BEFORE
THE HON’BLE BIHAR ELECTRICITY REGULATORY COMMISSION
FILING OF THE PETITION FOR TRUE UP FOR FY 2016-17,
ANNUAL PERFORMANCE REVIEW (APR) FOR FY 2017-18
AND
ANNUAL REVENUE REQUIREMENT (ARR) FOR FY 2018-19
FILED BY, NORTH BIHAR POWER DISTRIBUTION COMPANY LIMITED, PATNA
CHIEF ENGINEER (COMMERCIAL), NBPDCL
3rd FLOOR, VIDYUT BHAWAN, BAILEY ROAD, PATNA - 800 001 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
BEFORE THE BIHAR ELECTRICITY REGULATORY COMMISSION, PATNA
IN THE MATTER OF: Filing of the Petition for True up for FY 2016-17, Annual Performance Review (APR) for FY 2017-18, Annual Revenue Requirement (ARR) for FY 2018-19 under Bihar Electricity Regulatory Commission (Multi Year Distribution Tariff) Regulations, 2015 and its amendments thereof along with the other guidelines and directives issued by the BERC from time to time and under Section 45, 46, 47, 61, 62, 64 and 86 of The Electricity Act, 2003 read with the relevant guidelines.
AND IN THE MATTER OF: North Bihar Power Distribution Company Limited (hereinafter referred to as "NBPDCL” or “Petitioner” which shall mean for the purpose of this petition the Licensee),having its registered office at Vidyut Bhawan, Bailey Road, Patna.
The Petitioner respectfully submits as under: -
1. The Petitioner was formerly integrated as a part of the Bihar State Electricity Board (hereinafter referred to as “BSEB” or “Board”) which was engaged in electricity generation, transmission, distribution and related activities in the State of Bihar. 2. The Board is now unbundled into five (5) successor companies – Bihar State Power (Holding) Company Limited, Bihar State Power Generating Company Limited (hereinafter referred to as “BSPGCL”), Bihar State Power Transmission Company Limited (hereinafter referred to as “BSPTCL”), North Bihar Power Distribution Company Limited and South Bihar Power Distribution Company Limited (hereinafter referred to as “Discoms”) as per Energy Department,
Government of Bihar Notification no: under The Bihar State Electricity Reforms Transfer Scheme 2012. 3. Pursuant to the enactment of the Electricity Act, 2003, every utility is required to submit its Aggregate Revenue Requirement (ARR) for the control period and Tariff Petitions as per procedures outlined in section 61, 62 and 64, of Electricity Act, 2003, and the governing regulations thereof. 4. The Petition for True-up for FY 2015-16, Annual Performance Review (APR) for the FY 2016- 17 and Annual Revenue Requirement (ARR) for FY 2017-18 was filed by North Bihar Power Distribution Company Limited (NBPDCL) on 06.12.2016, and accordingly the Hon’ble Commission had issued the relevant tariff order on 24.03.2017. 5. The present petition is filed with the Hon’ble Commission for True up for FY 2016-17, Annual Performance Review (APR) of FY 2017-18, and estimating the Annual Revenue Requirement (ARR) for FY 2018-19. 6. This Petition has been prepared in accordance with the provisions of Sections 61 and 62 of the Electricity Act, 2003 and has taken into consideration the Bihar Electricity Regulatory
North Bihar Power Distribution Company Limited Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
Commission (Multi Year Distribution Tariff) Regulations, 2015, Bihar Electricity Regulatory Commission (Multi Year Distribution Tariff) (First Amendment) Regulations, 2017, other amendments and orders issued by the Hon’ble Commission from time to time. 7. NBPDCL along with this petition is submitting the regulatory formats with data & information to an extent applicable and would make available any further information/ additional data required by the Hon’ble Commission during the course of proceedings.
Prayers to the Commission: The Petitioner respectfully prays that the Hon’ble Commission may: a. Admit this Petition; b. Examine the proposal submitted by the Petitioner in the enclosed petition for a favourable dispensation; c. Approve the Annual Revenue Requirement (ARR) for FY 2018-19 under Bihar Electricity Regulatory Commission (Multi Year Distribution Tariff) Regulations, 2015, Bihar Electricity Regulatory Commission (Multi Year Distribution Tariff) (First Amendment) Regulations, 2017, other amendments and orders issued by the Hon’ble Commission from time to time. d. Pass suitable Orders with respect to the True up for FY 2016-17, Annual Performance Review (APR) for FY 2017-18, and Annual Revenue Requirement (ARR) for FY 2018- 19. e. Approve the proposed tariff schedule along with open access charges and the schedule for general and miscellaneous charges as proposed in this petition for different category of consumers to be made applicable from 1st April, 2018. f. Pass separate Order for the Petitioner against the present petition; g. NBPDCL may also be permitted to propose suitable changes to the respective ARRs, prior to the final approval by the Hon’ble Commission. NBPDCL believes that such an approach would go a long way towards providing a fair treatment to all the stakeholders and may eliminate the need for a review or clarification. h. Condone any inadvertent omissions / errors / shortcomings and permit NBPDCL to add / change / modify / alter this filing and make further submissions as may be required at a future date. i. Pass such Order, as the Hon’ble Commission may deem fit and appropriate keeping in view the facts and circumstances of the case.
North Bihar Power Distribution Company Limited, Patna Petitioner Location: Patna Date: 05/12/2017
North Bihar Power Distribution Company Limited Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
Table of Contents
1. Introduction...... 11 1.1. Background ...... 11 1.2. Profile of NBPDCL ...... 12 1.3. Procedural History...... 14 1.4. Judgment of Hon’ble APTEL on Appeal No. 141 and Appeal No. 142 of 2016...... 15 1.5. BERC Order against the Judgment of Hon’ble APTEL on Appeal No. 141 and Appeal No. 142 of 2016 17 1.6. Appeal No. 154 and Appeal No. 155 of 2017 ...... 17 1.7. Instant Petition ...... 17 1.8. Contents of the Petition...... 18 2. Overall approach for present filing...... 19 2.1. Present Approach ...... 19 2.2. Data and information sources for estimating the Aggregate Revenue Requirement ...... 19 3. True-up Summary for FY 2016-17 ...... 20 3.1. Preamble...... 20 3.2. Number of Consumers, Connected Load and Sales ...... 20 3.3. Distribution Loss...... 26 3.4. Transmission losses...... 27 3.5. Power Purchase...... 27 3.6. Actual Power Purchase quantum...... 28 3.7. Energy Balance...... 30 3.8. Power Purchase Cost ...... 31 3.9. Transmission charges ...... 35 3.10. Disallowance of power purchase due to excess Distribution loss ...... 35 3.11. Capital Investment Plan, Capitalization and Funding ...... 37 3.12. Gross Fixed Assets ...... 38 3.13. Depreciation ...... 38 3.14. Other finance charges...... 39 3.15. Operation & Maintenance charges ...... 40 3.16. Interest on working capital ...... 43 3.17. Return on Equity ...... 45 3.18. Interest on Loans ...... 45 3.19. Interest on Consumer Security Deposit ...... 47 3.20. Net Prior Period Credit / (Charges)...... 48 3.21. Provision for RPO ...... 48 3.22. Non-Tariff income...... 48 3.23. Revenue from Sale of Power at Existing Tariff ...... 49 3.24. Net ARR and revenue gap for FY 2016-17...... 50 4. APR Summary for FY 2017-18 ...... 52 4.1. Preamble...... 52
North Bihar Power Distribution Company Limited Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
4.2. Estimate of category wise number of consumers, connected load and sales for FY 2017-18...... 52 4.3. Distribution Loss...... 55 4.4. State Transmission losses ...... 56 4.5. Central Transmission Loss...... 56 4.6. Power Purchase...... 56 4.7. Energy Balance...... 62 4.8. Power Purchase Cost ...... 64 4.9. Transmission Charges ...... 68 4.10. Capital Investment Plan, Capitalization and Funding ...... 68 4.11. Operation & Maintenance (O&M) Expenses...... 70 4.12. Gross Fixed Assets ...... 75 4.13. Depreciation on Gross Fixed Assets...... 75 4.14. Return on Equity ...... 77 4.15. Interest on Consumer Security Deposit ...... 78 4.16. Interest on Working Capital...... 79 4.17. Subsidy Details ...... 80 4.18. Non-Tariff Income ...... 80 4.19. Interest on Normative Debt ...... 81 4.20. Other Finance Charges...... 82 4.21. Revenue from Sale of Power at Existing Tariff for FY 2017-18 ...... 82 4.22. Net ARR and Revenue Gap for FY 2017-18...... 83 5. Annual Revenue Requirement (ARR) for FY 2018-19 ...... 86 5.1. Preamble...... 86 5.2. Historical Assessment of Number of Consumers and Sales ...... 86 5.3. Projected Sales (MU), Number of Consumers and Connected Load for FY 2018-19...... 87 5.4. Detailed category-wise projections for ARR period FY 2018-19 ...... 91 5.5. Distribution Loss ...... 98 5.6. State Transmission Losses ...... 101 5.7. Central Transmission Losses ...... 101 5.8. Power Purchase...... 101 5.9. Renewable Power Purchase Obligation...... 105 5.10. Energy Balance...... 106 5.11. Power Purchase Cost ...... 107 5.12. Transmission Charges ...... 112 5.13. Capital Investment Plan, Capitalization and Funding ...... 112 5.14. Gross Fixed Assets ...... 114 5.15. Depreciation on GFA...... 115 5.16. Interest on project Loans ...... 116 5.17. Other Financial Charges...... 118 5.18. Operation & Maintenance (O&M) Expenses...... 119 5.19. Return on Equity...... 122 5.20. Interest on Consumer Security Deposit...... 123 5.21. Interest on Working Capital ...... 124 North Bihar Power Distribution Company Limited Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
5.22. Non-Tariff Income...... 126 5.23. Revenue from Sale of Power at Existing Tariff ...... 126 5.24. Net ARR for FY 2018-19 ...... 127 5.25. Net Gap at Existing Tariff...... 128 5.26. Revenue from Sale of Power at Proposed Tariff ...... 128 5.27. Revenue gap for FY 2018-19 at proposed tariff ...... 129 6. Revenue Gap and Regulatory Asset...... 130 6.1. Background ...... 130 7. Voltage-wise cost of supply ...... 133 7.1. Preamble...... 133 7.2. Background ...... 133 7.3. Methodology adopted for Computation of Voltage wise Cost of Supply...... 133 7.4. Determination of Voltage wise Losses ...... 134 7.5. Information required for arriving Voltage Wise Cost of Supply ...... 135 7.6. Methodology adopted for determination of Cost of Supply...... 136 8. Miscellaneous and General Charges...... 139 8.1. Schedule of Miscellaneous and General Charges ...... 139 8.2. Meter Rent...... 139 8.2.1. Background ...... 139 8.2.2. Existing Meter Rent ...... 140 8.2.3. Meter Cost...... 141 8.2.4. Meter Cost Realization ...... 142 8.2.5. Requirement for revising existing Meter Rent...... 142 8.2.6. State wise Comparison of Meter rent and Understanding...... 143 8.2.7. Proposed Monthly Meter Rent...... 146 8.3. SLC charges...... 147 8.4. Security Deposit ...... 149 8.5. Interest on Security Deposit...... 149 9. Proposed Tariff Schedule for FY 2018-19 ...... 150 9.1. Simplification of tariff structures for electricity consumers in Bihar ...... 150 9.3. Terms and Conditions of Low Tension Tariff...... 162 10. Wheeling and Open Access Charges ...... 171 10.1. Background ...... 171 10.4. Wheeling Charges...... 171 10.5. Cross Subsidy Surcharge ...... 173 10.6. Reactive Energy charges ...... 174 10.7. Standby Charges ...... 174 10.8. Roadmap for reduction of Cross Subsidy Surcharge ...... 174 11. Implementation of UDAY ...... 176 11.1. Background ...... 176 11.2. Overview of the scheme...... 176 Annexure A – Additional Formats...... 184 A.1. Annexure – I– Profile of NBPDCL ...... 184 North Bihar Power Distribution Company Limited Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
A.2. Annexure – II (A) – Category wise Number of Consumers in past 4 years...... 184 A.3. Annexure – II (B) – Category wise sanctioned / contracted Load in past 4 years...... 185 A.4. Annexure – II (C) – Category wise Energy sales in past 4 years...... 185 A.5. Annexure – II (D) – Category wise Number of Consumers of Muzaffarpur DF in past 4 years ...... 186 A.6. Annexure – II (E) – Category wise sanctioned / contracted Load of Muzzaffarpur DF in past 4 years187 A.7. Annexure – II (F) – Category wise Energy sales of Muzzafarpur DF in past 4 years ...... 187 A.8. Annexure – III : Input Energy to DF Muzzafarpur...... 188 A.9. Annexure – IV : RPO Obligation achieved during FY 2016-17 ...... 188 A.10. Annexure – V : Resource Gap Grants received from state government in FY 2016-17 ...... 189 A.11. Annexure – VI : Open Access consumers during FY 2016-17...... 189 A.12. Annexure – VII : Demand based LT Consumers during FY 2016-17...... 189 A.13. Annexure – VIII : Rebate or Late Payment Charges during FY 2016-17 ...... 189 A.14. Annexure – IX : Details of Energy Scheduled and Actual drawal during FY 2016-17 ...... 190 A.15. Annexure – X : Details of Energy Sale during 1st half of FY 2017-18 ...... 190 A.16. Annexure – XI : Details of Central and State transmission losses during FY 2016-17 ...... 194 A.17. Annexure – XII (A) : Scheme-wise details of capital expenditure and capitalization along with source of funding for FY 2016-17 ...... 195 A.18. Annexure – XII (B) : Scheme-wise details of capital expenditure and capitalization along with source of funding for FY 2017-18 ...... 197 A.19. Annexure – XII (C) : Scheme-wise details of capital expenditure and capitalization along with source of funding for FY 2018-19 ...... 199 A.20. Annexure – XIII : Revenue at existing tariff for FY 2018-19 ...... 201 A.21. Proforma- I: Month-wise, Category-Wise energy sales during FY 2015-16...... 203 A.22. Proforma-II: Month-wise, Category-Wise energy sales during FY 2016-17...... 205 A.23. Proforma-III: Month-wise, Category-Wise energy sales during FY 2017-18...... 207 A.24. Proforma- IV: Month-wise, Station/source-Wise energy procurement during FY 2015-16 ...... 211 A.25. Proforma-V: Month-wise, Station/source-Wise energy procurement during FY 2016-17 ...... 213 A.26. Proforma-VI: Month-wise, Station/source-Wise energy procurement during FY 2017-18 ...... 215 A.27. Proforma- VII: Month-wise, Station/source-Wise energy procurement during FY 2018-19 ...... 218 Annexure B – Additional data submission to BERC...... 221
North Bihar Power Distribution Company Limited Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
List of Tables
Table 1: Existing distribution infrastructure of NBPDCL...... 12 Table 2: Discoms’ Areas and Circles...... 13 Table 3: Discoms’ Circles & Other Establishment...... 13 Table 4: Procedural History of Filing ...... 14 Table 5: Highlights of the Hon’ble APTEL Judgment dated 25.11.2016 ...... 16 Table 6: Number of Consumers as on 31st March 2017...... 20 Table 7: No. of Consumers of Muzaffarpur Distribution Franchisee ...... 21 Table 8: Total connected load (in kW) as on 31st March 2017...... 22 Table 9: Total connected load (in kW) of Muzaffarpur Distribution Franchisee Area...... 23 Table 10: Total Energy Sales (in MU) for FY 2016-17 ...... 24 Table 11: Total Energy Sales for FY 2016-17 ...... 25 Table 12: Total Energy Sales (in MU) for Muzaffarpur Distribution Franchisee...... 25 Table 13: Distribution Losses (in %)...... 26 Table 14: Renewable Purchase Obligation (%) ...... 28 Table 15: RPO met for FY 2016-17 (in INR Crore) ...... 28 Table 16: Actual Power Purchased (MU) in FY 2016-17 ...... 28 Table 17: Energy balance (MU) in FY 2016-17...... 30 Table 18: Actual Power Purchased (MU) in FY 2016-17 ...... 33 Table 19: PGCIL, POSCO and ERLDC charges...... 35 Table 20: State transmission charges ...... 35 Table 21: Disallowance of power purchase cost due to excess distribution loss (in INR Crore) ...... 37 Table 22: CWIP, Capex, Capitalization and Funding (in INR Crore) ...... 37 Table 23: Gross Fixed Assets (in INR Crore)...... 38 Table 24: Depreciation (in INR Crore) ...... 39 Table 25: Other Finance charges (in INR Crore) ...... 40 Table 26: Employee expenses (in INR Crore)...... 40 Table 27: R&M expenses (in INR Crore)...... 41 Table 28: A&G expenses (in INR Crore) ...... 42 Table 29: Holding cost (in INR Crore) ...... 42 Table 30: O&M expenses (in INR Crore)...... 43 Table 31: Interest on working capital (in INR Crore) ...... 44 Table 32: Return on equity (in INR Crore)...... 45 Table 33: Interest on Loans Claimed for FY 2016-17 (in INR Crore)...... 46 Table 34: Interest on Loans Claimed for FY 2016-17 (in INR Crore)...... 46 Table 35: Interest on Consumer Security Deposit (in INR Crore) ...... 47 Table 36: Prior period (expense)/income (in INR Crore)...... 48 Table 37: Provision of RPO (in INR Crore)...... 48 Table 38: Non-tariff income (in INR Crore)...... 48 Table 39: Revenue from sale of power at existing tariff ...... 49 Table 40: Net ARR and revenue gap for FY 2016-17 (in INR Crore)...... 50 Table 41: Category-wise no. of consumers projected for FY 2017-18...... 52
North Bihar Power Distribution Company Limited Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
Table 42: Category-wise sales (MUs) projected for FY 2017-18 ...... 54 Table 43: Category-wise connected load (kW) for FY 2017-18 ...... 54 Table 44: Distribution loss trajectory ...... 56 Table 45: Details of RPO to be met for APR ...... 57 Table 46: Power purchase Allocation projected for FY 2017-18 (in MW) ...... 58 Table 47: Total power purchase for APR (in MU) ...... 61 Table 48: Energy Balance for APR FY 2017-18...... 63 Table 49: Power Purchase Projection for APR (in MW)...... 65 Table 50: Transmission charges for APR (in INR Crore) ...... 68 Table 51: Capitalization plan for FY 2017-18 (in INR Crore)...... 69 Table 52: CWIP, Capitalization and Funding of Capitalization projected for FY 2017-18 (in INR Crore) ...... 70 Table 53: Employee Expenses for APR (in INR Crore)...... 71 Table 54: Calculation of “K” Factor for FY 2017-18...... 72 Table 55: R&M Expenses for APR (in INR Crore)...... 72 Table 56: A&G Expenses for APR (in INR Crore) ...... 73 Table 57: Allocation of Holding Company Cost for APR (in INR Crore)...... 74 Table 58: Summary of O&M Expenses for APR (in INR Crore)...... 74 Table 59: Summary GFA for FY 2017-18 (in INR Crore) ...... 75 Table 60: Depreciation on GFA for APR (in INR Crore)...... 76 Table 61: Return on equity for APR (in INR Crore) ...... 77 Table 62: Interest on consumer security deposit (in INR Crore) ...... 78 Table 63: Interest on working capital for APR (in INR Crore)...... 79 Table 64: Non-tariff income for APR (in INR Crore) ...... 80 Table 65: Net-Non-tariff income for APR (in INR Crore) ...... 80 Table 66: Computation of weighted average rate of interest on project loans...... 81 Table 67: Interest on Normative debt (in INR Crore)...... 82 Table 68: Other finance charges (in INR Crore)...... 82 Table 69: Revenue from sales of power at existing tariff for FY 2017-18 (in INR Crore)...... 83 Table 70: Revenue requirement for FY 2017-18 (in INR Crore) ...... 84 Table 71: Net ARR & Revenue Gap for FY 2017-18 (in INR Crore) ...... 84 Table 72: Unrecovered Gap for FY 2016-17 (in INR Crore)...... 85 Table 73: Category wise number of consumer for past few years ...... 86 Table 74: Category wise sales for the past few years (in MU)...... 87 Table 75: Category-wise no. of consumers projected for FY 2018-19...... 88 Table 76: Category-wise sales projected for FY 2018-19 ...... 89 Table 77: Category-wise connected load (kW) projected for FY 2018-19 ...... 89 Table 78: Distribution Loss Trajectory ...... 100 Table 79: Power purchase Quantum for FY 2018-19 (in MW)...... 102 Table 80: Total power purchase (MU) for FY 2018-19...... 104 Table 81: Renewable energy purchase obligation for FY 2018-19 ...... 106 Table 82: Energy Balancing for ARR for FY 2018-19 ...... 107 Table 83: Detailed power purchase costs for FY 2018-19 (in INR Crore)...... 109 Table 84: Transmission charges for ARR (in INR Crore) ...... 112 North Bihar Power Distribution Company Limited Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
Table 85: Capitalization in FY 2018-19 (in INR Crore)...... 113 Table 86: Capital works in progress for ARR (in INR Crore)...... 113 Table 87: GFA for ARR (in INR Crore) ...... 114 Table 88: Depreciation on GFA (in INR Crore) ...... 115 Table 89: Detailed loan schedule for ARR (in INR Crore)...... 117 Table 90: Weighted Average rate of Interest on project loans for FY 2018-19 ...... 117 Table 91: Interest on normative debt for ARR (in INR Crore) ...... 118 Table 92: Other finance charges (in INR Crore)...... 119 Table 93: Employee numbers for ARR...... 119 Table 94: Employee expenses for ARR (in INR Crore)...... 120 Table 95: Calculation of “K” Factor for FY 2018-19...... 120 Table 96: R&M Expenses for APR (in INR Crore)...... 121 Table 97: A&G expenses for ARR (in INR Crore) ...... 121 Table 98: Holding company cost for ARR (in INR Crore)...... 122 Table 99: Return on equity for ARR (in INR Crore)...... 123 Table 100: Interest on consumer security deposits (in INR Crore) ...... 124 Table 101: Interest on working capital for ARR (in INR Crore) ...... 125 Table 102: Non-tariff income for ARR (in INR Crore)...... 126 Table 103: Revenue from sale of power at existing tariff for ARR (in INR Crore)...... 126 Table 104: Net ARR for FY 2018-19 (in INR Crore)...... 127 Table 105: Unrecovered revenue Gap for FY 2017-18 ...... 128 Table 106: Net revenue gap at existing tariff...... 128 Table 107: Total revenue from sale of power at proposed tariff ...... 128 Table 108: The revenue gap at proposed tariff for FY 2018-19 ...... 129 Table 109: Revenue Gap approved by the Commission for BSPHCL (in INR Crore) ...... 130 Table 110: Revenue Gap approved by the Commission up to FY 2013-14 for BSPHCL (in INR Crore) ...... 130 Table 111: Revenue Gap approved by the Hon’ble Commission up to FY 2013-14 for BSHPCL (in INR Crore) ...... 131 Table 112: Voltage wise Technical losses considered for FY 2018-19...... 135 Table 113: Classification of Categories on the basis of Voltage of power supply...... 135 Table 114: Voltage wise Technical losses considered for FY 2018-19...... 136 Table 115: Apportionment of technical losses to voltage wise sale ...... 136 Table 116: Apportionment of Commercial losses to voltage wise sale ...... 136 Table 117: Allocation of power purchase cost to the total energy sales ...... 137 Table 118: Allocation of Network Cost ...... 137 Table 119: Cost of Supply at different Voltage Levels ...... 137 Table 120: Existing Monthly Meter Rent...... 140 Table 121: Procurement cost of Meters ...... 141 Table 122: Cost Recovery time of meters (in Years) ...... 142 Table 123: Comparison of meter rents across states in India ...... 145 Table 124: Proposed Monthly Meter Rent...... 146 Table 125: Application fee...... 147 Table 126: Meter testing fee ...... 147 North Bihar Power Distribution Company Limited Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
Table 127: Meter testing fee for own installation ...... 147 Table 128: Removal/ refixing/ change of meter fee...... 148 Table 129: Reconnection charges ...... 148 Table 130: Supervision, labour and establishment charges for service connection ...... 148 Table 131: Proposed tariff structure for KJ category ...... 151 Table 132: Proposed tariff structure for DS category ...... 152 Table 133: Proposed tariff structure for NDS category ...... 153 Table 134: Proposed tariff structure for IAS category ...... 154 Table 135: Proposed tariff structure for LTIS category ...... 154 Table 136: Proposed tariff structure for PWW category...... 155 Table 137: Proposed tariff structure for SS category ...... 155 Table 138: Proposed tariff structure for HT category ...... 156 Table 139: Proposed tariff structure for RTS category...... 156 Table 140: Tariff schedule considering ‘Zero’ GoB Subsidy ...... 158 Table 141: Net tariff to consumer considering same per unit GoB subsidy as provided for FY 2017-18 ...... 159 Table 143: Proposed tariff rate for seasonal supply...... 169 Table 144: Allocation Matrix ...... 171 Table 145: Segregation of Wires and Retail Supply Costs ...... 172 Table 146: Wheeling Charges at 33 kV for FY 2018-19...... 172 Table 147: Wheeling charges at 11 kV for FY 2018-19 ...... 172 Table 148: Power purchase cost for FY 2018-19...... 173 Table 149: Roadmap for reduction in cross subsidy ...... 175 Table 150: Targets defined under UDAY for NBPDCL ...... 177 Table 151: Progress made by NBPDCL as against UDAY targets ...... 179
North Bihar Power Distribution Company Limited Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
1. Introduction
1.1. Background
1.1.1. Bihar State Electricity Board (“Board” or “BSEB”) originally constituted on 1st April 1958 under Section 5 of the Electricity (Supply) Act, 1948 and was engaged in the management of electricity generation, transmission, distribution and related activities in the State of Bihar.
1.1.2. Under the new 'Bihar State Electricity Reforms Transfer Scheme 2012', the BSEB has been unbundled into five companies: a. Bihar State Power (Holding) Company Limited (BSPHCL), b. Bihar State Power Transmission Company Limited (BSPTCL), c. Bihar State Power Generation Company Limited (BSPGCL), d. South Bihar Power Distribution Company Limited (SBPDCL), e. North Bihar Power Distribution Company (NBPDCL) with effect from 1st November’ 2012 vide notification no.
dated 30-10-2012.
a) “Bihar State Power (Holding) Company Limited” means the Company that will own shares of newly incorporated reorganized four companies i.e. Bihar State Power Generation Company Limited, Bihar State Power Transmission Company Limited, South Bihar Power Distribution Company Limited, and North Bihar Power Distribution Company Limited
b) “Bihar State Power Generation Company Limited” means the Generating Company to which the Generating Undertakings of the Board are to be transferred in accordance with this Scheme
c) “Bihar State Power Transmission Company Limited” means the Transmission Company to which the Transmission Undertakings of the Board are to be transferred in accordance with this Scheme
d) “South Bihar Power Distribution Company Limited” And “North Bihar Power Distribution Company Limited”, collectively mean the Distribution Companies, to which the Distribution Undertakings of the Board are to be transferred in accordance with this Scheme.
1.1.3. This Petition is being submitted separately by “North Bihar Power Distribution Company Limited”.
North Bihar Power Distribution Company Limited 11 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
1.2. Profile of NBPDCL
1.2.1. NBPDCL is a company registered under the provisions of the Companies Act 1956 and is a fully owned subsidiary Company of BSPHCL.
1.2.2. NBPDCL is engaged primarily in the business of distribution and retail supply of electricity. It has been vested with the distribution assets, interest in property, rights and liabilities of the erstwhile BSEB necessary for the business of distribution in its area of distribution comprising of all 7 circles of North Bihar.
1.2.3. NBPDCL has been given the status of a Distribution Licensee as per Section 14 of the Electricity Act, 2003, in order to fulfil the obligations of the Distribution Licensee as mandated under the provisions of the Bihar State Electricity Reforms Transfer Scheme 2012 and the Electricity Act, 2003.
1.2.4. The Bihar State Electricity Reforms Transfer Scheme, 2012 details out the following for the distribution business of NBPDCL: Schedule-C, Part-I: Description of Assets, Liabilities etc.;
Schedule-C, Part-II: Provisional Balance Sheet as on 1st November 2012;
Schedule-C, Part-III: Function and Duties of NBPDCL.
1.2.5. NBPDCL has divided its area of supply into 7 Distribution Circles which further comprises of 28 divisions and 80 subdivisions.
1.2.6. The Petitioner has a total consumer base of 62.96 lakhs as on 31st March 2017.
1.2.7. The details of the existing distribution infrastructure of the Petitioner as on 31st March 2017 are tabulated below for reference:
Table 1: Existing distribution infrastructure of NBPDCL
S. No. Particulars Unit Quantity 1 No. of electrified villages No 19,816 2 No. of consumers No 6,296,205 3 No. of capacity of 33/11 kV Substations No/MVA 354/5,218.7 MVA 4 No. of capacity of 11/0.4 kV 3 phase Transformers No/MVA 74,045/5076.82 MVA 5 Length of 33 kV line CKM 5657 6 Length of 11 kV line CKM 59,651 7 Length of LT line CKM 118,713
1.2.8. The two distribution companies were created based on reorientation of seven area offices. The reorientation was done based on regrouping of circles. As such from a circle level and below there is no change from the previous system.
North Bihar Power Distribution Company Limited 12 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
Table 2: Discoms’ Areas and Circles
Area Circle PESU East PESU PESU West Patna Patna Central Bhojpur (Ara) Nalanda Gaya Magadh Rohtas Bhagalpur Bhagalpur Munger Muzaffarpur Tirhut Chapra Motihari Darbhanga Mithila Samastipur Saharsa Kosi Purnea
1.2.9. The four area offices i.e. PESU, Patna central, Magadh and Bhagalpur were regrouped to form one company, i.e. South Bihar Power Distribution Company Limited. Hence the circles – PESU (East), PESU (West), Patna, Ara, Nalanda, Gaya, Rohtas, Bhagalpur and Munger constitute the South Bihar Power Distribution Company Limited (SBPDCL). The remaining three area offices viz. Tirhut, Mithila and Kosi Areas were combined to form another company, i.e. North Bihar Power Distribution Company Limited (NBPDCL). Consequently Muzaffarpur, Chapra, Motihari, Darbhanga, Samastipur, Saharsa and Purnea Circles are combined within the company North Bihar Power Distribution Company Limited.
1.2.10. Apart from these circles there are seven pole factories and seven TRWs (Transformer Repair Workshops) which provide support services to the distribution system. However, with the existing practice, Head of the pole factory and transformer repair workshop report directly to Headquarter and they are not directly a part of the distribution system. The existing TRWs and pole factories have been allocated to the Discom’s in their respective areas of jurisdiction. The final structure of the Discoms is shown in below.
Table 3: Discoms’ Circles & Other Establishment
S. No. Distribution Company Circles and other establishments
1 South Bihar Power Electrical Supply Area: Central (Patna), PESU (Patna) Distribution Company Electric Supply Circles: PESU (East), PESU (West, Patna, Limited, Patna Bhojpur (Ara), Nalanda (Biharsharif) TRW: Patna Pole Factory: Patna and Ara Electrical Supply Area: Magadh (Gaya) Electric Supply Circles: Gaya, Rohtas (Sasaram) TRW: Gaya Pole Factory: Barun, Dandibagh (Gaya)
North Bihar Power Distribution Company Limited 13 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
S. No. Distribution Company Circles and other establishments
Electrical Supply Area: Bhagalpur Electric Supply Circles: Bhagalpur, Munger TRW: Bhagalpur Pole Factory: Bhagalpur 2 North Bihar Power Electrical Supply Area: Kosi (Saharsa) Distribution Company Electric Supply Circles: Saharsa, Purnea Limited, Patna TRW: Katihar, Saharsa Pole Factory: Katihar Electrical Supply Area: Tirhut (Muzaffarpur), Mithula (Darbhanga) Electric Supply Circles: Muzaffarpur, Motihari, Chapra, Darbhanga, Samastipur TRW: Muzaffarpur, Darbhanga Pole Factory: Madhopur, Khabra
1.3. Procedural History
1.3.1. The procedural history of the filings of petition of erstwhile BSEB, BSPHCL and individual companies is tabulated below for ready reference:
Table 4: Procedural History of Filing
S. No. Scope of Filing in Petition Filing Date Order Date Remarks 1 ARR & Tariff Petition for FY 10.04.2006 29.11.2006 - 2006-07 2 ARR & Tariff Petition for FY 18.12.2007 - Delayed filing & hence 2007-08 directed to file petition for FY 2008-09 by 31.01.2008 3 ARR & Tariff Petition for FY 14.02.2008 26.08.2008 Review of FY 2006-07 was 2008-09 also undertaken in this order 4 ARR & Tariff Petition for FY 09.10.2009 - Delayed filing & hence 2009-10 directed to file petition for FY 2010-11. 5 ARR & Tariff Petition for FY 03.02.2010 06.12.2010 Review of FY 2008-09 was 2010-11 also undertaken in this order 6 ARR & Tariff Petition for FY 17.02.2011 01.06.2011 Order effective from 1.5.2011 2011-12 7 True-up Petition for FY 2006- 01.09.2011 04.01.2012 - 07, FY 2007-08 and FY 2008-09
Addendum to this petition 17.10.2011 8 True-up Petition for FY 2009- 13.10.2011 27.01.2012 - 10 9 Review of ARR for FY 2010- 13.10.2011 - Commission directed to file 11 based on provisional petition for review along with accounts petition of FY 2012-13
Submission of Audited 02.03.2012 Accounts for FY 2010-11
Submission of True-up 16.03.2012 petition for FY 2010-11 based on Audited Accounts 10 ARR & Tariff Petition for FY 15.11.2011 30.03.2012 Order included True-up of FY 2012-13 2010-11 & Review of FY 2011-12
North Bihar Power Distribution Company Limited 14 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
S. No. Scope of Filing in Petition Filing Date Order Date Remarks Supplementary petition for 02.01.2012 FY 2012-13 11 Business Plan for Control 20.09.2012 15.03.2013 Commission directed to Period FY 2013-14 to FY submit revise business plan. 2015-16 filed by BSPGCL, BSPTCL and 2 DISCOMs
Revised Business Plan as 14.11.2012 Commission again directed to per Commissions directive submit revised business plan vide letter dated 21.12.2012 Re-Revised Business Plan 03.01.2013 Approved along with MYT for BSPGCL & BSPTCL Order
Re-Revised Business Plan 04.01.2013 for 2 DISCOMs 12 Provisional True-up for 15.11.2012 15.03.2013 Commission issued MYT FY2011-12, Review petition order according to petition for FY 2012-13 and MYT Petition for FY 2013-14 to FY 2015-16 for BSPGCL, BSPTCL and 2 DISCOMs
Revised petition for True-up 24.12.2012 of FY 2011-12 based on Audited Accounts 13 True up for FY 2012-13 by - 28.02.2014 Commission issued Tariff BSPHCL order according to petition
Annual Performance Review for FY 2013-14 and Revised Annual Revenue Requirement for FY 2014-15 for BSPGCL, BSPTCL and 2 DISCOMs 14 True up for FY 2013-14, - 16.03.2015 Commission issued Tariff Annual Performance Review order according to petition for FY 2014-15 and Annual Revenue Requirement for FY 2015-16 for NBPDCL and SBPDCL 15 True-up for FY 2014-15, 15.11.2015 21.03.2016 Commission issued Tariff Annual Performance Review order according to petition, (APR) for the FY 2015-16 but disallowed various claims. Annual Revenue Requirement (ARR) for the control period FY 2016-17 to FY 2018-19 16 True-up for FY 2015-16, 06.12.2016 24.03.2017 Commission issued Tariff Annual Performance Review order according to petition, (APR) for the FY 2016-17 but disallowed various claims. Annual Revenue Requirement (ARR) for FY 2017-18
1.4. Judgment of Hon’ble APTEL on Appeal No. 141 and Appeal No. 142 of 2016
1.4.1. Hon’ble BERC had issued Tariff Order dated 21.03.2016 in response to Petitions filed by the Discoms with regard to True-up of FY 2014-15, the APR for FY 2015-16, and the ARR
North Bihar Power Distribution Company Limited 15 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
for the control period FY 2016-17 to FY 2018-19. In the said Tariff Order Hon’ble Commission had disallowed claims of SBPDCL and NBPDCL in the matter of power Purchase Cost, Depreciation, Return on equity, Sales, Prior Period Expenses etc. Aggrieved by the disallowance made by the Hon’ble Commission in the Tariff Orders dated 21.03.2016 Appeal No. 141 of 2016 and Appeal No. 142 of 2016 were filed by the SBPDCL and NBPDCL respectively before Hon’ble Appellate Tribunal for Electricity (APTEL).
1.4.2. Subsequently, the Hon’ble APTEL decided the matter vide Judgment dated 25th November, 2016. Brief of the major observations made by the Hon’ble APTEL are as follows:
Table 5: Highlights of the Hon’ble APTEL Judgment dated 25.11.2016
Parameter Observations of the Hon’ble APTEL Power Purchase In respect of this Issue, we direct the State Commission to re-examine to the extent to Cost which the power purchase cost is to be allowed on the quantum of power purchase allowed with reference to all the bills from the generators and other sources of power procurement and if the State Commission finds any specific quantum of power purchase claim is not supported by such bills may seek specific documents from the Appellant in this regard. The State Commission should also treat the power purchase rate of NBPDCL for FY 2014-15 as per audited accounts as there is eventually no adverse impact on the consumers Depreciation and In our opinion, the depreciation is an important segment and needs to be re-examined Gross Value of by the State Commission keeping in view the relevant details submitted by the Appellant Assets subject to its prudent check. The Appellant is entitled to raise the issue of rate of depreciation also before the State Commission while the depreciation amount is being re-examined by the State Commission. Return on Equity The matter for consideration is only whether the amount contributed by the State Government towards equity capital should be considered equity or not. To be fair to the Appellant, the State Commission is directed to re-examine whether the contribution of the State Government towards equity capital should be considered as equity or not and accordingly pass an appropriate order. Net Prior Period The State Commission is hereby directed to look into this issue based on the details (Credit/Charges) claimed by the Appellant to have been furnished and even the audited accounts of the Appellant. Energy Sales Our observation on this issue is limited to the point that the progress on the part of the Appellant in implementing these schemes in the remaining part of the current financial year could be kept under close watch and if considerable progress is achieved by the Appellant in the ensuing period, the State Commission can reconsider the projections and consumers mix etc. afresh for FY 2017-18 onwards. Recovery of We have observed that in the Impugned Order, the State Commission had deferred the Gap/Surplus of the carrying cost. past period We observe that the surplus of the past period pertaining to the erstwhile BSEB and also the issue regarding disallowance of carrying cost need to be reviewed by the State Commission. Employee Cost In light of the fact that the details of both these employees cost and A&G expenses for and A&G FY 2015-16 are now available as stated by the Appellant, the State Commission may Expenditures look into the employee cost and A&G expenses for the FY 2015-16 and subsequently employee cost and A&G expenses for FY 2015-16 should be considered a base year for estimating the same for the FY 2016-17 onwards. Since the matter is being remanded to the State Commission, the Appellant is given the liberty to raise the above aspect in the remand proceedings with satisfactory details for consideration in regard to Employees Cost and A&G expenses. Distribution Losses We have also noted that the reasoning of the State Commission to the effect that a non- Trajectory achievement of loss level as per the trajectory already decided by the State Commission
North Bihar Power Distribution Company Limited 16 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
Parameter Observations of the Hon’ble APTEL is on account of the inefficiencies of the Appellant and the consumers should not be burdened for such inefficiencies.
We do not wish to interfere with the impugned findings of this State Commission in its Order since the State Commission is in a better position to ascertain the efficiency of the Appellant. However, since the matter is being remanded to the State Commission for various issues as brought out above, we would like to state only that the State Commission should have to relook and decide only to the extent that such numbers should not become unachievable but not on account of the inefficiencies of the Appellant, if the State Commission observes so.
1.5. BERC Order against the Judgment of Hon’ble APTEL on Appeal No. 141 and Appeal No. 142 of 2016
1.5.1. The Hon’ble APTEL had issued disposed of the Appeal No. 141/2016 (pertaining to Case No. 50/2015 of SBPDCL) and Appeal No. 142/2016 (pertaining to Case No. 49/2015 of NBPDCL) by its common order dated 25th November 2016 setting aside the order of the Commission and remanded the case to Hon’ble BERC to reconsider eight issues and pass fresh order.
1.5.2. The Hon’ble BERC had passed separated Tariff Orders for SBPDCL and NBPDCL on 8th March 2017 on the eight issues. Hon’ble BERC in its revised order has allowed an additional ARR of INR 25.54 Crores in revised True up order of 2014-15 for SBPDCL and an additional ARR of INR 33.25 Crores in revised True up order of 2014-15 for NBPDCL. The same amount was considered in True up order of FY 2015-16 with applicable carrying costs in the Tariff Order for SBPDCL and NBPDCL dated 24th March 2017.
1.6. Appeal No. 154 and Appeal No. 155 of 2017
1.6.1. The Hon’ble BERC has proceeded to disallow the claims of SBPDCL and NBPDCL on the issues of Net prior period charges (FY 2014-15) and Recovery of Gap/(Surplus) of the past period in its revised Tariff Order for SBPDCL and NBPDCL dated 8th March 2017.
1.6.2. SBPDCL and NBPDCL had filed an appeal against the order of the Hon’ble Commission dated 8th March, 2017 vide appeal no 154/2017 and 155/2017 of FY 2016-17 on 24th April 2017.
1.7. Instant Petition
1.7.1. Section 62 of the Electricity Act, 2003 requires the Distribution Licensee to furnish details as may be specified by the SERC for determination of tariff. In addition, as per the regulations issued by the Hon’ble Commission, BSEB or its unbundled companies are required to file petition for all reasonable expenses which they believe they would incur over
North Bihar Power Distribution Company Limited 17 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
the next financial year and seek the approval of the Hon’ble Commission for the same in advance. The filing is to be done based on the projections of expected costs and revenue.
1.7.2. The current petition has been prepared in accordance with the provisions of the following Acts/ Policies/ Regulations:
a) The Electricity Act, 2003; b) The National Electricity Policy; c) The National Tariff Policy, and amendments issued therein; d) Bihar Electricity Regulatory Commission (Multi Year Distribution Tariff) Regulations, 2015, Bihar Electricity Regulatory Commission (Multi Year Distribution Tariff) (First Amendment) Regulations, 2017 and its amendments thereof, along with the other guidelines and directives issued by the BERC from time to time e) BERC (Terms and Conditions for Open Access) Regulations, 2005
1.7.3. The Petitioner has made genuine efforts for compiling all relevant information relating to the True-up, APR, and ARR petition as required by the regulations issued by the Hon’ble Commission and has also made every effort to ensure that the information provided to the Hon’ble Commission is accurate and free from material errors. However, there may be certain deficiencies owing to the limited operations of Distribution Company on independent basis. The Petitioner therefore prays to the Hon’ble Commission that the information provided be accepted for the current filing and at the same time assures that it is taking appropriate measures to improve its management information system for improved data collection.
1.8. Contents of the Petition
1.8.1. This petition comprises of following sections:
True up for FY 2016-17 Annual Performance Review for FY 2017-18 Annual Revenue Requirement for FY 2018-19 Revenue Gap and Tariff Proposal for FY 2018-19 Miscellaneous and General Charges Voltage Wise Cost of Supply Proposed tariff Schedule for FY 2018-19 Wheeling and Open access charges Implementation of UDAY
North Bihar Power Distribution Company Limited 18 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
2. Overall approach for present filing
2.1. Present Approach
2.1.1. The Petitioner requests the Hon’ble Commission to determine the ARR for FY 2018-19. It further requests the Hon’ble Commission to determine norms for the Petitioner for this period based on the learnings and its independent operations till FY 2017-18.
2.1.2. In line with the above, NBPDCL is filing its True-Up petition for FY 2016-17, Annual Performance Review petition for FY 2017-18 and Annual Revenue Requirement petition for FY 2018-19 for the consideration of the Hon’ble Commission.
2.1.3. The Petitioner requests the Hon’ble Commission to kindly approve the True-Up, APR and ARR, keeping in view the actual segregated figures now available for the entire year in the audited books of accounts for FY 2016-17.
2.2. Data and information sources for estimating the Aggregate Revenue Requirement
2.2.1. In this Petition, the true up is based on the actual audited accounts for FY 2016-17. The APR for FY 2017-18 is based on actual figures for the first 6 months (as available) for power purchase, and for components like O&M expenses etc. of the financial year. Appropriate pro-rata projections and escalations have been taken over the previous year, keeping in mind guiding principles defined by the Hon’ble Commission. The ARR for FY 2018-19 is based on projections and escalations over the previous year, keeping in mind the historical trends and key initiatives planned for the future, in line with the guidelines provided by the Hon’ble Commission for determining the same.
North Bihar Power Distribution Company Limited 19 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
3. True-up Summary for FY 2016-17
3.1. Preamble
3.1.1. This section outlines the performance of the Petitioner for FY 2016-17.
3.1.2. In line with the provisions of the BERC (Multi Year Distribution Tariff) Regulations, 2015 and amendments issued thereof, the Petitioner hereby submits the True Up petition for FY 2016- 17. The expenses of the Petitioner for FY 2016-17 presented for true-up are based on the audited books of accounts, and other principles adopted by the Hon’ble Commission for estimating normative interest on term loan, Return on Equity, interest on working capital loan and depreciation. The ARR so arrived has been compared with that approved by the Hon’ble Commission vide its Tariff Order dated 24th March, 2017. Accordingly, the revised Aggregate Revenue Requirement, revenue and gap for FY 2016-17 have been given in the subsequent sub-sections of this chapter.
3.2. Number of Consumers, Connected Load and Sales
Number of Consumers 3.2.1. The actual no. of consumers at the end of FY 2016-17 against the no of consumers revised approved in the Tariff Order dated 24st March 2017 is provided below:
Table 6: Number of Consumers as on 31st March 2017
S. Category Approved in Approved in Actual for FY No. MYT Order dated APR FY 2016-17 2016-17 21.03.16
1 KJY 1,873,212 2,236,678 2,516,282 2 DSI 4,499,309 2,096,133 1,967,498 3 DSII 1,088,549 1,104,248 1,176,543 4 DS III 43 83 85 5 NDS I Commercial 52,986 64,973 80,110 6 NDS II Commercial 142,045 175,998 214,557 7 NDS III Commercial 178 403 80 8 NDS IV 2 9 SS I 289 154 142 10 SS II 39 150 113 11 Irrigation and Agriculture I 2,793 4,504 9,147 12 Irrigation and Agriculture II 4,306 4,167 5,011 13 PWW 652 679 208 14 LTIS I 7,665 12,078 11,593 15 LTIS II 520 1,128 653 16 HTS I 507 706 643 17 HTS II 26 28 25 18 HTS III 2 3 2 19 HTSS 3 3 5
North Bihar Power Distribution Company Limited 20 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
S. Category Approved in Approved in Actual for FY No. MYT Order dated APR FY 2016-17 2016-17 21.03.16
20 RT 4 4 7 21 Sale to Nepal 0 0 1 22 UI 0 0 1 23 DF 0 0 313,499 24 Total 7,673,128 5,702,122 6,296,205
3.2.2. The above comparison clearly brings out the fact that Petitioner has added a significant number of consumers during the year and the actual no. of consumers is in fact higher by almost 27.92% over previous year. Increase can be observed in certain major categories like KJY (38.87%), NDS-I (47.96%) over previous year. As the Hon’ble Commission is also aware that the Petitioner has engaged an Input based Franchisee in the Muzaffarpur area for accessing greater consumer base with prompt meter reading, billing and collection. The category wise consumers in the area of Distribution Franchisee (DF) is provided below:
Table 7: No. of Consumers of Muzaffarpur Distribution Franchisee
Category FY 2016-17 Domestic 282,762 Kutir Jyoti- BPL Consumers 135,901 Domestic - I 52,943 Domestic - II 93,918 Domestic - III 27,722 Commercial 22,560 Non-Domestic - I 5,162 Non-Domestic - II 22,560 Non-Domestic - III 0 Non-Domestic - IV 0 Public Lighting 395 Street Light - I 6 Street Light - II 389 Irrigation 499 IAS – I 345 IAS – II 154 Public Water Works 58 Industrial LT 1,909 LTIS – I 1,752 LTIS – II 157 Industrial HT 154 HTS – I 147 HTS – II 5 HTS – III 0
North Bihar Power Distribution Company Limited 21 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
Category FY 2016-17 HTSS 2 Railway 0 Grand Total 313,499
3.2.3. The Hon’ble Commission has considered the entire consumers of DF area as one single consumer in the True up for FY 2015-16, in the Tariff Order dated 24th March 2017. It is pertinent to understand that the Petitioner has engaged the DF for facilitating its billing, collection and other activities, for serving its consumers in the designated geographical area. Other than that, all the consumers in the DF area are billed as per the applicable tariff approved by the Hon’ble Commission in its Tariff Orders for the prevalent period.
3.2.4. The EA, 2003 defines Distribution Licensee and Distribution Franchisee as follows:
“(17) "distribution licensee" means a licensee authorised to operate and maintain a distribution system for supplying electricity to the consumers in his area of supply; ... (27) “ franchisee means a persons authorised by a distribution licensee to distribute electricity on its behalf in a particular area within his area of supply;”
3.2.5. All the consumers residing in Muzaffarpur area also come under the Licensee area of the Petitioner, and therefore they should be treated as consumers of the Petitioner and not a single consumer just because of the fact that the Petitioner has delegated certain activities to the DF and is receiving payment based on the energy input on certain agreed terms. Therefore, treating consumers of various categories in DF area as a single consumer is an error apparent on the record and demands reconsideration of the entire issue.
3.2.6. Further, this assumption also has a bearing on the connected load and energy sales. The Petitioner therefore requests the Hon’ble Commission to approve the number of consumers as per actuals i.e. 62.96 lakhs for FY 2016-17 which also includes 3.13 lakhs consumers of the DF area.
Connected Load 3.2.7. The actual connected load at the end of FY 2016-17 against the connected load revised approved in the Tariff Order dated 24th March 2017 is provided below:
Table 8: Total connected load (in kW) as on 31st March 2017
S. No. Category Approved in MYT Approved in APR Actual for FY Order dated 21.03.16 FY 2016-17 2016-17 1 KJ 187,321.20 263,928.00 353,590.63 2 DS-I 5,023,909.81 2,168,879.86 1,975,877.26
North Bihar Power Distribution Company Limited 22 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
S. No. Category Approved in MYT Approved in APR Actual for FY Order dated 21.03.16 FY 2016-17 2016-17 3 DS-II 2,040,007.39 1,214,672.80 1,378,615.05 4 DS-III 380.51 809.98 87.00 5 NDS-I 48,122.34 67,499.22 85,122.24 6 NDS-II 407,223.59 413,882.18 546,352.49 7 NDS-III 789.12 714.45 254.00 8 NDS-IV 0.00 1.04 0.00 9 SS-I 4,610.59 4,444.18 965.00 10 SS-II 1,666.02 2,153.11 2,337.14 11 IAS-I 8,959.57 16,657.50 29,627.20 12 IAS-II 69,764.19 51,505.82 53,412.23 13 PWW 9,084.47 12,975.00 4,666.00 14 LTIS-I 55,443.23 94,624.07 22,879.85 15 LTIS-II 20,981.57 45,234.33 33,396.92 16 HTS-I 129,388.13 141,386.57 137,246.50 17 HTS-II 53,555.51 44,623.86 41,636.00 18 HTS-III 31,840.18 43,051.50 34,170.00 19 HTSS 19,008.48 9,665.70 10,737.00 20 RT 7,359.22 43,200.00 54,900.00 21 Sale to Nepal 0.00 0.00 0.00 22 UI 0.00 0.00 0.00 23 DF 0.00 0.00 455,156.98 24 Total 8,119,415.14 4,639,909.18 5,221,029.49
3.2.8. It is to be noted that the connected load of the Petitioner has increased by 2% from 5,107,836.74 kW in FY 2015-16 to 5,221,029.49 kW in FY 2016-17.
