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of 146 Petition No. RERC 1077/17, 1078/17, 1076/17

RAJASTHAN ELECTRICITY REGULATORY COMMISSION, JAIPUR

Petition No. RERC 1077/17, 1078/17, 1076/17

In the matter of approval of Aggregate Revenue Requirement and Tariff Petition of Jaipur Vidyut Vitran Nigam Ltd (JVVNL), Ajmer Vidyut Vitran Nigam Ltd (AVVNL) and Jodhpur Vidyut Vitran Nigam Ltd (JdVVNL) for FY 2016-17 and FY 2017-18.

Coram: Shri Vishvanath Hiremath, Chairman Shri R.P.Barwar, Member Shri S.C. Dinkar, Member

Petitioners: Jaipur Vidyut Vitran Nigam Ltd. Jaipur (1077/17) Ajmer Vidyut Vitran Nigam Ltd. Ajmer (1078/17) Jodhpur Vidyut Vitran Nigam Ltd. Jodhpur (1076/17)

Date of hearing: 23.08.2017

Date of Order: 02.11.2017

ORDER

Section-1: Background

1.1 The three distribution companies namely, Jaipur Vidyut Vitran Nigam Ltd. (JVVNL), Ajmer Vidyut Vitran Nigam Ltd. (AVVNL) and Jodhpur Vidyut Vitran Nigam Ltd. (JdVVNL), collectively called Discoms or Petitioners had filed petitions for approval of Aggregate Revenue Requirement (ARR) for FY 2016-17 and FY 2017-18 under section 62 & 64 of Electricity Act, 2003 read with RERC (Terms and Conditions for Determination of Tariff) Regulations, 2014.


1.2 JVVNL & AVVNL filed the petitions on 31.01.2017 and JdVVNL on 30.1.2017 for both FY 2016-17 and FY 2017-18.

1.3 Technical validation meetings of Discoms officers and Commission on the aforesaid

petitions were held on 28.02.2017 and 07.03.2017. 1.4 After examining the petitions, the Commission vide letter dated 08.03.2017 pointed

out the deficiencies observed in the petitions for both FY 2016-17 & FY 2017-18 and the Discoms were directed to clarify along with supporting documents.

1.5 JVVNL, AVVNL & JdVVNL, on dated 27.04.2017, 09.05.2017 & 09.05.2017 respectively,

submitted reply to the deficiencies indicated by the Commission vide its letter dated 08.03.2017 and JVVNL also filed revised information on dated 05.05.2017.

1.6 As per Section 64(2) of the EA, 2003 which requires that applicant should publish

application filed in such abridged form and manner as may be specified by the Appropriate Commission, the Commission on dated 23.05.2017 allowed Discoms to publish the notice in the newspapers.

1.7 Accordingly, public notices with salient features of the petitions, inviting

comments/suggestions, were published in the following newspapers on the dates shown against each of the petitions and were also placed on the websites of the Commission and Discoms. The last date for submission of comments/ suggestions was notified as 03.07.2017 for JVVNL, AVVNL & JdVVNL:

Sr. No. Name of Newspapers JVVNL AVVNL JdVVNL

(i) Rajasthan Patrika 01.06.2017 03.06.2017 31.05.2017 (ii) Dainik Bhaskar 01.06.2017 02.06.2017 31.05.2017 (iii) Times of India 02.06.2017 03.06.2017 - (iv) Rashtradoot 01.06.2017 - - (V) Navjyoti 01.06.2017 - - (vi) Indian Express - - 01.06.2017

1.8 In all, 15 numbers of comments/suggestions were received on JVVNL petitions and 9 numbers on AVVNL and JDVVNL petition from the stakeholders for both FY 2016-17 & FY 2017-18. The list of stakeholders is enclosed at Annexure-A.


1.9 The Commission forwarded the suggestions/comments submitted by the Stakeholders to the respective Discoms for furnishing the reply.

1.10 The public hearing in the matter was held on 23.08.2017. The list of stakeholders who have made oral submissions during the hearing is enclosed at Annexure-B.

1.11 The Commission has carefully considered the petitions filed by Discoms, objection

and suggestion filed by stakeholders thereon, reply given by the Discoms in respect of queries of the Commission & stakeholders and oral submissions made by the Discoms & Stakeholders during the hearing and also perused all the relevant records while finalizing this order.

1.12 As issues arising in all the petitions are common for all three Discoms and the Stakeholders have also made common submissions on all the petitions and a common hearing was held in the matter, the Commission therefore has decided to consider all the petitions together for both FY 2016-17 & FY 2017-18 and dispose them through this common order.

1.13 In this Order Commission has considered ARR for FY 2016-17 and FY 2017-18 of all the Discoms including the various proposals made keeping in view the RERC(Terms and Conditions of Tariff )Regulations, 2014 and norms prescribed therein, the earlier orders of the Commission, orders of the Hon’ble Supreme Court and Appellate Tribunal for Electricity.

1.14 The projections approved in this order for Generation and Transmission are for the purpose of estimating the aggregate revenue requirements of the petitioners. It shall not be construed as formal approval of the Commission for any investment or tariff for transmission or generating plant etc.

1.15 For ready reference, a list of abbreviations used in this order is placed at Annexure –

C of this order. 1.16 All energy figures used in this order, unless stated otherwise, are in Million Units (MU). 1.17 For the purpose of representation, figures given in the tables are shown as rounded

off. However, for calculation purpose, actual figures have been considered.


1.18 This order has been structured in six sections as given under.

a) Section 1 – Background discussed in this part. b) Section2 - Comments/suggestions of Stakeholders, Petitioners’ response and the

Commission’s observations/views thereon. In this section the Commission has considered comments/suggestions made by stakeholders on the General and specific issues related to proposals of ARR determination and tariff of three Discoms.

c) Section 3 - ARR for FY 2016-17 of the three Discoms. d) Section 4 - ARR for FY 2017-18 of the three Discoms.

In section 3 and 4 the Commission has looked into performance of Discoms, Distribution losses, effect of UDAY, various steps taken by Discoms for efficiency improvement and individually dealt various cost parameters viz power purchase cost, O&M, interest cost , depreciation etc. and decided the ARR of FY 2016-17 and FY 2017-18 and also calculated the estimated sales and revenue for various categories of consumers in accordance with RERC(Terms and Conditions for Determination of Tariff) Regulations, 2014.

e) Section 5 – Tariff Proposals and approved Tariff Discoms have not made any proposal for revision in tariff which has been accepted. However, Discoms have made certain rationalization measures in order to facilitate better utilization of resources, economic pricing and better revenue management which have been dealt in the order.

f) Section 6- Way Forward In this section the Commission has considered compliance of its previous order and other action taken by the Discoms under UDAY scheme and has made certain observation and advise for improvement.


Section – 2 Stakeholders comments, Petitioners’ response and the Commission’s views:

Part I – General issues/comments related to Aggregate Revenue Requirement (ARR) of FY 2016-17 & FY 2017-18

2.1. Hindi Version of Petition 2.1.1. Stakeholders’ Suggestions/Comments:

It was submitted that the petitions for ARR for FY 2016-17 and FY 2017-18 should be made available in Hindi.

2.1.2. Petitioners’ Response:

The Discoms submitted that the Hindi version of the ARR petitions has been published on the website and was also available for sale.

2.1.3. Commission’s View:

The Commission has noted the submission of Discoms. 2.2. Filing of petition 2.2.1. Stakeholders’ Suggestions/Comments:

1. It was submitted that as per Regulation 6 of RERC Tariff Regulations, 2014, every

licensee has to file the petition latest by 30th November of each year. Therefore, Discoms should submit the reasons for late filing of the petitions.

2. It was submitted that Discoms must ensure that copy of petitions are made

available at all local offices, so that the petitions reaches to the maximum people. 3. It was submitted that the Discoms should revise the petitions according to the

RVPN tariff order dated 26.05.2017, RWPL tariff order dated 19.06.2017, RVUN tariff order dated 20.06.2017.

4. It was submitted that ARR & Tariff projections related to FY 2016-17 is irrelevant as

the year is already over and its actual data & achievements are available.



1. The Discoms submitted that the Tariff Order for FY 2015-16 was issued by the Commission on 22th September 2016. After the issuance of Tariff Order, the Discoms undertook review of the Order and considered the impact of various decisions and directives given by the Commission. This entire process requires time.

2. The Discoms submitted that the copy of petitions along with annexures were

made available to concerned offices. Further, the summary of the petitions were published in English and Hindi newspapers.

3. The Discoms submitted that while preparing the ARR and Tariff Petition, the figures

available at that point of time with respect to transmission and other charges have been considered. It was further submitted that it would not be feasible to change and revise the same now.

4. The Discoms submitted that although the FY 2016-17 is over, the ARR still needs to

be determined to assess the overall performance while truing up.


The Commission has taken note of the comments of the Stakeholders and reply of Discoms thereto.

2.3. Non Compliance of CEA Safety Regulations 2.3.1. Stakeholders’ Suggestions/Comments:

It was submitted that there were non-compliances of directives issued in previous tariff order and Discoms have also not complied with under mentioned Regulations:

a. The Central Electricity Authority (Measures Relating to Safety and Electric Supply) Regulation 2010

b. The Central (Safety Requirements for Construction, Operation and Maintenance of Electric Plants and Electric Lines) Regulation 2011.



The Discoms submitted that the list of directives issued by the Commission in its previous Tariff Order along with its status of compliance has been clarified in the petitions. Further, they are trying their best to ensure that all the safety related norms and compliances are followed. The field officers and technicians are being imparted with safety related trainings and sessions. It is made sure that all the safety procedures are followed and the safety equipment being used is of superior quality to avoid any mishaps. It was submitted that there is a provision for medical check-up of every employee in services Regulations.


The Commission has taken note of the comments of the Stakeholders and reply of Discoms thereto. It has been noted that Discoms have submitted compliance of the Commission directions along with the petition. Commission reiterates that as per the provisions of Electricity Act, 2003, the petitioners have to strictly implement these Regulations. The Regulations also contemplate overseeing of implementation of these regulations by the Chief Electrical Inspectors/Electrical Inspectors appointed by the State Government and any non-implementation is to be dealt with by these Inspectors. The Chief Electrical Inspector and Electrical Inspectors are the watchdogs of the Safety Regulations and they shall ensure their implementation by periodical checking of any violation of the regulations. The Govt. of Rajasthan should periodically review the working of Electrical Inspectors and take action if need be for non-performance of their duties. Proper implementation of safety regulations will avoid electrical accidents which are occurring in large numbers and would save precious life and limbs of the individual and the livestock. If there is any negligence on the part of the persons in charge of electrical installations. As noted in investment plan order dated 06.09.2017, it is reiterated that if Petitioners need to spend any money for compliance of the Safety Regulations, the same can be claimed through Investment Plan/ARR and the Commission is willing to consider any additional amount spent on training of employees and for compliance of Safety Regulations.


2.4. Recovery of Arrear 2.4.1. Stakeholders’ Suggestions/Comments:

It was submitted that even though notices are being issued, but disconnections are not being made by Discoms officials thereby burdening the consumers with the burden of interest on loans as a result of non-recovery of dues. It was further submitted that the work of recovery from debtors should be outsourced.


Discoms submitted that for effective implementation of disconnections of defaulting consumers, CAO monitors the progress and strict action are being taken against the defaulting officers for failing in effective implementation of Disconnection Notices. For recovery of dues amnesty schemes are launched to encourage the consumers to deposit their dues.


The Commission has taken note of the comments of the Stakeholders and reply of Discoms thereto and has dealt with this issue in section 6 of this order.

2.5. Control Over Theft of Electricity 2.5.1. Stakeholders’ Suggestions/Comments:

1. It was submitted that the Discoms should take proper measures to control the theft

of electricity.

2. It was submitted that proper vigilance should be carried out at Hostels run by private institutions as these have been covered under non domestic category. It was further submitted that the Discoms should serve notice to change category from Domestic to Non-Domestic to such private Hostels and provide special direction to the Vigilance branch or the meter readers to report the non-compliances to A.R.O. for the necessary actions.


1. Discoms submitted that over the recent times it has been stringent and relentless in

its vigilance activities. The special vigilance campaign have been launched


recently considering the theft of electricity. Proper metering have been done on temples situated in public parks, Police stations etc. and instructions have been given and implemented at most of the places. Due to the constant endeavors of the Discoms in the field to curb and control the activities of theft and other misdoings, there is an increase in the number of thefts being caught and reported.

2. The Discoms submitted that under the circular issued in this regard the consumers

were to voluntarily get their category changed according to the changed definition of Hostels adopted as per the Urban Development and Housing Department. Further, regular vigilance is carried out and assessment is being made under section 126 of Electricity Act, 2003.



2.6. Conversion of Flat Rate Consumers To Metered 2.6.1. Stakeholders’ Suggestions/Comments:

It was submitted that JVVNL has failed to convert the flat rate consumer to metered category. Discom may be directed to obtain the voluntary declaration of the connected load from the consumers at the first instance and if on verification the load so declared is found higher than the sanctioned load, their supply should be disconnected. These should be reconnected only through the meters.


The Discom submitted that it has been persistent in its efforts to convert the flat rate consumers to metered category over the past years. This is very much evident from the decreasing number of flat rate consumers of the Discoms over the past years. Also if the flat rate consumer is disconnected due to non-payment of bills, they are reconnected in metered category only.



The Commission has taken note of the comments of the Stakeholders and reply of Discom thereto. Discoms should make all efforts to convert the balance flat rate consumers to metered category.

2.7. Tariff and Revenue Deficit 2.7.1. Stakeholders’ Suggestions/Comments:

1. It was submitted that Discoms need to state the reasons for not proposing any

revision in tariff in spite of revenue deficit and also the manner in which the deficit will be absorbed.

2. It was submitted that Discoms need to clarify measures to be taken under UDAY scheme.


1. The Discoms submitted that they are taking various steps to improve the performance and reduce the revenue deficit. The Commission issued the Tariff Order for FY 2015-16 on 22.09.2016 with tariff hike, therefore, there is no proposal for tariff hike by the Discoms for FY 2016-17 and FY 2017-18 due to recent tariff hike. Further, the Discoms have set loss reduction target and improvement in operational efficiency for generating additional revenue instead of going for anther increase in tariff in a short span of time. With regard to revenue deficit, Discoms submitted that in order to achieve envisaged operational efficiency and bring around improvements, various measures are being taken. These steps include restricting power supply in areas with high AT&C losses, performance monitoring and management system, 100% feeder and DT metering, AMR metering for high value consumers, energy audit & accounting at feeder level, feeder segregation, Mukhyamantri Vidhyut Sudhar Abhiyan, etc. Loss reduction targets have been formulated at the division/circle/zonal level and concerned officials have been made responsible for achieving the loss reduction targets. At the same time, efforts are also being made to reduce theft and other illegal activities by undertaking name and shame campaign and aggressive vigilance drives. Further, the capital investment plans


are also being taken up to achieve the distribution loss trajectory set forth in the UDAY scheme.

2. The Discoms are committed towards achieving the targets and measures as mentioned in the UDAY agreement. The efforts are targeted towards goal of achieving financial turnaround as per the scheme.



2.8. Sales and Revenue 2.8.1. Stakeholders’ Suggestions/Comments:

1. It was submitted that as per Regulation 75(1), Discoms need to provide forecast of

expected sale of electricity for different categories of consumers to each consumption slab within in its area of supply. In this regard Discoms may clarify the other factors which have affected the energy sales projection. It was also submitted that sale from FY 2014-15 to FY 2015-16 for industrial category have been decreasing, Discoms need to clarify the same.

2. It was submitted that in case of JVVNL projected sales in respect of electric traction is NIL for FY 2017-18, JVVNL need to clarify the same. Further, whether transmission and SLDC charges applicable to Railway Traction have been assessed and if so then the amount in respect of each station be furnished.

3. It was submitted that in case of JVVNL, in form 2.1, the sale to Agriculture metered category is shown as 52377.95 MUs in FY 2015-16 whereas the total sales for the year as shown in petition is 17852.21 MUs, JVVNL may clarify the same.

4. Discoms are required to provide the information of sales and revenue for temporary connections in past years and projection for FY 2016-17 and FY 2017-18.

5. It was submitted that the Discoms while assessing the revenue from sale, have not considered other charges like demand surcharge, power factor surcharge, CT/PT charges , miscellaneous charges etc.



1. Discoms submitted that there are various factors which are considered while projecting the sales for ensuing years. The past years sales trend is analyzed and CAGR is applied to arrive at the sales projections. As FY 2016-17 was half over while projecting the sales, the actual sales data for the first few months of FY 2016-17 was also looked upon while projecting sales. Also, in the domestic category additional release of connection under the “power for all” schemes were also considered. The past year sales figures as shown are as per actual. The dip in sales has been observed in some categories and the same have been addressed in the true up petitions of the concerned years. Regarding the sales in Industrial category, an upward trend has been observed during the course of time as is mentioned in the Petition also. The lower sales in FY 2015-16 can be attributed to the consumers opting for open access and other factors. Further, the Discoms submitted that it had filed the ARR and Tariff Petition as per the RERC Tariff Regulations, 2014. All the information required for the determination of ARR has been submitted in the petition, formats and the reply to the data gaps observed by the Commission. The format 2.1 along with the slab wise data duly filed has been resubmitted along with the reply to data gaps.

2. JVVNL submitted that railways has opted for complete open access and would not be a consumer of the Discom from 1st April 2017. Hence there would be sales to the railways in FY 2016-17 but not from FY 2017-18 onwards. The transmission and SLDC charges applicable to Railway Traction forms part of the income of RVPN and not of Discoms.

3. JVVNL submitted that the sales as mentioned in form 2.1 is in Lakh Units, whereas the sales as shown in petition is Million Units.

4. The Discoms submitted that the sales and revenue as shown in the true up petition for FY 2014-15 and FY 2015-16 is inclusive of the sales to temporary connections, the bifurcation of the same in not possible.


5. The Discoms submitted that while projecting revenue for the ensuing years only the revenue from fixed and energy charges are projected based on the expected sales and the existing tariff. Apart from this the Non-Tariff Income, revenue from additional surcharge, cross subsidy surcharge and wheeling charges is also computed and submitted. The miscellaneous charges and income from theft and malpractice are a part of the Non-Tariff Income only which have been duly projected for the upcoming years. Other charges cannot be projected as such and the same can be dealt with at the time True up.


The Commission has taken note of the comments of the Stakeholders and reply of Discoms thereto. The Discoms should provide the information related to temporary connection in next year filing. Commission has dealt with the issue of sale and revenue in ARR section of this order.

2.9. Distribution Losses 2.9.1. Stakeholders’ Suggestions/Comments:

1. It was submitted that Discoms should provide the town wise status of AT&C losses as specified under R-APDRP scheme.

2. It was submitted that the Discoms have not adhered to the distribution loss

reduction trajectory prescribed by the Commission in its order dated 20.02.2015 for the FY 2016-17 and FY 2017-18. Thus, it was requested to work out the energy requirement of the Discoms by adhering to the trajectory fixed by the Commission and also taking the RVPN transmission losses as 3.89% as approved by the Commission for FY 2017-18 vide order dated 26.05.2017 instead of 4.11% submitted by Discoms. Discoms need to clarify the reason for not achieving the losses on lower side in spite of huge capital investment in name of strengthening the distribution system and meeting the growth requirements by the Discoms.

3. It was submitted that JVVNL may provide the steps taken for reduction in losses through the strategy of feeder wise energy audit and the outcome from the same.



1. The Discoms submitted that the information regarding RAPDRP scheme has been provided in the Investment Plan petition and reply to various objections raised on the same. The requisite information for the determination of ARR for FY 2016-17 and FY 2017-18 has been provided in the petition, formats and the reply to the data gaps.

2. Discoms submitted that considering the large distribution area, sparse distribution

of load centers and significant number of agricultural connections, certain time would be required to bring down the loss levels. Disallowing expenses based on the loss trajectory set by the Commission will act as a setback in the Discoms efforts towards achieving operational and financial turnaround by FY 2018-19 thereby leading to negative impact on the consumers at large.

Further, it was submitted that in order to achieve envisaged operational efficiency and bring around improvements, various measures have been taken. These steps include restricting power supply in areas with high AT&C losses, performance monitoring and management system, 100% feeder and DT metering, AMR metering for high value consumers, energy audit & accounting at feeder level, feeder segregation, Mukhyamantri Vidhyut Sudhar Yojana, etc. Loss reduction targets have been prepared at the division/circle/zonal level and concerned officials have been made responsible for achieving the loss reduction targets. Further, it was submitted that efforts were made to reduce theft and other illegal activities by undertaking name and shame campaign and aggressive vigilance drives. Further, the capital investment plans were also going on to achieve the distribution loss trajectory set forth by the Commission.

The Discoms submitted that they are committed towards reduction of losses and

therefore time bound targets have been set for each of the improvement measures. These initiatives have also been recognized at the highest levels and form part of the landmark tripartite MoU signed under the UDAY scheme between the Discoms, the Central Ministry and the Rajasthan Government.

3. JVVNL submitted that various initiatives have been taken up vigorously in order to

reduce the losses and bring it down to the levels as agreed upon in the UDAY scheme. Further, regarding the energy audit JVVNL submitted that they are


carrying out system driven energy audit. Energy audit for all 11kV system started from September’16 and the results have been uploaded on the their website.


The Commission has taken note of the comments of the Stakeholders and reply of Discoms thereto. Further, restricting supply to area of high losses may be useful in short term. However, Discoms should focus on identifying the thefts and reasons for losses so that honest consumers of these area do not suffer on this account. The name & shame campaign should also be used for recovery of arrears. Commission has dealt with the issue of Distribution losses in ARR section of this order.

2.10. Distribution Franchisee

2.10.1. Stakeholders’ Suggestions/Comments: Detail information was sought in respect of distribution franchisee appointed by JVVNL at Kota and Bharatpur, similarly for AVVNL & JDVVNL, if any appointed by them. Further, Stakeholders also sought other operational details relating to functioning of franchisee and sharing of the revenue & expenditure.


JVVNL submitted that CESC has been appointed as distribution franchisee for Kota and Bharatpur. AVVNL has appointed Tata Power for Ajmer City circle and JdVVNL has appointed CESC for Bikaner city circle. They are input based franchisee where the per unit power purchase rate is decided at the franchisee input and the franchisee is to collect the tariff as prescribed by RERC as they are not separate licensees and works under Discoms. ARR is prepared for the Discom as a whole and no separate filing is to be done for the franchisee towns.




2.11. Rajasthan Urja Vikas Nigam Limited (RUVNL) 2.11.1. Stakeholders’ Suggestions/Comments:

Information was sought in respect of formation and function of Rajasthan Urja Vikas Nigam Limited (RUVNL).

2.11.2. Petitioners’ Response: The Discoms submitted that Rajasthan Urja Vikas Nigam Limited (RUVNL) was formed by Government of Rajasthan on 04.12.2015 in order to carry out the power procurement management for the distribution companies. Earlier the power procurement was being carried out by the Rajasthan Discoms Power Procurement Centre (RDPPC) constituted by the State Power Distribution Companies of Rajasthan.



Part II – Issues/comments related to Aggregate Revenue Requirement (ARR) of FY 2016-17 & FY 2017-18

2.12. Power Purchase 2.12.1. Stakeholders’ Suggestions/Comments:

1. It was submitted that the Discom should clarify the source, amount and rate at

which the power purchase have been projected during FY 2016-17 and FY 2017-18.

2. It was submitted that the JVVNL should provide the details of excess power

purchase proposed during FY 2016-17 and FY 2017-18. 3. It was submitted that JdVVNL in FY 2016-17 has purchased 154.20 MUs through

Indian Energy Exchange despite of surplus power in that financial year.


4. It was submitted that the projected power purchase cost for FY 2016-17 & 2017-18 were much higher than that approved in order dated 22.09.2016 which should not be allowed without prudence check.

5. It was submitted that the Discoms should furnish the reasons for selling the surplus

power at an average rate below Rs. 4.00 per unit as approved by the Commission in earlier year and even lower than the rate at which it was sold in FY 2014-15.

6. It was submitted that in form 3.1, for FY 2016-17 and FY 2017-18, the petitioner has

shown the power from “Case-1 PPA”. In this regard Discoms should furnish the name of generating station, its capacity, tariff at which supply would be available and reference of Commission order vide which tariff for this station has been approved.

7. Discoms have shown the availability of power from CTPP unit No.5, which has not yet achieved the COD.

8. Discoms have shown the availability from Satpura whereas the same is dismantled

and sold to Sikkim Ferrow Alloys Ltd. Discoms are required to furnish the reasons for such consideration.

9. JVVNL has shown the average cost of energy purchase from Suratgargh station of

Rs. 16.29 per unit. Discom may state the reason for consideration of such high cost.

10. It was submitted that the Discoms should provide the basis for cost of power purchased from NTPC & NHPC, furnish the copy of the order of CERC, if, any approved by it and PPA executed by Discoms.


1. The details pertaining to power purchase for FY 2016-17 and FY 2017-18 have been

shown in the Form 3.1 of the respective years.

2. JVVNL submitted that they have projected to sell the surplus power at Rs. 2.50 per unit and expect to realise Rs. 515.84 crore and Rs. 970.27 crore during FY 2016-17 and FY 2017-18.


3. JdVVNL submitted that the surplus scenario is arrived at by analyzing the demand and the tied up availability for a particular year. In the state of Rajasthan there is quite high capacity tied up from renewable sources. The reliability of such sources varies depending upon the weather conditions. There are instances when sometimes the peak demand is so high that the power from tied up sources is not sufficient to meet the demand. In such cases the Discom has to resort to short term exchange purchase also. Also there are vice versa cases where due to low demand the Discom sells its power through exchange.

4. The Discoms submitted that the energy availability for FY 2016-17 and FY 2017-18 is projected from existing and new stations. For existing stations, the power purchase quantum has been considered as per the actual energy received in previous years. The Discoms analyzed the existing power scenario and the power purchase has been accordingly projected considering the energy requirement and the merit order principles. The power purchase from stations which were commissioned in FY 2015-16 and were only available for part of the year has been computed based on capacity, PLF and Auxiliary consumption.

5. The Discoms submitted that the rates discovered in the power market are of dynamic nature and it sells surplus power in the power market at the rates prevailing in the market at that specific time. The power market works as per demand-supply scenario. These rates are found to be at a lower side and was even less than the approved rate of Rs 4.00/unit for sale of surplus power through exchange.

6. Discoms submitted that the Case 1 PPA is for procurement of 500 MW power done under Case 1 bidding through M/s PTC India Ltd. (Developer M/s Maruti Clean Coal & Power Ltd. Located at Bandhakhar village in Chattisgarh) for 250 MW at the levelized tariff of Rs. 4.51 and M/s PTC India Ltd. (Developer M/s DB Power Ltd. Located at Baradarha village in Chattisgarh) for 250 MW at the levelized tariff of Rs. 4.81. The Commission had approved the tariff for the same vide its order dated 22.07.2015.

7. The projections for Chhabra unit no. 5 were made on the basis of its expected CoD.

8. In case of the power being procured from Chambal/Satpura as shown in Format 3.1, it is submitted that the power is being procured from the Hydro sources of Chambal. The nomenclature is as per the previous bills received.


9. Discoms submitted that they are expected to be in a power surplus scenario in the upcoming years. Considering the power market scenario and prevailing conditions it would not be economically viable to sell off the surplus power at the rates discovered in the exchange. Thus in order to minimize the financial impact of the same and optimize the power purchase cost, less quantum is proposed to be scheduled from STPS, which would subsequently reduce the variable charges but the fixed charges component is still at the existing level thereby increasing the total per unit cost as reflecting in Format 3.1.

10. Discoms submitted that for projecting power purchase cost certain assumptions have been considered and for Coal, Gas and Hydro based Power Plants, an escalation rate in the range of 2% to 15% is considered over the per unit actual cost of FY 2015-16 for computing the per unit fixed cost for different power plants for FY 2016-17 and FY 2017-18 depending on the power procurement envisaged, plant load factor, availability, etc. Other charges (including cess, electricity duty, etc.) for FY 2016-17 and FY 2017-18 have not been considered while determining the power purchase cost.

