the best of

my knowledge and belief and that nothing has been concealed. I also affirm that all

further documentation and information to be provided by me in connection with the

accompanying petition shall be true to the best of my knowledge and belief.

DEPONENT

Y\ ' '21; Engr. lqbal thissain Khan

Chief Executive Officer Multan Electric Power Company Ltd.

(MEPCO)

Verified on oath this 02nd day of August 2013 that the contents hereof are true and correct to the best of my knowledge and belief and nothing has been concealed.

DEPONENT

■

Engr. lqhai Hussain Khan Chief Executive Officer

Multan Electric Power Company Ltd.

(MEPCO)

Ve y

MULTAN ELECTRIC POWER COMPANY LIMITED (MEPCO) TARIFF PETITION

UNDER SECTION 3(1) OF PART II OF NATIONAL ELECTRIC POWER REGULATORY AUTHORITY

(TARIFF STANDARDS AND PROCEDURE) 1998

1. PETITION SUMMARY

1.1 The Petitioner

Multan Electric Power Company Limited (MEPCO)

Multan Electric Power Company Limited, hereinafter referred to as MEPCO or Company, is a public limited company having its registered office at 414- Wapda House, Lahore and principal office at MEPCO Head Quarter, Khanewal Road, Multan. MEPCO as a public utility is engaged in distribution/supply of electric power in its licensed service territory comprising of 13 Administrative Districts of Southern Punjab.

1.1.1 MEPCO is Represented by:

• Mr. Iqbal Hussain Khan

• Abdhul Mateen Khan

• Mian Ansar Mahmood

• Mr. Saeed Ahmad Nasir

• Ch. Muhammad Arshad

• Mr. Malik Imtiaz Ahmad

• Mr. Jahangir Bhutta

Chief Executive Officer

General Manager (OP)

Finance Director.

C.E./ Customer Services director

Chief Engineer (P & E)

Addl. Customer Services Director

Manager Finance (CP&C)

1.1.3 Basis of Petition

Under NEPRA Act 1997, NEPRA (Authority/Regulator) is responsible for determining tariffs and other terms and conditions for the supply of electricity by the generation, transmission and distribution companies and to recommend these, to the Federal Government for notification. NEPRA is also responsible for determining the process and procedures for reviewing tariffs and recommending tariff adjustments.

MEPCO is a licensee public utility responsible to distribute/supply electricity to its service area, as set out in MEPCO's Distribution license No. 06/DL/2002, granted by

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NEPRA under the NEPRA Act. In accordance with the requirements of the license, MEPCO is hereby submitting a petition to determine tariffs in its license area for the year 2013-14.

This petition is, therefore, being filed under section 3(i) part II of NEPRA Tariff Standards and Procedure Rules 1998.

1.2 Grounds of Petition

MEPCO tariff has two components i.e pass through cost and distribution margin .The major portion of pass through cost is power purchased which the company must pay for on regular basis to ensure continuous flow of power in its distribution system. Distribution Margin is equally important, MEPCO must earn sufficient distribution margin and adequate stream of cash flow to maintain its system, discharge its financial commitments, invest on the augmentation and expansion of the network and a reasonable return to the sponsors on their investment.

Stable and predictable tariff rate is beneficial both for Distribution Company and its customers for a long term planning. The length of the review period is important for determining the size of the incentive for MEPCO to improve its efficiency. Longer the period of review, larger the incentive to make efficiency gains, reduce losses or achieve cost efficiencies in stable economic conditions. MEPCO is submitting its tariff petition for the Financial Year 2013-14. Following are the factors responsible for filing fresh tariff petition.

> Increase in cost of Power Purchased. > Low DM by not allowing genuine O&M costs.

✓ Provision of Pension benefits for its employees. ✓ Genuine Salary and wages cost of its employees.

> Increase in O&M cost. > Low tariff rate due to unrealistic line losses. > Markup cost on loans taken by CPPA to reduce circular Debt. > Working Capital requirement. > Prior period Adjustment. > Delayed Tariff determination/notification. > Delayed and irregular determination of FPA. > Nonpayment of UOSC by other DISCOs. > Just return to sponsors on their investment.

These result in insufficient cash flow making it difficult for the company to :

> Pay for electricity purchased. > Meet other obligations:

i. Investment on the system for maintenance and reduction of line losses. ii. Augmentation of the system to cater for growing demand.

iii. Expansion of the system. iv. Debt servicing.

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1.3.0 Relief sought

We, therefore, submit to the Authority to seek the following relief. D Determine consumer end tariff as submitted. D Accept revenue requirement computed by the company. > Ensure recovery of required revenue by timely determination. > Allow adequate 0 & M. > Acceptance of Investment Plan. D Any Other relief which the Authority may deem proper.

1.3 Key Aims and Features of the Petition

1.3.1 Aims of the Petition

This tariff petition sets out required revenues and timetable for rebalancing tariffs in MEPCO's distribution area for the year 2013-14. The aim of this petition is to obtain approval for the immediate implementation of cost reflective tariffs to yield MEPCO's required revenues. The implementation of cost reflective tariffs will benefit consumers and MEPCO as it will:

1. Enable the Company to pay its power purchase cost and play its role in mitigation of power shortage.

2. Enable the company to arrange funding to improve service quality and reliability.

3. Enable the company to arrange funds for its network expansion.

4. Provide signals for efficient usage of distribution network and investment

5. Give message for efficient use of electricity.

6. Promote financial sustainability of the company.

1.3.2 Features of the Petition

The purpose of petition is as follows:

> Sufficient average tariff to enable MEPCO to recover prudently incurred operating costs and earn a reasonable return on its regulatory asset base to meet with its cash flow requirements.

➢ Incentives for MEPCO to make operating efficiencies and reduce commercial losses.

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1.3.3 Structure of the Petition

This petition has three distinct components. The first part deals with the tariff methodology. This is the formula as explained in section 2 that will be used to determine MEPCO's distribution margin for the F.Y. year 2013-14 unless there is a fundamental change in the assumptions made. The second part covers the calculation of MEPCO's required revenues during the period. It explains the different components of required revenues including pass through costs (PPP, Income tax etc), operating costs. The third component covers investments costs, regulatory asset base and rate of return.

2. Tariff Review Formula and Process

The tariff formula provides a transparent and predictable way of determining MEPCO's distribution margin on annual basis. A formula is advantageous as it reduces uncertainty for the utility and for customers. It also provides a simple way for NEPRA to provide incentive to the company to reduce losses and/or make operating efficiencies as required.

2.1 Tariff Methodology

2.1.1 MEPCO's Margin

The formula calculates MEPCO's distribution margin based on forecast unit sales, operating expenses, depreciation, investment and return on investment (cost of capital). Generation and transmission cost, built in the invoice from CPPA, are treated as pass-through. The formula determines revenues for the F.Y. year 2012-13. The profits or losses that arise from changes in efficiency or demand would, however, be retained by MEPCO.

Under the proposed tariff-setting methodology, the average retail tariff would consist of (i) the Power Purchase Price (PPP), which would be passed through to the end users in the retail tariff, and (ii) the average distribution margin, which would be set on the formula-based methodology.

2.2.1 Power Purchase Price (PPP)

MEPCO pays a Power Purchase Price (in Rs/kWh) for the electricity it procures from CPPA or other sources, which would include the generation and transmission charges (regulated by NEPRA). This Power Purchase Price, adjusted for MEPCO's distribution losses, would then be simply added to MEPCO's overall distribution margin to work out retail tariffs. Thus, the cost of the purchased electricity would be "passed through" to consumers through the retail tariff, without affecting MEPCO's distribution margin.

4

While passing through the PPP, it is recognized that all distribution companies experience some level of distribution losses, defined as the percentage of the difference between the units received by the company and the units invoiced to the consumers. The PPP should thus be adjusted such that MEPCO would be compensated for some losses, without hindering the incentive to eliminate the total losses.

PPP = Unadjusted PPP 1-L

Where;

D Unadjusted PPP is the cost of electricity supply charged by CPPA or any other source at any given time;

> L is the target distribution losses for the year, defined as a percentage of purchased units, in accordance with a schedule established for the control period.

The schedule of losses (Transmission & Distribution) is set to level of 16.50% for Financial Year 2013-14. Thereafter, the target losses will be reset to account any further improvement that may be deemed achievable in subsequent years through investment in the system and other measures to achieve the target of 16.50% fixed for the current year.

Based on the above formula, the compensation for T&D losses would be automatically adjusted for any changes in the power purchase cost. The schedule of target losses, however, would be maintained for the whole year 2011-12, regardless of the actual T&D losses incurred by MEPCO. Thus, if MEPCO were not able to meet the target loss reduction, it would be penalized by not being able to recover the cost of extra units lost from the retail tariffs. If, on the other hand, MEPCO's actual loss reduction outperformed the target level, it would be able to gain extra revenues from the loss adjustments to the PPP.

2.3 Distribution Margin Formula

The average distribution margin for the financial year 2013-14 would be set in accordance with MEPCO's expected revenue requirements, based on the following formula:

Avg. Margin = O&M + Depreciation + RORB — (Amortization + Other Income) Total Unit Sales

5

Where:

O&M is the expected operating and maintenance cost per kWh , which includes the estimated cost of technical service and repair, necessary materials for operation, employees cost , administration, management and other operating costs related to MEPCO's distribution and supply business. The O&M component for the F.Y. 2013-14 would be established on the basis of forecast demand and inflation. The O&M cost is discussed in detail at Annex-A.

Depreciation Depreciation is provided in accordance with the company's policy, which is on straight line method on basis of useful life allocated to each class of asset. The depreciation detail of assets is given at form 13.However, the depreciation has been adjusted to the extent of amortization of deferred credit.

Profit Rate Base: Profit Rate Base is defined as sum of existing fixed assets plus work-in-progress and new investment reduced by accumulated depreciation and deferred credit.

Average Rate of Return is a pre-tax return on the Profit Rate Base. The average rate of return as approved by authority is calculated under WACC, with cost of equity being calculated under CAPM. The investment is typically financed with a combination of debt and equity, therefore the appropriate rate of return would be a market-based weighted average of the cost of capital. However, authority has started using post tax return on the plea that distribution company is not in profit. The post tax return was also used in determination of FY 2012-13 which also had a PYA of Rs 13,655(M) and there was no chance that distribution Company would have run into loss if that tariff had been implemented timely but again presumption was taken that company will run into loss, which is not justified. Therefore, it is prayed that pre tax return be allowed for FY 2013-14.

Total Unit Sales: A schedule of the total unit sales (in M/KWh) of MEPCO across all customer categories is forecast for the F.Y. year 2013-14. This forecast is used to determine the average distribution margin per unit (Rs/kWh) needed to cover the revenue requirement expected for the year.

Customer-specific retail tariffs will be set as follows:

Category-specific Category-specific Retail = PPP + Distribution Tariff Margin

The PPP is the power purchase price. It reflects the amount paid by MEPCO to CPPA. Since it is difficult to estimate future PPP with precision, the PPP is based on the Average PPP determined by NEPRA for the financial year

6

2012-13 with a minor change due to seasonal impact envisioned. This will become the reference PPP for setting the tariff rate.

Working Capital requirement has been made in compliance of authority instructions and its working is given as hereunder:

One month PPP inclusive of GST and one and a half month DM I Rs. 14,000 (m) Rate of mark up (KIBOR+3%) 12% Amount of markup Rs. 1,700 (m)

2.4 Other Proposals

Exclusion of LPS from other income for tariff purposes is required as the delay and nonpayment by consumers has become a major problem for the sector which has ultimately swelled the receivable of power distribution companies and in case of MEPCO we have had a huge increase in receivables pertaining to agriculture but the LPS charged on their bills will again benefit them and MEPCO will be left holding the all repercussions on delayed payment by consumers.

Furthermore, CPPA has been constantly issuing debit advices to MEPCO on account of supplemental charges paid by it to power generators. This has become a huge amount of Rs ----hanging between CPPA and MEPCO. This cost is principally paid by CPPA due to delay in its payments to power generators, similarly power distribution companies levy late payment surcharge on its non regular paying consumers but that same amount is again allowed for benefit of consumers by decreasing D.M. to that extent. The regulator has to ensure that whole sector works in an efficient manner and any party not fulfilling its duties is discouraged from doing so, but the regulator in its policy to include this in other income is again giving benefit to also those consumers which defaulted.

Therefore, it is prayed that the exclusion of LPS from other income be granted to promote equity between all stakeholders of the sector.

Exclusion of Amortised Deferred Income pertaining to Deposit Work from Depreciation is requested on the grounds that the distribution company creates assets from the following three sources i.e

o Own sources o Deposit works o Capital Contribution

The regulator allows cost allocation of fixed assets in a revenue period by allowing depreciation for assets created through own sources but it does not allow same for assets created through Deposit works and Capital Contribution.

Whenever, an asset is owned it comes with benefits and responsibilities. Whereas in instant case the assets owned through Deposit work does not give any benefit though the responsibility of maintaining the system even after completing its useful life is solely on the Power Distribution Company (MEPCO).

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The assets created through Deposit work are excluded from RAB which deprives any profit from use of the assets though these assets are financed through its owner, neither cost recovery is allowed through depreciation so a power distribution company can be able to keep the system updated after its useful life in order to successfully discharge its liability.

It has been established through previous petitions that assets created through Deposit Works are for village electrification, which not only cater to downtrodden people who are incidentally are also the lowest level consumers but also add to distribution loss of 0.73% for every 1000 village electrification of Company but no return is allowed on the basis of accounting treatment alongwith depreciation. The clear distinct liability of maintaining those assets even after their useful life, which would be not easy to finance from any outside source on the basis of cost and quantum.

It is therefore, prayed to please allow depreciation on these assets so that MEPCO can be able to undertake these investments and keep serving its consumers.

Approval of Loan allotted to Mepco by CPPA is required as CPPA through PH(P)L has taken loans to pay outstanding receivables of power generators which were basically payable by power distribution companies. The existence of such a heavy amount in sector in shape of circular debt was hindering in smooth operation of sector as a whole. These payables to CPPA are due to host of reasons like delayed determination of tariff and FPA, litigation in courts etc.

The loan of Rs 136 (B) has been apportioned by CPPA which for MEPCO comes out to be Rs19(B),Its financial cost per year comes out to be about Rs 2.5(B) which may please be allowed by NEPRA

2.5 Revision of Retail Tarff

While it is important for MEPCO to have certainty about the period of the review, of greater importance is the existence of clear rules about the procedures for re-setting tariffs.