3.2.9. The Hon’ble Commission is also aware that the Petitioner has engaged an Input based Franchisee in the Muzaffarpur area for accessing greater consumer base with prompt meter reading, billing and collection. The category wise connected load in the area of Distribution Franchisee (DF) is provided below:
Table 9: Total connected load (in kW) of Muzaffarpur Distribution Franchisee Area
Category FY 2016-17 Domestic 327,260.19 Kutir Jyoti- BPL Consumers 134,626.19 Domestic - I 53,449 Domestic - II 139,136 Domestic - III 49 Commercial 59,778 Non-Domestic - I 5,632 Non-Domestic - II 53,932 Non-Domestic - III 214 Non-Domestic - IV
North Bihar Power Distribution Company Limited 23 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
Category FY 2016-17 Public Lighting 1,165 Street Light - I Street Light - II Irrigation 2360.78 IAS - I 647.54 IAS - II 1,713.23 Public Water Works 687 Industrial LT 18,830 LTIS - I LTIS - II Industrial HT 45,076 HTS - I 32,550 HTS - II 5,226 HTS - III HTSS 7,300 Railway Grand Total 455,157
3.2.10. It would not be justifiable to ignore the connected load of the consumers residing in the area of operation of the Distribution Franchisee. Hence, the Hon’ble Commission is requested to approve actual load of 455156.98 kW of the consumers of DF area.
Sales 3.2.11. The category wise actual sales (MUs) at the end of FY 2016-17 against the sales revised approved in the Tariff Order dated 24th March 2017 is provided below:
Table 10: Total Energy Sales (in MU) for FY 2016-17
S. No. Category Approved in MYT Approved in APR Actual for FY Order dated 21.03.16 FY 2016-17 2016-17 1 KJY 674.36 816.39 848.69 2 DSI 3,120.27 1,443.55 1,522.29 3 DSII 2,383.92 1,595.82 1,195.71 4 DS III 0.84 0.73 0.35 5 NDS I Commercial 39.12 46.28 67.70 6 NDS II Commercial 544.01 514.11 633.64 7 NDS III Commercial 1.18 1.01 4.88 8 NDS IV 0.0006 9 SS I 9.35 11.99 6.24 10 SS II 6.08 11.43 9.03 11 Irrigation and Agriculture I 12.44 24.74 7.40 12 Irrigation and Agriculture II 233.82 191.13 152.80 13 PWW 39.79 26.43 30.16 14 LTIS I 109.91 102.78 145.40 15 LTIS II 60.58 57.88 17.95 16 HTS I 283.36 297.01 269.41 17 HTS II 111 99.53 93.24
North Bihar Power Distribution Company Limited 24 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
S. No. Category Approved in MYT Approved in APR Actual for FY Order dated 21.03.16 FY 2016-17 2016-17 18 HTS III 69.73 101.33 65.95 19 HTSS 58.28 16.27 45.59 20 RT 25.69 27.08 62.67 21 Sale to Nepal 1,418.77 1,476.04 1,188.89 22 UI 77.35 23 DF 812.01 766.46 749.87 24 Total 10,014.51 7,627.99 7,195.20 Note: The sales to Distribution Franchisee refers to the energy sold by NBPDCL to the DF
3.2.12. It can be observed from the above table that the Petitioner has made sales of 77.35 MUs with regard to UI and has calculated the total sales as 7,195.20 MUs as evident from the Audited Accounts for FY 2016-17. The Petitioner in line with the instructions of the Hon’ble Commission in its Tariff Order for FY 2017-18 has modified the approach followed in its earlier submissions and has considered the sales with regard to Unscheduled Interchange (UI) as an adjustment in the total power purchase for FY 2016-17. Thus, the Hon’ble Commission is prayed to approve sales of 7,117.85 MUs for FY 2016-17.
Table 11: Total Energy Sales for FY 2016-17
S. No. Particulars Sales (MUs) 1 Total Sales including UI (MUs) 7,195.20 2 UI (MUs) 77.35 3 Total Sales excluding UI (MUs) 7,117.85
3.2.13. The Hon’ble Commission is also aware that the Petitioner has engaged an Input based Franchisee in the Muzaffarpur area for accessing greater consumer base with prompt meter reading, billing and collection. The category wise sales in the area of Distribution Franchisee (DF) is provided below:
Table 12: Total Energy Sales (in MU) for Muzaffarpur Distribution Franchisee
Category FY 2016-17 Domestic 346.55 Kutir Jyoti- BPL Consumers 87.78 Domestic - I 58.50 Domestic - II 200.23 Domestic - III 0.05 Commercial Non-Domestic - I 5.44 Non-Domestic - II 67.80 Non-Domestic - III 0.21 Non-Domestic - IV Public Lighting 8.39 Street Light - I Street Light - II Irrigation IAS - I 1.17 IAS - II 14.27
North Bihar Power Distribution Company Limited 25 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
Category FY 2016-17 Public Water Works 3.43 Industrial LT 32.32 LTIS - I LTIS - II Industrial HT HTS - I 67.72 HTS - II 11.80 HTS - III Z HTSS 33.12 Railway Grand Total 592.22 Note: The above mentioned sales figure pertains to the energy sold by the Distribution Franchisee to the consumers residing in its area of operation
3.2.14. It can be observed from the above table that the sales made by the Muzaffarpur DF is 592.22 MUs in comparison to the 749.87 MUs of sales to DF claimed by the Petitioner. It is to be noted that 592.22 MUs of energy is sold by the DF to the consumers in its operational area and 749.87 MUs of energy is sold by the Petitioner to DF. Thus, the Commission is hereby prayed to consider the sales of 592.22 MUs for DF.
3.3. Distribution Loss
3.3.1. The Hon’ble Commission has approved 19.25% distribution loss in its MYT Order dated 24th March 2017 for FY 2016-17. However, it is important to bring into the kind notice of the Hon’ble Commission that the actual distribution losses for the Petitioner is higher than the loss trajectory approved by the Hon’ble Commission.
3.3.2. The following table captures the distribution loss for FY 2016-17:
Table 13: Distribution Losses (in %)
Particulars Approved in MYT Order Approved in APR FY Actual for FY As per UDAY dated 21.03.16 2016-17 2016-17 MoU Distribution Loss 19.25% 19.25% 31.43% 28%
3.3.3. The difference in the loss target and the actual loss levels is practically impossible to achieve in the given period, and therefore this shall add on to the burden of the Discom. Although the Hon’ble Commission has approved the losses for FY 2017-18 onwards as per the agreed UDAY MoU, it has not considered the same for FY 2016-17. It is therefore the request of the Petitioner that for FY 2016-17 as well, the distribution loss trajectory should be in synchronization of the MoU signed by the Discoms. The Hon’ble Commission is also requested to see the growth rates in consumer base of the Petitioner (28%) and consider the challenging operating scenario of the Petitioner wherein most consumers being added are in rural and remote areas further adding to network losses, ongoing measures, and
North Bihar Power Distribution Company Limited 26 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
regulatory precedents to approve the actual distribution loss for FY 2016-17. Therefore the Hon’ble Commission is kindly requested to consider the actual loss of 31.43% and adopt the loss target as agreed in the UDAY MoU i.e. 28%.
3.4. Transmission losses
3.4.1. Intra-State Transmission Loss: It is submitted that the Petitioner has taken the State transmission loss as per actuals i.e. 4.74% from the audited accounts for FY 2016-17 and accordingly requests the Hon’ble Commission to approve the same.
3.4.2. Inter-State Transmission Loss: It is submitted that the Petitioner has taken the Central Transmission loss as per actuals i.e. 2.66% from the audited accounts for FY 2016-17 and accordingly requests the Hon’ble Commission to approve the same.
3.5. Power Purchase
3.5.1. Bihar has historically been a State with limited natural resources which has led to an underdeveloped power generation sector in the State. As a result, the State Power Distribution Companies rely heavily on allocation from central generating stations and other outside State projects for procuring power for sale to consumers within the State. This dependence as a consequence creates a significant amount of uncertainty in terms of reliability and also significantly pushes up the power purchase costs (due to the fact that sometimes the power allocation is done from inefficient plants in addition to the higher inter- state transmission charges and losses). This fact should be given due consideration while approving power purchase costs of the Petitioner.
3.5.2. Power is procured by the central power management team, and this is allocated between the two Discoms, NBPDCL and SBPDCL, in the proportion as determined by the board resolution based on the demand growth requirement and consequent power supply requirement.
3.5.3. Long term power purchase: The power purchase for existing sources has primarily been NTPC, NHPC and PTC, and the same has been considered based on the actual quantum with adjustments to capture overall power purchase cost in a reasonable manner. Other sources of power include power procured from State Generating companies and IPPs.
3.5.4. Medium / Short Term power purchase: The power purchase from these sources are namely Adani, IEX, NEA, UI etc., and these have been adequately considered as per the actual power purchase data provided.
North Bihar Power Distribution Company Limited 27 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
3.5.5. Renewable Power Purchase Obligation: It is submitted that the Hon’ble Commission has notified the BERC (Renewable Purchase Obligation, its Compliance and REC Framework Implementation) Regulations, 2010 and BERC (Terms and Conditions for Tariff Determination from Solar Energy Sources) Regulations, 2010. Further Hon’ble Commission initiated a Suo-Motu proceedings no. 42/2016 dated 24.11.2016 to bring in 2nd amendment in the BERC (Renewable Purchase Obligation, its Compliance and REC Framework Implementation) Regulations, 2010 to incorporate the various new/amended provisions specified in the revised Tariff Policy,2016 notified by the Ministry of Power Govt. of India vide gazette notification dated 28.01.2016 and revised the RPO as follows:
Table 14: Renewable Purchase Obligation (%)
From FY 2016- FY 2017-18 FY 2018-19 FY 2019-20 FY 2020- FY 2021- Renewable 17 21 22 Sources RPO (%) 6.50% 7.75% 9.25% 11.50% 14.25% 17.00% Solar (%) 1.50% 2.25% 3.25% 4.75% 6.75% 8.00% Non-Solar (%) 5.00% 5.50% 6.00% 6.75% 7.50% 9.00%
3.5.6. In line with the above, the details of the Renewable Energy based power procured during FY 2016-17, has been given in the table below:
Table 15: RPO met for FY 2016-17 (in INR Crore)
S. No. Particulars Unit FY 2016-17 1 Energy consumption excluding Nepal MU 7,117.88 2 % of RPO Obligation % 6.50% Solar % 1.50% Non-Solar % 5.00% 3 MUs required as per RPO for the year MU 462.66 Solar MU 106.77 Non-Solar MU 355.89 4 Solar Energy procured during the year MU 38.55 5 Non-Solar Energy procured during the year MU 68.29 6 Solar REC purchased during the year No. 0.00 7 Non-solar REC purchased during the year No. 0.00
3.6. Actual Power Purchase quantum
3.6.1. The details of actual power purchased from various sources in FY 2016-17 is as follows:-
Table 16: Actual Power Purchased (MU) in FY 2016-17
S.No. Power Purchase Share allocation Energy(MU) Sources (MW)
1 Central Sector Stations 1,226.41 7,815.71 2 Talcher – I ( 2 x 500 MW) 166.60 1,216.88
North Bihar Power Distribution Company Limited 28 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
S.No. Power Purchase Share allocation Energy(MU) Sources (MW)
3 Farakka – I & II (1600 MW) 203.52 1,400.54 4 Farakka – III (500 MW) 43.04 441.16 5 Kahalgaon – I (840 MW) 141.96 1,023.77 6 Kahalgaon – II (1500 MW) 29.88 231.16 7 Barh-II 423.60 2,508.04 8 Korba 30.00 106.51 9 Rangit – HEP 8.40 47.63 10 Teesta - HEP 43.37 236.83 11 Chukha 32.00 253.34 12 Tala 104.04 349.85 13 Barh Stage-I (3 X 660 MW) - - 14 State Generating Stations 132.00 340.31 15 KBUNL 1 88.00 279.67 16 KBUNL 2 - - 17 Small Hydro (BSHPCL) - 5.27 18 Barauni Stage I 44.00 55.36 19 Barauni Stage II - - 20 IPP 184.00 817.84 21 GMR Kamalanga Energy 104.00 810.35 22 Adani Enterprises Limited 80.00 7.49 23 JV projects - - 24 Nabinagar Railway (4 X 250 MW) - - 25 Nabinagar Stage-I (3 X 660 MW) - - 26 Nabinagar JV (3 X 660 MW) Stage-II - - 27 Renewable 77.60 101.57 28 SECI 4.00 8.73 29 ACME Magadh 4.00 4.43 30 ACME Nalanda 6.00 5.86 31 Sunmark Energy Projects 4.00 2.08 32 Avantika 2.00 2.25 33 AZURE Power 4.00 3.45 34 Udipta Energy & Equipment Pvt ltd 2.00 0.13 35 Glatt Solution Private Limited 1.20 0.01 36 Welspun 2 6.00 4.72 37 Welspun 1 4.00 2.53 38 Alpha Infrapop Private Limited - - 39 Welspun 3 6.00 4.36 40 Response Renewable Energy - - 41 New Swadeshi Sugar Mill, Narkatiaganj 2.80 4.82 42 Harinagar Sugar Mills, Harinagar 4.40 21.16 43 Bharat SugarMills,Sidhiwalia, Gopalganj 4.40 13.09 44 Lauriya Sugar Mill 8.00 10.94 45 Sugauli Sugar Mill 8.00 6.56 46 Hasanpur Sugar Mills, Samastipur 4.00 3.47 47 Riga Sugar Company Ltd, Sitamarhi 1.20 0.81
North Bihar Power Distribution Company Limited 29 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
S.No. Power Purchase Share allocation Energy(MU) Sources (MW)
48 Siddhashram Rice Mill Cluster Pvt Ltd 0.40 1.05 49 Bihar Distillers and Bottlers Pvt Ltd 1.20 1.11 50 Open Market Purchase - 1,236.38 51 IEX/PXIL - 809.84 52 DB Power - 81.44 53 JAYPEE NIGRIE - 100.62 54 JPL - 11.44 55 GMR ETL - 91.39 56 TATA ETL - 84.90 57 Manikaran Power - - 58 NEA - 0.04 59 NVVNL - 27.37 60 PVVNL - 0.60 61 Adani Short Term - - 62 UI - 28.74 63 Net Total Power Purchase 1,620.01 10,311.81
3.6.2. In the FY 2016-17, NBPDCL sales under UI are 77.35 MU and revenue incurred from sale of power under UI is INR 4.18 Crores. The Petitioner has also made a purchase of 107.75 MUs with regard to UI at a cost of INR 42.64 Crore. Thus, the net Power purchase made through adjustment of UI is 28.74 MUs at a cost of INR 38.46 Crore. Therefore, the Petitioner requests the Hon’ble Commission to approve net UI figures as mentioned above.
3.6.3. The above information is as admitted in the annual books of accounts. It is also crucial to note that any disallowance on this regard severely impacts the liquidity and financial position of the Petitioner, and impediments its ability to further procure any additional power due to unavailability of funds. Accordingly the Hon’ble Commission is requested to approve the power purchase quantum for the Petitioner on an actual basis as 10,311.81 MU during FY 2016-17.
3.7. Energy Balance
3.7.1. The Petitioner has calculated the energy balance based on the actual sales, distribution losses and the power availability during FY 2016-17. The details are as provided in the following table:-
Table 17: Energy balance (MU) in FY 2016-17
S. No. Particulars Unit Approved in Approved in Actual for FY MYT Order APR FY 2016-17 2016-17 dated 21.03.16 1 Energy sales MU 10,014.51 7,627.99 7,195.23 2 Less: Energy supplied to DF MU 812.01 766.46 644.59 area
North Bihar Power Distribution Company Limited 30 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
S. No. Particulars Unit Approved in Approved in Actual for FY MYT Order APR FY 2016-17 2016-17 dated 21.03.16 3 Less: Sales to Nepal MU 1,418.77 1,476.04 1,188.89 4 Less: UI MU 77.35 5 Energy sale excluding DF MU 7,783.73 5,385.49 5,284.40 area and Nepal 6 Distribution loss % 19.25 19.25% 31.43% 7 Distribution loss MU 1,855.56 1,283.85 2,422.73 8 Energy required (3+5) MU 9,639.29 6,669.34 7,707.12 9 Add: Energy to DF area MU 812.01 766.46 644.59 including loss for DF area 10 Energy required at MU 1,0451.3 7,435.8 8,351.72 Distribution periphery (7+8) 11 Add: Sales to Nepal MU 1,418.77 1,476.04 1,188.89 12 Total energy required (9+10) MU 11,870.07 8,911.84 9,540.61 13 State Transmission loss % 3.92% 3.92% 4.74% 14 State Transmission loss MU 484.29 363.6 480.17 15 Add: UI sales MU 28.74 16 Energy required at State MU 12,354.37 9,275.44 10,049.52 Transmission periphery 17 Power Purchase from CGS, MU 12,498.57 10,032.98 10,311.36 SGS and others 18 UI MU 28.74 19 Power Purchase from CGS MU 9,840.54 20 Losses in Regional % 2.26% 2.26% 2.66% Transmission System (excluding state generating stations)
21 Losses in Regional MU 240.99 220.36 261.84 Transmission system (MU) 22 Power Purchase from SGS MU 442.08 23 Energy available at State MU 12,257.58 9,812.62 10,049.52 Transmission Periphery 24 Surplus energy (23-16) MU -96.79 537.18 -
3.7.2. The Petitioner requests the Hon’ble Commission to approve the energy balance based on actual calculations for FY 2016-17.
3.8. Power Purchase Cost
3.8.1. The power purchase cost mainly comprises of fixed and energy charges for two part tariff PPAs which are essentially with NTPC, NHPC and PTC, and only energy charges in case single part tariff based PPAs, which are typically for Adani, BSHPC, Solar and Sugar Mills etc. The Petitioner has presented the actual expenditure incurred on power purchase based on bills raised by the various power sellers. This actual amount has been considered and captured accordingly as a break up of two part tariff, wherever applicable, as per the audited accounts of the Petitioner. The Petitioner therefore humbly requests the Hon’ble Commission to allow the actual power purchase cost under this true-up process.
North Bihar Power Distribution Company Limited 31 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
3.8.2. In line with the above, the Petitioner presents its power purchase cost for FY 2016-17 based on audited annual accounts, for the kind consideration of the Hon’ble Commission.
North Bihar Power Distribution Company Limited 32 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
Table 18: Actual Power Purchased (MU) in FY 2016-17
S. Power Purchase Previous Year (FY 16-17) No. Sources Share Energy(MU) Fixed Fixed Energy Energy Other Total Avg. allocation Charge charge Rate charge charges Charges Tariff (MW) rate (INR Cr) (INR/kWh) (INR Cr) (INR Cr) (INR Cr) Rate (INR/MU) (INR/kWh) 1 Central Sector Stations 1,226.41 7,815.71 1.29 1,010.46 2.24 1,751.42 47.69 2,809.57 3.59 2 Talcher – I ( 2 x 500 MW) 166.60 1,216.88 0.85 103.46 1.65 200.34 10.82 314.62 2.59 3 Farakka – I & II (1600 MW) 203.52 1,400.54 0.86 120.56 2.53 354.19 3.32 478.07 3.41 4 Farakka – III (500 MW) 43.04 441.16 1.40 61.89 2.50 110.08 (1.15) 170.81 3.87 5 Kahalgaon – I (840 MW) 141.96 1,023.77 0.96 98.79 2.39 244.66 2.14 345.59 3.38 6 Kahalgaon – II (1500 MW) 29.88 231.16 1.01 23.34 2.27 52.36 0.09 75.79 3.28 7 Barh-II 423.60 2,508.04 2.19 550.06 2.45 614.87 23.67 1,188.59 4.74 8 Korba 30.00 106.51 1.24 13.15 1.50 15.94 1.41 30.51 2.86 9 Rangit – HEP 8.40 47.63 1.99 9.50 1.75 8.35 0.72 18.57 3.90 10 Teesta - HEP 43.37 236.83 1.25 29.71 1.13 26.82 6.67 63.19 2.67 11 Chukha 32.00 253.34 - - 2.09 52.95 - 52.95 2.09 12 Tala 104.04 349.85 - - 2.03 70.88 - 70.88 2.03 13 Barh Stage-I (3 X 660 MW) ------14 State Generating Stations 167.20 340.31 0.93 31.63 3.89 132.34 - 163.97 4.82 15 KBUNL 1 88.00 279.67 1.13 31.63 3.90 109.05 - 140.68 5.03 16 KBUNL 2 ------17 Small Hydro (BSHPCL) 35.20 5.27 - - 2.49 1.31 - 1.31 2.49 18 Barauni Stage I 44.00 55.36 - - 3.97 21.98 - 21.98 3.97 19 Barauni Stage II ------20 IPP 184.00 817.84 2.11 172.69 1.05 85.66 47.72 306.07 3.74 21 GMR Kamalanga Energy 104.00 810.35 1.90 154.35 1.02 82.90 46.09 283.33 3.50 22 Adani Enterprises Limited 80.00 7.49 24.49 18.34 3.69 2.76 1.63 22.74 30.36 23 JV projects ------24 Nabinagar Railway (4 X 250 MW) ------25 Nabinagar Stage-I (3 X 660 MW) ------26 Nabinagar JV (3 X 660 MW) Stage-II ------27 Renewable 77.60 101.57 - - 6.28 63.77 0.39 62.27 6.13 28 SECI 4.00 8.73 - - 5.50 4.80 0.39 5.19 5.95 29 ACME Magadh 4.00 4.43 - - 8.73 3.87 - 3.87 8.73 30 ACME Nalanda 6.00 5.86 - - 8.73 5.11 - 5.11 8.73 31 Sunmark 4.00 2.08 - - 7.02 1.46 - 1.46 7.02 32 Avantika 2.00 2.25 - - 7.69 1.73 - 1.73 7.69
North Bihar Power Distribution Company Limited 33 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19 S. Power Purchase Previous Year (FY 16-17) No. Sources Share Energy(MU) Fixed Fixed Energy Energy Other Total Avg. allocation Charge charge Rate charge charges Charges Tariff (MW) rate (INR Cr) (INR/kWh) (INR Cr) (INR Cr) (INR Cr) Rate (INR/MU) (INR/kWh) 33 AZURE 4.00 3.45 - - 8.39 2.89 - 2.89 8.39 34 Udipta Energy & Equipment Pvt ltd 2.00 0.13 - - 7.98 0.11 - 0.11 7.98 35 Glatt 1.20 0.01 - - 7.02 0.01 - 0.01 7.02 36 Welspun 2 6.00 4.72 - - 8.64 4.08 - 4.08 8.64 37 Welspun 1 4.00 2.53 - - 8.70 2.20 - 2.20 8.70 38 Welspun 3 6.00 4.36 - - 8.56 3.73 - 3.73 8.56 39 Response Renewable Energy 40 New Swadeshi Sugar Mill,Narkatiaganj 2.80 4.82 - - 5.04 2.43 - 2.43 5.04 41 Harinagar Sugar Mills,Harinagar 4.40 21.16 - - 5.36 11.33 - 11.33 5.36 42 Bharat SugarMills,Sidhiwalia,Gopalganj 4.40 13.09 - - 5.09 6.66 - 6.66 5.09 43 Lauriya Sugar Mill 8.00 10.94 - - 5.40 5.91 - 5.91 5.40 44 Sugauli Sugar Mill 8.00 6.56 - - 5.40 3.54 - 3.54 5.40 45 Hasanpur Sugar Mills,Samastipur 4.00 3.47 - - 5.80 2.01 - 2.01 5.80 46 Riga Sugar Company Ltd,Sitamarhi 1.20 0.81 - - 5.84 0.48 - 0.48 5.84 47 Siddhashram Rice Mill Cluster Pvt Ltd 0.40 1.05 - - 7.36 0.77 - 0.77 7.36 48 BDBPL 1.20 1.11 - - 5.80 0.64 (0.00) 0.64 5.78 49 Open Market Purchase - 1,236.38 - - 3.06 378.70 - 378.70 3.06 50 IEX/PXIL - 809.84 - - 2.84 229.73 - 229.73 2.84 51 DB Power - 81.44 - - 2.70 22.02 - 22.02 2.70 52 JAYPEE NIGRIE - 100.62 - - 2.75 27.65 - 27.65 2.75 53 JPL - 11.44 - - 2.87 3.28 - 3.28 2.87 54 GMR ETL - 91.39 - - 2.80 25.57 - 25.57 2.80 55 TATA ETL - 84.90 - - 2.85 24.18 - 24.18 2.85 56 Manikaran Power ------57 NEA - 0.04 - - 5.62 0.02 - 0.02 5.62 58 NVVNL - 27.37 - - 2.69 7.37 - 7.37 2.69 59 PVVNL - 0.60 - - 6.97 0.42 - 0.42 6.97 60 Adani Short Term 61 UI - 28.74 - - 13.38 38.45 - 38.45 13.38 62 Sub Total Power Purchase 1,655.21 10,311.81 1.18 1,214.78 2.34 2,411.89 95.80 3,720.58 3.61 63 Transmission charges ------480.57 - 64 PGCIL ------361.37 - 65 POSOCO & SLDC Charges ------2.72 - 66 BSPTCL charges ------116.49 - 67 BGCL ------68 Total Power Purchase 1,655.21 10,311.81 1.18 1,214.78 2.34 2,411.89 95.80 4,201.15 4.07
North Bihar Power Distribution Company Limited 34 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
3.9. Transmission charges
3.9.1. Interstate Transmission charges
3.9.1.1. It is submitted that the Petitioner has to pay transmission charges to PGCIL for use of transmission facilities enabling power drawl from the Eastern region. The transmission charges payable to PGCIL are computed based on new transmission pricing mechanism and the figures for computation for FY 2016-17 and based on actual bills.
3.9.1.2. Further the Petitioner also incurs POSOCO charges and Open Access charges.
3.9.1.3. The summary of expenses towards PGCIL, POSOCO and ERLDC charges for FY 2016- 17 based on actual audited accounts is given in the table below:
Table 19: PGCIL, POSCO and ERLDC charges
Source Total (in INR Crore) PGCIL 361.37 POSOCO & ELDC Charges 2.72
3.9.2. Intrastate Transmission charges
3.9.2.1. The charges payable to State Transmission Utility i.e. BSPTCL based on actuals for FY 2016-17 is shown below.
Table 20: State transmission charges
Source Total (in INR Crore) BSPTCL charges 116.49
3.9.3. Given the above information, the Hon’ble Commission is therefore requested to approve the total transmission charges of INR 480.57 Crore (INR 361.37 Cr. + INR 2.72 Cr. + INR 116.49 Cr.) in true up for FY 2016-17.
3.10. Disallowance of power purchase due to excess Distribution loss
3.10.1. In FY 2016-17, the Petitioner has added around 28% consumers to the consumer base of FY 2015-16 with increase of around 39% in KJY category. Due to addition in the number of consumers it is imperative that more effort is required to control the losses due to the existing consumers and also to ensure that the loss due to addition of the new consumers should also not exceed the existing level. Even in such a situation, the Petitioner was able to reduce the actual distribution loss level to 31.43%.
3.10.2. The present trajectory of Distribution Losses aims at 19.25% losses in FY 2016-17 which is far below the actual losses of 31.43% of the utility. Also in the light of this fact, it is pertinent
North Bihar Power Distribution Company Limited 35 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
to note that the state of Bihar and NBPDCL have signed a tripartite Memorandum of Understanding (MoU) of Ujwal Discom Assurance Yojana with the Ministry of Power, Government of India on 22nd February, 2016. Under UDAY scheme the Discoms have targeted to reduce the AT&C losses and bring it to the level of 15% by FY 2019-20.
3.10.3. The Commission while determining ARR for FY 2017-18 had adopted the Distribution Loss trajectory as agreed under UDAY Scheme, but kept the distribution loss as approved in the MYT Order for FY 2016-17 unchanged, in view of the fact that the Tariff for the 2016-17 has already been determined by the Commission and the Discoms will be getting resource gap assistance from the State Govt. for the distribution loss over and above the distribution loss trajectory approved by the Commission in its Tariff Order dated 21.03.2017. The relevant extract of the Tariff Order is reproduced below:
“The Commission, however, does not think it proper to revise the T&D losses set for 2016-17 in line with UDAY in view of the fact that the Tariff for the 2016-17 has already been determined by the Commission and more importantly as per Petitioners claims they will be getting resource gap assistance from the State Govt. for the distribution loss over and above the distribution loss trajectory approved by the Commission in its tariff order dated 21.03.2016. The finance department has also confirmed it vide its letter no 330 dated 08.03.2016”
3.10.4. Accordingly Hon’ble Commission revised its Distribution Loss trajectory for FY 2017-18 to FY 2019-20, keeping the trajectory for FY 2016-17 unchanged. Actual distribution loss for FY 2016-17 is far from the approved losses. Hon’ble Commission disallowed the resultant gap only because the State Govt. is taking over the distribution loss doesn’t qualify for argument. In one hand Hon’ble Commission has adopted the loss trajectory as agreed under UDAY scheme for rest of the years except FY 2016-17 and in other hand has disallowed the same for FY 2016-17 resulting partial adoption and differential treatment of the same loss reduction trajectory for FY 2016-17.
3.10.5. In compliance to the Hon’ble Commission’s directive to increase supply hours, the Petitioner has increased the hours of supply in both rural and urban areas. Currently, the utility is providing more than 18 hours per day to its rural consumers and around 22 hours per day to its urban consumers. The Petitioner is continuously doing efforts to reduce the loss levels by introducing spot billing, various payment channels etc.
3.10.6. Thus, in order to bring uniformity to the approach, also bringing in a logical bent to the matter considering actual facts kept on record, it is hereby requested to adopt the distribution loss of 28% for FY 2016-17 for calculation of disallowance of power purchase cost due to excess
North Bihar Power Distribution Company Limited 36 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
distribution loss. The table below represents the additional power purchase cost incurred due to higher distribution losses of the utility when compared to the distribution loss trajectory agreed under UDAY MoU.
Table 21: Disallowance of power purchase cost due to excess distribution loss (in INR Crore)
S. Particulars Approved in Approved Actual for FY No. MYT Order in APR FY 2016-17 dated 21.03.16 2016-17 Proposed resource gap assistance 1 1,417.77 1,417.77 1,513.66 from State Government Less: Disallowed power purchase 2 -- 330.68 145.32 funded through State Govt. grant Available balance resource gap 3 1,417.77 1,087.09 1,368.35 assistance
3.10.7. In light of this fact, the Hon’ble Commission is kindly requested to approve an amount of INR 145.32 Crore on account of disallowance of power purchase cost due to higher actual T&D losses as compared to the UDAY loss trajectory.
3.11. Capital Investment Plan, Capitalization and Funding
3.11.1. During the year Petitioner has capitalized INR 584.51 Crores of which INR 467.61 Crore pertains to CWIP and INR 116.90 Crore is towards new investment in FY 2016-17. As depicted in the table below, INR 240.53 Crore pertains to grants. These grants were received under various schemes. Apart from grant, fixed assets are funded through loans and equities too. The funding through loans amounts to INR. 24.85 Crore and through equity it is INR 319.13 Crore.
3.11.2. The table given below depicts the audited balance of Capital Works in Progress (CWIP), Gross Fixed Assets (GFA) and Grants etc. for FY 2016-17.
Table 22: CWIP, Capex, Capitalization and Funding (in INR Crore)
S. No. Particulars Approved in MYT Approved in Actual for FY Order dated APR FY 2016-17 2016-17 21.03.16 1 Opening CWIP 2,588.38 5,113.38 5,113.37 2 New Investment 6,002.07 8,259.04 2,298.67 3 Less: Capitalization (4+5) 4,226.09 11,468.33 584.51 4 CWIP 1,225.05 4,090.7 467.61 5 New Investment 3,001.04 7,377.63 116.90 6 Closing CWIP (1+2-3) 4,364.36 1,904.09 6,827.52 7 Funding 8 CWIP Capitalization(9+10+11) 1,225.05 4,090.7 467.61 9 Grant 965.9 2,975.38 192.43 10 Equity 97.65 674.68 19.88
North Bihar Power Distribution Company Limited 37 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
S. No. Particulars Approved in MYT Approved in Actual for FY Order dated APR FY 2016-17 2016-17 21.03.16 11 Loan 161.5 440.64 255.31 12 New Investment (13+14+15) 3,001.03 7,377.63 116.90 13 Grant 2,366.21 5,366.14 48.11 14 Equity 239.2 1,216.78 4.97 15 Loan 395.62 794.71 63.83 16 Total Capitalization (8+12) 4,226.08 11,468.33 584.51 17 Total Grant (9+13) 3,332.11 8,341.52 240.53 18 Total Equity (10+14) 336.85 1,891.46 24.85 19 Total Loan (11+15) 557.12 1,235.35 319.13
3.11.3. The Hon’ble Commission is therefore requested to approve the actual capitalization plan for FY 2016-17. Also, the Petitioner can furnish the adequate supporting document validating the amounts if required by the Commission.
3.12. Gross Fixed Assets
3.12.1. The Petitioner hereby submits the computation of Gross Fixed Assets considering the opening GFA as per Audited Annual Accounts as on 31st March 2017.
3.12.2. The details of the opening and closing GFA for FY 2016-17 have been provided in the table below:
Table 23: Gross Fixed Assets (in INR Crore)
S. No. Particulars Approved in Approved in Actual for FY MYT Order APR FY 2016- 2016-17 dated 21.03.16 17 1 Opening GFA 4,573.69 4,573.69 4,573.69 2 Additions during the year 4,226.09 11,468.33 584.51 3 Add : IDC 36.21 80.3 0.00 4 Add: Employee cost capitalized 9.04 -- 0.00 5 Closing GFA (1 to 4) 8,867.43 16,122.32 5,158.21
3.12.3. The Petitioner requests the Hon’ble Commission to approve closing Gross Fixed assets as INR 5,158.21 Crore as per the audited accounts for FY 2016-17.
3.13. Depreciation
3.13.1. As per regulation 23 of Bihar Electricity Regulatory Commission (Multi Year Distribution Tariff) Regulations, 2015 the Petitioner is claiming the depreciation expense after deducting the value of grant, depreciation on land and consumer contribution amortized in the ratio of depreciation
North Bihar Power Distribution Company Limited 38 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
3.13.2. Depreciation is an important cost component for any Distribution Licensee. The Petitioner in the below table submits the depreciation for FY 2016-17 on the various assets within GFA.
Table 24: Depreciation (in INR Crore)
S. No. Particulars Approved in Approved in Actual for FY MYT Order APR FY 2016- 2016-17 dated 21.03.16 17 1 Opening GFA 3,609 3,583.14 3,583.15 2 Additions during the Year 4,226.09 11,444.73 570.38 3 IDC 36.21 80.3 4 Expenses capitalized 9.04 -- 5 Closing GFA (1+2+3+4) 7,880.35 15,108.17 4,153.53 6 Average GFA (1+5)/2 5,744.68 9,345.65 3,868.34 7 Weighted average rate of depreciation 5.08% 4.95% 4.41% 8 Gross Depreciation(6*7) 291.83 462.61 192.49 9 Opening Grants 4,701.13 3,757.79 1,802.61 10 Grants during the year 3,332.11 8,324.5 240.53 11 Total Grants (9+10) 8,033.25 12,082.29 2,043.14 12 Average Grants (9+11)/2 6,367.19 7,920.04 1,922.88 13 Weighted average rate of depreciation 5.08% 4.95% 5.34% 14 Depreciation for GFA on Grants (12*13) 323.45 392.04 102.74 15 Depreciation for GFA on Loans (8-14) -- 70.57 89.76
3.13.3. The Gross depreciation expense incurred by the Petitioner in FY 2016-17 amounts to INR 192.49 Crore of which INR 102.74 Crore pertains to amortization of grants and consumer contribution in the ratio of depreciation. The Petitioner is claiming depreciation by reducing the value of grants and consumer contribution amortized in FY 2016-17.
3.13.4. The Petitioner requests the Hon’ble Commission to approve depreciation as per the actuals i.e. INR 89.76 Crore for FY 2016-17.
3.14. Other finance charges
3.14.1. Other finance charges include power factor rebate, interest to suppliers, bank charges etc. The below table captures the various head wise other finance charges as incurred for FY 2016-17:-
North Bihar Power Distribution Company Limited 39 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
Table 25: Other Finance charges (in INR Crore)
S. No. Particulars Approved in Approved in Actual for MYT Order APR FY FY 2016-17 dated 2016-17 21.03.16 1 Discount to consumers for timely payment of Bills (Rebate) 19.25 Power Factor Rebate 0.73 2 Interest to Suppliers/Contractors (LPSC to Power Suppliers) 39.00 Interest to Group Saving Scheme 0.01 Interest on General Provident Fund 0.05 Interest on Gratuity 0.04 Interest on Contributory Provident fund - LC Commission 1.78 3 Other Bank Charges 0.01 4 Other finance charges as per audited accounts 25.7 28.35 for FY 2015-16 5 Escalation percentage 10.00% 10.00% 6 Add: increase in finance charges 2.57 2.84 7 Other finance charges 28.27 31.19 60.87
3.14.2. The Petitioner requests the Hon’ble Commission to approve INR 60.87 Crore towards Other Finance charges for FY 2016-17.
3.15. Operation & Maintenance charges
3.15.1. As per Regulation 22 of Bihar Electricity Regulatory Commission (Multi Year Distribution Tariff) Regulations, 2015 the Petitioner has claimed O&M expenses. Operation and Maintenance charges comprises of Employee expenses, A&G expenses, R&M expenses and Holding company expenses. The Petitioner has furnished the details of O&M expenses in the below paragraphs. The Hon’ble Commission is requested to consider the same while truing up for FY 2016-17.
3.15.2. Employee Expenses
3.15.2.1. The employee expenses further primarily include costs towards salaries, Dearness Allowances, bonus, staff welfare and medical benefits, leave travel and earned leave encashment, and the terminal benefits in the form of pension, gratuity etc. The details of actual employee expenses as per the audited accounts for the FY 2016-17 is shown below:
Table 26: Employee expenses (in INR Crore)
S. No. Particulars Approved in Approved in APR Actual for FY MYT Order FY 2016-17 2016-17 dated 21.03.16 1 Salaries 73.44 2 Over Time 0.87 3 Dearness Allowance 82.32 4 Other Allowance 7.36
North Bihar Power Distribution Company Limited 40 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
S. No. Particulars Approved in Approved in APR Actual for FY MYT Order FY 2016-17 2016-17 dated 21.03.16 5 Medical Expenses Re-imbursement 0.38 6 Leave Salary Contribution 8.11 7 Staff Welfare Expenses 0.13 8 Terminal Benefits 15.51 9 Employee cost for FY 2016-17 171.86 188.01 10 Inflationary index 5.25% 3.94% 11 Inflationary increase 9.02 7.41 12 Employee Cost (1+3) 180.88 195.42 13 Less: Capitalization 9.04 -- 14 Total Employee Cost (4-5) 171.84 195.42 188.13
3.15.2.2. As per the audited accounts the employee expenses incurred by the Petitioner is INR 188.13 Crore. The Hon’ble Commission is therefore requested to approve the same as per the audited accounts.
3.15.3. Repairs and maintenance
3.15.3.1. The R&M expenses primarily include costs related to repair of different class of fixed assets etc. The detailed R&M expenses for the FY 2016-17 is shown below:
Table 27: R&M expenses (in INR Crore)
S. Particulars Approved in MYT Approved in APR Actual for FY No. Order dated FY 2016-17 2016-17 21.03.16 1 Plant and Machinery 1.94 2 Building 0.10 3 Civil Works 0.21 4 Line Cable Net Works 46.95 5 Furniture and Fixture 0.00 6 Office Equipment 0.02 7 Opening GFA 4,596.08 4,573.69 8 K factor 1.06% 1.21% 9 R & M expenses 48.72 55.34 49.21
3.15.3.2. As per the audited accounts the R&M expense incurred by the Petitioner is INR 49.21 Crore. The Hon’ble Commission is requested to approve the same as per the audited accounts.
3.15.4. Administrative expenses
3.15.4.1. Administration and General expenses mainly comprise costs towards rent charges, telephone and other communication expenses, professional charges, conveyance and travelling allowances and other debits. The detailed A&G expenses for the FY 2016-17 is shown below:
North Bihar Power Distribution Company Limited 41 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
Table 28: A&G expenses (in INR Crore)
S. Particulars Approved in Approved in Actual for FY No. MYT Order APR FY 2016-17 dated 2016-17 21.03.16 1 Rent, Rates & Taxes 0.24 2 Insurance 2.64 3 Telephone charges, Postage & Telex Charges 8.34 4 Legal Charges. 6.79 5 Audit Fees 0.05 6 Technical Fee 0.00 7 Consultancy Charges 0.05 8 Conveyance & Travel 7.05 9 Other Expenses 10 Fees & Subscription 2.05 11 Books & Periodicals 0.00 12 Printing & Stationary 1.07 13 Advertisement 0.41 14 Electricity & Water Charges 3.93 15 Entertainment Charges 0.20 16 Computer Billing 8.66 17 Home Guard/ Security Guard 2.31 18 Franchisee Commission 18.43 19 Franchisee Incentive 0.31 20 Meter Reading & Bills Distribution 3.77 21 Preliminary Expenses Amortized 0.00 22 Miscellaneous Expenses 0.86 23 Commission Others 1.02 24 Holding Tax Expenses 9.08 25 Remuneration to Executive Assistant 4.17 26 Freight 0.37 27 Other Purchase related Expenses 0.00 28 Miscellaneous losses and write-offs 4.25 29 Previous year A&G expenses 48.75 58.9 30 Inflationary index 2.63% -- 31 Inflationary increase 1.28 -- 32 A&G expenses 50.03 58.9 86.05
3.15.4.2. As per the audited accounts, the A&G expense incurred by the Petitioner is INR 86.05 Crore. The Hon’ble Commission is therefore requested to approve the same as per the audited accounts.
3.15.5. Allocation of holding cost
3.15.5.1. The allocation of the Holding company expenses for FY 2016-17 as per the provisions of the Transfer Scheme 2012, and based on the actual audited accounts has been tabulated below:
Table 29: Holding cost (in INR Crore)
Particulars Approved in MYT Approved in APR Actual for FY Order dated FY 2016-17 2016-17 21.03.16 Holding company expenses 6.66 9.86 5.38
North Bihar Power Distribution Company Limited 42 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
3.15.5.2. It is requested that the Hon’ble Commission approve the above holding expenses of INR 5.38 Crore as a part of O&M expenses.
3.15.6. Gist of O&M expenses: The following table captures the total O&M expenses incurred by the Petitioner in the FY 2016-17:-
Table 30: O&M expenses (in INR Crore)
S. No. Particulars Approved in Approved in Actual for FY MYT Order APR FY 2016-17 2016-17 dated 21.03.16 1 Employee cost 171.84 195.42 188.13 2 R&M expenses 48.72 55.34 49.21 3 A&G Expenses 50.03 58.9 86.05 4 Holding company expenses 6.66 9.86 5.38 5 Total O& M cost 277.25 319.52 328.77
3.15.7. The Hon’ble Commission is therefore requested to approve INR 328.77 Crores as O&M expenses for FY 2016-17.
3.16. Interest on working capital
3.16.1. The clause 26 of BERC (MYT) Regulations, 2015 with regard to Interest on Working Capital is as follows:
“The Distribution Licensee shall be allowed interest on estimated level of working capital for the financial year, computed as follows:
a) O&M expenses for one month b) Two months equivalent of expected revenue c) Maintenance spares @ 40% of R&M expenses for one month: Less: (j) Power purchase cost, transmission charges and load dispatch charges of one month (ii) Depreciation, return on equity and contribution to contingency reserves (iii) Security deposits from consumers, if any. Provided that the interest on working capital shall be on normative basis and rate of interest shall be equal to the State Bank Advance Rate (SBAR) as of the date on which petition for determination of tariff is accepted by the Commission. Provided further that interest shall be allowed on consumer security deposits and security deposits from Distribution System users at the Bank Rate as of the date on which the petition for determination of tariff is accepted by the Commission. Provided further that if the State Government is providing resource gap grant or subsidy, working capital shall be reduced by that amount.” 3.16.2. It can be observed from above provision that the consumer security deposit has to be deducted as per the methodology defined in the Regulations. The realization of total amount occurred at end of the year, with additions spread over the whole year. Thus, the Petitioner has considered security deposit from consumers as an average of the opening and closing of the total consumer security deposit while calculating interest on working capital.
North Bihar Power Distribution Company Limited 43 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
3.16.3. The Petitioner would like to submit that it has arrived at the working capital requirement according to the applicable norms for Distribution function as provided in the BERC (Multi Year Distribution Tariff) Regulations, 2015, the calculation for which has been captured in the following table:
Table 31: Interest on working capital (in INR Crore)
S. No. Particulars Approved in Approved Actual for MYT Order in APR FY FY 2016- dated 2016-17 17 21.03.16 1 O&M expenses (1 month) 23.1 26.63 27.40 2 Two months equivalent expected revenue 937.62 786.66 891.73 Maintenance spares @40% of R&M expenses for 3 1.62 1.84 1.64 one month 4 Sub-total (1+2+3) 962.35 815.13 920.77 5 Less: (i) Power purchase cost, transmission charges 446.5 347.25 350.10 and load dispatch charges of one month (ii) Depreciation, return on equity and contribution 19.99 34.47 45.71 to contingency reserve (iii)Security Deposits from consumers 278.74 268.89 21.06 (iv) Grant received from the State Govt. for power 236.3 236.3 24.22 purchase and other O&M expenses 6 Sub-total (5(i)+5(ii)+5(iii)+5(iv)) 981.53 886.91 441.09 7 Net working capital requirement (4-6) -19.18 -71.78 479.68 8 Rate of interest % 14.75% 14.05% 14.05% 9 Interest on working capital (7*8) -- -- 67.39
3.16.4. The Petitioner has considered O&M expenses equivalent to one month amounting to INR 27.40 Crore according to the above mentioned Regulation. Also, the Petitioner would like to submit that for calculating the maintenance spares, 40% of R&M expense for one month to arrive at an amount of INR 1.64 Crore. Two months equivalent revenue requirement deducted by non-tariff income has been considered for calculation of gross working capital of INR 920.77 Crore.
3.16.5. The Gross working capital requirement is thereby reduced by 2 months of subsidy provided by the Government of Bihar on account of disallowed power purchase amounting to INR 24.22 Crores, 2 months of the average of opening and closing of Security deposits from consumers in FY 2016-17 and Depreciation amounting to INR 21.06 Crore and INR 24.22 Crore respectively. The power purchase cost inclusive of transmission charges is there by reduced by one month amounting to INR 350.10 Crore. Finally an interest rate @ 14.05% at the SBI PLR has been taken on this quantum of working capital loan requirement.
3.16.6. Therefore, the Hon’ble Commission is requested to kindly approve the interest on working capital loan i.e. INR 67.39 Crore for FY 2016-17.
North Bihar Power Distribution Company Limited 44 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
3.17. Return on Equity
3.17.1. As per regulation 27 of the BERC MYT regulations 2015, Return on Equity shall be calculated as follows:-
(a) “Return on equity shall be computed on 30% of the capital base or actual equity, whichever is lower: Provided that assets funded by consumer contribution, capital subsidies/ grants and corresponding depreciation shall not form part of the capital base. Actual equity invested in the Distribution Licensee as per book value shall be considered as perpetual and shall be used for computation in this Regulation: (b) The return on the equity invested shall be allowed from the date of start of commercial operation: (c) The project which will be commissioned w.e.f. 01.04.2016 will be allowed RoE of 15.5% and if project is completed in schedule period 0.5% incentives in form of RoE will be allowed.”
3.17.2. It is to be noted that the actual equity infused in the company is greater than the norm of 30% of capital base. However in line with the above cited regulation, the return on equity is calculated on 30% of the capital base only.
Table 32: Return on equity (in INR Crore)
S. No. Particulars Claimed in True Up for FY 2016-17 1 Amount of total asset at the beginning 1,372.11 2 Less: asset created from grant at beginning 540.78 3 Addition during the year 175.35 4 Less: asset created from grant during the year 72.16 5 Net asset 934.52 6 Average equity 1,153.31 7 Amount of equity eligible for return 1,153.31 8 Rate of return on equity 16.00% 9 Amount of return on equity 184.53
3.17.3. In view of the above, the Petitioner requests the Hon’ble Commission to approve INR 184.53 Crore towards Return on Equity.
3.18. Interest on Loans
3.18.1. Interest on loans includes loans against schemes, central and state government loans, Bank Overdrafts, public bonds etc.
3.18.2. For computing the interest rate on the normative debt, the weighted average rate of actual loan portfolio is calculated as 8.16%. Below table captures weighted average rate of interest computation for FY 2016-17
North Bihar Power Distribution Company Limited 45 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
Table 33: Interest on Loans Claimed for FY 2016-17 (in INR Crore)
S. No Particulars FY 2016-17 1 Opening Balance a APDRP & RAPDRP 601,164,792 b REC 4,564,305,305 c ADB 629,482,647 A Total(1) 5,794,952,744 2 Additions during the year a APDRP & RAPDRP 12,300,000 b REC 422,656,847 c ADB 9,238,090 B Total(2) 444,194,937 3 Repayment of Loans a APDRP & RAPDRP 114,056,380 b REC 3,288,604,168 c ADB - C Total(3) 3,402,660,548 4 Closing balance of Loans a APDRP & RAPDRP 499,408,412 b REC 1,698,357,984 c ADB 638,720,737 D Total(4) 2,836,487,133 5 Interest on Loans a APDRP & RAPDRP 15,551,210 b REC 269,740,945 c ADB 66,670,553 E Total(5) 351,962,708
6 Average Loans (A+D)/2 4,315,719,939 7 Total interest 351,962,708 8 Weighted average rate of interest on project Loans(6*7) 8.16%
3.18.3. The Petitioner has considered INR 89.76 Crore claimed under depreciation as normative repayment for the period. The below table captures interest expense against loans as incurred for FY 2016-17:-
Table 34: Interest on Loans Claimed for FY 2016-17 (in INR Crore)
S. No. Particulars Claimed in True Up for FY 2016-17 1 Amount of total asset at the beginning 3,201.58 2 Less: asset created from grant at beginning 1,261.83 3 Addition during the year 409.16 4 Less: asset created from grant during the year 168.37 5 Net asset 2,180.55 6 Less: Normative repayment 89.76 7 Amount of debt(loan) 2,090.79 8 Average debt 2,646.19 9 Amount of loan eligible for return 2,646.19 10 Weighted average rate of interest on project loans 8.16% 11 Interest on project loans 215.81
North Bihar Power Distribution Company Limited 46 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
3.18.4. The Petitioner therefore requests the Hon’ble Commission to approve Interest on loan of INR 215.81 Crore for FY 2016-17.
3.18.5. The Petitioner had signed tripartite agreement with Government of Bihar and Ministry of Power, Government of India on 22nd Feb, 2016 wherein existing loans taken by the Petitioner were repaid through Government Grant under UDAY scheme.
3.18.6. The grant of INR 961.88 Crore received for financial restructuring under UDAY from Government of Bihar against issuing of Bonds through RBI for repayment of outstanding debt as 30th September 2015. Such Grant is moved directly to Capital reserve account in financial statements for FY 2016-17.
3.18.7. The loans restructured includes Term Loans, Loans from REC etc. As a result of such restructuring of Loans, the Petitioner has saved total interest amount INR 73.34 Crore in FY 2016-17.Such saving of interest is reflected in audited accounts for FY 2016-17.
3.19. Interest on Consumer Security Deposit
3.19.1. Section 47(1) (a) of the Electricity Act, 2003 specifies that any person who requires a supply of electricity, should provide a reasonable amount of security deposit in respect of the electricity supplied to such person. The BERC Supply Code Regulations 2007 specifies that the Distribution Licensee shall pay interest at the RBI Bank rate, applicable on security deposits taken from the consumers. And the interest amount of the previous financial year, shall be adjusted in the energy bill issued in May/June of each financial year, depending on the billing cycle.
3.19.2. The Petitioner would like to submit that as per the regulation, interest on consumer’s security deposit is paid to HT and LT consumers and the Petitioner possesses the details of the same. A summary of the same has been represented below.
Table 35: Interest on Consumer Security Deposit (in INR Crore)
S. No. Particulars Approved in APR Actual for FY FY 2016-17 2016-17 1 Opening Security Deposit 233.82 233.82 2 Addition / (Deletion) during the year 35.07 37.73 3 Closing Security Deposit 268.89 271.54 4 Average Security Deposit (1+3)/2 251.35 252.68 5 RBI Bank Rate 6.75% 7.75% 6 Interest on Security Deposit 16.97 19.58
3.19.3. The Hon’ble Commission is therefore requested to approve INR 19.58 Crore towards interest on consumer security deposits, as per the audited accounts for FY 2016-17.