2.12.3. Commission’s View: The Commission has taken note of the comments of the Stakeholders and reply of Discoms thereto and has dealt with this issue of power purchase in ARR section of this order.

2.13. Transmission & SLDC Charges

2.13.1. Stakeholders’ Suggestions/Comments: It was submitted that the transmission and SLDC charges should be considered as approved by the Commission vide its Order dated 27.10.2016 and 26.05.2017 for FY 2016-17 and FY 2017-18 respectively. The Discoms may revise their submission accordingly.

2.13.2. Petitioners’ Response: The Discoms submitted that while preparing the ARR and Tariff Petition they have considered the figures available at that point of time with respect to transmission and other charges. Further, it would not be feasible to change and revise the same now.



The Commission has taken note of the comments of the Stakeholders and reply of Discoms thereto and has dealt with this issue in ARR section of this order.

2.14. O&M Expenses 2.14.1. Stakeholders’ Suggestions/Comments:

Discoms must clarify the reason of claiming O&M expenses higher than approved by the Commission in order dated 22.09.2016.


The Discoms submitted that O&M expenses for FY 2016-17 and FY 2017-18 are based on normative calculations as per RERC (Terms and Conditions for Determination of Tariff) Regulations, 2014. The order dated 22.09.2016 was for FY 2015-16 against which the true up petitions have been filed with the Commission justifying the variations in approved and actual O&M expenses.


The Commission has taken note of the comments of the Stakeholders and reply of Discoms thereto and has dealt with this issue in ARR section of this order.

2.15. Terminal Benefit

2.15.1. Stakeholders’ Suggestions/Comments:

It was submitted that as FY 2016-17 has already come to end, terminal benefits should be allowed only to the extent of actual payment made to designated fund during FY 2016-17.


Discoms submitted that terminal benefits expenses as mentioned in the ARR for FY 2016-17 and FY 2017-18 is based on Actuarial valuation report. Regarding the Terminal benefits expenses for FY 2014-15 and FY 2015-16, the details pertaining to


regular and additional contributions have been mentioned in the True up petition filed with the Commission. Similarly the actual contribution made to the trust with respect to the Terminal Benefits in FY 2016-17 can be dealt with at the time of True Up.


The Commission has taken note of the comments of the Stakeholders and reply of Discoms thereto and has dealt with the issue in ARR section of this order.

2.16. Depreciation 2.16.1. Stakeholders’ Suggestions/Comments

It was submitted that while computing depreciation, the Discoms have not provided proper details of the assets which have completed their 12 years of useful life. Thus the Commission may deduct 20% under this head.


The Discom submitted that depreciation for FY 2016-17 and FY 2017-18 has been calculated as per Straight Line Method (SLM) at rates specified in Annexure-1 of the RERC Tariff Regulations, 2014 in accordance with Regulation 22 of the said Regulations. The depreciation has been determined by applying applicable depreciation rates on the average balance of opening and closing Gross Fixed Assets. The detailed computation of Depreciation is shown in format 3.6 submitted along with the petition.


The Commission has taken note of the comments of the Stakeholders and reply of Discoms thereto and has dealt with this issue of depreciation in ARR section of this order.

2.17. Interest and Finance charges 2.17.1. Stakeholders’ Suggestions/Comments

1. It was submitted that the amount equivalent to consumption of electricity of one

year should be deposited by the consumers in advance and Discoms may


provide interest on the same at a rate above the bank rate thereby benefiting both consumers and the Discoms.

2. It was submitted that the Discom need to clarify the amount and rate of interest at

which interest on loan has been computed. 3. It was submitted that interest on loan taken to meet the revenue deficit due to

non receipt of subsidy under section 65 of Electricity Act, 2003 in advance shall not be allowed.

4. It was observed that the Discoms have claimed interest liability on unfunded gap

as per annual account @12.40%. It is further submitted that Discoms need to provide the details of unfunded liability in the form of borrowings, outstanding payments to power suppliers, contractors and terminal benefits etc. It was submitted that unfunded gap needs to be reworked out by Discoms with higher liability taken over by the State Government.

5. It was submitted that the Discoms have estimated an increase of 5% per annum in

finance charges and other borrowing costs over the audited accounts of FY 2015-16 without giving the proper details. Further, it was observed from annual accounts of FY 2015-16 that the other borrowing costs consists mainly of bank charges and guarantee charges which are linked to debt and with debt reduced considerably with UDAY, financing charges should also have been reduced. Thus, the Discoms need to clarify the annual enhancement of 5%.

6. It was submitted that with the taking over of 75% of combined debt of all the

Discoms by State Government under UDAY in FY 2015-16 and FY 2016-17, financial restructuring of Discoms was done and with such financial restructuring, the debt have been progressively reduced so considering opening and closing balance of debt (based on past years) for interest computation would not be appropriate. Thus, debt should have been considered as net fixed assets less equity and if such debt works out to be equal or less than the breakup of residual debt after taking over of 75%, then rate of interest applicable on residual debt, should be the average rate of 9.54% instead of 12.40%.



1. Discoms have submitted that the Commission has already considered the aspect of advance deposit in RERC (Electricity Supply Code and Connected Matters) (Eleventh Amendment) Regulations, 2017.

2. It was submitted that the information of Loan and interest thereon have been

furnished in format 3.7 of the petition.

3. It was submitted that the Discoms have been receiving full Tariff Subsidy from the State Government. In fact the Government had released surplus subsidy during the previous years and there is no gap regarding the same.

4. The Discoms submitted that owing to the widening gap between the approved

unfunded gap and the actual losses, the petitioner had been reeling under severe financial stress. To bridge this ever increasing gap, the Government of India and Government of Rajasthan have taken over 75% of the outstanding loans of the Petitioner as on 30.09.2015 under the tripartite MoU signed with the Government of India and Government of Rajasthan in order to improve the operational and financial efficiency and enable the Petitioner to achieve financial turnaround. It is a part of the Government’s endeavour to help the Discoms to come out of its financial distress. Accordingly, the details of actual accumulated losses of the Discoms along with the amount of losses taken over and the interest computed thereof have been detailed out in the Petition. While calculating the interest on unfunded revenue gap for previous years, the Discoms have reduced the unfunded gap to the extent of excess of actual loan take over after first reducing the unrecognized losses.

5. The Discoms submitted that it is difficult to forecast item wise financing and other

cost for FY 2016-17 and FY 2017-18, therefore, the Discoms have forecasted financing cost taking into account the past trends, expected future financing requirements and the methodology followed during previous years. The other finance charges and cost are again subject to true up and the actual cost can be taken up at that time in case of any variations.

6. The Discoms submitted that under the UDAY scheme 75% of debt was to be taken

over by GoR. The GoR has taken over the 75% debt, the detailed information have


been submitted along with the reply to the data gaps. Further, it was submitted that the takeover have been on the actual losses of the Discoms and not as per the revenue gap approved by the Commission.

Further, with regard to rate of interest, Discoms submitted that, as per Regulation 21 (5) of Regulation 2014:

“The rate of interest shall be the weighted average rate of interest calculated on the basis of the actual loan portfolio at the beginning of each year applicable to the regulated business of the Generating Company or Licensee as the case may be:

Provided that the weighted average interest rate allowed by the Commission for normative loans shall continue to be applicable to the outstanding normative loans:

Provided further that if there is no actual loan for a particular year but normative loan is still outstanding, the last available weighted average rate of interest shall be considered:

Provided further that if the regulated business of the Generating Company or Licensee, as the case may be, does not have actual loan, then the weighted average rate of interest of the Generating Company or Licensee as a whole shall be considered.”

2.17.3. Commission’s View: The Commission has taken note of the comments of the Stakeholders and reply of Discoms thereto and has dealt with this issue in ARR section of this order.

2.18. Delayed Payment Surcharge 2.18.1. Stakeholders’ Suggestions/Comments

It was submitted that there is no question of Delayed Payment Surcharge (DPS) to be receivable from consumers arises as the same has not been considered as non tariff income in the ARR projection. This matter should examined later at the time of True Up.


2.18.2. Petitioners’ Response: The Discoms submitted that Delayed Payment Surcharge (DPS) is levied on the outstanding receivables of the consumers and considered in the books of accounts on accrual basis. Considering the DPS as a part of Non Tariff Income (NTI) does not reflect the actual amount of DPS being realized by the Petitioner. If the accrued DPS is considered to form part of NTI, it is important that the financing cost for corresponding receivables must also be considered. The Petitioner is allowed only 1.5 months receivable in allowance of working capital and for period beyond that period DPS is applicable. Thus the financing cost of such receivables must be allowed. Also the security deposit is deducted from the two months receivable while calculating the working capital interest.

2.18.3. Commission’s View: The Commission has taken note of the comments of the Stakeholders and reply of Discoms thereto and has dealt with this issue in section 3&4 of this order.

2.19. Voltage Rebate 2.19.1. Stakeholders’ Suggestions/Comments

1. It was requested to continue the existing voltage rebate on both energy and fixed

charges instead of only on the energy charges as proposed by the Discoms.

2. It was submitted that in order to avail the incentives of voltage rebate, consumers have to make heavy capital expenditure on transformation capacity, its bay and up-gradation of voltage level supply line, which will result in saving in cost incurred on infrastructure to be provided be Discoms, which is further recovered through fixed charges, therefore the rebate should also be given on fixed charges. It is further submitted that withdrawal of incentive/rebate by Discoms, once heavy capital investment has been made should not be allowed.


The Discoms submitted that voltage rebate is provided to HT consumers based on the voltage at which they are connected in order to incentivize HT consumers to avail connections on a higher voltage level. Although the energy charges are the same for all HT consumers of a category, consumers who have taken a


connection at a higher voltage level are given a rebate in accordance with their voltage level because the T&D losses at higher voltage level are less and hence the benefits of the same can be shared with the consumers. However, the benefits of higher voltages are only in terms of savings in energy alone and there is no impact on fixed charges. Moreover, the maintenance cost for HT lines are higher compared to lower voltage lines. The fixed charges in the tariff do not ensure recovery of fixed cost elements. Thus, the Discoms consider offering voltage rebate on energy charges only.



2.20. Contact Demand 2.20.1. Stakeholders’ Suggestions/Comments

It was submitted that the ceiling limit of the contract demand for H.T. consumers should be increased from 105% to 110% for the day time (06:00-22:00 hrs.).


Discoms submitted that the proposal to increase the existing ceiling limit 105% of the contract demand to 120% during night hours (22:00- 06:00 hours) for deemed energy drawl from Discoms have been made in order to encourage the user to consume power during night hours which would help to ease out the load curve.



2.21. Load Factor Rebate

2.21.1. Stakeholders’ Suggestions/Comments

It was submitted that for Large Industrial Consumers with Contract Demand up to 1 MW, a rebate of about of Rs. 0.25/kWh in energy consumption over the load


factor more than 25% and with Contract Demand more than 1MW, a rebate of about Rs. 0.75/kWh in the energy consumption over the load factor more than 35% should be allowed, which will result in the increase of energy consumption of H.T. Consumers and per unit average realization.


Regarding Load Factor Incentive, Discoms submitted that the same has been proposed so as to minimize the huge and random variations in the consumption pattern, as it tends to disrupt the entire system of the Discoms. The Discoms proposed a rebate of Rs 0.15 per unit on energy charges for consumers maintaining Load Factor of 50% and above during the billing period. The rebate would only be applicable on the energy consumption over a load factor above 50%. Whereas, the incentives as suggested by the stakeholder are on a higher side and would not be feasible for the Discoms.



2.22. Power Factor Improvement Incentive


It was submitted to continue the incentive on power factor improvement of present rate of 1% on full tariff instead of Discoms’ proposal of 0.5% of energy charges for each 0.01(1%) improvement above 0.95 (95%) till 0.97(97%). Further, the proposal of Discoms is to reduce incentive rate for power factor in the range of 0.95 to 0.97 by half of that at present but no financial basis of capital cost of capacitor installation vis-à-vis incentive has been given. It was submitted that the existing incentive of keeping average power factor above .95 (95%) may be continued for a 132 KV EHT consumer, who is owing, operating & maintaining his sub-station at his cost.


2.22.2. Petitioners’ Response: Discoms submitted that Power Factor of system is governed by nature of load. Generally low power factor is caused by the highly inductive load on the system. Due to low power factor actual working component of the power gets reduced leading the system to overloading, Higher Line Losses, Voltage Dips. Economical operation of the system becomes difficult in low power factor scenario as appropriate infrastructure needs to be added to compensate its ill effects. So, it becomes very important that a reasonable value of power factor to be maintained for reliable & economical operation of the system. Hence considering the various ill effects of low power factor it is proposed to modify the structure to ensure that the rebates are commensurate with the benefits accrued to the network. As the benefits do not increase equally for every percentage point improvement in power factor, it is proposed to introduce graded power factor as proposed.

Discoms submitted that as per the provisions of tariff, the power factor is worked out as the ratio of total watt hours to corresponding volt ampere hours. Accordingly, the power factor is worked out and penalty or incentive is provided as per the provisions of Tariff.



2.23. Temporary Supply tariff


1. It was submitted that either the proposal of change of temporary tariff for the corresponding permanent supply plus 50% to 10% be made applicable for construction purpose also or permanent connection may be allowed for construction of building where the duration is more than one year.

2. It was submitted that changes in temporary supply tariff should be applicable to

all and not only for the events of commercial nature. Further, clause 8.5.6 of revised tariff policy notified on 28th January, 2016 provides that “In case of outages


of generator supplying to a consumer on open access, standby arrangements should be provided by the licensee on the payment of tariff for temporary connection to that consumer category as specified by the Appropriate Commission. Provided that such charges shall not be more than 125 percent of the normal tariff of that category.” Therefore, while considering changes in temporary supply tariff provisions of tariff policy, 125% of tariff for corresponding category (instead of 150%) should be considered.


Discoms submitted that at present, in case of temporary tariff, the applicable tariff for corresponding permanent supply plus 50% is being charged. The Petitioner has proposed to revise the same to the corresponding permanent supply tariff plus 10% for a period of two months. The proposed change would be applicable for a group of consumers, trusts and societies holding events and will not be applicable for individual consumers and for construction purposes. The proposed change would only be applicable for fairs, exhibitions and decorative purposes. Post the period of two months the existing clause (permanent tariff plus 50%) will be applicable.



2.24. Jaipur Metro Rail Corporation


1. Jaipur Metro Rail Corporation (JMRC) submitted to allow the Integrated Maximum Demand of sub-stations meant for metro rail operations.

2. JMRC requested Commission to reconsider its decision to completely bill JMRC on

Railway traction tariff (HT large industrial Tariff), as it is not in line with Commission’s own observation and APTEL decision on preferential treatment to metro rail services over railway services.



1. JVVNL submitted that providing this facility means that the Discom has to keep additional spare capacity which would be solely blocked for Jaipur Metro which leads to extra transformer and equipment cost. Additionally, the backup system also has to be maintained to cater to such needs. The same view was also taken up by the Commission in its tariff order dated 22.09.2016 stating that integrated maximum demand facility cannot be allowed to Jaipur Metro as traction and non-traction load has not been segregated.

2. JVVNL submitted that a meeting was held on 13th April 2015 in compliance of

directives of the RERC given with Retail Tariff order dated 20th February 2015 regarding examination of issue of separate metering and billing of traction/non-traction load of Jaipur Metro. In the meeting it was intimated by the Jaipur metro members that it is not feasible to segregate traction and non-traction load by Jaipur Metro for separate metering and billing purposes. After detailed deliberation and discussions, the Committee was of the opinion that a single combined tariff may be considered for metro services. Accordingly, the JVVNL had given the proposal in the Petition that HT Industry Tariff may be applicable to the Metro without the 10% rebate. In case of Jaipur Metro, as discussed in the meeting of JMRC officials and JVVNL officials, such segregation cannot be done. Also, as communicated by JMRC, over 70% of their load is Non-Traction load, therefore such rebate should not be applicable. The same was also agreed upon by the Commission in its order dated 22.09.2016.


The Commission has taken note of the comments of the Stakeholders and reply of Discoms thereto. Commission has already taken a view in the matter vide order dated 22.09.2016.

2.25. Farm House 2.25.1. Stakeholders’ Suggestions/Comments

It was submitted in respect of the Farm House category, which have been incorporated in Domestic Service, Discoms need to clarify that whether the consumer can use the electricity for the purpose of lighting, heating and pumping


of water for swimming pool/agricultural purpose/ fruit garden/road light inside the Farm House and also for marriage purposes.


The Discoms submitted that the tariff is charged as per the respective category under which the connection has been issued.



2.26. Agriculture category 2.26.1. Stakeholders’ Suggestions/Comments

It was submitted that the Discoms may intimate the position in respect of news appeared in Rajasthan Patrika dated 20.06.2017 regarding no disconnection of agricultural consumer for a period of six months for non-payment by consumers and no DPS to be levied for such delay.


The Discoms submitted that as far as news of non-disconnection of agriculture connection for six months is concerned, it is submitted that no such order has been issued.



2.27. Prompt Payment


It was submitted the rebate proposed by Discoms would not attract most of the consumers as they make the bill payment prior to 10 days of due date. Further, it


was also suggested that instead of bi-monthly billing, bills should be raised on monthly basis, which shall improved the cash flow of Discoms.


As per bank rate of 12.40% the 10 days rate would be 0.35%, accordingly the Discoms have proposed the aforesaid rebate.




Section-3: Annual Revenue Requirement

3. Annual Revenue Requirement for FY 2016-17: 3.1 Determination of ARR requires assessment of energy sales as well as cost of

various elements like power purchase cost, O&M expenses, interest cost and depreciation, etc. Projection of the Petitioners with respect to various components of ARR, the Commission’s analysis thereon after consideration of views expressed by the Stakeholders and decision with respect to items given below are discussed in the following paras:

(1) Energy sales

(2) Losses, both transmission and distribution

(3) Power purchase cost, including transmission charges and SLDC

charges

(4) Operation and maintenance expenses

(5) Interest and finance charges and interest on working capital

(6) Depreciation

(7) Revenue from existing tariff

(8) Non-tariff and other income

(9) Revenue deficit based on existing tariff

Energy Sales

3.2 Discoms have worked out the energy sales for FY 2016-17 on the basis of the audited figures of FY 2015-16 as well as actual data for the past years. The consumer category wise sales projected by the three Discoms and the energy sales being approved now by the Commission have been discussed in the following sub-paras.

3.3 The Discoms have projected the energy sales for FY 2016-17 for the following consumer categories:

(1) All consumer categories, except agriculture (2) Agriculture consumers (Metered) (3) Agriculture consumers (Flat Rate)


Petitioners’ Submission

Energy Sales for Metered Categories (except Agriculture)

3.4 T h e Discoms have submitted that they have worked out energy sales for FY 2016-17 on the basis of historical sales data and audited figures of sales for FY 2015-16 using the category wise CAGR as per methodology approved by Commission in the previous year’s tariff order. The energy sales from FY 2008-09 to FY 2015-16 have been used for all categories except for agriculture category.

3.5 For Domestic category, besides the CAGR growth rate, Discoms stated that the increase in sales is largely attributable to increase in consumers in rural areas consequent to intensified efforts under RGGVY scheme, increase in specific consumption of the existing consumers due to improvement in living standards, policy decision release of all pending connections in domestic category and to improve the availability of energy in the rural areas.

3.6 Apart from above, Discoms have also kept in view the joint initiative of the Government of India and Government of Rajasthan to provide 24 X 7 power in the State to all consumers (except agriculture consumers) which ensures uninterrupted supply of quality power to existing consumers by the end of 12th Plan and providing access to electricity to all unconnected consumers in the next five years. Under this initiative, Discoms have envisaged to add approximately six lakh consumers in the State of Rajasthan.

3.7 For Non Domestic category, Discoms stated that there has been rapid growth in sales in last few years which is attributable to increasing urbanisation and increase in commercial activities in the recent past.

3.8 For Industrial consumers, the Discoms stated that there has been a growth in sales in small, medium and large industrial categories in the past, however, due to industrial consumers opting for open access, low growth of industrial sales was witnessed during the previous years.

3.9 With regard to mixed load category, Discoms stated that a decreasing trend has been observed in the previous years which can be attributed to the shift in certain consumer groups.


Energy sales to Agriculture Metered (M) Consumers

3.10 The energy sales for agriculture metered category have been estimated on the basis of the following factors:

a) Existing consumers at the start of the Financial Year b) Addition in the consumers during the Financial Year. c) Consumers converted from ‘Agriculture Flat’ to ‘Agriculture

Metered’ category. d) Connected load per consumer. e) Estimated specific energy consumption.

3.11 T h e connected load per consumer has been forecasted based on the trend observed in previous years and the growth anticipated in connected load per consumer due to the decrease in the water table.

3.12 T h e Discoms submitted that, they have considered the specific consumption of 2030 kWh/kW/year for JVVNL, 1621 kWh/kW/year for AVVNL and 1868 kWh/kW/year for JdVVNL.

3.13 The Discoms have furnished the following information regarding number of metered consumers, connected load and specific consumption in their petition:

Table 1: Agriculture (M) sales for FY 2016-17-JVVNL Particulars Consumers

(Nos.) Connected

Load per consumer

(kW)

Total Connected Load (kW)

Specific consumption

(kWh/kW/year)

Consumption (Sales) MU

Existing consumers 4,26,930 5.82 24,86,516 2030 5,047 Add: New Consumers 15,000 5.82 87,363 2030 177 Add: converted from flat rate 25,000 7.60 1,90,109 2030 386 Total 4,66,930

5,610


Table 2: Agriculture (M) sales for FY 2016-17- AVVNL

Particulars

Consumers

(Nos.)

Connected Load per consumer

(kW)

Total Connected Load

(kW)

Specific consumption (kWh/kW/yea

r)


Existing consumers 370909 6.47 24,00,333 1621 3,891 Add: New Consumers 7,500 6.47 48,536 1621 79 Add: converted from flat rate

10,000 11.52 1,15,194 1621 187 Total

3,88,409 4,156

Table 3: Agriculture (M) sales for FY 2016-17- JdVVNL

Particulars Consumers

(Nos.)


(kW)

Total Connecte

d Load (kW)


(kWh/kW/year)

Consumption

(Sales) MU

Existing consumers 2,63,528 17.28 45,54,665 1,868 8,510 Add: New Consumers 10,000 17.28 1,72,834 1,868 161 Add: converted from flat rate

20,000 17.74 3,54,841 1,868 331 Total

2,93,528 9,003

Energy Sales for Agriculture Flat Rate (FR) Consumers

3.14 For forecasting the connected load per consumer for 2016-17, the connected load of previous years has been considered for JVVNL, AVVNL and JdVVNL.

3.15 For projecting the sales for agriculture (flat) category for FY 2016-17, Discoms have considered the specific consumption of 1945 kWh/kW/year as approved earlier by the Commission.

3.16 Discoms indicated the following details sale to the agriculture Flat Rate category :


Table 4: Agriculture (FR) Sales for FY 2016-17 – JVVNL

Particulars

Consumers

(Nos.)


(kW)



(kWh/kW/year)

Consumption

(Sales) MU

Existing consumers 36,694 7.60 2,79,034 1,945 543 Less: converted to meter 25,000 7.60 1,90,109 1,945 370 Total

11,694 173 Table 5: Agriculture (FR) Sales for FY 2016-17– AVVNL

Particulars

Consumers (Nos.)


(kW)



r)

Consumption

(Sales) MU

Existing consumers 47691 11.52 5,49,374 1,945 1,069 Less: converted to meter 10,000 11.52 1,15,194 1,945 224 Total

37,691 844 Table 6: Agriculture (FR) Sales for FY 2016-17– JdVVNL

Particulars

Consumers

(Nos.)


(kW)



r)

Consumptio

n (Sales) MU

Existing consumers 37,034 17.74 6,57,059 1,945 1,278 Less: converted to meter 20,000 17.74 3,54,841 1,945 345 Total

17,034 933


Total energy sales projected by Discoms:

3.17 The projection of energy sales of different consumer categories discussed in preceding sub-paras is given in the following table:

Table 7: Total Energy Sales for FY 2016-17- Discoms’ Projection (MU) Particulars JVVNL AVVNL JdVVNL Total Domestic 5358 3701 3545 12604 Non-Domestic 2222 1100 1084 4406 Public Street Light 194 84 141 419 Agriculture (Metered) 5610 4156 9003 18769 Agriculture (Flat) 173 844 933 1950 Small Industry 322 285 243 850 Medium Industry 761 796 629 2186 Large Industry 3523 2319 1183 7025 Public Water Works (S) 239 276 265 781 Public Water Works (M) 43 44 108 195 Public Water Works (L) 285 188 483 956 Mixed Load / Bulk Supply 181 109 383 673 Electric Traction 392 392 Total 19304 13902 18000 51205

Commission’s Analysis

Energy Sales for Metered Categories (except Agriculture Flat Rate Category )

3.18 Many of the stakeholder in their written and verbal submission during hearing held on 23.08.2017 stated that since the FY 2016-17 is already ended, therefore it would be proper to take actual sales instead of CAGR approach based on past year data. The Discoms submitted actual sales and purchase data for 12 months from April 2016 till March 2017. The Commission has considered the same. The Commission will consider the actual figures based on audited accounts while carrying out the true up for FY 2016-17.

3.19 Accordingly, the category wise metered sales submitted and considered (except for flat rate agriculture) for FY 2016-17 are as follows:


Table 8: Actual Metered Sales for 12 Months (MUs) (Except Agriculture flat Rate) Particulars JVVNL AVVNL JdVVNL Total Domestic 4803 3389 3270 11462 Non-Domestic 2130 1088 1068 4285 Public Street Light 188 75 101 364 Agriculture (Metered) 5664 4161 8843 18668 Small Industry 315 278 232 825 Medium Industry 727 781 607 2115 Large Industry 3929 2390 1129 7448 Public Water Works (S) 241 283 264 788 Public Water Works (M) 41 70 100 212 Public Water Works (L) 304 201 459 965 Mixed Load / Bulk Supply 209 101 371 681 Electric Traction 226 226

Total 18776 12816 16446 48038


Connected Load per Consumer & Specific Consumption for Flat Rate Consumers.

3.20 The Commission has observed that the Discoms have considered the connected load per consumer of 7.60 KW for JVVNL, 11.52 KW for AVVNL and 17.74 KW for JdVVNL. The Commission has accepted connected load and number of consumers as filed by Discoms.

3.21 Further, the Commission has found that Discoms have filed the specific consumption for flat rate consumers as approved by Commission in the earl ier order which is accepted by the Commission for FY 2016-17.

3.22 It is observed that while computing the sale for flat rate category, JVVNL and AVVNL have considered the sale to converted consumer for the full year, instead of that consumers converted on the average could be taken to be in the metered category for 6 months and flat rate for 6 months. Whereas JdVVNL has considered the converted consumers for six months.

3.23 Accordingly, the connected load, specific consumption and estimated sales for FY 2016-17 have been approved by the Commission.