Based on the methodology discussed above, possible adjustments to retail tariffs are strictly limited to the following items:

Scheduled Change in Distribution Margins: The retail tariff is subject to revision warranted by fundamental changes in the basic assumptions formulating tariff formula.

Changes in PPP: At any point in time, changes in the Power Purchase Price (e.g. due to fuel cost adjustments) would automatically result in a corresponding change in retail tariffs on monthly basis.

Inflation Adjustments: The O&M component of the distribution margin would be automatically adjusted for exceptional inflation.

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2.6 Adjustment of PPP

It is proposed that instead monthly adjustment of only EPP and that without loss

adjustment may please be replaced in the full PPP adjusted with regulator approved loss

target.

This methodology will not only stream line the cash flow of Power Distribution

Companies but it will also reduce the Authority's calculation of quarterly determinations on

these issues with issue pertaining to adjustment of variable O&M pending for quarterly

adjustment.

2.7 General Conditions

Introduction of Residential and non Residential Tariff.

Reduction of Load of B1 category from 25 KW to 20 Kw.

Construction of industrial building, tariff be charged under temporary commercial

tariff.

2.8 SUBMISSION

In the end NEPRA is requested to allow MEPCO its tariff determination sought, at

its earliest so that MEPCO is able to pay power purchase cost, discharge its O&M cost for

smooth operation and pursue its development plans for 2013-14 in order to better serve its

consumers.

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Annex-A

O&M Expenses

MULTAN ELECTRIC POWER COMPANY LIMITED (MEPCO)

Distribution Margin

Distribution Margin comprises of O&M, depreciation and RORB. The 0 & M component is very important part of the D.M. and sufficient 0 & M is very essential to run the affairs of the company smoothly, which is briefly discussed below:

COMPARISON OF OPERATING AND MAINTENANCE EXPENSES

Rs. In Million

DESCRIPTION

F.Y 2013

Estimated Actual

Required for

F.Y. 2014

VARIATION

Salaries and Benefits 8294 9276 982

Repair And Maintenance 1035 1100 65

Traveling Expenses 675 700 25

Vehicle Expenses 310 340 30

Other Expenses 849 885 36

Total:- 11163 12301 1138

0 & M Expenses

The MEPCO requirement for Operating and Maintenance expenses for the financial year 2013-14 are Rs. 12301/- million against actual expenses of Rs. 11163/- million. The brief head wise detail is re-produced below and discussed against relevant head.

1

Rs. In Million

Actual (Audited)

Actual (Audited)

Actual (Audited)

Actual (Audited)

Actual (Audited)

Estimate Actual Project.

2008 2009 2010 2011 2012 2013 2014 3443 4433 5696 6994 8294 9276

388 466 598 821 952 1035 1100 7 7 11 11 15 14 18

30 27 29 29 28 33 38 32 35 37 44 48 48 50

75 57 78 87 90 150 150 197 216 239 381 406 675 700

0 7 6 11 11 17 18 11 17 27 46 51 50 55

16 14 20 28 38 39 42 164 211 238 253 288 310 340

233 252 271 278 289 315 315 22 25 10 34 21 25 26 66 50 19 21 26 33 258 147 177 158 173

4310 5012 6749 7887 9408 11163 12301 472 896 1594

Employees Cost Repair and Maintenance

Rent rates and taxes Telephone and postage

Power light and water Office supplies and other expenses

Travelling Expenses Insurance

Professional fee Computer and outside services

Transportation Electricity bills collection charges

Management fees

Authority overheads Other charges

TOTAL

Prov. For bad debt

EMPLOYEES COST

Salaries Wages and Benefits

It includes salary; house rent allowance, cash medical, adhoc allowance etc. employees benefits. The Government of Pakistan has allowed 10% adhoc relief in annual budget for F.Y. 2013-14 and the same is to be allowed by MEPCO to its employees. Similarly 3% increase assumed from December 2013 onward as annual increment. On this assumption of Salary, allowances and benefits comes to Rs. 6105/- million as shown in table below.

Rs. In Million Description 2008-09 2009-10 2010-11 2011-12 Estimated

Actual 2013

Projected 2013-14

Basic Pay 1160 1231 1342 2174 2673 2945 Allowance 837 1128 2100 1819 2187 2410 Employee Benefits 292 315 387 474 574 750 Total 2289 2674 3829 4467 5434 6105 % Increase 18.90 16.81 43.19 16.66 21.65 12.35

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Employee's Retirement Benefits.

The employee's retirement benefits are based on actuarial valuation made by actuarial firm as detailed below in the table. It is further added that the provision for retirement benefits are provided for those employees who are on regular cadre. The recruitments made on contract basis after approval of the Government, provision of such employees has not been included in the above provision. Our submission to the Authority is to allow the Rs. 3171/ million for retirement benefits.

Rs. In Million Description 2008-09 2009-10 2010-11 2011-12 Estimated

Actual 2013

Projected 2013-14

Pension 665 1241 1507 1681 2343 2343 Medical 81 119 264 308 320 320 Utility Expenses 155 240 156 177 285 285 Leave Encashment 30 160 80 360 223 223 Total 931 1759 2009 2525 3171 3171 % Increase 18.00 88.89 14.21 25.68 - -

MEPCO is going for actuarial valuation and any change will be submitted on receipt of report. Repair and Maintenance.

The repair and maintenance expenses have been assumed at Rs. 1100/- million which is 6.28% above as compared to last year. As per normal practice the maintenance expenses are 3.5% of the net fixed assets which comes to Rs.2100/- million but MEPCO has proposed 1.84 % of the amount simply not to over burden the consumers. The Authority is requested to allow Rs. 1100/- million for financial Year 2013-14 for R&M.

Description 2008-09 2009-10 2010-11 2011-12 Estimated Actual 2013

Projected 2013-14

Offices & Residential Building 18 18 21 23 25 28 Grid Stations 35 33 52 67 54 65 Transmission Lines 8 6 5 4 4 5 Distribution Transformers 147 161 253 456 521 546 Service Drops 107 83 132 101 122 130 Meters etc. 143 286 345 284 285 300 General Equipments 4 6 8 11 18 20 Others 4 5 5 6 6 6 Total 466 598 821 952 1035 1100

ti 3

Travelling Expenses.

The Federal Government in its budget for the year 2011-12 had enhanced the daily allowance to the employees from BPS 1-16 and BPS 17-22 in from August 2012 MEPCO has the largest network in the country, the employees have to travel to attend the complaints, maintain the system to ensure the continuous supply and other matters. The actual expense under this account head in the last year 2012-13 is Rs.675/- million. MEPCO Board of Directors has approved one new operation circle which will also require additional amount under this head. The Authority is requested to consider the fact and allow Rs. 700/- million.

Transportation/Vehicle Expenses.

MEPCO's service area comprises of 13 districts of southern Punjab having largest network and consumers in the country. The vehicles have to run for attending complaints, maintenance of the system and other related matters of the company. There is continuous upsurge in the prices of the petrol, diesel, Mobil oil and spare parts of the vehicles. The actual expenses under this head were Rs.288/- million, As explain above, the service area of MEPCO is the largest among all DISCOs in the Punjab province and largest network in the country, the comparison of vehicle expense with those other companies does no seem appropriate. Moreover, the MEPCO Board Directors has approved new operation sub-divisions. MEPCO,s actual requirement for financial year 2012-13 is Rs. 310/ million.

Other Operating Expenses

Other operating expenses include rent rates & taxes, Utility expenses, communications, management fees, electricity collection expenses, advertisement, collection expenses etc. The actual expenses for last year were Rs. 2593/- million and have projected for the next financial year 2012-13 at Rs. 2706/ million. The amount has been demanded after due diligence/consideration of actual requirement for the financial year 2011-12. The Authority is requested to allow the same.

Rs. In Million Description 2008-09 2009-10 2010-11 2011-12 Estimated

Actual 2013

Projected 2013-14

Rent, Rates and Taxes 7 11 11 15 14 18 Utility expenses 35 37 44 48 48 50 Communication 27 29 29 28 33 38 Office Supplies and other expenses 57 78 87 90 150 150 Professional fees 17 27 46 51 50 55 Outsourced Services 14 20 28 13 12 15 Management Fees/AOH 75 30 55 21 25 26 Advertising & Pub. 6 231 114 148 120 120 Miscellaneous Expenses 47 48 51 66 83 98 Sub Total 285 511 465 480 535 570 % Increase (9.52) 79.30 (9.00) 3.22 11.46 6.54 Electricity Bills Collection Expenses

252 271 278 289 315 315

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STANDARD PETITION FORMATS FOR DISTRIBUTION COMPANIES

MULTAN ELECTRIC POWER COMPANY LIMITED INDEX

FORM NO. DESCRIPTION

1 Company Statistics

2 Profit & Loss Statement

3 Profit & Loss Statement ( Month wise )

4 Balance Sheet

5 Cash Flow Statement

6 Power Purchase (Actual for Financial Year 2012-13)

7 Line Losses Statement

8 DISCO load factors

9 Average Rate per Unit Purchased and Sold

10 DEMAND (Actual and Calculated) and Number of Customers

11 Sold Energy Evaluation and Setting up Sold Energy Average

12 Load Growth Evaluation and Setting up Load Average

13 Asset Register

14 Aging of Accounts Receivables

15 Sales Growth with Distribution losses

16 Operating Cost

17 Distribution Margin Comparison

18 Financial Charges

19 RORB Calculation

20 Revenue Requirement

21 Investment

22 Interest on Development Loans

23 Development Loan

24 BONDS

25 Domestic Consumer's Analysis

26 Provision for Tax

27 Existing & Proposed Tariff Statement

28 Revenue & Subsidy Statement

29 Proposed Revenue & Subsidy Statement

FORM -1

MEPCO Company Statistics

Actual Projected

Peak demand during FY Number of Consumers Area Circles Divisions Sub Divisions Length of Feeders Average Length of Feeders Maximum Length of Feeder Minimum Length of Feeder Targe for new connections

3360 3528

4674094 4904094

105505 105505

8 9

35 35

152 152

69341 69341

70 67

250074 230000

Length of High Voltage Transmission lines (132 kV) 2932 3087 Length of STG lines (66 and 11 kV) 64608 64824 Length of Low Voltage Distribution lines (400 V) 46274 46449

Number of HV transformers Number of burned down HV transformers Number of STG transformers Number of burned down STG transformers Number of LV transformers 162315 Number of burned down LV transformers 1366 1210

A

B

Number of Employees Qualified Professionals Engineers Others

Staff Technical Clerical Non Technical

Strength Cost Period 2013 Period 2014

Actual Projected

289 332

200 223

11513 12541

846 1174

4365 4950

Period 2013 Actual

260 180

3264 254

1210 51681

Period 2014 Projected

293 197

3468 346

1352 5655

216

225

142284

1

FORM - 2

MEPCO Profit & Loss Statement

<=1 rii:P4e,66)

Power Balances

Determined Actual Projected

Units Received [MkWh] 12,701 11,952 12,466

Units Lost [MkWh] 1,905 2,039 2,057

Units Lost [%age] 15.00% 17.06% 16.50%

Units Sold [MkWh] 10,796 9,913 10,409

Revenue Sales Revenue [Min Rs] 160,396 83,815 96,999

Subsidy (Min Rs] 31,780 73,005

Fuel Price Adjustment [Min Rs] 3,357

Total Sales Revenue [Min Rs] 160,396 118,952 170,004 Rental & Service Income [Mln Rs] 282 269 276 Amortization of Def Credits [Min Rs] 1,555 1,563 1,746

Other Income (Min Rs] 1,959 2,745 2,279 Total Revenue [Min Rs] 164,192 123,528 174,305

Operating Cost Power Purchase Cost [Mln Rs] 137,997 121,554 130,602 Adjustment of Cr. Advice by CPPA ona/c of PPP of previous years [Min Rs] (3,277) O&M Expenses [Min Rs] 7,556 11,611 12,509 Depreciation [Mln Rs] 2,464 2,645 2,899 Amortization [Min Rs]

Provision for Bad Debt [Mln Rs] 300 Total Operating Cost [Min Rs] 148,017 132,532 146,310

EBIT [Min Rs] 16,175 (9,004) 27,996 Financial Charges [Mln Rs] - 4,200 EBT [Min Rs] 16,175 (9,004) 23,796 Tax [Min Rs] 8,328 EAT [Min Rs] 16,175 (9,004) 15,467 WPPF [Min Rs] 773 Profit for the period [Min Rs] 16,175 (9,004) 14,694 While submitting Quarterly Petitions , this form should be submitted with actual Profit & Loss of of previous quarters and projected profit & loss of next quarter. The Balance Sheet should be substantiated with notes to the accounts.