North Bihar Power Distribution Company Limited 47 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
3.20. Net Prior Period Credit / (Charges)
3.20.1. The Petitioner has considered the actual Net Prior Period Credit/ (Charges) as per the Audited Annual Accounts for FY 2016-17 as shown below:
Table 36: Prior period (expense)/income (in INR Crore)
S. No. Particulars Actual for FY 2016-17 1 Prior Period Income 9.33 2 Prior Period Expense 290.42 3 Net Prior Period Expense 281.09
3.20.2. The Hon’ble Commission is requested to approve INR 281.09 Crore as net prior period expense for FY 2016-17.
3.21. Provision for RPO
3.21.1. In FY 2016-17 the Petitioner has made provision for meeting its RPO obligations as provided under:-
Table 37: Provision of RPO (in INR Crore)
S. Particulars Approved in T.O. Approved in Actuals for FY No. dated 21.03.2016 Review for FY 2016-17 2016-17 (RE) 1 Deposit for RPO obligations NIL NIL 75.85
3.21.2. The Petitioner requests Hon’ble Commission to approve INR 75.85 Crores towards Deposit for RPO obligation.
3.22. Non-Tariff income
3.22.1. The Petitioner presents the non-Tariff income earned by it in FY 2016-17:-
Table 38: Non-tariff income (in INR Crore)
S. Particulars Approved in Approved Actual No. MYT Order in APR FY for FY dated 2016-17 2016-17 21.03.16 Interest Income 1 Interest on Advances to Suppliers/Contractors 49.33 2 Interest from Banks 7.52 3 Interest on Staff Loan & Advances 0.23 Other Income 4 Delayed Payment Surcharge from Consumers 53.28 5 Income from sale of Tender paper 0.54 6 Miscellaneous Receipts 0.76 7 Rebate and Discount Received 10.18
North Bihar Power Distribution Company Limited 48 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
S. Particulars Approved in Approved Actual No. MYT Order in APR FY for FY dated 2016-17 2016-17 21.03.16 8 Supervision Charges 0.13 Others 9 Meter Rent/ Service Line Rental 78.51 10 Miscellaneous Recoveries 15.54 11 Net Non-tariff income 152.66 159.29 12 Rate of Increase 10.00% 10.00% 13 Increase in non-tariff Income 15.27 15.93 Total Non-tariff income 167.93 175.22 216.01 DPS as per Audited Accounts (@1.5% per month=18% per 14 annum) 53.28 15 Principal amount on which DPS Charged 295.98 16 Interest Rate of funding DPS 14.05% 17 Interest on funding Principal 41.59 Net Non-Tariff Income 174.43
3.22.2. It is prayed to the Hon’ble Commission to consider INR 174.43 Crore as Non-Tariff income during FY 2016-17.
3.23. Revenue from Sale of Power at Existing Tariff
3.23.1. Following is the category wise revenue based on the tariff approved for FY 2016-17.
Table 39: Revenue from sale of power at existing tariff
S. Consumer Category Number Revenue form Unit Sold ABR No. of Effective Sale of energy Unit % of (INR/kWh) Consumers (INR Crore) sold in Unit MUs sold 1 Domestic 5,660,408 1,048.00 3,567.04 50.11% 2.94 Kutir Jyoti - BPL Consumer 2,516,282 197.53 848.69 11.92% 2.33 Domestic – I 1,967,498 317.84 1,522.29 21.39% 2.09 Domestic - II 1,176,543 532.33 1,195.71 16.80% 4.45 Domestic - III 85 0.29 0.35 0.00% 8.29 2 Commercial 294,747 367.38 706.21 9.92% 5.20 Non-Domestic - I 80,110 16.90 67.70 0.95% 2.50 Non-Domestic - II 214,557 348.08 633.64 8.90% 5.49 Non-Domestic - III 80 2.40 4.88 0.07% 4.92 3 Public Lighting 255 5.38 15.27 0.21% 3.52 Street Light - I 142 2.26 6.24 0.09% 3.62 Street Light - II 113 3.12 9.03 0.13% 3.46 4 Irrigation 14,158 90.07 160.20 2.25% 5.62 IAS - I 9,147 1.76 7.40 0.10% 2.38 IAS - II 5,011 88.31 152.80 2.15% 5.78 5 Public Water Works 208 18.66 30.16 0.42% 6.19 6 Industrial LT 12,246 119.87 247.76 3.48% 4.84 LTIS - I 11,593 108.29 145.40 2.04% 7.45 LTIS - II 653 11.58 17.95 0.25% 6.45 7 Industrial HT 675 324.28 495.09 6.96% 6.55 HTS - I 643 186.18 269.41 3.78% 6.91 HTS - II 25 55.87 93.24 1.31% 5.99 HTS - III 2 57.81 65.95 0.93% 8.77
North Bihar Power Distribution Company Limited 49 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
S. Consumer Category Number Revenue form Unit Sold ABR No. of Effective Sale of energy Unit % of (INR/kWh) Consumers (INR Crore) sold in Unit MUs sold HTSS 5 24.42 45.59 0.64% 5.36 8 Railway 7 44.40 62.67 0.88% 7.08 9 Nepal 1 665.39 1,188.89 16.70% 5.60 10 M/s Essel Vidyut Vitran-DF 313,499 203.19 749.87 10.54% 2.71 TOTAL 6,296,205 2,886.62 7,117.85 100.00% 4.06
3.23.2. The Petitioner requests the Hon’ble Commission to kindly approve the revenue from sale of power as submitted above.
3.24. Net ARR and revenue gap for FY 2016-17
3.24.1. The Gross ARR for the distribution company consists of the power purchase costs, interest and finance costs, O&M costs, depreciation and interest on working capital. These costs are then adjusted for Non-Tariff Income and other Income. Following is the total revenue requirement for FY 2016-17 against allocation from total approved revenue requirement by the Hon’ble Commission for FY 2016-17.
Table 40: Net ARR and revenue gap for FY 2016-17 (in INR Crore)
S. Particulars Approved in Approved in APR Actual for FY No. MYT Order FY 2016-17 2016-17 dated 21.03.16 1 Purchase of power 4,873.9 3,625.33 3,720.58 2 PGCIL & Other transmission charges 326.2 311.47 364.09 3 BSPTCL transmission charges 116.69 111.28 116.49 4 Discom to Discom purchases 41.17 118.88 0.00 5 O & M Expenses (a+b+c+d) 277.25 319.52 328.77 a. Employee expenses 171.84 195.42 188.13 b. R&M expenses 48.72 55.34 49.21 c. A&G expenses 50.03 58.9 86.05 d. Holding company expenses allocated 6.66 9.86 5.38 6 Depreciation -- 70.57 89.76 7 Interest on loans 71.54 163.3 215.81 8 Other finance charges 28.27 31.19 60.87 9 Return on equity 21.84 136.28 184.53 10 Interest on Security Deposit 19.41 16.97 19.58 11 Deposit for RPO obligation 35.44 70.76 75.85 12 Contingency Reserve 18.15 -- 0.00 13 Net prior period Expense -- -- 281.09 14 Less: IDC -36.21 -80.3 0.00 15 Interest on working capital -- -- 67.39 16 Total Revenue requirement 5,793.65 4,895.24 5,524.80 17 Less:: Non-tariff income 167.93 175.22 174.43 Less: Expenditure disallowed due to 18 -- 330.68 145.32 excess T&D losses 19 Net Revenue requirement 5,625.72 4,389.34 5205.06
North Bihar Power Distribution Company Limited 50 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
S. Particulars Approved in Approved in APR Actual for FY No. MYT Order FY 2016-17 2016-17 dated 21.03.16 20 Revenue from Existing tariff 3,220.3 2,324.31 2,221.22 21 Revenue from sale of power-Nepal 814.95 980.09 665.39 22 Gross Gap / (Surplus) 1,590.47 1,084.94 2,318.44 23 Add: Recovery of (Surplus) FY 2014-15 ------Add: Recovery Gap / (Surplus) of past 24 ------period (FY 2015-16) 25 Net Gap / (Surplus) before subsidy 1,590.47 1,084.94 2,318.44 26 Subsidy from State Government 1,417.77 1,417.77 1,513.66 27 Subsidy used for disallowed power -- 330.68 145.32 28 Subsidy available for revenue gap 1,417.77 1,087.09 1,368.35 29 Net Gap / (Surplus) after subsidy 172.7 -2.15 950.09
3.24.2. The Petitioner requests the Hon’ble Commission to approve INR 950.09 Crore as Revenue gap for FY 2016-17.
North Bihar Power Distribution Company Limited 51 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
4. APR Summary for FY 2017-18
4.1. Preamble
4.1.1. The Commission had determined the Multi-Year Aggregate Revenue Requirement (ARR) for the second control period FY 2016-17 to FY 2018-19 for the Petitioner in the revised MYT Order dated 8th March, 2017 based on the judgment of Hon’ble Aptel on Appeal No.142 of 2016. Subsequently, the Hon’ble Commission issued its order for determination of ARR for FY 2017-18 in its order dated 24th March 2017.
4.1.2. The Petitioner has submitted this instant Tariff Petition for FY 2018-19 which includes Annual Performance Review (APR) for FY 2017-18. While projecting the APR for FY 2017- 18 the Petitioner has considered the actual figures for the first 6 months (i.e. from April 2017 to September 2017) for components like power purchase, O&M expenses etc. and pro-rata projections & escalations over previous year has been considered, keeping in mind the guiding principles defined by the Hon’ble Commission.
4.2. Estimate of category wise number of consumers, connected load and sales for FY 2017- 18
4.2.1. Estimate of category wise number of consumers
4.2.1.1. While projecting energy sales for FY 2017-18 the 24x7 Power For All plan, Har Ghar Bijli and the Saubhagya scheme along with the large scale initiatives taken by Central Government and the State Government are taken into consideration. These initiatives aim for the overall development of the power sector in the State. The objective of the 24x7 Power For All initiative is to make 24x7 power available to all households, industry, commercial businesses, public needs, any other electricity consuming entity and adequate power to agriculture farm holdings by FY 2018-19.
4.2.1.2. These plans are mainly targeted for rural consumers in KJ, DS-I and IAS-I category and the growth rate projected under this category is above the normal CAGR growth as large number of new connections are to be released in the ensuing years. The Petitioner has also considered 6 months provisional data for revising the growth in number of consumers for FY 2017-18.
Table 41: Category-wise no. of consumers projected for FY 2017-18
FY 2017-18 Category (RE) Domestic 6,401,896 Kutir Jyoti- BPL Consumers 2,818,236 Domestic - I 2,348,201
North Bihar Power Distribution Company Limited 52 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
FY 2017-18 Category (RE) Domestic - II 1,235,459 Domestic - III 0 Commercial 317,495 Non-Domestic - I 92,127 Non-Domestic - II 225,369 Non-Domestic - III 0 Public Lighting 268 Street Light - I 149 Street Light - II 119 Irrigation 38,159 IAS - I 32,647 IAS - II 5,512 Public Water Works 873 Industrial LT 13,405 LTIS - I 12,752 LTIS - II 653 Industrial HT 1,008 HTS - I 961 HTS - II 40 HTS - III 2 HTSS 5 Railway 7 Nepal 1 UI 0 DF 332,421 Total 7,105,534
4.2.2. Revised Estimate of Category wise Sales
4.2.2.1. Under the Chief Minister Seven Resolution the Discom is determined to provide electricity to every household and electrify 45 lakhs households over next 2-3 years. Discom is also going to avail the facility of wide spread rural electrification as per Saubhagya Scheme.
4.2.2.2. The Petitioner has projected the category-wise sales based on the CAGR of the previous years’ data and considering factors like available average consumption per consumer per month, new consumers to be added, population data, expected conversion of unauthorized connections, connected load factor and specific growth factors and wherever the data was incongruous such incongruity was ignored while projecting the load growth for the ensuing years.
4.2.2.3. The Petitioner submits that the forecast model projects the specific consumption level (consumption per consumer) appropriate for each customer category. The Petitioner submits that this forecast is based on expected growth relationships to income and price, effect of Demand Side Management and impact of hours of service.
North Bihar Power Distribution Company Limited 53 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
4.2.2.4. The Petitioner also submits that the specific consumption level along with the number of consumers in each category gives the sales figure for that particular sub-category and the final detailed calculations estimate the connected load for each tariff category. Also, 6 months provisional figure was also used for revising the category wise sales for the above projected number of consumers for FY 2017-18. The units sold are projected by taking average consumption per consumer per month and multiplying the same to the projected number of consumers to arrive at units sold for a year.
Table 42: Category-wise sales (MUs) projected for FY 2017-18
Category FY 2017-18 (RE)
Domestic 4,365 Kutir Jyoti- BPL Consumers 1,271 Domestic - I 1,651 Domestic - II 1,443 Domestic - III 0 Commercial 743 Non-Domestic - I 78 Non-Domestic - II 666 Non-Domestic - III 0 Public Lighting 16 Street Light - I 7 Street Light - II 9 Irrigation 246 IAS - I 78 IAS - II 168 Public Water Works 34 Industrial LT 270 LTIS - I 246 LTIS - II 24 Industrial HT 684 HTS - I 403 HTS - II 149 HTS - III 66 HTSS 66 Railway 63 Nepal 1,189 UI 0 M/s Essel Vidyut Vitran-DF 1,008 Total 8,618.49
4.2.2.5. The Petitioner has calculated the connected load considering average Load per consumer as per the actuals, CAGR of past years and multiplying it by projected number of consumers to arrive at the connected load.
Table 43: Category-wise connected load (kW) for FY 2017-18
Consumer Category FY 2017-18 (RE)
Domestic 4,800,403 Kutir Jyoti- BPL Consumers 704,559
North Bihar Power Distribution Company Limited 54 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
Consumer Category FY 2017-18 (RE)
Domestic - I 2,546,858 Domestic - II 1,548,986 Domestic - III Commercial 688,147 Non-Domestic - I 102,785 Non-Domestic - II 585,362 Public Lighting 3,467 Street Light - I 1,013 Street Light - II 2,454 Irrigation 166,713 IAS - I 107,733 IAS - II 58,981 Public Water Works 19,584 Industrial LT 124,901 LTIS - I 89,835 LTIS - II 35,067 Industrial HT 316,705 HTS - I 205,114 HTS - II 66,684 HTS - III 34,170 HTSS 10,737 Railway 54,900 Nepal 0 UI 0 M/s Essel Vidyut Vitran-DF 446,189 Total 6,621,009
4.3. Distribution Loss
4.3.1. In FY 2017-18 and FY 2018-19 the Petitioner has planned addition of large number of rural consumers in view of Chief Minister Seven Resolution Scheme and Saubhagya Scheme. Due to addition in the number of consumers, especially in rural and remote areas, it is expected the distribution losses may in fact go up slightly.
4.3.2. Also, in the light of the fact, the state of Bihar and North Bihar Power Distribution Company Limited (NBPDCL) have signed a tripartite Memorandum of Understanding (MoU) of Ujwal Discom Assurance Yojana with the Ministry of Power, Government of India on 22nd February, 2016. The present trajectory of Distribution Losses aims at 24% losses in FY 2017-18 which is far below the actual losses of the utility. In UDAY scheme the Discoms have targeted to reduce the AT&C losses and bring it to the level of 15% by FY 2019-20.
4.3.3. The Hon’ble Commission also approved the distribution loss trajectory as agreed under UDAY Scheme in Tariff Order for FY 2017-18. It is prayed to the Hon’ble Commission to consider the losses as approved in the Tariff Order for FY 2017-18 .
North Bihar Power Distribution Company Limited 55 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
Table 44: Distribution loss trajectory
FY 2017-18 FY 2018-19 FY 2019-20 Distribution Losses 24 % 20 % 15 %
4.4. State Transmission losses
4.4.1. The Petitioner has considered transmission loss of 3.92% as approved by the Hon’ble Commission in its previous Tariff Order as the State transmission loss. The basis for this figure is the approved normative loss, as the actual loss incurred during the period between April 2017 and September 2017 is still in the process of getting reconciled.
4.5. Central Transmission Loss
4.5.1. It is submitted that the Petitioner has considered weighted average transmission loss of last 52 weeks of Eastern Region. The same practice is very much adopted by all State Commissions.
4.5.2. The Petitioner requests the Hon’ble Commission to consider the Central transmission loss of 2.26% in this petition.
4.6. Power Purchase
4.6.1. The Discom’s rely on allocation from central generating stations and state projects for procuring power for sale in the state. This power has been proposed to be allocated between North and South Bihar in the proportion as determined by the board resolution as detailed below.
4.6.2. Bihar State Power Holding Company Ltd (BSPHCL) issued vide its Resolution No.55- 10 dated 14th July 2017 for approval regarding distribution of power purchase agreement between NBPDCL and SBPDCL. The notification states that, “RESOLVED THAT Power Purchase & Transmission charges bills are to be admitted and payment by both discoms i.e NBPDCL and SBPDCL in the ratio 46:54 respectively w.e.f.1-4-2017subjected to the final reconciliation of actual consumption”
RESOLVED FURTHER THAT Chairman cum Managing Director, BSHPCL are here by authorized for deciding the power consumption ratio subsequently as per the actual consumption of both the DISCOMS based on the average consumption of the last 6 months of power drawal of both the discoms i.e. NBPDCL and SBPDCL”
The Board further ratifies the submission made in attached agenda note. 4.6.3. The Copy of above mentioned board resolution regarding power sharing ratio between DISCOM’sis attached in Annexure B.9
North Bihar Power Distribution Company Limited 56 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
4.6.4. NHPC, NTPC & PTC: The power purchase for existing sources has been NTPC, NHPC and PTC has been considered based on the 24 X 7 Power for All projection. The power purchase is further segregated into NBPDCL and SBPDCL as per allocation ratio.
4.6.5. New Sources: The power purchase for the new sources has been considered based on the commissioning status. Further the allocation of power from the new projects is in the ratio of 46:54 for NBPDCL & SBPDCL as per the board resolution.
4.6.6. Taking the realistic point of view currently there are no new plants added to the share allocation as per latest information on Commercial Operational Date (COD) for FY 2017- 18. The Power Purchase Quantum assumed for Bihar as per the Commercial Operation Dates of new generating stations for FY 2017-18 is attached in Annexure B.2
4.6.7. Medium/Short Term Sources: The power purchase from these sources are namely GMR Karmalanga and Adani. Power is not being purchased from Adani currently because of higher cost of supply from May 2016.
4.6.8. The Petitioner shall purchase power through short term from MSTC portal/IEX during the year in any financial year where the quantum and rate of this short term power purchase shall be within the limit of total quantum and rate of power purchase approved by the Hon'ble Commission.
4.6.9. Open Market Purchase: Petitioner is currently procuring power from IEX, DB power, GMR ETL and TATA ETL on the basis of Demand.
4.6.10. Renewable Power Purchase Obligation: It is submitted that Hon’ble Commission has notified the BERC (Renewable Purchase Obligation, its Compliance and REC Framework Implementation), Regulations, 2010, BERC (Multi Year Distribution Tariff) Regulations, 2015 and BERC (Terms and Conditions for Tariff Determination from Solar Energy Sources) Regulations, 2010. Further there were amendments in both Regulations wherein the RPO was modified.
4.6.11. The details of RPO to be met by the Petitioner for FY 2017-18 are given in the table below:
Table 45: Details of RPO to be met for APR
S. Particulars Unit FY 2017-18 No. 1 Energy consumption excluding Nepal MU 7,429.60 2 % of RPO Obligation % 7.75% Solar % 2.25% Non-Solar % 5.50% 3 MUs required as per RPO for the year MU 575.79
North Bihar Power Distribution Company Limited 57 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
S. Particulars Unit FY 2017-18 No. Solar MU 167.16 Non-Solar MU 408.63 Solar Energy to be procured during the 167.16 4 MU year Non-Solar Energy to be procured 408.63 5 MU during the year
4.6.12. The Petitioner has already been drawing solar power from a few sources like SECI, Welspun, ACME clean tech, Avantika and Azure Power. Petitioner has made a few tie ups with the solar power and non-solar power plants which shall add 103.04 MW (long term)
4.6.13. The Petitioner is also taking efforts to tie-up solar power through competitive bid process. Hence, the Petitioner has considered the quantum as approved by Hon’ble Commission for FY 2017-18 for solar and Non-solar. The Petitioner submits that the shortfall may please be allowed to carry forward to next year so as to meet the total RPO on cumulative basis. As has been the practice in the past, in case the Petitioner fails to achieve the Solar and Non-solar RPO, it shall maintain a separate account where the cost of purchase of solar and non-solar power, equivalent to the quantum of shortfall shall be maintained.
4.6.14. Projections for power purchase: Accordingly the revised projections of power purchase for FY 2017-18 is tabulated below:
Table 46: Power purchase Allocation projected for FY 2017-18 (in MW)
SBPDCL NBPDCL BIHAR S.No. Name of The Source (FY 2017-18) (FY 2017-18) (FY 2017-18) 1 Central Sector Stations 1,615.37 1,376.06 2,991.43 2 Talcher – I ( 2 x 500 MW) 224.91 192 417 3 Farakka – I & II (1600 MW) 274.75 234 509 4 Farakka – III (500 MW) 58.32 50 108 5 Kahalgaon – I (840 MW) 191.65 163 355 6 Kahalgaon – II (1500 MW) 40.34 34 75 7 Barh-II 571.86 487 1059 8 Korba - 0 0 9 Rangit – HEP 11.34 10 21 10 Teesta - HEP 58.55 50 108 11 Chukha 43.20 37 80
North Bihar Power Distribution Company Limited 58 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
SBPDCL NBPDCL BIHAR S.No. Name of The Source (FY 2017-18) (FY 2017-18) (FY 2017-18) 12 Tala 140.45 120 260 13 Barh Stage-I (3 X 660 MW) - 0 0 14 State Generating Stations 515 439 954 15 KBUNL 1 118.80 101.2 220 16 KBUNL 2 142.56 121.44 264 17 Small Hydro (BSHPCL) - 0 0 18 Barauni Stage I 118.80 101.2 220 19 Barauni Stage II 135.00 115 250 20 IPP 140.40 119.60 260.00 21 GMR Kamalanga Energy 140.40 119.6 260 22 Adani Enterprises Limited - 0 0 23 JV projects 27.00 23.00 50.00 24 Nabinagar Railway (4 X 250 MW) 27.00 23 50 25 Nabinagar Stage-I (3 X 660 MW) - 0 0 26 Nabinagar JV (3 X 660 MW) Stage-II - 0 0 27 Renewable 120.96 103.04 224.00 28 SECI 5.40 4.6 10.00 29 ACME Magadh 5.40 4.6 10.00 30 ACME Nalanda 8.10 6.9 15.00 31 Sunmark 5.40 4.6 10.00 32 Avantika 2.70 2.3 5.00 33 AZURE 5.40 4.6 10.00 34 Udipta Energy & Equipment Pvt ltd 2.70 2.3 5.00 35 Glatt 1.62 1.38 3.00 36 Welspun 2 8.10 6.9 15.00 37 Welspun 1 5.40 4.6 10.00 38 Alpha Infra Prop 10.80 9.2 20.00 39 Welspun 3 8.10 6.9 15.00 40 Response Renewable energy 5.40 4.6 10.00 41 New Swadeshi Sugar Mill,Narkatiaganj 3.78 3.22 7.00 42 Harinagar Sugar Mills,Harinagar 5.94 5.06 11.00 43 Bharat SugarMills,Sidhiwalia, Gopalganj 5.94 5.06 11.00 44 Lauriya Sugar Mill 10.80 9.2 20.00 45 Sugauli Sugar Mill 10.80 9.2 20.00 46 Hasanpur Sugar Mills,Samastipur 5.40 4.6 10.00 47 Riga Sugar Company Ltd,Sitamarhi 1.62 1.38 3.00
North Bihar Power Distribution Company Limited 59 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
SBPDCL NBPDCL BIHAR S.No. Name of The Source (FY 2017-18) (FY 2017-18) (FY 2017-18) 48 Siddhashram Rice Mill Cluster Pvt Ltd 0.54 0.46 1.00 49 Bihar Distillers and Bottlers Pvt Ltd 1.62 1.38 3.00 50 Grand Total 2,418.89 2,060.54 4,479.43
4.6.15. For Projecting the Power Purchase Quantum for FY 2017-18, The Petitioner has considered the actual Power Purchase quantum for the period April to September 2017 and projected for remaining months based on the following methodology.
i. Share allocation has been considered as actuals of April 2017 to September 2017.
ii. The Plant Load Factor (PLF) for each plant has been calculated on actual basis of FY 2017-18 and then Petitioner has made a consideration to take highest among the following two plant load factors very month of FY 2017-18 from October 2017 to March 2018.
iii. Normative Plant Load Factor Plant (PLF) provided by central Electricity Regulatory Commission (CERC) for the thermal and hydro plants and the auxiliary consumptions specified for plants. For the state plants PLF highest among the PLF norms specified by BERC and the plant wise auxiliary consumption determined by BERC for thermal, and biomass has been considered. For the solar plants highest among the CUF of 19%. The normative PLFs and auxiliary consumption assumptions considered for FY 2017-18 are attached in Annexure B.3.
iv. Actual Plant Load Factor (PLF) of the thermal, hydro, biomass and solar plants in the same month of previous financial year i.e. FY 2017-18
v. Considering the PLF as mentioned above and using the power purchase allocation data mentioned in the above table total number of units purchased were calculated from every source/ plant for every month separately.
vi. Actual PLF for first 6 months of FY 2017-18 and PFL considered for last 6 months of FY 2017-18 are attached in Annexure B.4 4.6.16. The actual power purchase quantum for the first six months of FY 2017-18 is attached in Annexure B.5
4.6.17. Total power purchase: The month wise projections data for the months of October 2017 to March 2018 is added to the actuals of April 2017 to September 2017. The total power purchase (MU) is therefore captured in the below table.
North Bihar Power Distribution Company Limited 60 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
Table 47: Total power purchase for APR (in MU)
S.No. Power Purchase Share Allocation Energy (MU) Sources (MW) 1 Central Sector Stations 1,376.06 8,844.82 2 Talcher – I ( 2 x 500 MW) 191.59 1,346.71 3 Farakka – I & II (1600 MW) 234.05 1,487.50 4 Farakka – III (500 MW) 49.68 330.89 5 Kahalgaon – I (840 MW) 163.25 1,130.23 6 Kahalgaon – II (1500 MW) 34.36 271.07 7 Barh-II 487.14 3,163.36 8 Korba - 0.95 9 Rangit – HEP 9.66 55.52 10 Teesta – HEP 49.88 284.42 11 Chukha 36.80 293.69 12 Tala 119.65 480.48 13 Barh Stage-I (3 X 660 MW) - - 14 State Generating Stations 438.84 742.07 15 KBUNL 1 101.20 299.15 16 KBUNL 2 121.44 312.11 17 Small Hydro (BSHPCL) - 2.01 18 Barauni Stage I 101.20 87.40 19 Barauni Stage II 115.00 41.40 20 IPP 119.60 848.15 21 GMR Kamalanga Energy 119.60 848.15 22 Adani Enterprises Limited - - 23 JV projects 23.00 80.67 24 Nabinagar Railway (4 X 250 MW) 23.00 80.67 25 Nabinagar Stage-I (3 X 660 MW) - - 26 Nabinagar JV (3 X 660 MW) Stage-II - - 27 Renewable 103.04 196.46 28 SECI 4.60 9.07 29 ACME Magadh 4.60 7.17 30 ACME Nalanda 6.90 10.17 31 Sunmark 4.60 7.14 32 Avantika 2.30 2.67 33 AZURE 4.60 5.90 34 Udipta Energy & Equipment Pvt ltd 2.30 2.81 35 Glatt 1.38 1.42 36 Welspun 2 6.90 10.41 37 Welspun 1 4.60 6.75 38 Alpha Infraprop 9.20 5.03 39 Welspun 3 6.90 10.27 40 Response Renewabe Energy 4.60 4.71 41 New Swadeshi Sugar Mill,Narkatiaganj 3.22 8.05 42 Harinagar Sugar Mills,Harinagar 5.06 23.16 43 Bharat SugarMills,Sidhiwalia,Gopalganj 5.06 19.08
North Bihar Power Distribution Company Limited 61 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
S.No. Power Purchase Share Allocation Energy (MU) Sources (MW) 44 Lauriya Sugar Mill 9.20 21.94 45 Sugauli Sugar Mill 9.20 21.20 46 Hasanpur Sugar Mills,Samastipur 4.60 10.59 47 Riga Sugar Company Ltd,Sitamarhi 1.38 3.18 48 Siddhashram Rice Mill Cluster Pvt Ltd 0.46 2.27 49 BDBPL 1.38 3.46 50 Open Market Purchase - 1,267.85 51 IEX/PXIL - 782.11 52 DB Power - - 53 JAYPEE NIGRIE - 117.81 54 JPL - 20.28 55 GMR ETL - 8.01 56 TATA ETL - 36.74 57 Manikaran Power - 232.27 58 NEA - 0.48 59 NVVNL - - 60 PVVNL - - 61 Adani Short Term - 9.07 62 UI - 61.09 63 Sub Total Power Purchase 2,060.54 11,980.03 64 Transmission charges - - 65 PGCIL - - 66 POSOCO & SLDC Charges - - 67 BSPTCL charges - - 68 BGCL - - 69 Total Power Purchase 2,060.54 11,980.03 70 Open Market Purchase 71 Transfer to Other Discom (407.18) 72 Net Power Purchase 2,060.54 11,572.85
4.6.18. As mentioned above considering the new plants will start operation on expected COD as mentioned in the Annexure B.2 the Petitioner has arrived at a power purchase of 11,572.85 MU for FY 2017-18.
4.7. Energy Balance
4.7.1. The energy availability from interstate plants has been computed considering the highest among the normative The Plant Load Factor (PLF) provided by Central Electricity Regulatory Commission (CERC) for the thermal and hydro plants and the auxiliary consumption specified for plants and the actual Plant Load Factor (PLF) in that specific month of previous year (FY 2016-17).
North Bihar Power Distribution Company Limited 62 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
4.7.2. For determining the PLF of state sector plants, the PLF norms specified by BERC and the plant wise auxiliary consumption determined by BERC for thermal, and biomass and actual PLF of the specific month of previous year (FY 2016-17) has been considered (whichever PLF is higher). 4.7.3. For the solar plants maximum among the CUF of 19% and actual in the specific month of previous year (FY 2016-17) has been considered. Based on this the energy available from various plants has been computed for the entire financial year. 4.7.4. The petitioner has considered a PLF of 40% for KBUNL 1 & KBUNL 2. Since the PLF of KBUNL was on the lower side in FY 16-17 (i.e. 33.3%). 4.7.5. The petitioner has considered a PLF of 20% for Baruni Stage I and 10% for Baruni Stage II. Since the PLF of Baruni Stage I for FY 16-17 was 12.77%. 4.7.6. The petitioner has made the above assumptions to reflect the realistic scenario during projections. 4.7.7. Based on above discussed elements such as sales, losses & power availability, the revised projected energy balance for FY 2017-18 is as under –
Table 48: Energy Balance for APR FY 2017-18
S. No. Particulars Unit FY 2017-18 (RE)
1 Energy sales MU 8,618.49 2 Less: Energy supplied to DF area MU 1,007.62 3 Less: Sales to Nepal MU 1,188.89 4 Less: UI MU 0.00 5 Energy sale excluding DF area and Nepal MU 6,421.98 6 Distribution loss % 24.00% 7 Distribution loss MU 2,028.00 8 Energy required (3+5) MU 8,449.98 9 Add: Energy to DF area including loss for DF area MU 1,007.62 10 Energy required at Distribution periphery (7+8) MU 9,457.60 11 Add: Sales to Nepal MU 1,188.89 12 Total energy required (9+10) MU 10,646.49 13 State Transmission loss % 3.92% 14 State Transmission loss MU 434.37 15 Add: UI sales MU 0.00 16 Energy required at State Transmission periphery MU 11,080.86 17 Power Purchase from CGS, SGS and others MU 11,572.85 18 UI MU 0.00 19 Power Purchase from CGS MU 10,884.78 20 Losses in Regional Transmission System (excluding state generating % 2.26% stations) 21 Losses in Regional Transmission system (MU) MU 246.00 22 Power Purchase from SGS MU 442.08 23 Energy available at State Transmission Periphery MU 11,080.86 24 Surplus energy (23-16) MU 0
4.7.8. We humbly request the Hon’ble Commission to approve the aforementioned revised energy balance for FY 2017-18.
North Bihar Power Distribution Company Limited 63 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
4.8. Power Purchase Cost
4.8.1. The power purchase cost mainly comprises of fixed charges and energy charges for two parttariffstationsi.e.NTPC,NHPC&PTCin caseofPetitioner.The Petitionerhasconsidered the actual energy charges and fixed cost for these power stations based on actual 12 months data for FY 2016-17 and actual 6 months information from April 2017 to September 2017.The average power purchase cost as mentioned below.
i. Petitioner has considered the new plants whose COD is in the next 6 months i.e. October 2017 to March 2017.
ii. The power purchase cost projections have been undertaken by considering the average of actual fixed cost and fuel costs respectively for the previous 6 months.
iii. The fixed cost projected using the above mentioned method is calculated to be 1.22 INR/kWh. This has also been adopted for the remaining period of FY 2017-18
iv. The fuel costs have been projected by escalating the average of actual fuel costs of the previous 6 months data of FY 2017-18 by 0 percent.
v. The fuel costs computed by the above method is calculated to be 2.59 INR/kWh
vi. The total cost of power purchase per unit has been calculated to be 4.44 INR/kWh inclusive of all charges. 4.8.2. The Petitioner requestsHon’ble Commission toallow powerpurchase costsfor APR period FY 2017-18 as provided in the table below.
4.8.3. Power purchase costs: The table here provides detailed power purchase costs-
North Bihar Power Distribution Company Limited 64 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
Table 49: Power Purchase Projection for APR (in MW)
S. No. Power Purchase Current Year (FY 2017-18) Sources Share Energy Fixed Fixed Energy Energy Other Total Avg. Allocation (MU) Charge charge Rate Charge charges Charges Tariff (MW) rate (INR Cr) (INR/kWh) (INR Cr) (pl. (INR Cr) Rate (Rs/M specify) (INR/kWh) U) (INR Cr) 1 Central Sector Stations 1,376.06 8,844.82 1.27 1,122.08 2.51 2,217.33 16.68 3,356.09 3.79 2 Talcher – I ( 2 x 500 MW) 191.59 1,346.71 0.89 120.50 1.60 215.56 7.30 343.35 2.55 3 Farakka – I & II (1600 MW) 234.05 1,487.50 0.98 146.05 2.82 420.17 7.30 573.52 3.86 4 Farakka – III (500 MW) 49.68 330.89 1.77 58.67 2.84 94.07 2.86 155.59 4.70 5 Kahalgaon – I (840 MW) 163.25 1,130.23 1.00 112.63 2.49 281.72 0.24 394.58 3.49 6 Kahalgaon – II (1500 MW) 34.36 271.07 0.88 23.73 2.43 65.87 0.04 89.65 3.31 7 Barh-II 487.14 3,163.36 1.97 624.64 2.92 924.95 (1.12) 1,548.48 4.90 8 Korba - 0.95 1.42 0.13 1.15 0.11 0.00 0.24 2.57 9 Rangit – HEP 9.66 55.52 1.76 9.77 1.96 10.86 0.01 20.64 3.72 10 Teesta - HEP 49.88 284.42 0.91 25.96 1.16 32.99 0.07 59.02 2.08 11 Chukha 36.80 293.69 - - 2.29 67.25 (0.03) 67.23 2.29 12 Tala 119.65 480.48 - - 2.16 103.78 - 103.78 2.16 13 Barh Stage-I (3 X 660 MW) ------14 State Generating Stations 438.84 742.07 1.38 102.06 3.41 253.31 - 355.37 4.79 15 KBUNL 1 101.20 299.15 1.41 42.06 3.41 101.97 - 144.03 4.81 16 KBUNL 2 121.44 312.11 1.92 60.00 3.16 98.57 - 158.57 5.08 17 Small Hydro (BSHPCL) - 2.01 - - 2.49 0.50 - 0.50 2.49 18 Barauni Stage I 101.20 87.40 - - 4.10 35.83 - 35.83 4.10 19 Barauni Stage II 115.00 41.40 - - 3.97 16.44 - 16.44 3.97 20 IPP 119.60 848.15 1.95 165.23 1.13 95.46 42.36 303.05 3.57 21 GMR Kamalanga Energy 119.60 848.15 1.95 165.23 1.13 95.46 42.36 303.05 3.57 22 Adani Enterprises Limited ------23 JV projects 23.00 80.67 2.21 17.84 1.99 16.05 - 33.88 4.20 24 Nabinagar Railway (4 X 250 MW) 23.00 80.67 2.21 17.84 1.99 16.05 - 33.88 4.20 25 Nabinagar Stage-I (3 X 660 MW) ------
North Bihar Power Distribution Company Limited 65 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
S. No. Power Purchase Current Year (FY 2017-18) Sources Share Energy Fixed Fixed Energy Energy Other Total Avg. Allocation (MU) Charge charge Rate Charge charges Charges Tariff (MW) rate (INR Cr) (INR/kWh) (INR Cr) (pl. (INR Cr) Rate (Rs/M specify) (INR/kWh) U) (INR Cr) 26 Nabinagar JV (3 X 660 MW) Stage-II ------27 Renewable 103.04 196.46 - - 4.67 91.69 - 91.69 4.67 28 SECI 4.60 9.07 - - 5.62 5.10 - 5.10 5.62 29 ACME Magadh 4.60 7.17 - - 8.73 6.26 - 6.26 8.73 30 ACME Nalanda 6.90 10.17 - - 8.73 8.88 - 8.88 8.73 31 Sunmark 4.60 7.14 - - 7.02 5.01 - 5.01 7.02 32 Avantika 2.30 2.67 - - 7.69 2.05 - 2.05 7.69 33 AZURE 4.60 5.90 - - 8.39 4.95 - 4.95 8.39 34 Udipta Energy & Equipment Pvt ltd 2.30 2.81 - - 7.98 2.25 - 2.25 7.98 35 Glatt 1.38 1.42 - - 7.02 1.00 - 1.00 7.02 36 Welspun 2 6.90 10.41 - - 8.64 8.99 - 8.99 8.64 37 Welspun 1 4.60 6.75 - - 8.70 5.87 - 5.87 8.70 38 Alpha Infraprop 9.20 5.03 - - 7.02 3.53 - 3.53 7.02 39 Welspun 3 6.90 10.27 - - 8.56 8.79 - 8.79 8.56 40 Response Renewabe Energy 4.60 4.71 - - 7.02 3.31 - 3.31 7.02 41 New Swadeshi Sugar Mill,Narkatiaganj 3.22 8.05 ------42 Harinagar Sugar Mills,Harinagar 5.06 23.16 - - 5.34 12.37 - 12.37 5.34 43 Bharat SugarMills,Sidhiwalia, Gopalganj 5.06 19.08 - - 5.04 9.62 - 9.62 5.04 44 Lauriya Sugar Mill 9.20 21.94 ------45 Sugauli Sugar Mill 9.20 21.20 ------46 Hasanpur Sugar Mills,Samastipur 4.60 10.59 - - 0.01 0.01 - 0.01 0.01 47 Riga Sugar Company Ltd,Sitamarhi 1.38 3.18 ------48 Siddhashram Rice Mill Cluster Pvt Ltd 0.46 2.27 - - 7.41 1.68 - 1.68 7.41 49 BDBPL 1.38 3.46 - - 5.80 2.01 - 2.01 5.80 50 Open Market Purchase - 1,267.85 - - 4.02 509.10 1.93 511.03 4.03 51 IEX/PXIL - 782.11 - - 3.95 309.32 1.93 311.25 3.98 52 DB Power ------
North Bihar Power Distribution Company Limited 66 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
S. No. Power Purchase Current Year (FY 2017-18) Sources Share Energy Fixed Fixed Energy Energy Other Total Avg. Allocation (MU) Charge charge Rate Charge charges Charges Tariff (MW) rate (INR Cr) (INR/kWh) (INR Cr) (pl. (INR Cr) Rate (Rs/M specify) (INR/kWh) U) (INR Cr)
53 JAYPEE NIGRIE - 117.81 - - 2.82 33.17 - 33.17 2.82 54 JPL - 20.28 - - 2.87 5.81 - 5.81 2.87 55 GMR ETL - 8.01 - - 3.19 2.56 - 2.56 3.19 56 TATA ETL - 36.74 - - 3.83 14.05 - 14.05 3.83 57 Manikaran Power - 232.27 - - 4.65 108.01 - 108.01 4.65 58 NEA - 0.48 - - 2.72 0.13 - 0.13 2.72 59 NVVNL ------60 PVVNL ------61 Adani Short Term - 9.07 - - 4.77 4.33 - 4.33 4.77 62 UI - 61.09 - - 5.19 31.73 - 31.73 5.19 63 Sub Total Power Purchase 2,060.54 11,980.03 1.17 1,407.20 2.66 3,182.93 60.97 4,651.11 3.88 64 Transmission charges ------667.21 - 65 PGCIL ------319.75 - 66 POSOCO & SLDC Charges ------5.73 - 67 BSPTCL charges ------257.34 - 68 BGCL ------84.39 - 69 Total Power Purchase 2,060.54 11,980.03 1.17 1,407.20 2.66 3,182.93 60.97 5,318.32 4.44 70 Sale of Power to Other Discom (407.18) 4.44 -180.76 -180.76 4.44 71 Net Power Purchase 2,060.54 11,572.85 1.22 1,407.20 2.59 3,002.17 60.97 5,137.56 4.44
North Bihar Power Distribution Company Limited 67 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
4.8.4. The Petitioner humbly requests the Hon’ble Commission to approve the above mentioned revised power purchase cost for the utility for FY 2017-18.
4.9. Transmission Charges
4.9.1. It is submitted that the Petitioner has to pay transmission charges to PGCIL for use of transmission facilities enabling power drawl from eastern region. The calculation of PGCIL charges is done by taking the average of 6 months actuals and then adding some growth rate as per the increase in the power purchase.
4.9.2. Further the Petitioner also pays BSPTCL, POSOCO charges and Open Access charges which are projected in the similar way as projected for PGCIL charges.
4.9.3. We request the Hon’ble Commission to approve the transmission and related charges for inter-state as well as intra-state transmission transactions for FY 2017-18 as per the below given table –
Table 50: Transmission charges for APR (in INR Crore)
Utilities Transmission Charge PGCIL 319.75 POSOCO & SLDC Charges 5.73 BSPTCL charges 257.34 BGCL 84.39 Total transmission Charges 667.21
4.10. Capital Investment Plan, Capitalization and Funding
4.10.1. The Petitioner submits that it has estimated Capex, Capitalization and funding taking into account the capital expenditure and investments to be done as per the recent developments and keeping in mind the targets to be achieved for Capitalization under various schemes during the forthcoming years. In line with the above, the Petitioner has computed the capitalization of investment on the assumption that 80% of the capitalization will come from opening CWIP and 20% of the capitalization from fresh investment in FY 2017-18.
4.10.2. During FY 2017-18 and forthcoming years Petitioner is owing to huge capitalization since, various schemes (BRGF, RAPDRP, RGGVY, MP LADS, NABARD etc.) are in the final stage of completion. The Discoms are specifically focusing on capitalization of assets created under various schemes post unbundling of BSEB
North Bihar Power Distribution Company Limited 68 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
4.10.3. The opening figures of CWIP, Gross Fixed Assets, Grants, etc. are taken from the audited annual accounts for FY 2016-17.
4.10.4. It is to be noted that the Petitioner has considered the sources of funding into Grant, equity and Loan as per the actual sources and have documentary evidence in this regard. Also, the Petitioner is submitting the detailed Capitalization plan in the Additional formats requested by the Hon’ble Commission.
4.10.5. The below table represents the capitalization plan for NBPDCL
Table 51: Capitalization plan for FY 2017-18 (in INR Crore)
S. No. Name of the Scheme FY 2017-18 (RE)
1 BRGF, Special plan Phase- I 600.58 2 BRGF, Special plan Phase- II 3 BRGF, Special plan Part "C" 4 BRGF RE Portion 5 RAPDRP Part A 67.37 6 RAPDRP Part B 7 APDRP 0.00 8 NABARD Phase VIII 9.16 9 NABARD Phase XI 7.36 10 MP/CM LAD 9.01 11 Deposit Scheme 5.07 12 ADB 20.86 13 ACA State Plan 10.10 14 Burnt DTR State Plan 43.47 15 State Plan 144.50 16 RSVY 0.00 Sub Total (A) 917.48 New Scheme 17 CM Seven Resolution (Har Ghar Bijli) 0.00 18 IPDS 38.64 Sub Total (B) 38.64 19 RGGVY 11th Plan Phase- I 1,198.60 20 RGGVY 11th plan Phase- II 21 RGGVY 12th Plan Sub Total (C) 1,198.60 New Scheme 22 DDUGJY 136.44 Sub Total (D) 136.44 Sub Total (A+B+C+D) 2,291.16 23 Own Sources 0.00 Grand Total 2,291.16
4.10.6. The Hon’ble Commission is requested to consider the capitalization plan as estimated for FY 2017-18. 4.10.7. The details of the opening CWIP, investment during the year, capitalization and funding for CAPEX for FY 2017-18 is detailed in the table below:
North Bihar Power Distribution Company Limited 69 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
Table 52: CWIP, Capitalization and Funding of Capitalization projected for FY 2017-18 (in INR Crore)
Particulars Current year (2017-18) S. No (RE) 1 Opening CWIP 6,827.52 2 New Investment 6,557.08 3 Less Capitalization 2,291.16 (a) CWIP 1,832.93 (b) New Investment 458.23 4 Closing CWIP (1+2-3) 11,093.44 5 Funding (a) CWIP Capitalization 1,832.93 (i) Grant 971.51 (ii) Loan 208.49 (iii) Equity 652.92 (b) New Investment Capitalization 458.23 (i) Grant 242.88 (ii) Loan 52.12 (iii) Equity 163.23 6 Total capitalization 2,291.16 (i) Total Grant 1,214.39 (ii) Total Loan 260.62 (iii) Equities 816.15
4.11. Operation & Maintenance (O&M) Expenses
4.11.1. As per regulation 22 of BERC (Multi Year Distribution Tariff) Regulations, 2015, O&M expenses comprises of Repair and maintenance expenses, Administrative & General expenses and employee expenses. In the below paragraphs the Petitioner would like to submit the estimated expenses on account of O&M for FY 2017-18 along with the reasoning and basis of projections.
4.11.2. Employee Expenses: Regulation 22.1 of Bihar Electricity Regulatory Commission (Multi Year Distribution Tariff) Regulations, 2015 provides methodology for calculation of Employee Cost as follows:
“Employee cost shall be computed as per the approved norm escalated by consumer price index (CPI), adjusted by provisions for expenses beyond the control of the Distribution Licensee and one time expected expenses, such as recovery/adjustment of terminal benefits, implications of pay commission, arrears and Interim Relief, governed by the following formula: EMPn = (EMPb * CPI inflation) + Provision Where: EMPn : Employee expense for the year n EMPb : Employee expense as per the norm CPI inflation : is the average increase in the Consumer Price Index (CPI) for immediately preceding three years Provision : Provision for expenses beyond control of the Distribution Licensee and expected one-time expenses as specified above.
North Bihar Power Distribution Company Limited 70 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
Till the norms is specified by the Commission the employee cost shall be determined on the basis of actual historical cost.”
4.11.2.1. The Petitioner has considered audited accounts of FY 2016-17 as base year for projecting employee expenses. The projections of employee expenses are based on new recruitment plan for FY 2017-18.The Petitioner has also taken Pay Revision in line with recommendation of the VIIth Central Pay Commission into account, with effect from 01.01.2016. The Petitioner has considered the impact of VIIth pay commission on employee expenses considering a multiplying factor of 2.62 from a range of 2.57 to 2.72 during the projections for FY 2017-18. Against these backdrop, BSPHCL has revised the pay structure of its employees.
4.11.2.2. Petitioner has initiated recruitment procedure for FY 2017-18 to appoint approximately 400 employees on its payroll. Also, it is pertinent to mention that the projections of expenses is done taking into account the retrials planned in FY 2017-18.
4.11.2.3. The projection of Dearness Allowance (D.A.) is based on 6 months actual expenses incurred in the period between Apr’17 to Sep’17 and 6 months forecasted on the basis of projected increment as a percentage of basic salary.
4.11.2.4. The terminal benefits and all other benefits are increased @ 10% seeing the additional employees’ requirement during the financial year. The detail of employee expenses for FY 2017-18 are shown as below –
Table 53: Employee Expenses for APR (in INR Crore)
S. No Particulars FY 2018-19 1 Salaries 218.00 2 Over Time 1.06 3 Dearness Allowance 21.80 4 Other Allowance 8.91 5 Medical Expenses Re-imbursement 0.47 6 Leave Salary Contribution 9.81 7 Free Electricity 0.00 8 Payment under Workmen Compensation Act 0.00 9 Staff Welfare Expenses 0.16 10 Terminal Benefits 18.76 11 Total 278.96
4.11.2.5. Therefore, the Petitioner would like to submit that projections have been done on the basis of employment plan during the year and since employee cost is a significant factor in any organization, it is requested to the Hon’ble Commission to approve the above given figure towards employee cost for FY 2017-18.
4.11.3. Repair and maintenance expenses: The R&M expenses primarily includes expenses incurred by the Petitioner related to repair of different class of fixed assets etc. Regulation
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22.2 of Bihar Electricity Regulatory Commission (Multi Year Distribution Tariff) Regulations, 2015 provides methodology for calculation of Employee Cost as follows:
“22.2 Repairs and Maintenance (R&M) Expense Repairs and Maintenance expense shall be calculated as percentage (as per the norm determined) of Opening Gross Fixed Assets for the year governed by following formula: R&Mn = Kb * GFAn Where: R&Mn : Repairs & Maintenance expense for nth year GFAn : Opening Gross Fixed Assets for nth year Kb : Percentage point as per the norm”
4.11.3.1. The Petitioner has accordingly computed the ‘K’ factor (i.e. R&M norm) based on available 3 (three) years audited accounts for FY 2014-15 to FY 2016-17 as given below:
Table 54: Calculation of “K” Factor for FY 2017-18
Particulars FY 2014-15 FY 2015-16 FY 2016-17 Closing GFA (in INR Crore) 4,004 4,299 4,574 R&M Cost (in INR Crore) 59.85 64.98 49.21 % of R&M Cost on Opening GFA 1.49% 1.51% 1.08% K Factor considered for FY 2017-18 1.35%
4.11.3.2. The Petitioner has computed the R&M expenses adopting ‘K’ factor on the Opening GFA for FY 2017-18 as detailed in the Table below:-
Table 55: R&M Expenses for APR (in INR Crore)
S. No Particulars Current Year (RE) FY 2017-18 1 Plant & Machinery 2.74 2 Building 0.14 3 Hydraulic works & civil works 0.29 4 Line cable & network 66.53 5 Vehicles - 6 Furniture & fixtures 0.00 7 Office equipment’s 0.02 8 Total expenses 69.72 9 Less capitalized 0.00 10 Net Expenses 69.72 11 Total expenses charged to revenue 69.72
4.11.3.3. Therefore, it is requested to the Hon’ble Commission to approve INR 69.72 Crore towards expenses against R&M as claimed by the Petitioner.
4.11.4. Administrative and General Expenses: Administration and General expenses mainly comprise costs towards rent charges, telephone and other communication expenses, professional charges, conveyance and travelling allowances and other debits.
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4.11.4.1. The Petitioner is projecting A&G expenses on the basis of actual expenses incurred from Apr’17 to Sep’17 and then the projection is done for next 6 months based on the actual data for 6 months. The below table represents the estimated expenses determined by the Petitioner on account of Administrative & General expenses.
Table 56: A&G Expenses for APR (in INR Crore)
S. No. Particulars Current year (RE) FY 2017-18 1 Rent, Rates & Taxes 0.29 2 Insurance 3.17 3 Telephone, Postage & Telegrams 10.00 4 Consultancy fees 0.06 5 Technical fees - 6 Other professional charges 8.20 7 Conveyance &travel expenses 8.46 8 Electricity & Water charges 4.72 9 Freight 0.44 10 Remuneration to Executive Assistant 5.00 11 Commission to RRF 22.49 12 Printing and Stationery 1.28 13 Meter reading and Bill Distribution 4.53 14 Home guard / Security guard 2.78 15 Other material related expenses 0.00 16 Commission 1.22 17 Computer Billing 10.39 18 Compensation (if any) 5.10 19 Holding Tax exp. 10.90 20 Any other expenses 4.23 21 Total expenses 103.27 22 Less Capitalized - 23 Net expenses 103.27 24 Total expenses charged to revenue 103.27
4.11.4.2. It is requested to the Hon’ble Commission to approve the Administrative and General expenses of INR 103.27 Crore for FY 2017-18.