Table 9: Agriculture (FR) Sales for FY 2016-17 – JVVNL Particulars Consume

rs (Nos.) Connecte

d Load per

consumer (kW)

Total Connecte

d Load (kW)

Specific consumption (kWh/kW/ye

ar)

Consumption (Sales)

MU

Existing consumers 36,694 7.60 2,79,034 1,945 543 Less: converted to meter 25,000 7.60 1,90,109 1,945 185 Total 11,694

358

Table 10: Agriculture (FR) Sales for FY 2016-17 – AVVNL Particulars Consumers

(Nos.) Connected

Load per consumer

(kW)



(kWh/kW/year)


Existing consumers 47691 11.52 5,49,374 1,945 1,069 Less: converted to meter 10,000 11.52 1,15,194 1,945 112 Total 37,691

957

Table 11: Agriculture (FR) Sales for FY 2016-17 – JDVVNL Particulars Consumers

(Nos.) Connected

Load per consumer

(kW)



(kWh/kW/year)


Existing consumers 37,034 17.74 6,57,059 1,945 1,278 Less: converted to meter 20,000 17.74 3,54,841 1,945 345 Total 17,034

933

Energy Sales as approved by the Commission for all categories

3.24 Based on the actual data approach as discussed in the preceding paragraphs and agriculture flat rate sales, as worked out on the basis of connected load and accepted specific consumption, the energy sales for Discoms are being approved as under:


Table 12: Energy Sales approved by the Commission for FY 2016-17(MU) Particulars JVVNL AVVNL JdVVNL Rajasthan

Domestic 4803 3389 3270 11462 Non-Domestic 2130 1088 1068 4285 Public Street Light 188 75 101 364 Agriculture (Metered) 5664 4161 8843 18668 Agriculture (Flat) 358 957 933 2247 Small Industry 315 278 232 825 Medium Industry 727 781 607 2115 Large Industry 3929 2390 1129 7448 Public Water Works (S) 241 283 264 788 Public Water Works (M) 41 70 100 212 Public Water Works (L) 304 201 459 965 Mixed Load / Bulk Supply 209 101 371 681 Electric Traction 226

226

Total 19134 13773 17379 50286

Transmission and Distribution losses

Distribution Losses


3.25 The Discoms have submitted that they are focusing on loss reduction programs initiated in previous years and also increasingly use technology to target erring consumers and reduce the losses during the projection period. The investments being made under schemes like R-APDRP, FIP, SIP etc. are also expected to aid in the reduction of distribution loss especially in urban pockets.

3.26 Further, to achieve operational efficiency and bring around improvements, other steps like loss based load management, performance monitoring and management system, 100% feeder and DT metering, AMR metering for high value consumers, energy audit & accounting at feeder level, feeder segregation, etc. have already been initiated.

3.27 Considering the focus and all round efforts being made to reduce the AT&C losses, the commitments made under the UDAY scheme and the present available details, the distribution losses as proposed by the Discoms are provided in the table below and this includes technical as well as commercial losses other than those relating to collection efficiency:


Table 13: Distribution Losses for FY 2016-17 – Petitioners’ Submission

Particulars FY 2016-17 JVVNL 25.00% AVVNL 22.00% JdVVNL 19.00%


3.28 For FY 2016-17, Discoms have projected distribution losses at higher side as compared to loss trajectory specified by the Commission for which no reasons have been provided.

3.29 It is observed that the Government of India, with an objective to bring in financial discipline and improvement of Discom’s efficiency, has formulated a financial restructuring plan namely “UDAY Scheme” subject to fulfilment of conditions. This scheme while restructuring the finances of the Discoms, has imposed several stringent conditions for improvement in efficiency. The “UDAY Scheme” has been accepted by the State of Rajasthan as well as the Discoms by signing of Memorandum of Understanding.

3.30 Under the UDAY scheme out of the total debt of Rs. 80530 Crore at the end of September , 2015, the GoI shall facilitates the GoR to take over Rs. 40265 crore (50% of the outstanding debt) of the DISCOMs as on 30th September, 2015 in the year 2015-16 and Rs. 20133 crore (25% of the outstanding debt) in the year 2016-17; Important commitments of Discoms as stated under the Scheme are as under. DISCOMs to take the following measures: a) For the 50% of the debt remaining with it as on 31st March,2016, DISCOMs shall fully/ partially issue State Government guaranteed bonds or get them converted by Banks/Fls into loans or bonds with interest not more than the Banks base rate plus 0.1%. DISCOMs shall ensure timely payment of lenders’ dues towards principal/interest for the balance debt remaining with them. b) The DISCOMs shall pay interest to the GoR on the outstanding GoR loan in a financial year at the rate at which GoR issued non-SLR Bonds (if asked for by GoR).


c) DISCOMs shall endeavour to reduce AT&C losses as per the following trajectory:

However, if the target in a particular year is not met, then the DISCOMs shall strive to achieve the targets in the subsequent years so as to achieve the desired target of 15 % AT&C losses by FY 2018-19. DISCOMs shall restrict power supply in areas with high or increasing AT&C losses from 1st April 2016, eliminate the gap between ACS and ARR by FY 2018-19, achieve operational milestones as specified in DDUGJY & IPDS, The DISCOMs shall take the following measures for loss reduction, Undertaking 'name and shame' campaign to control power theft from time to time, Preparing loss reduction targets at division/ circle/ zonal levels and making concerned officers responsible for achieving the loss reduction targets, Implementing performance monitoring and management system (MIS) for tracking the meter replacement, loss reduction and day to day progress for reporting to top management, Achieving 100% Distribution Transformer (DT) metering by June 2018, as per DISCOMs policy, Achieving 100% feeder metering by 30th June2016, Undertaking energy audit up to 11KV level in rural areas by September 2016, Undertaking Feeder Improvement Program for network strengthening and optimization, to be completed by March 2017, Undertaking Physical Feeder Segregation by March 2018 based on availability of funds sanctioned for the purpose under relevant schemes, Installation of AMR for all consumers with consumption above 500 units/month by June 2018 and for other consumers with consumption above 200 units/ month by June 2020, subject to cost benefit analysis, Providing electricity access to 30 lakh unconnected households as per trajectory finalized in the '24x7 Power for All' document by FY 19, Implementing ERP systems for better and effective inventory management personnel management, accounts management, etc. to reduce costs and increase efficiencies by March 2018. The DISCOMs shall undertake various measures for Demand Side Management and Energy Efficiency such as, Providing LED for domestic consumers under DELP Programme through EESL, Undertaking consumer

Discom FY 2015-16 FY 2016-17 2017-18 2018-19 JdVVNL 22.4% 18% 16.5% 15% JVVNL 28% 22% 18.5% 15% AVVNL 24% 20% 17.5% 15%


awareness programmes for optimum utilization of resources and to foster long-term behavioural changes; and Replacing at least 10% of existing agriculture pumps with energy efficient pumps by March 2019. The DISCOMs shall undertake the following tariff measures, Quarterly tariff revision particularly to offset fuel price increase, Timely filing of Tariff Petition before the RERC so that Tariff Order may be issued for the year as early as possible; and Timely preparation of annual accounts of the DISCOMs, which shall also enable timely filing of the Tariff Petition. The MoU also covers the action plan for efficiency improvement.

3.31 The increase in losses should really be a concern for Discoms as it is directly affecting their working and finances. Unless serious efforts are made to bring in the losses to the targeted level, the companies cannot turn around the corner more so the financial crisis which they are facing at present.

3.32 As mentioned above, Government’s have taken over the Debt of Rs. 60857 crore under UDAY, which has impact on ARR of Discoms in the form of reduction in interest cost, the detailed analysis of interest cost has been discussed in forgoing paras under interest cost head. The Discoms in their petition submitted the revised loss target of 25%, 22% & 19% as per in task force meeting for FY 2016-17 for JVVNL, AVVNL and JdVVNL respectively. However, MoU has not been revised accordingly. Further, in UDAY scheme the Government has provided huge financial support as discussed in this order and Discoms and in turn consumers have been benefitted by lower interest burden.

3.33 Looking to the steps being taken by Discoms under UDAY and takeover of interest liability by Government under UDAY and financial restructuring of Discoms the benefit of which has been considered later in this order, the Commission deem it appropriate to align the loss target with the targets given in UDAY MoU. Therefore, in line with AT&C loss targets under UDAY, the Commission has also revised its losses trajectory approved vide its order dated 20.02.2015.

3.34 Thus, the Revised loss target for the remaining control period will be as follows:


Table 14: Distribution Losses Name of Discoms FY 2016-17 2017-18 2018-19

JVVNL 22% 18.50% 15% AVVNL 20% 17.50% 15% JdVVNL 18% 16.50% 15%

Collection Efficiency

3.35 As Discoms have projected 100% collection efficiency for FY 2016-17. The Commission accepts the submission of Discoms as adoption of lower collection efficiency will increase the revenue gap of Discoms which will indirectly burden the consumers of the State.

Transmission Losses

3.36 The Discoms have filed the intra state and inter-state transmission loss of 4.11% and 3.15% respectively.

3.37 Whereas, the Commission has considered the intra state and inter-state transmission loss of 3.89% and 3.15% based on the RVPN Tariff Order dated 26.05.2017 being actual transmission losses achieved during FY 2015-16 and average of weekly losses for the grid filed by the Discoms respectively.

3.38 The levels of transmission losses as proposed by the Discoms and considered by the Commission for FY 2016-17 have been shown in the following table:

Table 15: Levels of Transmission Loss (%)

Particulars Proposed for FY 2016-17

Approved by Commission

for FY 2016-17 Intra-State Transmission Losses-Discoms 4.11% 3.89%

Inter-State Transmission Losses- Discoms 3.15% 3.15%

Energy Requirement as approved vis-à-vis Petitioners’ submission

3.39 On the basis of the sales and distribution & transmission losses discussed above, the energy requirement proposed by Discoms and approved by the Commission for FY 2016-17 is given in the following table:


Table 16: Energy Requirement for FY 2016-17 (MU)

JVVNL AVVNL JdVVNL Total Particulars Propose

d Approve

d Propose

d Approve

d Propose

d Approve

d Propose

d Approve

d Energy Sales to Consumers (MU) 19,304 19,134 13,902 13,773 18,000 17,379 51,205 50,286 Distribution Loss (%) 25.00% 22.00% 22.00% 20.00% 19.00% 18.00% Add: Distribution Loss (MU) 6,435 5,397 3,921 3,443 4,222 3,815 14,578 12,655 Energy Required at Discoms periphery (MUs) 25,738 24,531 17,823 17,216 22,222 21,193 65,782 62,940 Intra-State Transmission Losses (%) 4.11% 3.89% 4.11% 3.89% 4.11% 3.89% Add: Intra-State Transmission Losses (MU) 1192 993 829 697 955 858 2975 2547 Energy Requirement at Transco periphery 26930 25524 18651 17913 23177 22051 68758 65488 Inter-State Transmission Losses (%) 3.15% 3.15% 3.15% 3.15% 3.15% 3.15% Add: Inter-States Transmission Loss 299 296 206 207 235 237 740 741 Gross Energy Requirement (MU) 27229 25820 18857 18120 23412 22288 69497 66229


Power Purchase Cost Petitioners’ Submission

3.40 Discoms have projected energy availability for FY 2016-17 on the basis of estimated generation from existing stations and projected generation from new stations. For existing stations, the Discoms submitted that the power purchase quantum has been considered as per the actual energy received in previous years. The Discoms analyzed the existing power scenario and the power purchase has been accordingly projected considering the energy requirement and the merit order principles. The power purchase from stations which were commissioned in FY 2015-16 and were only available for part of the year has been computed based on capacity, PLF and Auxiliary consumption.

3.41 Discoms have submitted the following assumptions while projecting the power purchase cost for FY 2016-17:

• For Coal, Gas and Hydro based Power Plants, an escalation rate in the range of 2% to15 % is considered over the per unit actual cost for FY 2015-16.

• For Nuclear Power Plants, a nominal escalation rate of 2 % has been considered over average per unit tariff from nuclear sources as per DAE reply to Lok Sabha query dated 09.03.2016.

• The fixed charges and variable charges for the plants which are going to be commissioned in FY 2016-17 have been assumed on the basis of similar types of plant.

• The availability from RFF has been wholly allocated to JVVNL.

• The purchase from renewable energy sources has been projected as per the RPO Obligation approved by the Commission.

3.42 Summary of the power purchase quantum and cost as submitted by Discoms in their petitions are as under:

Table 17: Power Purchase (MU) and Cost (Rs. Cr.) for FY 2016-17 – submitted by Discoms Energy Availability (MUs) and Cost for FY 2016-17- Submission

Stations JVVNL AVVNL JdVVNL Total Units Cost Units Cost Units Cost Units Cost

NTPC 2260 717 1582 502 1808 574 5649 1793


Energy Availability (MUs) and Cost for FY 2016-17- Submission

Stations JVVNL AVVNL JdVVNL Total Units Cost Units Cost Units Cost Units Cost

NHPC 730 244 511 171 584 195 1824 611 RVUN 10195 4210 7137 2947 8156 3368 25489 10525 Rajwest 2559 1057 1791 740 2047 846 6396 2643 GLTPP 78 33 54 23 62 26 194 82 NPCIL 1227 358 859 250 982 286 3068 894 Share projects 1372 48 960 33 1097 38 3429 119 RFF 183 73 - - - - 183 73 TEHRI 96 55 67 39 77 44 241 138 KOTESHWAR 43 17 30 12 35 13 108 41 Tala 19 4 13 3 15 3 48 10 SJVVN and Rampur 286 89 200 62 229 71 715 222 Neyveli lignite 441 163 309 114 353 130 1103 407 Aravali power 3 3 2 2 3 2 8 7 Coastal Gujarat 1004 241 703 169 803 193 2510 603 Adani Power Rajasthan Limited 3297 1180 2308 826 2638 944 8243 2949 Sasan Power Ltd. 1161 193 813 135 929 155 2903 483 Karcham Wangtoo 177 60 124 42 142 48 443 151 NVVN Bundled 891 386 624 270 713 309 2228 966 NCES 2401 1175 1673 819 2106 1030 6180 3024 CPP's 11 2 7 1 8 2 26 5 New Stations (case 1 PPA, CTPP unit 5 and Teesta) 857 343 600 240 686 275 2142 858 Total 29292 10651 20369 7401 23472 8553 73133 26605 Sale of surplus energy 2063 516 1512 378 61 15.13 3636 909

Net power purchase cost 27229 10135 18857 7023 23412 8538 69497 25696


3.43 While estimating energy availability and power purchase cost for FY 2016-17, the Commission has considered the generation from State and Central generating units based on the twelve months actual data submitted by the Discoms as referred to in foregoing paras. Likewise, the position as per latest tariff orders ( order/interim order) has also been considered in working out power purchase cost, as discussed later in the order.


3.44 For estimating the power purchase cost, the Commission has considered availability from various sources for the State as a whole. For working out Discom wise availability and cost, the allocation of power to JVVNL, AVVNL and JdVVNL from all generating stations has been considered in the ratio of 40%, 28% and 32% respectively, except that 100% allocation of RFF share has been considered for JVVNL.

Energy Availability and Cost for FY 2016-17

RVUN Stations

3.45 For RVUN generating stations, including KTPS (Unit 1-7) & STPS(Unit 1-6), DCCPP, RGTPS(Stage I, II& III), Mahi, MMH, Chhabra (Unit 1-4) & Kalisindh(Unit 1&2), the Commission has considered the energy availability as per actual purchase from April 2016 to March 2017.

3.46 The fixed and energy charges for the aforesaid RVUN plants are as per RVUN Tariff order dated 17.10.2016 for FY 2016-17 and applicable regulation.

3.47 Tariff of Mini/Micro (MMH) plants have been considered as per Regulation 58 of RERC Tariff Regulations, 2014.

3.48 The energy availability and cost of RVUN’s generating stations as considered by the Commission have been shown in the table below:

Table 18: Energy Availability (MU) and Cost (Rs. Cr.)- RVUN Stations for FY 2016-17 Station Energy Availability Cost KTPS(1 to 7) 6628 2078 STPS(1 to 6) 4023 1679 DCCPP 95 43 RGTP(1&2) 432 153 RGTP 3 936 432 MAHI 209 49 MMH 9 3 Chabbra – 1&2 3059 1077 Chabbra – 3 1515 597 Chabbra – 4 1559 575 Kalisindh unit 1 3415 1571 Kalisindh unit 2 2116 927 Total 23996 9187


Lignite based projects

3.49 The lignite based projects include Giral Lignite Power Limited, Rajwest Limited and Neyveli Lignite Corporation Limited. For Giral unit 1 & 2, Commission has not considered any generation for FY 2016-17 as the plant has not been functioning for a long period. The availability for Rajwest and Neyveli has been considered as per actual purchase of FY 2016-17.

3.50 The per unit charge for FY 2016-17 for Rajwest have been considered as per the Commission’s Tariff order dated 19.06.2017.

3.51 The fixed and variable charges of Neyveli project has been considered as per actual for FY 2016-17.

3.52 The energy availability and total power purchase cost for Lignite based projects have been summarized in the table below:

Table 19: Energy Availability (MU) and Cost (Rs. Cr.)- Lignite Plants for FY 2016-17

Station Energy Availability Total Cost

Giral –1&2 0 0 Rajwest 5826 2121

Neyveli Lignite Corporation Ltd 1271 506 Total 7097 2627

Nuclear Power Corporation of India Ltd. (NPCIL)

3.53 Total power purchase quantum and power purchase cost for NPCIL have been considered as per actual purchase of FY 2016-17.

3.54 The energy availability and total power purchase cost for NPCIL plants have been summarized in the table below:

Table 20: Energy Availability (MU) and Cost (Rs. Cr.)- NPCIL for FY 2016-17


NPCIL 2791 828


Partnership Projects (PP) and RFF

3.55 Total power purchase quantum and power purchase cost for partnership projects and RFF have been considered as per actual purchase of FY 2016-17.

3.56 Energy availability and total power purchase cost for partnership projects and RFF have been summarized in the table below:

Table 21: Energy Availability (MU) and Cost (Rs. Cr.)- Partnership Projects for FY 2016-17 Station Energy Availability Total Cost

Partnership Projects 2915 103 RFF 122 49

NTPC, NHPC & Others

3.57 The energy availability and charges for NTPC & NHPC plants have been considered as per actual purchase of FY 2016-17.

3.58 The energy availability and charges of Tehri, Koteshwar, Tala, Rampur, SJVNL, Aravali, Adani, Sasan, NVVN, Coastal Gujarat, Karcham Wangtoo and new PPA have been considered as per actual of FY 2016-17.

3.59 The energy availability and total power purchase cost for NTPC, NHPC and other plants have been summarized in the table below:

Table 22: Energy Availability (MU) and Cost (Rs. Cr.)- NTPC & NHPC and Other Generating Stations for FY 2016-17 Plants Energy Availability Total Cost

NTPC Stations 5893 1783 NHPC Stations 1698 616 Rampur+Aravali+ Adani+ Sasan+ SJVVNL+NVVN+coastal Guj.+Wangtoo+other 17171 5714 Tehri Hydro 245 126 Koteshwar 106 41 Tala 49 10 Total 25162 8289

Non-Conventional Energy Sources

3.60 The Commission has taken the availability from non-conventional energy sources to the extent of RPO requirement, i.e., 7.80% for wind, 1.10% for Bio-mass and 2.50% for Solar.


3.61 The availability has been considered as per RPO and the per unit cost has been considered as per actual.

Table 23: Energy Availability (MU) and Cost (Rs. Cr.)- Wind, Solar & Biomass for FY 2016-17

Plants Energy Availability Total Cost Wind farms 5166 2571

Solar 1656 764 Biomass 729 484

Total 7550 3819

Short term Sources

3.62 After considering the energy available to Discoms based on their respective allocated shares, the Commission has estimated a surplus in JVVNL & AVVNL and deficit in JdVVNL in energy availability.

3.63 Discoms have proposed to sell the surplus power at the rate of Rs. 2.50 per unit. In this context, the Commission agrees with the Stakeholders’ concern that the Discoms must try to sell the surplus power at higher rate than the variable charges of thermal generation, for example, STPS variable charges of Rs. 3.32 per unit plus some margin. In light of above fact, the Commission has considered the sale price of surplus power at Rs. 4.00 per unit.

3.64 However, there may have been a situation when Discoms may have resorted to short term power purchase. In that situation, the Regulation 79(6) provides that the Commission shall indicate a tariff for procurement of short term power. Accordingly, the Commission deems it proper to continue with the rate of Rs. 4/unit considered for this purpose in last year tariff order dated 22.09.2016.

3.65 It has also been observed that while the two Discoms are having surplus while the other Discom is having shortage. This is due to allocation of power in certain ratio to respective Discom. The Discoms may take up the matter with Government for suitable amendment in existing allocation ratio as per requirement.

Total Power Purchase Cost

3.66 Based on the above, the summary of source wise and Discom wise breakup of power purchase quantum and cost for 2016-17 as


considered by the Commission for the three Discoms is given in the table below:

Table 24: Energy Availability (MU) and Cost (Rs. Cr.) for FY 2016-17 Stations JVVNL AVVNL JdVVNL Total

Units Cost Units Cost Units Cost Units Cost NTPC 2357 713 1650 499 1886 570 5893 1783 NHPC 679 246 475 172 543 197 1698 616 NPCIL 1116 331 781 232 893 265 2791 828 Tehri+Koteshwar+Tala 160 71 112 49 128 57 400 177 RVUN/ State Generation 11929 4523 8350 3166 9543 3618 29823 11307 Shared Projects 1166 41 816 29 933 33 2915 103 RFF 122 49 - - - - 122 49 NCES 3020 1528 2114 1069 2416 1222 7550 3819 SJVN and Rampur 285 89 199 62 228 71 712 222 New Stations 260 107 182 75 208 85 649 266 Aravali+ Adani+ Sasan+ Neyveli+costal Guj.+Wangtoo 5871 1863 4109 1304 4696 1490 14676 4657 NVVN Bundled 962 430 674 301 770 344 2406 1074 TOTAL 27927 9990 19463 6959 22244 7953 69634 24902 Less/add: Short Term -2107 -843 -1343 -537 44 18 -3405 -1362 Net power Purchase 25820 9147 18120 6422 22288 7971 66229 23540

Transmission Charges

Petitioners ‘Submission

3.67 For estimation of the RVPN transmission charges and SLDC charges for FY 2016-17, the escalation rate in the range of 5%-15% is considered over the actual cost of FY 2015-16. Further, for estimating the PGCIL charges, the Discoms have considered an escalation rate of approx. 5% over the PGCIL transmission charges as payable during FY 2015-16.

3.68 The details of the transmission and SLDC charges submitted by Discoms have been summarized in the table below:

Table 25: Transmission Charges & SLDC Charges for 2016-17 (Rs. Crore)

Particulars JVVNL AVVNL JdVVNL Total PGCIL Charges 548 384 438 1370RVPN Charges 916 642 733 2291SLDC Charges 7 5 6 18 RLDC Charges 1 1 1 4


Particulars JVVNL AVVNL JdVVNL Total Total Transmission Charges 1473 1031 1178 3683


3.69 The Commission has considered the RVPN and SLDC charges for FY 2016-17 as per the RVPN tariff order dated 27.10.2016 for FY 2016-17.

3.70 The Commission has considered the other transmission, PGCIL and RLDC charges as proposed by Discoms for FY 2016-17.

3.71 The transmission & SLDC charges accordingly approved by the Commission for FY 2016-17 are as under:

Table 26: Transmission Charges approved by the Commission for FY 2016-17 (Rs. Crore) Particulars JVVNL AVVNL JdVVNL Total PGCIL Charges 548 384 438 1370 RVPN and Other Charges 954 668 763 2386 RLDC Charges 1 1 1 4 SLDC Charges 4 3 3 9 Total Transmission Charges 1508 1055 1206 3769

Operation and maintenance Expenses


3.72 Discoms have estimated O&M expenses based on the O&M norms specified in RERC Tariff Regulations, 2014.

3.73 the O&M expenses projected by Discoms for FY 2016-17 have been summarized below:

Table 27: Operation and Maintenance Expenses for FY 2016-17 (Rs. Crore)

Particulars JVVNL AVVNL JdVVNL Total Employee Costs 822 592 766 2180Administrative & General Costs 87 62 74 223Repairs & Maintenance Costs 173 125 149 446

Total O&M Costs 1081 779 989 2849Less: Expenses to be Capitalized 285 15 146 445

Net O&M Costs charged to revenue 797 764 844 2404



3.74 Commission has allowed O&M expenses in accordance with Regulation 83 of RERC Tariff Regulations, 2014.

3.75 The per unit norms for each component for first year of the control period FY 2014-15 are as follows:

• Employee expenses-Rs. 0.38/per unit of sale • A&G expenses-Rs. 0.04/ per unit of sale • R&M Expenses –Rs. 0.08/ per unit of sale

3.76 As per regulation 24(3), the Commission has escalated the O&M expenses at the rate of 5.85% per annum for FY 2016-17.

3.77 Commission has considered the sales allowed for FY 2016-17 for projecting normative O&M expenses. Capitalized O&M expenses have been considered in the same ratio as projected by Discoms.

3.78 O&M expenses approved by the Commission for Discoms for FY 2016-17 have been summarized below:

Table 28: Operation and Maintenance Expenses approved for FY 2016-17 (Rs. Crore) Particulars JVVNL AVVNL JdVVNL Total Employee Costs 815 586 740 2141 Administrative & General Costs 86 62 78 225 Repairs & Maintenance Costs 172 123 156 451 Total O&M Costs 1072 772 974 2817 Expenses to be Capitalized 282 15 143 440 Net O&M Costs charged to revenue 790 757 830 2377

Terminal Benefit Expenses


3.79 The Discoms have considered the terminal benefits for FY 2016-17 as per the liability assessed in the actuarial valuation for the FY 2015-16.

3.80 The terminal benefit liability submitted by the Discoms for FY 2016-17 has been tabulated below:

Table 29: Terminal Benefit Expenses for FY 2016-17 (Rs. crore) Particulars JVVNL AVVNL JdVVNL Total

Terminal Benefit Expenses 700 569 298 1567



3.81 The Commission has considered terminal benefit expenses for FY 2016-17 as submitted by Discoms. However, the Commission shall allow the payment made towards actuarial valuation liability in the true up of FY 2016-17 only to the extent of funds actually transferred to the designated Fund.

Capitalization


3.82 The capital investment and capitalization proposed by Discoms are shown in the table below:

Table 30: Capital Expenditure and Capitalization proposed for FY 2016-17 (Rs. crores)

Particulars JVVNL AVVNL JdVVNL Capital Expenditure 1807 1244 1345

Capitalization 2355 2333 1999*

*Before assets not in use as given in format 3.6 of the petition


3.83 Following the methodology adopted in 22.09.2016 order for FY 2015-16, the Commission has considered 80% of the proposed capitalization in this ARR order as under.

Table 31: Projected Capitalization approved by the Commission for FY 2016-17 (Rs. Crore)

Particulars JVVNL AVVNL JdVVNL

Capitalization 1884 1866 1599

Interest on Loans and Finance Charges & Lease rental


3.84 To compute the interest on loan, Discoms have considered opening normative loan as on 1st April 2016 equivalent to closing balance of long term loans for FY 2015-16 as per audited accounts for the year. Further, capitalisation during the year after deducting consumer contribution, normative equity @30% of the remaining capitalisation and the balance amount has been considered as addition to long term


loans during the year. The loan repayment has been considered in accordance with Regulation 21 of the RERC Tariff Regulations, 2014 which caps deemed repayments to the extent of depreciation charged for the year. The closing normative loan is considered after aforesaid addition to loan and deducting normative repayment for FY 2016-17.

3.85 The interest on long term loans is estimated on the basis of actual weighted average interest rate for long term loans and applied on the average of normative loans (average of opening and closing normative loan).

3.86 The Discoms have projected interest on security deposit on the basis of average of actual security deposit per consumer in the previous two years as per audited accounts of FY 2014-15 and 2015-16 and the projected growth in number of consumers. The interest rate has been considered as per the applicable RBI bank rate as on 1st April, 2016 i.e. 7.75% in accordance with the RERC Supply Code.

3.87 Discoms have projected the finance charges and other borrowing cost to be increased by 5% per annum from audited accounts for FY2015-16.

3.88 The Unfunded Gap and interest thereon upto FY 2015-16 has been separately shown by the Discoms as under: a) Discoms submitted the following factual position of loan taken over

under UDAY Scheme. S. No. Description JVVNL AVVNL JDVVNL Total

A Accumulated Losses as on 31.03.2016 as per balance sheet 32,294 30,348 30,010 92,652

B Losses owned by GoR 2,867 2,701 2,947

C Subsidy received against losses owned by GoR 978 834 906

D Actual Accumulated Losses as on 31.03.2016 (A + B - C) 34,183 32,215 32,051 98,449

E Loans taken over under UDAY 20,998 20,569 19,290 60,857 F Difference (D - E) 13,185 11,646 12,761 37,592

G Unfunded gap approved by the Commission 15,392 15,918 16,536 47,846

Unfunded gap considered for computation of interest liability (Min of F,G) 13,185 11,646 12,761 37,592


b) From the above table, it is observed that the Government’s have

actually taken over loan of Rs. 60857 crore. Further, for the purpose of computing the interest on unfunded gap upto 2015-16, Discoms have considered the lower of following: i. Accumulated Gap after UDAY of Rs. 37592 crore and

ii. Unfunded gap approved by the Commission of Rs. 47846 crore.