2

Actual • tf,t. Actual Actual Actual Actual Actual Actual Actual Actual Actual Actual Actual

1,269 1,284 1,122 3,675 1,053 942 831 2,825 772 686 865 2,323 868 1,066 1,195 3,129 11,952

324 297 153 774 153 72 56 281 82 72 173 327 156 248 253 657 2,039 25.56% 23.15% 13.59% 21.06% 14.53% 7.65% 6.72% 9.94% 10.64% 10.43% 20.03% 14.08% 17.98% 23.29% 21.17% 21.01% 17.06%

945 987 970 2,901 900 869 775 2,544 690 614 692 1,996 712 818 942 2,471 9,913

FORM - 3

MEPCO Profit & Loss Statement (FY.. 2012-13)

Actual

Power Balances

Units Received IMI(Wh/ Units Lost /PAWN Units Lost 156a901 Units Sold

11MINIE Actual

Actual Actual

Revenue Sales Revenue Min Rs] 8,020 8,462 8,259 24,741 7,059 7,701 6,451 21,211 5,743 5,526 5,687 16,956 5,835 6,676 8,396 20,907 83,815 Subsidy fkln Fts] 3,211 3,518 3,573 10,302 3,017 2,859 2,319 8,194 1,883 1,701 1,869 5,453 2,135 2,563 3,132 7,830 31,780 Fuel Price Adjustment RAI. fist 494 (42) 29 480 20 654 699 1,373 681 216 500 1,396 271 485 (648) 108 3,357 Total Sales Revenue IMIn Rs] 11,725 11,938 11,860 35,524 10,096 11,213 9,469 30,778 8,307 7,442 8,056 23,805 8,241 9,724 10,880 28,845 118,952 Rental & Service Income Pia IN 23 16 36 75 23 24 20 67 21 20 20 61 22 22 22 66 269 Amortization of Def Credits Ma Rs/ 125 126 127 379 129 130 131 389 132 9 164 304 164 164 164 491 1,563 Other Income [Min Rs] 198 243 254 694 233 235 205 674 191 171 594 957 140 140 140 420 2,745 Total Revenue pin Rs] 12,071 12,323 12,277 36,672 10,481 11,603 9,825 31,908 8,651 7,643 8,833 25,127 8,567 10,049 11,205 29,821 123,528

Operating Cost

Power Purchase Cost pan Rs] 12,011 11,047 9,859 32,917 10,311 9,150 9,780 29,241 10,782 7,828 9,861 28,471 9,471 10,940 10,515 30,925 121,554 O&M Expenses Mn Rs] 759 914 851 2,523 1,103 857 760 2,720 870 803 1,174 2,847 1,174 1,174 1,174 3,521 11,611 Depreciation [Mn Rs/ 206 207 208 622 213 212 214 640 215 208 205 628 241 257 257 755 2,645 Amortization Mil Rs] - - - - Provision for Bad Debt [Mn

n Rs] - - - - - Total Operating Cost 88n Rs] 12,976 12,168 10,918 36,062 11,627 10,219 10,754 32,600 11,867 8,839 11,240 31,946 10,886 12,370 11,945 35,201 135,809 EBIT pin Rs] (904) 1551,360 610 Financial Charges [Mn Rs]

(1,146) 1,384 (929) (692) (3,216) (1,196) (2,407) (6,819) (2,319) (2,321) (740) (5,380) (12,281) - EBT Ma Rs) (904) 155 1,360 610 (1,146) 1,384 (929) (692)

pin Rs] (3,216) (1,196) (2.407) (6,819) (2,319 Tax ) (2,321) (740) (5,380) (12,281)

- - EAT pan Rs] (904) 1551,360 610 (1,146) 1,384 (929) (692) (3,216) (1,196) (2,407 WPPF 1141n Rs1 ) (6,819) (2,319) (2,321) (740) (5,380) (12,281) - - - - Profit for the period Min Rs] (904) 155 1,360 - 610 (1,146) 1,384 (929) (692) (3,216) (1,196) (2,407) (6,819) (2,319) (2,321) (740) (5,380) (12,281)

(82) (6,901)

3

MEPCO

Profit & Loss Statement (Projecfecr2013-14)

Power Balances

fl.'•:"kr ,;• . -

Units Received

Units Lost Units Lost

Units Sold

ISAINh]

Diagel [WWII

1,320

328

24.84%

992

1,335

299

22.41%

1,036

1,167

149

12.76% 1,018

3,822

776

20.30%

3,046

1,100

155

14.12%

945

984

71

7.21% 913

868

54 628%

814

2,952

281

9.51% 2,672

807

82 10.21%

724

717

72 10.00%

645

904

178

19.65%

726

2,428

332 13.67%

2,096

907

159 17.58%

747

1,114

255 22.92%

859

1,249

260

20.79%

989

3,269

674

20.63%

2,595

12,472

2,063

16.54%

10,409

Revenue

Sales Revenue

Subsidy pin Rs] 9,246 9,654 9,488 28,388 8,806 8,508 7,582 24,896 6,751 6.011 6,770 19,532 6,963 8,001 9,219 24,183 96,999

Fuel Price Adjustment [Min Rs]

[Mn Rs]

6,959 7,266 7,141 21,366

-

6,628 -

6,403 -

5,706 -

18,737 5,081 4,524 5,095

-

14,701 5,241 6,022 6,938 18,201 73,005

Total Sales Revenue

Rental & Service Income

]Mn Rs] 16,205 16,920 16,629 49,755 15,433 14,911 13,288 43,633 11,832 10,535 11,865 34,233 12,204 14,023 16,157 42,384 170,004

Amortization Def Credits of [Mn Rs] 23 23 23 69 23 23 23 69 23 23 23 69 23 23 23 69 276

Otherincome

pin Rs] 146 146 146 437 146 146 146 437 146 146 146 437 146 146 146 437 1,746

Total Revenue pAn Rs] 190 190 190 570 190 190 190 570 190 190 190 570 190 190 190 570 2,279 Nan Rs] 16,563 17,279 16,988 50,830 15,792 15,270 13,647 44,708 12,190 10,894 12,224 35,308 12,562 14,381 16,515 43,459 174,305

Operating Cost - - Power Purchase Cost

O&M Expenses (Mn Rs] 12,555 11,552 10,313 34,419 10,838 9,611 10,273 30,722 11,325 8,227 10,353 29,904 9,945 12,630 12,980 35,556 130,602

Depreciation [Min Rs] 1,042 1.042 1,042 3,127 1,042 1,042 1,042 3,127 1,042 1,042 1,042 3,127 1.042 1,042 1,042 3,127 12,509

Amortization pin Rs]

[Mn Rs] 242 242 242 725

-

242 242 242 725 -

242 242 242 725 242 242 242 725 2,899

- Provision for Bad Debt

Total Operating Cost

[Mn Rs] - - - - - 300 300 300 pin Rs/ 13,839 12,836 11,597 38,271 12,122 10,895 11,557 34,574 12,609 9,511 11,637 33,756 11,229 13,914 14,564 39,708 146,310

EBIT - -

Financial Charges

[Ain Rs] 2,725 4,443 5,391 12,558 3,670 4,375 2,089 10,134 (418) 1,383 587 1,552 1,333 467 1,951 3,751 27,996

EBT [Mn Rs] - - - - 4,200 4,200 4,200

Tax Win Rs] 2,725 4,443 5.391 12,558 3,670 4,375 2,089 10,134 (418) 1,383 587 1,552 1.333 467 (2,249) (449) 23,796

EAT [Mn Rs] - - - - - - - 8,328

WPPF [Mln Rs] 2,725 4,443 5,391 12,558 3,670 4,375 2,089 10,134 (418) 1,383 587 1,552 1,333 467 (2,249) (449) 15,467

Profit for the period

[Mn Rs] - - - - - - - 773 Min Rs] 2,725 4,443 5,391 12,558 3,670 4,375 2,089 10,134 (418) 1,383 587 1,552 1,333 467 (2,249) (449) 14,694 • Where actual figures are available , these should be replaced by the actual figures.

4

47,873 52,515 47,873 52,515

FORM - 4

MEPCO

Balance Sheet fin million Rupees'

Previous Qrt/ FY

as on June 30, 2012

Current Qrt/ FY

as on June 30, 2013

Projected Qrt/ FY

as on June 30, 2014

Description

Intangible Fixed Assets Net Fixed Assets in Operations Total Net Fixed Assets in Operations

Capital Work in Progress Long Term Loans to Employees Deferred Cost & Long Term Deposits

Current Assets Stores & Spares Trade Debts Advances, Prepayments, Other Receivables Tariff Subsidy (Receivable from GoP) Receivable from Associated Companies Cash & Bank Balances

Total Current Assets Total Assets

Subscribed Equity Unappropriated Profit Total Equity

Long Term Liability Security Deposits Employee Retirement Benefits TFCs & SUKUK Deferred Credits Total Long Term Loan

Total Long Term Liability

Current Liability Current Maturity on Long Term Loans Subsidy Received in Advance from GoP Provision for Taxation & WPPF Receipt Against Deposit work Payable to NTDC Creditors, Accrued and Other Liabilities

Total Current Liability

Total Liabilities and Commitments

Total Liabilities and Equity

61,621 118,006

8,476 36

0.05

63,545 131,754

124,827

175,136

118,005

117,895

183,195

131,754

488

5

67,742 130,882

10,572 52

0.15

4,975 16,895 5,795

27,065 3,060 5,755

59,752 59,752

8,382 75 I

0.15 8,457

10,824 (62,264)1 (51,440)

4,975 14,067

37,517 8,740

65,299

136,924

197,016

130,882

488

13,292 101,110

9,938

10,824 (67,954) (57,131)

10,824 (76,958) (66,134)

3,995 4,545 9,645 11,781

32,634 4,034

50,308

37,001 6,765

60,092

8,512

3,536 18,092 4,039

29,398 1,649 4,907

10,624

4,480 24,497 5,021

27,140 2,480 4,125

14,155 115,745

7,024

9,102 9,245

92,546 6,515

MAIM - 0

MEPCO Cash Flow Statement fin million Rupees]

Description

Previous for Qrt/FY ending

June 30, 2012

Current for Qrt/FY ending

June 30, 2013

Projected for Qrt/FY ending

June 30, 2014

Average Monthly Demand Index (MDI) [MW] 2,763 3,360 3,528 Units Purchased Transmission Losses (132 kV) Distribution Losses

[GWh] [GWh] [GWh]

11,952 12,466

Units Sold to Customers

Average Tariff Required Average Tariff Existing

[GWh]

[Rs/unit] [Rs/unit]

9,913

11.999 11.950

10,409'

16.333 14.860

Tariff Difference

Revenue from Sales Collection from Required

[Rs/unit]

[%]

0.049 I 1.473

170,004 100.0%

Inflows from Operations Collection from Current Sales Prior Year Recovery

96,999

96,999

Outflow from Operations Payment for electricity (to CPPA) Distribution Service Cost (=DMC) Total Outflow from Operations

154,115 10,267

164,382

(67,383)

0

0

Surplus/Deficit from Operations

Inflows from Other Sources Capital Contributions Consumer Security Deposits Other Incomes GOP Subsidy (Actual and Estimated) Long Term Loan / Redeemable Capital

2,300 430

2,555 73,005

1,975 80,265

Total Inflows from Other Sources

0 0

Outflow Others Financial Charges Repayment of Long Term Loans Investment Program Working Capital/other Changes

4,200 488

7992 -1428

Total Outflow Others

Surplus/Deficit Others

0

-

0

-

11,252

69,013

Total Inflows (Operations + Others) - - 177,264

Total Outflows (Operations + Others) - - 175,634

Opening Balance 0 4,125 Surplus/Deficit for Fiscal Year Deficit from Financing/Loans

0 0 1,630

0 0 5,755

6

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FORM - 7

MEPCO Line Losses (F.Y.2012-13)

; ;; ;.") .; [ 1: 11!,; j- s• .

Power Balances

Actual Actual Actual Actual Actual Actual Actual Actual Actual Actual Actual Actual Actual

Units Received [MkWh] 1,269 1,284 1,122 1,053 942 831 772 686 865 868 1,066 1,195 11,952

Units Sold [MkWh] 945 987 970 900 869 775 690 614 692 712 818 942 9,913

Units Lost [MkVV1] 324 297 153 153 72 56 82 72 173 156 248 253 2,039

Units Lost Magel 25.56% 23.15% 13.59% 14.53% 7.65% 6.72% 10.64% 10.43% 20.03% 17.98% 23.29% 21.17% 17.06%

Technical Losses liGagel 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0%

Administrative Losses roagel 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0%

Technical Losses at Different Levels

Transmission Losses 132 kV [%age] 0% - 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0%

11 kV Losses [%age] 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0%

LT Losses [%age] 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% Total Technical Losses [%age] 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0%

FORM - 7 (A)

MEPCO Line Losses * (Projected F.Y. 2013-14)

I I. 1;-111;;- ■14rzno.re, 1.

Power Balances Units Received [MkWh] 1,320 1,335 1,167 1,100 984 868 807 717 904 907 1,114 1,249 12,472 Units Sold (MkWh] 992 1,036 1,018 945 913 814 724 645 726 747 859 989 10,409 Units Lost (MkWh] 328 299 149 155 71 54 82 72 178 159 255 260 2,063

Units Lost [%age] 25% 22% 12.8% 14% 7% 6% 10% 10% 20% 18% 23% 21% 16.5%

Technical Losses [%age] 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0%

Administrative Losses Magel 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0%

Technical Losses at Different Levels

Transmission Losses 132 kV Nage] 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0%

11 kV Losses [%age] 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0%

LT Losses Magel 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0%

Total Technical Losses [%age] 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0%

* Where actual figures are available , these should be replaced by the actual figures.

FORM - 8 MEPCO

Operational and Technical Information

DISCO load factors on yearly basis 2013-14 63%

NTDC/DISCO Delivery Points metering accuracy 98.00%

DISCO metering accuracy For all customers (residential, commercial, industrial, etc.) 96.00%

Estimated High Voltage Transmission lines losses (132 kV) 3.50%

11

FORM • 9 MEPCO

Average Rate per Unit Purchased and Sold

- Weighted Average Cost per Unit Sold to Customers

10.01 Use of System Charges (NTDC)

10.02 Estimated Average Rate (Table 11 - 11.18) [Rs/kW/Month) 85.91 10.03 Estimated Maximum Demand Indicator (MDI) (Table 11 - 11.17) [MW) 2 511 10.04 Number of Months (Fiscal Year)

191 12 10.05 Estimated Use of System Charges = (10.02 x 10.03 x 10.04)

1,000,000 Rs] 3,407

10.08 fixed/Caoacity Charge

10.07 Estimated Average Rate (Table 11 - 11.33) [Rs/kW/Month) 950.70 10.08 Estimated MDI Form 8 ( A) [MW] 2 511 10.09 Number of Months (Fiscal Year)

191 12 10.10 Estimated Capacity Charge a (10.07 x 10.08 x 10.09)

[000,000 Rs] 28,845

10.11 f why Charms

10.12 Estimated Average Energy Charge (Table 11 - 11.33) (Rs/kWh) 7.9018 10.13 Estimated Energy Purchase for Fiscal Year

[GW1r[ 12,472 10.14 Estimated Energy Charges = (10.12 x 10.13)

1,000,000 Rs) 98,550

10.15 Estimated Power Purchase Price (10.05 10.10 + 10.14) [,000,000 Rs] 130,802

10.18 Average Rate per Unit Purchased = (10.15 / 10.13) [ Rs/kWh 10.4717

10.17 Estimated Energy Sold [GM] 10,409

10.18 Average Energy Rate per Unit Sold = (10.13 / 10.17) Rs/kWh)

12.5473

10.19 Distribution Margin [,000,000 Rs] 22,358

10.20 Distribution Margin per Unit Sold • (10.19 / 10.17) [ Rs/kWh ] 2.1478

10.21 Total Cost per Unit Sold to Customers ■• (10.20 + 10.18) ( Rs/kWh ] 14.6951

10.22 Estimated Revenue from Energy Sold (10.15 + 10.19) (.000,000 Rs) 162,958

1023 Prior Period AdJustement (Uncovered Costs) 1,000,000 Rs)

10.24 Required Estimated Revenue from Energy Sold (10.22 + 10.23) 1,000,000 Rs) 152,958

While submihing Quarterly Petitions , this form should be submitted with actual amounts of previous quarters and projected figures of next quarter .

Figures in the forms should be substantiated with the forms below.