4.11.5. Allocation of Holding Company cost: As per Schedule ‘F”, the Holding Company shall handle all issues relating to the subsidiary companies in respect of: -
“SCHEDULE“F”REORGANISATIONOFBSEB&TRANSFEROF PERSONNEL Part II COMMON SERVICES The Testing Divisions, Training Department at Head-Quarter and all the Departments at the Corporate Head Office like – General Administration Accounts and Finance IT Stores & Purchase
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Transmission/Distribution/Generation Personnel Publicity Legal Vigilance and Security Commercial Planning Civil Engineering Transmission (O&M) Rural Electrification Shall constitute “Common Services‟ which shall continue to provide services to all successor entities during the Interregnum period, until issue of further transfer notifications allocating the employees to respective companies.”
4.11.5.1. The Petitioner is claiming the holding company expenses taking the expenses incurred in FY 2016-17 as the same and escalating it by 10% for projecting for Annual performance review of FY 2017-18. The below table represents the allocation of Holding Company cost towards the Petitioner for FY 2017-18:-
Table 57: Allocation of Holding Company Cost for APR (in INR Crore)
S. No Particulars FY 2017-18 (RE)
1 Previous year expenses 5.38 2 Inflation rate considered 0.10 3 Inflationary increase (1*2) 0.54 4 Employee expenses 0.00 5 R&M expenses 0.00 6 A&G expenses 0.00 7 Total 5.92
4.11.5.2. The total expenses given in the above table are allocated in employee cost, R&M expenses and R&M expenses on the basis of actual cost ratio in FY 2016-17. 4.11.5.3. Therefore the Petitioner requests the Hon’ble Commission to approve INR 5.92 Crore towards holding company expenses for FY 2017-18.
4.11.6. Summary of O&M Expenses: The below table summarizes the O&M expenses estimated by the Petitioner for FY 2017-18:-
Table 58: Summary of O&M Expenses for APR (in INR Crore)
S. No. Particulars FY 2017-18 1 Employee Cost 237.63 2 R&M Expense 69.72 3 A&G Expenses 103.27 4 Holding Company Expenses 5.92 5 Total O&M Cost 416.54
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4.12. Gross Fixed Assets
4.12.1. The Petitioner hereby submits the computation of Gross Fixed Assets considering the opening fixed assets, capitalization as per the new schemes in FY 2017-18. 4.12.2. Through various new schemes like DDUGJY, IPDS etc introduced during FY 2017-18 huge Capitalization is planned in FY 2017- 18. The Petitioner has provided the detailed Capitalization plan in additional information requested by the Hon’ble Commission explaining the sources of funding in every schemes like equity, loan and grants. 4.12.3. The table below demonstrates the Asset addition planned in FY 2017-18 and closing balance of Gross Fixed Assets as on FY 2017-18 –
Table 59: Summary GFA for FY 2017-18 (in INR Crore)
S. Assets group Closing balance Addition during Closing balance No FY 2016-17 FY 2017-18 (RE) FY 2017-18 (RE)
1 Land and land rights 1,004.68 55.42 1,060.10 2 Buildings 37.82 1.45 39.27 3 Hydraulic Works 0.00 - 0.00 4 Others Civil Works 5.11 3.32 8.43 5 Plant and Machinery 630.21 118.95 749.17 6 Lines and Cable Network 3,457.13 2,108.07 5,565.20 7 Vehicles 1.52 0.02 1.54 8 Furniture and Fixtures 2.90 0.74 3.64 9 Office Equipment 3.95 3.20 7.15 Total 5,143.34 2,291.16 7,434.50 10 Capital expenditure resulting in - - an assets not belonging to Company 11 Spare Units/Service Units 14.03 14.03 12 Capital spare at generating - - station 13 Assets taken over from Licensees 0.84 0.84 pending final valuation GRAND TOTAL 5,158.21 2,291.16 7,449.37
4.12.4. Gross Fixed Assets (GFA) is funded through equity, Loan and grants. The Hon’ble Commission is requested to approve the GFA as determined by the Petitioner for FY 2017- 18. The Petitioner has annexed the detailed capitalization plan in the additional formats requested by the Hon’ble Commission.
4.13. Depreciation on Gross Fixed Assets
4.13.1. As per regulation 23 of Bihar Electricity Regulatory Commission (Multi Year Distribution Tariff) Regulations, 2015 the Petitioner has estimated the depreciation on the Gross Fixed assets reduced by grants. The Petitioner has calculated depreciation on GFA based on the Capitalization plan for FY 2017-18.
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4.13.2. The Petitioner would like to clarify that while claiming the depreciation the value of Land and addition thereon is reduced from the opening value and additions during the year. 4.13.3. As per the standard practice, the Petitioner shall not be allowed any depreciation on account of assets that has been capitalized through grants. Therefore the Petitioner has reduced the Depreciation on the assets which were added through grants. 4.13.4. The GFA at the beginning of the year (excluding value of Land) is INR 4153.53 Crore which is the closing GFA as per the audited accounts for FY 2016-17.The addition to GFA excluding value of land comes to INR 2854.23 Crore. 4.13.5. The Petitioner has considered closing grant of INR 2043.14 Crore in FY 2016-17 as per the audited books of accounts as the opening grant for FY 2017-18. The total value of grant has been reduced from the value of Gross GFA. The weighted average rate for depreciation comes to 6.15 % in FY 2017-18. 4.13.6. Below is the table representing the calculations for claiming depreciation for FY 2017-18 :
Table 60: Depreciation on GFA for APR (in INR Crore)
S. Particulars Current (RE) No. FY 2017-18 1 Opening GFA 5,158.21 2 Less: Value of Land 1,004.68 3 Net Opening GFA 4,153.53 4 Additions during the year (Excluding land value) 2,235.75 5 IDC 6 Expenses Capitalized 7 Closing GFA 6,389.27 8 Average GFA 5,271.40 9 Weighted Average Rate of Depreciation 5.89% 10 Gross Depreciation 310.49 11 Opening grants 2,043 12 Grants during the year 1,185 13 Total Grants 3,228.16 14 Average Grants 2,636 15 Weighted Average rate of Depreciation 6.27% 16 Depreciation for GFA on Grants 165.28 17 Net Depreciation of GFA on loans (7-13) 145.21
4.13.7. It is to be noted that the matter of depreciation was filed in the Appeal no 142 of 2016 by the Petitioner. The decision for the appeal came on 25th November, 2016. 4.13.8. The relevant excerpt from the Appeal order is as under:- “In our opinion, the depreciation is an important segment and needs to be re-examined by the State Commission keeping in view the relevant details submitted by the Appellant subject to its prudent check. The Appellant is entitled to raise the issue of
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rate of depreciation also before the State Commission while the depreciation amount is being re-examined by the State Commission .
4.13.9. Therefore, in the light of the above facts and calculations, it is requested to the Hon’ble Commission to approve the above given figure of INR 145.21 Crore towards depreciation on Fixed Assets for FY 2017-18.
4.14. Return on Equity
4.14.1. The Regulation 27 of BERC (Multi Year Distribution Tariff) Regulations,2015 provides for calculation of Return on Equity as demonstrated as under: “27. Treatment of Return on equity (a) Return on equity shall be computed on 30% of the capital base or actual equity, whichever is lower: Provided that assets funded by consumer contribution, capital subsidies/ grants and correspondingdepreciation shall not formpartof the capital base.Actual equity invested in the Distribution Licensee as per book value shall be considered as perpetual and shall be used for computation in this Regulation: (b) The return on the equity invested shall be allowed from the date of start of commercial operation: (c) The project which will be commissioned w.e.f. 01.04.2016 will be allowed RoE of 15.5% and if project is completed in schedule period 0.5% incentives in form of RoE will be allowed.”
4.14.2. The Government of Bihar has also infused a capital of INR 447 crores as equity. It is to be noted that petitioner is not claiming any RoE on this capital, since the capital infused is not used for developing infrastructure or assets and therefore it does not impact the ARR calculations. The Government of Bihar notification related to above capital infusion is attached as Annexure B.8 4.14.3. The Petitioner has calculated return on equity on the basis of the closing balance of fixed assets as claimed in True up for FY 2016-17.The 30% of the addition in GFA is added to the opening GFA which is further reduced by 30% of the grant contributing to the addition of Fixed Assets. 4.14.4. The rate of return on equity is calculated at the rate of 16% of the average equity. The below table demonstrates the calculation for Return on equity:-
Table 61: Return on equity for APR (in INR Crore)
Amount of S. No. Particulars equity 1 Amount of total asset at the beginning 1,547.46 2 Less: asset created from grant at beginning 612.94 3 Addition during the year 687.35 4 Less: asset created from grant during the year 355.51
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Amount of S. No. Particulars equity 5 Net asset 1,266.36 Less: Normative repayment 6 Amount of debt(loan) Average equity and debt 1,406.91 7 Amount of equity 1,406.91 8 Debt equity ratio 9 Amount of equity eligible for return 1,406.91 10 Rate of return on equity 16.00% 11 Amount of return on equity 225.11
4.14.5. It is to be noted that the matter of Return on equity was filed in the Appeal no 141 of 2016 by the Petitioner. The decision for the appeal came on 25 th November, 2016.
4.14.6. The relevant excerpt from the Appeal order is as under:-
“The matter for consideration is only whether the amount contributed by the State Government towards equity capital should be considered equity or not. To be fair to the Appellant, the State Commission is directed to re-examine whether the contribution of the State Government towards equity capital should be considered as equity or not and accordingly pass an appropriate order.”
4.14.7. The Petitionerhasdone the calculationskeeping in mind the relevant regulation in the context of return on equity. 4.14.8. In the light of above facts, the Petitioner requests the Hon’ble Commission to approve INR 225.11 towards return on equity for FY 2017-18.
4.15. Interest on Consumer Security Deposit
4.15.1. The Petitionerhastaken the opening balanceofconsumersecuritydepositasper the audited financial statements for FY 2016-17. 4.15.2. It has been assumed that the additions to the balance of consumer security deposits is as per actual addition in FY 2016-17. Therefore INR 37.73 Crore is considered as addition in consumer security deposits for FY 2017-18. 4.15.3. The interest on consumer security deposits is calculated at the rate of 7.75% which is bank rate of RBI as on 01.04.2017.
Table 62: Interest on consumer security deposit (in INR Crore)
S. No Particulars FY 2017-18 (RE) 1 Opening Security Deposit 271.54 2 Addition / (Deletion) during the year 37.73 3 Closing Security Deposit 309.27 4 Average Security Deposit (1+3)/2 290.40 5 RBI Bank Rate 7.75% 6 Interest on Security Deposit 22.51
4.15.4. The Petitioner requests Hon’ble Commission to approve the computation of interest on security deposit for FY 2017-18.
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4.16. Interest on Working Capital
4.16.1. The Petitioner has estimated the amount of interest on Working capital for FY 2017-18 as per Regulation 26 of BERC Regulations, 2015. “26. Interest on Working Capital The Distribution Licensee shall be allowed interest on estimated level of working capital for the financial year, computed as follows: a) O&M expenses for one month b) Two months equivalent of expected revenue c) Maintenance spares @ 40% of R&M expenses for one month: Less: (j) Power purchase cost, transmission charges and load dispatch charges of one month (ii) Depreciation, return on equity and contribution to contingency reserves (iii) Security deposits from consumers, if any. Provided that the interest on working capital shall be on normative basis and rate of interest shall be equal to the State Bank Advance Rate (SBAR) as of the date on which petition for determination of tariff is accepted by the Commission. Provided further that interest shall be allowed on consumer security deposits and security deposits from Distribution System users at the Bank Rate as of the date on which the petition for determination of tariff is accepted by the Commission. Provided further that if the State Governmentisproviding resource gap grantor subsidy, working capital shall be reduced by that amount.”
4.16.2. The Petitioner has taken O&M expenses for 1 month which amounts to INR 34.71 Crore. The Gross working capital requirement is reduced by depreciation, ROE for 1 month, consumer security deposit and grant for 2 months. 4.16.3. The total subsidy received and to be received by the Petitioner from State Government amounts to INR 1165.50 Crore. The Petitioner has not considered any grant against disallowed power purchase for low distribution loss, since the distribution loss considered by the Petitioner is in line with the loss trajectory approved by the Hon’ble commission for FY 2017-18. 4.16.4. The interest on working capital is calculated at the rate of 14.75% which is SBI advance rate. 4.16.5. Also it is pertinent to note that the Petitioner has taken short term loans from REC and PFC for payment of Power Purchase liability. In addition to it there are other short term loans like bank overdraft etc. on which Petitioner is bearing huge interest burden, 4.16.6. In the light of the above facts the Petitioner would submit that it is incurring the interest on working capital at a higher level than as calculated as per normative requirement.
Table 63: Interest on working capital for APR (in INR Crore)
S. No Particulars FY 2017-18 (RE) 1 O&M expenses (1 month) 34.71 2 Two months equivalent of expected Revenue 1,038.19 3 Maintenance Spares @40% of R&M expense for one month 2.32 428.13 4 Less: Power Purchase cost, Load dispatch charges and transmission charges for one month
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S. No Particulars FY 2017-18 (RE) 61.72 5 Less: Depreciation, ROE, Contribution to contingency reserve equivalent to two months 6 less: Security Deposit from consumer if any 24.20 - 7 Less: Grant received from Govt for power purchase and other O&M expense equivalent to two months 8 Net Working Capital 561.18 9 Interest rate 14.75% 10 Interest on Working Capital 82.77
4.16.7. The Petitioner requests Hon’ble Commission to approve the interest on working capital at INR 82.77 Crore for FY 2017-18.
4.17. Subsidy Details
4.17.1. The total subsidy received and to be received by the Petitioner from State Government amounts to INR 1165.50 Crore.
4.18. Non-Tariff Income
4.18.1. Non-Tariff income includes meter rent, bank charges, interest on investments and bank balances. 4.18.2. ThePetitionerhasprojectednon-tariffincomeforFY2017-18onthebasisof10%escalation on the non-tariff income in FY 2016-17. 4.18.3. Below table demonstrates the estimates for non-tariff income for FY 2016-17:-
Table 64: Non-tariff income for APR (in INR Crore)
S. No. Category Projected in APR for FY 2017-18 1 Base Non-tariff income 216.01 2 Rate of Increase 10% 3 Increase in non-tariff income 21.60 4 Total Non-tariff income 237.61
4.18.4. The Petitioner has then deducted the cost of funding the DPS from the total Non-Tariff Income and calculated the net Non-tariff income as follows:
Table 65: Net-Non-tariff income for APR (in INR Crore)
S. Particulars Amount No. 1 Total Non-tariff income 237.61 2 DPS as per Audited Accounts 58.60
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3 Principal amount on which DPS Charged 325.58 4 Interest Rate of funding DPS 14.75% 5 Interest on funding Principal 48.02 6 Net Non-Tariff Income 189.59
4.18.5. The Petitioner requests Hon’ble Commission to approve net non-tariff income for FY 2017-18 amounting to INR 189.59 Crore.
4.19. Interest on Normative Debt
4.19.1. The Petitioner has calculated normative interest on loans on 70% of the addition in GFA in FY 2017-18. 4.19.2. The opening balance of GFA funded through debt is taken as INR 3610.75 Crore which is the closing balance as determined in the true up for FY 2016-17.The addition to GFA as per the estimations is INR 4,900.50 Crore of which 70% addition i.e. INR 3,430.35 Crore is added in the opening balance of GFA. The additions to GFA are further subtracted by 70% of total Grants contributing to the addition of fixed assets which is INR 1311.49 Crore .The normative repayment equivalent to depreciation claimed is taken as INR 243.25 Crore. 4.19.3. The interest on normative debt is calculated at the rate of 10.03% i.e. weighted average rate on project Loans. The below table demonstrates the calculation:-
Table 66: Computation of weighted average rate of interest on project loans
S. No Particulars FY 2017-18 (RE) 1 Opening Balance a APDRP & RAPDRP 499,408,412 b REC 1,698,357,984 c ADB 638,720,737 A Total(1) 2,836,487,133 2 Additions during the year a APDRP & RAPDRP - b REC - c ADB 100,000,000 B Total(2) 100,000,000 3 Repayment of Loans a APDRP & RAPDRP 85,000,000 b REC 355,000,000 c ADB - C Total(3) 440,000,000 4 Closing balance of Loans a APDRP & RAPDRP 414,408,412 b REC 1,343,357,984 c ADB 738,720,737 D Total(4) 2,496,487,133 5 Interest on Loans a APDRP & RAPDRP 41,121,757
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S. No Particulars FY 2017-18 (RE) b REC 136,877,219 c ADB 89,533,696 E Total(5) 267,532,671
6 Average Loans (A+D)/2 2,666,487,133 7 Total interest 267,532,671 8 Weighted average rate of interest on project Loans(7/6) 10.03%
Table 67: Interest on Normative debt (in INR Crore)
S. No. Particulars Amount of loan 1 Amount of total asset at the beginning 3,610.75 2 Less: asset created from grant at beginning 1,430.20 3 Addition during the year 1,603.81 4 Less: asset created from grant during the year 829.51 5 Net asset 2,954.85 Less: Normative repayment 145.21 6 Amount of debt(loan) 2,809.64 Average Debt 3,210.19 7 Amount of Debt considered for Interest 3,210.19 8 Debt equity ratio 9 Amount of loan eligible for Interest 3,210.19 10 Weighted Average Rate of Interest 10.03% 11 Interest on Normative debt 322.08
4.19.4. Therefore, the Petitioner requests the Hon’ble Commission to approve interest on normative debt at INR 322.08 Crore
4.20. Other Finance Charges
4.20.1. Other Finance charges includes power factor rebate, Interest to suppliers/ contractors, rebate to consumers etc. The finance charges for FY 2017-18 is calculated by escalating the Finance charges for FY 2016-17 by 10%. 4.20.2. The below table demonstrates the Finance charges estimated for FY 2017-18:-
Table 68: Other finance charges (in INR Crore)
Particulars Amount Finance Charges for FY 2016-17 60.87 Escalation Considered 10% Escalated Amount 6.7 Finance Charge 66.96
4.20.3. Therefore, the Petitioner requests the Hon’ble Commission to approve the finance charges of INR 66.96 Crore for FY 2017-18.
4.21. Revenue from Sale of Power at Existing Tariff for FY 2017-18
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4.21.1. Following is the category wise revenue based on the existing tariff for FY 2017-18 based on existing tariff:
Table 69: Revenue from sales of power at existing tariff for FY 2017-18 (in INR Crore)
FY 2017-18 Category Sales ( MU) ABR (INR/kWh) (RE) Domestic 4,365.17 1,608.0 3.68 Kutir Jyoti- BPL Consumers 1,271.23 305.6 2.40 Domestic - I 1,651.16 557.4 3.38 Domestic - II 1,442.78 744.9 5.16 Commercial 743.42 548.4 7.38 Non-Domestic - I 77.85 32.1 4.12 Non-Domestic - II 665.57 516.3 7.76 Public Lighting 16.03 14.5 9.06 Street Light - I 6.55 5.1 7.86 Street Light - II 9.48 9.4 9.90 Irrigation 246.22 180.0 7.31 IAS - I 78.14 15.6 2.00 IAS - II 168.08 164.3 9.78 Public Water Works 33.98 36.5 10.75 Industrial LT 270.10 194.9 7.22 LTIS - I 245.74 172.2 7.01 LTIS - II 24.36 22.7 9.31 Industrial HT 684.40 542.0 7.92 HTS - I 402.64 337.3 8.38 HTS - II 149.33 118.2 7.92 HTS - III 65.95 53.1 8.05 HTSS 66.49 33.4 5.03 Railway 62.67 61.6 9.84 Nepal 1,188.89 665.4 5.60 DF 1,007.62 442.1 4.39 Total 8,618.49 4,293.4 4.98
4.21.2. It is submitted by Petitioner that above computed revenue is based on the approved tariffs and revised projections of sales, consumers and load for respective years and requests Hon’ble Commission to approve the same.
4.22. Net ARR and Revenue Gap for FY 2017-18
4.22.1. The Gross ARR for the distribution company consist of the power purchase costs, interest and finance costs, O&M costs, depreciation and interest on working capital. 4.22.2. The below tables demonstrates the net gap for FY 2017-18 taking into account all the expenses estimated for the entire year reduced by revenue from sale of power and Other income. 4.22.3. It is to be noted that the Petitioner has claimed an unrecovered True up gap along with the carrying cost for FY 2016-17 to arrive at net gap of INR 1160.30 crores
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4.22.4. Following is the total revenue requirement for FY 2017-18 against allocation from total approved revenue requirement by the Hon’ble commission for FY 2017-18
Table 70: Revenue requirement for FY 2017-18 (in INR Crore)
S. No. Particulars Current Year 2017-18 1 Power purchase cost 4,470.35 2 PGCIL & other transmission charges 325.48 3 State Transmission charges & BGCL 341.73 4 O&M Expenses i) Employee Cost 237.63 ii) R&M expenses 69.72 iii) A&G expenses 103.27 5 Share of Holding Company expenses 5.92 6 Depreciation 145.21 7 Interest and Finance charges 389.04 8 Interest on working capital 82.77 9 Return on equity 225.11 10 Income Tax - 11 Interest on security deposit 22.51 12 Bad debts (if any) 0 13 Contingency reserves (if any) 0 14 Total Revenue Requirement 6418.74 15 Less: Non-tariff income 189.59 16 Aggregate Revenue Requirement 6229.15
4.22.5. Following is the Net revenue requirement and revenue gap for FY 2017-18 against allocation from total approved revenue requirement by the Hon’ble Commission for FY 2017-18.
Table 71: Net ARR & Revenue Gap for FY 2017-18 (in INR Crore)
S. No. Particulars Amount (INR Cr) 1 Aggregate Revenue Requirement (ARR) 6,418.74 2 Less : Non-Tariff Income 189.59 3 Add : Recovery of revenue gap / (Surplus) of past 1,160.30 period, if any (FY 2016-17) 4 Net ARR 7,389.45 5 Less : Power Purchase Cost disallowed, if any - 6 Less : Revenue from Existing Tariff 4,293.45 7 Less : Revenue from sale of power to other Agency - 8 Gap (4–5–6) 3,096.00 9 Total grant from State Govt. 1,165.60 10 Grant used for compensating disallowed power - 11 Balance resource grant assistance from Stat Govt. (9–10) 1,165.60 12 Net Gap/(Surplus) at existing tariff (8–11) 1,930.40
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Table 72: Unrecovered Gap for FY 2016-17 (in INR Crore)
True up FY 2016-17 (All figures in INR Cr) Revenue gap approved in true up for FY 2016-17 950.09 Interest for FY 2016-17 (SBI Adv R @ 14.75%) for 6 months 70.07 Interest for FY 2017-18 (SBI Adv R @ 14.75%) for 12 months 140.14 Total unrecovered gap for FY 2016-17 1,160.30
4.22.6. In the light of the above explanation the Petitioner would request the Hon’ble Commission to approve the figure of INR 1160.30 Crore towards net gap in FY 2017- 18.
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5. Annual Revenue Requirement (ARR) for FY 2018-19
5.1. Preamble
5.1.1. The Petitioner has provided this section for Annual Revenue Requirement for the FY 2018- 19. Rational estimation of category-wise energy sales for the control period is essential to arrive at the optimum quantum of power to be purchased and the likely revenue by sale of energy. Likewise it is essential that the cost components driving ARR should be projected in an optimal manner. The below sections deals with the projections of ARR components for FY 2018-19.
5.2. Historical Assessment of Number of Consumers and Sales
5.2.1. Rational estimation of category-wise energy sales for the ensuing year is essential to arrive at the optimum quantum of power to be purchased, and the likely revenue from sale of energy. This section examines in detail the consumer category-wise energy sales projected for the distribution company in the Petition for the period of FY 2018-19, for approval of ARR. 5.2.2. The Petitioner serves more than 62.96 lakh consumers (as on 31 st March 2017). The electricity consumers in the area served by the Petitioner have increased by approximately 27.92% over the last year, as per the audited accounts. This high rate of growth is also reflective of the efforts that the Petitioner is putting in to connect un-electrified consumers to the grid to enhance electricity access in recent years. The historical trend in the number of consumers serviced by the Petitioner as per the data available in its audited books of accounts, has been captured in the following table.
Table 73: Category wise number of consumer for past few years
Consumer Category FY 2013-14 FY 2014-15 FY 2015-16 FY 2016-17 Domestic 2,337,948 3,184,729 4,394,465 5,660,408 Kutir Jyoti- BPL Consumers 978,468 1,223,212 1,811,913 2,516,282 Domestic – I 726,732 1,125,478 1,550,465 1,967,498 Domestic – II 632,713 836,001 1,032,008 1,176,543 Commercial 106,973 162,923 222,097 294,747 Non-Domestic – I 19,445 33,911 54,144 80,110 Non-Domestic – II 87,429 128,839 167,617 214,557 Public Lighting 112 190 290 255 Street Light – I 40 155 147 142 Street Light – II 72 35 143 113 Irrigation 4,329 5,087 6,461 14,158 IAS – I 2,101 2,533 3,493 9,147 IAS – II 2,228 2,554 2,968 5,011 Public Water Works 530 632 679 208 Industrial LT 4,827 7,424 11,005 12,246 LTIS – I 4,483 6,952 10,065 11,593 LTIS – II 344 472 940 653
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Consumer Category FY 2013-14 FY 2014-15 FY 2015-16 FY 2016-17 Industrial HT 366 489 626 675 HTS – I 344 460 596 643 HTS – II 15 24 25 25 HTS – III 1 2 2 2 HTSS 6 3 3 5 Railway 2 4 4 7 Nepal 1 1 1 1 M/s Essel Vidyut Vitran-DF 1 190,720 286,451 313,499 Total 2,455,090 3,552,200 4,922,080 6,296,205 Growth Rates 44.69% 38.56% 27.92%
5.2.3. This increase in the number of consumers leads to further increase in energy sales under various categories of consumers. Following table covers the energy sale trend for the Petitioner in the past few years –
Table 74: Category wise sales for the past few years (in MU)
Consumer Category FY 2013-14 FY 2014-15 FY 2015-16 FY 2016-17 Domestic 1,607.89 2,174.92 3,209.48 3,567.04 Kutir Jyoti- BPL Consumers 366.02 506.37 811.17 848.69 Domestic – I 491.92 668.04 1,067.76 1,522.29 Domestic – II 749.19 999.87 1,329.85 1,196.06 Commercial 298.40 416.08 533.50 706.21 Non-Domestic – I 17.60 27.94 43.02 67.70 Non-Domestic – II 279.82 387.30 489.63 638.52 Public Lighting 26.05 10.99 20.92 15.27 Street Light – I 10.79 6.66 10.55 6.24 Street Light – II 15.27 4.33 10.36 9.03 Irrigation 104.84 103.19 130.88 160.20 IAS – I 12.19 10.68 24.19 7.40 IAS – II 92.64 92.51 106.69 152.80 Public Water Works 24.26 28.33 26.43 30.16 Industrial LT 90.36 121.39 132.71 163.45 LTIS – I 56.22 78.25 85.65 145.40 LTIS – II 34.14 43.13 47.06 17.95 Industrial HT 351.44 371.88 433.41 474.19 HTS – I 193.96 201.73 250.60 269.41 HTS - II 74.17 79.03 87.59 93.24 HTS - III 25.67 49.64 80.42 65.95 HTSS 57.65 41.49 14.80 45.59 Railway 12.05 18.29 22.26 62.67 Nepal 751.18 1,010.07 1,221.02 1,188.89 UI 76.58 170.28 77.64 77.35 M/s Essel Vidyut Vitran-DF 261.75 578.10 696.79 749.87 Total 3,604.82 5,003.52 6,505.03 7,195.20 Growth rate 39% 30% 11%
5.3. Projected Sales (MU), Number of Consumers and Connected Load for FY 2018-19
5.3.1. The projection of energy sales for the control period is based on the 24x7 Power For All, Har Ghar Bijli and Saubhagaya Scheme for all plan in line with the large scale initiative taken by Central Government along with the State Government. This initiative aims for the overall
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development of the power sector in the state. The objective of the above mentioned initiatives is to make power available to all households, industry, commercial businesses, public needs, any other electricity consuming entity and adequate power to agriculture farm holdings by FY 2018-19. 5.3.2. The initiatives of Discom are expected to mainly impact the rural consumers who would fall under the Kutir Jyoti, DS-I and IAS-I categories, since a lot and the growth rate projected under this category is above the normal CAGR growth as large number of new connections to be released in the ensuing years.
Table 75: Category-wise no. of consumers projected for FY 2018-19
Category FY 2018-19 Growth rate Domestic 7,201,858 12.50% Kutir Jyoti- BPL Consumers 3,156,424 12.00% Domestic - I 2,748,201 17.03% Domestic - II 1,297,232 5.00% Domestic - III 0 NA Commercial 337,976 6.45% Non-Domestic - I 101,339 10.00% Non-Domestic - II 236,637 5.00% Non-Domestic - III 0 NA Public Lighting 281 5.00% Street Light - I 157 5.00% Street Light - II 125 5.00% Irrigation 156,210 309.37% IAS - I 150,147 359.91% IAS - II 6,063 10.00% Public Water Works 917 5.00% Industrial LT 14,681 9.51% LTIS - I 14,028 10.00% LTIS - II 653 0.00% Industrial HT 1,084 7.52% HTS - I 1,037 7.89% HTS - II 40 0.00% HTS - III 2 0.00% HTSS 5 0.00% Railway 7 0.00% Nepal 1 0.00% UI 0 NA M/s Essel Vidyut Vitran-DF 349,042 5.00% Total 8,062,057 13%
5.3.3. Under Chief Minister Seven Resolution in which the primary objective is to provide electricity to household and electrify approximately 20.99 lakhs households in North Bihar over the next 2-3 years. 5.3.4. The Petitioner has also been making other efforts to enhance the overall power availability for the consumers of the State. This includes contracting additional power
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from various sources across the State and the country, and enhancing the State’s power transmission capacity for bringing it to the distribution network. 5.3.5. The commissioning of the transmission capacity shall also lead to a higher energy supply to urban areas of the Discoms. The category wise projections of energy sales for FY 2018- 19, has been done taking into account the above factors.
Table 76: Category-wise sales projected for FY 2018-19
Category FY 18-19 Growth rate Domestic 5,450.68 24.87% Kutir Jyoti- BPL Consumers 1,515.08 19.18% Domestic - I 2,223.25 34.65% Domestic - II 1,712.35 18.68% Domestic - III 0.00 NA Commercial 784.48 5.52% Non-Domestic - I 85.64 10.00% Non-Domestic - II 698.84 5.00% Non-Domestic - III 0.00 NA Public Lighting 16.83 5.00% Street Light - I 6.88 5.00% Street Light - II 9.96 5.00% Irrigation 522.95 112.39% IAS - I 338.06 332.63% IAS - II 184.88 10.00% Public Water Works 35.67 5.00% Industrial LT 294.67 9.10% LTIS - I 270.32 10.00% LTIS - II 24.36 0.00% Industrial HT 716.15 4.64% HTS - I 434.39 7.89% HTS - II 149.33 0.00% HTS - III 65.95 0.00% HTSS 66.49 0.00% Railway 62.67 0.00% Nepal 1,188.89 0.00% UI 0.00 NA M/s Essel Vidyut Vitran-DF 1,058.00 5.00% Total 10,131.00 17.55%
Table 77: Category-wise connected load (kW) projected for FY 2018-19
Category FY 18-19 Growth rate Domestic 5748545 19.75% Kutir Jyoti- BPL Consumers 789106 12.00% Domestic - I 3219154 26.40% Domestic - II 1740286 12.35% Commercial 745639 8.35% Non-Domestic - I 118717 15.50% Non-Domestic - II 626922 7.10% Non-Domestic - III 0.00 NA Public Lighting 3641 5.00% Street Light - I 1064 5.00% Street Light - II 2577 5.00% Irrigation 504792 368.56%
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Category FY 18-19 Growth rate IAS - I 65130 10.43% IAS - II 20563 5.00% Public Water Works 35.67 5.00% Industrial LT 140579 12.55% LTIS - I 103759 15.50% LTIS - II 36820 5.00% Industrial HT 339538 7.21% HTS - I 225715 10.04% HTS - II 68018 2.00% HTS - III 34853 2.00% HTSS 10952 2.00% Railway 54900 0.00% Nepal NA UI NA M/s Essel Vidyut Vitran-DF 468498 5.00% Total 8091825 22.21%
5.3.6. Based on the above, the Petitioner estimates an energy sales of 10,131 MU during FY 2018- 19 and a connected load of 7818.2 MW ending 31st March 2019. 5.3.7. The general approach followed for projection of all categories include:-
i. The consumer numbers are projected by taking the base year as FY 2017- 18 and then applying a CAGR as observed over the past few years.
ii. For projecting the connected load, an average connected load per consumer has been taken as per the actual data of the past few years. This has then been then multiplied by projected number of consumers to arrive at the connected Load.
iii. The energy sales has been projected by considering the average consumption per consumer per month and applying the same to the projected number of consumers.
iv. The number of years taken for estimating the CAGR however varies since the trend in certain categories is impacted by multiple other factors, and taking a uniform period for calculating the CAGR skews the outcome.
vii. In addition to the CAGR, it has also been ensured that other factors impacting demand, such as growth in the no. of consumers (due to schemes including 24X7 power for all, Chief Minister scheme and Saubhagya scheme), enhanced power procurement, strengthening of distribution network for enhancing quality of supply, energy efficiency and DSM measures etc., have been adequately incorporated to reflect a realistic demand scenario. viii. The following paragraphs capture highlights of the approach and assumptions used for projecting the specific category wise number of consumers, connected load and energy sales for the ensuing year.
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5.4. Detailed category-wise projections for ARR period FY 2018-19
5.4.1. Kutir Jyoti: The projections in Kutir Jyoti category are done considering the following assumptions:-
i. Consumers: There is a major drive to enhance access to electricity in the State, and the majority of the new potential consumers would fall under Kutir Jyoti, DS-I and IAS-I categories. The Petitioner In line with all schemes, has estimated a growth rate of 12% for the consumers in this category. In FY 2018-19, it is estimated that approximately 3.38 lakh KJ consumers would be added by the Petitioner
ii. Connected Load: The connected Load for this category is projected considering average Load per consumer at 250 W and multiplying it by number of consumers to arrive at the connected Load.
iii. Units sold: As a result of the addition of 3.38 lakhs consumers in this category, the consumption and units sold are expected to increase at a higher rate as compared to the historical CAGR. The Petitioner has considered an average monthly consumption of 40 kWh per consumer per month and multiplying with total number of consumers projected in this category for FY 2018-19 to arrive at an estimated sales figure. The overall growth rate for sales in this category is 19.2% over FY 2017-18.
5.4.2. Domestic Service I: The projections in DS I category are done considering the following assumptions:-
i. Consumers: A survey was also conducted to identify that number of APL households to be electrified. It is estimated that approximately 32.98 lakh consumers need to be electrified by the end of FY 2018-19. In order to reflect the realistic scenario in the process of determining ARR for FY 2018-19, the Petitioner has considered 4 lakh consumers to be added to this category in the FY 2018-19
ii. Connected Load: The overall connected load for this category has been projected considering 5% escalation on the average connected load per consumer for FY 2017- 18 and multiplying it by the projected number of consumers fur FY 2018-19.
iii. Units sold: The sales in this category are projected considering 5% growth rate in average consumption per consumer per month in FY 2017-18, which is little higher than 3 year CAGR (4.6%) and multiplying with total number of consumers projected in this category for FY 2018-19. The overall growth rate for sales in this category is 34.6 % over FY 2017-18.
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5.4.3. Domestic Service II: The projections in DS II category are done considering the following assumptions:- i. Consumers: The number of consumers in this category are projected by considering the growth rate of 5% on the total number of consumers projected in this category for FY 2017-18, thereby directly impacting energy sales. ii. Connected Load: The connected load for this category is projected considering 5% growth rate on the average load per consumer for FY 2017-18 and multiplying it by the number of consumers. iii. Units sold: The sales in this category are projected considering 10% growth rate in average consumption per consumer per month in FY 2017-18, and multiplying with total number of consumers projected in this category for FY 2018-19. The overall growth rate for sales in this category is 18.7 % over FY 2017-18.
5.4.4. Non-Domestic Service I: The projections in NDS I category are done considering the following assumptions:- i. Consumers: The number of consumers in this category are projected considering a growth rate of 10% on the number of consumers ending FY 2017-18. Although the historical trend shows that there has been an accelerated growth in the number of consumers, the Petitioner has considered a growth rate of 10 % since there are not many significant consumers left un-electrified in this sub-category.
ii. Connected Load: Similarly, for projecting the connected load, the Petitioner has moved away from the historical erratic and high rate of growth and adopted a nominal growth rate of 2.5% on average load per consumer in FY 2017-18, which comes to 1.116 kW and multiplying them with consumers projected in this category
iii. Units sold: The sales have therefore been projected by considering the average consumption per consumer per month same as FY 2016-17 and multiplying with total number of consumers projected in this category for FY 2018-19. The overall growth rate for sales in this category is 10.0% over FY 2017-18.
iv. The Central and State Government are taking multiple measures towards Demand Side Management, and accordingly a programme is being carried out for distribution of LED lights which helps conserve energy. As a result, this would taper down the specific consumption from this consumer segment in the coming years. Therefore 0% growth rate on average consumption per consumer per month is assumed in this category.
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5.4.5. Non-Domestic Service II: The projections in NDS-II category are done considering the following assumptions:-
i. Consumers: The number of consumers are projected taking a growth rate of 5% on the number of consumers ending FY 2017-18. Although the historical trend shows that there has been an accelerated growth in the number of consumers, the Petitioner has considered a growth rate of 5% since there are not many significant consumers left un-electrified in this sub-category.
ii. Connected Load: For projecting connected Load in NDS-II category growth rate of 2% percent growth rate is assumed on average load per consumer in FY 2017-18 and multiplied with total number of consumers to project the connected Load for FY 2018- 19.
iii. Units sold: The sales for NDS-II is projected considering 0% growth rate on average consumption per consumer per month for FY 2016-17. The average consumption per day per consumer is then multiplied by number of consumers projected for FY 2018-19. Since there has been promotion towards usage of energy efficient lighting and air conditioning in the NDS category, the specific consumption of the category has to remain constant. The overall growth rate for sales in this category is 5 % over FY 2017-18.
5.4.6. SS-I: The projections in SS-I category are done considering the following assumptions:-
i. Consumers: This is the metered category provided for the Street Light Supply category and the trend of number of consumers in this sub-category is quite uneven. The 3 year CAGR comes to approximately 53% while the variation in growth in the corresponding period is showing no growth. In light of this, a nominal growth rate of 5% has been assumed, taking a conservative approach for projecting the number of consumers for FY 2018-19.
ii. Connected Load: The Petitioner has made efforts towards Demand Side Management (DSM) by replacement of 150W lamps with 40-50W sodium vapour lamps which has reduced the average connected load per consumer drastically in FY 2016-17. Therefore, Petitioner has considered average connected load per consumer for FY 2018-19 same as for FY 2016-17.
iii. Units sold: Units sold in this category are projected considering 0% escalation on average consumption per consumer per month for FY 2016-17 and multiplying with consumers projected in this category for FY 2018-19. The overall growth rate for sales in this category is 5 % over FY 2017-18.
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5.4.7. SS-II: The projections in SS-II category are done considering the following assumptions:- i. Consumers: In this category nominal growth rate of 5% is assumed for projecting numberofconsumers. Asvariation in the corresponding period was negative, therefore a nominal growth is assumed.
ii. Connected Load: The average Load in this category is calculated by considering 0% growth rate on average Load per consumer for FY 2016-17 and multiplying by number of consumers projected in this category.
iii. Units sold: Units sold are projected based of average consumption per consumer per month for FY 2016-17. The average consumption per consumer is multiplied by the consumers to arrive at units sold for FY 2018-19. The overall growth rate for sales in this category is 5% over FY 2017-18. In the Street Lights category the process is going on for replacement of 150W lamps with 40-50W Sodium vapour lamps which shall possibly reduce the units consumed in Street Lights category.
5.4.8. IAS-I:The projections in IAS-I category are done considering the following assumptions:-
i. Consumers: The State has been taking major steps to ensure that a significant portion of the agriculture pump-sets that are currently operating on Diesel Gensets are converted to operate on grid connected electricity. Currently, approximately 11 lakh pump-sets are operating in Bihar. As a resultant, the consumers in this sub-category are increasing beyond the normal CAGR due to the addition of approximately 1.18 lakh new connection in FY 2018-19.
ii. Connected Load: The connected Load for FY 18-19 is projected considering 1 year CAGR growth rate (1.88 %) on average load per consumer for FY 2017-18 and multiplying with number of consumers projected in this category for FY 2018-19.
iii. Units sold: The units sold for IAS I category is projected considering and average consumption of 335.17 kWh per consumer per month, which is the average consumption per consumer per month during the first half of FY 2016-17.The Petitioner has considered only 3 months consumption of 75% new connections to be added in FY 18-19, since most of the connections will be released during the last quarter of FY 2018-19. The overall growth rate for sales in this category is above 300 % over FY 2017-18. The high growth rate is due to the addition of new consumers to the electricity grid directly impacting the sales in this category. The Petitioner has shown a growth rate of 167% in consumers. Agriculture feeder separation is under process, once it is done separate transformers will be issued connecting to pump sets. Promotion of Solar Pump sets will be done to reduce
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demand. Currently 11 lakh pump sets are operating in Bihar.
5.4.9. IAS-II: The projections in IAS-II category are done considering the following assumptions:-
i. Consumers: There is a constant growth around 30% every year in the consumers of IAS II category. So. The Petitioner has considered a nominal growth rate of 10% for this category.
ii. Connected Load: The connected Load for FY 18-19 is projected considering 1 year CAGR growth rate (0.39 %) on average load per consumer for FY 2017-18 and multiplying with number of consumers projected in this category for FY 2018-19.
iii. Units sold: The units sold is IAS II category are projected considering same average consumption perconsumer per month as in FY 2016-17 for FY 2018-19 considering 0% growth rate and multiplying with the total number of consumers projected in this category. The overall growth rate for sales in this category is 10 % over FY 2017-18.
5.4.10. Public waterworks: The projections in PWW category are done considering the following assumptions:-
i. Consumers: As the variation in the corresponding period was uneven, therefore Petitioner has considered a nominal growth rate of 5% during projections.
ii. Connected Load: The Load is projected by calculating average load per consumer and multiplying by the number of consumers projected for FY 2017-18.
iii. Units sold: The units sold in this category is projected by considering average consumption per consumer per month same as in FY 2016-17 and multiplying the same with number of consumers projected for FY 2018-19. The overall growth rate for sales in this category is 5 % over FY 2017-18.
5.4.11. LTIS-I: The projections in LTIS-I category are done considering the following assumptions:-
i. Consumers: While projecting the number of consumers in this category, growth rate of 10% is assumed .There is accelerated growth rate of 15.18%(1 year CAGR) in FY 2016-17 in this category, therefore 10% growth rate in number of consumers is assumed.
ii. Connected Load: The connected Load is projected considering average Load per consumer as on 30th September 2017 for projecting average Load for FY 2018-19 and multiplying the same with the total number of consumers.
iii. Units sold: The units sold in this category is projected by considering average
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consumption per consumer per months in FY 2016-17 and multiplying the same with number of consumers. The overall growth rate for sales in this category is 10 % over FY 2017-18.
5.4.12. LTIS-II: The projections in LTIS-II category are done considering the following assumptions:-
i. Consumers: While projecting the number of consumers in this category, the Petitioner has considered 0% growth rate since the historical trend of this category is uneven.
ii. Connected Load: The connected load for FY 2018-19 for this category is projected by considering average load per consumer same as in FY 2016-17 and multiplying it with the total number of consumers.
iii. Units sold: The units sold in this category is projected by considering average consumption per consumer per month and multiplying the same with number of consumers. As the growth in the consumption was negative in past years therefore, no growth rate is assumed while calculating average consumption per consumer per month. The overall growth rate for sales in this category is 0 % over FY 2017-18.
5.4.13. HTS-I: The projections in HTS-I category are done considering the following assumptions:-
i. Consumers: Recently the Discoms have seen an increasing trend in the addition of consumers in the HTS-I category, including both conversions from the LTIS categories and addition of new consumers. While projecting the number of consumers in this category growth rate of 7.89 % growth rate which is based on 1 year CAGR.
ii. Connected Load: The connected Load in this category is projected by taking average Load per consumer for FY 2016-17 and multiplying it by number of consumers projected for FY 2018-19.
iii. Units sold: The units sold in this category is calculated on the basis of average consumption per consumer per month in FY 2017-18 and multiplying by consumers projected for FY 2018-19. The overall growth rate for sales in this category is 7.9 % over FY 2017-18.
5.4.14. HTS-II: The projections in HTS-II category are done considering the following assumptions:-
i. Consumers: Recently the Discoms have seen an increasing trend in the addition of consumers in the HTS-II category, including both conversions from the LTIS
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categories and addition of new consumers. The Petitioner has shown a growth rate of approximately 60% in the first six months ( i.e up to September 2017) of FY 2017-18. The Petitioner has considered 0 % growth rate while projecting the number of consumers in this category.
ii. Connected Load: The connected Load in this category is projected by taking average Load per consumer for FY 2016-17 and multiplying it by number of consumers projected for FY 2018-19.
iii. Units sold: The units sold in this category is calculated on the basis of average consumption per consumer per month in FY 2017-18 and multiplied by consumers projected for FY 2018-19. The overall growth rate for sales in this category is 0 % over FY 2017-18.
5.4.15. HTS-III: The projections in HTS-III category are done considering the following assumptions:-
i. Consumers: The Petitioner has not assumed any growth rate during the projections for FY 2018-19.
ii. Connected Load: The connected Load in this category is projected by taking average Load per consumer for FY 2016-17 and multiplying it by number of consumers projected for FY 2018-19.
iii. Units sold: The units sold in this category is calculated on the basis of average consumption per consumer per month for FY 2016-17 and multiplying the same by consumers projected for FY 2018-19. The overall growth rate for sales in this category is 0 % over FY 2017-18.
5.4.16. HTSS: The projections in HTSS category are done considering the following assumptions:-
i. Consumers: The Petitioner has not assumed any growth rate during the projections for FY 2018-19.
ii. Connected Load: The connected Load in this category is projected by taking average Load per consumer for FY 2016-17 and multiplying it by number of consumers projected for FY 2018-19
iii. Units sold: The units sold in this category is calculated on the basis of average consumption per consumer per month for FY 2016-17 and multiplying the same by consumers projected for FY 2018-19. The overall growth rate for sales in this category is 0 % over FY 2017-18.
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5.4.17. Railways: The projections in RTS category are done considering the following assumptions:-
i. Consumers: There has been no growth rate assumed in the railways category for projecting number of consumers. The number of consumers are considered as 7 which is equivalent to last year. ii. Connected Load: Seeing the past trend in connected Load, no growth rate is assumed in railways category
iii. Units sold: The Petitioner has not assumed any growth rate in railways category. The overall growth rate for sales in this category is 0 % over FY 2017-18. 5.4.18. DF: While projecting sales and consumers for DF, 5 % growth rate for consumers and an average consumption per consumer at 252 kWh is assumed on last year figure i.e. projections for FY 2017-18. The overall growth rate for sales in this category is 0 % over FY 2017-18.
5.4.19. Nepal: The Petitioner has not considered any growth while projecting sales, since Nepal has increased its installed capacity with new hydro power plants coming up in FY 2018-19.
5.5. Distribution Loss
5.5.1. Emphasizing on the commitment to reform themselves by achieving a financial and operational turnaround, the Government of Bihar and the two Distribution Companies have signed a tripartite Memorandum of Understanding (MoU) of Ujwal Discom Assurance Yojana (UDAY) with the Ministry of Power, Government of India on 22nd February, 2016. This combined with other initiatives that the State Government and the Discoms are taking, are targeted to achieve the following vision for the State of Bihar. 5.5.2. Ensuring 24X7 Power For All by 2019: A detailed action plan to achieve the vision of providing electricity access to all Households in the State has been prepared by the state. The aim is to achieve 24X7 availability of reliable power to all households, industrial, commercial establishments and all other electricity consuming entities by FY19. 5.5.3. 100% village electrification in thousand days: The State has electrified substantial no. of villages during 2015-16 and has been at top in the Country. As against total 3056 no. of villages to be electrified as on 31st March,2015, 1686 no. of villages were electrified during 2015-16 and the remaining 1370 nos. of villages is expected to be electrified by March,2017. Further, the average existing supply of 12-16 hours a day in rural areas has been planned to be increased to 24 hours. The advent of DDUGJY scheme, where segregation of rural feeders is one of the objectives, is expected to significantly improve the electricity access in villages.
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5.5.4. Self-sufficiency in power and development of Bihar as power hub: To meet the burgeoning power demand and considering the existing tied up capacity, the State has planned to enhance its own generation Capacity as well tie-ups with other central generating stations and Independent Power Producers (IPPs). The endowed coal resources provide a promising opportunity for State to not only become self-sufficient but also to become the power hub for the country. Further, the development of a robust transmission system to form the back-bone has been planned. 5.5.5. Reducing AT&C losses to below 15%: Along with achieving the multiple objectives such as enhancing the reach, reliability and quality of electricity, the Petitioner has endeavored to bring down AT&C losses to below 15% by FY19. Several focused interventions at all levels are being undertaken, including metering of feeders, distribution transformers and consumers, improving and augmenting existing sub-transmission and distribution infrastructure, enhancing revenue collection initiatives and ensuring consumer satisfaction. 5.5.6. Reducing the gap between ACS and ARR to zero: As a foremost step towards building a financially sustainability, the state is initiating several steps to bring down the wide gap between Average Cost of Supply (ACS) and Average Revenue Realized (ARR). Historically, the retail tariff for electricity in Bihar has been one of the lowest in the Country and has remained non-reflective of the actual costs. The utility’s comprehensive plan to reduce AT&C losses, improve billing and collection efficiency coupled with realistic tariff increase and rationalizations to cover the costs sufficiently are key to ensuring financial viability of the sector. 5.5.7. The UDAY MoU and the corresponding action plan, which are targeted to specifically address operational inefficiency as well, set out a clear performance improvement roadmap, setting specific key performance targets. This would include taking multiple initiatives towards the goals:
5.5.8. Increasing Billing Efficiency: a. Automatic Meter Reading of Industrial Consumers b. Metering including prepaid/ Smart Meter c. Web based Spot Billing through Mobile d. Image of Meter Reading on Bill e. Consumer Indexing & GIS Mapping f. Input Based Franchisee g. Frequent raids and inspection of consumer premises to prevent power theft. h. 100% feeder metering i. 100% DT metering j. Energy Audit upto 11 KV
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k. Energy Accounting and Audit
5.5.9. Increasing Collection Efficiency: a. Appointment of Rural Revenue Franchisee for door to door collection from rural consumers b. Uploading of all Electricity bill on web for direct download and on-line payment c. Multiple options of payment such as on-line through Billdesk/PayU, HDFC Bank, ATP machine, Paytm, Branches of Gramin Bank, Vasudha Kendra, e-wallet, Block Collection Counter, Post offices, Mobile App, Mobile Van, etc. d. Disconnection drive in case of non-payment e. Filing Certificate Cases and their disposal promptly f. Customer Facilitation Centre for rectification of bill/ consumer complain g. Monthly Bill rectification Camp at all Sub-division/Division
5.5.10. Other measures: a. Strengthening and capacity addition of electricity distribution infrastructure b. Physical feeder segregation c. Feeder improvement program for network strengthening d. DSM and energy efficiency measures e. Name and shame campaign to control power theft f. Consumer awareness programs g. Centralized Customer Call Centre to enhance response time and overall quality of service
5.5.11. In light of the various measures being undertaken by the State and the existing levels of T&D losses, the Petitioner has targeted a reduction in AT&C losses and achieve 15% AT&C loss by FY 2019-20. The T&D loss reduction trajectory that has been agreed between the Petitioner, the Government of Bihar and the Government of India, has been as given below.
Table 78: Distribution Loss Trajectory
FY 2017-18 FY 2018-19 FY 2019-20 Distribution losses 24% 20% 15%
5.5.12. Further, in FY 2017-18 and FY 2018-19, a large number of rural consumers are planned to be added to the Discom. This includes approximately 20 Lakh rural 25 Lakh urban consumers. Due to this addition in the number of consumers at a Low Tension level in rural areas, where the length of feeders are generally longer, the technical losses are expected to
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go up. Therefore for the Discom as a whole, it would not be possible to drastically reduce losses in FY 2018-19. 5.5.13. It is submitted to the Hon’ble Commission that although the Discoms are making the best possible efforts to reduce the losses with the introduction of feeder separation schemes, spot billing etc. and various other IT initiatives, the reduction in losses would still occur in a phased manner. 5.5.14. Given the fact that the Discoms of Bihar have already entered into a MoU which clearly lays out a loss reduction target agreed by the Government of Bihar and the Government of India, this target may be treated as the base for setting the loss reduction trajectory. 5.5.15. Accordingly, it is prayed to the Hon’ble Commission to adopt the trajectory agreed under UDAY scheme and approve a Distribution loss of 20% for NBPDCL for FY 2018-19.