3.89 Accordingly, the interest charges and finance charges for FY 2016-17 have been summarized in the table below:

Table 32: Interest and Financing Charges for FY 2016-17 (Rs. Crore)

Descriptions JVVNL AVVNL JdVVNL Total Opening balance of LTL 4558 4070 4389 13017Capitalization 2355 2333 1999 6686Capital expenditure financed by Equity 634 578 420 1632Capital expenditure financed by Consumer Contribution and grants 241 406 598 1245

Receipt of LTL for Capital expenditure 1480 1349 980 3809Principal Repayment 773 510 522 1805Closing balance of LTL 5265 4908 4848 15021Average LTL 4911 4489 4618 14019Average Interest rate of LTL (%) 12.40% 12.91% 13.03% Interest Charges on LTL 609 580 602 1790Interest on Security Deposit 83 58 51 191Finance Charges & Lease Rental 98 96 294 488Gross Interest Charges 790 733 947 2470Interest Expenses Capitalized 145 93 32 270Total Interest & Financing Charges 645 640 915 2200unfunded Gap up to FY 16 13185 11646 12761 37592Average ROI 12.40% 12.91% 13.03% Interest liability on unfunded gap 1635 1504 1663 4801Total Interest & Financing Charges 2280 2144 2578 7001


3.90 The interest and finance charges have been calculated by the Commission considering the following:


a) The closing balance of long-term loans for FY 2015-16 allowed in the true-up order of FY 2015-16, has been considered by the Commission as the opening balance of FY 2016-17.

b) For capitalization for FY 2016-17 only 80% capitalization has been considered by the Commission, the equity, consumer contribution and grants have also been considered on proportionate basis.

c) The long-term loans required for capitalization during the FY 2016-17 have been reduced by the amount of consumer contribution, capital grants and equity received during the year.

d) Repayment for FY 2016-17 has been considered equal to the depreciation allowed by the Commission for FY 2016-17.

e) With regard to Unfunded Gap, it is observed that the Discoms have signed the MoU under “UDAY” scheme, wherein the Government’s have taken over the accumulated debt of Rs 60857 crore subject to achievement of certain conditions as discussed in foregoing paras of distribution losses, the Commission has considered the unfunded gap for FY 2016-17 as under:

i). The Discoms have submitted the total accumulated losses of Rs. 98449 crore as on 31.03.2016.

ii). As the above losses have been met through loan, the government have taken over outstanding loan of Rs. 60857 crore.

iii). After, taking over of loan of Rs. 60857 crore, the Discoms have been left with accumulated gap of Rs. 37592 crore. This gap is lesser than the Commission approved unfunded gap of Rs. 51867crore as on 31.03.2016, thus for computing the carrying cost, Commission has considered the lower of the two gaps i.e. Rs. 37592 Core

f) The weighted average interest rate has been considered at 10.12%, 11.39% and 9.11% respectively as per regulation 21(5) of RERC tariff Regulations, 2014.

g) Finance charges have been allowed as sought by the three


Discoms i.e. escalation of 5% over the finance charges of FY 2015-16, whereas in case of JdVVNL, the finance charges for FY 2015-16 was inclusive of delayed payment surcharge to power producers, thus the same has been removed first and escalation has been considered thereafter.

h) Interest on Security deposit has been considered as submitted by Discoms.

3.91 Based on the above, the approved interest and finance charges (with respect to the assets capitalized) approved for FY 2016-17 for the three Discoms have been summarized in the tables below:

Table 33: Interest and Finance Charges approved by the Commission for FY 2016-17 (Rs. Crore)

Particular JVVNL AVVN

L JdVVN

L Total Opening balance of LTL (A) 5435 2896 2914 11246 Capitalization (B) 1884 1866 1599 5349 Capital expenditure financed by Equity (C) 507 462 336 1306 Capital expenditure financed by Consumer Contribution and grants (D) 193 325 479 996 Receipt of LTL for Capital expenditure E=(B-C-D) 1184 1079 784 3047 Principal Repayment(F) 622 397 379 1399 Closing balance of LTL, G=(A+E-F) 5997 3578 3319 12894 Average LTL, H=(A+G)/2 5716 3237 3117 12070 Average Interest rate of LTL (%)(I)

10.12% 11.39

% 9.11% Interest Charges on LTL, J=(HXI) 578 369 284 1231 Interest on Security Deposit (K) 83 58 51 191 Finance Charges & Lease Rental (L) 98 96 93 287 Gross Interest Charges, M=(J+K+L) 759 522 428 1710 Interest Expenses Capitalized (N) 139 66 14 220 Total Interest & Financing Charges (O) 620 456 414 1490 Unfunded Gap upto FY 2015-16 (P) 13185 11646 12761 37592 Interest on Carry Forward Revenue Gap, Q=(PXI) 1334 1326 1163 3823 Total Interest & Financing Charges after interest on carry forward Gap (O+Q) 1954 1783 1576 5313


Interest on Working Capital


3.92 Discoms estimated their working capital requirement for FY 2016-17 as per Regulation 27 of the RERC Tariff Regulations, 2014 and the same has been tabulated below:

Table 34: Interest on Working Capital for FY 2016-17 (Rs. Crore)

Descriptions JVVNL AVVNL JdVVNL Total O&M expenses (as per norms) 66 64 70 200Maintenance Spare (as per norms) 120 115 171 405Receivables (as per norms) 2047 1493 1711 5252Less: Security deposit of Consumers 1068 744 655 2468Total Working Capital 1165 927 1298 3390Interest Rate (%) 11.80% 11.80% 11.80% Interest on Working Capital 137 109 153 400

3.93 The Petitioner has further submitted that it has considered the latest base rate of State Bank of India of FY 2016-17 plus 250 basis points.


3.94 The normative working capital requirement along with interest thereon has been calculated as per regulation 27 of RERC Tariff Regulations, 2014, by the Commission as under:

a) Operation and Maintenance expenses for one month; plus

b) Maintenance spares @15% of O&M expenses as per Regulation 83 of the RERC Tariff Regulations 2014; plus

c) Receivables equivalent to one and a half-months billing of

consumers; Less

d) The security deposits as submitted by the Discoms have been considered;

e) For the purpose of calculating interest on working capital,


the Commission has considered weighted average SBI base rate prevalent during first six months of the previous year plus 250 basis points as per RERC Tariff Regulations, 2014. The rate of interest thus works out to 12.26%

3.95 Accordingly, the interest on working capital considered by the Commission is as under:

Table 35: Interest on Working Capital approved by the Commission for FY 2016-17 (Rs. Crore) Particulars JVVNL AVVNL JdVVNL Total

O&M expenses (as per norms) 66 63 69 198 Maintenance Spare (as per norms) 118 114 125 357 Receivables (as per norms) 1800 1312 1494 4605 Less: Security deposit of Consumers 1068 744 655 2468 Total Working Capital 916 744 1032 2692 Interest Rate (%) 12.26% 12.26% 12.26% Interest on Working Capital 112 91 127 330

Depreciation


3.96 The Discoms have submitted that for computation of depreciation they have considered the specified rates as provided in the RERC Tariff Regulations, 2014 in Appendix-I based on Straight Line Method (SLM)

3.97 The submission of the three Discoms with respect to depreciation has been tabulated below:

Table 36: Depreciation for FY 2016-17 (Rs. crore) Particulars JVVNL AVVNL JdVVNL Total

Depreciation 773 510 522 1805


3.98 Commission has considered depreciation based on the following consideration:

• The closing balance of depreciable assets for FY 2015-16 allowed in the True-up order for FY 2015-16 has been


considered by the Commission as the opening balance for FY 2016-17.

• Capitalization, consumer contribution and grants for FY 2016-17 has been considered as discussed earlier.

• Depreciable assets for FY 2016-17 have been reduced by the amount of consumer contribution and capital grants projected for the year.

• Average depreciation rate has been considered as per true up order for FY 2015-16.

3.99 Deprecation allowed by the Commission for each of the three Discoms has been tabulated below:

Table 37: Depreciation allowed by the Commission for FY 2016-17 (Rs. Crore) Particulars JVVNL AVVNL JdVVNL Total

Depreciable Assets at the beginning of the Year (A) 11753 7833 7692 27278 Capitalization during the year (B) 1884 1866 1599 5349 Consumer Contribution and Capital Grants during the year (C) 193 325 479 996 Depreciable Assets added during the Year D=(B-C) 1691 1541 1120 4353 Depreciable Assets at the end of the Year (E= (A+D)) 13445 9374 8812 31631 Average Depreciable Assets during the Year (F=(A+E)/2) 12599 8603 8252 29454 Average Depreciation Rate (G) 4.94% 4.61% 4.60% Depreciation (FXG) 622 397 379 1399

Insurance Expenses


3.100 Dis coms have estimated the Insurance expenses for FY 2016-17 on the basis of net fixed assets subject to the ceiling specified in Regulation 25 of the RERC Tariff Regulations, 2014.

Table 38: Insurance Expenses- Discoms submission for FY 2016-17 (Rs. in Crore)

Particulars JVVNL AVVNL JdVVNL Total Insurance charges 23 16 17 56



3.101 Commiss ion has allowed Insurance expenses in accordance with Regulation 25 of RERC Tariff Regulations, 2014.

3.102 To com pute the insurance expenses on average Net Fixed Assets (NFA) as per aforesaid regulation, the Commission has considered the following:

a)The closing Net Fixed Assets as per Audited Accounts for FY 2015-16 is considered as opening balance as 1.04.2016.

b)The additional capitalization as discussed in above para’s have been added and depreciation during the year has been deducted from the above opening balance to arrive at closing balance.

3.103 Accord ingl y, the following insurance expenses have been computed on the average NFA.

Table 39: Insurance Expenses Approved for FY 2016-17 (Rs. in Crore)

Particulars JVVNL AVVNL JdVVNL Total

Insurance charges 23 15 16 55 Return on Equity


3.104 Discoms have not claimed return on equity for FY 2016-17.

Commission’s Observation

3.105 As Discoms have not sought Return on Equity, the Commission has also not considered Return on Equity.

Interest on Delayed Payment Surcharge


3.106 Discoms in their petition for FY 2016-17 have claimed the interest on principle amount of Delayed Payment Surcharge (DPS) stating that the consideration of DPS from books of accounts adversely affects the


revenue gap of the Discoms. If the accrued DPS is considered to form part of Non Tariff Income, the financing cost for corresponding receivables must also be considered.


3.107 This matter of interest on DPS can be examined based on actual and audited data, as ARR petitions for FY 2016-17 are based on projections and un-audited data, therefore, the Commission is not inclined to examine this matter in the current petition and direct the Discoms to take up this matter while filing the petition for true-up for FY 2016-17 wherein Discoms should furnish detailed calculations corroborating their claim based on actual/audited data.

Non-Tariff Income and Wheeling Charges


3.108 Discoms have projected Non-Tariff Income for FY 2016-17 using the escalation of 5% per annum on the figures of FY 2015-16. No increase has been considered for projecting income from wheeling and reactive energy charges for FY 2016-17. Further, income from cross subsidy surcharge and additional surcharge have also been projected for FY 2016-17 based on the rates approved by the Commission and the projections made for energy drawl through open access as given below:

Table 40: Non-Tariff Income for FY 2016-17 (Rs. Crore) Particulars JVVNL AVVNL JdVVNL Total

Non-Tariff Income 317 247 386 950 Income from Wheeling Charges, Cross Subsidy Surcharge and Additional Surcharge 142 349 68 559 Total 459 596 454 1509


3.109 The Commission has considered the non-tariff income and wheeling charges for FY 2016-17 as projected by Discoms.


Aggregate Revenue Requirement


3.110 The Annual Revenue Requirement for FY 2016-17 proposed by the three Discoms has been given in the table below:

Table 41: Summary of ARR for FY 2016-17 – Discoms’ submission (Rs. Crore) Sr. No. Particulars JVVNL AVVNL JdVVNL Total

Submission FY 2016-17 1 Power Purchase Cost* 10135 7023 8538 25696 2 Transmission Charges 0 0 0 0 PGCIL 548 384 438 1370 RVPN 916 642 733 2291 SLDC and RLDC 9 6 7 21 3 Operation & Maintenance Expenses 797 764 844 2404 4 Terminal Benefit 700 569 298 1567 5 Interest and Finance Charges 645 640 915 2200 6 Interest on unfunded gap 1635 1504 1663 4801 6 Interest on working Capital 137 109 153 400 7 Depreciation 773 510 522 1805 8 Insurance charges 23 16 17 56 9 Aggregate Revenue Requirement 16319 12166 14129 42614 10 Less: Non-Tariff Income 317 247 386 950 11 Less: Cross Subsidy and Additional Surcharge 142 349 68 559 12 Net Aggregate Revenue Requirement 15860 11570 13675 41105

*

*Power purchase cost has been considered after adjustment of sale of surplus power

Commission’s Approval

3.111 Commission has approved the ARR for FY 2016-17 based on the items of expenditure discussed in the preceding sections and the same has been summarized in the table below:

Table 42: Summary of ARR for all the three Discoms for FY 2016-17 – Approved by Commission (Rs. Crore) Sr. No. Particulars JVVNL AVVNL JdVVNL Total

Approved FY 2016-17 1 Power Purchase Cost* 9147 6422 7971 23540 2 Transmission Charges PGCIL 548 384 438 1370 RVPN 954 668 763 2386 SLDC and RLDC 5 4 4 13 3 Operation & Maintenance Expenses 790 757 830 2377 4 Terminal Benefit 700 569 298 1567 5 Interest and Finance Charges 620 456 414 1490 6 Interest on unfunded gap 1334 1326 1163 3823


Sr. No. Particulars JVVNL AVVNL JdVVNL Total 7 Interest on working Capital 112 91 127 330 8 Depreciation 622 397 379 1399 9 Insurance charges 23 15 16 55

10 Aggregate Revenue Requirement 14857 11089 12404 38349 11 Less: Non-Tariff Income 317 247 386 950 12 Less: Cross Subsidy and Additional Surcharge 142 349 68 559 13 Net Aggregate Revenue Requirement 14398 10493 11950 36841


Revenue and Revenue Deficit based on Existing Tariff Revenue on Existing Tariff Petitioners’ Submission

3.112 Discoms have projected the revenue based on energy sales forecasts for the period and the applicable retail tariff as per the RERC’s Tariff Order for FY 2015-16 dated 22nd September 2016

3.113 The revenue in FY 2016-17 from existing tariff as per Discoms’ submission is as under:

Table 43: Revenue from existing tariff for FY 2016-17– Discoms’ submission (Rs. Crore) Particulars JVVNL AVVNL JdVVNL Total

Domestic Service 3508 2434 2319 8261

Non-Domestic Service 1993 983 941 3917Public Street Light 129 55 91 274Agriculture Metered Supply 2747 2045 4284 9077Agriculture Flat Rate Supply 93 445 307 845Small Industrial Service 222 207 171 600Medium Industrial Service 576 621 496 1693Large Industrial Service 2731 1934 1087 5752P.W.W. & S. Pumping –Small 152 179 165 496P.W.W. & S. Pumping –Medium 31 32 78 141P.W.W. & S. Pumping –Large 207 142 376 725Mixed Load / Bulk Supply 133 87 271 491Electric Traction 291 0 0 291Total 12812 9164 10586 32561

Interest subvention, Electricity Duty and Subsidy

3.114 Discoms have shown Differential Interest Subvention on World Bank Loan, Subvention from State Govt against electricity duty, Subsidy


against compounding charges for FY 2016-17 as under:

Table 44: Interest subvention, electricity duty and subsidy for FY 2016-17 (Rs. Crore)

Particular

JVVNL AVVNL JdVVNL Total Submission FY 2016-17

Differential Interest Subvention on World Bank Loan 4 3 3 10 Subvention from State Govt. against ED 564 376 362 1302 Subsidy against compounding charges 15 6 10 31 Total Subsidy Amount 583 385 375 1343

Revenue Deficit

3.115 The revenue deficits submitted by Discoms for FY 2016-17 at the existing tariff have been provided in the table below:-

Table 45: Revenue Deficit/Surplus at existing tariff for FY 2016-17 (Rs. Crore) Particulars JVVNL AVVNL JdVVNL Total

Submission FY 2016-17

Net Aggregate Revenue Requirement (A) 15,860 11,570 13,675 41,105 Revenue from Existing tariff (B) 12,812 9,164 10,586 32,561 Total of interest on subvention, ED and Subsidy (C) 583 385 375 1,343 Deficit including Carrying cost D= (A-B-C) 2,465 2,021 2,714 7,200 Carrying cost on revenue deficit as per SBI base rate during the first half (E) 153 130 177 460 Gap after last year Losses claimed By Discoms (D+E) 2,618 2,151 2,891 7660

Commission’s Analysis:

3.116 Commission has calculated the revenue from existing tariff on the basis of consumer category wise energy sales approved by the Commission in this order for FY 2016-17, retail tariff notified for the first 5 months of FY 2016-17 as per tariff order dated 20.02.2015 and remaining 7 months as per tariff order dated 22.09.2016. The estimated revenue at existing tariff for different consumer categories for all the three Discoms for FY 2016-17 has been summarized in the table below:

Table 46: Revenue from Existing Tariff for FY 2016-17- Approved by the Commission (Rs. Crore)

Particular

JVVNL AVVNL JdVVNL Total Approved FY 2016-17

Domestic Service 3178 2265 2177 7,620 Non-Domestic Service 1935 982 939 3,856 Public Street Light 134 56 72 261 Agriculture Metered Supply 2773 2047 4245 9,066


Particular


Agriculture Flat Rate Supply 192 505 491 1,188 Small Industrial Service 218 203 165 586 Medium Industrial Service 553 611 481 1,646 Large Industrial Service 2972 1936 1010 5,918 P.W.W. & S. Pumping –Small 153 183 164 500 P.W.W. & S. Pumping –Medium 30 49 73 151 P.W.W. & S. Pumping –Large 219 150 353 722 Mixed Load / Bulk Supply 152 78 260 489 Electric Traction 157 157

Total 12,664 9,064 10,430 32,159

ARR and Revenue

3.117 Considering the ARR and Revenue at existing tariff as determined by the Commission and subsidy & subvention as shown by Discoms in their petition, the revenue gap for all the three Discoms for FY 2016-17 at the existing tariff has been worked out. The Commission has carried out the true up of RVUN for FY 2013-14, FY 2014-15 and FY 2015-16 wherein certain amount has been considered as payable by Discoms, the same has also been considered while working out the gap for FY 2016-17.

Table 47: Revenue Deficit/Surplus at existing tariff for FY 2016-17 – Approved by the Commission (Rs. Crore)

Particulars JVVNL AVVNL JdVVNL Total Approved FY 2016-17

Net Aggregate Revenue Requirement (A) 14,398 10,493 11,950 36,841 Revenue from Existing tariff (B) 12,664 9,064 10,430 32,159 Total of interest on subvention, ED and Subsidy (C) 583 385 375 1,343 Deficit including Carrying cost D= (A-B-C) 1,150 1,043 1,145 3,338 Add: RVUN True For FY 2013-14, FY 2014-15 and FY 2015-16 74.50 52.15 59.60 186.26 Add: Consumer Education 0.50 0.50 0.50 1.50 Net Deficit including Carrying cost 1225 1096 1205 3526


Section-4: Annual Revenue Requirement

4. Annual Revenue Requirement for FY 2017-18:

4.1 Determination of ARR requires assessment of energy sales as well as cost of various elements like power purchase cost, O&M expenses, interest cost and depreciation, etc. Projection of the Petitioners with respect to various components of ARR, the Commission’s analysis thereon after consideration of views expressed by the Stakeholders and decision with respect to items given below are discussed in the following paras:

Energy Sales

4.2 Discoms have worked out the energy sales for FY 2017-18 on the basis of the audited figures of FY 2015-16 as well as actual data for the past years. The consumer category wise sales projected by the three Discoms and the energy sales being approved now by the Commission have been discussed in the following sub-paras.

4.3 The Discoms have projected the energy sales for FY 2017-18 for the following consumer categories:

(1) All consumer categories, except agriculture

(2) Agriculture consumers (Metered)

(3) Agriculture consumers (Flat Rate) Petitioners’ Submission

Energy Sales for Metered Categories (except Agriculture)

4.4 T h e Discoms have submitted that they have worked out energy sales for FY 2017-18 on the basis of historical sales data and audited figures of sales for FY 2015-16 using the category wise CAGR as per methodology approved by Commission in the previous year’s tariff order and on the basis as explained in above paras for FY 2016-17 .

Energy sales to Agriculture Metered (M) Consumers

4.5 The energy sales for agriculture metered category have been


estimated on the basis of the following factors: a) Existing Consumers at the start of the Financial Year b) Addition in the consumers during the Financial Year. c) Consumers converted from ‘Agriculture Flat’ to ‘Agriculture

Metered’ category. d) Connected load per consumer. e) Estimated specific energy consumption.

4.6 The connected load per consumer has been forecasted based on the trend observed in previous years and the growth anticipated in connected load per consumer due to the decrease in the water table.

4.7 The Discoms submitted that, they have considered the specific consumption of 2030 kWh/kW/year for JVVNL, 1621 kWh/kW/year for AVVNL and 1868 kWh/kW/year for JdVVNL.

4.8 The Discoms have furnished the following sales to Agriculture Metered category for FY 2017-18 in their petition:

Table 48: Agriculture (M) sales for FY 2017-18-JVVNL Particulars Consumers

(Nos.) Connected

Load per consumer

(kW)



(kWh/kW/year)


Existing consumers 4,66,930 6.12 28,55,457 2030 5,795 New Consumers 15,000 6.12 91,731 2,030 186 Add: converted from flat rate 10,000 7.60 76,044 2,030 154 Total 4,91,930 30,23,232 6,136 Table 49: Agriculture (M) sales for FY 2017-18- AVVNL

Particulars

Consumers

(Nos.)

Connected Load

per consume

r (kW)

Total Connecte

d Load (kW)


r)

Consumption (Sales)

MU

Existing consumers 3,88,409 6.54 25,38,719 1621 4,115


Particulars

Consumers

(Nos.)

Connected Load

per consume

r (kW)

Total Connecte

d Load (kW)


r)

Consumption (Sales)

MU

Add: New Consumers 7,500 6.54 49,022 1,621 79 Add: converted from flat rate

15,000 11.52 1,72,792 1,621 280 Total 4,10,909 27,60,533 4,475

Table 50: Agriculture (M) sales for FY 2017-18- JdVVNL


(Nos.)


(kW)



(kWh/kW/year)

Consumpti

on (Sales) MU


10,000 17.74 1,77,420 1,868 331 Total

3,18,528 10,793


4.9 For projecting the sales for agriculture (flat) category for FY 2016-17, Discoms have considered the specific consumption of 1945 kWh/kW/year as approved earlier by the Commission and the connected load per consumer as projected for FY 2016-17 has been kept at same level for FY 2017-18.

4.10 Discoms indicated the following details regarding the number of flat rate consumers, connected load and specific consumption:

Table 51: Agriculture (FR) Sales for FY 2017-18 – JVVNL

Particulars

Consumers

(Nos.)


(kW)



(kWh/kW/year)

Consumption

(Sales) MU


Particulars

Consumers

(Nos.)


(kW)



(kWh/kW/year)

Consumption

(Sales) MU

Existing consumers 11,694 7.60 88,925 1,945 173 Less: converted to meter 10,000 7.60 76,044 1,945 148 Total

1,694 25 Table 52: Agriculture (FR) Sales for FY 2017-18– AVVNL


(Nos.)

Connected Load

per consumer

(kW)



r)

Consumption

(Sales) MU


22,691 508 Table 53: Agriculture (FR) Sales for FY 2017-18 – JdVVNL

Particulars

Consumers

(Nos.)


(kW)



r)

Consumptio

n (Sales) MU


7,034 243

Total energy sales projected by Discoms:

4.11 The projection of energy sales of different consumer categories discussed in preceding sub-paras is given in the following table:


Table 54: Total Energy Sales for FY 2017-18- Discoms’ Projection (MU)

Particular JVVNL AVVNL JdVVNL Total Domestic 6,919 4,836 4,572 16,328 Non-Domestic 2,511 1,204 1,193 4,908 Public Street Light 214 86 145 445 Agriculture (Metered) 6,136 4,475 10,793 21,403 Agriculture (Flat) 25 508 243 776 Small Industry 345 285 252 881 Medium Industry 761 788 646 2,195 Large Industry 3,635 2,319 1,183 7,136 Public Water Works (S) 251 293 272 815 Public Water Works (M) 46 46 110 202 Public Water Works (L) 314 200 541 1,055 Mixed Load / Bulk Supply 190 109 417 716 Total 21,345 15,149 20,367 56,862


Energy Sales for Metered Categories (except Agriculture Flat Rate Category )

4.12 Considering the approach followed in order dated 20.02.2015, the Commission has considered the 5 year CAGR (from FY 2011-12 to FY 2016-17) for all categories (except Agriculture, large Industry and mixed load).

4.13 While computing the aforesaid 5 year CAGR, the Commission has considered the approved sale for FY 2016-17 as discussed in previous section and actual data of previous year.

4.14 Due to opting of open access by Large Industrial consumers, the 5 year CAGR for large Industrial category is reflecting slow pace of growth of less than 1%. Discoms have projected sales 7136 MUs for FY 2017-18 to this category as against actual sale of 7448 MUs for FY 2016-17. Therefore, for Large Industry category, the Commission has considered actual sales for FY 2016-17 for projecting the sales for FY 2017-18.

4.15 Due to shift of large number of consumers from mixed load category to non domestic category over the years, 5 year CAGR for mixed load


category is reflecting negative growth for three Discoms. Therefore, for mixed load category, the Commission has considered actual sales for FY 2016-17 for projecting the sales for FY 2017-18.

4.16 Further, in case of JdVVNL under Public Street light and public water works (M) category, the 3, 5 & 7 year CAGR is reflecting negative growth for three Discoms. Therefore, in the aforesaid categories, the Commission has considered actual sales for FY 2016-17 for projecting the sales for FY 2017-18.