12

11.19 Month

Year

11.20 1

11.21 Jul

11.22 Aug

11.23 Sep

11.24 Oct

11.25 Nov

11.28 Dec

11.27 Jan

11.28 Feb

11.29 Mar

11.30 Apr

11.31 May

11.32 Jun 11.33 11.34

2

Avg Cap. Charge •

FORM - 9 ( A )

Table 11 CPPA Charges: Use of System, Capacity and Energy

11.01 Use of System Charges (MC)

Variable Use of

Fixed Use of Fixed Use of System Variable Use of Sum Use of Demand System Rate System Charges Energy Rate System Charges System Charges

11.02 Month Year [kW] (Ra/kW1 I Rs) (kWh) IRs/kVVh) I Rs( I Re)

11.03 1 2 3 4 5.3x1 6 7 8 . 6 x 7 9

11.04 Jul 10 2,833,531 85.910 243,454,432 1,320,096,960 243,454,432

11.05 Aug 10 2,796,751 85.910 240,268,875 1,335,221,680 240,268,875

11.08 Sep 10 2,691,464 85,910 231223,713 1,167,114,000 231,223,713

11.07 Oct 10 2,824.446 85.910 242,648,115 1,100,349,470 242,648,115

11.08 Nov 10 2,210,607 85.910 189,913,211 683,651,085 189,913,211

11.09 Dec 10 2,386,253 85.910 203,285,671 668,080,455 203,285,671

11.10 Jan 11 2,583,432 85.910 221,942,639 806,819,420 221,942,639

11.11 Feb 11 2,097,564 85.910 180,203,468 716,736,330 180,203,466

11.12 Mar 11 2,175,061 85.910 186,859,455 904,1411,640 186,859,455

11.13 Apr 11 2,171,494 85.910 188,552050 906,627,370 166,553,050

11.14 May 11 2,531,617 85.910 217,491,189 1,113,870,725 217,491,189

11.15 Jun 11 2,847,392 85.910 244,619,416 1,248,899,355 244,619,416

11.16 30,129,944 85.910 2,588,463,231 12,471,845,390 2,588,463,231

11.17 Avg per month (MW) ,.,•,' ' 42,510,129 Avg per month (MWh) 1,039,320,449

11.18 Capacity and Enemy

Capacity Capacity Energy Sum of all Use Of System Rate per Energy Final Rate Charge Charge Charges Rate per kWh kWh Rate per kWh per kWh

( Rs/kVVh [Rs( [Rs( (Rs) I Rs/kWh )

) [ Rs/kWh ) ( Rs/kWh I

15 . 11 / 11 12 13 .9.11.12 14.916 6 16.1216 17 -13/6

2,612,616,200 9,635,205,840 12,491275,472 0.1844 1.979109 7.2989 9.4624

2,369,520,400 8,879,469,040 11,489,258,315 0.1799 1.774627 6.6502 80048

2,310,733,360 7,711,113,280 10253,070,353 0.1981 1.979889 6.8070 8.7850

• 2,717,613,415 7,814,241,435 10,774,502,965 0.2205 2.469773 7.1016 07919

2,258,734,975 7,113,273,200 9,559,921,386 0.1930 2293707 7.2298 9.7165

2,243,033,960 7,774,298,310 10,220,615,981 0.2342 2.583901 8.9557 11.7738

2,530,136,235 8,514,794,805 11,268,873,679 0.2751 3.135939 10.5535 130646

2,042,174,530 5,957,850,140 8,180,228,136 0.2514 2.849281 8.3124 11.4131

1,561,932,930 8,280,908,920 10309,701,305 0.2067 2.059327 9.1367 114027

2,062,828,955 7,647,511,685 9,898,893,690 0.2058 2.275278 8.4351 10.9162

2,700,690,960 9,585,748,685 12,503,930,834 0.1953 2.4248 8.6058 11.2257

2,938,637,053 9,655 365 803 12 838 522,273 0.1959 2.3513 7.7311 102783

26,844,551,993 96,549,779,144 129,782,794,368 0.2075 2.2967 7.9018 10.4061 ' PT"." "950:1

13

FORM - 10 MEPCO

DEMAND (Actual and Calculated) and Number of Customers

A. Actuals for Demands and Number of Customers B. Forecasted Demands and Number of Customers using re resion analysis

Demand Actual

Demand Calculated

Number of

Fiscal /Forecast /Forecast Customers Year [,000 kW ] change [,000 kW ] change [ ,000 ] change

12.01 2000-01 1,318 1,318 12.02 2001-02 1,382 4.9% 1,382 4.9% 2,181 12.03 2002-03 1,453 5.1% 1,453 5.1% 2,308 12.04 2003-04 1,531 5.4% 1,531 5.4% 2,503 12.05 2004-05 1,618 5.7% 1,618 5.7% 2,758 12.06 2005-06 1,721 6.4% 1,721 6.4% 3,046 12.07 2006-07 1,831 6.4% 1,831 6.4% 3,371 12.08 12.09

2007-08 2008-09

2,218 T-2412 'f

21.1% 8.7%

2,218 21.1% 8.7%

3,666 ;:!:,Fir;%3,842

12.10 2009-10 2,988 23.9% 2,373 -1.6% . ,14;041 12.11 2010-11 2,949 -1.3% 2,503 5.5% 4,260 12.12 2011-12 3,022 2.5% 2,634 5.2% 4,497 12.13 2012-13 3,360 11.2% 2,764 4.9% 4,734 12.14 2013-14 3,528 5.0% 2,895 4.7% 4,971 12.15 2014-15 3,700 4.9% 3,025 4.5% 5,209 12.16 2015-16 3,890 5.1% 3,156 4.3% 5,446

[MW; Nu000 Customers] 6000

5000

4000

3000

2000

1000

of Demand Actual/Forecasted and # of Customers

0

`:; P

4 P.

R '4 P P. A

-0- Demand Actual/Foremasead

P■ i -U-- Number of Customer.

f= : 6 '..7. 5"

g , -.

2 g !15 ;.

r 4 T.1

r_ .5 <q.,

-4- Demand Calculated/Forecasted by DISCO

14

Table/Graph 14 - Sold Energy Evaluation and Setting up Sold Energy Average

12 months Load moving

Month 11AVVIA average Jul-08 9011,827 782,312

Aug-08 891,212 779,838 Sep-08 555,219 785,383 Oct-08 811,616 782,488 Nov-08 733,593 758,094 Dec-08 573,3110 755,003 Jan-09 509,390 748,835 Feb-09 861,249 741,288 Mane, 76■11•10►

DISCO Evaluation of Sold Energy to Consumers by Using 12 Month Moving Average

.41011640AInrollt4v4044reelPeo'10114•00,4110 •virn 4,4,1100,41vv1, •toil,tervev*.foel 410419011 iMPOPI PM" 60 /PEPIN MorM4 SIS1EMI

.:aft,;.

1200000

1000000

FORM - 11 MEPCO

15

Table/Graph 13 - Load Growth Evaluation and Setting up Load Average

1,600,003

1409000

1,200.000

1,003,00o

so3,000

Ooo,oao

403,030

200,000

AO' s

1,027,7811 Load Averogo for last 12 months 11000119898 Awing. Load for not Fiscal Year

DISCO Evaluation of load Growth by using 12 Months Moving Average

FORM - 12 MEPCO

Month Load MWhI

12 months moving average

Jul-08 1,162,332 959,770 Aug-08 1,104,200 950,442 Sop-08 1,234,798 930,723 Oct-08 909,429 932,559 Nov-08 848,3116 921,399 0e0-013 990,019 925,692 Jon-09 621,340 914,034 Feb-09 779,492 905,582 Mar-09 933,031 907,249 Apr-09 1130,144 005,677

May-09 1,110,139 911,431 Jun-09 1,070,0114 923,913 Jul-09 1,104207 924,288

Aug-09 1,319,031 924,470 Sop-09 1,277,949 942,365 Oct-09 970,0116 945,961 Nov-09 910,021 951,013 Dec-09 891,063 956,587 Jan-10 726,282 9131,705 Fob-10 912,420 990,700 Mar-10 043,381 993,444 Apr-10 594,397 994,306

May-10 1,243,383 998,827 Jun-10 Jui.,0

1.198.038 1,009,281 1,387200 1.019.927

Aug-10 1223,063 1,038.848 Sop-10 1,193264 1.028,850 Oct-10 1,910,933 1,021,787 Nov-10 981,139 1,025,193 Dec-10 848,9118 1,022,370 Jan-11 799,192 1,018,837 Fob-11 7111,127 1,024,463 Mar-11 930,219 1,016,43E1 Apr-11 979,107 1,023,075

May-11 1,260,021 1,023,241 Jun-11 1,394,139 1,024,344 Jul-11 1,302,263 1,037,353

Aug-11 1,407238 1,037,741 Sop-11 1,121,113 1,053,125 Oct-11 1,137,406 1,047,119 Nov-11 989,922 1,057,658 Dec-11 892,391 1,066,699 Jan-12 836,6113 1,069,656 Feb-12 629,774 1,072,936 Mar-12 1194,620 1,082,408 Apr-12 946,722 1,079,431

May-12 1,017,128 1,079,975 Jun-12 1,074,800 1,060,0113 Jul-12

Aug-12 AVIPPINAll 1,036,740

1,028,996 Me9111e98 WPM/1M Sop-12 1,018,692

Oct-12 1/0/100899 1,018,775 Nov-12 941,513 1,012,572 Dec-12 830,700 1,009,562 Jon-13 772,076 1,004,258 Feb-13 885,874 998,719 Mar-13 885.212 986,7271 Apr-13

May-13 887,587

emeanneto 984,2E15 982,773

Jun-13 SPOISSAPOS 998,838

16

Asset register as the year ended at date June 30, 2014 (Projected)

No. Description

Cost Accumulated Depreciation Book Value as As at July 01, Addition/ deletions

As at June 30, 0

As at July 01, Charge during the veer

Adjustments As at .June 30, on June 30,

A. Land

1

2

Freehold

Leasehold 181,232,265 181,232,255 0 181,232,255

2,277,338 2,277,338 790,164 0 790,184 1,487,174 Total 183,509,593 0 183,509,593 790,164 0 0 182,719,429 B. Buildings 790,164

1

2

Residential Buildings 1,027,253,075 87,000,000 1,114,253,075 263,498,199 29,480,591 292,978,790 821,278,285 93,335,832 19,209,242

3

Non-Residential Buildings

GSO 478,071,848 241,500,000 717,571,848 112,545,074 605,026,774

328,739,251 0 4

Residential Buildings 744,981,958 21,500,000 768,451,958 328,739,251 437,712,707 2,351,794 0

Non•GSO Residential Buildings 9,681,245 9,881,245 2,351,794 7,309,451 Total 2,257,938,126 350,000,000 2,607,938,126 687,923,076 48,889,833 0 736,612,909 1,871,325,217 C. Sub Transmission

1

2

132 KV Sub Transmission Liner

88 KV Sub Transmission 3,351,883,659 104,440,000 3,458,303,859 1,910,868,145 138,788,059 2,049,854,204 1,406,849,455

154,837,833 3

Lines

33 KV Sub 203,244,902 203,244,902 0 154,837,833 48,607,069

0 Transmission Lines 0 0 0 0 0 Total 3,555,108,561 104,440,000 3,659,548,581 2,065,503,978 138,788,059 0 2,204,292,037 1,455,256,524 D. Grid Station

1

2

132 KV Grid Station

68 KV Grid Station 4,808,245,930 5,117,580,000 9,922,808,930 1,164,105,155 316,998,343 1,481,101,498 8,441,707,432

1,408,437,489 3 33 KV Grid Station

3,399,594,036 3,399,594,035 0 1,408,437,489 1,993,156,546 0 0 0 0 0 0 Total 8,204,842,965 6,117,580,000 13,322,402,965 2,570,542,844 316,996,343 0 2,887,538,987 10,434,863,978 E. 11 KV Distribution Equipments

1

2

11 KV Poles

11KV Line 5,448,317,538 90,600,000 5,538,917,538 1,866,177,278 202,789.724 2,068,967,002 3,469,950,536

3,758,885,824 3 Distribution Transformer

11,384,390,590 136,900,000 11,500,290,590 430,512.492 4,189,398,316 7,310,892,274 4,335,832,590 17,423,556,108 407,700,000 17,831,255,108 730,448,665 5,066,079,255 12,765,175,853 Total 34,238,263,238 834,200,000 34,870,463,236 9,960,695,692 1,363,748,882 0 11,324,444,574 23,546,018,662 F. LV Distribution Equipments

1

2

LV Poles

440 LV Distribution 4,822,202,323 90,600,000 4,712,802,323 1,570,591,045 253,800,340 1,824,391,385 2,888,410,938

0 Line 0 0 0 0 0 3

4

220 LV Distribution Line

KWh Meters & Service Cable 6,322,299,887 75,600,000 6,397,799,887 2,034,070,797 241,830,020 2,275,700,817 4,122,099,070

1,181,148,173 5 Misc. Equipment

4,892,261,082 3,382,400,000 8,254,881,082 387,187,389 1,588,333,582 6,688,327,520 3,243,082,880 11,378,760,561 347,300,000 11,728,080,561 146,917,220 3,390,000,100 8,338,060,481 Total

27,215,523,853 3,875,800,000 31,091,323,853 8,028,890,895 1,029,534 969 0 9,058,425,864 22,032,897,989 G. Vehicles

1

2

132/66/33 KV GSO Vehicles

Vehicles 94,209,383 50,000,000 144,209,383 36,313,842 1,544,585 37,858,427 108,350,958

527,172,573 583,250,705 583,250,705 22,630,520 549,803,093 13,447,812 Total 657,460,088 50,000,000 707 460 088 563,486,415 24,175 105 0 587,861,520 119,798,568 H. Detail of General Plant Assets

1

2

Computer Equipment

Fumiture/Work 96,955,091 98,955,091 72,340,114 5,674,288 78,014,382 18,940,709

309,537,615 211,758,399 3

shop/Mis.Equip 259,537,615 60,000,000 17,392,540 229,150,939 80,386,878 0 0

Workshop Equipment 0 0 0 0 4

5

Laboratory Equipment

Misc. Equipment 240,360 240,350 14,020 0 14,020 228,330

35,328,213 25,512,813 35,328,213 0 25,512,613 Total 392,061,269 50,000,000 442,061,269 309 625,146 23,066,808 0 332 691,954

9,815,800

109,369,315 J. O&M Equipments

Grand Total 76,702,707,691 10,182,000,000 86,884,707,691 24,187,458,010 2,945,000,000 0 27,132,458,010 59,752,249,681

17

Actual Actual Projected for FY ending for FY ending for FY ending June 30, 2012 June 30, 2013 June 30, 2014

Rs In Million 13,348 21,166 13,696 Rs In Million 605 1,477 882 Rs In Million 367 358 359 Rs In Million 212 260 267 Rs In Million 568 185 188 Rs In Million 915 1502 1,503 Rs In Million 16,015 -4--- 24,947 16,895

FORM - 14

Aging of Accounts Receivables as on 30th June

Outstanding for current year

Outstanding for more than 1 year

Outstanding for more than 2 years

Outstanding for more than 3 years

Outstanding for more than 4 years

Outstanding for more than 5 years

Total Receivables as on June 30,

c=i

This form should be accompanied with a reconcilation of bad debts written off during the year . In case of quarterly filing this form should be replaced with the most recent updated figures.