5.6. State Transmission Losses
5.6.1. The state transmission loss has been considered as 3.92% for FY 2017-18 and a reduction of 1.2% per year on 3.92% is considered for the control period FY 2018-19.
5.7. Central Transmission Losses
5.7.1. A nominal value of around 2.26% is considered as the CTU loss throughout the FY 2018- 19.
5.8. Power Purchase
5.8.1. The Discom’s rely on allocation from central generating stations and state projects for procuring power for sale in the state. This power has been proposed to be allocated between north and south Bihar in the proportion as determined by the board resolution as detailed below: 5.8.2. Bihar State Power Holding Company Ltd (BSPHCL) issued vide its Resolution No.55- 10 dated 14th July 2017 for approval regarding distribution of power purchase agreement between NBPDCL and SBPDCL. The notification states that, “RESOLVED THAT Power Purchase & Transmission charges bills are to be admitted and payment by both discoms i.e NBPDCL and SBPDCL in the ratio 46:54 respectively w.e.f.1-4-2017subjected to the final reconciliation of actual consumption”
RESOLVED FURTHER THAT Chairman cum Managing Director, BSHPCL are here by authorized for deciding the power consumption ratio subsequently as per the actual consumption of both the DISCOMS based on the average consumption of the last 6 months of power drawal of both the discoms i.e. NBPDCL and SBPDCL”
The Board further ratifies the submission made in attached agenda note.
The following were considered by the petitioner during the power purchase projections for FY 2018-19 i. Barh Stage I, Unit II has been considered to be available from Jan of FY 2018-19.
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ii. Nabinagar Stage I has been considered to be available in February 2019
iii. Nabinagar Railway project has been considered that 25MW from Unit III will be available in July 2018 and then subsequently 25MW from other Unit will be available from January 2019.
5.8.3. The Petitioner has attached table summarizing month-wise power purchase capacity for Bihar for FY 2018-19 in Annexure B.6. 5.8.4. The Petitioner has also attached the Plant Load factors considered for FY 2018-19 in Annexure B.7. 5.8.5. The table attached below summarizes the power purchase quantum for FY 2018-19.
Table 79: Power purchase Quantum for FY 2018-19 (in MW)
S. No. Name of the source SBPDCL NBPDCL Bihar (FY 2017-18) (FY 2017-18) (FY 2017-18) 1 Central Sector Stations 1,892.39 1,612.04 3,504.43 2 Talcher – I ( 2 x 500 MW) 224.91 191.59 417 3 Farakka – I & II (1600 MW) 274.75 234.048 509 4 Farakka – III (500 MW) 58.32 49.68 108 5 Kahalgaon – I (840 MW) 191.65 163.254 355 6 Kahalgaon – II (1500 MW) 40.34 34.362 75 7 Barh-II 571.86 487.14 1059 8 Korba - 0 0 9 Rangit – HEP 11.34 9.66 21 10 Teesta - HEP 58.55 49.8778 108 11 Chukha 43.20 36.8 80 12 Tala 140.45 119.646 260 13 Barh Stage-I (3 X 660 MW) 277.02 235.98 513 14 State Generating Stations 521 443 964 15 KBUNL 1 118.80 101.2 220 16 KBUNL 2 142.56 121.44 264 17 Small Hydro (BSHPCL) 5.40 4.6 10 18 Barauni Stage I 118.80 101.2 220 19 Barauni Stage II 135.00 115 250 20 IPP 140.40 119.60 260.00 21 GMR Kamalanga Energy 140.40 119.6 260 22 Adani Enterprises Limited - 0 0 23 JV projects 333.72 284.28 618.00 24 Nabinagar Railway (4 X 250 MW) 54.00 46 100 25 Nabinagar Stage-I (3 X 660 MW) 279.72 238.28 518 Nabinagar JV (3 X 660 MW) 26 - 0 0 Stage-II 27 Renewable 120.96 103.04 224.00 28 SECI 5.40 4.6 10.00 29 ACME Magadh 5.40 4.6 10.00 30 ACME Nalanda 8.10 6.9 15.00 31 Sunmark 5.40 4.6 10.00 32 Avantika 2.70 2.3 5.00 33 AZURE 5.40 4.6 10.00 34 Udipta Energy & Equipment Pvt ltd 2.70 2.3 5.00 35 Glatt 1.62 1.38 3.00 36 Welspun 2 8.10 6.9 15.00 37 Welspun 1 5.40 4.6 10.00
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S. No. Name of the source SBPDCL NBPDCL Bihar (FY 2017-18) (FY 2017-18) (FY 2017-18) 38 Alpha Infra Prop 10.80 9.2 20.00 39 Welspun 3 8.10 6.9 15.00 40 Response Renewable energy 5.40 4.6 10.00 New Swadeshi Sugar 41 3.78 3.22 7.00 Mill,Narkatiaganj 42 Harinagar Sugar Mills,Harinagar 5.94 5.06 11.00 Bharat SugarMills,Sidhiwalia, 43 5.94 5.06 11.00 Gopalganj 44 Lauriya Sugar Mill 10.80 9.2 20.00 45 Sugauli Sugar Mill 10.80 9.2 20.00 46 Hasanpur Sugar Mills,Samastipur 5.40 4.6 10.00 Riga Sugar Company 47 1.62 1.38 3.00 Ltd,Sitamarhi Siddhashram Rice Mill Cluster Pvt 48 0.54 0.46 1.00 Ltd 49 Bihar Distillers and Bottlers Pvt Ltd 1.62 1.38 3.00 50 Grand Total 3,008.03 2,562.40 5,570.43
5.8.6. The power purchase (MU) has been calculated month wise month on month from April 2017 to March 2018. The methodology of projecting Power purchase quantum (MU) is as mentioned below: i. The above mentioned share allocation has been considered using the latest COD’s of each unit. Many new plants are expected to start operations in the financial year 2018-19. The increase in the share allocation has grown with the demand and is in lines allocated generation capacity in the 24X7 Power For All agreement.
ii. The Plant Load Factor (PLF) for each plant has been calculated on actual basis and then Petitioner has made a consideration to take highest among the following two plant load factors very month of FY 2018-19 from April 2017 to May 2018.
a. Normative Plant Load Factor Plant (PLF) provided by central Electricity Regulatory Commission (CERC) for the thermal and hydro plants and the auxiliary consumptions specified for plants. For the state plants PLF highest among the PLF norms specified by BERC and the plant wise auxiliary consumption determined by BERC for thermal, and biomass has been considered. For the solar plants highest among the CUF of 19%
b. Actual Plant Load Factor (PLF) of the thermal, hydro, biomass and solar plants in the same month of previous financial year i.e. FY 2017-18.
iii. Considering the PLF as mentioned above and using the power purchase allocation data mentioned in the above table total number of units purchased were calculated from every source/ plant for every month separately.
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5.8.7. The month wise projections data of April 2017 to May 2018 is added to get the total power purchase. The total power purchase (MU) is provided in the below table.
Table 80: Total power purchase (MU) for FY 2018-19
S. No. Power Purchase Share Allocation (MW) Energy (MU) Sources 1 Central Sector Stations 1,612.04 10,351.32 2 Talcher – I ( 2 x 500 MW) 191.59 1,442.58 3 Farakka – I & II (1600 MW) 234.05 1,774.96 4 Farakka – III (500 MW) 49.68 382.44 5 Kahalgaon – I (840 MW) 163.25 1,239.97 6 Kahalgaon – II (1500 MW) 34.36 280.26 7 Barh-II 487.14 3,629.75 8 Korba - - 9 Rangit – HEP 9.66 56.95 10 Teesta - HEP 49.88 287.83 11 Chukha 36.80 297.19 12 Tala 119.65 526.14 13 Barh Stage-I (3 X 660 MW) 235.98 433.26 14 State Generating Stations 443.44 1,563.69 15 KBUNL 1 101.20 364.83 16 KBUNL 2 121.44 428.65 17 Small Hydro (BSHPCL) 4.60 2.85 18 Barauni Stage I 101.20 364.40 19 Barauni Stage II 115.00 402.96 20 IPP 119.60 953.08 21 GMR Kamalanga Energy 119.60 953.08 22 Adani Enterprises Limited - - 23 JV projects 284.13 458.96 24 Nabinagar Railway (4 X 250 MW) 46.00 256.65 25 Nabinagar Stage-I (3 X 660 MW) 238.13 202.31 26 Nabinagar JV (3 X 660 MW) Stage-II - - 27 Renewable 103.04 307.73 28 SECI 4.60 9.43 29 ACME Magadh 4.60 7.81 30 ACME Nalanda 6.90 11.54 31 Sunmark 4.60 7.80 32 Avantika 2.30 3.83 33 AZURE 4.60 7.67 34 Udipta Energy & Equipment Pvt ltd 2.30 3.83 35 Glatt 1.38 2.30 36 Welspun 2 6.90 11.61 37 Welspun 1 4.60 7.73 38 Alpha Infraprop 9.20 15.31 39 Welspun 3 6.90 11.66 40 Response Renewabe Energy 4.60 7.66
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S. No. Power Purchase Share Allocation (MW) Energy (MU) Sources 41 New Swadeshi Sugar Mill,Narkatiaganj 3.22 15.42 42 Harinagar Sugar Mills,Harinagar 5.06 31.78 43 Bharat SugarMills,Sidhiwalia, 5.06 30.38 Gopalganj 44 Lauriya Sugar Mill 9.20 43.00 45 Sugauli Sugar Mill 9.20 42.26 46 Hasanpur Sugar Mills,Samastipur 4.60 21.12 47 Riga Sugar Company Ltd,Sitamarhi 1.38 6.34 48 Siddhashram Rice Mill Cluster Pvt Ltd 0.46 2.63 49 BDBPL 1.38 6.63 50 Open Market Purchase - - 51 IEX/PXIL - - 52 DB Power - - 53 JAYPEE NIGRIE - - 54 JPL - - 55 GMR ETL - - 56 TATA ETL - - 57 Manikaran Power - - 58 NEA - - 59 NVVNL - - 60 PVVNL - - 61 Adani Short Term - - 62 UI - - 63 Sub Total Power Purchase 2,562.24 13,634.79 64 Transmission charges - - 65 PGCIL - - 66 POSOCO & SLDC Charges - - 67 BSPTCL charges - - 68 BGCL - - 69 Total Power Purchase 2,562.24 13,634.79 70 Open Market Purchase 71 Transfer to Other Discom (476.95) 72 Net Power Purchase 2,562.24 13,157.84
5.8.8. The Petitioner requests the Hon’ble Commission to approve the aforementioned revised power purchase quantity for the period of FY 2018-19.
5.9. Renewable Power Purchase Obligation
5.9.1. It is submitted that Hon’ble Commission has notified the BERC (Renewable Purchase Obligation, its Compliance and REC Framework Implementation) Regulations, 2010 and BERC(TermsandConditionsforTariffDeterminationfromSolarEnergySources)Regulations, 2010. Further there were amendments in both regulations in September 2012 wherein the Solar RPO was modified.
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5.9.2. Petitioner has already been drawing solar power from a few sources like SECI, Welspun, ACME clean tech, Avantika and Azure Power. Petitioner has made a few tie ups with the solar power and non-solar power plants which shall add 58 MW (long term) and 18 - 21 MW under biomass and bagasse based cogeneration plants from next month i.e. December 2016. 5.9.3. The Licensees are already taking steps to ensure that they enhance their Renewable Energy mix and accordingly anticipate adding another 680 MW of Solar power from FY 2018-19 onwards as provided in the following table; however the PPAs are still to be signed and executed 5.9.4. The details of RPO to be met by the Petitioner for the control period FY 2018-19 are given in the table below – Table 81: Renewable energy purchase obligation for FY 2018-19
S. Particulars Unit FY 2018-19 No. 1 Energy consumption excluding Nepal MU 8942.11 2 % of RPO Obligation % 9.25% Solar % 3.25% Non-Solar % 6.00% 3 MUs required as per RPO for the year MU 827.15 Solar MU 290.62 Non-Solar MU 536.53 Solar Energy to be procured during the 4 MU year 290.62 Non-Solar Energy to be procured 5 MU during the year 536.53
5.9.5. The Petitioner has made plan to achieve target of solar power under RPO. The Petitioner submits that the shortfall may please be allowed to carry forward to next year so as to meet the total RPO on cumulative basis.
5.10. Energy Balance
5.10.1. The energy availability from various interstate plants have been computed considering the highest among the normative Plant Load Factor (PLF) provided by central Electricity Regulatory Commission (CERC) for the thermal and hydro plants and the auxiliary consumptions specified for plants and the actual Plant Load Factor (PLF) in that specific month of previous year (FY 2017-18) . For the state plants PLF highest among the PLF norms specified by BERC and the plant wise auxiliary consumption determined by BERC for thermal, and biomass and actual PLF of the specific month of previous year (FY 2016-17) has been considered. For the solar plants highest among the CUF of 10% and actual of that specific of previous year (FY 2017-18) has been considered. The peaking availability for the existing and future plants for various fuel sources has been
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considered as provided in NEP. Based on this the energy available from various plants has been computed for the entire control period. The plant wise energy availability for the utility has been provided in the table above 5.10.2. Based on above discussed elements such as sales, losses &power availability, the revised projected energy balance for control period FY 2018-19 is as under –
Table 82: Energy Balancing for ARR for FY 2018-19
S. No. Particulars Unit FY 2018-19 1 Energy sales MU 10131.00 2 Less: Energy supplied to DF area MU 1058.00 3 Less: Sales to Nepal MU 1188.89 4 Less: UI MU 0.00 5 Energy sale excluding DF area and Nepal MU 7884.11 6 Distribution loss % 20.00% 7 Distribution loss MU 1971.03 8 Energy required (3+5) MU 9855.14 9 Add: Energy to DF area including loss for DF area MU 1058.00 10 Energy required at Distribution periphery (7+8) MU 10913.14 11 Add: Sales to Nepal MU 1188.89 12 Total energy required (9+10) MU 12102.03 13 State Transmission loss % 3.92% 14 State Transmission loss MU 493.75 15 Add: UI sales MU 0.00 16 Energy required at State Transmission periphery MU 12595.79 17 Power Purchase from CGS , SGS and others MU 13157.84 18 UI MU 0 Losses in Regional Transmission System (excluding state 2.26% 19 % generating stations) 20 Losses in Regional Transmission system (MU) MU 281.02 21 Power Purchase from SGS MU 442.08 22 Energy available at State Transmission Periphery MU 12595.79 23 Surplus energy (23-16) 0
5.11. Power Purchase Cost
5.11.1. The power purchase cost mainly comprises of fixed charges and energy charges for two part tariff stations i.e. NTPC, NHPC & PTC in case of Petitioner. The Petitioner has considered the actual energy charges and fixed cost for these power stations based on actual 12 months month wise data and actuals 6 months month wise information from April 2017 to September 2017.The average power purchase cost as mentioned below.
i. Petitioner has considered the new plants whose COD is in the FY 2018-19 with the latest information on COD to ensure projections from realistic point of view.
ii. The power purchase cost projections have been made by taking the average of fixed costs and fuel costs of the 12 months data of FY 2017-18 which consists 6 months actuals and 6 months projections as mentioned in the APR. Using this projections of
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FY 2017-18 have been made month wise and then summation of cost is taken to arrive at total power purchase cost.
iii. The fixed cost projected using the above mentioned method and kept constant for the period of FY 2017-18 is calculated as 1.32 INR/kWh The fuel costs have been projected by escalating the average of fuel costs of the 12 months data of FY 2017-18 which consists 6 months actuals and 6 months projections as mentioned in the APR by 0% for NTPC plants.
iv. The fuel costs computed by the above method is calculated to be 2.26 INR /kWh
v. The total cost of power purchase per unit has been calculated to be 4.36 INR/kWh inclusive of all charges.
5.11.2. Power purchase costs: The table here provides detailed power purchase costs –
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Table 83: Detailed power purchase costs for FY 2018-19 (in INR Crore)
S. No. Power Purchase Ensuing Year (FY 18-19) Sources Share Energy Fixed Fixed Energy Energy Other Total Avg. Allocation (MU) Charge charge Rate Charge charges Charges Tariff (MW) rate (INR Cr) (INR/kWh) (INR Cr) (pl. (INR Cr) Rate (Rs/M specify) (INR/kWh) U) (INR Cr) 1 Central Sector Stations 1,612.04 10,351.32 1.30 1,350.27 2.50 2,583.69 18.92 3,952.88 3.82 2 Talcher – I ( 2 x 500 MW) 191.59 1,442.58 0.89 129.07 1.60 230.90 7.82 367.79 2.55 3 Farakka – I & II (1600 MW) 234.05 1,774.96 0.98 174.28 2.82 501.37 8.71 684.35 3.86 4 Farakka – III (500 MW) 49.68 382.44 1.77 67.80 2.84 108.72 3.31 179.83 4.70 5 Kahalgaon – I (840 MW) 163.25 1,239.97 1.00 123.57 2.49 309.07 0.26 432.90 3.49 6 Kahalgaon – II (1500 MW) 34.36 280.26 0.88 24.54 2.43 68.10 0.05 92.69 3.31 7 Barh-II 487.14 3,629.75 1.97 716.73 2.92 1,061.32 (1.28) 1,776.77 4.90 8 Korba ------9 Rangit – HEP 9.66 56.95 1.76 10.02 1.96 11.14 0.01 21.17 3.72 10 Teesta - HEP 49.88 287.83 0.91 26.27 1.16 33.39 0.07 59.73 2.08 11 Chukha 36.80 297.19 - - 2.29 68.06 (0.03) 68.03 2.29 12 Tala 119.65 526.14 - - 2.16 113.65 - 113.65 2.16 13 Barh Stage-I (3 X 660 MW) 235.98 433.26 1.80 77.99 1.80 77.99 - 155.97 3.60 14 State Generating Stations 443.44 1,563.69 0.70 109.68 3.66 572.47 - 682.15 4.36 15 KBUNL 1 101.20 364.83 1.41 51.29 3.41 124.36 - 175.65 4.81 16 KBUNL 2 121.44 428.65 1.36 58.30 3.22 138.03 - 196.32 4.58 17 Small Hydro (BSHPCL) 4.60 2.85 0.30 0.09 2.49 0.71 - 0.80 2.79 18 Barauni Stage I 101.20 364.40 - - 4.10 149.40 - 149.40 4.10 19 Barauni Stage II 115.00 402.96 - - 3.97 159.98 - 159.98 3.97 20 IPP 119.60 953.08 1.95 185.67 1.13 107.27 47.60 340.54 3.57 21 GMR Kamalanga Energy 119.60 953.08 1.95 185.67 1.13 107.27 47.60 340.54 3.57 22 Adani Enterprises Limited ------23 JV projects 284.13 458.96 2.03 93.16 1.91 87.47 - 180.62 3.94 24 Nabinagar Railway (4 X 250 MW) 46.00 256.65 2.21 56.74 1.99 51.05 - 107.79 4.20
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S. No. Power Purchase Ensuing Year (FY 18-19) Sources Share Energy Fixed Fixed Energy Energy Other Total Avg. Allocation (MU) Charge charge Rate Charge charges Charges Tariff (MW) rate (INR Cr) (INR/kWh) (INR Cr) (pl. (INR Cr) Rate (Rs/M specify) (INR/kWh) U) (INR Cr) 25 Nabinagar Stage-I (3 X 660 MW) 238.13 202.31 1.80 36.42 1.80 36.42 - 72.83 3.60 26 Nabinagar JV (3 X 660 MW) Stage-II ------27 Renewable 103.04 307.73 - - 3.99 122.68 - 122.68 3.99 28 SECI 4.60 9.43 - - 5.62 5.31 - 5.31 5.62 29 ACME Magadh 4.60 7.81 - - 8.73 6.82 - 6.82 8.73 30 ACME Nalanda 6.90 11.54 - - 8.73 10.07 - 10.07 8.73 31 Sunmark 4.60 7.80 - - 7.02 5.48 - 5.48 7.02 32 Avantika 2.30 3.83 - - 7.69 2.94 - 2.94 7.69 33 AZURE 4.60 7.67 - - 8.39 6.43 - 6.43 8.39 34 Udipta Energy & Equipment Pvt ltd 2.30 3.83 - - 7.98 3.05 - 3.05 7.98 35 Glatt 1.38 2.30 - - 7.02 1.61 - 1.61 7.02 36 Welspun 2 6.90 11.61 - - 8.64 10.03 - 10.03 8.64 37 Welspun 1 4.60 7.73 - - 8.70 6.73 - 6.73 8.70 38 Alpha Infraprop 9.20 15.31 - - 7.02 10.75 - 10.75 7.02 39 Welspun 3 6.90 11.66 - - 8.56 9.98 - 9.98 8.56 40 Response Renewabe Energy 4.60 7.66 - - 7.02 5.37 - 5.37 7.02 41 New Swadeshi Sugar Mill,Narkatiaganj 3.22 15.42 ------42 Harinagar Sugar Mills,Harinagar 5.06 31.78 - - 5.34 16.97 - 16.97 5.34 43 Bharat SugarMills,Sidhiwalia, Gopalganj 5.06 30.38 - - 5.04 15.31 - 15.31 5.04 44 Lauriya Sugar Mill 9.20 43.00 ------45 Sugauli Sugar Mill 9.20 42.26 ------46 Hasanpur Sugar Mills,Samastipur 4.60 21.12 - - 0.01 0.02 - 0.02 0.01 47 Riga Sugar Company Ltd,Sitamarhi 1.38 6.34 ------48 Siddhashram Rice Mill Cluster Pvt Ltd 0.46 2.63 - - 7.41 1.95 - 1.95 7.41 49 BDBPL 1.38 6.63 - - 5.80 3.85 - 3.85 5.80 50 Open Market Purchase ------51 IEX/PXIL ------
North Bihar Power Distribution Company Limited 110 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
S. No. Power Purchase Ensuing Year (FY 18-19) Sources Share Energy Fixed Fixed Energy Energy Other Total Avg. Allocation (MU) Charge charge Rate Charge charges Charges Tariff (MW) rate (INR Cr) (INR/kWh) (INR Cr) (pl. (INR Cr) Rate (Rs/M specify) (INR/kWh) U) (INR Cr)
52 DB Power ------53 JAYPEE NIGRIE ------54 JPL ------55 GMR ETL ------56 TATA ETL ------57 Manikaran Power ------58 NEA ------59 NVVNL ------60 PVVNL ------61 Adani Short Term ------62 UI ------63 Sub Total Power Purchase 2,562.24 13,634.79 1.28 1,738.77 2.55 3,473.59 66.52 5,278.88 3.87 64 Transmission charges ------667.21 - 65 PGCIL ------319.75 - 66 POSOCO & SLDC Charges ------5.73 - 67 BSPTCL charges ------257.34 - 68 BGCL ------84.39 - 69 Total Power Purchase 2,562.24 13,634.79 1.28 1,738.77 2.55 3,182.93 66.52 5,946.09 4.36 70 Sale of Power to Other Discom (476.95) 4.36 -208.00 -208.00 4.36 71 Net Power Purchase 2,562.24 13,157.84 1.32 1,738.77 2.26 2,974.93 66.52 5,738.09 4.36
North Bihar Power Distribution Company Limited 111 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
5.11.3. The Petitioner has made PPA agreements with the new plants according to 24X7 Power For All MoU but considering the reality the expected COD from the plants we have considered the following dates mentioned in the COD considerations table above in FY 2018-19. The average cost of power is found to be INR 4.40 / kWh but this is subjected to change on actual basis since power drawl from open market will be available which is subjected to Annual performance review and true up process. 5.11.4. We humbly request the Hon’ble Commission to approve the above mentioned projected power purchase costs for the period of FY 2018-19.
5.12. Transmission Charges
5.12.1. It is submitted that the Petitioner has to pay transmission charges to PGCIL for use of transmission facilities enabling power drawl from eastern region. The calculation of PGCIL charges is done by taking the average of FY 2017-18 which includes 6 months actuals, 6 months projected as per and then adding some growth rate as per the increase in the power purchase. 5.12.2. Further the Petitioner also pays BSPTCL, POSOCO charges and Open Access charges which are projected in the similar way as projected for PGCIL charges. 5.12.3. We request the Hon’ble Commission to approve the transmission and related charges for inter-state as well as intra-state transmission transactions for FY 2018-19 as per the below table:
Table 84: Transmission charges for ARR (in INR Crore)
S. No. Particulars Transmission Charges 1 PGCIL Charge 319.75 2 POSOCO & SLDC Charges 5.73 3 BSPTCL charges 257.34 4 BGCL 84.39 5 Total Transmission Purchase 667.21
5.12.4. We humbly request the Hon’ble Commission to approve the aforementioned transmission charges for FY 2018-19.
5.13. Capital Investment Plan, Capitalization and Funding
5.13.1. The Petitioner has computed the capitalization of investment on the assumption that 80% of the opening CWIP will get capitalized every year and 20% of the fresh investment is would capitalize. During FY 2018-19 huge capitalization will be done owing to capitalization in BRGF schemes, chief Minister’s seven resolution scheme, IPDS, DDUGJY etc.
North Bihar Power Distribution Company Limited 112 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
Table 85: Capitalization in FY 2018-19 (in INR Crore)
S. No. Name of the Scheme During FY 2018-19
1 BRGF, Special plan Phase- I 480.47 2 BRGF, Special plan Phase- II 3 BRGF, Special plan Part "C" 4 BRGF RE Portion 5 RAPDRP Part A 53.90 6 RAPDRP Part B 7 APDRP 0.00 8 NABARD Phase VIII 7.33 9 NABARD Phase XI 5.88 10 MP/CM LAD 7.21 11 Deposit Scheme 4.05 12 ADB 16.69 13 ACA State Plan 8.08 14 Burnt DTR State Plan 34.78 15 State Plan 115.60 RSVY 0.00 Sub Total (A) 733.98 New Scheme 16 CM Seven Resolution (Har Ghar Bijli) 0.00 17 IPDS 927.28 Sub Total (B) 927.28 18 RGGVY 11th Plan Phase- I 958.88 19 RGGVY 11th plan Phase- II 20 RGGVY 12th Plan Sub Total (C) 958.88 New Scheme 21 DDUGJY 327.46 Sub Total (D) 327.46 Sub Total (A+B+C+D) 2,947.61 22 Own Sources 0.00 Grand Total 2,947.61 5.13.2. The Petitioner has allocated the investments through various schemes into grant, Loan and Equity. The said allocation is based on the actual source from which funds were received by the Petitioner. The Petitioner has provided the detailed capitalization plan to the Hon’ble Commission as required in Annexure-A.19 of the additional formats. 5.13.3. The Capitalization plan bifurcated into various sources of funds is as follows –
Table 86: Capital works in progress for ARR (in INR Crore)
Ensuing year S. No. Particulars (FY 2018-19) 1 Opening CWIP 11,093.44 2 New Investment 2,626.19 3 Less Capitalization 2,947.61 (a) CWIP 2,358.09 (b) New Investment 589.52 4 Closing CWIP (1+2-3) 10,772.02 5 Funding (a) CWIP Capitalization 2,358.09
North Bihar Power Distribution Company Limited 113 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
Ensuing year S. No. Particulars (FY 2018-19) (i) Grant 1,312.26 (ii) Loan 434.32 (iii) Equity 611.51 (b) New Investment Capitalization 589.52 (i) Grant 328.06 (ii) Loan 108.58 (iii) Equity 152.88 6 Total capitalization 2,947.61 (i) Total Grant 1,640.32 (ii) Total Loan 542.90 (iii) Equity 764.39
5.13.4. The Petitioner would like to submit that the sources of funds under each scheme is as per the sanctioned documents for every scheme. 5.13.5. Therefore the Petitioner requests the Hon’ble Commission to approve the Capitalization plan as estimated by the Petitioner.
5.14. Gross Fixed Assets
5.14.1. The Petitioner hereby submits the computation of Gross Fixed Assets considering the opening fixed assets, capitalization as per the new schemes in FY 2018-19. 5.14.2. In addition to ongoing schemes, various new schemes were introduced during FY 2017-18 like Chief Minister’s Bijli Yojana, DDUGJY and IPDS etc. due to which Capitalization is projected for FY 2018-19. The Petitioner has provided the detailed Capitalization plan annexed as Annexure-A.19 in additional information requested by the Hon’ble Commission explaining the sources of funding for each scheme with bifurcation of equity, loan and grants. 5.14.3. The below table demonstrates the Asset addition planned in FY 2018-19 and closing balance of Gross Fixed Assets as on FY 2018-19 –
Table 87: GFA for ARR (in INR Crore)
S.No. Assets group Closing balance Addition during Closing balance at at the end of ensuing year the end of ensuing Current Year (FY 2018-19) year (FY 2017-18) (FY 2018-19) 1 Land and land rights 1,060.10 71.29 1,131.39 2 Buildings 39.27 1.87 41.14 3 Hydraulic Works 0.00 - 0.00 4 Others Civil Works 8.43 4.27 12.70 5 Plant and Machinery 749.17 153.03 902.20 6 Lines and Cable Network 5,565.20 2,712.06 8,277.26 7 Vehicles 1.54 0.02 1.57 8 Furniture and Fixtures 3.64 0.95 4.59 9 Office Equipment 7.15 4.11 11.27 Total 7,434.50 2,947.61 10,382.11
North Bihar Power Distribution Company Limited 114 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
S.No. Assets group Closing balance Addition during Closing balance at at the end of ensuing year the end of ensuing Current Year (FY 2018-19) year (FY 2017-18) (FY 2018-19) 10 Capital expenditure resulting in an - - assets not belonging to Company 11 Spare Units/Service Units 14.03 14.03 12 Capital spare at generating station - - 13 Assets taken over from Licensees 0.84 0.84 pending final valuation GRAND TOTAL 7,449.37 2,947.61 10,396.98
5.14.4. The Petitioner would like to submit that asset additions are done as per the Capitalization plan an as per the approved schemes. 5.14.5. The Petitions would request the Hon’ble Commission to approve the GFA as estimated by the Petitioner for FY 2018-19.
5.15. Depreciation on GFA
5.15.1. The depreciation has been computed annually based on straight line method by applying weighted average rate of depreciation on the average GFA. For this purpose, the Petitioner has adopted the Regulation 23 of the Bihar Electricity Regulatory Commission (Multi Year Distribution Tariff) Regulations, 2015 read with Bihar Electricity Regulatory Commission (Multi Year Distribution Tariff) (First Amendment) Regulations, 2017. The Petitioner has followed Straight line depreciation method while calculating depreciation for FY 2018-19. 5.15.2. The rate of depreciations has been taken as notified by Central Electricity Regulatory Commission. The Petitioner has reduced the depreciation on assets created out of Grants from the gross depreciation to arrive at the net depreciation to be charged. The computation of depreciation on the assets created out of Grants is based on the actual ratio of ‘Grants’ in GFA. 5.15.3. Also it is to bring into kind attention of the Hon’ble Commission that the balance of GFA in the beginning of the year and additions during the year does not include the value of Land as it is a non-depreciable asset. 5.15.4. Below is the table demonstrating the depreciation projected by the Petitioner for FY 2018- 19 –
Table 88: Depreciation on GFA (in INR Crore)
S. Particulars Current (RE) No. FY 2018-19 1 Opening GFA 7,449.37 2 Less: Value of Land 1,060.10 3 Net Opening GFA 6,389.27 4 Additions during the year (Excluding land value) 2,876.32
North Bihar Power Distribution Company Limited 115 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
S. Particulars Current (RE) No. FY 2018-19 5 IDC 6 Expenses Capitalized 7 Closing GFA 9,265.59 8 Average GFA 7,827.43 9 Weighted Average Rate of Depreciation 5.91% 10 Gross Depreciation 462.29 11 Opening grants 3,228.16 12 Grants during the year 1,600.65 13 Total Grants 4,828.80 14 Average Grants 4,028.48 15 Weighted Average rate of Depreciation 6.20% 16 Depreciation for GFA on Grants 249.75 17 Net Depreciation of GFA on loans (7-13) 212.54
5.15.5. As seen from the above table it is clearly evident that the Petitioner has deducted the depreciation on those fixed assets which are funded through grants. It is requested to the Hon’ble Commission to allow the depreciation of INR 212.54 Crore in FY 2018-19.
5.15.6. The matter of disallowance of depreciation in previous year Tariff Order had gone to the Appellate authority, the order of which came on 25th November, 2016. The relevant excerpt regarding this matter is reproduced below:- “In our opinion, the depreciation is an important segment and needs to be re- examined by the State Commission keeping in view the relevant details submitted by the Appellant subject to its prudent check. The Appellant is entitled to raise the issue of rate of depreciation also before the State Commission while the depreciation amount is being re-examined by the State Commission.”
Therefore, in the light of the above decision of the Hon’ble APTEL, the Petitioner would request the Hon’ble Commission to re-examine the component of depreciation in the last year’s Tariff Order as besides depreciation many components like Return on equity, interest on working capital are affected by it.
Also, it is requested to the Hon’ble Commission to approve the depreciation of INR 212.54 Crore towards depreciation for FY 2018-19.
5.16. Interest on project Loans
5.16.1. The Petitioner submits that the calculation of interest on Project loans is as per Regulation 25 of the BERC Multi-Year Tariff Regulations 2015 read with Multi-Year Tariff Regulations 2017.
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5.16.2. The Petitioner has provided detailed loan schedule depicting the project Loans and their additions and repayment during the year. The below is the detailed Loan schedule for FY 2018-19 –
Table 89: Detailed loan schedule for ARR (in INR Crore)
S. Particulars Opening Rate of Addition Repayment Closing Amount of No. balance interest during during the balance interest to the year year be paid 1 APDRP & RAPDRP 41.44 9.00% - 8.50 32.94 3.35 2 REC 134.34 9.00% - 13.00 121.34 11.51 3 ADB 73.87 13.00% 5.00 - 78.87 9.93 4 State Plan Loan - 13.00% - --- 5 State Non Plan Loan 169.80 13.00% 25.00 - 194.80 23.70 6 10.2% Bond - 10.20% - --- 7 FRP Term Loan - 10.00% - --- 8 Non FRP Term loan - 10.00% - - - - 9 STL for working 450.00 10.00% 750.00 315.00 885.00 66.75 capital 10 BRGF Term Loan - 10.00% - - - - PFC 11 BRGF Term Loan - 10.00% - - - - REC 12 10% Bond for 780.00 10.00% - - 780.00 78.00 outstanding power purchase liabilities Total 1,649.45 - 780.00 336.50 2,092.95 193.23
5.16.3. The interest on normative debt is calculated on the 70% of the amount of capital assets reduced by the value of grants and depreciation representing normative repayment. 5.16.4. The weighted average interest on project Loans for FY 2018-19 is calculated at 10.28%. The weighted average rate of interest on project loans is computed as mentioned in the table below.
Table 90: Weighted Average rate of Interest on project loans for FY 2018-19
S.No Particulars FY 2018-19 1 Opening Balance a APDRP & RAPDRP 414,408,412 b REC 1,343,357,984 c ADB 738,720,737 A Total(1) 2,496,487,133 2 Additions during the year a APDRP & RAPDRP - b REC - c ADB 50,000,000 B Total(2) 50,000,000 3 Repayment of Loans a APDRP & RAPDRP 85,000,000 b REC 130,000,000 c ADB - C Total(3) 215,000,000 4 Closing balance of Loans
North Bihar Power Distribution Company Limited 117 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
S.No Particulars FY 2018-19 a APDRP & RAPDRP 329,408,412 b REC 1,213,357,984 c ADB 788,720,737 D Total(4) 2,331,487,133 5 Interest on Loans a APDRP & RAPDRP 33,471,757 b REC 115,052,219 c ADB 99,283,696 E Total(5) 247,807,671 6 Average Loans (A+D)/2 2,413,987,133 7 Total interest 247,807,671 8 Weighted average rate of interest on project Loans(6*7) 10.27%
5.16.5. The below table demonstrates the computation of interest on normative debt for FY 2018- 19 –
Table 91: Interest on normative debt for ARR (in INR Crore)
S. No. Particulars Amount of loan 1 Amount of total asset at the beginning 5,214.56 2 Less: asset created from grant at beginning 2,259.71 3 Addition during the year 2,063.33 4 Less: asset created from grant during the year 1,120.45 5 Net asset 3,897.72 6 Less: Normative repayment 212.54 7 Amount of debt(loan) 3,685.18 8 Average debt 4,449.87 9 Interest on Loan (%) 10.27% 10 Interest on Loan 456.80
5.16.6. The Petitioner would like to submit that the opening assets representing the value of debt are estimated in the annual performance review for FY 2017-18 after reducing the amount of Grants from Gross Fixed Assets. The opening balance is enhanced by the asset additions in FY 2018-19 to the tune of 70% after reducing the value of grants. 5.16.7. The amount of net assets after deducting the value of grants amounts to INR 3,897.72 Crore. The value of net assets is reduced by the amount of normative repayment which is equivalent to the depreciation claimed amounting to INR 212.54 Crore. 5.16.8. It is requested to the Hon’ble Commission to approve INR 456.80 Crore towards interest on normative debt.
5.17. Other Financial Charges
5.17.1. The Petitioner is incurring other Finance charges i.e. Discount to consumers for timely payment of bills, power factor rebate, interest to suppliers/contractors etc. The
North Bihar Power Distribution Company Limited 118 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
Petitioner is claiming other Finance charges by escalating the charges estimated for FY 2017-18 by 10% in FY 2018-19.
Table 92: Other finance charges (in INR Crore)
S.No. Particulars Projections for FY 2017-18 1 Expenses estimated in FY 2017-18 66.96 2 Inflationary index 10% 3 Other Finance charges estimated for FY 2018-19 73.66
5.17.2. Therefore, the Petitioner requests the Hon’ble Commission to allow INR 73.66 Crore towards other Finance charges.
5.18. Operation & Maintenance (O&M) Expenses
5.18.1. O&M expenses are detailed in this section comprising of Repair and maintenance expenses, Administrative & General expenses and employee expenses. The O&M expenses are estimated as per regulation 22 of BERC Multi-Year Tariff Regulations, 2015 and Multi-Year Tariff Regulations 2017. 5.18.2. Employee expenses: The present strength of the employees as on 31st March 2017 is 3,444 employees. The recruitment of employee is in pipeline and for some posts examinations were also conducted in FY 2017-18 and will be conducted in FY 2018-19.The retrials planned are also taken into account for estimating the manpower requirement for FY 2018-19. It is estimated that by the end of FY 2018-19 the employee strength shall be around 3800. The Petitioner has considered the impact of 7th pay commission on employee expenses considering a multiplying factor of 2.62 from a range of 2.57 to 2.72 during the projections for FY 2017-18 and an escalation of 10% on employee expenses for FY 2017- 18 during the projections for FY 2018-19.
Table 93: Employee numbers for ARR
Ensuing year S. No. Particulars projections for FY 2017-18 1 Number of employees at the beginning of FY 2018-19 3,492 2 Number of employees added during FY 2018-19 388 3 Number of employees retiring/leaving during FY 2018- 80 19 4 Number of employees at the end of FY 2018-19 3,800
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5.18.3. Employee cost: While estimating for employee cost the Petitioner has taken the recruitment plan into consideration. In addition to this the factors like salary revision etc. the employee cost will increase by 10% .The calculation of DA is done taking into account 10% increase in periods when DA increases. 5.18.4. The employee expenses projected by the Petitioner for FY 2018-19 is demonstrated as below.
Table 94: Employee expenses for ARR (in INR Crore)
S. No. Particulars Ensuing Year FY 2018-19 1 Salaries & Allowances (i) Existing Employees 234.18 (ii) New Employees 26.02 (ii) Total 260.20 2 Contribution to Terminal Benefits (Accrual Basis) 18.76 3 Total of Salary & Allowances and Terminal Benefits 278.96 4 Amount Capitalized - 5 Net Amount 278.96 6 Grand Total 278.96
5.18.5. In the light of the above explanation the Petitioner would request the Commission to allow the employee expenses of INR 278.96 Crore.
5.18.6. Repair and maintenance expenses: The R&M expenses primarily includes expenses incurred by the Petitioner related to repair of different class of fixed assets etc. Regulation 22.2 of Bihar Electricity Regulatory Commission (Multi Year Distribution Tariff) Regulations, 2015 provides methodology for calculation of Employee Cost as follows: “22.2 Repairs and Maintenance (R&M) Expense Repairs and Maintenance expense shall be calculated as percentage (as per the norm determined) of Opening Gross Fixed Assets for the year governed by following formula: R&Mn = Kb * GFAn Where: R&Mn : Repairs & Maintenance expense for nth year GFAn : Opening Gross Fixed Assets for nth year Kb : Percentage point as per the norm”
5.18.6.1. The Petitioner has accordingly computed the ‘K’ factor (i.e. R&M norm) based on previous 2(two) years audited accounts for FY 2015-16 & FY 2016-17 and projected figures for FY 2017-18 as given below:
Table 95: Calculation of “K” Factor for FY 2018-19
S. No. Particulars FY 2015-16 FY 2016-17 FY 2017-18 1 Opening GFA (in INR Crore) 4,299 4,574 5,158 2 R&M Cost (in INR Crore) 64.99 49.21 69.72 3 % of R&M Cost on Opening GFA 1.51% 1.08% 1.35% 4 K Factor considered for FY 1.31% 2018-19
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5.18.6.2. The Petitioner has computed the R&M expenses adopting ‘K’ factor on the Opening GFA for FY 2018-19 as detailed in the Table below:-
Table 96: R&M Expenses for APR (in INR Crore)
S. No. Particulars FY 2017-18 1 Opening GFA 7,449.37 2 % of R&M to opening GFA 1.31% 3 R&M Expense 97.64
5.18.7. Therefore in the light calculations it is prayed to the Hon’ble Commission to allow the expenses for R&M for INR 97.64 Crore. 5.18.8. Administration and General Expenses: As per Regulation 22.3, of BERC MYT Tariff Regulations, 2015 A&G expense shall be computed as per the norm escalated by wholesale price index (WPI), adjusted by provisions for confirmed initiatives (IT and other initiatives as proposed by the Distribution Licensee and validated by the Commission) or other expected one-time expense. The relevant Regulation has been extracted below: “22.3 Administrative and General (A&G) Expense A&G expense shall be comp as per the norm escalated by wholesale price index (WPI) and adjusted by provisions for confirmed initiatives (IT etc. initiatives as proposed by the Distribution Licensee and validated by the Commission) or other expected one-time expenses, and shall be governed by following formula: A&Gn = (A&Gb * WPI inflation) + Provision Where: A&Gn: A&G expense for the year n A&Gb: A&G expense as per the norm WPI inflation: is the average increase in the Wholesale Price Index (WPI) for immediately preceding three years Provision: Cost for initiatives or other one-time expenses as proposed by the Distribution Licensee and validated by the Commission. Till the norms of A&G expenses is specified by the Commission, the actual historical cost will be considered for determination of A&G expenses.”
5.18.9. As there are no norms yet specified for the projection of A&G expenses, therefore the Petitioner has taken the A&G expenses estimated for FY 2017-18 as the base and increased the base amount by increase in A&G expenditure in FY 2017-18 and FY 2016- 17. 5.18.10. Below is the projection for FY 2018-19 for A&G expenses:-
Table 97: A&G expenses for ARR (in INR Crore)
S. No. Particulars Ensuing years (Projection) FY 2018-19 1 Rent, Rates & Taxes 0.34 2 Insurance 3.80 3 Telephone, Postage & Telegrams 12.00 4 Consultancy fees 0.07 5 Technical fees -
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S. No. Particulars Ensuing years (Projection) FY 2018-19 6 Other professional charges 9.85 7 Conveyance &travel expenses 10.15 8 Electricity & Water charges 5.66 9 Freight 0.53 10 Remuneration to Executive Assistant 6.01 11 Commission to RRF 26.99 12 Printing and Stationery 1.54 13 Meter reading and Bill Distribution 5.44 14 Home guard / Security guard 3.33 15 Other material related expenses 0.00 16 Commission 1.47 17 Computer Billing 12.47 18 Compensation (if any) 6.12 19 Holding Tax exp. 13.08 20 Any other expenses 5.07 21 Total expenses charged to revenue 123.92
5.18.11. The Petitioner therefore requests the Hon’ble Commission to approve the expenses of INR 123.92 Crore towards A&G expenses for FY 2018-19. 5.18.12. Allocation of Holding Company cost: The Petitioner is claiming the holding company expenses by escalating the expenses projected for FY 2017-18 in Annual performance review by 10%. 5.18.13. The below table represents the allocation of Holding Company cost towards Petitioner for FY 2018-19:-
Table 98: Holding company cost for ARR (in INR Crore)
S. No Particulars Ensuing year 1 Previous year expenses 5.92 2 Inflation rate considered 0.10 3 Inflationaryincrease(1*2) 0.59 4 Employee expenses 5 R&M expenses 6 A&G expenses 7 Total 6.51
5.18.14. The Petitioner requests the Hon’ble Commission to approve INR 6.51 Crore for FY 2018- 19 towards allocation of Holding Company cost.
5.19. Return on Equity
5.19.1. The Petitioner has projected Return on Equity as per Regulation 27 of the BERC Multi Year Distribution Tariff Regulations 2015 read with Multi Year Tariff Regulations 2017, as extracted below:.
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a. Return on equity shall be computed on 30% of the capital base or actual equity, whichever is lower: Provided that assets funded by consumer contribution, capital subsidies/ grants and corresponding depreciation shall not form part of the capital base. Actual equity invested in the Distribution Licensee as per book value shall be considered as perpetual and shall be used or computation in this Regulation: b. The return on the equity invested shall be allowed from the date of start of commercial operation: c. The project which will be commissioned w.e.f. 01.04.2016 will be allowed RoE of 15.5% and if project is completed in schedule period 0.5% incentives in form of RoE will be allowed.
5.19.2. The return on equity is calculated on 30% of the fixed assets reduced by the amount of grants. The below table shall demonstrates the detailed calculation for return on equity:-
Table 99: Return on equity for ARR (in INR Crore)
S. No. Particulars Amount of equity 1 Amount of total asset at the beginning 2,234.81 2 Less: asset created from grant at beginning 968.45 3 Addition during the year 884.28 4 Less: asset created from grant during the year 480.19 5 Net asset 1,670.45 6 Average equity 1,952.63 7 Amount of equity eligible for return 1,952.63 8 Rate of return on equity 16.00% 9 Amount of return on equity 312.42
5.19.3. As depicted from the above table the opening GFA of INR 2234.81 Crore is 30% of the value of the GFA estimated in APR i.e. as on 1st Apr 2018. 5.19.4. In FY 2018-19 the total additions in GFA is estimated as INR 884.28 Crore of which assets funded through grants are amounting to INR 480.19 Crore. The return on equity is calculated at the rate of 16% on the amount eligible for equity 5.19.5. Therefore, in the light of the above explanations it is requested to the Hon’ble Commission to approve the RoE as INR 312.42 Crore for FY 2018-19. 5.19.6. Therefore it is requested to the Hon’ble Commission to reconsider the amount of equity in Tariff order for FY 2018-19 in the light of the judgement passed by the Hon’ble APTEL.
5.20. Interest on Consumer Security Deposit
5.20.1. The Petitioner submits that Interest on Security Deposit amount has been claimed as per the provisions of Multi-Year tariff regulations 2015 read with Multi-Year tariff regulations 2017, Regulation 26 (iii) specifies that
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“Provided further that interest shall be allowed on consumer security deposits and security deposits from Distribution system users at the Bank Rate as of the date on which the petition for determination of tariff is accepted by the Commission”. 5.20.2. The below table demonstrates the calculation of interest on consumer security deposits projected for FY 2018-19:-
Table 100: Interest on consumer security deposits (in INR Crore)
S. No. Particulars FY 2018-19 1 Opening Security Deposit 309.27 2 Addition / (Deletion) during the year 37.73 3 Closing Security Deposit 346.99 4 Average Security Deposit (1+3)/2 328.13 5 RBI Bank Rate 7.75% 6 Interest on Security Deposit 25.43
5.20.3. The Petitioner has taken opening balance for FY 2018-19 as INR 309.27 Crore which is the closing balance as estimated in annual performance review of FY 2017-18. The additions are assumed as per the audited financial statement for FY 2016-17 i.e. INR 37.73 Crore. The interest on consumer security deposits is calculated at the rate of 7.75% which is the RBI bank rate as on 1st April, 2018. 5.20.4. Therefore, it is requested to the Hon’ble Commission to approve INR 25.43 Crore towards interest on consumer security deposit for FY 2018-19.
5.21. Interest on Working Capital
5.21.1.The Petitioner has estimated the amount towards interest on Working capital for FY 2018-19 as per Amendment to Regulation 26 of Bihar Electricity Regulatory Commission (Multi Year Distribution Tariff) Regulations, 2015 issued by the Hon’ble Commission under Bihar Electricity Regulatory Commission (Multi Year Distribution Tariff) (First Amendment) Regulations, 2017, Regulation 26 as extracted below:
"The Distribution Licensee shall be allowed interest on estimated level of working capital for the financial year, computed as follows:
a) Two months equivalent of expected revenue b) Maintenance spares@40% of R&M expenses for one month: Less: (i) Power purchase cost, transmission charges and load dispatch charges of one month (ii) Depreciation, return on equity and contribution to contingency reserves equivalent to two months (iii) Security deposits from consumers, if any Provided that the interest on working capital shall be on normative basis and rate of interest shall be equal to the State Bank Advance Rate (SBAR) as of the date on which petition for determination of tariff is accepted by the Commission.
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Provided further that interest shall be allowed on consumer security deposits and security deposits from Distribution System users at the Bank Rate as of the date on which petition for determination of tariff is accepted by the Commission. Provided further that if the State Government is providing resource gap grant or subsidy, working capital shall be reduced by that amount."
5.21.2. The Petitioner has considered two months equivalent expected revenue and 40% of one month of R&M expense as specified in the above Regulation which was further deducted by Power Purchase cost along with transmission charges for one month, depreciation, ROE, contingency reserve for 2 month, consumer security deposit. 5.21.3. It is pertinent to note that the Petitioner has determined the ARR for FY 2018-19 taking UDAY scheme loss trajectory into consideration which is also approved by the Hon’ble commission in the tariff order dated 24 th March 2017. Therefore in the absence of any difference in the loss trajectory of UDAY scheme and the approved trajectory by the Hon’ble commission. Therefore there will be no state government fund allocated towards disallowance of power purchase cost. In the light of the above explanation Petitioner has not deducted any amount towards disallowed power purchase from working capital requirement. 5.21.4. The interest on working capital is calculated at the rate of 14.75% which is SBI advance rate. In the light of the above facts the Petitioner would submit that it is incurring the interest on working capital at a higher level than as calculated as per normative requirement.
Table 101: Interest on working capital for ARR (in INR Crore)
S. No. Particulars Amount 1 Two months equivalent of expected Revenue 1,201.27 2 Maintenance Spares @40% of R&M expense for one month 3.25 3.1 Less: Power Purchase cost, Load dispatch charges and transmission charges for 478.17 one month 3.2 Less: Depreciation, ROE, Contribution to contingency reserve equivalent to two 87.49 months 3.3 less: Security Deposit from consumer if any 27.34 3.4 Less: Grant received from Govt for power purchase and other O&M expense - equivalent to two months 4 Net Working Capital 611.51 5 Interest rate 14.75% 6 Interest on Working Capital 90.20
5.21.5. The Petitioner requests Hon’ble Commission to approve the interest of working capital at INR 90.20 Crore for FY 2018-19.
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5.22. Non-Tariff Income
5.22.1. The Petitioner has projected the Non-Tariff income taking the amount estimated in Annual performance review of FY 2017-18 and then escalating the same by 10%. The below table demonstrates the other non-tariff income for FY 2018-19:
Table 102: Non-tariff income for ARR (in INR Crore)
S.No. Particulars Amount Interest Income 1 Interest on Advances to 59.69 Suppliers/Contractors 2 Interest from Banks 9.09 3 Interest on Staff Loan & Advances 0.28 Other Income 4 Delayed Payment Surcharge from 64.47 Consumers 5 Income from sale of Tender paper 0.65 6 Miscellaneous Receipts 0.92 7 Rebate and Discount Received 12.32 8 Supervision Charges 0.16 Others 9 Meter Rent/ Service Line Rental 95.00 10 Miscellaneous Recoveries 18.80 Total Non-tariff income 261.38 11 DPS as per Audited Accounts 64.47 12 Principal amount on which DPS 358.14 Charged 13 Interest Rate of funding DPS 14.75% 14 Interest on funding Principal 52.83 Net Non-Tariff Income 208.55
5.22.2. The Petitioner requests the Hon’ble Commission to approve INR 208.55 Crore towards non-tariff income for FY 2018-19.