4.17 The category wise growth rate and energy sales for FY 2017-18 (except flat agriculture) are as given in the tables below:

Table 55: Growth Rate and Energy Sales for FY 2017-18 - JVVNL

Consumer Category

Sales Approved in 2016-17

3-Year CAGR

5-Year CAGR

7-Year CAGR

Growth Rate Adopted by Commission

Energy Sales (MU) approved

Domestic 4,803 8.49% 8.86% 8.82% 8.86% 5,228

Non-Domestic 2,130 10.63% 12.38% 13.13% 12.38% 2,393

Public Street Light 188 9.65% 11.28% 13.24% 11.28% 209

Small Industry 315 4.79% 3.35% 3.50% 3.35% 326

Medium Industry 727 0.24% 2.69% 4.12% 2.69% 747

Large Industry 3,929 4.11% 0.49% 3.46% - 3,929

PWW (S) 241 7.34% 2.03% 2.22% 2.03% 246

PWW (M) 41 9.40% 9.94% 6.89% 9.94% 46

PWW (L) 304 15.04% 16.28% 14.99% 16.28% 353

Mixed Load 209 9.06% -10.63% -6.46% - 209

Total 12887 13686 Table 56: Growth Rate and Energy Sales for FY 2017-18 - AVVNL

Consumer Category


3-Year CAGR

5-Year CAGR

7-Year CAGR



Domestic 3,389 7.79% 9.90% 11.23% 9.90% 3,724


Consumer Category


3-Year CAGR

5-Year CAGR

7-Year CAGR



Non-Domestic 1,088 10.06% 16.19% 15.19% 16.19% 1,264 Public Street Light 75 6.92% 7.22% 8.51% 7.22% 80 Small Industry 278 0.26% 2.40% 2.64% 2.40% 285 Medium Industry 781 4.84% 4.98% 5.87% 4.98% 820 Large Industry 2,390 -2.36% -0.47% 3.05% - 2,390 PWW (S) 283 7.97% 7.39% 6.21% 7.39% 304 PWW (M) 70 22.85% 14.94% 12.41% 14.94% 80 PWW (L) 201 7.17% 6.07% 7.47% 6.07% 214 Mixed Load 101 1.71% -16.86% -10.85% - 101

Total 8656 9,262 Table 57: Growth Rate and Energy Sales for FY 2017-18 – JdVVNL

Consumer Category


3-Year CAGR

5-Year CAGR

7-Year CAGR



Domestic 3,270 8.76% 10.26% 11.14% 10.26% 3,606 Non-Domestic 1,068 8.44% 15.16% 14.38% 15.16% 1,230 Public Street Light 101 -18.32% -3.09% -0.86% - 101 Small Industry 232 1.27% 1.63% 2.50% 1.63% 236 Medium Industry 607 1.54% 4.82% 6.88% 4.82% 637 Large Industry 1,129 1.60% 0.09% 3.05% - 1,129 PWW (S) 264 4.79% 4.28% 2.18% 4.28% 275 PWW (M) 100 -1.12% -0.24% -0.67% - 100 PWW (L) 459 8.86% 5.52% 5.12% 5.52% 485 Mixed Load 371 4.60% -5.36% -2.95% - 371 Total 7602 8,170 Agriculture Metered (M) consumers

4.18 The Commission has accepted Discoms’ submissions in respect of number of existing consumers, new consumers and consumers to be converted from flat rate to metered category.

4.19 For projecting the sale to metered agriculture consumers connected


load and specific consumption as applicable for metered category have been considered for 6 months in case of new consumers and those converted from flat rate for working out their sales.

4.20 Accordingly, using the connected load, consumers and specific consumption as filed by Discoms the Commission worked out the sale to agriculture metered category for FY 2017-18 as follows:

Table 58: Agriculture (M) sales for FY 2017-18-JVVNL

Particulars Consumers (Nos.)


(kW)



(kWh/kW/year)


Existing consumers 4,66,930 6.12 28,55,457 2,030 5,795 Add: New Consumers 15,000 6.12 91,731 2,030 93 Add: converted from flat rate 10,000 7.60 76,044 2,030 77 Total 4,91,930

5,966

Table 59: Agriculture (M) sales for FY 2017-18- AVVNL

Particulars

Consumers

(Nos.)


(kW)

Total Connected Load

(kW)


r)


Existing consumers 3,88,409 6.54 25,38,719 1,621 4,115 Add: New Consumers 7,500 6.54 49,022 1,621 40 Add: converted from flat rate

15,000 11.52 1,72,792 1,621 140 Total

4,10,909 4,295 Table 60: Agriculture (M) sales for FY 2017-18- JdVVNL

Particulars

Consumers

(Nos.)


(kW)

Total Connecte

d Load (kW)


(kWh/kW/year)

Consumption

(Sales) MU


Particulars

Consumers

(Nos.)


(kW)

Total Connecte

d Load (kW)


(kWh/kW/year)

Consumption

(Sales) MU


10,000 17.74 1,77,420 1,868 166 Total

3,18,528 10,373

Energy Sales for Agriculture Flat Rate (FR) Consumers Connected Load per Consumer & Specific Consumption for Flat Rate Consumers.

4.21 The Commission has considered the connected load per consumer of 7.60 KW for JVVNL, 11.52 KW for AVVNL and 17.74 KW for JdVVNL as filed by Discoms.

4.22 Further, the Commission has observed that Discoms have filed the specific consumption for flat rate consumers as approved by Commission in the earl ier order which is accepted by the Commission for FY 2017-18.

4.23 However as mentioned above in metered category connected load of converted consumers have been considered for 6 months, Accordingly, using the connected load, specific consumption and consumers as filed by the Discoms, the sale to agriculture flat rate category have been worked out for FY 2017-18 as follows: Table 61: Agriculture (FR) Sales for FY 2017-18 – JVVNL

Particulars

Consumers

(Nos.)


(kW)



(kWh/kW/year)

Consumption

(Sales) MU

Existing consumers 11,694 7.60 88,925 1,945 173 Less: converted to meter 10,000 7.60 76,044 1,945 74


Total 1,694 99

Table 62: Agriculture (FR) Sales for FY 2017-18– AVVNL


(Nos.)

Connected Load

per consumer

(kW)



r)

Consumption

(Sales) MU


22,691 676 Table 63: Agriculture (FR) Sales for FY 2017-18 – JdVVNL

Particulars

Consumers

(Nos.)


(kW)



r)

Consumptio

n (Sales) MU


7,034 415

Energy Sales as approved by the Commission for all categories

4.24 Based on the CAGR and actual sales approach as discussed in the preceding paragraphs and agriculture metered & flat rate sales, as worked out on the basis of connected load and accepted specific consumption, the energy sales for Discoms are being approved as under:

Table 64: Energy Sales approved by the Commission for FY 2017-18 (MU) Particular JVVNL AVVNL JdVVNL Total

Domestic 5,228 3,724 3,606 12,558 Non-Domestic 2,393 1,264 1,230 4,887 Public Street Light 209 80 101 390


Particular JVVNL AVVNL JdVVNL Total Agriculture (Metered) 5,966 4,295 10,373 20,633 Agriculture (Flat) 99 676 415 1,191 Small Industry 326 285 236 846 Medium Industry 747 820 637 2,203 Large Industry 3,929 2,390 1,129 7,448 Public Water Works (S) 246 304 275 825 Public Water Works (M) 46 80 100 227 Public Water Works (L) 353 214 485 1,052 Mixed Load / Bulk Supply 209 101 371 681 Total 19,750 14,233 18,958 52,941

Transmission and Distribution losses

Distribution Losses


4.25 The Discoms have submitted that they are focusing on loss reduction programs initiated in previous years and also increase use of the technology to target erring consumers and reduce the losses during the projection period. The investments being made under schemes like R-APDRP, FIP, SIP etc. are also expected to aid in the reduction of distribution loss especially in urban pockets.

4.26 Further, to achieve operational efficiency and bring around improvements, other steps like loss based load management, performance monitoring and management system, 100% feeder and DT metering, AMR metering for high value consumers, energy audit & accounting at feeder level, feeder segregation, etc. have already been initiated.

4.27 Considering the focus and all round efforts being made to reduce the AT&C losses, the commitments made under the UDAY scheme and the present available details, the distribution losses as proposed by the Discoms are provided in the table below and this includes technical as well as commercial losses other than those relating to collection efficiency:

Table 65: Distribution Losses for FY 2017-18 – Petitioners’ Submission

Particulars FY 2017-18


Particulars FY 2017-18 JVVNL 20.00% AVVNL 17.50% JdVVNL 16.50%


4.28 As discussed in order for FY 2016-17 in foregoing paras, the distribution losses as claimed by Discoms and approved by the Commission for FY 2017-18 are as under:

Table 66: Distribution Losses for FY 2017-18

Name of Discoms

Losses Proposed by Discoms for FY 17-18

Losses Approved by Commission for

FY 17-18

JVVNL 20.00% 18.50% AVVNL 17.50% 17.50% JdVVNL 16.50% 16.50%

Collection Efficiency

4.29 As Discoms have projected 100% collection efficiency for FY 2017-18. The Commission accepts the submission of Discoms as adoption of lower collection efficiency will increase the revenue gap of Discoms which will indirectly burden the consumers of the State.

Transmission Losses

4.30 The Discoms have filed the intra state and inter-state transmission loss of 4.11% and 3.15% respectively.

4.31 Whereas, the Commission has considered the intra state and inter-state transmission loss of 3.89% and 3.15% based on the RVPN Tariff Order dated 26.05.2017 being actual transmission losses achieved during FY 2015-16 and average of weekly losses for the grid submitted by the Discoms respectively.

4.32 The levels of transmission losses as proposed by the Discoms and considered by the Commission for FY 2017-18 have been shown in the following table:

Table 67: Levels of Transmission Loss (%)

Particulars Proposed for FY

2017-18 Approved by

Commission for FY 2017-18


Particulars

Proposed for FY 2017-18

Approved by Commission for

FY 2017-18

Intra-State Transmission Losses 4.11% 3.89%

Inter-State Transmission Losses 3.15% 3.15%

Energy Requirement as approved vis-à-vis Petitioners’ submission

4.33 On the basis of the sales and distribution & transmission losses discussed above, the energy requirement proposed by Discoms and approved by the Commission for FY 2017-18 is given in the following table:

Table 68: Energy Requirement for FY 2017-18 (MU)

JVVNL AVVNL JdVVNL Total Particulars Propos

ed Approv

ed Propos

ed Approv

ed Propos

ed Approv

ed Propos

ed Approv

ed Energy Sales to Consumers (MU) 21,345 19,750 15,149 14,233 20,367 18,958 56,862 52,941 Distribution Loss (%) 20.00% 18.50% 17.50% 17.50% 16.50% 16.50% Add: Distribution Loss (MU) 5,336 4,483 3,213 3,019 4,025 3,746 12,574 11,248 Energy Required at Discoms periphery (MUs) 26,682 24,233 18,363 17,252 24,392 22,704 69,436 64,190 Intra-State Transmission Losses (%) 4.11% 3.89% 4.11% 3.89% 4.11% 3.89% Add: Intra-State Transmission Losses (MU) 1310 981 915 698 1065 919 3291 2598 Energy Requirement at Transco periphery 27992 25214 19278 17951 25457 23623 72727 66788 Inter-State Transmission Losses (%) 3.15% 3.15% 3.15% 3.15% 3.15% 3.15% Add: Inter-States Transmission Loss 305 296 213 207 244 237 762 741 Gross Energy Requirement (MU) 28297 25511 19491 18158 25701 23860 73489 67529

Power Purchase Cost



4.34 Discoms have projected energy availability for FY 2017-18 on the basis of estimated generation from existing stations and projected generation from new stations. For existing stations, the Discoms submitted that the power purchase quantum has been considered as per the actual energy received in previous years. The Discoms analyzed the existing power scenario and the power purchase has been accordingly projected considering the energy requirement and the merit order principles. The power purchase from stations which were commissioned in FY 2015-16 and were only available for part of the year has been computed based on capacity, PLF and Auxiliary consumption.

4.35 Discoms have submitted that they have made the following assumptions while projecting the power purchase cost for FY 2017-18:

• For Coal, Gas and Hydro based Power Plants, an escalation rate in the range of 2% to15 %is considered over the per unit actual cost for FY 2015-16.

• For Nuclear Power Plants, a nominal escalation rate of 2 % has been considered over average per unit tariff from nuclear sources as per DAE reply to Lok Sabha query dated 09.03.2016.

• The fixed charges and variable charges for the plants which are going to be commissioned in FY 2017-18 have been assumed on the basis of similar types of plant.

• The availability from RFF has been wholly allocated to JVVNL.

• The purchase from renewable energy sources has been projected as per the RPO Obligation approved by the Commission.

4.36 Summary of the power purchase quantum and cost as submitted by Discoms in their petitions are as under:

Table 69: Power Purchase (MU) and Cost (Rs. Cr.) for FY 2017-18 – submitted by Discoms Energy Availability (Mus) and Cost for FY 2017-18- Submission

Stations JVVNL AVVNL JdVVNL Total

Units Cost Units Cost Units Cost Units Cost NTPC 2377 727 1664 509 1902 581 5943 1816 NHPC 777 254 544 178 622 203 1943 635


Energy Availability (Mus) and Cost for FY 2017-18- Submission

Stations JVVNL AVVNL JdVVNL Total

Units Cost Units Cost Units Cost Units Cost RVUN 9132 3683 6392 2578 7305 2946 22829 9207 Rajwest 3065 1238 2146 867 2452 991 7663 3095 GLTPP 237 57 166 40 189 46 591 143 NPCIL 1227 358 859 250 982 286 3068 894 SHARE PROJECTS 1372 48 960 33 1097 38 3429 119 TEHRI 96 56 67 39 77 45 241 139 KOTESHWAR 73 23 51 16 58 18 182 56 Tala 19 4 13 3 15 3 48 10 SJVVN and Rampur 286 90 200 63 229 72 715 224 Neyveli Lignite 710 209 497 146 568 167 1774 522 Aravali Power 3 3 2 2 3 2 8 7 Coastal Gujarat 1004 243 703 170 803 195 2510 608 Adani Power Rajasthan Ltd. 3297 1190 2308 833 2638 952 8243 2975 Sasan Power Ltd. 1161 194 813 136 929 155 2903 484 Karcham Wangtoo 177 60 124 42 142 48 443 151 NVVN Bundled 891 388 624 272 713 310 2228 970 NCES 3316 1597 2277 1097 3075 1481 8668 4175 CPP's 11 2 7 1 8 2 26 5 New Stations 2946 1407 2062 985 2357 1125 7365 3516 Total 32178 11828 22481 8259 26165 9666 80823 29753 Sale/purchase of surplus/(deficit) energy 3881 970 2990 747 464 116 7335 1834

Net power purchase cost 28297 10858 19491 7511 25701 9550 73489 27920


4.37 While estimating energy availability and power purchase cost for FY 2017-18, the Commission has considered the actual data of generation of twelve months from State and Central generating units as submitted by the Discoms of FY 2016-17 for projection for FY 2017-18. Likewise, the position as per latest tariff orders order/interim order as well as the actual variable cost of FY 2016-17 has been escalated in working out power purchase cost for FY 2017-18, as discussed later in the order.

4.38 For estimating the power purchase cost, the Commission has considered availability from various sources for the State as a whole. For working out Discom wise availability and cost, the allocation of power to


JVVNL, AVVNL and JdVVNL from all generating stations has been considered in the ratio of 40%, 28% and 32% respectively, except that 100% allocation of RFF share has been considered for JVVNL.

Energy Availability and Cost for FY 2017-18

RVUN Stations

4.39 For RVUN generating stations, including KTPS (Unit 1-7) & STPS(Unit 1-6), DCCPP, RGTPS(Stage I, II& III), Mahi, MMH, Chhabra (Unit 1-4) & Kalisindh(Unit 1&2), the Commission has considered the energy availability for FY 2017-18 as per actual purchase from April 2016 to March 2017.

4.40 The fixed and energy charges for the aforesaid RVUN plants are as per RVUN Tariff order dated 20.06.2017 for FY 2017-18 and applicable regulations.

4.41 Tariff of Mini-Micro (MMH) plants have been considered as per Regulation 58 of RERC Tariff Regulations, 2014.

4.42 The energy availability and cost from RVUN’s generating stations as considered by the Commission have been shown in the table below:

Table 70: Energy Availability (MU) and Cost (Rs. Cr.)- RVUN Stations for FY 2017-18 Station Energy Availability Cost

KTPS(1 to 7) 6628 2410 STPS(1 to 6) 4023 1876 DCCPP 95 41 RGTP(1&2) 432 107 RGTP 3 936 424 MAHI 209 52 MMH 9 3 Chabbra – 1&2 3059 1184 Chabbra – 3 1515 624 Chabbra – 4 1559 607 Kalisindh unit 1 3415 1578 Kalisindh unit 2 2116 934 Total 23996 9840


Lignite based projects

4.43 The lignite based projects include Giral Lignite Power Limited, Rajwest Limited and Neyveli Lignite Corporation Limited. For Giral unit 1 & 2, Commission has not considered any generation for FY 2017-18 as the plant is not functioning for a long period. The availability for Rajwest and Neyveli for FY 2017-18 has been considered as per actual purchase of FY 2016-17.

4.44 The per unit charge for FY 2017-18 for Rajwest have been considered as per the Commission’s interim order dated 27.04.2017.

4.45 The fixed charges of Neyveli project for FY 2017-18 has been considered as per actual charges for FY 2016-17 and variable charges of FY 2016-17 have been escalated by 2% for FY 2017-18.

4.46 The energy availability and total power purchase cost for Lignite based projects have been summarized in the table below:

Table 71: Energy Availability (MU) and Cost (Rs. Cr.)- Lignite Plants for FY 2017-18


Giral –1&2 0 0 Rajwest 5826 2338

Neyveli Lignite 1271 510 Total 7097 2848

Nuclear Power Corporation of India Ltd. (NPCIL)

4.47 For NPCIL, the Commission has considered the actual purchase of FY 2016-17. The charges per unit as approved above of FY 2016-17 have been escalated by 2% for FY 2017-18.

4.48 The energy availability and total power purchase cost for NPCIL plants have been summarized in the table below:

Table 72: Energy Availability (MU) and Cost (Rs. Cr.)- NPCIL for FY 2017-18


NPCIL 2791 844


Partnership Projects (PP) and RFF

4.49 For partnership projects and RFF, the Commission has considered the actual purchase of FY 2016-17. The variable charge per unit as approved above of FY 2016-17 have been escalated by 2% for FY 2017-18.

4.50 Energy availability and total power purchase cost for partnership projects and RFF have been summarized in the table below:

Table 73: Energy Availability (MU) and Cost (Rs. Cr.)- Partnership Projects for FY 2017-18


Partnership Project 2915 105 RFF 122 50

NTPC, NHPC & Others

4.51 The energy availability and fixed charges for NTPC & NHPC and other plants have been considered as per actual purchase for FY 2016-17 and variable charges of FY 2016-17 have been escalated by 2% for FY 2017-18.

4.52 The cost per unit of Bhadla-II (New PPA) of FY 2016-17 has been kept at same level for FY 2017-18

4.53 The energy availability and total power purchase cost for NTPC, NHPC and other plants have been summarized in the table below:

Table 74: Energy Availability (MU) and Cost (Rs. Cr.)- NTPC & NHPC and Other Generating Stations for FY 2017-18 Plants Energy Availability Total Cost

NTPC Stations 5893 1804 NHPC Stations 1698 622 Rampur+Aravali+ Adani+ Sasan+ SJVVNL+NVVN+coastal Guj.+Wangtoo+other 17171 5814 Tehri Hydro 245 127 Koteshwar 106 42 Tala 49 10 Total 25162 8419


Non-Conventional Energy Sources

4.54 The Commission has taken the availability from non-conventional energy sources to the extent of RPO requirement i.e., 8.20% for wind, 1.30% for Bio-mass and 4.75% for Solar.

4.55 Vide notification dated the 07.06.2017, to be effective from 1.04.2017, the Commission amended the “Rajasthan Electricity Regulatory Commission (Renewable Energy Certificate and Renewable Purchase Obligation Compliance Framework) (Second Amendment) Regulations, 2017.” wherein the Commission stated as under:

Amendments in Regulation 3 of the Principal Regulations: The following proviso shall be added below the existing Regulation 3(g) of the Principal Regulations: “Provided that for the years 2017-18 and 2018-19, the consumption of the obligated entity as defined above shall exclude the consumption met from hydro sources of power.”

4.56 Accordingly, the availability has been considered as per aforesaid RPO Regulations and per unit cost has been considered as per actual of FY 2016-17.

Table 75: Energy Availability (MU) and Cost (Rs. Cr.)- Wind, Solar & Biomass for FY 2017-18

Plants Energy Availability Total Cost

Wind farms 5016 2497 Solar 2906 1341

Biomass 795 528 Total 8717 4366

Short term Sources

4.57 After considering the energy available to Discoms based on their respective allocated shares, the Commission has estimated a surplus in JVVNL & AVVNL and deficit in JdVVNL in energy availability.

4.58 Commission has considered sale and purchase the short term power at Rs. 4 per unit as discussed above in FY 2016-17 order.

4.59 It has also been observed that while the two Discoms are having surplus while the other Discom is having shortage. This is due to allocation of power in certain ratio to respective Discom. The Discoms may take up


the matter with Government for suitable amendment in existing allocation ratio as per requirement.

Total Power Purchase Cost

4.60 Based on the above, the summary of source wise and Discom wise breakup of power purchase quantum and cost for FY 2017-18 as considered by the Commission for the three Discoms is given in the table below:

Table 76: Energy Availability (MU) and Cost (Rs. Cr.) for FY 2017-18 Stations JVVNL AVVNL JdVVNL Total

Units Cost Units Cost Units Cost Units Cost NTPC 2357 722 1650 505 1886 577 5893 1804 NHPC 679 249 475 174 543 199 1698 622 NPCIL 1116 338 781 236 893 270 2791 844 Tehri+Koteshwar+Tala 160 71 112 50 128 57 400 178 RVUN/ State Generation 11929 4871 8350 3410 9543 3897 29823 12178 Shared Projects 1166 42 816 30 933 34 2915 105 RFF 122 50 - - - - 122 50 NCES 3487 1746 2441 1223 2790 1397 8717 4366 SJVN and Rampur 285 90 199 63 228 72 712 224 New Stations 260 107 182 75 208 86 649 268 Aravali+ Adani+ Sasan+ Neyveli+coastal Guj.+Wangtoo 5871 1886 4109 1320 4696 1509 14676 4715 NVVN Bundled 962 447 674 313 770 358 2406 1118 TOTAL 28394 10619 19790 7399 22617 8456 70801 26473 Less/add: Short Term -2883 -1153 -1632 -653 1243 497 -3273 -1309 Net power Purchase 25511 9466 18158 6746 23860 8953 67529 25164

Transmission Charges

Petitioners ‘Submission

4.61 For estimation of the RVPN transmission charges and SLDC charges for FY 2017-18, the escalation rate in the range of 5%-15% is considered over the actual cost of FY 2015-16. Further, for estimating the PGCIL charges, the Discoms have considered an escalation rate of 5%-6% over the PGCIL transmission charges as payable during FY 2015-16.

4.62 The details of the transmission and SLDC charges submitted by Discoms have been summarized in the table below:


Table 77: Transmission Charges & SLDC Charges for 2017-18 (Rs. Crore) Particulars JVVNL AVVNL JdVVNL Total

PGCIL Charges 603 422 482 1507 RVPN Charges 1053 737 842 2632 RLDC Charges 2 1 1 4 SLDC Charges 8 6 7 21 Total Transmission Charges 1665 1166 1332 4163


4.63 The Commission has considered the RVPN and SLDC charges for FY 2017-18 as per the RVPN tariff order dated 26.05.2017 for FY 2017-18.

4.64 The Commission has considered the other transmission, PGCIL and RLDC charges as proposed by Discoms for FY 2017-18.

4.65 The transmission & SLDC charges accordingly approved by the Commission for FY 2017-18 are as under:

Table 78: Transmission Charges approved by the Commission for FY 2017-18 (Rs. Crore) Particulars JVVNL AVVNL JdVVNL Total PGCIL Charges 603 422 482 1507 RVPN and Other Charges 820 574 656 2051 RLDC Charges 2 1 1 4 SLDC Charges 3 2 2 7 Total Transmission Charges 1428 999 1142 3569

Operation and maintenance Expenses


4.66 Discoms have estimated O&M expenses based on the O&M norms specified in RERC Tariff Regulations, 2014.

4.67 The O&M expenses projected by Discoms for FY 2017-18 have been summarized below:

Table 79: Operation and Maintenance Expenses for FY 2017-18 (Rs. Crore) Particulars JVVNL AVVNL JdVVNL Total

Employee Costs 962 683 918 2563

Administrative & General Costs 101 72 79 252

Repairs & Maintenance Costs 203 144 157 504

Total O&M Costs 1266 898 1154 3318


Particulars JVVNL AVVNL JdVVNL Total Less: Expenses to be Capitalized

333 17 172 522



4.68 Commission has allowed O&M expenses in accordance with Regulation 83 of RERC Tariff Regulations, 2014.

4.69 As per regulation 24(3), the Commission has escalated the normative O&M expenses based on per unit sale of FY 2016-17 at the rate of 5.85% per annum for FY 2017-18.

4.70 Commission has considered the sales allowed for FY 2017-18 for projecting normative O&M expenses. Capitalized O&M expenses have been considered in the same ratio as projected by Discoms.

4.71 O&M expenses approved by the Commission for Discoms for FY 2017-18 have been summarized below:

Table 80: Operation and Maintenance Expenses approved for FY 2017-18 (Rs. Crore) Particulars JVVNL AVVNL JdVVNL Total

Employee Costs 890 641 854 2386 Administrative & General Costs 94 68 90 251 Repairs & Maintenance Costs 187 135 180 502 Total O&M Costs 1171 844 1124 3139 Expenses to be Capitalized 308 16 167 492


Terminal Benefit Expenses


4.72 The Discoms have considered the terminal benefits for FY 2017-18 as per the liability assessed in the actuarial valuation for the FY 2015-16.

4.73 The te rm inal benefit liability submitted by the Discoms for FY 2017-18 has been tabulated below:


Table 81: Terminal Benefit Expenses for FY 2017-18 (Rs. crore)

Particulars JVVNL AVVNL JdVVNL Total Terminal Benefit Expenses 700 569 298 1567


4.74 The Commission has considered terminal benefit expenses for FY 2017-18 as submitted by Discoms. However, the Commission shall allow the payment made towards actuarial valuation liability in the true up of FY 2017-18 only to the extent of funds actually transferred to the designated Fund.

Capitalization


4.75 The capital investment and capitalization proposed by Discoms are shown in the table below:

Table 82: Capital Expenditure and Capitalization proposed for FY 2017-18 (Rs. crores)

Particulars JVVNL AVVNL JdVVNL Capital Expenditure 1793 1405 2040Capitalization 1905 1591 2000*

* Before assets not in use as per form 3.6 of the petition


4.76 Following the methodology adopted in 22.09.2016 order for FY 2015-16, the Commission has considered 80% of the proposed capitalization in this ARR order as under.

Table 83: Projected Capitalization approved by the Commission for FY 2017-18 (Rs. Crore)

Particulars JVVNL AVVNL JdVVNL Capitalization 1524 1272 1600

Interest on Loans and Finance Charges & Lease rental


4.77 To compute the interest on loan, Discoms have considered opening normative loan as on 1st April 2016 equivalent to closing balance of


long term loans for FY 2015-16 as per audited accounts for the year. Further, capitalisation during the year after deducting consumer contribution, normative equity @30% of the remaining capitalisation and the balance amount has been considered as addition to long term loans during the year. The loan repayment has been considered in accordance with Regulation 21 of the RERC Tariff Regulations 2014 which caps deemed repayments to the extent of depreciation charged for the year. The closing normative loan is considered after aforesaid addition to loan and deducting normative repayment for FY 2016-17.

4.78 On the similar line the additional capitalization and repayment during FY 2017-18 have been considered to arrive at closing figure of FY 2017-18.

4.79 The interest on long term loans is estimated on the basis of actual weighted average interest rate for long term loans and applied on the average of normative loans (average of opening and closing normative loan).

4.80 The interest on security deposit and finance charges for FY 2017-18 have been projected as explained in above ARR order For FY 2016-17.

4.81 The Discoms have kept the unfunded gap and interest thereon at the same level as claimed in FY 2016-17 i.e. upto FY 2015-16.

4.82 The interest charges and finance charges for FY 2017-18 have been summarized in the table below:

Table 84: Interest and Financing Charges for FY 2017-18 (Rs. Crore) Description JVVNL AVVNL JdVVNL Total Opening balance of LTL 5265 4908 4876 15048 Capitalisation 1905 1591 2000 5496 Capital expenditure financed by Equity 491 394 420 1306

Capital expenditure financed by Consumer Contribution and grants 268 277 599 1144 Receipt of LTL for Capital expenditure 1146 920 981 3046 Principal Repayment 878 601 614 2093 Closing balance of LTL 5533 5227 5242 16002 Average LTL 5399 5068 5059 15525


Description JVVNL AVVNL JdVVNL Total Average Interest rate of LTL (%) 12.40% 12.91% 13.03% Interest Charges on LTL 669 654 659 1983 Interest on Security Deposit 88 64 57 208 Finance Charges & Lease Rental 103 101 309 513 Gross Interest Charges 860 819 1026 2704 Interest Expenses Capitalized 149 96 33 278 Total Interest & Financing Charges 711 722 993 2426 Unfunded Gap upto FY 16 13185 11646 12761 37592 Average ROI 12.40% 12.91% 13.03% Interest liability on unfunded gap 1635 1504 1663 4801 Total Interest & Financing Charges 2346 2226 2656 7227


4.83 Interest on term loan and finance charges have been computed as per methodology explained in above order for FY 2016-17.