Govt Arrear Reduced Spill over Govt Subsidy (GOP 8 GST) Deferred Amount Running (Pvt) Disconnected (Pvt)

1375 950 4548 5439 2258 Due to FPA 9600 Resistannce to Disconnect / Recovery of arrear by Kisan Union 2457

18

Projected Energy Sales by Tariffs

Voltage

Level

Energy Purchased Category Energy Sales Distribution

Losses

0 Al Domestic

FLOI.Rele Pala. Upto - 50

1 -100

101 - 300 301 - 700

above 700

Temporary Domestic Al (TOD)

Projection

2

Projection

1

Summary A2 Commercial A2 - A LV > 20 kW LV A2(2) TOD LV Temporary Commercial LV

Summary Industry B-1 400 V Upto 40 kW LV B1 (TOD) LV B-2 400 V Upto (41-500 kW) LV B-2 400 V (TOD) LV B-3 11/33 KV HV B-3 11/33 KV (TOD) HV 13-4 68/132/220 KV STG B-4 66/132/220 KV (TOD) STG

Summary Bulk Supply C-1(a) upto 20 kW LV C-1(b) above 20 kW LV C-2 11/33 KV HV C2 (TOD) STG C-3 (66/132/220 KV) STG C3 (TOD) STG Temporary (E2-iia,E2iib,E2iii) HV K(A) - AJK HV K(B) - KESC (Billing) STG K(C ) Rawat Lab HV

Summary Tubewells

D-1 Scarp LV D-1 (TOD) LV D-2 (i) Punjab & Sind

LV D-2 (ii) NWFP 8 Balochistan LV AGRI T/W D-2 (1)STOD LV D-2 (ii) STOD LV 0-2 (1) TOD

D-2 (II) TOD

Summary Others G-1 Public Lighting LV G-2 Public Lighting LV H-1 Residential Colonies HV H-2 Residential Colonies HV I-Traction HV J-Co-Generation HV

Summary

Total

LV

LV

LV

LV LV

LV LV

LV

FROM - 15

0

Sales Growth

rate

Sales Growth

rate

19

FORM -16

MEPCO

Operating Cost

A Power Purchase Cost

Determined Actual Projected

Energy Charge [Mln Rs] 102,996 92,035 98,550 Capacity Charge [Mln Rs] 31,953 27,042 28,645 Transmission Charge [Mln Rs] 3,049 2,477 3,407 Adjustment * [Mln Rs]

Total Power Purchase Cost [Mln Rs] 137,998 121,554 130,602

* Provide the detail of adjustment

B Operation & Maintenance

Employees Cost **

Salaries, Wages & Benefits [Mln Rs] 5,405 5,753 6,330 Retirement Benefits [Mln Rs] 3,171 3,171

Total Employees Cost [Min Rs] 5,405 8,924 9,501 Admin Expenses [Mln Rs]

Repair & Maintenance [Mln Rs] 660 1,035 1,100 Travelling [Mln Rs] 507 675 700 Transportation [Mln Rs] 243 310 340 Management Fee [Mln Rs] - 26 28 Miscellaneous Expenses [Mln Rs] 727 849 885 Total O&M [Mln Rs] 7,542 11,819 12,554

C Depreciation & Amortization

Depreciation [Mln Rs] 2464 2645 2945 Amortization of Leased Assets [Mln Rs] 0.00

Total [Mln Rs] 2,464 2,645 2,945

D Provision for Bad Debts

Provision for bad debts *

[Mln Rs]

300 Bad debts written off

[Mln Rs]

20

<:=I 2014

FORM - 17 MEPCO Distribution Margin Comparison:

O&M Expenses Increase in %

2010 2011 2012 2013 6,563

14.440 8,574 23.6%

10,748 25.4%

11,819 10.0%

12,554 6.2% Depreciation

RORB Interest on Loans of PHPL Interest on short term Loan (working Capital) Income Tax Other Income

1,823 3,011

(2,877)

2,039 3,176

(3,387)

2,241 3,868

(3,595)

2,645 4,121

(4,772)

2,945 4,624

2500 1700

(1,968) Distribution Margin Energy Sold DM per unit

8,520 9,916

0.86

10,402 10,189

1.02

13,262 10,218

1.30

13,813 9,913

1.39

22,356 10409

2.15 DM per unit increase 0.16 0.28 0.10 0.75

Financial Char es

A Long Term Loans

GOP loans

Foreign Loans

Bonds

TFCs

Others

Total

B Short Term Loan

Running Finance

Short Term Loan

Others (PHPL) Total

Determined Actual Projected

159

1,230

1,389

1,700

2,500 4,200

C Total Financial Charges (A+B) 5,589

Note :- The Interest on Long term Loans of World Bank, Asian Development Bank, and CDL from the Government of Pakistan is chargeable to the Project during construction

22

A

B Gross Fixed Assets in Operation - Opening Bal Addition in Fixed Assets

[Mln Rs]

Determined

Two years

69,416 [Mln Rs] 6,909 C Gross Fixed Assets in Operation - Closing Bal [MIn Rs] 76,325 D Less: Accumulated Depreciation [Mln Rs] 24,007 E Net Fixed Assets in Operation [Mln Rs] 52,318 F Add: Capital Work In Progress - Closing Bal [Mln Rs] 10,264 G Investment in Fixed Assets

H Less: Deferred Credits [Mln Rs] 62,582

I Regulatory Assets Base [Mln Rs] 38,132 [Mln Rs] 24,450 J Average Regulatory Assets Base [min Rs] 22,309

Rate of Return [%age]

Return on Rate Base [Mln Rs]

• A ;;TYPrii";,. Actual Projected

69,416 76,702 7,287 10,182

76,702 86884 24,187 27,132 52,515 59752 10,572 8,382 63,087 68134 37,001 37,517 26,086 30617 25,268 28,351

16.31 16.31 4,121 4,624

10.60

2,365

FORM - 19

MEPCO RORB Calculation

23

FORM - 20

MEPCO

Revenue Requirement

Determined Actual Pe plaVA

Projected

A Power Purchase Price [Mln Rs] 137,997 121,554 130,602 B DM

O&M [Min Rs] 7,556 11,819 12,554 Depreciation [Mln Rs] 2,464 2,645 2,945 RORB [Mln Rs] 2,365 4,121 4,624 Other Income [Mln Rs] (3,796) (4,577) (1,968) Interest on Short Term Loan & PHPL

4,200 Impact of Disallowed Losses [Mln Rs]

Total DM [Mln Rs] 8,589 14,008 22,356 Prior Period Adjustment [Mln Rs] 13,809 3,357 17,047

C Revenue Requirement (A+B) [Mln Rs] 160,395 138,919 170,005

D Less/ (Excess) Recovery [Mln Rs] E Total Revenue Requirement (C+D) [Mln Rs] 160,395 138,919 170,005

FORM - 20 ( A )

Revenue Requirement (per unit sold)

Determined Actual Projected

A

B Power Purchase Price DM

[Rs/ kWh] 12.61 11.89 12.55

O&M [Rs/ kWh] 0.69 1.19 1.21 Depreciation [Rs/ kWh] 0.23 0.27 0.28 RORB [Rs/ kWh] 0.22 0.42 0.44 Other Income [Rs/ kWh] (0.35) (0.46) (0.19) Interest on Short Term Loan

0.40 Impact of Disallowed Losses [Rs/ kWh]

Total DM [Rs/ kWh] 0.78 1.41 2.15 Prior period Adejsutment 1.26 1.64

C Revenue Requirement (A+B) [Rs/ kWh] 14.6520 13.31 16.33

D Less/ (Excess) Recovery [Rs/ kWh] E Total Revenue Requirement (C+D) [Rs/ kWh] 14.65 13.31 16.33

24

FORM - 21 (A)

MEPCO Investment

"ri,f(VtIr;tozp:•70 Actual (Audited) Determined Actual/ Revised Projected

A Investment Plan DOP

ELR

STG (energy efficiency, capaicitors) Village Electricification

Others (Capital receipts)

R.F. AMR Energy Meters Total

[Mln Rs]

[MM Rs]

[Mln Rs]

[Mln Rs]

[Mln Rs]

455

980

2835

2619

1778

600

1430

1500

3167

2000

534

641

2378

3073

2756

670

1440

2332

500

1800

1250 [Min Rs] 8667 8697 9382 7992

B Financing Arrangement Local

[Min Rs] Loan

[Mln Rs] PSDP / Own Resources [Mln Rs] Grant

[Min Rs] Consumer Contribution [Mln Rs] Others (Please Mention) Deposit work [Mln Rs] Total

[MM Rs]

,1975

3717

2756 1800 3073 500 5829 7992

25

FORM - 22 MEPCO

Interest on Development Loans Ns. Million

Sr. No. Loans Interest Rate %

FY 1st Qrt 2nd Qrt 3rd Qrt 4rth Qrt Total 1

2 3

Word Bank ADB CDL

17 17 17

136.487 133.18

33.87

136.487 158.383 38.760

136.487 191.930 42.372

136.487 200.305 44.072

545.948 683.80 159.07

17_ 303.537 333.630 370.789 380.864 1,388.82

26

MEPCO FORM - 23

Development Loan

Sr. No.

1

Loan

World

Interest Rate Remaining

Years

First art of FY Second Qrt of FY Third art of FY Fourth Cut of FY 0/Bal Disbursement Repayment r CIBaI 0/Bal ! Disbursement 1 Repayment C/Bal Mal Disbursement !Repayment CIBaI OfBal Disbursement ! Repayment ! ClBal

2 3

Bank Asian Bank CDL

17% 17%

3211.47 2738.67 395.00

3211.47 3211.47 3211.47 3211.47 3211.47 3211.47 3211.47 17% 797.00

3133.67 3133.67 593.00 3726.67 3726.67 790.00 4516.67 4516.67 197.00 4713.67 797.00 797.00 115.00 912.00 912.00 85.00 997.00 997.00 40.00

I I

I I

I I

I I

I I

I I

1 1 1 1

I ,

I 1 I 1 1

I

I .

, I I I

1

.

I

I

I 1 1

1037.00

6,747.144 395.000 I - I 7,142.144 7,142.144 I 708.0001 - I 7,850.144 7,850.144 I 875.000 I I 8,725.144 - I 1 i 8,725.144 237.000 - 8,962.144

This form should be submitted for each loan appearing on the DISCO's Balance Sheet

27

FORM - 24

MEPCO BONDS

Particulars Interest

Rate

FY -- Opening

Balance Redemption

Closing

Balance

Interest

Charges

NIL

28

FORM - 25 Domestic Consumers No. of Customers 1 - 100

701-800 101 - 200

0-50 1 - 100 101 - 200 201 -300 301 - 400 401-500 501-600 601-700 701-800 801-900 901-1000 1001-1100 Total

Slabs 201-300 301-400 401-500 501-600 601-700 801-900 901-1000 1001-1100 Total Revenue

Rs.Million Average Rate

Ps./kWh

29

FORM - 26 MEPCO

Provision for Tax

Sr. No. Provision for Tax allowed Actual tax paid during the FY 1st Qrt 2nd Qrt 3rd fart 4rth Qrt Total

4440 3,591 475 8,506

######## 475.000 8,506.000

30

50.00 1.85

FORM - 27

MEPCO

Existing & Proposed Tariff Statement Month! Quarter as well as Consolidated

(Rs W (Rs/kWh) (Rs/kW/II) (Rs/kWh) Residential Up to 50 Units

For peak load requirement up to 5 kW

01-100 Units

101-300 Units 1,526 301-700Units 401 Above 700 Units 84

For peak load requirement exceeding 5 kW

Time of Use (IOU) - Peak

Time of Use (TOO) - Off-Peak

46.69%

62

Total Residential 5,088

4.00 6.0

15.15 15.65

17.65

19.50

19.50 14.00

17.45

19.70

21.70

21 70 15.55

1.80

2.05

2.20

1.55

Commercial • A2 Commercial • For peak load requirement up t

19.50 Commercial (<100) 21 0.200% 400 16.00 450

21.66

Commercial (<20 KW) For peak load requirement exceeding 5 kW 0.000% 400 18.00 450

17.85

Re•ular 2 0.020% 400 16.00 450 17.80

Time of Use (TOU) - Peak (A•2)

Time of Use (TOO) • Off-Peak (Tamp) 52 0.500% 400 19.50 450

17.85

260 2.502% 400 14.00 21.75

Total Commercial 643 6.2% • 450 15.60

Industrial

81

B1 (b) (Peak) 54 0.520%

15.50 17.25 42 0.400% 19.50 81 b Off-Peak 203 1.952% 14.00 21.75

B2 14 0.135% 400 15.00 450

15.60

B2 - TOU Peak

82 - TOU (Off-peak) 101 0.971% 400 19.50

16.70

709 8.824% 400 450

450 21.70

15.40 13.80 B3 - TOO (Peak) 169 1 624% 380

■ 19.50 430 B3 - TOU (Off-peak) 991 9.520%

380 21.75

6

13.70 430 15.25 B4 - TOO (Peak) 84 0.808% I34 • TOO (Off-peak) 408 3.923%

360 19.50 410 21.75 360 13.60 410 15.15 Total Industrial 2,775 26.7% -

Bulk Cl a Su at 400 Volts - up to 5 kW 2 0.016% CI (b) Supply at 400 Volts -exceeding 5 kW 21 0.200% 400

15.00 14.50 450

16.70

Time of Use (TOU) • Peak 4 0.040% 400 19.50 450 16.15

Time of Use OU - Off-Peak 21 0 200% 400 14.00 450

21.75

C2 Su ly et 11 kV 14 0.130% 380 14.40 430 15.60

16.05 Time of Use (TOO) - Peak 21 0.200% 380 19.50 430 Time of Use 0 - Off-Peak 94 0.900% 380 13.90 430 21.75

C3 Su above 11 kV 0.000% 360 14.30 410 15.50

Time of Use (TOO) • Peak 1 0.008% 360 19.50 410 15.95

Time of Use (TOO) - Off-Peak 4 0.040% 360 13 80 410

21.70

Total Single Point Supply 180 1.69% - 15 40

A rlcultural Tube-wells - Tariff D DI Sca •

D2 9 0.090%

15.50 1725 A • ricuttual Tube-walls 1 0 008% 200 15.00 250 16.70 Agricultual Tube-walls D-2 (5) 0.000%

Time of Use OU - Peak 0-2(1

Time of Use OU - Peak D-2 0.000%

- -

198 1.904% 200 19.50 250 21.75 Time of Use (TOU) • Off-Peak D2 1,506 14.472% 200 1180

Total Agricultural 1,715 16.5% • 250 15.40

Public Ligrpriq G 21 0.200% 16.00 Residential Colonies H 7 0.070% 16.00

17.85

17.85 S 'KIM Contracts • Tariff K (AJK) 0.000% - Time of Use (TOO) - Peak 0.000%

Time of Use (TOO) • Off-Peak 0.000% Railway TractionTracton • 1 0.000%

16.00 -

17.85 Co-Genration-J 0000% Grand Total 10,409

In Ana 100% • •

-

1,715 18

19

2.16

50.00 2.25

2.25

1.60

1.70

2.20

1.60

2.25

1.60

1.65

2.20 1 60

1,75

31

50.00 1.60

1.85

1 85

1.85

1.70

1.65

2.25

1.60

1.65

2.25

2.25 1 55

1.55

1.75

13

MEPCO

Existing & Proposed Tariff Statement (Monthly , Quarterly as well as Consolidated)

(MkWh) (%agri)

1 .