5.23. Revenue from Sale of Power at Existing Tariff
5.23.1. Revenue from Sale of Power at Existing Tariff for the Petitioner is given in table below-
Table 103: Revenue from sale of power at existing tariff for ARR (in INR Crore)
ABR Category Sales ( MU) FY 2018-19 (INR/kWh) Domestic 5,450.68 1,968.58 3.61 Kutir Jyoti- BPL Consumers 1,515.08 361.57 2.39 Domestic - I 2,223.25 717.22 3.23 Domestic – II 1,712.35 889.78 5.20 Commercial 784.48 580.19 7.40 Non-Domestic - I 85.64 35.47 4.14 Non-Domestic - II 698.84 544.72 7.79 Public Lighting 16.83 15.26 9.06
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ABR Category Sales ( MU) FY 2018-19 (INR/kWh) Street Light - I 6.88 5.40 7.86 Street Light - II 9.96 9.86 9.90 Irrigation 522.95 253.06 4.84 IAS – I 338.06 71.80 2.12 IAS – II 184.88 181.26 9.80 Public Water Works 35.67 38.37 10.75 Industrial LT 294.67 213.28 7.24 LTIS – I 270.32 190.24 7.04 LTIS – II 24.36 23.05 9.46 Industrial HT 716.15 570.97 7.97 HTS – I 434.39 365.37 8.41 HTS – II 149.33 118.69 7.95 HTS – III 65.95 53.32 8.09 HTSS 66.49 33.58 5.05 Railway 62.67 61.64 9.84 Nepal 1,188.89 665.39 5.60 DF 1,058.00 484.56 4.58 Total 10,131.00 4,851.30 4.79
5.23.2. The Petitioner requests the Hon’ble Commission to approve revenue from existing Tariff as INR 4851.30 Crore for FY 2018-19.
5.24. Net ARR for FY 2018-19
5.24.1. The Annual Revenue Requirement for FY 2018-19 is given in the table below-
Table 104: Net ARR for FY 2018-19 (in INR Crore)
Ensuing Year S. No. Particulars 2018-19 1 Power purchase cost 5070.89 2 PGCIL & other transmission charges 325.48 3 State Transmission charges & BGCL 341.73 4 O&M Expenses i) Employee Cost 278.96 ii) R&M expenses 97.64 iii) A&G expenses 123.92 Share of Holding Company 6.51 5 expenses 6 Depreciation 212.54 7 Interest and Finance charges 530.46 8 Interest on working capital 90.20 9 Return on equity 312.42 10 Income Tax 0.00 11 Interest on security deposit 25.43 12 Bad debts (if any) 0 13 Contingency reserves (if any) 0 14 Total Revenue Requirement 7,416.17 15 Less: Non-tariff income 208.55 16 Aggregate Revenue Requirement 7,207.62
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5.25. Net Gap at Existing Tariff
5.25.1.The Petitioner would like to submit the Net ARR requirement for FY 2018-19 is INR 7207.62 Crore. The unrecovered revenue gap along with the carrying cost for True-Up of FY 2016- 17 and APR 2017-18 is computed considering SBI Advance rate for FY 2018-19. The below table represents the revenue gap in APR for FY 2017-18 increased by carrying cost at SBI Advance rate.
Table 105: Unrecovered revenue Gap for FY 2017-18
Deficit with carrying cost Amount (INR Crore) Revenue gap in APR for FY 2017-18 1,930.40 Interest for FY 2017-18 (SBI Adv R @ 14.75%) for 6 months 142.37 Interest for FY 2018-19 (SBI Adv R @ 14.75%) for 12 months 284.73 Total unrecovered gap for FY 2017-18 2,357.50
5.25.2.The Petitioner requests the Hon’ble Commission to approve unrecovered gap of INR 2,357.50 Crore for FY 2017-18. 5.25.3.The petitioner has not considered unrecovered gap for True up of FY 2016-17 and APR FY 2017-18 during the computation of net revenue gap for FY 2018-19. The net revenue gap at existing tariff for FY 2018-19 is as below.
Table 106: Net revenue gap at existing tariff
S.No. Particulars Amount (INR Crore) 1 Aggregate Revenue Requirement (ARR) 7416.17 2 Less : Non-Tariff Income 208.55 3 Add : Recovery of revenue gap / (Surplus) of past period, if any 0.00 4 Net ARR 7207.62 5 Less : Power Purchase Cost disallowed, if any 0 6 Less : Revenue from Existing Tariff 4851.30 7 Less : Revenue from sale of power to other Agency 0 8 Gap (4–5–6) 2356.32 9 Total grant from State Govt. (Same per Unit Subsidy) 0.00 10 Grant used for compensating disallowed power 0 11 Balance resource grant assistance from Stat Govt. (9–10) 0.00 12 Net Gap/(Surplus) at existing tariff (8–11) 2356.32
5.26. Revenue from Sale of Power at Proposed Tariff
5.26.1. Revenue from sale of power at proposed tariff for FY 2018-19 is given in table below Table 107: Total revenue from sale of power at proposed tariff
Category Sales ( MU) FY 2018-19 ABR (INR/kWh) Domestic 5,450.68 3948.53 7.24 Kutir Jyoti- BPL Consumers 1,515.08 953.04 6.29 Domestic – I 2,223.25 1623.61 7.30 Domestic – II 1,712.35 1371.88 8.01 Commercial 784.48 664.88 8.48 Non-Domestic - I 85.64 60.61 7.08
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Non-Domestic - II 698.84 604.26 8.65 Public Lighting 16.83 14.75 8.76 Street Light - I 6.88 5.29 7.69 Street Light - II 9.96 9.46 9.50 Irrigation 522.95 365.61 6.99 IAS – I 338.06 196.10 5.80 IAS – II 184.88 169.51 9.17 Public Water Works 35.67 36.12 10.13 Industrial LT 294.67 221.72 7.52 LTIS – I 270.32 197.49 7.31 LTIS – II 24.36 24.23 9.95 Industrial HT 716.15 600.98 8.39 HTS – I 434.39 369.23 8.50 HTS – II 149.33 124.82 8.36 HTS – III 65.95 58.59 8.88 HTSS 66.49 48.34 7.27 Railway 62.67 71.50 11.41 Nepal 1,188.89 665.39 5.60 DF 1,058.00 629.93 5.95 Total 10,131.00 7219.42 7.13
5.27. Revenue gap for FY 2018-19 at proposed tariff
5.27.1. The Petitioner is estimating Annual Revenue Requirement for FY 2017-18 on 100% cost coverage basis. 5.27.2. The average cost of supply for NBPDCL is determined as INR 7.11 per unit for FY 2018-19 Table 108: The revenue gap at proposed tariff for FY 2018-19
S.No. Particulars Amount (INR Crore) 1 Aggregate Revenue Requirement (ARR) 7416.17 2 Less : Non-Tariff Income 208.55 Add : Recovery of revenue gap / (Surplus) of 3 0.00 past period, if any 4 Net ARR 7207.62 5 Less : Power Purchase Cost disallowed, if any 0 6 Less : Revenue from proposed Tariff 7219.42 Less : Revenue from sale of power to other 7 0 Agency 8 Gap (4–5–6) -11.79 9 Total grant from State Govt. 0.00 10 Grant used for compensating disallowed power Balance resource grant assistance from Stat 11 0.00 Govt. (9–10) 12 Net Gap/(Surplus) at Proposed tariff (8–11) -11.79
The Petitioner requests the Hon’ble commission to consider the facts presented for determination of Tariff for FY 2018-19
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6. Revenue Gap and Regulatory Asset
6.1. Background
6.1.1. The BSEB was restructured and the successor entities started independent functions with effect from 1st November 2012 6.1.2. The Hon’ble Commission had approved cumulative revenue surplus of INR 298 Crores in tariff orders from FY 2006-07 to FY 2011-12 for BSEB
Table 109: Revenue Gap approved by the Commission for BSPHCL (in INR Crore)
Particulars Amount (INR Crore) Revenue Gap/(Surplus) for FY 2006-07 7.23 Revenue Gap/(Surplus) for FY 2007-08 86.56 Revenue Gap/(Surplus) for FY 2008-09 123.41 Revenue Gap/(Surplus) for FY 2009-10 274.67 Revenue Gap/(Surplus) for FY 2010-11 -639.93 Revenue Gap/(Surplus) for FY 2011-12 -149.94 Total Revenue Gap/(Surplus) up to FY 2011-12 -298
6.1.3. Post restructuring, the True up petition for FY 2012-13 was filed by the Holding company (BSPHCL) on behalf of erstwhile BSEB and the four successor companies i.e. BSPGCL, BSPTCL and two Discoms (i.e. NBPDCL and SBPDCL). This was a joint petition of all successor entities. 6.1.4. The Hon’ble Commission in the True-up petition for FY 2012-13 approved true up surplus of INR 917.33 Crore (revenue surplus Rs.801.51 crore + carrying cost Rs.115.82 crore) vide its True-up Order dated 28th February, 2014 which is further adjusted with approved surplus of BSEB and and gap for FY 2013-14 as approved by the Hon’ble Commission. 6.1.5. The below paragraph demonstrates the details of revenue surplus approved by the Hon’ble Commission for FY 2012-13 along with surplus approved for BSEB period and gap approved by the Hon’ble Commission for FY 2013-14.
Table 110: Revenue Gap approved by the Commission up to FY 2013-14 for BSPHCL (in INR Crore)
Particulars Amount (INR Crore) Total Revenue Gap/(Surplus) up to FY 2011-12 -298 Revenue Gap/(Surplus) for FY 2012-13 -801.51 Interest for FY 2013-14 (SBI PLR @ 14.45%) for 1 year -115.82 Total Surplus with Interest up to Mid of FY 2013-14 -917.33 Total amount at mid of FY 2013-14 -1215.33 Revenue Gap/(Surplus) for FY 2013-14 307.67 Total amount as on mid of 2013-14 -907.66
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6.1.6. The above surplus of INR 907.66 crore was allocated to NBPDCL INR 381.22 crore and SBPDCL INR 526.44 crore in their power sharing ratio of 42:58 respectively by the Hon’ble Commission. The Commission also adjusted the balance revenue surplus along with carrying cost against the as given in the Table below:
Table 111: Revenue Gap approved by the Hon’ble Commission up to FY 2013-14 for BSHPCL (in INR Crore)
Particulars Amount (INR Crore) Revenue Gap/(Surplus) for FY 2012-13 -801.51 Carrying cost for FY 2013-14 (SBI PLR @ 14.45%) for 1 -115.82 year Total Surplus with carrying cost up to Mid of FY 2013-14 -917.33 Total Revenue Gap/(Surplus) up to FY 2011-12 for BSEB -298 period Total revenue surplus to be carried forward in FY 2013-14 -1215.33 Revenue Gap/(Surplus) for FY 2013-14 307.67 Total surplus as on FY 2013-14 -907.66 NBPDCL @42% -381.22 SBPDCL @ 58% -526.44 Carrying Cost for FY 2013-14 @ 14.75% -133.88 NBPDCL -56.23 SBPDCL -77.65 Carrying Cost for 6 months of FY 2014-15 @ 14.75% -66.94 NBPDCL -28.11 SBPDCL -38.83 Revenue Gap/(Surplus) carried forward as on 31st March 2015 -1108.48
6.1.7. Subsequently, aggrieved by the decision of the Hon’ble Commission, on the determination of cumulative surplus of INR 1,108.48 Crore the Petitioner had filed appeal (Appeal No.141 of 2016 of SBPDCL and Appeal No.142 of 2016 of NBPDCL) before the Hon’ble APTEL. The Hon’ble APTEL vide its Judgment dated 25th November, 2016 held that the surplus of the past period pertains to the erstwhile BSEB and also the issue regarding disallowance of carrying cost need to be reviewed by the State Commission. 6.1.8. The Hon’ble Commission in response to the Judgment of the Hon’ble APTEL issued a revised Order dated 8th March, 2017 wherein the Hon’ble Commission opines that such surplus created as a result of truing-up belongs to consumers and the consumers cannot be deprived of the benefit of such surplus. 6.1.9. The Petitioner had filed an appeal against the order of the Hon’ble Commission dated 8th March,2017 vide appeal no 154/2017 and 155/2017 of FY 2016-17 on 24th April 2017 6.1.10. The Petitioner understands that since the whole matter is sub-judice before Hon’ble APTEL and till the time any judgment in the matter comes, the prevailing Order of Hon’ble Commission shall stand effective.
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6.1.11. Without prejudice to the rights and contentions of the Petitioner, this is to put on record that the present petition for determination of tariff for FY 2018-19 is based on the order passed by this Hon'ble Commission dated 8th March, 2017. 6.1.12. It is submitted that the Petitioner herein has filed an appeal being no 154/2017 and 155/2017 of FY 2016-17 against the above order dated 8th March,2017 of the Hon'ble Commission and the same is pending before the Hon'ble Tribunal. The Petitioner herein reserves the right to make the necessary changes in the present petition depending on the outcome of appeal no 154/2017 and 155/2017 of FY 2016-17 and seek appropriate directions from this Hon'ble Commission. 6.1.13. It is suggested that the amount recoverable for past period gap / (surplus) by the two Discoms and the gap / (surplus) for FY 2017-18, be created into a Regulatory Asset and not passed on to consumer tariffs for the ensuing year. This amount may be allowed to be recovered by the Petitioner as Regulatory Surcharge at a rate as allowed by the Hon’ble Commission in the subsequent years. Only the revenue gap for FY 2018-19 be passed on to consumer tariffs for FY 2018-19. This shall enable the Petitioner to recover from the cascading effect of the carrying cost and the consumers shall also be benefited by comparatively reduced tariffs.
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7. Voltage-wise cost of supply
7.1. Preamble
7.1.1. This section deals with the voltage wise cost of service by the Petitioner for FY 2018-19.
7.2. Background
7.2.1. The Commission had determined the Multi Year Aggregate Revenue Requirement (ARR) for the second control period FY 2016-17 to FY 2018-19 in the order dated 21st March, 2016. 7.2.2. The Petitioner computed the voltage wise cost of supply for both Discoms, considering energy sales, T&D loss and fixed costs combined for both Discoms for FY 2018-19. The Petitioner has considered distribution losses in line with UDAY distribution loss trajectory, as approved by the commission in the Tariff Order dated 24th March 2017. Since the approved distribution loss trajectory is different for both the Discoms at 22% for SBPDCL and 20% for NBPDCL. The Petitioner has computed Voltage-wise cost of supply separately for SBPDCL and NBPDCL.
7.3. Methodology adopted for Computation of Voltage wise Cost of Supply
7.3.1. The Hon’ble APTEL has proposed a simple methodology to functionalize use of Cost of Supply model. The APTEL notes that identical consumers connected at different nodes of distribution system need not to be differentiated. In addition, it is adequate to determine voltage-wise cost of supply taking into account the major cost elements which would be applicable to all the categories of the consumers connected at the same voltage level at different locations in the distribution system. 7.3.2. In the method suggested by the Hon’ble APTEL, there are five major components to arrive at the voltage wise cost of supply. These elements are: Technical losses at each voltage level of the network: This value of the technical losses is found by the field studies. Sampling of the feeders which are representative of the consumers in the system will help in identifying the technical losses at each voltage levels. The APTEL recognizes the difficulty in collecting data for technical loss at 11 kV and LT level, hence the suggestion to compute losses using maximum possible representative feeders for various consumer categories at respective voltage levels. Commercial losses at each voltage level of the network: The commercial loss of the system is the difference between approved loss in the ARR and the total technical loss computed from system study. This difference is to be apportioned according to the sales in each voltage level to arrive at the commercial loss at each voltage level.
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Voltage wise sales: The energy sale at a particular voltage level is the sum of energy sold for all the categories of consumers connected at the said voltage level. Due to its share of sales in total sales, the consumers of the 132/220 kV network will be apportioned a share of the commercial losses. The Hon’ble APTEL recognizes that in reality, there may be minimal technical losses at that level and very low probability of commercial losses. However, the APTEL is of the opinion that the consumers at 132/220 kV, being a part of the distribution system will bear these apportioned losses. Power Purchase Cost: The power purchase cost is the cost of energy purchased for sustaining the energy sales at each voltage level. This power purchase units for each voltage level is arrived by finding the energy input at each voltage level and adding the losses (technical and commercial) for the same voltage level and upstream. The energy input at each voltage level is the sum of the sales at the voltage level and the losses for the corresponding voltage level. Network Cost: The network costs are the costs like O&M, interest and finance charges, depreciation, return on equity etc. These costs are a part of the ARR which in turn provides the average cost of supply. Thus, the network cost is essentially the difference between the ARR value and the power purchase cost. The APTEL has suggested apportioning these costs according to the sales volume in each of the voltage level. 7.3.3. The above elements will help to establish the voltage wise Cost of Supply. Due to the methodology applied to apportion losses in the various voltage levels, all the consumer categories at a particular voltage level will have same cost of supply. In this regard, APTEL has noted that refinements in the methodology may be done when more data becomes available.
7.4. Determination of Voltage wise Losses
7.4.1. Transmission & Distribution losses in a system are comprised of two separate components - Technical losses and Commercial losses. Technical losses occur naturally and consist mainly of power dissipation in electricity system components such as transmission and distribution lines, and transformers. Commercial losses are caused by actions external to the power system and consist primarily of electricity theft, non-payment by customers, and errors in accounting and record-keeping. Since the rationale behind these two components is quite distinct, quantifying them separately is imperative for arriving at meaningful conclusions. 7.4.2. At each voltage level, the Technical losses consist of two major components: Transmission losses which refer to the losses in the current carrying wires; and Transformation losses which refer the losses incurred during the voltage transformation in the system. Aggregating the
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losses in these two elements at each voltage level would give the technical loss at that level. The losses remaining would be the commercial losses.
7.5. Information required for arriving Voltage Wise Cost of Supply
7.5.1. Following is the list of details required in order to carry out voltage wise cost of supply: Voltage wise technical losses Overall T&D losses Voltage wise energy sales Power Purchase Cost Network Costs 7.5.2. It is submitted that the Petitioner has computed voltage wise losses based on certain assumptions after observing the sample feeder data available with discoms 7.5.3. The Petitioner has computed voltage wise cost of supply for NBPDCL in view of distribution loss percentage approved by the Hon’ble commission for FY 2018-19.
Table 112: Voltage wise Technical losses considered for FY 2018-19
Voltage Level S. No. Technical loss (%) Cumulative loss (%) (kV) 1 220/132 3.92% 3.92% 2 33 5.00% 8.72% 3 11 6.00% 10.70% 4 0.4 10.50% 20.08%
7.5.4. The Petitioner has arrived at voltage wise sales considering the projected sale of power for FY 2018-19, across various categories at the respective voltages mentioned in the table below
Table 113: Classification of Categories on the basis of Voltage of power supply
S.No Voltage Level Categories
1 220/132 kV HTS-III, Railways, Nepal 2 33 kV HTS-II, HTSS, DF 3 11 kV HTS-I 4 LT Domestic, Non Domestic, Agriculture and Others
7.5.5. The Petitioner further submits that since the voltage wise cost of supply study is based on the sample data certain parameters such as total loss, energy input etc. may not tally with the main energy balance projected for FY 2017-18. 7.5.6. Voltage Wise Technical Loss: The Petitioner submits that it has taken suitable assumptions to arrive at the loss at 220 kV and 132 kV to arrive at the audited loss of BSPTCL.
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7.6. Methodology adopted for determination of Cost of Supply
7.6.1. The Petitioner has claimed Distribution Loss at 31.43% for FY 2016-17. Due to lack of data for segregation of technical and commercial losses, it is not feasible to fix the technical and commercial loss levels within proposed loss levels. 7.6.2. In order to understand component of technical losses in total T&D loss, technical loss at each voltage level need to be grossed. Following is the total technical loss at each voltage level and cumulative losses at subsequent voltage levels.
Table 114: Voltage wise Technical losses considered for FY 2018-19
Voltage Level S. No. Technical loss (%) Cumulative loss (%) (kV) 1 132 3.92% 3.92% 2 33 5.00% 8.72% 3 11 6.00% 10.70% 4 0.4 10.50% 20.08%
7.6.3. Following is the apportionment of technical losses to the voltage wise sale.
Table 115: Apportionment of technical losses to voltage wise sale
Voltage Energy Energy input Technical Technical Cumulative loss S. No. Level Sale (MU) loss losses(%) (%) (kV) (MU) (MU) 1 220/132 3.92% 3.92% 1,317.51 1,371.27 53.75 2 33 5.00% 8.72% 1,273.27 1,340.29 67.01 3 11 6.00% 10.70% 434.39 462.12 27.73 4 0.4 10.50% 20.08% 7,105.83 7,939.47 833.64 Total 10,131.00 11,113.14 982.14
7.6.4. Commercial losses (difference of total losses and grossed up technical losses) shall be apportioned pro rata to energy sales at each voltage level.
Table 116: Apportionment of Commercial losses to voltage wise sale
Energy Voltage Input at Technical Sales + Tech Loss Commercial S. No. Level Energy sale(MU) State loss(MU) (MU) Loss (MU) Periphery (kV) (MU) 1 220/132 1,317.51 53.75 1,371.27 252.30 1,623.57 2 33 1,273.27 67.01 1,340.29 246.60 1,586.88 3 11 434.39 27.73 462.12 85.02 547.14 4 0.4 7,105.83 833.64 7,939.47 1,460.77 9,400.25 Total 10,131.00 982.14 11,113.14 2,044.69 13,157.84
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7.6.5. The Projected Power Purchase Cost (including PGCIL, POSOCO, BSPTCL, BGCL & ERLDC transmission costs) of NBPDCL for FY 2018-19 is INR 4.37/ kWh. It is submitted that overall power purchase cost for both Discom’s is INR 4.37/kWh. 7.6.6. Following is the allocation of power purchase cost to the total energy sales.
Table 117: Allocation of power purchase cost to the total energy sales
Cost of Power Voltage Energy Input at Power S. Energy Sale Average power per unit sale Level State Purchase Cost No. (MU) purchase cost of Energy (kV) periphery(MU) (INR Crore) (INR/kWh)
1 220/132 1,317.51 1,623.57 4.37 709.34 5.38 2 33 1,273.27 1,586.88 4.37 693.32 5.45 3 11 434.39 547.14 4.37 239.05 5.50 4 0.4 7,105.83 9,400.25 4.37 4,107.02 5.78 Total 10,131.00 13,157.84 4.37 5,748.73 5.67
7.6.7. The details of fixed distribution costs for FY 2018-19 are provided below which are excluding Power Purchase and PGCIL charges.
Table 118: Allocation of Network Cost
Amount S. No. Particulars (INR Cr) 1 Employee Cost 278.96 2 R&M costs 97.64 3 A&G expenses 123.92 4 Holding Company 6.51 5 Depreciation 212.54 6 Interest & Finance Charges 530.46 7 Interest on Working Capital 90.33 8 RPO fund 9 Return on Equity 312.42 10 Interest on Security Deposit 25.43 11 Less: IDC 12 Less: Non-Tariff Income 208.55 13 Total 1,469.67 14 Transmission cost 347.46 15 Total cost 1,817.13 16 Energy Sales (MU) 10,131.00 17 Network Cost per unit sale of energy (Distribution + Transmission) (INR/kWh) 1.79
7.6.8. The Cost of Supply at different voltage levels is given in the table below:
Table 119: Cost of Supply at different Voltage Levels
Cost of Network Cost of power cost supply S. No. Supply Voltage purchase (INR/unit) (INR/unit) (INR/unit) 1 220/132 KV 5.38 1.79 7.18
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Cost of Network Cost of power cost supply S. No. Supply Voltage purchase (INR/unit) (INR/unit) (INR/unit) 2 33 KV 5.45 1.79 7.24 3 11 KV 5.50 1.79 7.30 4 0.4 KV 5.78 1.79 7.57
7.6.9. The Hon’ble Commission is requested to approve the Voltage wise cost of supply for the Petitioner for FY 2017-18.
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8. Miscellaneous and General Charges
8.1. Schedule of Miscellaneous and General Charges 8.2. Meter Rent 8.2.1. Background
8.2.1.1. The Electricity Act, 2003 empowers the Discom to recover its legitimate business expenses and enlist the charges to be levied on its consumers. Such charges include fixed charge in addition to the charge for the actual electricity supplied and rent or other charges in respect of any electric meter or electrical plant provided by the distribution licensee. The relevant extract from the EA, 2003 is provided as under:
“(3) The charges for electricity supplied by a distribution licensee may include - (a) a fixed charge in addition to the charge for the actual electricity supplied; (b) a rent or other charges in respect of any electric meter or electrical plant provided by the distribution licensee.”
8.2.1.2. Further, Clause 55 of the EA, 2003 also mandates for supply of electricity through meter. In its endeavor to provide metered connection, the Petitioner has been making huge investments for procurement of meters for its consumers, which are dynamic in nature with advanced technology. The technology of meter reading and billing in India is continuously evolving and has undergone a paradigm shift in recent past. The Petitioner has moved from the old electromechanical meters to electronic meters for LT consumers and AMR meter for the consumers connected at higher voltage level. Also, the Distribution Licensees are planning to install large number of prepaid meters and also to introduce smart meters among the LT consumers. This shall bring in more transparency into the system in terms of better energy accounting and less prone to tampering. The Petitioner has also established facilities for in-house meter testing and calibration for testing all kinds of meters for its consumers. 8.2.1.3. The cost of meters needs to be recovered from the consumers within a certain timeframe. Section 8.7 of the Bihar Electricity Supply Code, 2007 provides for recovery of meter rent from its consumers. The relevant extract of the said provision is provide below:-
“The licensee shall supply the meter and metering equipment, cut-out/ MCB/ CB/ load limiter to consumers at the time of serving new service connection or at any other time as required. The licensee shall keep the meter in proper working condition and the consumer shall pay the monthly rent, if any, for the meter and metering equipment at the rate approved by the Commission.” [Emphasis Supplied]
8.2.1.4. It is to be noted that the Petitioner’s investment for purchasing meters is a cost incurred to provide electricity to its consumers and it should be recovered in a timely manner. However, the BERC (Multi Year Distribution Tariff) Regulation, 2015 considers the meter
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rent collection as a source of other income for the Discom. The relevant extract of the BERC (Multi Year Distribution Tariff) Regulations, 2015 is provided below:
“30. Non-Tariff Income a) All incomes being incidental to electricity business and derived by the Licensee from sources, including but not limited to profit derived from disposal of assets, rents, delayed payment surcharge, meter rent (if any), income from investments other than contingency reserves, miscellaneous receipts from the consumers, other miscellaneous receipts, income to Licensed business from the Other Business of the Distribution Licensee and any other income mentioned in Schedule-5 of The Electricity (Supply)Annual Accounts Rule 1985 shall constitute Non-Tariff Income of the Licensee.” [Emphasis Supplied]
8.2.1.5. This is to bring to the notice of the Hon’ble Commission that the Petitioner is unable to recover the meter cost from its consumers within a certain timeframe with the existing monthly meter rent fixed by the Hon’ble Commission. The Petitioner also raised this issue during the proceedings of the Tariff Order for FY 2017-18. In the said Tariff Order the Hon’ble Commission acknowledged the issue and mentioned to take up the matter in the subsequent year. The relevant portion of the Tariff Order for FY 2017-18 is extracted below:
“The proposal of the DISCOMs to increase the Miscellaneous charges such as Meter Rent, Fees for New Connection/reduction of load/enhancement of load/disconnection, testing/inspection of installations, meter testing fees, removing/fixing of meters, reconnection/disconnection charge, supervision & labour and installation charge have not been approved keeping in view the hike in tariff rates. However, it will be reviewed next tariff year.”
8.2.1.6. The section below provides a snapshot of the current meter rent and charges as specified by the Hon’ble Commission in its previous Tariff Order for FY 2017-18.
8.2.2. Existing Meter Rent
8.2.2.1. Those consumers who opt for meters provided by the Petitioner are entitled to pay the applicable monthly meter rent for their category to the Petitioner. Meter testing charges are also levied on those consumers who want to test their meters. The meter rent charges as well as the meter testing charges which have been approved by the Hon’ble Commission in the Tariff Order for FY 2017-18 in the provided below:
Table 120: Existing Monthly Meter Rent
Particulars Existing Meter Rent Charges (INR/ Month) KJ 10 Single Phase LT Except KJ 20 Three Phase LT up to 100 Amps 50 LT meter with CT 500
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Particulars Existing Meter Rent Charges (INR/ Month) 11 kV HTS-I Meter at low Voltage 500 Metering at 11kV 700 33 kV HT metering equipment for HTS-II and HTSS 3,000 132 kV EHT metering equipment for HTS-III 15,000 25 kV RTS 3,000 132 kV RTS 15,000 Smart/ Prepaid Programmable Meters (GPRS based): 0 Single phase Smart/ Prepaid Programmable Meters (GPRS based): 0 Three phase Prepaid Meters: Single phase 0 Prepaid Meters: Three phase 0
8.2.3. Meter Cost
8.2.3.1. The following table depicts the rate at which the meters of various categories are being procured by the Petitioner. The type of meters has been provided against various consumer categories approved in the Tariff Order.
Table 121: Procurement cost of Meters
Particulars Meter Type Current Meter Cost (INR) KJ Single phase electronic meter 628 Single Phase LT Except KJ Single phase electronic meter 628 Three Phase LT up to 100 Amps Three phase electronic meter 2,751 LT meter with CT Three phase four wire electronic meter 14,335 11 kV HTS-I Meter at low Voltage Three phase four wire electronic meter 116,500 Metering at 11kV Three phase four wire electronic meter 116,500 33 kV HT metering equipment for HTS-II Three Phase electronic meter 116,500 and HTSS 132 kV EHT metering equipment for HTS- Three Phase electronic meter 228,000 III 25 kV RTS Three Phase electronic meter 250,000 132 kV RTS Three Phase electronic meter 250,000 Smart/Prepaid Programmable Meters Single phase prepaid meter 5,103 (GPRS based): Single phase Smart/Prepaid Programmable Meters Three phase prepaid meter 7,085 (GPRS based): Three phase Prepaid Meters: Single phase Single phase prepaid meter 4,500 Prepaid Meters: Three phase Three phase prepaid meter 6,500 * For RF based smart meters, it is to be noted that for every 50 meters (Approx.), 1 DCU unit has to be installed which costs around Rs. 75,000-150,000, depending upon stability of the system. Note: The Petitioner has also attached the copy of its Purchase Order for meters of each category for reference.
North Bihar Power Distribution Company Limited 141 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
8.2.4. Meter Cost Realization
8.2.4.1. Though the intent of monthly meter rents were to ease the burden of the meter costs on to the consumers rather than the revenue enhancement considerations of the Discoms, it is imperative to recover the Meter cost it in a timely manner to avoid any bad debt accumulation. 8.2.4.2. Tabled below is the meter cost realization time of each category of consumers, considering present meter rental structure. It is evident that for certain category of consumer the cost realization time is much more than 5 years, such as 11 kV HTS meters.
Table 122: Cost Recovery time of meters (in Years)
Particulars Meter Type Current Expense Recovery Meter Cost recovered Time at (INR) per year existing rate (INR) (Yrs.) KJY Single phase electronic meter 628 120 5.23 Single Phase LT Except KJ Single phase electronic meter 628 240 2.62 Three Phase LT up to 100 Three phase electronic meter 2,751 600 4.59 Amps LT meter with CT Three phase four wire 19,075 6,000 3.18 electronic meter 11 kV HTS-I Meter at low Voltage Three phase four wire 121,240 6,000 20.21 electronic meter Metering at 11kV Three phase four wire 121,240 8,400 14.43 electronic meter 33 kV HT metering Three Phase electronic meter 121,240 36,000 3.37 equipment for HTS-II and HTSS 132 kV EHT metering Three Phase electronic meter 232,740 180,000 1.29 equipment for HTS-III 25 kV RTS Three Phase electronic meter 254,740 36,000 7.08 132 kV RTS Three Phase electronic meter 254,740 180,000 1.42 Smart/Prepaid Single phase prepaid meter 5,103 0 N.A. Programmable Meters (GPRS based): Single phase Smart/Prepaid Three phase prepaid meter 7,085 0 N.A. Programmable Meters (GPRS based): Three phase Prepaid Meters: Single Single phase prepaid meter 4,500 0 N.A. phase Prepaid Meters: Three Three phase prepaid meter 6,500 0 N.A. phase
8.2.5. Requirement for revising existing Meter Rent
8.2.5.1. Expiry of warranty Period: By the time the meter cost is recovered, the meters are way past their warranty period. If a meter gets defective before the warranty period, it is either
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to be replaced by the meter supplier or to be fixed by the Petitioner which is an addition to the cost of meter. Therefore a rationalized Meter rent structure is to be adopted which compensates up to certain extent the burden on the Petitioner. 8.2.5.2. Obsolesce of Technology: There is constant technological advancement in the present market dynamic of the Metering and Billing technologies used by the Petitioner, demanding its system upgradation to match with the advancements. For instance the electromechanical meters became obsolete and were replaced by the electronic meters. Thus, it is imperative on the part of the Petitioner to recover the cost of the investment in meters, before the technology becomes obsolete. 8.2.5.3. Opportunity Cost: An investment for purchase of meter funded by a banking agency costs certain rate of interest to the Petitioner. The prolonged recovery period of the meter cost, only hinders the future investment in new technological prospects by increasing the lock in period. This also affects the working capital of the Petitioner.
8.2.6. State wise Comparison of Meter rent and Understanding
8.2.6.1. Meter rent has been a major area of concern for the Discoms, as huge investments are being done in same, there have been visible efforts put in by the various Discoms to come up with a methodology for calculating exact monthly Meter rent, but due to highly dynamic Distribution scenarios it is tedious activity to come at a monthly meter rental figure to be charged. 8.2.6.2. Therefore it is prudent to also compare the Meter rental charged across different utilities. Meter rentals across Odisha, Haryana, Uttar Pradesh as compared to existing Meter Rental in Bihar have been captured below: 8.2.6.3. Key Observations on Meter Rentals Comparison of Various States: KJ Consumers: The existing rent for Single Phase Meter (Electronic) in Bihar is comparable with that of Haryana whereas it is half of the Odisha rent. While KJ consumers in Bihar have to pay only Rs. 10/month as meter rent, it is pertinent to mention that large number of KJ connections have been released in Bihar since last one year, which highlights the bottleneck in realizing the monthly meter rents due to lower bill payments from the KJ consumers. At the present meter rate the cost of single phase meter is about 5 years. It is also observed that due to highly scattered presence of KJ consumers in village areas, large number of meters are found in damaged state. Single Phase LT except KJ: At the current monthly meter rent of Rs. 20 for Single Phase LT Consumers (Except KJ), the meter cost can be recovered in 2.6 years. It is comparable with that of Haryana but seems to be slightly lower than that of Odisha, if Single Phase Static Meter is to be installed.
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Three Phase LT up to 100 Amps: At the present purchase cost of this Energy Meter the recovery period comes out to be around 5 Years considering the Meter rental to be Rs. 50. In comparison to Haryana & Odisha’s Electromagnetic Meters the rent seems to be comparable, but from revenue realization perspective the 5 years payback is on a higher side. LT meter with CT: At the present monthly rental of Rs. 500 the Meter cost can be realized in about 3 years. Since only 0.03% of the existing consumer base are installed with this Energy Meter, combined with low meter failure rate, the current Meter rent is acceptable, even though the same leads to delayed realization of the complete Meter cost. As compared to Haryana, the present rental rate seems to be acceptable. 11 kV HTS-I Meter at low Voltage: Monthly rental of the 11 kV HTS meters is to be urgently looked into as the full cost of the Purchased Meter is realized only after 20 years, which renders it completely unviable. It is to be highlighted that the present rental in Haryana for H.T. Tri-vector meter is on the basis of “3% of actual cost of meter (s) & metering equipment and the installation”. Considering this fact monthly meter rental in Haryana comes out to be around Rs. 3,400, which is 7 (seven) times that of Bihar. Whereas in Odisha the same rental is around Rs. 1000 i.e. twice that of Bihar. It is hereby requested that the Petitioner be Allowed to recover the Meter Cost in no later than 5 Years for this category @ rent of Rs.1,900/ month 11 kV HTS-I Meter at 11kV: The present monthly rental of this meter is fixed at Rs. 700/Month in the state of Bihar, with a recovery period of 14 years, which renders the activity unviable from Discoms perspective. It is hereby requested that the Petitioner be allowed to recover the Meter Cost in no later than 5 Years in this category @ rent of Rs.1,900/ month 25 kV RTS Meters: As per present Monthly rental of Rs. 3,000 the cost of this meter will be recovered in 7 years. Considering the monthly meter rental in Haryana which is roughly 3% of the Meter Cost, the Petitioner could have recovered Rs. 7,500 per Month in order to reduce the delayed recovery of the Meter Cost It is hereby requested that the Petitioner be allowed to recover the Meter Cost in no later than 5 Years in this category @ rent of Rs.4,000/ month Smart/Prepaid Programmable Meters (GPRS based): With a vision to enhance the revenue and pre-ponement of revenue realization from government consumers, an inclusion of Single and Three phase Smart/Pre-Paid (GPRS based programmable) meters in the system have been considered. The Petitioner also envisions to install Three Phase Smart/Pre-Paid (GPRS based programmable) meters for their BTS consumers and all consumers in the 10-20 kW load category.
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These single phase and the three phase prepaid/smart meters would cost approximately Rs. 5000 & Rs. 7000 respectively, which the Petitioner aims at recovering the cost in no later than 5 years. It is hereby requested that the Petitioner be allowed to recover the Pre-Paid Meter Cost in not later than 5 Years in this category @ Rs. 90/month for Single Phase Pre-Paid & Rs. 120/month for Three Phase Pre-Paid. Pre-Paid Meters Single Phase & Three Phase: It is to be noted that the standalone Single phase & three phase Pre paid meters would also be introduced in the system and would cost slightly lesser than the Communicable Pre paid meters. Here also it is prudent to considering the rental in other states such as Uttar Pradesh. As per UPERC Cost Data Book Article 27, the Pre-Paid Meter cost has been spread over a period of 60 months. It is hereby requested that the Discom be Allowed to recover the Standalone Single Phase & Three Phase Pre-Paid Meter Cost in not later than 5 Years in this category of consumer @ Rs. 80/month for Single Phase & Rs. 110/month for Three Phase Meters.
Table 123: Comparison of meter rents across states in India
Odisha Haryana Bihar Monthly Monthly Monthly Meter Type of Meter Meter Rent Type of Meter Type of Meter Meter Rent Rent (INR) (INR) (INR) Single phase Single phase electro-magnetic 20 20 KJ 10 Meter Kwh meter Three phase Three phase Single Phase LT electro-magnetic 40 Whole Current 30 20 Except KJ Kwh meter Meter Three phase Three phase Three Phase LT electro-magnetic 1,000 C.T. Operated 150 50 up to 100 Amps tri-vector meter meter 3% of actual cost of meter (s) Tri-vector meter Three phase & metering for Railway 1,000 L.T. Tri-vector LTmeterwithCT 500 equipment and Traction meter the installation of the same 3% of actual cost of meter (s) 11 kV HTS-I- Single phase H.T. Tri-vector & metering 40 Meter at low 500 Static Kwh meter meter equipment and Voltage the installation of the same 3% of actual cost of meter (s) Three Phase E.H.T. & metering 11 kV HTS-I- 150 700 Static Kwh meter Trivector meter equipment and Metering at 11kV the installation of the same Three phase 33 kV HT Static Tri-vector 1,000 metering 3,000 meter equipment for
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HTS-II and HTSS
132 kV EHT Three phase metering Static Bi-vector 1,000 15,000 equipment for meter HTS-III LT Single phase AMR/AMI 50 25kVRTS 3,000 Compliant meter LT Three phase AMR/AMI 150 132kVRTS 15,000 compliant meter
8.2.7. Proposed Monthly Meter Rent
8.2.7.1. Considering various factors such as different State practices, opportunity cost lost due to delayed revenue collection, need for replacement of Meters before the expiry of their warranty, the Petitioner has worked out monthly meter rent for recovery of the cost of meter within a period of 5 years. The Petitioner therefore humbly requests the Hon’ble Commission to revise the Meter rent and other charges accordingly.
Table 124: Proposed Monthly Meter Rent
S. No. Particulars Current Proposed Rent Rent (INR/month) (INR/month) 1 KJ 10 10 2 Single Phase LT Except KJ 20 20 3 Three Phase LT up to 100 Amps 50 50 4 LT meter with CT 500 500 5 11 kV HTS-I Meter at low Voltage 500 1,900 Metering at 11kV 700 1,900 6 33 kV HT metering equipment for HTS-II and HTSS 3,000 3,000 7 132 kV EHT metering equipment for HTS-III 15,000 15,000 8 25 kV RTS 3,000 4,000 9 132 kV RTS 15,000 15,000 10 Smart/Prepaid Programmable Meters (GPRS 0 90 based): Single Phase 11 Smart/Prepaid Programmable Meters (GPRS 0 120 based): Three Phase 12 Prepaid Meters: Single Phase 0 80 13 Prepaid Meters: Three Phase 0 110
8.2.7.2. It may be noted that the meter cost be allowed to be recovered before the expiry of warranty period of the meter for the relevant category. Thus the Petitioner has proposed 5 years as a reasonable period for recovery of the cost of meter. A timely recovery of the investment will help the Discom to utilize the recovered amount for further investment in progressive technologies. Thus it is prayed before the Hon’ble Commission to approve the above
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proposed monthly meter rent specified for the respective consumer category for a timely recovery of the cost of meter.
8.3. SLC charges
8.3.1. Application fee for new connection/ reduction of load/ enhancement of load/ request for permanent disconnection/ request for tatkal connection: 8.3.1.1. The following application fees will be charged for requesting a new connection or Tatkal connection or a reduction of load or enhancement of load or permanent disconnection Table 125: Application fee
S. No. Category / class Rate (INR)
1 Kutir Jyoti 20.00 2 LT Single phase except Kutir Jyoti 75.00 3 LT Three phase 200.00 4 LT Industrial 300.00 5 HT Connection 750.00 6 For tatkal connection Two (2) times the normal rate
8.3.2. Testing / Inspection of consumer’s installation: 8.3.2.1. The following fees will be applicable for testing or inspection of customer’s installation: Table 126: Meter testing fee
S. No. Category / class Rate (INR)
1 Initial Test / Inspection Free of cost
2 Subsequent test and inspection necessitated by Rs. 100.00 for single phase connection fault in installation or by not complying with Rs. 200.00 for three phase LT connection terms and conditions of supply Rs. 800 for HT connection.
8.3.3. Meter Testing Fee:
8.3.3.1. The meter testing fee at the following rates will be charged from the consumers opting to provide their own meters
Table 127: Meter testing fee for own installation
S. No. Category / class Rate (INR)
1 Single Phase meter (L.T.) 100.00 2 Three Phase meter (L.T.) 200.00 3 Three Phase meter with CT 300.00 4 Tri-vector and special type meter 1,800.00 5 33 kV or 11 kV metering equipment 5,000.00 6 132 kV/220 kV metering equipment 8,000.00 Note: No meter testing fee shall be charged from the consumers if the meter has been provided by the licensee. If the meter is tested at third party testing laboratory at the request of the consumer then the fees charged by the testing laboratory will be payable by the consumer.
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8.3.3.2. Consumer requiring hard copy of the MRI/RMR report of their Energy meter have to pay an upfront charge of INR 1000 per report. The Petitioner would like to emphasize that these proposed charges are nominal as compared to INR 5000 plus GST@18% charged by CPRI.
8.3.4. Removing / Re-fixing / Changing of Meter / Meter Licensee at consumer’s request: 8.3.4.1. The following fees will be charged from the consumers opting to remove or re-fix or change their meter: Table 128: Removal/ refixing/ change of meter fee
S. No. Category / class Rate (INR)
1 Single Phase meter 200.00 2 Three Phase meter 400.00 Cost of material, as 3 Three Phase meter with CT 500.00 required, will be borne by 4 Trivector and special type meter 600.00 the consumer 5 High tension metering equipment 1,200.00
8.3.5. Reconnection/ Disconnection Charge: 8.3.5.1. The following reconnection/disconnection charges will be charged from consumers: Table 129: Reconnection charges
S. No. Category/class Rate (INR)
1 Single Phase supply, LT 100.00 2 Three Phase supply other than LT industrial 200.00 3 Three Phase LT industrial supply 900.00 4 HT supply 3,000.00
8.3.6. Supervision, Labour and Establishment charge for service connection: 8.3.6.1. The following supervision, labour and establishment fees will be charged from consumers for service connections: Table 130: Supervision, labour and establishment charges for service connection
S. No. Category/ Class Rate (INR)
1 Single Phase LT 400.00 2 Three Phase LT other than industrial 900.00 3 Three Phase industrial 1,500.00 4 HT As per approved estimate 5 For tatkal connection Two (2) times the normal rate
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8.4. Security Deposit
8.4.1. The consumer (except Kutir Jyoti rural and Kutir Jyoti urban) shall pay initial security deposit equivalent to the estimated energy charges including fixed / demand charges for a period of two months or as per the provisions of Bihar Electricity Supply Code notified by the Commission. 8.4.2. All Central Government and State Government departments are exempted from payment of security deposit. However all public sector undertakings and local bodies shall pay security deposit, as applicable. 8.4.3. The amount of security deposit obtained from the consumer is liable to be enhanced every year, in April-May of next year on the basis of consumption during previous years or as specified in clause 7.15 of Bihar Electricity Supply Code. In default of payment of additional security deposit, wherever payable after review, the service line may be disconnected on serving thirty days’ notice and connection thereafter can be restored only if the deposit is made in full along with the prescribed reconnection charges and surcharge @1.5% per month or part thereof on the amount of outstanding.
8.5. Interest on Security Deposit
8.5.1. Security deposit made by a consumer shall bear interest as specified in Bihar Electricity Supply Code, payable at Bank rate notified by RBI from time to time. The interest will be calculated for full calendar months only and fraction of a month in which the deposit is received or refunded, shall be ignored. The interest for the period ending 31st March shall be adjusted and allowed to the consumer in the energy bill for May issued in June and in subsequent month(s), if not adjusted completely against the bill for the month of May.
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9. Proposed Tariff Schedule for FY 2018-19
9.1. Simplification of tariff structures for electricity consumers in Bihar
9.1.1. Historically, the State of Bihar had a very elaborate tariff structure, with tariff categories and slabs defined for various segments of consumers. These had been developed over the years taking into account the socio-economic profile of the state, consumption patterns, etc. Multiple sub-categories and slabs in each tariff category make the tariff structure highly complex and difficult for the consumer to understand. A comparison with other states with a similar socio- economic and consumer profile shows that Bihar has one of the highest number of electricity tariff categories, sub-categories and slabs in the country, which in cumulatively added upto over 100 plus charging slabs. 9.1.2. In its tariff petition filing for last year viz. FY 2017-18, and with the subsequent approval of the Hon’ble Commission, the power Distribution companies of Bihar have been successful in reducing the number of tariff categories, sub-categories and energy slabs to create a comparatively simpler tariff schedule for the consumers of the State. i. Simplifying the tariff structure, ii. Bring in a progressive tariff structure that helps promote efficiency, and iii. Rationalization of tariffs for the ease of consumers in the State. 9.1.3. For this year as well, the power distribution companies of Bihar have kept the following objectives while proposing the tariff structure for FY 2018-19 Ensuring that an adequate balance is maintained between the interest of consumers and the distribution utility, Enabling consumers to efficiently and effectively plan their expenditure on electricity Ensuring that tariffs progressively reflect the prudent and efficient cost of supply to the consumers, and Incentivizing the consumer for efficient utilization of electricity. 9.1.4. The Discoms have followed the given below key guiding principles for proposing the tariff structure and tariffs which would be applicable for the financial year 2018-19, which is the same as used for the prevalent tariff structure. i. Merging or elimination of category / sub-category has been done based on relevance, whether the categorization is still valid in the current scenario; ii. Ensure that each major tariff category has a maximum of 3 energy slabs to maintain simplicity of structure; iii. Introduction of two part tariff for all metered consumer categories; iv. Unmetered tariff category to be phased out with the large metering drives that the Discoms are planning to undertake over the next twelve to eighteen months;
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v. Apart from a few categories such as Kutir Jyoti, DS-I and Agriculture, move to a Maximum Demand based billing for recovering of fixed charges from all other metered consumers. Demand for levying of fixed charge to be taken as maximum of actual demand or 85% of connected load. And in case the MD is recorded at more than 110% of Contracted Load more than thrice a year, the Contracted Load is proposed to be revised to the MD. For unmetered consumers however, fixed charges to be currently billed on connected load basis; vi. Preserving kVAh based billing for all consumer categories wherever feasible, starting with Street Lighting, and gradually include Non-Domestic category as well. This would be in addition to the already existing LTIS, PWW, HT Supply, HTSS and RTS categories which are on kVAh based billing; vii. Termination of Monthly Minimum Charges (MMC) for all consumer categories.
9.1.5. Overall Based on the above, the following tariff categories and structures have been proposed for FY 2018-19:
9.1.5.1. DOMESTIC: Kutir Jyoti The BPL consumers in the State are served through the Kutir Jyoti tariff category. At present, the consumption of Kutir Jyoti consumers is capped at 50 units per month, with the balance consumption being levied as per DS-I tariffs. Considering that there are still significant no. of unmetered consumers in this category, a differentiation in tariffs for metered and unmetered consumers has been retained. At present, two part tariff structure is applicable for metered Kutir Jyoti consumers, with fixed charges to be levied on a-per connection basis per month. The Discoms are proposing to retain two part tariff structure for metered Kutir Jyoti consumers, with fixed charges proposed to be levied on a-per KW connected load basis per month The revised tariff structure is proposed below.
Table 131: Proposed tariff structure for KJ category
S. Consumer Proposed tariff structure No. Category 1 Kutir Jyoti a K.J. (Unmetered) Only fixed charge (per month per connection) b K.J. (Metered) Two part tariff (fixed charge per month per connection plus energy charge per unit)
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9.1.5.2. DOMESTIC: Others The Domestic category, comprising of the existing DS-I and DS-II sub-categories, had been developed for APL consumers, consuming electricity for household purposes. On one hand wherein DS-I consumers are typically supplied from rural feeders, DS-II consumers are supplied power from urban feeders. Under the new structure, it is proposed to retain DS-I and DS-II in its existing structure. Further, considering that there are still significant no. of unmetered consumers in this category, this differentiation is proposed to be retained till the time all consumers are completely metered. Fixed charges is now proposed to retain through a Maximum-Demand based tariff structure for all DS consumers (excluding Kutir Jyoti and DS-I unmetered consumers) The energy slabs are retained in their current structure for both the sub-categories. The revised tariff structure is proposed below.
Table 132: Proposed tariff structure for DS category
S. No. Consumer Category Proposed tariff structure 1 DS – I a Unmetered Only fixed charges (per connection per month) b Metered First 50 units Two part tariff (Fixed charges on maximum demand per month) 51-100 units 101-200 units Above 200 units 2 DS – II a 1-100 units Two part tariff (Fixed charges on maximum demand per month) b 101-200 units 201-300 units Above 300 units
9.1.5.3. NON-DOMESTIC The non-domestic category is for consumers using electricity for commercial purposes in the State of Bihar. Sub-categories have been created on the basis of connected load and point of connected load. There are currently two sub-categories within NDS; NDS-I serving rural consumers with a connected load up to 2 KW and NDS-II serving rural and urban consumers applicable to loads above 2 KW and up to 70 KW, which has been created by the Hon’ble BERC in the tariff order for FY 2017-18, for consumers utilizing electricity for hoardings, banners etc.
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Ideally, there should be no provision of billing any consumer on unmetered basis; however an interim provision has been retained for billing all unmetered consumers, till the time the Discoms complete the metering of all such pending connections. Fixed charges is proposed to be recovered through a Maximum-Demand based tariff structure. The revised tariff structure is proposed below.