4.84 Based on the above, the approved interest and finance charges approved for FY 2017-18 for the three Discoms have been summarized in the tables below:

Table 85: Interest and Finance Charges approved by the Commission for FY 2017-18 (Rs. Crore)

Particulars JVVNL AVVNL JdVVNL Total Opening balance of LTL (A) 5997 3578 3319 12894 Capitalization (B) 1524 1272 1600 4396 Capital expenditure financed by Equity (C) 393 315 336 1044 Capital expenditure financed by Consumer Contribution and grants (D) 214 222 479 915 Receipt of LTL for Capital expenditure E=(B-C-D) 917 736 785 2437 Principal Repayment(F) 697 457 431 1584 Closing balance of LTL, G=(A+E-F) 6217 3857 3673 13747

Average LTL, H=(A+G)/2 6107 3718 3496 13321 Average Interest rate of LTL (%)(I) 8.88% 9.01% 9.54% Interest Charges on LTL, J=(HXI) 542 335 334 1210 Interest on Security Deposit (K) 88 64 57 208


Particulars JVVNL AVVNL JdVVNL Total Finance Charges & Lease Rental (L) 103 101 98 302 Gross Interest Charges, M=(J+K+L) 732 499 489 1720 Interest Expenses Capitalized (N) 127 59 16 201 Total Interest & Financing Charges (O) 605 440 473 1519 unfunded Gap upto FY 2016-17 (P) 14410 12742 13966 41118 Interest on Carry Forward Revenue Gap, Q=(PXI) 1279 1147 1332 3759 Total Interest & Financing Charges after interest on carry forward Gap (O+Q) 1885 1588 1806 5278

Interest on Working Capital


4.85 Discoms estimated their working capital requirement for FY 2017-18 as per Regulation 27 of the RERC Tariff Regulations, 2014 and the same has been tabulated below:

Table 86: Interest on Working Capital for FY 2017-18 (Rs. Crore)

Descriptions JVVNL AVVNL JdVVNL Total O&M expenses (as per norms) 78 73 82 233 Maintenance Spare (as per norms) 140 132 192 464 Receivables (as per norms) 2247 1624 1902 5774 Less: Security deposit of Consumers 1129 820 740 2689 Total Working Capital 1335 1010 1436 3781 Interest Rate (%) 11.80% 11.80% 11.80% Interest on Working Capital 158 119 169 446

4.86 The Petitioner has further submitted that it has considered the latest base rate of State Bank of India of FY 2017-18 plus 250 basis points


4.87 The normative working capital requirement along with interest thereon has been calculated as per regulation 27 of RERC Tariff Regulations, 2014.

4.88 Accordingly, the interest on working capital considered by the


Commission is as under:

Table 87: Interest on Working Capital approved by the Commission for FY 2017-18 (Rs. Crore) Description JVVNL AVVNL JdVVNL Total O&M expenses (as per norms) 72 69 80 221 Maintenance Spare (as per norms) 129 124 144 397 Receivables (as per norms) 1827 1305 1652 4784 Less: Security deposit of Consumers 1129 820 740 2689 Total Working Capital 899 678 1135 2712 Interest Rate (%) 11.80% 11.80% 11.80% Interest on Working Capital 106 80 134 320

Depreciation


4.89 The Discoms have submitted that for computation of depreciation they have considered the specified rates as provided in the RERC Tariff Regulations, 2014 in Appendix-I based on Straight Line Method (SLM)

4.90 The submission of the three Discoms with respect to depreciation has been tabulated below:

Table 88: Depreciation for FY 2017-18 (Rs. crore)

Particulars JVVNL AVVNL JdVVNL Total Depreciation 878 601 614 2093


4.91 Commission has considered depreciation based on the same methodology explained earlier in the order for FY 2016-17

4.92 Accordingly, depreciation allowed by the Commission for each of the three Discoms has been tabulated below:

Table 89: Depreciation allowed by the Commission for FY 2017-18 (Rs. Crore)

Particulars JVVNL AVVNL JdVVNL Total Depreciable Assets at the beginning of the Year (A) 13445 9374 8812 31631 Capitalization during the year (B) 1524 1272 1600 4396


Particulars JVVNL AVVNL JdVVNL Total less: Consumer Contribution and Capital Grants during the year (C) 214 222 479 915 Depreciable Assets added during the Year D=(B-C) 1310 1051 1121 3482 Depreciable Assets at the end of the Year (E= (A+D)) 14754 10425 9933 35112 Average Depreciable Assets during the Year (F=(A+E)/2) 14099 9899 9373 33371 Average Depreciation Rate (G) 4.94% 4.61% 4.60%

Depreciation (FXG) 697 457 431 1584

Insurance Expenses


4.93 Discoms have estimated the Insurance expenses for FY 2017-18 on the basis of net fixed assets subject to the ceiling specified in Regulation 25 of the RERC Tariff Regulations, 2014.

Table 90: Insurance Expenses- Discoms submission for FY 2017-18 (Rs. in Crore)

Particulars JVVNL AVVNL JdVVNL Total Insurance charges 26 19 20 64


4.94 Commission has allowed Insurance expenses in accordance with Regulation 25 of RERC Tariff Regulations, 2014 as explained earlier in this Order.

Table 91: Insurance Expenses Approved for FY 2017-18 (Rs. in Crore)

Particulars JVVNL AVVNL JdVVNL Total

Insurance charges 25 18 19 62

Return on Equity


4.95 Discoms have not claimed return on equity for FY 2017-18.



4.96 As Discoms have not sought Return on Equity, the Commission has also not considered Return on Equity.

Interest on Delayed Payment Surcharge


4.97 Discoms in their petition for FY 2017-18 have claimed the interest on principle amount of Delayed Payment Surcharge (DPS) stating that the consideration of DPS from books of accounts adversely affects the revenue gap of the Discoms. If the accrued DPS is considered to form part of Non Tariff Income, the financing cost for corresponding receivables must also be considered.


4.98 As discussed in ARR section of FY 2016, the Commission direct the Discoms to take up this matter while filing the petition for true-up for FY 2017-18 wherein Discoms should furnished detailed calculations corroborating their claim based on actual/audited data.

Non-Tariff Income and Wheeling Charges


4.99 Discoms have projected Non-Tariff Income for FY 2017-18 using the escalation of 5% per annum on the figures of FY 2015-16. No increase has been considered for projecting income from wheeling and reactive energy charges for FY 2017-18. Further, income from cross subsidy surcharge and additional surcharge have also been projected for FY 2017-18 based on the rates approved by the Commission and the projections made for energy drawl through open access as given below:

Table 92: Non-Tariff Income for FY 2017-18 (Rs. Crore)

Particulars JVVNL AVVNL JdVVNL Total Non-Tariff Income 333 260 406 998 Income from Wheeling Charges, Cross Subsidy Surcharge and Additional Surcharge 224 585 115 924 Total 557 844 521 1922



4.100 The Commission has considered the non-tariff income and wheeling charges for FY 2017-18 as projected by Discoms.

Aggregate Revenue Requirement


4.101 The Annual Revenue Requirement for FY 2017-18 proposed by the three Discoms has been given in the table below:

Table 93: Summary of ARR for FY 2017-18 – Discoms’ submission (Rs. Crore) Sr. No. Particulars JVVNL AVVNL JdVVNL Total

Submission FY 2017-18 1 Power Purchase Cost* 10858 7511 9550 27920 2 Transmission Charges 0 0 0 0 PGCIL 603 422 482 1507 RVPN 1053 737 842 2632 SLDC 10 7 8 25 3 Operation & Maintenance Expenses 933 881 982 2796 4 Terminal Benefit 700 569 298 1567 5 Interest and Finance Charges 711 722 993 2426 6 Interest on unfunded gap 1635 1504 1663 4801 6 Interest on working Capital 158 119 169 446 7 Depreciation 878 601 614 2093 8 Insurance charges 26 19 20 64 9 Aggregate Revenue Requirement 17563 13091 15623 46277 10 Less: Non-Tariff Income 333 260 406 998 11 Less: Cross Subsidy and Additional Surcharge 224 585 115 924 12 Net Aggregate Revenue Requirement 17007 12246 15102 44355

*


Commission’s Approval

4.102 Commission has approved the ARR for FY 2017-18 based on the items of expenditure discussed in the preceding sections and the same has been summarized in the table below:


Table 94: Summary of ARR for all the three Discoms for FY 2017-18 – Approved by Commission (Rs. Crore) Sr. No. Particulars JVVNL AVVNL JdVVNL Total

Approved FY 2017-18 1 Power Purchase Cost* 9466 6746 8953 25164 2 Transmission Charges PGCIL 603 422 482 1507 RVPN 820 574 656 2051 SLDC 4 3 3 11 3 Operation & Maintenance Expenses 863 828 957 2647 4 Terminal Benefit 700 569 298 1567 5 Interest and Finance Charges 605 440 473 1519 6 Interest on unfunded gap 1279 1147 1332 3759 6 Interest on working Capital 106 80 134 320 7 Depreciation 697 457 431 1584 8 Insurance charges 25 18 19 62 9 Aggregate Revenue Requirement 15169 11284 13739 40191

10 Less: Non-Tariff Income 333 260 406 998 11 Less: Cross Subsidy and Additional Surcharge 224 585 115 924 12 Net Aggregate Revenue Requirement 14612 10439 13218 38269


Revenue and Revenue Deficit based on Existing Tariff Revenue on Existing Tariff Petitioners’ Submission

4.103 Discoms have projected the revenue based on energy sales forecasts for the period and the applicable retail tariff as per the RERC’s Tariff Order for FY 2015-16 dated 22nd September 2016

4.104 The revenue in FY 2017-18 from existing tariff as per Discoms’ submission is as under:

Table 95: Revenue from existing tariff for FY 2017-18– Discoms’ submission (Rs. Crore)

Particular


Domestic Service 4,736 3,341 3,118 11,195 Non-Domestic Service 2,410 1,145 1,103 4,659 Public Street Light 149 59 98 305 Agriculture Metered Supply 3,071 2,250 5,239 10,561 Agriculture Flat Rate Supply 14 274 130 418 Small Industrial Service 245 217 185 647 Medium Industrial Service 596 643 531 1,770


Particular


Large Industrial Service 2,939 2,029 1,167 6,136 P.W.W. & S. Pumping –Small 166 199 177 542 P.W.W. & S. Pumping –Medium 34 35 83 152 P.W.W. & S. Pumping –Large 238 158 438 833 Mixed Load / Bulk Supply 145 89 309 543 Total 14,744 10,440 12,578 37,762

Interest subvention, Electricity Duty and Subsidy

4.105 Discoms have shown Differential Interest Subvention on World Bank Loan, Subvention from State Govt against electricity duty, Subsidy against compounding charges for FY 2017-18 as under:

Table 96: Interest subvention, electricity duty and subsidy for FY 2017-18 (Rs. Crore)

Particular


Differential Interest Subvention on World Bank Loan 3 3 2 8 Subvention from State Govt. against ED 664 410 410 1484 Subsidy against compounding charges 17 6 10 33 Total Subsidy Amount 684 419 422 1525

Revenue Deficit

4.106 The revenue deficits submitted by Discoms for FY 2017-18 at the existing tariff have been provided in the table below:-

Table 97: Revenue Deficit at existing tariff for FY 2017-18 (Rs. Crore) Particulars JVVNL AVVNL JdVVNL Total

Submission FY 2017-18

Net Aggregate Revenue Requirement (A) 17,007 12,246 15,102 44,355 Revenue from Existing tariff (B) 14,744 10,440 12,578 37,762 Total of interest on subvention, ED and Subsidy (C) 684 419 422 1,525 Deficit including Carrying cost D= (A-B-C) 1,579 1,387 2,102 5,068 Revenue Deficit of last year E 2,618 2,151 2,891 7660 Carrying cost on revenue deficit F 423 367 514 1303 Gap after last year Losses claimed By Discoms (D+F) 4,619 3,905 5,507 14032

Commission’s Analysis:

4.107 Commission has calculated the revenue from existing tariff on the


basis of consumer category wise energy sales approved by the Commission in this order for FY 2017-18 based on retail tariff notified on dated 22.09.2016. The estimated revenue at existing tariff for different consumer categories for all the three Discoms for FY 2017-18 has been summarized in the table below:

Table 98: Revenue from Existing Tariff for FY 2017-18- Approved by the Commission (Rs. Crore)

Particular


Domestic Service 3649 2676 2524 8,848 Non-Domestic Service 2276 1186 1127 4,589 Public Street Light 156 63 76 295 Agriculture Metered Supply 2988 2163 5083 10,234 Agriculture Flat Rate Supply 54 365 224 643 Small Industrial Service 232 217 176 626 Medium Industrial Service 583 658 519 1,761 Large Industrial Service 3111 2031 1083 6,224 P.W.W. & S. Pumping –Small 163 206 179 548 P.W.W. & S. Pumping –Medium 34 59 76 169 P.W.W. & S. Pumping –Large 265 166 390 821 Mixed Load / Bulk Supply 159 83 276 518 Total 13,671 9,872 11,733 35,276

ARR and Revenue

4.108 Considering the ARR and Revenue at existing tariff as determined by the Commission and subsidy & subvention as shown by Discoms in their petition, the revenue gap for all the three Discoms for FY 2017-18 at the existing tariff has been worked out.

Table 99: Revenue Deficit at existing tariff for FY 2017-18 – Approved by the Commission (Rs. Crore)

Particulars JVVNL AVVNL JdVVNL Total Approved FY 2017-18

Net Aggregate Revenue Requirement (A) 14,612 10,439 13,218 38,269 Revenue from Existing tariff (B) 13,671 9,872 11,733 35,276 Total of interest on subvention, ED and Subsidy (C) 684 419 422 1,525 Deficit including Carrying cost D= (A-B-C) 257 149 1,063 1,468 Add: Consumer Education 0.50 0.50 0.50 1.50 Net Deficit including Carrying cost 258 149 1063 1470


Section-5 : Tariff Proposal and approved Tariff

5. Tariff proposal for FY 2016-17 and FY 2017-18

5.1 Discoms have not made proposal for revision in tariff which has been accepted, accordingly, the tariff determined vide order 22.09.2016 shall continue to prevail during FY 2016-17 and FY 2017-18. The category wise tariff is enclosed at annexure D.

5.2 Discoms have made certain rationalization measures in order to facilitate better utilization of resources, economic pricing and better revenue management which have been dealt below: Load Factor Rebate

5.3 Discoms have proposed a rebate of Rs 0.15 per unit on energy charges for consumers maintaining Load Factor of 50% and above during the billing period. They have submitted that this would ensure system stability and forecasting of power requirement become more accurate. Discom also clarified that this rebate would only be applicable on the energy consumption over a load factor of above 50% for Large Industrial Consumer Category.

Commission’s view

5.4 In light of higher energy availability as mentioned in ARR section and looking to the fact that large industrial consumer are opting for open access, the Commission accepts the proposal of load factor based incentive scheme wherein consumers will be incentivized by way of lower tariff for higher consumption.

5.5 Further, the Discoms may analyse this aspect in light of high availability of power and file appropriate proposals for incentive scheme for higher consumption for other categories of consumers also, which may fetch additional revenue and encourage consumers to purchase power from Discoms only.

Power Factor Rebate

5.6 With regard to Power Factor rebate Discoms submitted that low power factor is detrimental to the network of the licensee. Power Factor of


system is governed by nature of load. Generally low power factor is caused by the highly inductive load on the system. Due to low power factor actual working component of the power gets reduced leading the system to overloading, Higher Line Losses and Voltage Dip. Economical operation of the system is difficult in low power factor scenario as appropriate infrastructure needs to be added to compensate its ill effects. So, it becomes very important that a reasonable value of power factor to be maintained for reliable & economical operation of the system. Discoms submitted that following are the ill effects of low power factor:

• System load with a low power factor draws more current than a system with a higher power factor

• Low power factor draws higher internal current which generates excessive heat that further reduces the equipment life or damages the equipment

• Increased reactive loads can reduce output voltage and damage equipment sensitive to reduced voltage

Discoms submitted that considering the above ill-effects of a low power factor and benefits of maintaining a higher power factor, the power factor penalty/rebate structure is already present and applicable. However, Discoms have proposed to modify the structure to ensure that the rebates are commensurate with the benefits accrued to the network. As the benefits do not increase equally for every percentage point improvement in power factor, Discoms have proposed to introduce graded power factor rebate in the following manner:

In case average power factor is above 0.95 (95%), an incentive of 0.5% of energy charges shall be provided for each 0.01 (1%) improvement above 0.95 (95%) till 0.97 (97%). If the average power factor is above 0.97 (97%), an incentive of 1% of energy charges shall be provided for each 0.01 (1%) improvement above 0.97 (97%). Where the installation of the meters at the consumer’s premise comply with the requirements of the CEA (Installation & Operation of Meters) Regulations, 2006, in case average power factor is above 0.950 (95.0%), an incentive of 0.05% of energy charges shall be provided for each 0.001 (0.1%) improvement above 0.950 (95.0%) till 0.970 (97.0%). If the average power factor is above 0.970 (97.0%), an incentive of 0.1% of energy charges shall be provided for each 0.001 (0.1%) improvement above


0.970 (97.0%).

In case the average power factor falls below 0.90 (90%), a surcharge of 1% of energy charges for every 0.01 (1%) fall in average power factor below 0.90 (90%), shall be charged. Where the installation of the meters at the consumer’s premise comply with the requirements of the CEA (Installation & Operation of Meters) Regulations, 2006, in case average power factor falls below 0.900 (90.0%), a surcharge of 0.1% of energy charges for every 0.001 (0.1%) fall in average power factor below 0.900 (90.0%), shall be charged.

If the power factor falls below 0.70 (70%), the installation shall be disconnected and will not be reconnected till the time average power factor is improved to the satisfaction of the Petitioner. In this regard, some of stakeholder submitted to continue the present incentive on power factor improvement of 1% on full tariff instead of Discoms proposal of 0.5% of energy charges for each 0.01(1%) improvement above 0.95 (95%) till 0.97(97%). They also submitted that the proposal of Discoms is to reduce incentive rate for power factor in the range of 0.95 to 0.97 by half of that at present but no financial basis of capital cost of capacitor installation vis-à-vis incentive has been given. Stakeholder also submitted that the existing incentive of keeping average power factor above .95 (95%) may be continued for 132 KV EHT consumer, who is owning, operating & maintaining his sub-station at his cost. It was also submitted that the proposed clause should only be made applicable for general consumers.

Commission’s view

5.7 Commission observes that improvement of power factor mainly benefits the consumers by way of reduced demand charges besides to the system. Therefore, there is a merit in the submission of Discoms. It is undisputable that if the consumer maintains a higher power factor, he derives the benefit of reduced demand charges and consequently it becomes commercially beneficial to him to install a capacitor. Further, the extent of benefit the consumer gains by investment on capacitors is quite substantial as compared to the cost of the capacitors installed.

5.8 As such the Commission accepts the proposal of Discoms. However, in the last para the words “will not be reconnected till the time average power factor is improved to the satisfaction of the petitioner” shall be


replaced with the words “will not be reconnected till the consumer undertakes to improve the power factor to the satisfaction of the Discoms within (2) months time from the date of notice”.

Voltage Rebate

5.9 Discoms have proposed to redefine the applicability of the voltage rebate which should be applicable only on the energy charges and not on both energy charges and fixed charges. This shall facilitate economic pricing of electricity reflecting the true costs/ benefits of availing supply at higher voltage level.

5.10 Discoms also clarified that the benefits of higher voltages are only in terms of savings in energy alone and there is no impact on fixed charges. The maintenance cost for HT lines are higher compared to lower voltage lines, at present the fixed charges in the tariff do not ensure recovery of fixed cost elements. Accordingly, they have proposed that voltage rebate should be allowed only on the energy charges or units billed.

5.11 Some of the stakeholders requested to continue the existing voltage rebate on both energy and fixed charges instead of only on the energy charges as proposed by the Discoms. They also submitted that in order to avail the incentives of voltage rebate, consumers have to make heavy capital expenditure on transformation capacity, its bay and up-gradation of voltage level supply line, which will result in saving in cost incurred on infrastructure to be provided by Discoms, which is further recovered through fixed charges. Therefore, the rebate should also be given on fixed charges. It is further submitted that withdrawal of incentive/rebate by Discoms, once heavy capital investment has been made should not be allowed.

Commission’s view

5.12 The Hon’ble Supreme Court in the case of Hyderabad Engineering Vs APSEB (reported in 1988(2) Scc. 181 has recognized the right of the supplier to insist upon the high consuming consumers to avail power supply on higher voltage as higher the voltage lower the transmission losses.


5.13 Commission has considered the proposal of Discoms as well as plea of industrial consumers. Commission observes that availing power at high voltage gives permanent benefit to the consumers in terms of quality of power and investment is done one time only, which will be recovered by them from end users of their products. Further, availing power supply at high voltage is in overall interest of the electricity consumers. Therefore, considering the interest of both Discoms and consumers, Commission find the proposal of Discoms fair and reasonable and hence decides to accept the same.

Domestic Service (Schedule DS/LT-1)

5.14 With regard to domestic services Discoms have proposed to clarify that in case of a new consumer, for the first six months, Fixed charges are levied at the lowest slab of General Domestic-1 and not in Small Domestic and thereafter on the basis of six months average consumption. Discoms have suggested modified terms and conditions as follows:

“Fixed charges shall be levied on the basis of average monthly consumption of previous financial year. In case of a new consumer, for the first six months, Fixed charges shall be levied at the lowest slab of General Domestic and thereafter on the basis of six months average monthly consumption.”

5.15 It is further clarified by Discoms that connection to a new consumer is provided under General Domestic only and to provide the benefit of rebate provided to Small Domestic, it has to be first ensured that the consumption does not exceed 50 units in any month.

Commission’s view

5.16 It is observed that above clarification as proposed by Discoms is for the purpose of timely classifying and providing benefit to domestic consumers for applicable slab. Therefore, the Commission accepts the proposal of Discoms

Prompt Payment Rebate

5.17 With regard to prompt payment rebate, Discoms submitted that at present an incentive of 0.15% is being allowed on energy and fixed


charges in the next bill if payment is received before seven (7) working days from the due date of the bill. Discoms have proposed to add another provision to incentivise consumers for prompt payment which will also improve the cash flows of the Discom. Accordingly they have proposed to allow an incentive of 0.35% on energy and fixed charges in the next bill if payment is received before ten (10) days from the due date of the bill.

5.18 Discoms submitted that considering the interest rate of 12.40% per annum the rebate for 10 days would be 0.35%, accordingly the Discoms have proposed the aforesaid rebate.

Commission’s view

5.19 The Commission observes that the above proposal would be beneficial for both consumers as well as Discoms, wherein on the one hand consumers would be benefited in terms of slightly lower payment and on other hand improve the cash flow of the Discoms, therefore, the Commission accepts aforesaid proposal of prompt payment rebate. In case of payment by cheque, rebate shall be applicable only if cheque is realized before ten days from due date.

Temporary Supply tariff

5.20 Discoms have proposed to modify the existing Tariff for temporary supply, wherein, the applicable tariff for corresponding permanent supply plus 50% is being charged, the same is being proposed to be revised to the corresponding permanent supply tariff plus 10% for a period of two months.

5.21 Discoms further clarified that the proposed change would be applicable for a group of consumers, trusts and societies holding events like fairs, exhibitions and decorative purposes and will not be applicable for individual consumers and for construction purposes. Post the period of two months the existing clause (permanent tariff plus 50%) will be applicable.

5.22 In this regard Stakeholders submitted that either the proposal of change of temporary tariff for the corresponding permanent supply plus 50% to 10% be made applicable for construction purpose also or permanent


connection may be allowed for construction of building where the duration is more than one year.

5.23 Some of stakeholders also submitted that changes in temporary supply tariff should be applicable to all and not only for the events of commercial nature.

Commission’s view

5.24 The Commission observe that Discoms have not submitted all the material details and financial implication of the aforesaid proposal. Therefore, the proposal of Discoms is not accepted by the Commission.

Contact Demand

5.25 Discoms have proposed to increase the existing ceiling limit 105% of the contract demand to 120% during night hours (22:00- 06:00 hours) for deemed energy drawl from Discoms, in order to encourage the user to consume power during night hours which would help to ease out the load curve.

Commission’s view

5.26 In light of higher energy availability as mentioned in ARR section and looking to the fact that large industrial consumer are opting for open access, the Commission accepts the Discoms proposal wherein consumers will be incentivized by way of increase in ceiling limit of contract demand in night hour.

Cross Subsidy

5.27 As per Regulation 89 of RERC (Terms and Conditions for Determination of Tariff) Regulations, 2014, the average cost of supply and realization from a category of consumers shall form the basis of estimating the extent of cross subsidy and determination of tariff for that consumer category.

5.28 Regulation 89 of RERC (Terms & Condition of Tariff) Regulations, 2014 read with National Tariff Policy makes it evident that average cost of supply has to be the benchmark in assessing cross-subsidy from any consumer category. The National Tariff Policy states that SERC shall notify a road map with a target that tariff are within +/- 20% of average cost of supply. The Commission has also specified in its Tariff Regulations


that the Commission shall endeavour to determine the tariff in such a manner that it progressively reflects the average cost of supply and the extent of cross subsidy to any consumer category is within maximum range of +/- 20% of average cost of supply.

5.29 Average cost of supply for the three Discoms as per ARR and sales considered by the Commission earlier in this order for FY 2017-18 are as under:

Table 100: Average Cost of Supply for FY 2017-18 Particular JVVNL AVVNL JdVVNL Total Net ARR (Rs. In crore) 14,612 10,439 13,218 38,269 Sales (MU) 19,750 14,233 18,958 52,941 COS (Rs./Unit) 7.40 7.33 6.97 7.23

5.30 The Discoms have not proposed any tariff revision. Therefore, cross subsidy for various consumer categories at existing tariff shall be as under:

Table 101: Cross Subsidy for FY 2017-18 Particular JVVNL AVVNL JdVVNL Total.

Domestic Service -6% -2% 0% -3% Non- Domestic Service 29% 28% 31% 30% Public Street Light 0% 7% 8% 4% Agriculture Metered Supply -32% -31% -30% -31% Agriculture Flat Rate Supply -26% -26% -23% -25% Small Industrial Services -3% 4% 7% 2% Medium Industrial Service 6% 10% 17% 11% Large Industrial Service 7% 16% 38% 16% P.W.W. & S. Pumping - Small -10% -8% -7% -8% P.W.W. & S. Pumping - Medium 0% 0% 9% 3% P.W.W. & S. Pumping - Large 1% 6% 15% 8% Mixed Load/ Bulk Supply 3% 11% 7% 5% Revenue Deficit/Gap

5.31 Discoms have shown a combined deficit of Rs 7660 Crores and Rs. 14032 Crore during FY 2016-17 and FY 2017-18 respectively whereas no tariff increase is proposed during FY 2016-17 and FY 2017-18. The Discoms submitted that they have taken various initiatives to reduce the cumulative revenue gap and to improve overall efficiency such as Loss Reduction, Feeder Segregation, Billing efficiency, Network


Strengthening, Cost Optimisation, Vigilance Drives, Private Sector Participation, Demand Side Management, Focus on customer service and other efficiency improvement measures.

5.32 Against the aforesaid deficit, after taking into account the loan taken over by Government under UDAY, Commission has approved the deficit of Rs. 3526 Crore and Rs. 1470 Crore for FY 2016-17 and 2017-18 respectively, the Discoms should attempt to bridge the gap by taking measures for loss reduction, efficiency improvement and Cost optimization.