(kW) Otago

.21 fr,ni,

/ ' )

it „

'....

•-.7.71.1 7' .. , •

1.1.1

ici,:!,•') (Mln Rs) (Min Rs) (111n Rs) (Min Rs) (Min Rs) (Min Rs)

Residential

Up to 50 Units 859.97 8.28% 3,439.88 5154.66 1,714.78 For peak load requirement up to 5 kW

01-100 Units 2,130.89 20.47% 28 767 02 32,272.3 3,505.31 101-300 Units 1,526.35 14.68% 23,887.38 26 634.4 2,747.05 301-7000nks 401.36 186% 7,084.00 7,906.69 82269 Above 700 Unita 83.68 0.80% 1 631 78 1,816.09 184.31 For peak load requirement exceeding 5 kW - 0.00% - -

Time of Use (TOU) - Peak 3.12 0.03% 6089 67.77 6.88 Time of Use (TOU) - Off-Peak 62.45 0.60% 874.38 971.16 96.80 Total Residential 5,067.83 48.89% • • 66,745.30 • 74,823.12 • 9,077.82

Commercial • A2 Commercial - For peak load requirement up to 5 kW 307.27 2.95% 5,991.77 6 656 24 - 664.47 Commercial (.000) 20.82 0.20% 9.70% 118 333.09 132.30 371.80 14.70 38.51 Commercial (<20 KW) For peak load requirement exceeding 5 kW - 9.70% - - - - - Regular 2.08 0.02% 9.70% 12 33.31 13.23 37.16 1

-

3.85 Time of Use (TOU) • Peak (A-2) 52.05 0.50% 9.70% 294 1,014.88 330.75 1,132.11 37 11723 Time of Use (TOU) - Off-Peak (Temp) 260.43 2.50% 9.70% 1,471 3,646.01 1,655.04 4,062.70 184 416.69 Total Commercial 642.84 6.17% - 1,896 11,019 2,131 12,260 237 1,241 Industrial

BI 54.13 0.52% 0.00% 838.97 933.82 B1 - TOU (peak) 41.64 811.90

94.86

BI - TOU (Off-peak) 203.18

14.05 0.14% 33.00% 23

93.79

210.78

2,844.52

26.25

905.69

234.60

3,16981

3 325.09

23.82 82

B2 - TOU (Peak) 101.09 0.97% 33.00% 168 1,971.26 188.84 2,193.91 21

147 222.65 82 - TOU (Off-pe) 708.63 6.81% 33.00% 1,177 9,779.09 1,323.72 10,910.78 B3 - TOU (Peak) 189.09 1.62% 64.00% 138 3,297.26 155.63 3,678.13 18

1,131.68

380.88 B3 - TOU (Off-peak) 990.90

84.09 9.52%

0.81% 64.00%

65.00% 806

64

13,57533

1,639.76 912.00

72.66 15,106.77

1,829.17

106

9

1,531.44 84 - TOU (Peak) B4 - TOU (Off-peak) 408.36 3.92% 65.00% 310 5,553.70 352.85 6,188.29 43

189.41 634.59 Total Industrial 2,776 24.3% • 2,686 40,623 3,032 46,161 347 4,628

Bulk . Ai in Supply at 400 Volta - up to 5 kW 1.61 0.02% 0.00% 2420 C1(b) Supply at 400 Volts -exceeding 5 kW 20.82 0.20% 55.00% 21 301.86 23.33 336.16

26.94

3 2.73

Time of Use (TOU) - Peak 4.16 0.04% 55.00% 4 81.19 4.67 90.57 1 34.30

Time of Use a5U) - Off-Peak 20.82 0.20% 55.00% 21 291.45 23.33 324.76 3 9.38

C2 Supply at 11 kV 13.53 013% 55.00% 13 194.86 14.49 3531

Time of Use (TOU) - Peak 20.82 0.20% 55.00% 20 405.95 22.30 217.13

45284 3

2 22.27

Time of Use (TOU) - Off-Peak 93.68 0.90% 55.00% 89 1,302.17 100.33 1,451.91 12 46.89

C3 Supply above 11 kV - 0 00% 55.00% - - - - - 149.75

Time of Use (TOU) - Peak 0.83 0.01% 55.00% 1 16.24 0.85 18.07 0 •

Time of Use (TOU) - Off-Peak 4.16 0.04% 55.00% 4 57.46 4.25 64.11 1 1.83 6.65 Total Single Point Supply 180 1.89% • 171 2,675 194 2,982 22 304

Agricultural Tube•wells • Tariff 0 0.00% DI Scarp 9.37 009% 47.00% - 145.21 - 161.62 D2 Agricuiluel Tube-wells 0.78 0.01% 47.00% 0 11.71 0.57 13.03 __ 0

29

16.42

1.32

446.40 Time of Use (TOU) - Peak 0.2 198.18 1.90% 47.00% 116 3,864.51 144.40 4,310.91 Time of Use (TOU) - Off-Peak 02 1,506.35 14.47% 47.00% 878 20,787.63 1,097.60 23.202.3 220 2,414.84

Total Agricultural 1,715 15.47% • 994 24,809 1,243 27,688 ,

249 2,879 Public Lighting G 20.82 0.20% 333.09 371.60 38.51 Residential Colonies H 7.29 0.07% 116.58 130.06 13.48 Special Contracts - Tanff K (AJK) - Time of Use (TOU) - Peak - 0.00%

-

Time of Use (IOU) • Off -Peak - 0.00% Railway TractionTraction - 1 - 0.000% - - - Co-Genration-J - 0%

Grand Total 10,409 98% - 5,745 145,221 6,699 183,406 856 18,182

10,409 150,966

170,005 32

FORM - 28

MEPCO

Revenue & Subsidy Statement (Monthly, Quarterly as well as Consolidated)

(MkWh)

,•

Maga)

.

(kW) (%age)

,• .

(RsAW/M)

,.

(RsAVVh)

•

(RsAW/M) (RsAkVh)

• .,

Residential (Rs/kW/M) (RitAW11)

U • to 50 Units 860 8% 2.00 4.00 2.00 For ak load re• uirement u • to 5 kW

01-100 Units 2,131 101-300 Units 1,526

0% 13.50 5.79 7.71

301-700Units 401

0% 15.65 8.11 7.54

Above 700 Units 84

0% 17.65 12.33 5.32

For peak load requirement exceeding 5 kW

Time of Use OU - Peak -

3

0% 19.50 15.07 4.43

- -

Time of Use (TOU) -Oft-Peak 62

0%

0% 19.50 13.99 5.51 14.00

Total Residential 5,068 8% - -

8.22 5.78

Commercial - A2

Commercial

-

- For Sanctioned load less than 5 kW 307 0% 9.70% 19.50 For Sanctioned load 5 kw 8 above 21 0% 9.70% 400 16.00 400.00

14.77 4.73

Commercial (<20 KW) For peak load requirement exceeding 5 kW -

9.70%

6.28

400 16.00 400.00

9.72 -

Regular 2 0% 9.70% 400 16.00 400.00

9.72 6.28 Time of Use (TOU) - Peak (A-2) 52 0% 9.70% 400 19.50 400.00

9.72 6.28 Time of Use (TOU) - Off-Peak (Temp) 260 0% 9.70% 400 14,00 400.00

13.20 .. 6.30

Total Commercial 843 0% - 8.01 5.99

Industrial

10.51 15.50 B1 54 0%

B1 (b) (Peak) 42

203

14

101

709

0%

0%

4.99

5.51

5.78

5.86

6.73

131 (b) (Off-Peak) 19.50

14.00

15.00

19.50

400.00

400.00

400.00

13.99

8.22

9.14

B2 33

33

33

64

64

63

63

400

400 132 - TOU (Peak) -

B2 - TOU Off-•eak 12.77 -

B3 - TOU Peak)

83 - IOU Off-•eak

84 - TOU Peak

Total Industrial

B4 - IOU (Off -peak)

169

991

84

408

2,776

0%

0%

0%

0%

0%

0% -

400 13.80 400.00 8.01 - 5.79 380 19.50 380.00 12.68 - 6.82 380 13.70 380.00 7.75 - 5.95 360 19.50 360.00 12.37 7.13 360 13.60 360.00 7.46 - 6.14

Bulk

3.45

C1 a Su I at 400 Volts - up to 5 kW 2 0%

55

55

55

55

55

55

55

55

55

- 15.00 11.55 C1 Suv2 - ceedin 5 kW 21 Time of Use OU - Peak 4

0% 400 14.50 400.00 10.35 - 4.15

Time of Use (TOU) - Off-Peak 21

0% 400 19.50 400.00 13.01 - 6.49

C2 Su•1 at 11 kV

Time of Use (TOU) - Peak

Time of Use (TOU) - Off-Peak

14

21

94

0%

0%

0% _

400 14.00 400.00 8.01 5.99 380 14.40 380.00 10.25 - 4.15 380 19.50 380.00 12.60 - 6.90

C3 Su ••I above 11 kV

Time of Use OU) - Peak -

1

0%

0% 380 13.90 380.00 7.75

-

6.15 360 14.30 360.00 10.10 4.20

Time of Use (TOU) - Off-Peak

Total Single Point Supply 4

180

0%

0%

0%

-

360 19.50 360.00 12.18 - 7.32 360 13.80 360.00 7.35 - 6.45

Agricultural Tube-wells - Tariff 0 D1 Scarp 9 0%

47

47

47

- 15.50 10.00 5.50 D2 A ricultual Tube•wells

Time of Use OU - Peak D-2 1 0%

200 15.00 120.00 6.77 80 8.23

Time of Use (TOU) - Off-Peak D2 198

1,506

0%

0% 200 19.50 200.00 13.00 _ 6.50 200 200.00 8.00 5.80 Total Agricultural 1,716 0% -

13.80

Public Lighting G 21 0% 16.00

16.00 . 13.73

12.92 2.27

3.08

Residential Colonies H

Special Contracts - Tariff K (AJK) 7 0%

Time of Use OU - Peak - 0% Time of Use OU - Off-Peak 0%

Rallwa TractionTraction - 1 0%

16.00 Co-Genration-J - 0% 11.00 5.00

Grand Total 10,409 8% •

1 0, 409

33

FORM - 17 ( A )

MEPCO

Revenue & Subsidy Statement

(MkWh) Magri) (k1/10 (%age)

'zi:4,) , )1-.L:t.:".lLA. ...:-

(Min Rs) (Min Rs) (Min Rs) (Min Rs) (Mn Rs) (Min Rs) Residential

llp to 50 Units 860 8% 3,440 1,720 - 1,720 For peak load requirement up to 5 kW

- - 01-100 Units 2,131 0% 28,767 16,429 - 12,338 101-300 Units 1,526 0% 23,887 11,509 - 12,379 301-7000nits 401 0% 7,084 2,135 - 4,949 Above 700 Units 84 0% 1,632 371 - 1,261 For peak load requirement exceeding 5 kW - - -

Time of Use (TOU) - Peak 3 0% 61 17 - 44 Time of Use (TOU) - Off-Peak 62 0% 874 361 - 513 Total Residential 5,088 8% - - 65,745 - 32,542 -

Commercial • A2 33,203

Commercial - For peak load requirement up to 5 kW 307 0% 5,992 - 1,453 - Commercial (<100) 21 0% 9.70% 118 333 - 131 118

4,538

202 Commercial (•20 KW) For peak load requirement exceeding 5 kW - 9.70% - - - - - - Regular 2 0% 9.70% 12 33 - 13 12

Time of Use (TOU) - Peak (A-2) 52 0% 9.70% 294 1,015 - 328 294

20

687 Time of Use (TOU) - Off-Peak (Temp) 260 0% 9.70% 1,471 3,646 - 1,560 1,471 2,086 Total Commercial 843 0% - 1,895 11,019 - 3,485 1,895 7,534

Industrial

El1 54 0% 839 270 B1 - TOU (Peak) 42 812 229

- 569

B1 - TOU (Off-peak) 203 2,845 1,174

582

B2 14 0% 33% 23 211 - 82

1,670

B2 - TOU (Peak) 101 0% 33% 168 1,971 - 168

23 128_

B2 - TOU (Off-peak) 709

169 0%

0% 33%

64%

1,177

138

9,779

3,297

-

-

-

680

4,103

1,153

5,896

1,177

138

1,291

5,676

2,144 B3 - TOU (Peak)

B3 - TOU (Off-peak) 991 0% 64% 806 13,575 B4 - TOU (Peak) 84 0% 65% 64 1,640 - 600

806

64

7,679

B4- TOU (Off-peak) 408 0% 65% 310 5,554 - 2,507 310 1,040

Total Industrial 2,776 0% • 2,885 40,523 • 18,895 2,885 3,046

Bulk 23,827

C1(a) Supply at 400 Volta - up to 5 kW 2 0% 24 6 C1(b) Supply at 400 Volts -exceeding 5 kW 21 0% 55% 21 302 - 86

-

21

19

Time of Use (70U) - Peak 4 0% 55% 4 81 - 27 4

215

Time of Use (TOU) - Off•Peak 21 0% 55% 21 291 - 125 21

54

C2 Supply at 11 kV 14 0% 55% 13 195 - 56 13

167

Time of Use (TOU) - Peak 21 0% 55% 20 406 - 144 20

139

Time of Use (TOU) - Off-Peak 94 0% 55% 89 1,302 576 89

262

C3 Supply above 11 kV - 0% 55% - - - . . 728 .