Table 133: Proposed tariff structure for NDS category
S. Consumer Category Proposed tariff structure No. 1 NDS-I Unmetered Only fixed charges (per connection per month) 2 NDS-I Rural Connected Load Based 1-100 units Two part tariff (Fixed charges on maximum demand per month) 101-200 units Above 200 units 3 NDS-II (Contract demand up Two part tariff (fixed charge per month per connection to 0.5 KW) plus energy charge per unit) 4 NDS-II (Contract demand Demand Based above 0.5 KW) Metered Two part tariff (Fixed charges on maximum demand per month) 1-100 units 101-200 units Above 200 units
9.1.5.4. IRRIGATION AND AGRICULTURE
Under the Irrigation and Agriculture category, there are two separate sub-categories for private and State owned tube-wells, with differentiated tariffs for providing benefit of lower tariffs to private consumers. For the State owned connections, ideally there should be no unmetered connection. However given the existing scenario, it is proposed to retain the unmetered class till the time all such connections are metered. For levying of fixed charges, tariff to be levied on the connected / sanctioned load in the absence of meters with the feature of capturing Maximum-Demand. For metered consumers, it is also proposed to retain two-part tariff structure The revised tariff structure is proposed below.
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Table 134: Proposed tariff structure for IAS category
S. No. Consumer Category Proposed tariff structure 1 Pvt. Tubewell IAS – I Unmetered Supply Only fixed charge (based on per HP per month) Metered Supply Two part tariff (Fixed charges on connected load) 2 State Tubewell IAS – II Unmetered Supply Only fixed charge (based on per HP per month) Metered Supply Two part tariff (Fixed charges on connected load)
9.1.5.5. LOW TENSION INDUSTRIAL LTIS category includes consumers for small industries bifurcated into single phase and three phase connection. LTIS-I is for consumers with contract demand up to 19 kW and LTIS-II is for three phase connection with a contracted load above 19 kW and up to 74kW. Further, demand based tariff is mandatory for three phase connection and optional for single phase connection. Further, since all meters have the feature of recording Maximum Demand, it is proposed to retain levy fixed charges on Maximum Demand only. Fixed charges are to be levied for all consumers in the category on per kW basis as per the existing tariff for FY 2017- 18 In line with other states, it is also proposed to retain kVAh based billing for this category. This will help introduce efficiency into the system. The revised tariff structure is proposed below.
Table 135: Proposed tariff structure for LTIS category
S. Consumer Proposed tariff structure No Category 1 LTIS-I Two part tariff (Fixed charges on maximum demand and energy charges on kVAh based billing) 2 LTIS-II Two part tariff (Fixed charges on maximum demand and energy charges on kVAh based billing)
9.1.5.6. PUBLIC WATER WORKS Used for public lift irrigation based connections, owned by the State Govt. At present, a two part tariff is in place with fixed charges being levied on per Horse Power basis. All energy charges are to be charged on a kVAh basis and fixed charges are proposed to be levied on an MD basis. The revised tariff structure is proposed below.
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Table 136: Proposed tariff structure for PWW category
S. No. Consumer Category Tariff Structure 1 Metered Two part tariff (Fixed charges on maximum demand basis And energy charges on kVAh basis)
9.1.5.7. STREET LIGHT SERVICES This category is formed for supply of electricity for street light system with separate sub- categories for metered and unmetered connections. Ideally, there should be no provision of billing any consumer on unmetered basis; however an interim provision has been retained for billing all unmetered consumers, till the time the Discoms complete the metering of all street lights. All energy charges are to be charged on a kVAh basis and fixed charges are proposed to be levied on an MD basis. The revised tariff structure is proposed below.
Table 137: Proposed tariff structure for SS category
S. Consumer Proposed tariff structure No. Category 1 SS Metered Two part tariff (Fixed charges on maximum demand) 2 SS Unmetered Two part tariff (Fixed charges on maximum demand on per 100W basis )
9.1.5.8. HIGH TENSION SUPPLY HTS-I and HTS-II are categories for supplying power to HT Industrial consumers at 11 kV and 33 kV voltage levels respectively.
HTIS –III is specifically for consumers with a minimum contract demand of 7.5 MVA and supply to be taken at 132kV voltage level. In FY 16-17, another category viz. HTIS -IV has been added for consumers taking a connection from the Discoms at the 220 kV voltage level, with a minimum contract demand of 10MVA. HT Special Supply: For specifically supplying power to arc furnaces, and in line with their consumption pattern, the tariff structure currently provides for a high fixed charge with low per unit energy charges. Therefore, no change is proposed in this category, and the following existing structure would continue.
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Table 138: Proposed tariff structure for HT category
S. Consumer Tariff Structure No. Category 1 HTS-I (11 kV) Two part tariff (Fixed charges on maximum demand and 2 HTS-II (33 kV) energy charges on kVAh billing) 3 HTS-III (132 kV) 4 HTS-IV (220 kV) 5 HTSS (11 kV/33 kV)
9.1.5.9. RAILWAYS This category is for supplying power to Railway Traction services wherein the connection is to be provided only at 132 kV level. There is also a provision of rebate/surcharge at 13 paise/kVAh for higher voltage/lower voltage than 132 kV shall be allowed. No change is proposed in this category and the following existing structure would continue.
Table 139: Proposed tariff structure for RTS category
S. Consumer Category Tariff Structure No. 1 RTS (132 kV) Two part tariff (Fixed charges on maximum demand and energy charges on kVAh billing)
9.1.6. The existing structure has been retained for the tariff schedule for FY 2018-19. However, it is pertinent to mention the following key points on the designing of tariff structure and rates. 9.1.6.1. Unmetered consumer category: The Petitioner is taking several measures for completion of metering of all consumers. Larger district wise programs are being undertaken for both metering of unmetered consumers, as well as replacement of defective meters. This is an ongoing drive and the Discoms expect to gradually narrow down the number of unmetered connections. This would only remain in some specific categories such as KJY, DS-I, IAS and Street Lighting (which is primarily due to technical issues). 9.1.6.2. No. of energy slabs: In its quest for simplifying the tariff structure, the Discoms have already removed several sub-categories. However for energy slabs, given the current standard practice followed across states, the Discoms would want to retain the current no. of energy slabs within each category / sub-category. Going forward, it is their endeavor to reduce the number of energy slabs within each sub-category as well. For this, they also plan to carry out a scientific study to substantiate the rationale behind setting various slab limits.
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9.1.6.3. Existence of special categories: In Bihar, a separate category exists as HTSS for specifically supplying power to arc furnaces, and in line with their consumption, their tariff structure provides for a high fixed charge with a low per unit energy charge. The Discom is planning to undertake a study for assessing the demand and consumption patterns of the consumers on a sample basis, based on which it will develop a roadmap for merging this category with relevant HTS category, starting FY 2019-20. For the ensuing year however, no revision is proposed. 9.1.6.4. Levying of fixed charges: The endeavor of the Discoms is to levy the fixed tariff on consumers based on their maximum demand in the long term, and on their contracted demand in the short term. However for some specific unmetered consumer categories and sub-categories, the fixed charge is proposed to be levied on each connection. The Discoms are taking steps to reconcile the connected load of such consumers especially in the KJY, DS-I and NDS-I categories, so as to avoid any excessive burden due to inaccurate load records or limited energy usage. 9.1.6.5. Demand Based tariffs: The Discoms are planning to gradually move to demand based tariffs for all consumers, and most meters being currently installed, have the feature of recording the maximum demand. 9.1.6.6. Implementation of flat tariff: In order to simplify the tariff structure further, and also encourage energy efficiency for consumers especially with higher specific consumption, the Discoms have been exploring the concept of implementing a flat tariff for each energy slab. However for the ensuing year, the existing structure has been retained wherein the benefit of lower tariffs would continue for consumption at lower energy slabs. 9.1.6.7. Classification of consumers under urban and rural sub-category for DS-I/DS-II and NDS-I/NDS-II: The extension of the electrical network of the Discoms has been done for many areas, and in several cases, electrical feeders initially emerging from urban areas, have now been extended to rural areas as well, based on financial viability. Therefore in order to avoid any ambiguity pertaining to a classification of a consumer as Urban / Rural, the categorization in the applicable sub-category within Domestic and Non-Domestic categories, would be done only based on the latest / prevalent notification issued by the relevant authority, denoting an area to be falling under Urban / Rural areas. No other methodology would be followed. 9.1.6.8. Recovery fixed charges: The total gross ARR for FY 2018-19 for the two Discoms has been estimated at INR 17,152 crores, with a split of 57% as fixed costs and 43% as variable costs. The fixed costs include the establishment and network costs, as well as the fixed costs payable to the Generators, irrespective whether power is drawn from them. The variable costs is the energy cost paid to Generators for supply of energy. On one hand wherein the cost structure of the two Discoms is heavily tilted towards fixed charges, the
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recovery of revenue through the existing tariff approved by the Hon’ble Commission is tilted more towards energy tariffs (for FY 2018-19 at existing tariffs, the revenue from fixed charges is only 17% and the balance 83% is from energy charges). Due to this skewed nature of tariff recovery, the Discoms have limited revenue assurance and therefore face uncertainty. For designing the tariff structure for FY 2018-19, a ratio of 27% revenues from fixed tariff and 73% revenue from energy tariff has been considered.
9.1.6.9. General and miscellaneous charges: The Discoms have also proposed a revision in meter rent charges for meter cost realization within the warranty expiration time of the meters.
9.1.6.10. Therefore accordingly, the Discoms propose the following tariff schedule to be adopted for the FY 2018-19, w.e.f. 01.04.2018 for 100% cost recovery, without taking the impact of any subsidy to be provided by the Government of Bihar for tariff relief.
Table 140: Tariff schedule considering ‘Zero’ GoB Subsidy
S. Consumer Category Fixed Unit Energy Unit ABR Cost No. charge Charge Coverage (%) 1 DOMESTIC (DS) 1.1 Kutir Jyoti Unmetered 350 INR/ conn./ month 0 3.76 51% Metered (0-50) 50 INR/ conn./ month 5.15 INR/kWh 6.47 87% 1.2 DS-I Unmetered 500 INR/ conn./ month 0 6.38 86% Metered First 50 Units per month 100 INR /kW / month 5.15 INR/kWh 7.40 99% 51 - 100 Units per month 100 INR /kW / month 6.5 INR/kWh 7.22 97% Above 100 Units per 100 INR /kW / month 7.5 INR/kWh 7.37 99% month 1.3 DS-II 1-100 Units per month 200 INR /kW / month 4.6 INR/kWh 8.48 114% 101 - 200 Units per 200 INR /kW / month 6.9 INR/kWh 7.54 101% month 201 -300 Units per 200 INR /kW / month 8.4 INR/kWh 7.98 107% month Above 300 Units per 200 INR /kW / month 8.9 INR/kWh 8.22 110% month 2 NON-DOMESTIC (NDS) 2.1 NDS-I Unmetered 550 INR/ conn./ month 0 8.77 118% Metered 1-100 U/Month 175 INR /kW / month 4.0 INR/kWh 7.68 103% 101 - 200 U/Month 175 INR /kW / month 7.0 INR/kWh 6.03 81% Above 200 U/Month 175 INR /kW / month 7.5 INR/kWh 6.11 82% 2.2 NDS-II
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S. Consumer Category Fixed Unit Energy Unit ABR Cost No. charge Charge Coverage (%) Contract Demand < 0.5 200 INR/ conn./ month 6 7.77 104% kW Contract Demand > 0.5 kW 1-100 U/Month 300 INR /kW / month 5 INR/kWh 8.64 116% 101 - 200 U/Month 300 INR /kW / month 5.8 INR/kWh 8.93 120% Above 200 U/Month 300 INR /kW / month 6.4 INR/kWh 8.81 119% 3 IRRIGATION & AGRICULTURE (IAS) 3.1 Pvt. Tubewell: IAS-I Unmetered 420 INR /HP / month 0 6.17 83% Metered 100 INR /HP / month 2.5 INR/kWh 6.62 89% 3.2 State Tubewell: IAS-II Unmetered 1700 INR /HP / month 0 8.44 114% Metered 550 INR /HP / month 5.5 INR/kWh 8.86 119% 4 LT INDUSTRIAL (LTIS) LTIS-I 220 INR /kW / month 5.8 INR/kVAh 7.99 108% LTIS-II 220 INR /kW / month 5.9 INR/kVAh 8.93 120% 5 PUBLIC WATER WORKS PWW 500 INR /kW / month 6 INR/kVAh 8.58 115% 6 STREET LIGHT SERVICCES SS-I 1000 INR /kW / month 5.5 INR/kVAh 8.57 115% SS-II 3600 INR /kW / month 0 INR/kVAh 8.68 117% 7 HT SUPPLY 7.1 HTS-I 500 INR / kVA / month 5 INR/kVAh 8.50 114% 7.2 HTS-II 500 INR / kVA / month 5.2 INR/kVAh 8.57 115% 7.3 HTS-III 500 INR / kVA / month 5.3 INR/kVAh 8.49 114% 7.4 HTS-IV 500 INR / kVA / month 5.3 INR/kVAh 0.00 0% 7.5 HTSS 800 INR / kVA / month 5.2 INR/kVAh 6.97 94% 8 RAILWAYS RTS 500 INR / kVA / month 5.80 INR/kVAh 8.48 114%
9.1.7. The Government of Bihar in FY 2017-18 had provided revenue subsidy for giving relief to consumers in their tariffs. Considering that this support would be continued for the ensuing FY 2018-19 as well, viz. considering the same per unit subsidy, the following tariff schedule is proposed for FY 2018-19.
Table 141: Net tariff to consumer considering same per unit GoB subsidy as provided for FY 2017-18
S. Consumer Category Fixed Unit Energy Unit No. charge Charge 1 DOMESTIC (DS) 1.1 Kutir Jyoti Unmetered 239 INR/ conn./ month 0 Metered (0-50) 50 INR/ conn./ month 1.57 INR/kWh 1.2 DS-I Unmetered 267.50 INR /kW / month 0 Metered
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S. Consumer Category Fixed Unit Energy Unit No. charge Charge First 50 Units per month 100 INR /kW / month 2.05 INR/kWh 51 - 100 Units per month 100 INR /kW / month 3.40 INR/kWh Above 100 Units per month 100 INR /kW / month 4.40 INR/kWh 1.3 DS-II 1-100 Units per month 200 INR /kW / month 3.12 INR/kWh 101 - 200 Units per month 200 INR /kW / month 5.42 INR/kWh 201 -300 Units per month 200 INR /kW / month 6.92 INR/kWh Above 300 Units per month 200 INR /kW / month 7.42 INR/kWh 2 NON-DOMESTIC (NDS) 2.1 NDS-I Unmetered 445 INR/ conn./ month 0 Metered 1-100 U/Month 175 INR /kW / month 1.50 INR/kWh 101 - 200 U/Month 175 INR /kW / month 4.50 INR/kWh Above 200 U/Month 175 INR /kW / month 5.00 INR/kWh 2.2 NDS-II Contract Demand < 0.5 kW 200 INR/ conn./ month 5.60 Contract Demand > 0.5 kW 1-100 U/Month 300 INR /kW / month 4.60 INR/kWh 101 - 200 U/Month 300 INR /kW / month 5.40 INR/kWh Above 200 U/Month 300 INR /kW / month 6.00 INR/kWh 3 IRRIGATION & AGRICULTURE (IAS) 3.1 Pvt. Tubewell: IAS-I Unmetered 168 INR /HP / month 0 Metered 100 INR /HP / month 0.96 INR/kWh 3.2 State Tubewell: IAS-II Unmetered 1700 INR /HP / month 0 Metered 550 INR /HP / month 5.5 INR/kWh 4 LT INDUSTRIAL (LTIS) LTIS-I 220 INR /kW / month 5.49 INR/kVAh LTIS-II 220 INR /kW / month 5.55 INR/kVAh 5 Public Water Works PWW 500 INR /kW / month 6 INR/kVAh 6 Street Light Services SS-I 1000 INR /kW / month 5.5 INR/kVAh SS-II 3600 INR /kW / month 0 INR/kVAh 7 HT SUPPLY 7.1 HTS-I 500 INR / kVA / month 4.75 INR/kVAh 7.2 HTS-II 500 INR / kVA / month 4.77 INR/kVAh 7.3 HTS-III 500 INR / kVA / month 4.81 INR/kVAh 7.4 HTS-IV 500 INR / kVA / month 5.30 INR/kVAh 7.5 HTSS 800 INR / kVA / month 4.83 INR/kVAh 8 RAILWAYS RTS 500 INR / kVA / month 5.80 INR/kVAh
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9.2. Tariff schedule for consumers under DDG scheme of DDUGJY 9.2.1. There are certain localities within the licensing area of the Petitioner where traditional way of electrifications is neither possible nor commercial viable. For such areas the Petitioner has chosen SOLAR Power based Stand Alone system under Decentralized Distribution Generation (DDG) Scheme of DDUGJY recommended by M/s Rural Electrification Corporation Limited, New Delhi (REC) as per their guidelines.
9.2.2. The Petitioner has chosen M/s Larsen & Toubro Ltd, Chennai through open competitive bidding vide NIT No. 04/PR/NBPDCL/2017 Dated 11/01/2017 to electrify, operate, maintain and collect revenue in 5 revenue districts of North Bihar i.e West champaran, Supaul, Katihar, Madhubani & Gopalgunj. A formal contract agreement has been signed between the Petitioner & L&T on 19th August 2017 vide no. 31/2017-18-CE(P-II) and 32/2017-18-CE(P-II).
9.2.3. As per the contract agreement; M/s Larsen & Toubro Ltd (the agency) has the following responsibilities: 1) Survey & identify the locality targeted to be electrified under DDG Scheme of DDUGJY. 2) Detail Engineering, planning & designing of Solar Power Plant and its associated network lines to electrify villages and extend power supply to BPL & APL Consumers in these list of villages, 3) Procurement of all the material required for the project area. 4) Commissioning of Solar Power plant as per the approved design & Specification approved by NBPDCL 5) Laying LT Network and other infrastructure for extending power supply to BPL & APL consumers identified in this scheme 6) Providing connection to BPL & APL Households without meters as per the Technical specification with 3 LED Light points and 2 Power sockets. 7) Operation & Maintenance of the system for next 5 years from actual date of commissioning.
9.2.4. As per the aforesaid Contract Agreement the agency needs to provide electricity supply to rural households at least 75 days in a quarter as per the schedule defined in the contract agreement as follows; In summer period (March to October): Morning: 5 AM to 10 AM (1 to 3 hours) Evening: 6 PM to 11 PM (5 hours) In Winter Period (November to February): Morning: 5 AM to 10 AM (1 to 3 hours) Evening: 5 PM to 10 PM (5 hours)
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9.2.5. Simultaneously as per the contract agreement, the implementing agency need to collect fixed revenue from rural households as per the tariff plan finalized in the contract agreement as tabulated below; Table 142: Revenue collection under DDG scheme
Habitation / Non- Category Revenue (INR/ month) habitation
House Holds BPL Rs 30 Per Month
APL Rs 60 Per Month
Non Households Street Light Per Point of 20 Rs 20 Per Month Watts
Community Building of 100 Rs 55 Per Month Watts
Atta Chakki (5 HP) Rs 1500 per Month
Water Pumping per HP Rs 267 per HP/ Month
9.2.6. The Agency has already started rollout of DDG scheme and requested to provide authorization letter from the Petitioner towards collecting revenue as per the above fixed tariff. Hence these sets of consumers may be added in the consumer base of the Petitioner under Decentralized Distributed Generation (DDG) category.
9.3. Terms and Conditions of Low Tension Tariff
The foregoing tariffs are subject to the following conditions: 9.3.1. Rebate for prompt payment
The due date for making payment of energy bills or other charges shall be 15 days from the date of issue of the bill. To motivate the consumers to make timely payment of the bills it is proposed to provide a rebate of 1.5% on the billed amount for timely payment of the bills for all the consumers served in LT category.
In case a consumer makes full payment after due date but within 10 days after the due date, no DPS shall be levied for this period but rebate for prompt payment will not be admissible.
9.3.2. Rebate for online payment
The due date for making payment of energy bills or other charges shall be 15 days from the date of issue of the bill. To motivate the consumers to make timely payment of the bills it is
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proposed to provide a rebate of 1.5% on the billed amount for timely payment of the bills for all the consumers served in LT category. Payment made through all electronic modes of payment made directly in the Discom account will be considered as online payment. However, online payment rebate shall be applicable if the consumer makes the payment within due date in full.
In case a consumer makes full payment after due date but within 10 days after the due date, no DPS shall be levied for this period but rebate for prompt payment will not be admissible.
9.3.3. Accounting of Partial Payment
All payment made by consumers in full or part shall be adjusted in the following order of priority: a. Statutory taxes and duties on current consumption b. Arrear of Statutory taxes and duties c. Delayed payment surcharge d. Balance of arrears e. Balance of current bill
9.3.4. Delayed Payment Surcharge (DPS)
In case a consumer does not pay energy bills in full within 10 days grace period after due date specified in the bill, a delayed payment surcharge of one and half (1.5) percent per month or part thereof on the outstanding principal amount of bill will be levied from the due date for payment until the payment is made in full without prejudice to right of the licensee to disconnect the supply in accordance with Section 56 of the Electricity Act, 2003. The licensee shall clearly indicate in the bill itself the total amount, including DPS, payable for different dates after the due date after allowing for the grace period of 10 days. No DPS shall be charged on DPS arrear. The bill shall indicate the energy charges for the month, arrears of energy charges and DPS separately.
9.3.5. Duties and Taxes
Other statutory levies like electricity duty or any other taxes, duties etc., imposed by the State Government / Central Government or any other competent authority, shall be extra and shall not be part of the tariff as determined under this order.
9.3.6. Defective / Damaged / Burnt Meters Supply
In case of meter being defective / damaged / burnt the licensee or the consumer as the case may be, shall replace it within the specified period prescribed in “Standards of Performance for Distribution Licensee”, Regulations issued by the Commission.
Till defective / damaged / burnt meter is replaced, the consumption will be assessed and billed on an average consumption of last 12 months from the date of meter being
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out of order. Such consumption shall be treated as actual consumption for all practical purposes including calculation of electricity duty until the meter is replaced/ rectified. In cases of newly installed meter of a consumer becoming defective/ damaged/ burnt after installation of the meter prior to completion of 12 months since its installation, the billing for the period for such defective/ damaged/ burnt meter, till it is not replaced, shall be done on the basis of average monthly consumption of the consumer or the MMC whichever is higher. In case of the meter of a consumer becoming defective in the first month of installation itself, without taking any reading the consumer shall be provisionally billed on the basis of amount of security collected for one month. However, the provisional bill will be done for one month only and that will be finalized and adjusted on the basis of consumption of the second month.
9.3.7. Shunt Capacitor Installation Every LT consumer including irrigation pump set consumers whose connected load includes induction motor (s) of capacity 3 HP and above and other low power factor consuming appliances shall arrange to install low tension shunt capacitors of appropriate capacity of standard make which meet the Bureau of Indian Standard Specification at his cost across terminals of his motor (s). The consumer shall ensure that the capacitors installed by him are properly matched with the actual rating of the motor so as to ensure power factor of 90%. All LT consumers having welding transformers will be required to install suitable shunt capacitor(s) of adequate capacity so as to ensure power factor of not less than 90%. No new supply to LT installations having low power factor consuming equipment such as induction motor of 3 HP and above or welding transformers etc., will be released unless shunt capacitors are installed to the satisfaction of the licensee. The ratings of shunt capacitor to be installed on the motors of different ratings are provided in the “Electric Supply Code” notified by the Commission. Any LT consumer except Domestic category of consumer in whose case, the meter installed has power factor recording feature and who fails to maintain power factor of 90% in any month shall pay a surcharge of 1% for every fall of 1% below 90% subject to a maximum of 5% in addition to its normal tariff total current bill amount except DPS.
9.3.8. Charges to Tatkal Connections (Optional)
If any consumer (other than High Tension and Railway) opts for availing connection under Tatkal scheme, the licensee shall release the Tatkal connection to such consumer with the following conditions:
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The Tatkal connections shall be released by licensee in half the time limit prescribed in the Supply code for that consumer category. Two (2) times of the following charges approved under head miscellaneous and general charges will be taken from the consumers willing to avail Tatkal connection. Application fees for new connection, and; Supervision, labor and establishment charge for service connection In case licensee fails to release connection within this time limit, licensee will refund the additional amount claimed to the consumer in the first energy bill.
9.3.9. Contract Demand for billing under Domestic Tariff: For computation of the connected load of a domestic consumer either load of coolers/ fans or room heaters whichever is higher shall be considered. For the premises having Air conditioner (without heater) and that of geysers, the computation of connected load shall be as per the provision of Bihar Electricity Supply Code, 2007. The contract demand of those consumers for the monthly billing purpose in the premises who have opted for demand based tariff, the recorded demand or the contract demand, whichever is higher, shall be considered. Subject to the minimum load of 1 kW, the fraction of the load below 500 W shall be rounded to its nearest lower level of whole number and 500 W and above shall be rounded to its nearest higher level of whole number, as specified in the Bihar Electricity Supply Code, 2007. In case of demand based tariff, verification of connected load is not required.
9.3.10. Existing provision of demand based tariff being optional for three phase LT consumer should be made compulsory.
Tri-vector meters are installed in all the three phase consumers, Petitioner proposes to cover all three phase consumers under demand based tariff.
All the other terms and conditions for the LT supply as has been decided by the Hon’ble Commission in its tariff order dated 16.03.2015 shall remain applicable for the FY 2016-17 also.
9.4. Terms and Conditions of High Tension Tariff The foregoing tariffs are subject to the following conditions: 9.4.1. Rebate for prompt payment The due date for making payment of energy bills or other charges shall be 15 days from the date of issue of the bill. To motivate the consumers to make timely payment of the bills it is proposed to provide a rebate of 1.5% on the billed amount for timely payment of the bills for all the consumers served in HT category.
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In case a consumer makes full payment after due date but within 10 days after the due date, no DPS shall be levied for this period but rebate for prompt payment will not be admissible.
9.4.2. Rebate for online payment To motivate the consumers to make online payment of the bills through online web portal of the Petitioner it is proposed to provide a rebate of 1% of the billed amount in addition to rebate @ 1.5%. Payment made through all electronic modes of payment made directly in the Discom account will be considered as online payment. However, online payment rebate shall be applicable if the consumer makes the payment within due date in full.
9.4.3. Accounting of Partial Payment All payment made by consumers in full or part shall be adjusted in the following order of priority: a. Statutory taxes and duties on current consumption b. Arrear of Statutory taxes and duties c. Delayed payment surcharge d. Balance of arrears e. Balance of current bill
9.4.4. Delayed Payment Surcharge (DPS) In case of consumer does not pay energy bills in full within 10 days grace period after due date specified in the bill, a delayed payment surcharge of one and half (1.5) % per month or part thereof on the outstanding principal amount of bill will be levied form the original due date for payment until the payment is made in full without prejudice to right of the licensee to disconnect the supply in accordance with Section 56 of the Electricity Act, 2003. The licensee shall clearly indicate in the bill itself the total amount, including DPS, payable for different dates after the due date after allowing for the grace period of 10 days. No DPS shall be charged on DPS arrear.
9.4.5. Duties and Taxes Other statutory levies like electricity duty or any other taxes, duties etc., imposed by the State Government / Central Government or any other competent authority, shall be extra and shall not be part of the tariff as determined under this order.
9.4.6. Defective / Damaged / Burnt Meters Supply In case of meter being defective / damaged / burnt the licensee or the consumer as the case may be, shall replace it within the specified period prescribed in “Standards of Performance for Distribution Licensee”, Regulations issued by the Commission.
Till defective / damaged / burnt meter is replaced, the consumption will be assessed and billed on an average consumption of last 12 months from the date of meter being
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out of order. Such consumption shall be treated as actual consumption for all practical purposes including calculation of electricity duty until the meter is replaced/ rectified. In cases of newly installed meter of a consumer becoming defective/ damaged/ burnt after installation of the meter prior to completion of 12 months since its installation, the billing for the period for such defective/ damaged/ burnt meter, till it is not replaced, shall be done on the basis of average monthly consumption of the consumer or the MMC whichever is higher. In case of the meter of a consumer becoming defective in the first month of installation itself, without taking any reading the consumer shall be provisionally billed on the basis of amount of security collected for one month. However, the provisional bill will be done for one month only and that will be finalized and adjusted on the basis of consumption of the second month.
9.4.7. Exceeding Contract Demand If the actual recorded demand of a consumer exceeds 110% consecutively for three months Licensee may issue a notice and inform the consumer to get additional contract demand sanctioned or to limit their drawal as per their contract. Otherwise Licensee will take action as per provisions of the Act/Rules/Regulations. In case the consumer do not respond to the notice within 30 days of issue of notice, to get additional demand sanctioned or limit their drawal as per the contract, the Distribution Licensee may revise and enhance the contracted demand of the consumer to the extent of highest demand in the past three months of the violation.
9.4.8. Contract Demand for Induction Furnaces The prevailing practice will continue for determining the contract demand of induction furnaces in the existing services connections. However, for new connections and where the furnaces are replaced in existing connections, contract demand shall be based on the total capacity of the furnace and equipment as per manufacturer technical specifications and in case of difference of opinion, the provisions of clause No.6.39 and 6.40 of Bihar Electricity Supply Code shall apply.
9.4.9. Shift to KVAH based Tariff Understanding that the KVAH based tariff has an inbuilt mechanism for incentivizing the consumers who maintain better power factor, the Petitioner proposes the Commission to introduce KVAH based tariff in the state for HT consumers. This is bound to encourage HT consumers to save on their electricity bills. All the other terms and conditions for the HT supply as has been decided by the Hon’ble Commission in its tariff order dated 16.03.2015 shall remain applicable for the FY 2016-17 also.
North Bihar Power Distribution Company Limited 167 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
9.4.10. Temporary Supply (LT and HT) Applicability: This tariff is for connection of temporary in nature for period of less than one year. The applicability shall be as given in the respective category tariff rate schedule. Temporary supply cannot be claimed by a prospective consumer as a matter of right but will normally be arranged by the Licensee when a requisition is made giving due notice subject to technical feasibility and in accordance with electricity supply code issued by the Commission. Tariff: Fixed charge and energy charge shall be chargeable at one and half times the normal tariff as applicable to the corresponding appropriate tariff category.
9.4.11. Terms of Supply Temporary supply under any category of service may be given for a period not exceeding 30 days in the first instance, the duration of which, however may be extended on month-to- month basis subject to maximum of one year. In addition to the charges mentioned above, the consumer shall have to deposit the following charges before commencement of the temporary supply: o Estimated cost of erection of temporary service line and dismantling. o Cost of irretrievable materials which cannot be taken back to service. o Meter rent for the full period of temporary connection as per appropriate Tariff Schedule and miscellaneous charges. o Rental on the cost of materials as per estimate framed but not payable by the consumer shall be payable at the rate of Rs. 15/- per month on every Rs. 100/- or part thereof. o Ten per cent on the total cost of the estimate for the temporary service connection to cover as security for loss of materials and contingencies. In case such loss is not noticed, the amount will be refunded. The applicants for temporary supply shall be required to make a deposit in advance of the cost as detailed above including the energy consumption charges estimated for full period on the basis of connected load. This will however, be adjusted against the final bill that will be rendered on disconnection of supply month to month basis. If the consumer intends to extend the temporary supply beyond the period originally applied for, he will have to deposit in advance all charges as detailed above including the estimated electricity consumption charges, for the period to be extended and final bill for the previous period, as well. The temporary supply shall continue as such and be governed by the terms and conditions specified above until the supply is terminated or converted into permanent supply at the written request of the consumer. The supply will be governed by the terms and conditions of permanent supply only after the consumer has duly completed all the formalities like execution of
North Bihar Power Distribution Company Limited 168 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
agreement, deposit of security money, cost of service connection and full settlement of the account in respect of the temporary supply etc.
9.4.12. Security deposit The initial security deposit shall be calculated on the basis at a load factor of 30% and power factor of 90% on contract demand payable at prevailing unit rate for HTS-I category. For HTS-II category it shall be calculated on the basis at a load factor of 35% and power factor of 90% on contract demand payable at prevailing unit rate. For HTS-III and HTS-IV category it shall be calculated on the basis at a load factor of 50% and power factor of 90% on contract demand payable at prevailing unit rate. For HTSS consumer the formula for calculation of initial security deposit as below: (Contract demand * 289 * energy charge per unit)*2 + (Contract demand * Demand Charge per kVA)*2
9.4.13. Seasonal Supply (LT and HT) The Petitioner proposes to provide seasonal supply to any consumer on written request to the Licensee subject to the following conditions. Table 143: Proposed tariff rate for seasonal supply
Period of Supply Tariff Rate Upto 3 consecutive months in a year Appropriate tariff plus 30 percent More than 3 consecutive months and upto 6 consecutive Appropriate tariff plus 20 percent months in a year More than 6 consecutive months and upto 9 consecutive Appropriate tariff plus 15 percent months in a year More than 9 consecutive months but less than one year Appropriate tariff plus 5 percent.
The meter rent and other charges as provided in the appropriate tariff are applicable to seasonal loads and would be charged extra for the entire period of supply. The supply would be disconnected after the end of the period unless the consumer wants the supply to be continued. Any reconnection charges have to be borne by the consumer. Consumer proposing to avail seasonal supply shall sign an agreement with the Licensee to avail power supply for a minimum period of 3 years in the case of HT, and 2 years in the case of LT category of supply. The consumers must avail supply in terms of whole calendar month continuously. The consumer is required to apply for seasonal supply and pay initial cost and security deposit as an applicant for normal electricity supply. The consumer shall ensure payment of monthly energy bills within 7 days of its receipt. The supply will be disconnected if payment is not made on due date.
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Incremental charges will not be applicable for fixed charge component of the electricity bill in case of seasonal supply.
9.4.14. Additional terms and conditions of HT tariff The billing demand shall be the maximum demand recorded during the month or 85% of the contract demand whichever is higher for HTS –I, HTS-II, HTS-III, RTS and HTS-IV. The billing demand shall be the maximum demand recorded during the month or the contract demand whichever is higher for HTSS category. In HTSS tariff if the power is availed at 11 KV a surcharge of 5% will be charged extra on demand and energy charges.
If in any month the recorded maximum demand of the consumer exceeds 110% of contract demand that portion of the demand in excess of the contract demand will be billed at twice the normal charges for HTS –I, HTS-II, HTS-III, RTS and HTS-IV. Time of Day (TOD) tariff will remain same as per tariff order for FY2017-18. In case, the consumer exceeds 110% of the contract demand, the demand in excess of contract demand shall be billed at twice the normal tariff applicable for day time i.e. 5:00 a.m. to 5:00 p.m. irrespective of the time of use.
Applicability of different HT categories, its capping of contract demand and character of service will remain same as per tariff order for FY2017-18.
North Bihar Power Distribution Company Limited 170 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
10. Wheeling and Open Access Charges
10.1. Background
10.1.1. The Petitioner submits that for the purpose of open access on distribution network, determination of wheeling losses and wheeling charges are essential. Further as the consumer is deemed to be moving out of system, the revenue loss from such consumers is recovered through Cross Subsidy Surcharge and Additional Surcharge, as the case may be.
10.2. Transmission Charge 10.2.1. The transmission charges to be levied on open access consumer would be same as that approved by Hon’ble Commission for FY 2018-19 as transmission tariff.
10.3. Transmission Loss 10.3.1. The transmission losses to be levied to open access consumer would be same as that approved by Hon’ble Commission for FY 2018-19 as transmission loss.
10.4. Wheeling Charges
10.4.1. It is submitted that till date complete segregation of accounts between Wheeling and Retail Supply function has not yet taken place. Thus, ARR proposals for Wheeling and Retail Supply function is submitted on the basis of an allocation statement to be prepared by the Distribution Licensee based on their best judgment and in line with the approach followed by the Hon’ble Commission in its Tariff Order for FY 2017-18.
10.4.2. The Licensee, in the instant Petition, has followed the following allocation for calculating segregating its wire and supply business.
Table 144: Allocation Matrix
Particulars Wire Business Retail Supply Power purchase cost 0% 100% PGCIL & other transmission charges 0% 100% State Transmission charges & BGCL 0% 100% O&M Expenses Employee Cost 60% 40% R&M expenses 90% 10% A&G expenses 40% 60% Share of Holding Company expenses 0% 100% Depreciation 90% 10% Interest and Finance charges 90% 10% Interest on working capital 90% 10% Return on equity 90% 10% Interest on security deposit 90% 10% Deposit for RPO Obligation 0% 0%
North Bihar Power Distribution Company Limited 171 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
Particulars Wire Business Retail Supply Bad debts (if any) 0% 100% Contingency reserves (if any) 0% 100% Less: Non-tariff income 0% 100%
10.4.3. The total costs (net ARR) are segregated into wire business and retail supply business as per the above matrix.
Table 145: Segregation of Wires and Retail Supply Costs
Particulars Wire Business Retail Supply Total Power purchase cost 5,318.68 0.00 5,318.68 Employee expenses 692.16 415.30 276.87 Administration and General expenses 205.45 102.72 102.72 Repair and Maintenance expenses 249.09 224.18 24.91 Depreciation 491.34 442.20 49.13 Interest and Finance charges 1,322.82 1,190.54 132.28 Interest on working capital 211.53 21.15 190.38 Interest on consumer security deposits 64.76 6.48 58.28 Return on equity 764.70 688.23 76.47 Less: Non-tariff income 360.76 36.08 324.69 TOTAL 8,959.77 3,054.73 5,905.04
1.1.4. The wheeling charges have been computed on the basis of projected costs of the Petitioner for its distribution wire business and the total energy expected to be wheeled through their distribution network. The average per unit wheeling charge is calculated in the table below
Table 146: Wheeling Charges at 33 kV for FY 2018-19
S. No Particulars Unit FY 2018-19
1 Energy input into 33 kV system MU 30,720.94 2 Total distribution cost INR Cr 3,054.73 3 Distribution cost for 33 kV voltage levels (assuming 50% of item 2) INR Cr 1,527.36 4 Wheeling charges for 33 kV voltage level (item 3÷1) Ps./kWh 0.50
10.4.4. The wheeling cost has been computed for 11 kV level as below
Table 147: Wheeling charges at 11 kV for FY 2018-19
S. No. Particulars Unit Wheeling Charges 1 Energy input into 33 kV system MU 30,720.94 2 Losses in 33 kV (5%) % 1,536.05 3 Energy sales in 33 kV system as approved by the Commission MU 1,508.48 4 Energy input into 11 kV system [1-(2+3)] MU 27,676.42 5 Total distribution cost INR Cr 3,054.73 Distribution cost for 11 kV voltage levels (assuming 50% of INR Cr 6 1,527.36 item 5) Wheeling charges for 11 kV voltage level (item 6÷4) Ps/ 7 0.55 kWh
North Bihar Power Distribution Company Limited 172 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
10.5. Cross Subsidy Surcharge
10.5.1. The open access consumers are liable to pay cross subsidy surcharge to compensate the distribution utility for any loss of revenue due to shifting of its consumer to the open access system. The cross subsidy surcharge for open access consumers for the year 2018-19 is calculated as per the following recommended formula in the Tariff Policy, 2016.
“S= T – [C/ (1-L/100) + D+ R] Where S is the surcharge T is the tariff payable by the relevant category of consumers, including reflecting the Renewable Purchase Obligation C is the per unit weighted average cost of power purchase by the Licensee, including meeting the Renewable Purchase Obligation D is the aggregate of transmission, distribution and wheeling charge applicable to the relevant voltage level L is the aggregate of transmission, distribution and commercial losses, expressed as a percentage applicable to the relevant voltage level R is the per unit cost of carrying regulatory assets.”
10.5.2. The weighted average cost of power purchase for both Discoms is Rs 4.49/kWh as shown below:-
Table 148: Power purchase cost for FY 2018-19
Particulars Gross power purchase (MU) 30172.77 Less:-PGCIL loss (MU) 1137.45 Net power purchase (MU) 29035.32 Power purchase cost including PGCIL 13148.80 charges Average power purchase rate 4.53
Calculation of Cross Subsidy Surcharge: -
S = T–[C(1-L)/100)+D+R] a) For 132 kV consumers =8.47–[(4.49/ (1-3.92) +0.43+0] = Rs.3.37/kWh b) For 33kV consumers = 8.56 – [(4.49/ (1-3.92) x (1-5%)+(0.43+0.41)+0] = Rs.3.28/kWh c) For 11kV consumers = 8.48–[(4.49/ (1-3.92) x (1-5%)x(1-6%)+(0.43+0.41+0.47)+0] = Rs.3.04/kWh d) For HTSS consumers = 6.96–[(4.49/ (1-3.92) x (1-5%)+(0.43+0.41)+0] = Rs.1.69/kWh 10.5.3. The Revised Tariff Policy suggest that the cross subsidy shall not increase 20% of applicable tariff to the category of consumers seeking Open Access. The cross subsidy surcharge for 132 kV, 33 kV, 11 kV and HTSS category of the consumers are approved by the Commission at 20% of applicable tariff of the respective category of consumers seeking Open Access.
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a) The cross subsidy surcharge for FY 2018-19 are:-. b) For 132 kV consumers :- INR 1.69/kWh c) For 33kV consumers (other than HTSS) :- INR 1.71/kWh d) For 11kV consumers (other than HTSS) :- INR 1.70/kWh e) For HTSS :- INR 1.39/kWh
10.6. Reactive Energy charges
10.6.1. The open access consumers should pay a reactive energy charge to Transmission and Distribution companies as the case may be for drawl/ injection of reactive energy. Discom proposes the same reactive charges of 04 Paisa/ kVAR for FY 2018-19. 10.6.2. The Hon’ble Commission is requested to approve all the open access charges,CrossSubsidy Charges and other charges
10.7. Standby Charges
10.7.1. As per BERC open access regulations “20 A. Standby Power In case of outage of a power plant supplying power to an open access customer, the licensee will, on request, provide standby supply to meet the requirement of load catered through open access. Such standby supply will be provided by the licensee at day ahead request from the open access customer. The open access customer will, for that supply, be liable to pay charges under tariff for temporary connection to that category of consumer.”
10.7.2. The Hon’ble Commission is requested to approve the same in line with the regulations
10.8. Roadmap for reduction of Cross Subsidy Surcharge
10.8.1. Section 8.3 (2) of the Tariff Policy 2016 specifies that: “For achieving the objective that the tariff progressively reflects the cost of supply of electricity, the Appropriate Commission would notify a roadmap such that tariffs are brought within ±20% of the average cost of supply. The road map would also have intermediate milestones, based on the approach of a gradual reduction in cross subsidy”. 10.8.2. The Tariff Policy provides that SERCs should notify a roadmap such that tariffs are in ±20% of ACoS. The First proviso to para 8.5.1 of Tariff Policy 2016 also specifies that Cross Subsidy Surcharge (CSS) should be capped at 20% of the tariff applicable to the category of the consumers. The Petitioner aims at gradual reduction of cross subsidy surcharge in line with National Tariff policy. 10.8.3. The Petitioner is proposing the following roadmap for reduction in cross subsidy in next 3 years
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Table 149: Roadmap for reduction in cross subsidy
FY 2018-19 FY 2019-20 FY 2020-21 FY 2020-21 ACoS ABR ACoS ABR ACoS ABR ACoS ABR Catego Cross Cross Cross Cross (INR/kW (INR/kW (INR/kW (INR/kW (INR/kW (INR/kW (INR/kW (INR/kW ry subsidy subsidy subsidy subsidy h) h) h) h) h) h) h) h) KJ 7.55 6.39 84.67% 8.30 7.35 88.52% 9.13 8.23 90.13% 10.05 9.22 91.77% DS-I 7.55 7.05 93.43% 8.30 8.11 97.68% 9.13 9.08 99.45% 10.05 10.08 100.36% DS-II 7.55 7.65 101.33% 8.30 8.80 105.94% 9.13 9.15 100.16% 10.05 10.06 100.16% NDS-I 7.55 6.33 83.91% 8.30 7.29 87.73% 9.13 8.16 89.32% 10.05 9.14 90.95% NDS-II 7.55 8.64 114.47% 8.30 9.25 111.35% 9.13 10.08 110.34% 10.05 11.29 112.34% IAS-I 7.55 7.41 98.22% 8.30 8.38 100.90% 9.13 9.22 100.90% 10.05 10.14 100.90% IAS-II 7.55 8.36 110.73% 8.30 8.78 105.70% 9.13 9.48 103.78% 10.05 10.43 103.78% LTIS 7.55 8.02 106.25% 8.30 8.50 102.38% 9.13 9.18 100.52% 10.05 10.10 100.52% PWW 7.55 8.59 113.83% 8.30 8.59 103.49% 9.13 9.28 101.60% 10.05 10.12 100.68% HTS-I 7.55 8.48 112.32% 8.30 8.90 107.21% 9.13 9.62 105.26% 10.05 10.58 105.26% HTS-II 7.55 8.56 113.35% 8.30 8.98 108.20% 9.13 9.25 101.31% 10.05 10.09 100.39% HTS-III 7.55 8.47 112.22% 8.30 9.23 111.20% 9.13 10.07 110.19% 10.05 10.97 109.19% HTSS 7.55 6.96 92.26% 8.30 8.01 96.45% 9.13 8.97 98.21% 10.05 10.05 99.99% RT 7.55 8.48 112.35% 8.30 8.48 102.13% 9.13 9.24 101.20% 10.05 10.08 100.28%
North Bihar Power Distribution Company Limited 175 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
11. Implementation of UDAY
11.1. Background
11.1.1. The Ujwal Discom Assurance Yojana or UDAY was launched on 5 November 2015 with an aim of providing financial and operational turnaround to debt ridden Power Distribution companies in the country. UDAY enables the DISCOMs with the opportunity to break even in the next 2-3 years through four initiatives (i) Improving operational efficiencies of DISCOMs; (ii) Reduction of cost of power; (iii) Reduction in interest cost of DISCOMs; (iv) Enforcing financial discipline on DISCOMs through alignment with State finances.
11.2. Overview of the scheme
11.2.1. States shall take over 75% of DISCOM debt as on 30 September 2015 over two years - 50% of DISCOM debt shall be taken over in 2015-16 and 25% in 2016-17. 11.2.2. States will issue non-SLR including SDL bonds in the market or directly to the respective banks/ Financial Institutions (FIs) holding the DISCOM debt to the appropriate extent 11.2.3. Non-SLR bonds issued by the State will have a maturity period of 10-15 years with a moratorium on repayment of principal upto 5 years, as required by the State. 11.2.4. The 10 year State bonds issued will be priced at 10 year G-Sec plus 0.5% spread for 10 year State bonds plus 0.25% spread for non-SLR status on semi-annual compounding basis, or market determined rate, whichever is lower. This may be further reduced if interest is paid on monthly basis. 11.2.5. States to take over future losses of DISCOMs as per trajectory in a graded manner: [0% of loss of 14-15 & 15-16; 5% of 16-17; 10% of 17-18; 25% of 18-19 & 50% of 2019-20]
11.3. The Petitioner entered into a tripartite MoU with the Ministry of Power, Government of India and Government of Bihar on 22 February 2016 for achieving turnaround of the Discom. The salient features of UDAY are broadly captured below: Cleaning up of legacy issues by clearing liabilities of 75% outstanding loan and restructuring of 25% of outstanding loan (Total outstanding loan of NBPDCL is INR 1,282.51 Crore as on 30.09.2015), thereby adjusting past losses of DISCOM to that extent and continuing reduction of interest cost of DISCOM. Defining a roadmap for achieving AT&C loss level of 15% by resorting to activities related to Energy Accounting and Audit, Metering, Strengthening of Distribution network and proper monitoring of Billing and Collection for increasing Billing efficiency and Collection efficiency. Reducing the gap between ACS and ARR to zero by way of operational turnaround and quarterly increase in tariff.
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Achieving the primary objective of reliable and round the clock power for all and ensuring sustainability of distribution utilities. Establishing deterrents for State govt. to closely monitor DISCOM financial performance, by including DISCOM losses in the FRBM limits.
11.4. The scheme directs below targets to be achieved within the stipulated timelines by participating states for achieving financial and operational turnaround of Discoms:
Table 150: Targets defined under UDAY for NBPDCL
Sr. Activity Targeted benefit Expected date of No. completion 1 Compulsory feeder and Ability to track losses at the Feeders - 30th June Distribution Transformer feeder and DT level for 2016 (DT) metering by States corrective action DTs- 30th June 2017 2 Feeder improvement and Improvement in quality of 31st December 2017 separation supply of power and load balancing 3 Consumer Indexing & GIS Identification of loss making 30th September 2018 Mapping of losses areas for corrective action 4 Upgradation/ change of Reduce technical losses and 31st December 2017 transformers, meters etc. minimize outages 5 Smart metering of all Smart meters will be Tamper Consumption above 500 consumers consuming proof and allow remote units/month- 31st December above 500 or 200 units / 2017 reading thus helping reduce month Others- 31st December theft, implementation of 2019 DSM activities and consumer engagement 6 Demand Side Management Reduce peak load and Provide Domestic (DSM) which includes energy energy consumption and connections- 31st March efficient LED bulbs, meeting targets of 24*7 2019 agricultural pumps, fans & Power For All program. Distribution of LED bulbs- air-conditioners and efficient Annual estimated savings of 31st December 2017 industrial equipment through Rs. 40,000 crore for PAT. consumers from LED lighting Provide Domestic programme alone connections to 101.6 lac consumers 8 Comprehensive campaign to Enhance public participation One year awareness check power theft to reduce power theft programme jointly with States upto 31st December 2016 9 Assure increased power Encourage local participation 31st March 2018 supply in areas where the to reduce losses AT&C losses reduce 10 Implementation of ERP Software solution will 32 RAPDRP towns- 30th system improve productivity, June 2016 increase efficiency and Entire ERP system- 31st streamline processes March 2018
11.5. As of September 2015 the outstanding debt of the Petitioner stood at INR 1,282.5 Crores; with the ARR of the company unable to meet the ACS and operating with a cost recovery of only
North Bihar Power Distribution Company Limited 177 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
60.74%. Recognizing the need to have an action plan in place and take adequate intervention, NBPDCL, Ministry of Power, GOI and the Government of Bihar, signed a MoU under the UDAY scheme on 22nd February, 2016. The MoU had a commitment of eliminating the gap between ACS and ARR, and reducing the AT&C loss from 41.76% in FY 2014-15 to 15% by FY 2019- 20. 11.6. In order to achieve reduction in AT&C loss and ACS-ARR gap the following efforts have been undertaken by the Petitioner to comply with the UDAY targets within the stipulated timeline: 33kV and 11kV Feeder Metering: At 33kV level, the Petitioner has a total of 403 feeders, while at 11 kV level there are a total of 1236 feeders with a metering level of 80%. The Petitioner is working towards 100% 33kV and 11 kV feeder metering by Dec 2017 DTR Metering: In order to achieve the target of energy audit and appropriate accounting to contain the T&D losses, the Petitioner has prepared a comprehensive distribution transformer metering plan. The Petitioner understands the importance of effective metering and billing, and illustrates the potential increase in metered consumption that utility may achieve through DT metering. As of June 2016 the Petitioner has 58,643 nos. of DTs, out of which 6,749 are metered. Feeder Improvement and Segregation Program: The Petitioner understands the importance of renovating the feeders in form of continuous operation & maintenance of feeders, metering the feeders, using appropriate conductor at different voltage levels, optimizing the feeder length, underground cabling (wherever possible) revamping the feeders by maintain a ring system for emergency and creating necessary redundancies in the distribution network. In this regard, feeder data is being collected from various circles and analysis on same is targeted to be completed at the earliest. Apart from this, the Feeder Managers have been appointed for each feeder who will identify the requirements and steer the revamping work on their designated feeder(s). The focus of such program shall be on improving the quality of supply by reviewing the transformer capacity and load will be shifted after monitoring the ring system. Under ring system, one ring network of distributors is fed by more than one feeder. Thus, ensuring unaffected power supply to consumers even when any feeder becomes out of order Consumer Metering: The Petitioner has already achieved metering of over 85% of its existing base of 6.08 Million consumers. All Industrial (LT & HT), Traction consumers are 100% metered in the State. Out of un-metered consumers, majority are rural/ BPL domestic consumers covered under the initial phase of the RGGVY program. The Petitioner has proposed to cover metering for all un-metered consumers as well as
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replacement of identified defective meter cases within the next two years as covered under the PFA and UDAY Roadmap. a. Defective Meter Replacement: Defective meter replacement will help to achieve the true target of 100% consumer metering. The Discom plans to replace all defective meters at the earliest. b. Smart Metering: The Petitioner has planned to roll out smart metering in the premises of consumers consuming 500 units/ 200 units as per the target under the scheme. Performance Monitoring and Management System: To ensure that the targets set up under UDAY are achieved in a timely manner, the following committees have been constituted:- a. State Level Monitoring Committee: In line with the foremost UDAY target, a State level monitoring committee has been constituted, as approved by the Hon’ble Chief Minister of the State. The committee, under the chairmanship of Chief Secretary shall review the progress and achievement of the Discom on regular intervals. b. DISCOM level committee – Monitoring by CMD/ MD: A DISCOM level committee has also been set up under the leadership of CMD. This is to ensure that there is a regular watch on the targets set up under UDAY and the timely attainment of various UDAY targets. Apart from this a Nodal Officer has also been appointed to correspond on all issues related to the scheme. c. Project Management Agency (PMA) for UDAY: The Petitioner has decided to appoint a Project Management Consultant/ Agency for closely advising and monitoring on all issues envisaged under UDAY from concept to commissioning at Headquarter, and field offices level for the period of UDAY. This agency will assist in achieving all the targets of UDAY including the broad objective of reduction in AT&C loss and elimination of ACS and ARR Gap. 11.7. The following are the UDAY objectives implemented by the Petitioner along with the progress status of each: Table 151: Progress made by NBPDCL as against UDAY targets
S. Parameter Progress made No. 1. Issuance of bonds a) Total Outstanding Debts of Rs. 1,282.5 crore as on 31st Sept,2015 to be restructured under UDAY. b) Bonds of Rs. 961.8 crore (75% of total outstanding debts as on 30th Sept’15) already issued. c) Amount received from State Govt. and loan paid to the concerned. d) Balance loan has been rescheduled by M/s Canara Bank at Base Rate + 0.1%.