5.33 Commission accepts the reasons for not proposing tariff revision for FY 2016-17 and FY 2017-18 and decides to continue the tariff as determined vide order dated 22.09.2016 for FY 2016-17 and FY 2017-18 and also till the next tariff order of the Commission is passed. All existing provisions which are not modified by this order shall continue to be in force.

(S.C. Dinkar) (R.P. Barwar) (Vishvanath Hiremath)

Member Member Chairman


Section 6 - Way Forward

6. Way Forward

6.1 The power sector is witnessing rapid changes over the last few years. Under the Electricity Act, 2003 several initiatives have been taken for development of electricity industry, promoting competition, protecting interests of the consumers and supply of electricity to all areas etc.

6.2 The Standards of Performance have also been specified according to which Discoms shall provide services within time limits specified and This regulation also provides for complaint handling mechanism, payment of compensation and Minimum Overall Standards of Performance to be achieved by a Licensee. This has increased the expectations of the consumers of delivery of a quality and reliable supply.

6.3 During previous years, to cater the demand, the large scale capacities have been added and focus has always been on conventional power generation, as alternatives were very costly. To promote the environmentally benign policies envisaged under the Electricity Act, 2003, Commission has specified preferential tariff for renewable energy and also specified Renewable Purchase Obligation (RPO) for obligated entities including Discoms. The validity of Regulations framed by the Commission enforcing RPO in the State was challenged before Hon’ble High Court, Rajasthan and Supreme Court of India However, the decision of the Commission was upheld by the Hon’ble Courts.

6.4 Govt. of India has set a target of 175 GW of Renewable Power by 2022, 100 GW of this is planned through solar energy, 60 GW through wind energy. The State has been given targets of 5762 MW Solar and 8600 MW Wind power, which would require the huge scaling up of generation from these sources in the State. The year 2017 has seen turning points for both wind and solar PV prices. The lowest bid as low as Rs. 2.44/kWh has been received in a recent bidding for phase-III of

Bhadla solar park. Similarly, in a first ever competitive bidding based price discovery of wind power procurement, a new low of Rs. 3.46/kWh

has emerged. RPO has also been increased in line with National goal. Now with parity in prices the focus may be shifted to capacity additions


using solar and wind energy. In order to enable installation of distributed rooftop solar PV systems in the State, the Net Metering has also been introduced by the Commission. This will not only reduce the losses of the Discoms but also defer their investments on new capacities and up-gradations in the transmission and distribution systems. Further, Forecasting and Scheduling Regulations has been put in place by the Commission to enable generation from solar and wind sources seamlessly integrate into the grid.

6.5 With the advent of open access envisioned under the Electricity Act, 2003, the end consumers especially, subsidising consumers with higher demands, are opting for open access . The short term power market has become an integral part of the power sector. Electricity which used to be available at Rs. 5 to 6/kWh unit earlier is now available at an average price of around Rs. 2.50 to 3.50/kWh. As high paying consumers

have started frequently switching over from Discoms to open market due to which Discoms started facing operational problems. Due to this the demand growth is not high as envisaged by the State Discoms and demand forecasting also became challenging for them. Looking to the development in power sector and with a view to ensure smooth grid operation and to balance the interest of open access consumers and Discoms, the Commission has introduced RERC (Term & Condition of Open Access) Regulation 2016. This has brought in the requisite discipline in the system.

6.6 Govt. of Rajasthan is aiming at power for all, which requires huge investment. However, keeping in veiw the large public interest the Commission will continue to encourage to provide power to all.

6.7 Discoms of Rajasthan were facing financial stress due to various reasons. This was inturn affecting the consumers services. Therefore, to overcome this situation GoI and GoR framed a financial scheme namely “UDAY” which will take out the Discoms from financial distress.

6.8 While issuing the last tariff order dated 22.9.2016, the Commission took note of UDAY Scheme subject to fulfillment of conditions sets therein which were almost akin to Commission's earlier Directives. The Commission also noted the various measures to be taken for efficiency improvement and losses reduction under UDAY which, while


restructuring the finances of the Discoms, has also imposed several stringent conditions for improvement in efficiency.

6.9 Commission in its last order dt. 22.09.2016

6.10 gave various directives and stressed the need for fulfilling the conditions under UDAY Scheme. In the same order Commission noted that it would also look into the development closely. It has been observed that Discoms have taken various initiatives under “UDAY Scheme”

6.11 It has been observed that Discoms have complied with the various direction issued in previous tariff dated 22.09.2016. With regard to conversion of urban flat rate consumers, Discoms submitted that meters have been provided on all the urban areas flat rate agriculture consumers. With regard to reduction of losses to 15% under UDAY, Discoms have submitted that a road map with quarterly target for reduction of AT&C losses have been prepared and officers have been directed to implement measures so as to bring the loss level down to specified targets. With regard to Energy Accounting & Auditing and consumer indexing, Discoms have submitted that 11 KV feeder wise energy accounting has been started under Network Indexing Module (NIM), they have appointed consultant for energy audit of all sub-divisions of Discoms and Consumer indexing of all the 11KV feeders have been completed and DT wise consumer indexing is under process. With regard to voltage wise cost of supply, Discoms submitted that the work of feeder segregation is under progress. The DT metering also has not yet been completed. Upon completion of the above works in progress, the basic parameters required for ascertaining voltage wise losses will be available subsequently which will help in computation of voltage wise cost of supply. Discoms have submitted that they are carrying consumer education programmes for saving electricity including advantages of using star labelled equipments. Regarding basic facilities at sub-division, Discoms submitted that the basic amenities for the consumers are in existence & have been provided in all sub division of Discoms. Also one employee in sub division has been designated as consumer clerk/ consumer friend to guide/ facilitate the consumers. With regard to replacement of defective meters Discoms have submitted that they


have issued the necessary direction for replacement of defective meters. With regard to ERP implementation Discoms submitted that they have appointed the consultant for preparation of DPR and the same has been submitted to PFC for approval.

6.12 Discoms considering the benefits arising out of UDAY have not proposed any revision in tariff for FY 16-17 and 17-18 which will place the consumers at ease. Instead of increase in tariff they have proposed necessary steps like loss reduction, improvement in billing efficiency to reduce the cumulative revenue gap and to improve overall efficiency, Network strengthening and Vigilance Drives.

6.13 Discoms have also resorted to private sector participation by way of Distribution franchisee and demand side management.

6.14 Progress made by Discoms under UDAY has been reviewed and noted below. Its effect on finances of Discoms has been considered in ARR section of this order.

6.15 The Commission observes that UDAY, though time being has addressed the issue of interest burden on Discoms but will prove useful in long term only if the Discoms achieve goals of AT&C losses reduction along with desired level of operational efficiency. Discom should ensure that they achieve the prescribed goals otherwise they will again fall in debt trap as UDAY does not offer any cure for inefficiency.

6.16 In a recent review the status of achievement of various goal set under UDAY by Discoms is as under:

Goal 1: AT& C Loss Reduction

• Target under UDAY by FY 18-19: 15% and for FY17-18 is 18.78%

• Achievement for AT&C loss levels reduced from 28.36% FY-16 to 23.81% FY-17 (-4.55% )

Goal 2: Eliminate ACS-ARR Gap by FY19 • Target : Eliminate ACS-ARR Gap by FY-19 and ACS ARR Gap to Rs. 0.25 pu

in FY-18

• Achievement:

1. ACS & ARR gap reduced from Rs. 2.36 pu FY-16 to Rs. 1.02 pu in FY-17

2. Interest burden reduced from Rs. 1.96 pu FY-16 to Rs. 0.96pu in FY-17


3. Distribution Franchisee appointed in Kota, Bharatpur, Bikaner & Ajmer

City Goal 3: Metering at All Levels

• Target: 100% feeder metering up to June’16, DT level metering in RAPDRP towns as per Discom’s policy) And AMR metering for high value consumers (LIP+MIP)

• Achievement:

1. 100% (19904/19904) Rural and (4018/4018) Urban 11kV feeder metered

2. 14078/22045 DT metered in Go-Live towns

3. AMR metering provided to 12798/38000 high value consumers

Goal 4: Energy Audit

• Target: 100% energy audit at 11kV feeders by Sept’16 and DT level energy audit in RAPDRP towns

• Achievement:

1. Energy audit started for all 11kV feeders w.e.f. Sept’1

2. Feeder in-charge appointed for each feeder 3. Energy audit for 67% feeders validated, remaining by June’17 4. Energy audit started for 14078 DT’s in RAPDRP towns (under Validation)

Goal 5 : Connection to Un-connected Households

• Target:30 lac household by FY 19- target of 12th plan-20.5 Lakh

• Achievement: 18.88 lacs households electrified in last 3 years and Remaining by (June’18 – March 19)

Goal 6: Demand Side Management

• Target: Provide LED under DELP/UJALA Programme and Replacing at least 10% existing agriculture pumps with energy efficient pumps by March’19

• Achievement:

1. 1.33 Cr LED, 24188 Energy Efficient Fans, 75841 tube lights distributed.


2. Replacement of 28 pump sets under pilot project, DPR for 31200 pump sets under process

Goal 7: Increase Employee Engagement • Target: Capacity Building of employees, devising KPIs and Customer

Service Strategy and ERP Implementation

• Achievement:

1. Various trainings conducted for senior officers at corporate office and for subordinate staff at district level

2. KPI’s for O&M offices have been finalized and issued

3. Average 1 lac complaints registered monthly and more than 97% resolved within time

Apart from that Discoms have also taken following measures for reduction of AT&C losses:

Measures for reduction in AT&C Losses (In Rural Areas):

Rural area target 15% by March-18 (i) 11 kV Feeder to be smallest unit for measurement. (ii) One Feeder In charge for each feeder. (iii) Public Reps. & District Admn. to be involved in loss reduction. (iv) Feeder Management Committee being constituted. (v) Each JEN to identify 33 kV S/S in phases. (vi) Identification of technical interventions on each feeder. (vii) Technical interventions to be completed by December 2017. (viii) Feeder vigilance squad - after technical interventions. (ix) Workshops have been conducted.

Measures for reduction in Losses (In Urban and Industrial Areas)

Urban areas Industrial areas Reduction in AT&C Losses Target – < 15% 1. XEN to be responsible 2. DT-wise energy audit in high loss areas 3. Implement scheme like

Reduction in Dist. Losses 1. Target – < 2% 2. XEN to be responsible 3. Feeder wise energy audit 4. Suitable technical interventions


undergrounding or overhead AB cable, system 4. Timely replacement of defective meters 5. Necessary vigilance

5. Necessary vigilance

6.17 Apart from UDAY, Rajasthan State Electricity Distribution Management Responsibility Act, 2016 has been enacted to provide for responsibilities of the State Government and State Distribution Licensees to ensure financial and operational turnaround and long-term sustainability of the State-owned Distribution Licensee to enable adequate electricity supply to consumers through financial restructuring support on sustainable basis in the areas of long term planning corporate governance regulatory compliances and laying down of policy directives and various other measures connected therewith or incidental thereto.

6.18 It is observed that though Discoms are moving towards efficiency improvement, but significant improvement is yet to be achieved and above initiatives would not be sufficient to overcome financial crisis faced by the Discoms and apart from above, the Discoms should also focus on the following measures of revenue enhancement and expenditure control.

A. Revenue Side Management With regard to revenue management the Discoms shall ensure the following which will bring enormous benefits: 1. Focus on metering, billing and collection

In last Tariff order, the Commission noted that a lot more is required to be done in this area. Metering, Billing and Collection are three important commercial activities which is the financial backbone of Discom. As discussed earlier and as mentioned in UDAY Scheme, use of AMR meters, issue of bills through SMS/e-mail, availability of bills through website and allowing online payment is the need of the hour. Discoms during proceedings have also submitted that they are taking steps for improvement in Metering, Billing and Collection activities but results of these are yet to be reflected in financial position of Discoms. Therefore, Discoms must focus on considering the AMR metering, e-billing and e-Collection.


Discoms should focus on the activities, like installation of the new meters/replacement of the defective meters on war footing ,prepare age wise and category wise details of arrears and chalk out action plan for recovery of arrears, Introduce checks and balances for billing errors. Discoms should ensure to take energy audit seriously and make use of results of energy audit. Periodic analysis of result of energy audit for each feeder must be conducted at circle level and responsibility of feeder managers/ field level officers must be fixed for taking corrective actions. Revenue Audits should also be carried out to find out revenue leakages and loopholes must be plugged. Bills should be delivered timely so that maximum number of consumers can avail prompt payment facility. During Public hearing MD, JVVNL submitted that they have prepared a web/mobile based application for use of consumers. Discoms should make maximum use of technology to reduce errors, minimize human intervention and increase customer satisfaction.

2. Step up vigilance activity for better revenue collection

Curbing of theft should be of prime concern for the Discoms. The Discoms are advised to strengthen their vigilance cells and take up frequent checking of theft prone areas. Discoms should take appropriate steps to improve revenue collection in relation to revenue assessed. The Commission reiterates that in appropriate cases, instead of giving benefit of compounding as a routine course, Discoms shall pursue penal actions such as initiating prosecution both against the consumers and others who conspire so that people are deterred from indulging in theft. Discoms may also initiate penal action against the employees and officers, if they are found to be conspiring with the person making the theft. It is well known that prevention is always better than cure. Therefore, Discoms instead of going in search of thieves may also consider such initiative which will reduce the scope of theft by regular checking of theft prone areas at such intervals as has been found necessary in each case and also by taking appropriate technical interventions, such as installation of tamper proof meters, etc.

3. Monthly billing for all consumers

In the last tariff Order Commission had observed that the Discoms should consider to shift consumers from bi-monthly to monthly billing, which will


help in speedy recovery of funds, improve the cash flow position and early identification of defaulting consumers. Therefore, Discoms now should take steps for necessary changes in the billing software, so that atleast from 01.04.2018 the billing is made on monthly basis for all category of consumers.

4. Load/Demand based billing

Commission from time to time has stressed that Discoms should move towards demand based billing, so that the fixed tariff are charged and collected more scientifically. In the tariff order for FY 2012-13, the Commission had allowed LT MIP consumers to opt for billing on the basis of demand. Further, in the tariff order for FY 2013-14, the Commission while moving towards goal of demand based billing for all categories of consumers allowed LT consumers of Non Domestic category (NDS/LT-2) and Bulk supply for Mixed load category (ML/LT-7) having sanctioned connected load more than 18.65 KW (25HP) also to opt for billing on the basis of demand. Now meters installed are having load/demand recording facility, the Commission desires to extend the facility of load/demand based billing to all categories of consumer during next financial year. So that the consumers will be billed based on their actual load/demand usage. This step will also save precious time of field staff of the Discoms which they can utilize to curb theft and ensure better consumer services, instead of keep on checking the connected load of consumers. which is an irritant to honest consumers Accordingly, Discoms may file suitable proposal with the next tariff filing.

5. Private Sector Participation

Input based distribution franchise model has already been introduced in one or two circles in each Discom. During the hearing, MD, JVVNL has informed that franchisee operations are yielding good results. Successful model can be replicated in other circles. PPP model may also be explored where private participation with higher accountability may be considered. For improving billing and collection efficiency and reduction


in AT&C losses, private sector role may also be suitably considered.

B. Expenditure Side Control

Discoms should minimize the expenditure and focus on individual item of expenditure to curtail it to the possible. Special focus should be given to the major item of cost i.e. power purchase and interest cost along with control on capital expenditure and other expenses.

6. Power Purchase cost

Discoms in their petitions have submitted that improved power purchase management, better forecasting, load curve straightening, improved inventory management etc. have been planned with the use of better systems and IT implementation. The Discom is actively working on improving its efficiency of power procurement especially to take advantage of cheaper power available at exchanges or through bilateral deals. The Discom are also evaluating other options such as surrendering costly PPAs, under-drawing power through PPAs when the variable cost is higher than what is available bilaterally or through exchanges. They are also undertaking measures for accurate load forecasting so that impact of over drawl and under drawl on power purchase cost can be minimized. These measures will help to optimise the cost and reduce the existing revenue gap. The Commission notes the submission of the Discoms and observes that Power Purchase Cost is the most significant cost component and need to be managed dynamically. Discoms may have a comprehensive relook on all power purchase tied up by them vis-à-vis their requirement and decide future course of action in cost effective manner.. Proper and adequate arrangement of economical solar power will also assist the Discoms to supply the day time power at lower tariff as the line loss would be lower.

7. Late Payment Surcharge and Interest Cost

Post UDAY financial position of Discoms has improved and now Discoms should ensure that it makes the timely payment to power suppliers so that no additional liability towards late payment surcharge is incurred and instead Discoms shall avail prompt payment incentive.


Discoms should also keep on looking for cheaper and economical sources of funding to reduce the interest rate and finance charges. Discom should ensure that they timely get the subsidy from State Government , realise their dues from consumers and make timely debt servicing so that they should not fall into debt trap. The Govt. of Rajasthan, which has stood rock solid behind Discoms shall ensure timely release of subsidy as prescribed in the subsidy Regulations.

8. Day power to agriculture sector:

The average cost of Discoms for supplying power has reached approximately to Rs. 7.23/kWh. The tariff of agriculture category is already charged on lower side as compared to other categories. Additionally State Govt. is providing huge tariff subsidy of approximately Rs. 7000 crore per annum to this category. In the recent past the solar PV technology is rapidly becoming less expensive and now electricity generated from this technology is available at cheaper rates (below Rs 2.50/kWh). The solar PV generation, when deployed as a distributed generation, would not only reduce the power purchase cost of the Utilities but would also result in savings in T&D losses. In addition, this would allow them to defer their future investments in new generation capacity and up-gradation of the existing transmission and distribution system. The distributed solar PV generation would cater the day time power demands of the agriculture sector but would also make their power supply more reliable as the power is generated by many generators spread over a wide geographic area. This makes it harder for a large area to be without power and easier to maintain grid stability. Considering average power purchase cost of Rs. 3.70/kWh and a saving of technical distribution loss of 15% and Transmission losses and also considering savings in investment, it may be assumed that by making use of the distributed solar generation the Discoms save Rs. 2 /kWh. The estimated sales for Metered Category agriculture Consumers is approx 20000 MUs. If only 25% of these sales (present or future) are shifted to distributed solar PV generation there is a scope of savings of approx Rs. 1000 crore which can be utilized for reducing accumulated losses or government subsidy. Though above outlook may appear ambitious but in long term Discom may have to strategically adopt such measures. Greening the grid is new mantra. As such Discoms may examine and explore the possibilities of inviting tehsil wise/District wise bids for setting up of the distributed solar PV


projects preferably in the vicinity of existing distribution system substations to cater to the agriculture/rural load requirement. Primary Schools mainly require day time power. In such cases solar PV not only fulfills the power requirement but also saves the Cost which can be used for other purposes. Likewise, other places like Panchayat Samitis, Primary Health Sub-Centres also require day time power. In all such cases solar PV is a cheap and viable option which not only relieves the distribution system but also help in avoiding future investments needed for upgradation of the distribution system. Therefore, Discoms may take up this with the State Govt. on priority and take further action.

C. Other Measures

1. Focus on services improvement –

Discoms should run a program for skill development, imparting training, refresher training to new entrants, engineers, administrative and financial personnel, technical workmen and the executives for improving their services.

Discoms are advised to relook into their manpower requirement as it has a direct impact on the quality of consumer service provided by them. The shortage of technical staff required for maintenance of lines and restoration of supply as well as the other operation related issues need to be looked into by Discoms at priority. The Discoms must strive hard to follow the norms laid down in Standard for Performance for Distribution Licensees, Regulations, 2014, for better customer services.

The Commission vide Rajasthan Electricity Regulatory Commission (Electricity Supply Code and Connected Matters) XIth Ammendment Regulations, has also introduced following measures:-

Simplification of process of release of new connection:

(1) The process of releasing new connection has been simplified. Now there will be no application fee for LT domestic consumers.

(2) In order to expedite the process of release of a new connection, in case of an application received with all required documents and


distribution licensee fails to accord sanction or communicate reason for refusal for the proposed connection within 30 days, the connection shall be deemed to have been sanctioned.

Simplification of Agreement:

(3) The agreements to be executed by HT/EHT consumers applying for a new connection have been simplified to minimize the disputes. For other consumers the application form itself shall be the agreement.

Facility of using existing connection for construction purpose:

(4) Existing LT domestic and non-domestic category consumers shall be able to use their existing connection for the purpose of further construction in the same premises provided their connected load/ contract demand doesn’t exceed their overall sanction load/demand. However this facility shall not be available for construction of building complexes and to other categories of consumers.

Transfer of connection and transfer of security:

(5) In order to facilitate the transfer of connection from one consumer to other detailed modalities have been introduced. The facility of transfer of security has also been provided in cases of transfer of connection/clubbing of connection.

Interest on security deposit:

(6) The procedure of payment of interest on security deposit of the consumer lying with licensee has been made more transparent. Now the distribution licensee is required to give details of the security deposits lying with it and the interest thereon along the bill of the month in which the interest is adjusted.

Provision for self-reading of meter:

(7) In case of non-receipt of electricity bill, the facility of self-reading has been introduced for the consumers according to which the consumer may read meter by himself for the period for which the bill is not received.

The assessment in case of stopped/ defective, lost or stolen meter where

previous period record is not available:


(8) In such cases the consumer shall be billed provisionally on the basis of 25% load factor on 8 hours use per day in case of domestic category and 50% load factor on 8 hours use per day for all other categories and the assessment shall be reviewed average consumption of succeeding six month period after installation of correct meter and charged accordingly.

Provision for refund of testing fee in case of meter is found inaccurate:

(9) (i) In order to provide relief to the consumer in suspected cases of inaccurate meters, the testing fee deposited by the consumer shall be refunded/ credited by the distribution licensee to the consumer’s account, if a meter is found inaccurate. (ii) The copy of MRI Reports/ Laboratory test report detecting inaccuracy shall also be required to be made available to the consumer. (iii) In cases of meter found inaccurate, the time limit of intimation of consumption assessment has been reduced from six months to two months.

Annual statement of account:

(10) On a payment of a token amount of Rs 10/- by a consumer, the licensee has to furnish the details of statement of accounts of consumers duly indicating the consumption, date of payment and amount thereof, the security held and interest payable and when it was paid, additional security, if any, required and due date of the same.

Introduction of cheque dishonor fee:

(11) To take care of cheque dishonor cases, the provision has been made that no further cheques shall be accepted from such consumers without prejudice to the licensee taking action such as levying cheque dishonor fee besides initiating prosecution under the applicable law.

Rebate on Advance payment:

(12) If a consumer under any category voluntarily deposits the average amount of six or twelve months energy bill on the basis of average bill of preceding year in advance, he would be allowed a rebate at the rate equivalent to Bank Rate as on 1st April.


Rationalisation of process of disconnection:

(13) (i) In cases of disconnection of supply, in addition to the notice, the licensee shall also intimate the consumer through sms/e-mail on his registered mobile number/e-mail id if available. (ii) The licensee shall not disconnect the supply on general holidays and Sundays. (iii) Disconnection of power supply shall be effected as far as possible before 1.30 PM and reconnection shall preferably be effected on the same day of payment. (iv) If arrear is Rs 100/- or less, there will be no disconnection and arrears shall be carried forward to the next bill. (v) If a consumer produces proof of payment or deposits under protest, an amount equal to the sum claimed from him or the electricity charges due from him for each month calculated on the basis of average charges for electricity paid by him during the preceding six months, whichever is less, his supply shall not be cut off/if cut off shall be reconnected immediately.

Recovery of old outstanding dues:

(14) The distribution licensee shall be able to recover old outstanding dues against any permanently disconnected connection from another existing/new connection in the name of same person.

Relief in penal assessment in case connected load is found more than sanctioned load: (15) A relief has been provided to the consumers in cases of unauthorised use of electricity, where the sanctioned connected load gets exceeded through meter (other than domestic and small (upto 5 kW) non-domestic consumers). Earlier, in such cases the penal assessment was being done for the connected load as well as the energy in proportion of exceeded load to total load at twice the fixed charges and energy charges. Now the penal assessment shall only be made on the basis of quantum of exceeded load and shall be charged only at twice the fixed charges.


Duplicate copy of bill:

(16) Duplicate copy of bill for all category consumers shall be provided free of cost. Charges for release of connection and other miscellaneous charges and rentals have not been increased.

Discoms should ensure that all consumers get benefit of measures introduced by the Commission. Discoms may recruit employees at cutting age level i.e. the level requires to cater the need of consumers like lineman, helpers and supervisors etc.

2. Employees and Consumer Education

Discoms should make efforts to create awareness regarding consumer grievance redressal mechanism as well as towards consumer education. To enable Discoms to conduct consumer awareness campaign periodically and institutionalize a mechanism for having a dialogue with the consumers for educating them and addressing common problems in previous order, the Commission has allowed an additional amount of Rs. 50 lakh per Discom, towards consumer awareness /consumers education.

3. Safety Measures

It is observed that number of accidents are happening due to lack of safety measures and lack of awareness among employees as well as general public. Discoms should ensure effective safety measures as envisaged in CEA (Measures relating to Safety and Electricity Supply) Regulations, 2010 and CEA (Safety requirements for construction, operation and maintenance of electrical plants and electric lines) Regulations 2011. The Discoms should conduct necessary training/courses for all employees of the Discoms in this matter. A consumer awareness campaign related to safety issues should also be launched for making them aware about how to avoid accidents and protect themselves, this may be done through TV/newspaper, ads, pamphlets, workshops and seminars or any suitable means. We would also like to note again that the Safety Regulations contemplated overseeing of implementation of these regulations by the Chief Electrical Inspectors/Electrical Inspectors appointed by the State


Government and any non-implementation is to be dealt with by these Inspectors. The Chief Electrical Inspector and Electrical Inspectors are the watchdogs of the Safety Regulations and they shall ensure implementation by periodical checking of any violation of the Regulations. The Govt. of Rajasthan should periodically review the working of Electrical Inspectors and take action if need be for non-performance of their duties. Proper implementation of safety regulations will avoid electrical accidents which are occurring in large numbers and would save precious life and limbs of the individual and the livestock. In case of criminal negligence State shall not hesitate to prosecute the offender.

4. Energy Efficiency measures

DSM cell of Discoms needs to assume more active role in agriculture sector and use of energy efficient pump sets among farmers. They may also study the dynamics of drip irrigation module with solar based energy efficient pump and reducing dependence of agriculturist in far flung areas on Discom’s system.

It is observed that Discoms have distributed 1.33 Cr LED, 24188 Energy Efficient Fans, 75841 tube lights. LED street lights are also giving good results in energy savings. Discoms may also consider to propose a suitable rebate for energy efficient/green buildings and continue to pursue the programs like LED distribution programme.

5. Tariff for Charging Stations of Electrical vehicle

The GoI has launched a National Electricity Mobility Plan 2020 (NEMMP-2020) IN 2013 setting a target of 6-7 million hybrid and electric vehicles by the year 2020. Subsequent to above GoI has also launched a scheme for Faster Adoption and Manufacturing of (Hybrid and) Electric Vehicles in India (‘FAME’). Commission intends to promote the alternate sources of energy for transport which are eco-friendly. For achieving this, electric vehicle charging is to be made affordable and easily available everywhere. The Discoms should come out with a proposal for suitable incentivized tariff for such charging station along with next ARR petition.