Time of Use (TOU) - Peak 1 0% 55% 1 16 - 6 1 Time of Use (TOU) - Off-Peak 4 0% 55% 4 57 - 27 4 10

31 Total Single Point Supply 180 0% - 171 2,875 - 1,053 171 1,623 Agricultural Tube-wells - Tariff D

D1 Scarp 9 0% 47% - 145 - 52 D2 Agricultual Tube-wells 1 0% 47% 0 12 0 6

-

0 94

5 Time of Use (TOU) - Peak D-2 198 0% 47% 116 3,865 - 1,288 116 Time of Use (TOU) - Off-Peak D2 1,506 0% 47% 878 20,788 - 8,737 878 2,576

12,051 Total Agricultural 1,715 0% - 994 24,809 0 10,083 994 14,728 Public Lighting G 21 0% 333 47 - Residential Colonies H 7 0% 117 22 -

286

94 Special Contracts - Tariff K (AJK)

Time of Use (TOU) - Peak 0% Time of Use (TOU) - Off-Peak 0%

Railway TrectionTraction - 1 - 0% - - - Co-Genration-J 0% Grand Total 10,409 8% - 6,745 145,221 0 83,928 6,745 81,293

FORM - 29

MEPCO

Proposed Revenue & Subsidy Statement (Monthly, Quarterly as well as Consolidated)

...

(MkWh) (%age) (%age) (Rs/kW/M)

. ?%

(Rs/kWh)

.+m <xw ti w'= .. . kt

. •

(Rs/kW/M) (Rs/kWh) (RsAVV/M) (Re/kWh) Residential

Up to 50 Units 0% 5.99 2.00 3.99 For peak load requirement up to 5 kW _

01-100 Units 096 15.15 5.79 9.36 101-300 Units 0% 17.45 8.11 9.34 301-700Units 0% 19.70 12.33 7.37 Above 700 Units 0% 21.70 15.07 6.63 For peak load requirement exceeding 5 kW - - -

Time of Use (TOU) - Peak 0% 21.70 13.99 7.71 Time of Use (TOU) - Off-Peak 0% 15.55 8.22 7.33

Total Residential - 0% - • - - Commercial - A2 Commercial - For peak load requirement up to 5 kW 0% 21.66 - 14.77 Commercial (<100) 0% 450 17.85 400 9.72 50

6.89

Commercial (<20 KW) For peak load requirement exceeding 5 kW 450 17.80 400 9.72 50 8

8.13

Regular 0% 450 17.85 400 9.72 50 8.13 Time of Use (TOU) - Peak (A-2) 0% 450 21.75 400 13.20 50 8.55 Time of Use (TOU) - Off-Peak (Temp) 0% 450 15.60 400 8.01 50 7.59

Total Commercial • 0% - • • • - - • Industrial

•

81 0% - 17.25 - 10.51 81 (b) (Peak)

- 21.75 - 13.99 7.76

6.74

B1 (b) (Off-Peak) 15.60 400.00 8.22 (400)

50 7.56

7.38 B2 0% 450 16.70 400 9.14 82 - TOU (Peak) 0% 450 21.70 400 12.77 50 B2 - TOU (Off-peak) 0% 450 15.40 400 8.01 50 7.39

8.93

B3 - TOU (Peak) 0% 430 21.75 380 12.68 50 B3 - TOU (Off-peak) 0% 430 15.25 380 7.75 50

9.07

B4 - TOU (Peak) 0% 410 21.75 360 12.37 50 9.38

7.50

B4 - TOU (Off-peak) 0% 410 15.15 360 7.46 50 7.69 Total Industrial - 0% - - - - - • • •

Bulk

C1(a) Supply at 400 Volts - up to 5 kW 0%

0%

0% -

450 16.15

16.70 -

400 10.35

11.55

50 5.80 5.15 C1(b) Supply at 400 Volta -exceeding 5 kW

Time of Use (TOU) - Peak 450 21.75 400 13.01 50 8.74 Time of Use (TOU) - Off-Peak 0% 450 15.60 400 8.01 50 7.59 C2 Supply at 11 kV 0% 430 16.05 380 10.25 50 5.80 Time of Use (TOU) - Peak 0% 430 21.75 380 12.60 50 9.15 Time of Use (TOU) - Off-Peak 0% 430 15.50 380 7.75 50 7.75

C3 Supply above 11 kV 0% 410 15.95 360 10.10 50 5.85 Time of Use (TOU) - Peak 0% 410 21.70 360 12.18 50 9.52 Time of Use (TOU) - Off-Peak 0% 410 15.40 360 7.35 50 8.05

Total Single Point Supply • 0% • • • - - • - - Agricultural Tube-wells - Tariff D

-

D1 Scarp 0% - 17.25 - 10.00 7.25 . 02 Agricultual Tube-wells 0% 250 16.70 120 6.77 9.93 Time of Use (TOU) - Peak D-2 0% 250 21.75 200 13.00 8.75 Time of Use (TOU) - Off-Peak D2 0% 250 15.40 200 8.00 7.40

Total Agricultural - 0% - - - - - - • Public Lighting G 0% 17.85 13.73 - 4.12 Residential Colonies H 0% 17.85 12.92 - 4.93 Special Contracts - Tariff K (AJK)

Time of Use (TOU) - Peak 0% Time of Use (TOU) • Off-Peak 0%

Railway TractionTraction - 1 0% 17.85 11.00 - 6.85 Co-Genration-J 0%

Grand Total - 0% - - - - - - -

35

FORM - 18 ( A )

MEPCO

Proposed Revenue & Subsidy Statement (Month!y, Quarterly as well as Consolidated)

(MkWh) (%aga) (%age) (Mn Rs) (Mln Rs) (Mln Rs) (Mln Rs) (Mln Rs) (Min Rs) (Mln Rs) (Mln Rs) Residential

Rs) (Mln

Up to 50 Units 860 eDIV/01 0.00% 5,155 5,155 3,435 3,435 - For peak load requirement up to 5 kW 0.00% - - - 1,720 1,720

01-100 Units 2,131 0% 0.00% 32,272 32,272 19,934 19,934 - -

101-300 Units 1,526 0% 0.00% 26,634 26,634 14,256 14,256 - 12,338 12,338

301-700Units 401 0% 0.00% 7,907 7,907 2,958 2,958 - 12,379 12,379

Above 700 Units 84 0% 0.00% 1,816 1,816 555 555 - 4,949 4,949

For peak load requirement exceeding 5 kW - 0.00% - - - - -

1,261 1,261

Time of Use (TOU) - Peak 3 0% 0.00% 68 68 24 24 -

- -

Time of Use (TOU) - Off-Peak 62 0% 0.00% 971 971 458 458 - 44

513 44

Total Residential 5,068 SDIWOI - 74,823 74,823 - 41,620 41,620 - 513

Commercial - A2 33,203 33,203

Commercial - For peak load requirement up to 5 kW 307 0% 9.70% - 6,656 6,656 - 1,453 1,453 - Commercial (<100) 21

-

0% 9.70%

9.70%

132

-

372

-

504

-

373 -

-

1 131

-

131 132

5,203

241

5,203

Commercial (<20 KW) For peak load requirement exceeding 5 kW

Regular 2 0% 9.70% 13 37 50 13 13 13 - -

Time of Use (TOU) - Peak (A-2) 52 0% 9.70% 331 1,132 1,463 - 328 328 331 24 37

Time of Use (TOU) - Off-Peak (Temp) 260 0% 9.70% 1.655 4,063 5,718 - 1,560 1,560 1,655 804 1,135

Total Commercial 643 0% 2,131 12,260 14,391 3,485 3,485 2,131 2,503

8,775 4,158

Industrial 10,906

B1 54 0% 0.00% - 934 934 - 270 270 - 81 - TOU (Peak) 42 906 906 229 229 664 664

B1 - TOU (Off-peak) 203 3,170 3,170 1,174 1,174 676 676

82 14 0% 33.00% 26 235 261 - 82 t 82 26 1,995 1,995

82 - TOU (Peak) 101 0% 33.00% 189 2,194 2,383 - 680 680 189 152 179

82 - TOU (Off-peek) 709 0% 33.00% 1,324 10,911 12,234 - 4,103 4,103 1,514 1,702

83 - TOU (Peak) 169 0% 64.00% 156 3,678 3,834 - 1,153 1,153 1,324

156 6,808 8,132

B3 - TOU (Off-peak) 991

84 0%

0% 64.00% 63.00%

912

73 15,107

1,829 16,019

1,902 -

- 5,896

600 5,896

600 912

73

2,525

9,211 2,681

10,123 B4 - TOU (Peak)

84 - TOU (Off-peak) 408 0% 63.00% 353 6,188 6,541 2,507 2,507 353 1,230 3,681

1,302

Total Industrial 2,776 0% 3,032 45,151 48,183 - 16,695 16,695 3,032 28,455 4,034

Bulk 31,487

C 1(a) Supply at 400 Volts - up to 5 kW 2

21

4

0%

0%

0%

0.00%

55.00%

55.00%

-

23

5

27

336

91

27

359

95

-

-

-

6

86

27

6

86 -

23

5

21

250 21

273 C1(b) Supply at 400 Volts -exceeding 5 kW

Time of Use (TOU) - Peak

Time of Use (TOU) - Off-Peak 21 0% 55.00% 23 325 348 - 125 125 27

23 64 68

C2 Supply at 11 kV 14 0% 55.00% 14 217 232 - 56 56 14 200 223

Time of Use (TOU) - Peak 21

94 0%

0% 55.00%

55.00% 22

100 453

1,452 475

1,552 -

- 144 576

144

576 22

100

161

309 175

331 Time of Use (TOU) - Off-Peak

C3 Supply above 11 kV - 0% 55.00% - - - - - -

876 976

Time of Use (TOU) - Peak 1 0% 55.00% 18 18 - 6 6 - - -

Time of Use (TOU) - Off-Peak 4 0% 55.00% 64 64 - 27 27 -

12 37

12

Total Single Point Supply 180 0% 188 2,982 3,171 - 1,053 1,053 188 1,930 37

Agricultural Tube-walls - Tariff D 2,118

D1 Scarp 9 0% 0.00% - 162 162 - 52 52 - 110 D2 Agricultual Tube-wells 1 0% 47.00% 1 13 14 0 6 7 0 7 110

Time of Use (TOU) - Peak D-2 198 0% 47.00% 144 4,311 4,455 - 1,288 1,288 144 7

Time of Use (TOU) - Off-Peak D2 1,506 0% 47.00% 1,104 23,202 24,306 - 8,737 8,737 1,104 3,023

14,465 3,167

Total Agricultural 1,715 0% 1,249 27,688 28,936 0 10,083 10,083 1,248 15,569

Public Lighting G 21 0% 0.00% 372 372 - 47 47 -

17,605

324

18,853

Residential Colonies H 7 0% 0.00% 130 130 - 22 22 - 108 324

Special Contracts - Tariff K (AJK) - 108

Time of Use (TOU) - Peak - 0% -

Time of Use (TOU) - Off-Peak - 0% -

Railway TractionTraction - 1 - 0% 0.00% - - - - - -

Co-Genration-J - 0% - -

Grand Total 10,409 #01V/01 8,600 183,406 170,006 0 73,005 73,006 6,600 -

90,400 97,000

170,006 36

MULTAN ELECTRIC POWER COMPANY LIMITED

FINANCE DEPARTMENT

Subject: COMPLIANCE OF GUIDE LINE /DIRECTION

Ref: MEPCO Tariff Determination for F.Y. 2012-13 issued vide No. NEPRA/R/

TRF-220/ MEPCO 2012/4324-4331 dated April 29, 2013.

Sr.

No. Directions by NEPRA Remarks

1 To continue with the consumer awareness campaign and training of its staff with respect to TOU. Monitoring Division of NEPRA would constantly

monitor this campaign and directs the Petitioner to submit monthly revenue sheets (Form-28) in order to assess revenue implications of post TOU meters scenario.

a. MEPCO has launched extensive consumers awareness programme regarding TOU metering as well as the energy saving during the peak hours. The benefit for installation of the TOU meters is being printed on every general consumer electricity bills, whereby the consumers are informed to get installed TOU meter connection against above 5-KW load and reduce their bill, copy of the specimen of electricity bill is annexed at 'A'.

b. Radio programme regarding the awareness for installation of the TOU meter are periodically being conducted by the MEPCO and last programme were transmitted on dated 08.06.2013 and 23.06.2013 on FM-101.

c. The MEPCO has also conducted the training of the Meter Reader and M&T staff from the manufacturers of the TOU meters and compliance already been reported to the NEPRA copies enclosed, moreover continuous training session are being conducted by Regional Training Centre as well as USAID regarding TOU meter reading.

2 To take up the matter of recovery of UOSC charges to the same committee of PEPCO which included all the stakeholders and report back to the Authority on the matter not later than 30th June, 2013.

Matter has been taken up with M.D PEPCO for settlement of issue.

To submit their genuine working capital requirement needs.

To submit a concrete recovery plan, no later than 30th June, 2013.

10

11

3

4

5

6

The concerns raised by the technical division of the

Authority with respect to the software used for the study of T&D losses, must be addressed not later than 30th June 2013.

To expedite the creation of Independent Post retirement benefits funds.

To get the reported figure of additional recruitments

verified by its Auditor and if it plans to carryout

replacement hiring, a certificate from the Auditor of

the Petitioner certifying that the recruitment is done

as replacement hiring with no additional/incremental cost impact.

WAPDA and Others (including Petitioner) to come up

clearly on the settlement modality of accumulated costs in this regard till 30th June 2012 and a way

forward for the future payments of these retired employees not later than 30th June, 2013.

The trust has been formed, bye laws has

been framed by the consultants. The fund account will be opened and operative by August 31, 2013.

The auditors have been asked to verify the

recruitment the report will be submitted by August 31, 2013.

G.M Finance PEPCO has conducted meeting

in this regard and decision will be informed to the authority accordingly.

Sample technical study on new software i.e. synergy is attached for perusal please.

7 To submit its comments on draft PSA at its earliest and sign the PSA not later than 30th April, 2013.

8

9

To submit comments on TOU metering for cellular companies (issue raised by IESCO) not later than 30th April, 2013.

To submit comments on changing terms and

conditions of life line consumers, (as proposed by IESCO) not later than 30th April, 2013.

The committee has been formed at Ministry Level, the convenership of F.D FESCO and

MEPCO has submitted its comments after meeting are attached.

MEPCO has installed TOU meter against the connection exceeding load 5-KW including

cellular company, the compliance has been

reported to the NEPRA vide this office Memo

No. 6947 dated 22.05.2013, copy enclosed at annexed at 'B'.

MEPCO agreed with IESCO stance.

Working Capital requirement has been

submitted in Tariff Petition for F.Y. 2013-14

Recovery Plan for the year 2013-14 is attached at 'C'.

Mian Ansar Mahmood

Finance Director

•

MULTAN ELECTRIC POWER COMPANY - ELECTRICITY CONSUMER BILL Your Better Service-Our Pride www.mepco.com.pk MEPCO GST # 04-07-2716-007-55

SUB-DIVISION E Dia

BILL MONTH4j:,..,1 READING DATE J4,6,r ISSUE DATE ,12Ibit. DUE DATE 6.

REFERENCE No. TARIFF L) LOAD .t.;I OLD NC No.

NAME &ADDRESS.yr CONN. DATE ,A‘'(6,t.

MONTH UNITS BILL PAYMENT

C. frzkj:. .&-■

_eLL7br METER No. 1)% PREVIOUS...(4.41,- PRESENT. MF‘./.)2 UNITS STATUS

METER RENT

TOTAL UNITS JAI CONSUMED .2..y.e..4".

TOTAL COST *J :.):.j. OF ELECTRICITY

SRVC. RENT L/'/

INCOME j.f.4 TAX WITH HELD

ELECTRICITY DUTY kr" INSTALLMENT BILL ADJ.

CURRENT BILL Litel.r:y•

PTV FEE LA,...)).‘,,k: G.S.T. UNPAID DEBT 61.11,7-11)A DEFERRED AMOUNT (1),,)C.; ARREARS/AGE '=-:41:41

TARIFF SUBSIDY + GST

FEEDER 4.3 BILL CALCULATION PAYABLE WITHIN DUE DATE

L.P. SURCHARGE 6.C14,,i1;

PAYABLE AFTER DUE DATE L

* Total Cost of Electricity includes Energy / Min'mum / Fixed Charges, Fuel Adjustment Surcharge, Surcharge & Additional Surcharge.

h 1 1.1514.4.,-APIcAAL,4...1 11):': TOD

Cfr

losi eihai AAA. it Job." 5JA)V-- le:KvicAL.94_.

D A'v NON TOD ,fra. .(,XTU D if .7. -.1:0 d — -4 Li -'

Ai—G_0 ..14.

.31.... ,......;:i •

6.)) to,

1624. 9599 7972 900 800 100 „L._,Ar ...5074, 17724 12650 1200 1000 200 t YX

2 LL

BANK COPY

MULTAN ELECTRIC POWER COMPANY - ELECTRICITY CONSUMER BILL www.mepco.com.pk

Bank Stamp

BILL MONTH t).:e./ DUE DATE •,:;-;t-,,,./' REFERENCE No. /-?,.11,, PAYABLE WITHIN DUE DATE 1,0,7_,1,_1.- u, G,,,:

PAYABLE AFTER DUE DATE 1,01.,..-:f.,,,,:l,;;c,, -:"

TARGET OF REVENUE COLLECTION (F.Y. 2013-14)

Month Target of Units

Sold 2013-14

TARGET OF COLLECTION FROM BILLING TARGET Curent Dues

Arrear

(Monthly Billing) Running P.Disc Deferred

07/2013 945 9922 92% 20% 1.5% 0.02%

08/2013 987 10360 94% 15% 0.5% 0.02%

09/2013 970 10182 94% 15% 0.6% 0.02%

10/2013 900 9449 96% 12% 0.6% 0.02%

11/2013 869 9130 96% 11% 0.7% 0.02%

12/2013 775 8136 97.5% 10% , 0.7% 0.02%

01/2014 690 7244 97% 10% 0.9% 0.02%

02/2014 614 6450 99% 10% 0.9% 0.02%

03/2014 692 7265 100% 10% 1.0% 0.02%

04/2014 712 7472 99.5% 10% 1.25% 0.02%

05/2014 818 8586 98% 12% 1.3% 0.02%

06/2014 920 9655 101% 15% 1.5% 0.02%

Total 989t f0#150.,-. . %-i _ .;..

Action Plan for Recovery

1) Running Arrear

No discrimination between Govt. & Private defaulters, disconnect supply without priority. List out slab wise and age wise arrear for monitoring of recovery. The billing dispute shall be decided within 7 days for recovery of actual billing and adjustment of wrong billing. Initiate disciplinary action on pending EROs aging 60 days and above

2) Amount deferred by Department

The power delegated under book of financial power shall keep in view while giving executive order. Officer exceeding the power and keeping time limit beyond allowed will be dealt with disciplinary action. Order to keep the amount deferred of ERO's receivable or over billed cases shall not be given and genuine efforts be made for recovery. All old cases shall forthwith be reviewed for cancellation of deferred amount beyond prescribed time.

3) Amount deferred by Order of Courts

Maximum efforts be made for issuance of bills error less and according to genuine consumption of consumers. The effort shall be made for deciding the dispute out side the court as per power delegated by the Authority through special committee. The MEPCO Counsel shall be associated and provided assistance for defence of case in Court of Law. The XEN & RO shall attend the hearing of High Court, Session Court, Electric Inspector and Wafaqi Mohtasib. The cases of Industrial connections shall also be contested by the said officers. The SDO shall contest the Tubewell, Commercial and heavy amount cases in person and also depute L/S Feeder Incharge to attend proceeding of important cases in Court of Law.

4) Receivables against PDISC

To raise debit against the permanently disconnected premises in case of illegal restoration or direct supply is banned unless connection is restored, legal action is taken and payment of detection bill is recovered, only the SE will be allowed to order debit if payment and arrear is recovered.

Feeding of ERO against consumers having installed dedicated transformers is banned unless the record and certificate about removal of

transformer and other allied material is given by SDO on the executed

ERO.

XEN is responsible as per commercial procedure for recovery from disconnected premises arrear Rs. 500/- and above and continuous monitoring to ensure that disconnected premises / consumer may not use electricity from any source till arrear is paid.

5) Detection against Universal A/C Nos.

Legal action against the person having installed direct supply shall be taken and FIR shall be pursued till registration and prosecution. The debit of detection bill will only be allowed / approval of the SE after verification of payment of detection bill. The RO will monitor the payment / IOT and

get adjusted thereafter.

High level committee shall be constituted for checking of old cases and report thereof about genuiness of amount debited and present site and

payment position.

6) Unidentified Cash

Unidentified cash balances are increasing day by day, which directly manifesting the performance of Revenue Officer. Daily work on CP-form-125 followed by CP-form-107 shall be taken for identification of cash and adjustment thereof to correct NC No.

7) Unpaid debts / installments

- Efforts be made for getting payment of receivable in lump sum, however power

delegated under book of financial power be ept in view for allowing installment of very genuine and desiring cases. However Installment to seasonal and regular Industrial and

Commercial consumer under tariff A-2(c) is nor allowed.

MULTAN ELECTRIC POWER COMPANY LIMITED

COMMENTS ON POWER PURCHASE AGREEMENT BETWEEN DISCOS AND CPPA

Definition share in Power Generation Pool: Share of a DISCO in total power generation Pool. calculated in %age terms.

Contract supply Section 2.4 missing.

Section 3.1 (c) Insertion of word damages in last line after liquidated.

Section 5 The power purchaser has a right to ask for any new CDP and power seller have to install.

Section 4.2 (d) Subject to condition that power seller has not violated the share of DISCO from total generation pool..

Section 6.1(f) test in the presence of power purchaser.

Section 6.3 (d) In case of seal broken or tempering of backup metering system, provisions of

section 6.4 (d) shall apply whereas there is no section 6.4 (d).

Section 7.1 (a) Insertion of "regulator determined & CA notified rates". Furthermore M

incurred due to system constraints of power seller will not be included in invoice.

Section 7.1 (d) Subject to force majeure: in scenario of energy short fall i.e. Power Purchaser

in unable to procure energy according to notice in section 4.1 and /or utilize its

allocated share then power purchaser can have the option to get flanked energy from next month.

Section 7.4 The power invoice should stand adjusted to the extent.

i. Receivables from Govt. ii. JoSC on behalf and for CPPA for calculation of net amount due to ('PPA

for payment in the same or following months. iii. Receivable appearing in GST Return.

Section 7.7 Insertion to the extent agreed by DISCO.

Misc Provision12.1 (c): Focal persons for operations.

SR. NG

-

Name of Circle

.

Name of

' Division

•

Name of Sub.

Division

. Name of

Feeders

Name of Grid

Stations

.

Category Peak Load

(A)

Voltage (KV)

Power Fader

Main Cond.

Tra i A .i.) C') - Technical iI

Losses Results On

M fr• i. f' .. ; ----•

. M/S Barqaab

neiGti' •---.-.

. r,,iu,sula":.s,yq, -- i ------ • -----

Connct KVA

HT Length (KM)

Line Losses (KW)

Transfor .

rnahon Losses (KW)

Total Power Loss (KW)

Total Power Loss

o,k,

Gonad KVA

HT Lengt (KM)

Ltioe •-- .. c •• - Z . °S-SI.: • , "(KW) . .._ -

-11-......._,Thalt...i, ' t ''.1.-4.4t -', - • ' .-Z.YVT

LTot___al Power LOSS o''''

I (KW) i

Total „ P

Loss Wo

Multan City Pak Gate Arif Pura

Qasim Bagh

U

.

200 11.0 84.00 OSP

•

• 7710 9.00

-

159.80

.

. 5 7712 9.13

'

" -A 118_013.

C.:. .......--.....

4..; •-• . -49;00 '

i' ---i p:

i 067.00

I !

5.04

2 • Multan City Pak Gate Iqbal Nagar

Vehari Road

U 380 • 11.0 93.00 OSP

•

10385 8.80 328.00 5 - 10386 8.81

'

269 112 381 5.45

I D&I)

3 Multan City Pak Gate Road

Qasim Pur U 400 11.0 92.00 OSP Nishat

9450 12.30 634.70 9 9453 -12.34 510

l '7.,

;

I,C.S)

: (Stand

131-A i (04S) 8.84

•-i.:'-41 qP8.1)

' • 5 tlildt i

4 R.Y.Khan R.Y.Khan

-

)innah

•

)innah R.Y.Khan 1 U

. .

'

360 11.0 94.00 OSP

•

11865

-

31.10

.

.

778.60

.

12 12086 31.08

-

684.00

J

129.00

'

813 12.19

.

5 Multan Mumt/Abad Ghalla Mandi Old

Vehari Road

Qasim Pur R 380 11.0

•

0.85 Dog 14055 105.40 -_

•

" .

1 _

1019.40 17 14047 105.57 929.00 117.00 1046.00 17.07

• •

• $

•

SR.

NO

Name of Circle

Name of

Division

. ....... . Name of

Sub. Division

. Name

of Feeders

Name of Grid

Stations Category -

Peak Load (A)

Voltage (KV)

Power Fader

Main Cond.

I i • i Technica I 1

Losses Results On

M/S Barqaab SnerGEE y USING SLD

Connci KVA

HT Length

(KM)

Line Losses (KW)

Transfor mation

Losses (KW)

Tal Power ot Loss (KW)

Total Power Loss

oh,

Coned KVA

HT Length (KM)

Line Losses (KW)

Tra ns tor malion Losses (KW)

Total Power Loss

(KW)

Total Power Loss %

1 . Multan City Pak Gate A if Pura

r Qam Basigh

U

•

200 11.0 84.00 OSP 7710 9.00 .

159.80 5 7712 9.13 118.00 49.00 -167 00 5.04

2 • Multan City Pak Gate NaIqbal

gar ' RoadVehari

U

•

380 11.0 93.00 OSP 10385 8.80 - 328.00 S 10386 8.81 269 112 381 5.45

3 Multan City Pak Gate Nishat Road

Qasim Pur U 400 11.0 92.00 OSP 9450 12.30 634.70 9 9453 12.34 510 131 641 8.84

4 R.Y.Khan R.Y.Khan )innate )innah R.Y.Khan 1 U 360 11.0 94.00

•

OSP 11865 X1.10 778.60 12 12086 31.08 684.00 129 00. 813 12.19

5 Multan Mumt/Abad Ghalla Mand Old

Vehari Road

Qasim Pur R 380 11.0 0.85 Dog 14055 105.40 1019.40 17 14047 105.57 929.00 117.00 1046.00 17.07

Total Power

Loss

(KW)

;1 1918.00 134.00

A

SR. NO

Name of Circle

Name of

Division

Peak Load

(A)

Voltage (KV)

Power Facter

Main Cond.

Technical Losses Results On

Name of Sub.

Division

Name of

Feeders

Name of Grid

Station's

SynerGEE USING SLD

Category M/S Barqaab

Total Power Loss

Connct . KVA

Total Power Loss

HT Length (KM)

HT Length (KM)

Transfor mation Losses (KW)

Line .

Losses (KW)

Total Power Loss

(KW)

Line

Losses (KW)

Transfor matuan

Losses (KW)

310 89.00 Rabb; Ant' Wdla I Al -Hadnt Anf Wala 1901.80 74.65 17& 00 32 1

11.0 Sa h iwa I Anf Wa

Note

The slight variation in lenoth of feeders in synerGEE model is caused by Transformers 1 lumbers which imoactino veration in-the length between FDRANA & SynerGEE Results

2 The analysis resultS of M/S Barqaab is rounded off to Zero Digit where as SynerGEE analysis considers twodecimal digitis in the results of technical loss.

3 Model in SynerGEE are drawn using sinole line diaoram and having same parameters as in FDRANA. 4 SynerGEE results are based on ware house provided by USAID PDP. 5 The FDRANA results are obtained from the the technical analysis carried out by M/S Bargob

Average % Power Loss

ttA (M.As t

Ada. Manager (P&E)

11.0

(M.Rafiq Bari)

Assisitant Manager (P&E)

Endorcment NO )- ,(4. Dated '3 D JUL 2043

Farwarded to.

—....--:—.>.; C.E /CSD Mepco Ltd. Multan –1. .

With reference to verbal discussion for sample checking of technical losses assessed 2 ' C.E (Development) Mepco Ltd. Multan by M/S Barqaab on FDRANA software with SynerGEE software analysis accordingly please.

i -1g Chief E ' eer Pr I

co Ltd. Multan