6. IT and ERP

In last order, the Commission stressed on to implementation of Enterprise Resource Planning (ERP) systems for better and effective Material


Management including inventory management to reduce costs and increase efficiencies. Further, Discoms were also asked to monitor the material management and inventory management so that adequate material is available for its works and at the same time excess purchase of material is avoided in compliance to above direction, Discoms submitted that they have appointed the consultant for preparation of DPR for implementation of ERP system and the same is submitted to the PFC for its approval. Commission observe that the above efforts are not sufficient and Discoms must put in more efforts to implement the ERP system expeditiously. It is observed that Discoms have taken some initiatives towards implementation of IT but that is in bits and pieces, they have to adopt an integrated approach towards IT implementation. . As far as use of Information technology is concerned, it needs no emphasis. The Discoms must promote the use of information technology to save the cost and improve efficiency. Electric power utilities worldwide are increasingly adopting the computer aided monitoring, control and management of electric power distribution system to provide better services to their consumers. Therefore, Discoms should focus on adapting recent advancement in the area of IT (Information Technology), data communication & control system Apart from use of website and online payment, the Discoms must develop and promote mobile applications for billing and collection as well as for customer complaints where consumer grievance can be addressed timely and expeditiously, which will on one hand improve revenue collection of Discoms and on other hand improve the consumer satisfaction level. The long term goal of IT enablement should be transformation of Discoms into a virtual enterprise to handle 24X7 operations with full responsiveness, which the consumers have become accustomed to in e-commerce era. Only with the full IT enablement Discom will be able to derive out the best benefit of investments.

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Annexure – A- 1. Sh. Y.K. Bolia (JVVNL, AVVNL & JdVVNL) 2. M/s JMRC (JVVNL) 3. Sh. B.M. Sanadhya (JVVNL, AVVNL & JdVVNL) 4. M/s Mansarover Sector-5 Welfare Society (JVVNL) 5. M/s. Credai Rajasthan (JVVNL) 6. Sh. G.L. Sharma (JVVNL, AVVNL & JdVVNL) 7. M/s. Rajasthan Steel Chambers (JVVNL, AVVNL & JdVVNL) 8. M/s. Shree Cement Ltd. (JVVNL, AVVNL & JdVVNL) 9. M/s Rudraksh Energy (JVVNL, AVVNL & JdVVNL) 10. Sh. P.C. Jain (JVVNL) 11. M/s Rajasthan Textile Mills Association (JVVNL, AVVNL & JdVVNL) 12. M/s Rajasthan Vidyut Takniki Karmchari Association (JVVNL) 13. Sh. Rakesh Rastogi (JVVNL) 14. M/s Sunil Health Care (JVVNL, AVVNL & JdVVNL) 15. Sh. Shanti Prasad (JVVNL, AVVNL & JdVVNL)

Annexure - B

1. Sh. G.L. Sharma 2. Ms. Neha Garg 3. Sh. Rakesh Rastogi 4. Sh. Gyan Singh 5. Sh. Mohit Nebhwani 6. Sh. Sukhmal Jain 7. Sh. S. N. Gupta 8. Sh. B.M. Sanadhya


Annexure C List of abbreviations

A&G : Administrative and General Expenses AMR : Automatic Meter Reading APTEL : Appellate Tribunal for Electricity ARR : Aggregate Revenue Requirement AT & C : Aggregate Technical and Commercial AVVNL : Ajmer Vidyut Vitran Nigam Ltd. CAGR : Compound Annual Growth Rate CAO : Chief Account Officer CEA : Central Electrical Authority CERC : Central Electricity Regulatory Commission CESC : Calcutta Electric Supply Corporation COD : Commercial Date of Operation CPP : Captive Power Plants CT/PT : Current Transformers/Potential Transformers CTPP : Chhabra Thermal Power Plant DAE : Department of Atomic Energy DCCPP : Dholpur Combined Cycle Gas based Thermal Power Plant DELP : Domestic Efficient Lighting Programme DISCOM : Distribution Company DPS : Delayed Payment Surcharge DS : Domestic Supply DSM : Demand Side Management DT : Distribution Transformer EA 2003 : Electricity Act, 2003 ED : Electricity Duty EESL : Energy Efficiency Services Limited EHT : Extra High Voltage ERP : Enterprise Resource Planning FIP : Feeder Improvement Programme FR : Flat Rate FY : Financial Year GoI : Government of India GoR : Government of Rajasthan GLTPP : Giral Lignite Thermal Power Plant HT : High Tension JdVVNL : Jodhpur Vidyut Vitran Nigam Limited


List of abbreviations JVVNL : Jaipur Vidyut Vitran Nigam Limited JMRC : Jaipur Metro Railway Corporation KTPS : Kota Thermal Power Station KW : Kilo Watt KWH : Kilo Watt Hour KVA : Kilo Volt Ampere LED : Light Emitting Diode LT : Low Tension LTL : Long-Term Loans MIS : Management Information System MIP : Medium Industrial Power MMH : Mini Micro Hydro ML : Mixed Load MoU : Memorandum of Understanding MU : Million Unit MW : Mega Watt NCES : Non Conventional Energy Sources NDS : Non Domestic Supply NFA : Net Fixed Assets NHPC : National Hydro Power Corporation NLC : Neyveli Lignite Corporation NPCIL : Nuclear Power Corporation NTI : Non Tariff Income NTPC : National Thermal Power Corporation NVVN : NTPC Vidyut Vyapar Nigam O&M : Operation & Maintenance PGCIL : Power Grid Corporation of India Ltd. PLF : Plant Load Factor PP : Partnership Projects PTC : Power Trading Corporation PWW : Public Water Works PV : Photovoltaic RAPDRP : Restructured Accelerated Power Development & Reform Programme RDPPC : Rajasthan Discoms Power Procurement Centre RBI : Reserve Bank of India RERC : Rajasthan Electricity Regulatory Commission RGGVY : Rajiv Gandhi Grameen Vidyutikaran Yojana

https://en.wikipedia.org/wiki/Photovoltaic_system

http://rggvy.gov.in/


List of abbreviations RGTPS : Ramgarh Gas Thermal Power Station RLDC : Region Load Dispatch Centre RoE : Return on Equity ROI : Return on Investment RPO : Renewable Power Obligation R&M : Repairs & Maintenance RVPN : Rajasthan Vidyut Prasaran Nigam RVUN : Rajasthan Vidyut Utpadan Nigam SIP : Small Industrial Power SJVNL : Satluj Jal Vidyut Nigam Limited SLDC : State Load Dispatch Centre

SLM : Straight Line Method STPS : Suratgarh Thermal Power Station T&D : Transmission & Distribution UDAY : Ujwal Discom Assurance Yojana


Annexure D Approved Tariff for FY 2016-17 and FY 2017-18 DOMESTIC CATEGORY (LT-1 and HT-1) (BPL, Astha Card Holders and Small Domestic having consumption upto 50 units per month) BPL and Small Domestic

Domestic Category Particulars Approved Tariff

Energy Charges Fixed Charges

BPL and Astha card Holders*

(i) For consumption upto first 50 units per month Rs. 3.50/ unit Rs. 100/ connection / month

Small Domestic*

(i) For consumption upto first 50 units per month Rs. 3.85/ unit Rs. 100/ connection / month

*Note: The BPL and Astha card Holder domestic tariff shall be exclusively applicable to individual consumer person and shall not be applicable to any institution. In case any BPL, Astha Card Holder and Small Domestic consumers has consumed more than 50 unit per month in any billing cycle, the consumer will be charged as per the applicable tariff of the respective slab under the LT-I domestic category for the additional units consumed.

General Domestic-1 Domestic Category

Particulars Approved Tariff General Domestic-1 (Consumption upto 150 units/month)


(i) For consumption upto first 50 units per month Rs. 3.85/ unit

Rs. 200/ connection / month (ii) For consumption above 50 units and upto 150 units per month

Rs. 6.10/ unit

General Domestic-2


General Domestic-2 ( Consumption above 150 units and upto 300 units/month )



Rs. 220/ connection / month (ii)For consumption above 50 units and upto 150 units per month

Rs. 6.10/ unit

(iii)For consumption above 150 units and upto 300 units per month Rs. 6.40/ unit

General Domestic-3


General Domestic-3 (Consumption above 300 and upto 500 units/month)




Rs. 265/ connection / month

(ii)For consumption above 50 units and upto 150 units per month

Rs. 6.10/ unit

(iii)For consumption above 150 units and upto 300 units per month

Rs. 6.40/ unit

(iv)For consumption above 300 units and upto 500 units per month

Rs. 6.70/ unit

General Domestic-4


General Domestic-4 (Consumption above 500 units/month)



Rs. 285/ connection / month

(ii)For consumption above 50 units and upto 150 units per month

Rs. 6.10/ unit

(iii) For consumption above 150 units and upto 300 units per month

Rs. 6.40/ unit

(iv)For consumption above 300 units and upto 500 units per month

Rs. 6.70/ unit

(v)For consumption above 500 units per month Rs. 7.15/ unit

Domestic Category (HT-1)


HT – Domestic (HT-1)


For contract demand over 50 kVA Rs. 6.15/ unit Rs. 190 per kVA of Billing Demand per month

NON-DOMESTIC CATEGORY (LT-2 & HT-2) NDS up to 5 kW of SCL (NDS- type1)

Non-Domestic Category Particulars Approved Tariff

LT-NDS(LT-2) Type1 (Consumption upto 100 units/month)


Consumption upto first 100 units per month Rs. 7.55 /unit

Rs. 230 / connection / month (NDS- type2)



LT-NDS(LT-2)

Type 2 (Consumption above 100 units/month and upto 200 units/month)



Rs. 230 / connection / month Consumption above 100 units and upto 200 unit per month

Rs. 8.00 /unit

(NDS- type 3)

Non-Domestic Category Particulars Approved Tariff LT-NDS(LT-2)

Type 3 (Consumption above 200 units and upto 500 units/month)



Rs. 275 / connection / month Consumption above 100 units and upto 200 unit per month

Rs. 8.00 /unit

Consumption above 200 unit and upto 500 unit per month Rs. 8.35 /unit

(NDS- type 4)

Non-Domestic Category Particulars Approved Tariff LT-NDS(LT-2)

Type 4 (Consumption above 500 units/month)



Rs. 330 / connection / month

Consumption above 100 units and upto 200 unit per month Rs. 8.00 /unit

Consumption above 200 units and upto 500 units per month Rs. 8.35 /unit

Consumption above 500 unit per month Rs. 8.80 /unit

NDS above 5 kW of SCL


NDS above 5 KW of SCL (LT-2)



Rs.95/ KW of SCL / month Consumption above 100 units and upto 200 units per month

Rs. 8.00 /unit

Consumption above 200 units and upto 500 units per month Rs. 8.35 /unit

Consumption above 500 units per month Rs. 8.80 /unit

Rs. 105/ KW of SCL / month Or Rs. 190 per kVA of Billing Demand per month (If SCL is more than

18.65 KW)


NDS –Contract Demand Over 50 kVA

HT-NDS (HT-2) Approved Tariff

For contract demand over 50 kVA Energy Charges Fixed Charges

All units Rs. 8.35 /unit Rs.190/ kVA of Billing Demand per month

PUBLIC STREET LIGHTING (LT-3)

AGRICULTURE (Metered and Flat Rate) (LT-4)

Particulars Approved Tariff

Metered (AG/MS/LT-4) Agriculture Supply Energy Charges Fixed Charges

(i) General (getting supply in block hours)

Rs. 4.75 /unit Rs.15 per HP per Month of SCL

(ii)All others not covered under items (i) and getting supply more than block hours

Rs. 6.05 /unit Rs.30 per HP per Month of SCL

Flat/ unmetered (AG/FR/LT-4)

(i)General (getting supply in block hours)

Rs. 635 HP /Month Rs.15 per HP per Month of SCL

(ii)All others not covered under items (i) above and getting more than block hour supply

Rs. 765 HP /Month Rs.30 per HP per Month of SCL

SMALL INDUSTRIES (LT-5)

Particulars Approved Tariff Small Industrial Service (LT-5) (Load not exceeding 18.65 kW (25HP) Energy Charges Fixed Charges

Upto first 500 units Rs.6.00/ unit Rs. 65/ HP/ month of sanctioned connected load

Above 500 units Rs.6.45/ unit Rs. 65/ HP/ month of sanctioned connected load

MEDIUM INDUSTRIES (LT-6 and HT-3)

Particulars Approved Tariff Energy Charges Fixed Charges

Particulars Approved Tariff

Public Street Lighting Energy Charges Fixed Charges

Population <1 Lakh Rs. 6.55/ unit Rs. 85/ Lamp point/ month subject to a maximum of Rs. 850 /service connection/month

Population = >1 Lakh Rs. 7.05/ unit Rs. 105/ Lamp point/ month subject to a maximum of Rs. 2100 /service connection/month



Medium Industrial Service (LT-6) Rs. 7.00/ unit

Rs. 75 per HP per month of sanctioned connected load

or Rs. 165 per kVA of Billing Demand per month

Medium Industrial Service (HT-3) Rs. 7.00/ unit Rs. 165/ kVA of Billing Demand per month

BULK SUPPLY FOR MIXED LOAD (LT-7 and HT-4)


Schedule ML/LT-7 Rs. 7.00/ unit

Rs. 75 per HP per month of sanctioned connected load

or Rs. 165 per kVA of Billing Demand per month

Schedule ML/HT-4 Rs. 7.00/ unit Rs. 165/kVA of Billing Demand per month

LARGE INDUSTRIES (HT-5) Particulars Approved Tariff


SCL above 150 HP &/or having Contract/Maximum Demand above 125 kVA (HT-5)

Rs. 7.30/ unit Rs. 185/ kVA of Billing Demand per month

General Note: All existing provisions which are not modified by this order, shall continue to be in force.


Annexure E

Power Purchase Quantum and Cost for FY 2016-17 JVVNL AVVNL JdVVNL

Source of Power(Station wise)

Net Gener ation (MU)

Total Ann ual Fixed char ges (Rs Cr.)

Vari able Cost (Rs./ unit


Total Fixed Cost (Rs. Cr.)

Total Vari able Cost (Rs. Cr.)

Total Cost JVV NL (Rs. Cr.)




Total Cost AVVNL NL (Rs. Cr.)




Total Cost JdVVNL NL (Rs. Cr.)

NTPC

ANTA GTPS 120 42 2.82 48 17 14 30 34 12 9 21 38 13 11 24

AURIYA GTPS 45 28 3.39 18 11 6 17 12 8 4 12 14 9 5 14

DADRI GTPS 194 32 2.71 77 13 21 34 54 9 15 24 62 10 17 27

FGUTTPS -I 60 14 2.97 24 6 7 13 17 4 5 9 19 5 6 10

FGUTTPS -II 132 26 2.95 53 10 16 26 37 7 11 18 42 8 12 21

FGUTPP III 88 22 2.91 35 9 10 19 25 6 7 13 28 7 8 15

F.S.T.P.S 53 6 2.55 21 3 5 8 15 2 4 6 17 2 4 6

K.H.S.T.P.S. I 112 17 2.41 45 7 11 18 31 5 8 12 36 6 9 14

K.H.S.T.P.S. & II 523 85 2.25 209 34 47 81 146 24 33 57 167 27 38 65

RHIND STPS 548 56 1.62 219 22 35 58 153 16 25 40 175 18 28 46

RIHAND II 720 63 1.57 288 25 45 70 202 18 32 49 230 20 36 56

RIHAND III 824 120 1.60 330 48 53 101 231 34 37 71 264 38 42 81

SINGUARLI 2115 126 1.44 846 50 121 172 592 35 85 120 677 40 97 137

KHPS-I 347 85 2.17 139 34 30 64 97 24 21 45 111 27 24 51

NCTPS 2 13 3 3.03 5 1 2 3 4 1 1 2 4 1 1 2

NHPC TANAKPUR HEP 32 11 1.66 13 4 2 6 9 3 1 4 10 3 2 5

SALAL HEP 95 6 1.73 38 2 7 9 27 2 5 6 31 2 5 7

CHAMERA-I 420 38 1.22 168 15 20 36 118 11 14 25 134 12 16 28

CHAMERA-II 148 17 1.05 59 7 6 13 41 5 4 9 47 5 5 10

CHAMERA-III 104 26 2.13 42 10 9 19 29 7 6 13 33 8 7 15

URI HEP 245 21 1.41 98 8 14 22 69 6 10 15 78 7 11 18

URI HEP II 172 47 2.95 69 19 20 39 48 13 14 28 55 15 16 31

DHOLIGANGA 95 16 2.35 38 6 9 15 27 4 6 11 30 5 7 12

DULHASTI 255 66 3.28 102 27 33 60 71 19 23 42 82 21 27 48

PARBATI III 77 17 2.74 31 7 8 15 22 5 6 11 25 6 7 12



















SEWA II 55 15 2.35 22 6 5 11 15 4 4 8 18 5 4 9

STATE GEN. & OTHER

RVUN

KTPS(1 to 7) 6628 393 2.54 2651 157 674 831 1856 110 472 582 2121 126 539 665

STPS(1 to 6) 4023 345 3.32 1609 138 534 672 1127 96 374 470 1287 110 427 537

DCCPP 95 9 3.57 38 4 14 17 27 3 9 12 30 3 11 14

CTPP (1&2) 3059 472 1.98 1224 189 242 431 857 132 169 302 979 151 194 345

CTPP (3) 1515 278 2.11 606 111 128 239 424 78 90 167 485 89 102 191

CTPP (4) 1559 246 2.11 624 99 132 230 437 69 92 161 499 79 105 184

GLTPP 2

RGTP(1&2) 432 28 2.91 173 11 50 61 121 8 35 43 138 9 40 49

KaTPP#1 3415 738 2.44 1366 295 333 628 956 207 233 440 1093 236 266 503

KaTPP#2 2116 412 2.44 846 165 206 371 592 115 144 260 677 132 165 297

RGTP 3 936 143 3.09 374 57 116 173 262 40 81 121 300 46 93 138

MAHI 209 43 0.30 83 17 3 20 58 12 2 14 67 14 2 16

MAHI MMH 1 0 3.78 0 0 0 0 0 0 0 0 0 0 0 0

MANGROL 6 0 3.78 2 0 1 1 2 0 1 1 2 0 1 1

STPS MMH 2 0 3.78 1 0 0 0 0 0 0 0 1 0 0 0

Rajwest 5826 1044 1.85 2331 418 431 848 1631 292 301 594 1864 334 345 679

GLTPP

NPCIL

NAPP 328 0 2.58 131 0 34 34 92 0 24 24 105 0 27 27

RAPP-I& II 862 0 2.88 345 0 99 99 241 0 70 70 276 0 79 79

RAPP-III& IV 1073 0 2.87 429 0 123 123 301 0 86 86 343 0 99 99

RAPP-V& VI 528 0 3.53 211 0 75 75 148 0 52 52 169 0 60 60

RAPP-V 0 0 0.00 0 0 0 0 0 0 0 0 0 0 0 0

SHARE PROJECTS BBMB(BHAKRA,DEHAR&PONG 2159 0 0.48 864 0 41 41 605 0 29 29 691 0 33 33 CHAMBAL/SATPURA 756 0 0.00 302 0 0 0 212 0 0 0 242 0 0 0



















RFF 122 0 3.99 122 0 49 49

OTHERS

TEHRI 245 70 2.28 98 28 22 50 69 20 16 35 78 22 18 40

KOTESHWAR 106 21 1.90 43 8 8 16 30 6 6 12 34 7 6 13

Tala 49 0 2.03 19 0 4 4 14 0 3 3 16 0 3 3

SJVNL-NATHPA-JHAKRI 555 88 1.40 222 35 31 66 156 25 22 46 178 28 25 53

Rampur 156 31 1.66 62 12 10 23 44 9 7 16 50 10 8 18

Other Neyveli Lignite Corporation Ltd 1271 309 1.55 508 124 79 203 356 87 55 142 407 99 63 162 Aravali Power Co. Pvt. Ltd. 9 6 4.94 3 2 2 4 2 2 1 3 3 2 1 3

Coastal Gujerat 2529 241 1.43 1011 96 145 241 708 67 101 169 809 77 116 193 Adani Power Rajasthan Ltd. 7871 1193 2.15 3148 477 677 1155 2204 334 474 808 2519 382 542 924 Sasan Power Ltd. 2585 45 1.51 1034 18 156 173 724 12 109 121 827 14 125 139 Karcham Wangtoo 412 0 5.30 165 0 87 87 115 0 61 61 132 0 70 70

NVVN Bundled 2406 214 3.58 962 86 344 430 674 60 241 301 770 68 275 344

NCES

Wind farms 5166 0 4.98 2066 0 1029 1029 1446 0 720 720 1653 0 823 823

Solar 1656 0 4.61 662 0 306 306 464 0 214 214 530 0 244 244

Biomass 729 0 6.64 291 0 194 194 204 0 136 136 233 0 155 155

NEW STATIONS

BHADLA-II 25 0 5.00 10 0 5 5 7 0 3 3 8 0 4 4

PTC (DB) 501 131 1.62 200 52 32 85 140 37 23 59 160 42 26 68

PTC (Maruti) 123 22 1.64 49 9 8 17 35 6 6 12 39 7 6 13



















Short term -3405

4.00 -2107

-843 -843 -1343

-537 -537 44

18 18

Total 66229 7524 25820 3010 6112 9147 18120 2107 4327 6422 22288 2408 5577 7971


Annexure F













Total Cost AVV NL (Rs. Cr.)




Total Cost JdVV NL (Rs. Cr.)

NTPC

ANTA GTPS 120 42 2.87 48 17 14 30 34 12 10 21 38 13 11 24

AURIYA GTPS 45 28 3.46 18 11 6 18 12 8 4 12 14 9 5 14

DADRI GTPS 194 32 2.76 77 13 21 34 54 9 15 24 62 10 17 27

FGUTTPS -I 60 14 3.03 24 6 7 13 17 4 5 9 19 5 6 10

FGUTTPS -II 132 26 3.00 53 10 16 26 37 7 11 18 42 8 13 21

FGUTPP III 88 22 2.97 35 9 10 19 25 6 7 13 28 7 8 15

F.S.T.P.S 53 6 2.60 21 3 6 8 15 2 4 6 17 2 4 6

K.H.S.T.P.S. I 112 17 2.45 45 7 11 18 31 5 8 13 36 6 9 14

K.H.S.T.P.S. & II 523 85 2.30 209 34 48 82 146 24 34 57 167 27 38 66

RHIND STPS 548 56 1.65 219 22 36 59 153 16 25 41 175 18 29 47

RIHAND II 720 63 1.60 288 25 46 71 202 18 32 50 230 20 37 57

RIHAND III 824 120 1.63 330 48 54 102 231 34 38 71 264 38 43 82

SINGUARLI 2115 126 1.46 846 50 124 174 592 35 87 122 677 40 99 139

KHPS-I 347 85 2.21 139 34 31 65 97 24 21 45 111 27 25 52

NCTPS 2 13 3 3.09 5 1 2 3 4 1 1 2 4 1 1 2

NHPC

TANAKPUR HEP 32 11 1.70 13 4 2 6 9 3 2 5 10 3 2 5

SALAL HEP 95 6 1.76 38 2 7 9 27 2 5 6 31 2 5 7

CHAMERA-I 420 38 1.24 168 15 21 36 118 11 15 25 134 12 17 29

CHAMERA-II 148 17 1.07 59 7 6 13 41 5 4 9 47 5 5 10

CHAMERA-III 104 26 2.17 42 10 9 19 29 7 6 13 33 8 7 15

URI HEP 245 21 1.44 98 8 14 22 69 6 10 16 78 7 11 18

URI HEP II 172 47 3.01 69 19 21 40 48 13 15 28 55 15 17 32

DHOLIGANGA 95 16 2.39 38 6 9 15 27 4 6 11 30 5 7 12

DULHASTI 255 66 3.35 102 27 34 61 71 19 24 42 82 21 27 49

PARBATI III 77 17 2.80 31 7 9 16 22 5 6 11 25 6 7 13

SEWA II 55 15 2.40 22 6 5 11 15 4 4 8 18 5 4 9



















STATE GEN. & OTHER

RVUN

KTPS(1 to 7) 6628 405 3.02 2651 162 802 964 1856 113 561 675 2121 130 641 771

STPS(1 to 6) 4023 344 3.81 1609 138 613 750 1127 96 429 525 1287 110 490 600

DCCPP 95 9 3.43 38 3 13 16 27 2 9 12 30 3 10 13

CTPP (1&2) 3059 456 2.38 1224 183 291 474 857 128 204 332 979 146 233 379

CTPP (3) 1515 273 2.31 606 109 140 249 424 76 98 175 485 87 112 200

CTPP (4) 1559 246 2.31 624 98 144 243 437 69 101 170 499 79 115 194

GLTPP 2 0

RGTP(1&2) 432 28 1.84 173 11 32 43 121 8 22 30 138 9 25 34

KaTPP#1 3415 705 2.56 1366 282 349 631 956 197 245 442 1093 225 280 505

KaTPP#2 2116 395 2.55 846 158 216 374 592 111 151 262 677 126 173 299

RGTP 3 936 137 3.07 374 55 115 170 262 38 81 119 300 44 92 136

MAHI 209 45 0.30 83 18 3 21 58 13 2 14 67 15 2 17

MAHI MMH 1 0 3.78 0 0 0 0 0 0 0 0 0 0 0 0

MANGROL 6 0 3.78 2 0 1 1 2 0 1 1 2 0 1 1

STPS MMH 2 0 3.78 1 0 0 0 0 0 0 0 1 0 0 0

Rajwest 5826 1121 2.09 2331 448 487 935 1631 314 341 655 1864 359 389 748

GLTPP 0 0 1.00 0 0 0 0 0 0 0 0 0 0 0 0

NPCIL

NAPP 328 0 2.63 131 0 34 34 92 0 24 24 105 0 28 28

RAPP-I& II 862 0 2.94 345 0 101 101 241 0 71 71 276 0 81 81

RAPP-III& IV 1073 0 2.93 429 0 126 126 301 0 88 88 343 0 101 101

RAPP-V& VI 528 0 3.60 211 0 76 76 148 0 53 53 169 0 61 61

RAPP-V 0

SHARE PROJECTS BBMB(BHAKRA,DEHAR&PONG 2159 0 0.49 864 0 42 42 605 0 30 30 691 0 34 34 CHAMBAL/SATPURA 756 0 0.00 302 0 0 0 212 0 0 0 242 0 0 0



















RFF 122 0 4.07 122 0 50 50 0 0 0 0 0 0 0 0

OTHERS

TEHRI 245 70 2.33 98 28 23 51 69 20 16 35 78 22 18 41

KOTESHWAR 106 21 1.93 43 8 8 17 30 6 6 12 34 7 7 13

Tala 49 0 2.07 19 0 4 4 14 0 3 3 16 0 3 3

SJVNL-NATHPA-JHAKRI 555 88 1.43 222 35 32 67 156 25 22 47 178 28 25 54

Rampur 156 31 1.69 62 12 11 23 44 9 7 16 50 10 8 18

Other Neyveli Lignite Corporation Ltd 1271 309 1.58 508 124 80 204 356 87 56 143 407 99 64 163 Aravali Power Co. Pvt. Ltd. 9 6 5.04 3 2 2 4 2 2 1 3 3 2 1 3

Coastal Gujerat 2529 241 1.46 1011 96 148 244 708 67 103 171 809 77 118 195 Adani Power Rajasthan Ltd. 7871 1193 2.19 3148 477 691 1168 2204 334 484 818 2519 382 553 934 Sasan Power Ltd. 2585 45 1.54 1034 18 159 177 724 12 111 124 827 14 127 141 Karcham Wangtoo 412 0 5.40 165 0 89 89 115 0 62 62 132 0 71 71

NVVN Bundled 2406 214 3.76 962 86 362 447 674 60 253 313 770 68 289 358

NCES

Wind farms 5016 0 4.98 2007 0 999 999 1405 0 699 699 1605 0 799 799

Solar 2906 0 4.61 1162 0 536 536 814 0 375 375 930 0 429 429

Biomass 795 0 6.64 318 0 211 211 223 0 148 148 254 0 169 169

NEW STATIONS

BHADLA-II 25 0 5.00 10 0 5 5 7 0 3 3 8 0 4 4

PTC (DB) 501 131 1.65 200 52 33 86 140 37 23 60 160 42 26 68

PTC (Maruti) 123 22 1.67 49 9 8 17 35 6 6 12 39 7 7 13

Short Term -3273

4.00 -2883

-1153 -1153 -1632

-653 -653 1243

497 497



















Total 67529 7536 2.61 25511 3014 6425 9466 18158 2110 4648 6746 23860 2412 6555 8953

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