2. Interest amount saved so far Year Particulars Amount Total (INR Crore) (INR Crore)
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S. Parameter Progress made No. Due to repayment 70.54 of loan FY 2016-17 73.34 Due to loan 2.80 reschedule Due to repayment 105.81 of loan FY 2017-18 106.71 Due to loan 0.91 reschedule 3 Savings in cost of power purchase on Year Per unit cost of Total power Savings account of UDAY power purchased (MU) (INR Crore) 2015-16 4.39 21,677.70 - 2016-17 4.26 22,975.28 298.69 2017-18 4.29 14,162.66 184.11
(Note: Progress is for the State as a whole)
4 ARR and ACS gap Year ACS ARR Gap 2015-16 5.39 4.66 0.73 2016-17 4.79 4.16 0.63 2017-18 (Q1) 5.25 4.47 0.78 2017-18 (Q2) 5.52 4.63 0.89
ACS and ARR Gap has decreased by 10 paise/unit during FY 2016-17 as compared to FY 2015-16
5 Reduction in Aggregate losses Year Gap Input Power Aggregate (in rupees) (in MU) losses (INR Crore) 2015-16 0.73 8,929 652 2016-17 0.63 9,722 612 2017-18 0.83 5,534 459
6 Feeder metering status Feeder type Total 11 kV Metered (as Unmetered feeders on date) (including defective) Urban 217 217 Nil Rural 1019 768 251* Total 1236 985 251
*- All 11kV feeders have been installed with tri-vector energy meters in panels Action Plan for Feeder Metering :- 1. Unmetered / Defective meter to be installed / Replaced by Dec’17 2. Integration with national portal to be done by Dec’17. 3. For timely replacement of defective meter/metering unit and communication of meters (AMR) deliberations are in progress with firms on AMC 4. Replacement of existing meter/ metering unit to be done under IPDS scheme metering tender to be floated by Dec ‘17
7 DT metering status
North Bihar Power Distribution Company Limited 180 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
S. Parameter Progress made No. Urban/ Semi Total no of DT Metered Unmetered urban & rural (June 2017) (including defective) Urban 3,919 3,919 Nil Rural 54,724 2,830 51,894 Total 58,643 6,749 51,894
Action Plan for DT metering :- 1. Existing Unmetered DT in rural areas not to be metered due to non- commercial viability as of now. 2. Metering of existing unmetered DTs in IPDS area to be taken under IPDS scheme. 3. For timely replacement of defective DT meter and communication of meters (AMR) deliberations are in progress with firms on AMC
8 Smart meters rollout Units consumption No. of consumers No. of smart meters installed Above 500 30,919 Nil units/month Above 200 40,647 Nil units/month Total 71,566 Nil
Action Plan for Smart metering :- 1. Vendors conference for implementation of smart metering organised on 29.05.17. 2. Smart metering for 3.2 lakhs consumers on Service Model to be rolled out. Delay Reasons : IS for Smart Meters IS-16444 –II with amendment published on 19.06.17. Testing of Smart meters only available at –ERDA-Vadodra, CPRI- Bangalore & YMPL
9 Outstanding dues/arrears with Year Outstanding dues/ arrears state government (Rs. In crores) Feb 2016 253 Sep 2017 270
Initiatives taken for timely release of arrear and Current energy dues by State Govt. 1. A meeting with Principal Secretary/ Secretary of Major Departments taken by Chief Secretary on 16.05.2017 for timely release of arrear and current energy dues of DISCOMs. 2. All Departments directed to make required budget provision. 3. Pre paid meter be installed in the premises of big Government consumers (1939 nos.).
10 Status of household electrification Figures in lacs Discom Total Households Balance households electrified till households Mar 2017 NBPDCL + 155 101 APL BPL Total SBPDCL 29 25 54 (Note: Progress is for the State as a whole)
North Bihar Power Distribution Company Limited 181 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
S. Parameter Progress made No.
1. Electrification of BPL household taken up under DDUGJY. 2. Electrification of APL household taken up under Mukhya Mantri Saat Nischaya Yojana. 3. Target for Electrification of total household by Dec’18.
11 Details of stressed assets Year Amount (INR Crore) 2015-16 1,615.40 2016-17 1,615.40
Action for revival of stressed Assets. 1. Disconnection drive for recovery of dues. 2. Permanent Disconnection and filing of certificate case.
12 Demand side Distribution of LED bulbs under DELP program till May 2017 management Year Target defined Achievement under UDAY (in lacs) (in lacs) 2016-17 14.80 51.15 2017-18 10.00 16.11
Estimated Saving in terms of unit saved during April’16 to May’17 is 983 MU
11.8. Other major initiatives taken by the Bihar Distribution Companies to increase the billing and collection efficiency, reduce AT&C losses and ACS-ARR Gap: 1. Rationalization of Electricity Tariff aiming for Simplification, Transparency and 100% Cost coverage with provision of subsidy to consumers. 2. Additional Rebate of 1% for on-line payment through web portal in addition to Rebate of 1.5% for timely payment will be allowed for consumers 3. Web based Spot billing through mobile and Bluetooth printer already implemented for all consumers 4. Spot billing agencies appointed for IPDS area where 85-90 % spot bills are being issued every month 5. Mobile based Spot billing has been introduced in rural areas through Rural Revenue Franchisee using virtual wallet / POS/ Empos for collection 6. Mobile based Spot billing has been introduced in rural areas through Agencies for 28 lakhs consumers using E-wallet / POS/ Empos for collection 7. Meter shifting /Installation /Replacement of meter work for connected consumer has been given to the billing agencies on scheduled rate 8. Collection of revenue from consumers has been given to billing agencies of R-APDRP area for one town on pilot basis.
North Bihar Power Distribution Company Limited 182 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
9. Disconnection drive through deployment of dedicated gang in every section is being taken. 10. High Power Incentive scheme for 05 divisions having max. losses has been undertaken on Pilot basis 11. Major reshuffle of engineers based on their performance done in April’17. 12. Monthly revenue collection increased from Rs. 445 crore (April’17) to Rs. 625 crore (Sept’17). 13. Rs. 1500 crore additional revenue expected during 2017-18.
North Bihar Power Distribution Company Limited 183 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
Annexure A – Additional Formats
A.1. Annexure – I– Profile of NBPDCL
Sl.No. Particulars Unit Quantity 1 No. of fully electrified villages No 19,816 2 No. of un-electrified villages (including partially electrified) No 6,296,205 3 No. of consumers No 354/5218.7 MVA 4 No. & capacity of 33/11 KV Substations No/MVA 74045/5076.82 MVA 5 No. & capacity of 11/0.4 KV 3 Phase Transformers No/MVA 5657 6 Length of 33 KV line CKM 59651 7 Length of 11 KV line CKM 118713 8 Length of LT line CKM 19,816
A.2. Annexure – II (A) – Category wise Number of Consumers in past 4 years
Consumer Category FY 2013-14 FY 2014-15 FY 2015-16 FY 2016-17 Domestic 2,337,948 3,184,729 4,394,465 5,660,408 Kutir Jyoti- BPL Consumers 978,468 1,223,212 1,811,913 2,516,282 Domestic – I 726,732 1,125,478 1,550,465 1,967,498 Domestic – II 632,713 836,001 1,032,008 1,176,543 Domestic - III Commercial 106,973 162,923 222,097 294,747 Non-Domestic – I 19,445 33,911 54,144 80,110 Non-Domestic – II 87,429 128,839 167,617 214,557 Non-Domestic – III 99 173 336 80 Public Lighting 112 190 290 255 Street Light – I 40 155 147 142 Street Light – II 72 35 143 113 Irrigation 4,329 5,087 6,461 14,158 IAS – I 2,101 2,533 3,493 9,147 IAS – II 2,228 2,554 2,968 5,011 Public Water Works 530 632 679 208 Industrial LT 4,827 7,424 11,005 12,246 LTIS – I 4,483 6,952 10,065 11,593 LTIS – II 344 472 940 653 Industrial HT 366 489 626 675 HTS – I 344 460 596 643 HTS – II 15 24 25 25 HTS – III 1 2 2 2 HTSS 6 3 3 5 Railway 2 4 4 7 Nepal 1 1 1 1 DF 1 190,720 286,451 313,499 Total 2,455,090 3,552,200 4,922,080 6,296,205
North Bihar Power Distribution Company Limited 184 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
A.3. Annexure – II (B) – Category wise sanctioned / contracted Load in past 4 years
Consumer Category FY 2013-14 FY 2014-15 FY 2015-16 FY 2016-17 Domestic 2,197,909.00 2,887,654.00 3,820,216.23 3,708,169.94 Kutir Jyoti- BPL Consumers 839,282.00 891,501.00 1,156,172.00 353,590.63 Domestic – I 634,266.00 1,074,457.00 1,527,880.00 1,975,877.26 Domestic – II 723,949.00 921,340.00 1,135,781.23 1,378,615.05 Domestic - III 412 356 383 87 Commercial 240,488.50 327,814.50 450,431.50 631,728.73 Non-Domestic – I 13,736.00 34,338.00 55,533.00 85,122.24 Non-Domestic – II 225,962.50 292,874.50 394,173.50 546,352.49 Non-Domestic – III 790 602 725 254 Public Lighting 3,352.00 3,992.00 9,422.00 3,302.14 Street Light – I 1,623.00 3,218.00 4,031.00 965 Street Light – II 1,729.00 774 5,391.00 2,337.14 Irrigation 35,986.05 36,281.50 42,619.00 83,039.43 IAS – I 7,528.11 8,333.00 11,105.00 29,627.20 IAS – II 28,457.94 27,948.50 31,514.00 53,412.23 Public Water Works 8,216.65 10,003.00 12,975.00 4,666.00 Industrial LT 50,188.80 62,130.00 106,661.51 56,276.77 LTIS – I 36,588.31 45,813.00 73,276.33 22,879.85 LTIS – II 13,600.49 16,317.00 33,385.17 33,396.92 Industrial HT 132,438.60 180,451.00 201,520.50 223,789.50 HTS – I 68,722.20 104,163.00 119,294.50 137,246.50 HTS – II 26,360.10 38,131.00 39,269.00 41,636.00 HTS – III 24,003.00 34,170.00 34,170.00 34,170.00 HTSS 13,353.30 3,987.00 8,787.00 10,737.00 Railway 19440 140400 43200 54900 Nepal DF 420,791.00 420,791.00 Total 2,688,019.60 3,648,726.00 5,107,836.74 5,186,663.51
A.4. Annexure – II (C) – Category wise Energy sales in past 4 years
Consumer Category FY 2013-14 FY 2014-15 FY 2015-16 FY 2016-17 Domestic 1,607.89 2,174.92 3,209.48 3,567.04 Kutir Jyoti- BPL Consumers 366.02 506.37 811.17 848.69 Domestic – I 491.92 668.04 1,067.76 1,522.29 Domestic – II 749.19 999.87 1,329.85 1,196.06 Commercial 298.40 416.08 533.50 706.21 Non-Domestic – I 17.60 27.94 43.02 67.70 Non-Domestic – II 279.82 387.30 489.63 638.52 Public Lighting 26.05 10.99 20.92 15.27 Street Light – I 10.79 6.66 10.55 6.24 Street Light – II 15.27 4.33 10.36 9.03 Irrigation 104.84 103.19 130.88 160.20 IAS – I 12.19 10.68 24.19 7.40 IAS – II 92.64 92.51 106.69 152.80 Public Water Works 24.26 28.33 26.43 30.16 Industrial LT 90.36 121.39 132.71 163.45 LTIS – I 56.22 78.25 85.65 145.40 LTIS – II 34.14 43.13 47.06 17.95 Industrial HT 351.44 371.88 433.41 474.19 HTS – I 193.96 201.73 250.60 269.41 HTS - II 74.17 79.03 87.59 93.24 HTS - III 25.67 49.64 80.42 65.95
North Bihar Power Distribution Company Limited 185 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
HTSS 57.65 41.49 14.80 45.59 Railway 12.05 18.29 22.26 62.67 Nepal 751.18 1,010.07 1,221.02 1,188.89 UI 76.58 170.28 77.64 77.35 M/s Essel Vidyut Vitran-DF 261.75 578.10 696.79 749.87 Total 3,604.82 5,003.52 6,505.03 7,195.20 Growth rate 39% 30% 11%
A.5. Annexure – II (D) – Category wise Number of Consumers of Muzaffarpur DF in past 4 years
Consumer Category FY 2013-14 FY 2014-15 FY 2015-16 FY 2016-17 Domestic 115,204 189,339 259,309 282,762 Kutir Jyoti- BPL Consumers 23,601 81,194 128,330 135,901 Domestic – I 15,321 23,835 40,525 52,943 Domestic – II 76,278 84,302 90,445 93,918 Domestic - III 4 8 9 0 Commercial 18,441 21,917 24,895 27,722 Non-Domestic – I 1,116 2,071 3,321 5,162 Non-Domestic – II 17,313 19,820 21,539 22,560 Non-Domestic – III 12 26 35 0 Non-Domestic - IV - - - - Public Lighting 4 228 375 395 Street Light – I 4 6 6 6 Street Light – II 0 222 369 389 Irrigation 22 40 111 499 IAS – I 16 34 103 345 IAS – II 6 6 8 154 Public Water Works 34 34 34 58 Industrial LT 989 1,355 1,593 1,909 LTIS – I 866 1,210 1,438 1,752 LTIS – II 123 145 155 157 Industrial HT 96 116 134 154 HTS – I 92 111 128 147 HTS – II 3 4 4 5 HTS – III 0 0 0 0 HTSS 1 1 2 2 Railway 0 0 0 0 Nepal 0 0 0 0 DF 0 0 0 0 Total 134,790 213,029 286,451 313,499
North Bihar Power Distribution Company Limited 186 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
A.6. Annexure – II (E) – Category wise sanctioned / contracted Load of Muzzaffarpur DF in past 4 years
Consumer Category FY 2013-14 FY 2014-15 FY 2015-16 FY 2016-17 Domestic 151,982.00 229,566.24 285,184.00 311,960.00 Kutir Jyoti- BPL Consumers 23,601.00 81,203.00 117,905.00 128,859.00 Domestic – I 15,380.00 24,024.00 34,355.00 43,916.00 Domestic – II 112,985.00 124,302.24 132,886.00 139,136.00 Domestic - III 16.00 37.00 38.00 49.00 Commercial 40,248.46 48,127.36 53,836.00 59,295.00 Non-Domestic – I 1,205.00 2,302.00 3,634.00 5,149.00 Non-Domestic – II 39,000.46 45,648.36 50,003.00 53,932.00 Non-Domestic – III 43.00 177.00 199.00 214.00 Non-Domestic - IV - - - - Public Lighting 38.00 712.00 1,083.00 1,165.00 Street Light – I 38.00 58.00 58.00 58.00 Street Light – II 0.00 654.00 1,025.00 1,107.00 Irrigation 141.74 188.74 302.00 690.97 IAS – I 96.98 143.98 252.00 613.97 IAS – II 44.76 44.76 50.00 77.00 Public Water Works 467.74 467.74 464.00 687.00 Industrial LT 11,188.54 14,801.50 16,843.00 18,830.35 LTIS – I 6,496.93 9,066.13 10,773.00 12,653.97 LTIS – II 4,691.61 5,735.37 6,070.00 6,176.38 Industrial HT 26,426.00 30,814.00 39,785.00 45,076.00 HTS – I 20,000.00 23,388.00 28,259.00 32,550.00 HTS – II 3,226.00 4,226.00 4,226.00 5,226.00 HTS – III 0.00 0.00 0.00 0.00 HTSS 3,200.00 3,200.00 7,300.00 7,300.00 Railway 0.00 0.00 0.00 0.00 Nepal 0.00 0.00 0.00 0.00 DF 0.00 0.00 0.00 0.00 Total 230,492.48 324,677.58 397,497.00 437,704.32
A.7. Annexure – II (F) – Category wise Energy sales of Muzzafarpur DF in past 4 years
Consumer Category FY 2013-14 FY 2014-15 FY 2015-16 FY 2016-17 Domestic 93.44 236.41 312.86 358.14 Kutir Jyoti- BPL Consumers 15.88 72.99 102.53 108.68 Domestic – I 11.58 28.37 38.58 49.18 Domestic – II 65.97 135.02 171.68 200.23 Domestic - III 0.01 0.03 0.06 0.05 Commercial 23.70 48.35 63.61 73.03 Non-Domestic – I 0.85 2.17 3.49 5.02 Non-Domestic – II 22.84 46.03 59.95 67.80 Non-Domestic – III 0.01 0.14 0.17 0.21 Non-Domestic - IV - - - - Public Lighting 0.45 2.12 5.36 8.39 Street Light – I 0.45 0.08 0.19 0.18 Street Light – II 0.00 2.04 5.17 8.21 Irrigation 1.13 2.65 2.72 1.67 IAS – I 0.15 0.31 0.53 1.12 IAS – II 0.98 2.34 2.20 0.55 Public Water Works 0.85 0.61 1.31 3.43
North Bihar Power Distribution Company Limited 187 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
Industrial LT 8.40 20.95 23.93 32.32 LTIS – I 4.66 11.92 13.87 18.43 LTIS – II 3.73 9.03 10.06 13.89 Industrial HT 27.70 73.61 95.03 112.64 HTS – I 17.42 48.27 55.19 67.72 HTS - II 3.08 8.16 11.60 11.80 HTS - III 0.00 0.00 0.00 0.00 HTSS 7.20 17.18 28.25 33.12 Railway 0.00 0.00 0.00 0.00 Nepal 0.00 0.00 0.00 0.00 DF 0.00 0.00 0.00 0.00 Total 155.66 384.70 504.82 589.62
A.8. Annexure – III : Input Energy to DF Muzzafarpur
Sl.No. Month Input Energy Unit Rate Amount (Kwh) (Rs/Kwh) Payable to D.F.
1 April, 2016 62,549,192 3.529 180,736,098.57 2 May, 2016 62,839,861 3.529 181,761,869.47 3 June, 2016 71,821,767 3.529 213,459,015.74 4 July, 2016 70,603,161 3.529 209,158,555.17 5 August, 2016 72,949,323 3.529 217,438,160.87 6 September, 2016 67,201,048 3.529 197,152,498.39 7 October, 2016 68,147,784 3.529 200,493,529.74 8 November, 2016 55,215,954 4.077 185,115,444.46 9 December, 2016 54,552,633 4.077 182,411,084.74 10 January, 2017 56,430,539 4.077 190,067,307.50 11 February, 2017 49,105,158 4.077 160,201,729.17 12 March, 2017 56,171,622 4.077 189,011,702.89 Total 747,588,042 2,307,006,996.71 Note 1: Above details is for one and only DF in NBPDCL i.e. MVVL Note 2: Excess 2109950 Kwh billed in Jun'2016 has been reversed in Jul' 2016 Invoice Note 3: Excess 169960 Kwh billed in Nov'2016 has been reversed in Dec' 2016 Invoice Note 4: TA @ 22 paise per unit allowed for each month Invoice for Apr'2016 to Mar'2017 Note 5: Additional TA of Rs. 4,00,00,000.00 has been allowed from Apr'2016 to Mar'2017
A.9. Annexure – IV : RPO Obligation achieved during FY 2016-17
S. No. Particulars Unit FY 2016-17 1 Energy consumption excluding Nepal MU 7,117.88 2 % of RPO Obligation % 6.50% Solar % 1.50% Non-Solar % 5.00% 3 MUs required as per RPO for the year MU 462.66 Solar MU 106.77 Non-Solar MU 355.89 4 Solar Energy procured during the year MU 38.55 5 Non-Solar Energy procured during the year MU 68.29 6 Solar REC purchased during the year No. 0.00 7 Non-solar REC purchased during the year No. 0.00
North Bihar Power Distribution Company Limited 188 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
A.10. Annexure – V : Resource Gap Grants received from state government in FY 2016-17
Sl.No. Month Amount Received Share of SBPDCL Share of NBPDCL (INR) (INR) (INR) 1 April, 2016 2 May, 2016 6,000,000,000 3,63,12,00,000 2,368,800,000 3 June, 2016 3,000,000,000 1,81,56,00,000 1,184,400,000 4 July, 2016 3,000,000,000 1,81,56,00,000 1184400000 5 August, 2016 3,000,000,000 1,81,56,00,000 1184400000 6 September, 2016 3,000,000,000 1,81,56,00,000 1184400000 7 October, 2016 3,126,700,000 1,89,22,78,840 1,234,421,160 8 November, 2016 3,000,000,000 1,81,56,00,000 1184400000 9 December, 2016 3,000,000,000 1,81,56,00,000 1184400000 10 January, 2017 5,213,300,000 3,15,50,89,160 2,058,210,840 11 February, 2017 3,000,000,000 1,81,56,00,000 1,184,400,000 12 March, 2017 3,000,000,000 1,81,56,00,000 1,184,400,000 Total 38,340,000,000 23,20,33,68,000 15,136,632,000
A.11. Annexure – VI : Open Access consumers during FY 2016-17
Sl.No. Name of Open Access Open Access Period MWh consumer contracted From To Drawn load 1 North Bihar is not having any open access consumers
A.12. Annexure – VII : Demand based LT Consumers during FY 2016-17
Sl.No. Category No of Consumers opted Total Contracted Demand Demand Based Tariff 1 DS-II 681,730 759,131 2 NDS-II 118,927 427,522 3 NDS-III 6 69 4 LTIS-I 9,193 10,031 5 LTIS-II 565 37,338 Total 810,421 1,234,091
A.13. Annexure – VIII : Rebate or Late Payment Charges during FY 2016-17
Sl.No. Month Power Purchase Total Power Rebate received Late Payment (MU) Purchase Cost (Rs. Lakhs) Charges paid (Rs. Lakhs) (Rs. Lakhs) 1 April, 2016 847.78 32,634.47 9.53 2 May, 2016 854.79 34,670.46 61.56 3 June, 2016 880.89 35,170.49 3.75 4 July, 2016 916.12 36,147.31 5.21 5 August, 2016 928.20 36,111.71 10.97 6 September, 2016 866.05 32,229.25 4.01 7 October, 2016 942.85 36,910.36 41.2 8 November, 2016 819.99 33,344.90 28.47 9 December, 2016 840.32 33,638.59 16.32 10 January, 2017 875.46 36,943.40 28.48 11 February, 2017 771.72 34,932.44 36.19 12 March, 2017 844.43 37,989.70 696.54 Total 10388.60 420,723.08 942.23 3900.08
North Bihar Power Distribution Company Limited 189 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
A.14. Annexure – IX : Details of Energy Scheduled and Actual drawal during FY 2016-17
Month Scheduled Actual Over Deviation Addl. Total UI Energy Drawal Drawal / Charges (Rs. Deviation charges(Rs. (MU) (MU) Under Lakhs) Charges (Rs. Lakhs) Drawal Lakhs) (UI) (MU) April, 2016 753380.81 778361.93 -24981.1 66777383.52 72247531.59 139024915.1 May, 2016 782317.45 771655.58 10661.87 10695897.21 11962937.5 22658834.71 June, 2016 812121.64 815814.29 -3692.66 4783183.936 6762715.018 11545898.95 July, 2016 860923.47 844345.57 16577.9 303376.8381 3113918.669 3417295.507 August,2016 877895.18 880456.45 -2561.27 29912375.4 8623916.822 38536292.22 September,2016 834620.01 841556.87 -6936.86 35300913.7 5623674.746 40924588.44 October,2016 880169.86 865077.60 15092.26 22368918.08 3319722.973 25688641.05 November, 2016 764232.12 759935.70 4296.423 7529496.588 4401546.74 11931043.33 December, 2016 768395.76 773925.29 -5529.53 37607792.47 9862259.959 47470052.43 January, 2017 796654.02 799843.33 -3189.31 15047528.26 4263149.473 19310677.73 February, 2017 708982.98 720548.88 -11565.9 30169697.04 3338171.086 33507868.13 March, 2017 762445.19 779905.75 -17460.6 53888000.77 8151221.318 62039222.09 Total 9602138.49 9631427.24 -29288.75 314384563.81 141670765.89 456055329.70
A.15. Annexure – X : Details of Energy Sale during 1st half of FY 2017-18
S.no Category of No of Connected Energy sales Revenue Billed consumption Consumers as Load in KW as in MU 2017-18 in Rs. In Lakh on 30.09.2017 on 30.09.2017 (upto 2017-18 (upto 30.09.2017) 30.09.2017) A Domestic 1 Kutir Jyoti KJ 49,582 9,713 9.96 999.42 rural(Unmetered) KJ rural(metered) 2,540,807 341,862 - - First 30 units 94.79 6,490.72 31-50 units 42.74 1,904.08 51 - 100 Units 67.74 3,216.14 KJ urban(metered) 3,631 3,217 - - First 30 units 45.80 3,120.51 31-50 24.25 1,047.21 51 - 100 U/Month 25.28 1,281.59 SubTotal -- -- 2 DS-I -- Unmetered 382,422 388,251 223.02 11,872.51 Metered - 1,476,929 1,592,611 - - First 50 Units 331.82 14,032.85 51 - 100 Units 107.79 5,365.06 Above 100 Units 428.23 23,543.31 SubTotal -- -- 3 DS - ll --
North Bihar Power Distribution Company Limited 190 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
Single Phase -- 1-100 U/Month -- 101 - 200 U/Month -- 201 -300 U/Month -- above 300 U/Month -- Three Phase -- 1-100 U/Month -- 101 - 200 U/Month -- 201 -300 U/Month -- above 300 U/Month -- SubTotal -- -- 4 DS-II(Demand -- Based) Single Phase 1,099,042 1,160,666 - - 1-100 U/Month 196.72 16,740.99 101 - 200 U/Month 140.94 8,128.57 201 -300 U/Month 87.30 5,223.54 above 300 U/Month 549.10 36,974.74 Three Phase 4,143 25,475 - - 1-100 U/Month 0.03 2.45 101 - 200 U/Month 0.33 18.80 201 -300 U/Month 0.26 14.74 above 300 U/Month 2.23 151.17 SubTotal -- -- 5 DS-III -- 6 DS-III (Demand -- based) B NON-DOMESTIC -- SERVICES 1 NDS - I -- Unmetered 8,781 10,482 5.19 306.82 Metered 67,389 73,765 - - 1-100 U/Month 13.27 752.69 101 - 200 U/Month 5.04 275.64 above 200 U/Month 23.86 1,480.51 2 NDS - II - Single -- phase upto 0.5 kW 94 42 - - 1-100U/m -- 101-200 U/m -- above 200 U/m -- above 0.5kW -- 1-100U/m -- 101-200 U/m -- above 200 U/m --
North Bihar Power Distribution Company Limited 191 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
3 NDS - II(D)-Single 160,383 114,807 - - Phase 1-100U/m 17.99 2,234.38 101-200 U/m 9.22 817.65 above 200 U/m 36.53 2,632.80 4 NDS - II(D)-Three 28,606 276,608 - - Phase 1-100U/m 14.84 1,819.46 101-200 U/m 11.21 944.30 above 200 U/m 278.20 20,984.72 5 NDS-III -Single -- Phase 1-100U/M -- 101-200U/M -- Above 200U/M -- 6 NDS-III(D)- Single -- phase 1-100U/M -- 101-200U/M -- Above 200U/M -- 7 NDS-III(D)- Three -- phase 1-100U/M -- 101-200U/M -- Above 200U/M -- 8 NDS-IV -- Single phase -- Three phase -- C Street Light -- Services 1 SS-I GP 178 1,243 0.92 65.45 2 SS-I NP/NAC/M -- 3 SS-I MC -- 4 SS-II GP 219 13,661 - 288.26 5 SS-II NP/NAC/M -- 6 SS-II MC -- SubTotal -- D IAS -- 1 IAS-I Unmetered 884 3,466 2.13 149.46 Rural 2 IAS-I Unmetered 0.11 13.08 Urban 3 IAS-I Metered Rural 3,438 10,256 2.46 126.89 4 IAS-I Metered Urban 2.57 123.75 5 IAS-II Unmetered 1,584 24,985 33.11 2,613.79 Rural 6 IAS-II Unmetered 10.46 819.27 Urban 7 IAS-II Metered Rural 1,922 21,031 36.29 2,230.60 8 IAS-II Metered Urban 17.16 1,199.34
North Bihar Power Distribution Company Limited 192 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
SubTotal -- E PWW 734 10,768 12.38 1,086.77 -- F Low tension -- industrial 1 LTIS-I -- 2 LTIS-I (D) 11,009 98,271 104.25 7,097.96 3 LTIS-II -- 4 LTIS-II (D) 371 16,891 15.19 1,085.64 SubTotal -- G High Tension -- Supply 1 HTS - I 120,014 125.80 9,514.59 2 HTS - II 32,082 49.75 3,483.35 3 HTS - III -- 4 HTS - IV -- 5 HTSS 5,748 14.43 737.23 SubTotal -- H Railways -- 1 RTS (132kV) 8 69,900 57.37 4,688.61 2 RTS (25kV) -- SubTotal -- I DF -- J Nepal 540.62 32,282.00 K Other bilateral -- sales(Please specify) Grand Total 5,842,156 4,425,814 3,818.69 239,983.42
North Bihar Power Distribution Company Limited 193 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
A.16. Annexure – XI : Details of Central and State transmission losses during FY 2016-17
Sl.No Central Scheduled CTL CTL Actual Drawl Net UI Energy from Total Energy Energy Energy Sector, IPPs Energy Losses Losses (MU) (MU) State Sector Available at consumed in consumed in etc., Billed (Central (MU) (%) (3-6) and other State NBPDCL SBPDCL Energy Sector etc., sources (MU) (KWH) (KWH) (MU) Net (MU) (Sugar mills (6+8) etc) (MU) 12 3 456 7 8 9 10 11
23503.94 22889.00 614.95 2.62 22955.25 -66.25 1022.67 23977.92 9569.38 13271.65
Total Energy State State % share of % share of NBPDCL SBPDCL NBPDCL SBPDCL consumed in Transmission Transmission energy energy NBPDCL + Loss (STL) Loss (STL) drawal by drawal by CTL CTL STL STL SBPDCL NBPDCL SBPDCL NBPDCL + NBPDCL + (MU) (MU) (KWH) (KWH) (KWH) SBPDCL SBPDCL (10+11) (KWH) (%) (9-12)
12 13 14 15 16 17 18 19 20
22841.025 1136.89 4.74 41.90 58.10 257.63 357.31 476.31 660.58
North Bihar Power Distribution Company Limited 194 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19 A.17. Annexure – XII (A) : Scheme-wise details of capital expenditure and capitalization along with source of funding for FY 2016-17
Balanc Capital expenditure e Source of Funding Capitalisation incurred/invested Capex Name of to be Sl the Name of the Scheme Duri Investe No. funding Consum Total Durin Upto Grant/Ca Own Upto up to ng d in agency Equi er Loa (up to g FY 31.03. pital Sour 31.03.2 Total 31.03.2 FY Total subseq ty Contribu n 31.03.2 2016- 16 Subsidy ce 016 016 2016 uent tion 017) 17 -17 years 14 17 9 (5 to 18 (14- 1 2 3 4 5 6 7 8 10 13 (10+1 15 16 (15+ 8) 17) 3) 16) BRGF, Special plan 1 GoI/GoB Phase- I BRGF, Special plan 2 GoI/GoB 1193. 520. 1073.5 641.2 1714. Phase- II 0.00 0.00 0.00 0.00 1714.72 11.74 9.14 20.88 1693.83 BRGF, Special plan Part 75 97 0 2 72 3 GoI/GoB "C" 4 BRGF RE Portion GoB GoI(PFC)/ 5 RAPDRP Part A GoB 190.4 74.7 265.1 0.00 0.00 0.00 0.00 265.14 233.48 31.66 0.00 0.00 0.00 265.14 GoI(PFC)/ 1 3 4 6 RAPDRP Part B GoB 7 APDRP GoI 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 8 NABARD Phase VIII GoB 50.81 0.00 0.00 0.00 0.00 0.00 50.81 18.96 6.91 25.87 1.68 3.31 4.99 20.88 9 NABARDPhaseXI GoB 48.37 0.00 0.00 0.00 0.00 0.00 48.37 10.05 4.18 14.23 11.59 0.00 11.59 2.64 13.3 10 MP/CMLAD 59.78 0.00 0.00 0.00 0.00 0.00 59.78 52.91 1.59 54.50 1.44 14.74 39.77 0 11 DepositScheme 25.34 0.00 0.00 0.00 0.00 0.00 25.34 5.11 0.07 5.18 0.00 0.00 0.00 5.18 104.3 12 ADB GoI 0.00 0.00 0.00 0.00 0.00 104.30 0.25 0.92 1.17 0.00 0.00 0.00 1.17 0 13 ACAStatePlan GoB 50.49 0.00 0.00 0.00 0.00 0.00 50.49 1.29 1.48 2.77 0.00 0.00 0.00 2.77 217.3 14 Burnt DTR State Plan GoB 0.00 0.00 0.00 0.00 0.00 217.35 0.00 0.00 0.00 0.00 0.00 0.00 5 799.6 62.0 252.0 14.7 139.1 15 State Plan GoB 0.00 0.00 0.00 0.00 861.64 217.46 34.61 124.42 112.92 4 0 7 4 6 RSVY 0.00 0.29 0.00 0.00 0.00 0.00 0.29 0.00 0.29 0.29 0.00 0.29 0.29 0.00 2740. 583. 74.7 1613.0 722.9 2335. 40.7 191.6 Sub Total (A) 0.00 0.00 0.00 3398.23 150.87 2144.30 24 26 3 1 3 94 7 4
North Bihar Power Distribution Company Limited 195 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19 New Scheme 0.00 0.00 0.00 0.00 CM Seven Resolution 16 GoB 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 (Har Ghar Bijli) 17 IPDS GoI/PFC 10.35 0.00 0.00 0.00 0.00 0.00 10.35 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Sub Total (B) 10.35 0.00 0.00 0.00 0.00 0.00 10.35 0.00 0.00 0.00 0.00 0.00 0.00 0.00 RGGVY 11th Plan Phase- 18 REC I RGGVY 11th plan Phase- 2541. 146. 2721.4 1280. 4001. 248. 372.0 19 REC 0.00 1314.79 0.00 0.00 4001.91 123.59 3629.83 II 03 09 3 48 91 49 8 20 RGGVY 12th Plan REC/GoB 2541. 146. 2721.4 1280. 4001. 248. 372.0 Sub Total (C) 0.00 1314.79 0.00 0.00 4001.91 123.59 3629.83 03 09 3 48 91 49 8 New Scheme 0.00 0.00 0.00 0.00 203.6 21 DDUGJY REC/GoB 0.00 0.00 0.00 0.00 203.65 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5 203.6 Sub Total (D) 0.00 0.00 0.00 0.00 0.00 203.65 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5 5495. 583. 220. 4334.4 2003. 6337. 289. 563.7 Sub Total (A+B+C+D) 0 1314.79 0.00 0.00 7614.14 274.46 5774.13 27 26 82 4 41 85 26 2 295. 295.2 295.2 295. 295.2 22 Own Sources Utility 0.00 295.26 0.00 26 6 6 26 6 5495. 878. 220. 4334.4 2298. 6633. 584. 858.9 Grand Total 1314.79 0.00 0.00 7909.39 274.46 5774.13 27 51 82 4 67 11 51 7
North Bihar Power Distribution Company Limited 196 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
A.18. Annexure – XII (B) : Scheme-wise details of capital expenditure and capitalization along with source of funding for FY 2017-18
Capital expenditure Balanc Source of Funding Capitalisation incurred/invested e Capex Name of 01.04. 01.10. Duri to be Sl the Consu Total Name of the Scheme Upto Grant/C Own Upto 2017 2017 up to ng Investe No. funding Equi mer Loa (up to Tota 31.03 apital Sou 31.03. to to Total 31.03. FY d in agency ty Contrib n 31.03.2 l .17 Subsidy rce 2017 30.09. 31.03. 2017 2017 subseq ution 018) 2017 2018 -18 uent years 13 16 9 (5 to 17 (13- 1 2 3 4 5 6 7 8 10 11 12 (10+11 14 15 (15+ 8) 16) +12) 14) BRGF, Special plan 1 GoI/GoB Phase- I BRGF, Special plan 2 GoI/GoB 1714. 1309 3023.7 1714.7 3023.7 600. 621. Phase- II 0.00 0.00 0.00 0.00 542.29 766.78 20.88 2402.33 72 .07 9 2 9 58 46 BRGF, Special plan 3 GoI/GoB Part "C" 4 BRGF RE Portion GoB GoI(PFC 5 RAPDRP Part A )/GoB 265.1 71.7 67.3 67.3 0.00 0.00 0.00 0.00 336.87 265.14 24.82 46.91 336.87 0.00 269.50 GoI(PFC 4 3 7 7 6 RAPDRP Part B )/GoB 7 APDRP GoI 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 14.1 8 NABARD Phase VIII GoB 50.81 0.00 0.00 0.00 0.00 0.00 50.81 25.87 0.00 24.94 50.81 4.99 9.16 36.66 5 18.9 9 NABARDPhaseXI GoB 48.37 0.00 0.00 0.00 0.00 0.00 48.37 14.23 0.00 34.14 48.37 11.59 7.36 29.42 5 23.7 10 MP/CMLAD 59.78 0.00 0.00 0.00 0.00 0.00 59.78 54.50 0.00 5.28 59.78 14.74 9.01 36.04 4 11 DepositScheme 25.34 0.00 0.00 0.00 0.00 0.00 25.34 5.18 0.00 20.16 25.34 0.00 5.07 5.07 20.27 104.3 20.8 20.8 12 ADB GoI 0.00 0.00 0.00 0.00 0.00 104.30 1.17 0.00 103.13 104.30 0.00 83.44 0 6 6 10.1 10.1 13 ACAStatePlan GoB 50.49 0.00 0.00 0.00 0.00 0.00 50.49 2.77 0.00 47.72 50.49 0.00 40.39 0 0 217.3 43.4 43.4 14 Burnt DTR State Plan GoB 0.00 0.00 0.00 0.00 0.00 217.35 0.00 0.00 217.35 217.35 0.00 173.88 5 7 7 861.6 144. 283. 15 State Plan GoB 0.00 0.00 0.00 0.00 0.00 861.64 252.07 38.21 571.36 861.64 139.16 577.99 4 50 65 16 RSVY 0.29 0.00 0.00 0.00 0.00 0.00 0.29 0.29 0.00 0.00 0.29 0.29 0.00 0.29 0.00
North Bihar Power Distribution Company Limited 197 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19 3398. 1309 71.7 4779.0 2335.9 1837.7 4779.0 917. 1109 Sub Total (A) 0.00 0.00 0.00 605.32 191.64 3669.91 23 .07 3 3 4 7 3 48 .12 New Scheme 0.00 0.00 0.00 0.00 CM Seven Resolution 17 GoB 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 (Har Ghar Bijli) 37.6 112. 38.6 38.6 18 IPDS GoI/PFC 10.35 225.61 0.00 0.00 386.37 0.00 44.63 341.74 386.37 0.00 347.73 0 81 4 4 37.6 112. 38.6 38.6 Sub Total (B) 10.35 225.61 0.00 0.00 386.37 0.00 44.63 341.74 386.37 0.00 347.73 0 81 4 4 RGGVY 11th Plan 19 REC Phase- I RGGVY 11th plan 4001. 236. 6365.1 4001.9 1881.9 6365.1 1198 1570 20 REC 0.00 2126.87 0.00 0.00 481.21 372.08 4794.42 Phase- II 91 32 0 1 8 0 .60 .68 REC/Go 21 RGGVY 12th Plan B 4001. 236. 6365.1 4001.9 1881.9 6365.1 1198 1570 Sub Total (C) 0.00 2126.87 0.00 0.00 481.21 372.08 4794.42 91 32 0 1 8 0 .60 .68 New Scheme 0.00 0.00 0.00 0.00 REC/Go 203.6 116. 348. 1364.4 1152.5 1364.4 136. 136. 22 DDUGJY 696.47 0.00 0.00 0.00 211.87 0.00 1227.99 B 5 08 23 3 6 3 44 44 203.6 116. 348. 1364.4 1152.5 1364.4 136. 136. Sub Total (D) 696.47 0.00 0.00 0.00 211.87 0.00 1227.99 5 08 23 3 6 3 44 44 Sub Total 7614. 1462 769. 12894. 6337.8 1343.0 5214.0 12894. 2291 2854 10040.0 0 3048.95 0.00 0.00 563.72 (A+B+C+D) 14 .75 08 93 5 3 5 93 .16 .88 5 295.2 295. 23 Own Sources Utility 295.26 295.26 0.00 0.00 295.26 295.26 0.00 0.00 6 26 7909. 1462 769. 13190. 6633.1 1343.0 5214.0 13190. 2291 3150 10040.0 Grand Total 3048.95 0.00 0.00 858.97 39 .75 08 18 1 3 5 18 .16 .14 5
North Bihar Power Distribution Company Limited 198 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
A.19. Annexure – XII (C) : Scheme-wise details of capital expenditure and capitalization along with source of funding for FY 2018-19
Balanc Capital expenditure e Source of Funding Capitalisation incurred/invested Capex Name of to be Sl the Name of the Scheme Duri Duri Investe No. funding Awa Consum Ow Total Upto Grant/Ca Upto ng up to ng d in agency rd Equi er Loa n (up to 31.03. pital 31.03. FY Total 31.03. FY Total subse Cos ty Contrib n Sou 31.03.2 18 Subsidy 2018 2018- 2018 2018- quent t ution rce 019) 19 19 years BRGF, Special plan 935. 1 GoI/GoB Phase- I 27 BRGF, Special plan 148 2 GoI/GoB Phase- II 4.09 3023. 3023.7 3023.7 3023. 480.4 1101. 1921.8 0.00 0.00 0.00 0.00 0.00 0.00 621.46 BRGF, Special plan 271. 79 9 9 79 7 93 6 3 GoI/GoB Part "C" 49 332. 4 BRGF RE Portion GoB 94 GoI(PFC) 51.0 5 RAPDRP Part A /GoB 9 336.8 336.8 121.2 0.00 0.00 0.00 0.00 0.00 336.87 336.87 0.00 67.37 53.90 215.60 GoI(PFC) 285. 7 7 7 6 RAPDRP Part B /GoB 78 7 APDRP GoI 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 50.8 8 NABARD Phase VIII GoB 50.81 0.00 0.00 0.00 0.00 0.00 50.81 50.81 0.00 50.81 14.15 7.33 21.49 29.32 1 48.3 9 NABARD Phase XI GoB 48.37 0.00 0.00 0.00 0.00 0.00 48.37 48.37 0.00 48.37 18.95 5.88 24.83 23.54 7 10 MP/CMLAD 59.78 0.00 0.00 0.00 0.00 0.00 59.78 59.78 0.00 59.78 23.74 7.21 30.95 28.83 11 DepositScheme 25.34 0.00 0.00 0.00 0.00 0.00 25.34 25.34 0.00 25.34 5.07 4.05 9.12 16.22 104.3 104.3 12 ADB GoI 0.00 0.00 0.00 0.00 0.00 104.30 104.30 0.00 20.86 16.69 37.55 66.75 0 0 60.8 13 ACA State Plan GoB 50.49 0.00 0.00 0.00 0.00 0.00 50.49 50.49 0.00 50.49 10.10 8.08 18.18 32.31 9 217. 217.3 217.3 14 Burnt DTR State Plan GoB 0.00 0.00 0.00 0.00 0.00 217.35 217.35 0.00 43.47 34.78 78.25 139.10 37 5 5 861.6 861.6 115.6 399.2 15 State Plan GoB 0.00 0.00 0.00 0.00 0.00 861.64 861.64 0.00 283.65 462.39 4 4 0 5 RSVY 0.29 0.00 0.00 0.00 0.00 0.00 0.29 0.29 0.00 0.29 0.29 0.00 0.29 0.00 4779. 4779.0 4779.0 4779. 1109.1 733.9 1843. 2935.9 Sub Total (A) 0.00 0.00 0.00 0.00 0.00 0.00 03 3 3 03 2 8 10 3
North Bihar Power Distribution Company Limited 199 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19 New Scheme 0.00 0.00 0.00 0.00 CM Seven Resolution 16 GoB 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 (Har Ghar Bijli) 965. 386.3 57.9 173. 579.5 965.9 927.2 965.9 17 IPDS GoI/PFC 347.73 0.00 0.00 965.92 386.37 38.64 0.00 92 7 6 87 5 2 8 2 386.3 57.9 173. 579.5 965.9 927.2 965.9 Sub Total (B) 347.73 0.00 0.00 965.92 386.37 38.64 0.00 7 6 87 5 2 8 2 RGGVY 11th Plan 106 18 REC Phase- I 9.25 RGGVY 11th plan 973. 6365. 6365.1 6365.1 6365. 1570.6 958.8 2529. 3835.5 19 REC 0.00 0.00 0.00 0.00 0.00 0.00 Phase- II 79 10 0 0 10 8 8 56 4 432 20 RGGVY 12th Plan REC/GoB 2.06 6365. 6365.1 6365.1 6365. 1570.6 958.8 2529. 3835.5 Sub Total (C) 0.00 0.00 0.00 0.00 0.00 0.00 10 0 0 10 8 8 56 4 New Scheme 0.00 0.00 0.00 0.00 341 1364. 204. 613. 3411.0 1364.4 2046. 3411. 327.4 463.9 2947.1 21 DDUGJY REC/GoB 1227.99 0.00 0.00 136.44 1.07 43 66 99 7 3 64 07 6 1 6 1364. 204. 613. 3411.0 1364.4 2046. 3411. 327.4 463.9 2947.1 Sub Total (D) 1227.99 0.00 0.00 136.44 43 66 99 7 3 64 07 6 1 6 12894 262. 787. 15521. 12894. 2626. 15521 2854.8 2947. 5802. 9718.6 Sub Total (A+B+C+D) 0 1575.72 0.00 0.00 .93 62 86 12 93 19 .12 8 61 49 3 295.2 295.2 295.2 22 Own Sources Utility 0.00 295.26 295.26 0.00 295.26 0.00 0.00 6 6 6 13190 262. 787. 15816. 13190. 2626. 15816 3150.1 2947. 6097. 9718.6 Grand Total 1575.72 0.00 0.00 .18 62 86 38 18 19 .38 4 61 75 3
North Bihar Power Distribution Company Limited 200 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19 A.20. Annexure – XIII : Revenue at existing tariff for FY 2018-19
Category Consumers Connected Sales Tariff Fixed Energy Total ABR Load (KW) (MU) Charges Charges Revenue (Rs/kWh) Fixed Unit Energy Unit (Crores) (Crores) (Crores) charge Charges Domestic Kutir Jyoti Unmetered 15624 3906.07 43.18 239 Per Connection Per Month 0.00 kWh 4.48 0.00 4.48 1.04 Metered (0-50) 3140800 785199.96 1471.90 10 Per Connection Per Month 2.17 kWh 37.69 319.40 357.09 2.43 Total - KJ 3156424 789106.04 1515.08 42.17 319.40 361.57 2.39 DS-I (Rural) Unmetered 637308 746521.70 597.39 268 Per Connection Per Month 0.00 kWh 204.58 0.00 204.58 3.42 Metered First 50 Units 1776739 2081214.21 928.37 20 Per kW Per Month 2.65 kWh 49.95 246.02 295.97 3.19 51 - 100 Units 214678 251466.66 152.99 20 Per kW Per Month 2.90 kWh 6.04 41.15 47.18 3.08 Above 100 Units 119688 140198.22 544.50 20 Per kW Per Month 3.15 kWh 3.36 166.13 169.50 3.11 Total 2748201 3219153.53 2223.25 263.92 453.30 717.22 3.23 DS-II (Urban- Demand Based) 1-100 U/Month 989788 1326812.47 579.31 40 Per kW Per Month 4.27 kWh 54.13 247.36 301.50 5.20 101 - 200 U/Month 158985 213119.50 444.37 40 Per kW Per Month 5.02 kWh 8.70 208.77 217.46 4.89 201 -300 U/Month 72924 97754.40 345.13 40 Per kW Per Month 5.77 kWh 3.99 179.45 183.44 5.32 above 300 U/Month 75536 102599.30 343.54 40 Per kW Per Month 6.52 kWh 4.19 183.20 187.38 5.45 Total 1297232 1740285.67 1712.35 71.00 818.78 889.78 5.20 Total - Domestic (Other than 4045434 4959439.20 3935.59 334.93 1272.07 1607.00 4.08 KJY) NDS-I (Rural) Unmetered 3377 2117.48 1.31 445 Per Connection Per Month 0.0 kWh 1.80 0.00 1.80 13.76 Metered 1-100 U/Month 78106 90255.39 42.43 30 Per kW Per Month 3.5 kWh 2.76 14.85 17.61 4.15 101 - 200 U/Month 8776 11657.37 21.77 30 Per kW Per Month 4.0 kWh 0.36 8.18 8.54 3.92 above 200 U/Month 11081 14686.56 20.13 30 Per kW Per Month 4.5 kWh 0.45 7.06 7.51 3.73 Total 101339 118716.80 85.64 5.37 30.09 35.47 4.14 NDS-II (Demand Based) Contract Demand < 0.5 kW 7885 11182.02 10.69 100 Per Connection Per Month 5.60 kWh 0.95 5.99 6.94 6.48 Contract Demand > 0.5 kW First 100 Units 182385 476622.73 346.24 180 Per kW Per Month 5.60 kWh 102.95 193.90 296.85 8.57
North Bihar Power Distribution Company Limited 201 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19 101 - 200 Units 20493 61560.50 177.64 180 Per kW Per Month 6.10 kWh 13.30 107.13 120.43 6.78 Above 200 Units 25875 77557.12 164.26 180 Per kW Per Month 6.60 kWh 16.75 103.76 120.51 7.34 Total 236637 626922.37 698.84 133.95 410.77 544.72 7.79 Total - NDS 337976 745639.17 784.48 139.32 440.87 580.19 7.40 IAS-I (Pvt Tubewell) Unmetered 40660 136697.68 160.17 168 Per HP per month 0.00 kWh 36.96 0.00 36.96 2.31 Metered 109487 368094.35 177.89 30 Per HP per month 0.96 kWh 17.77 17.08 34.85 1.96 Total 150147 504792.04 338.06 54.73 17.08 71.80 2.12 IAS-II (State Tubewell) Unmetered 2854 35196.12 99.91 2,100 Per HP per month 0.00 kWh 118.94 0.00 118.94 11.90 Metered 3209 29933.63 84.97 200 Per HP per month 6.20 kWh 9.63 52.68 62.32 7.33 Total 6063 65129.75 184.88 128.57 52.68 181.26 9.80 Total - IAS 156210 569921.79 522.95 183.30 69.76 253.06 4.84 LTIS LTIS-I (Contract Demand < 19 14028 103758.89 270.32 160 Per kW Per Month 5.77 kVAh 16.93 173.30 190.24 7.04 kW) LTIS-II (Contract Demand 19-74 653 36820.11 24.36 200 Per kW Per Month 5.74 kVAh 7.51 15.54 23.05 9.46 kW)) Total - LTIS 14681 140579.00 294.67 24.44 188.84 213.28 7.24 PWW - Public Water Works (Demand Based) PWW 917 20562.93 35.67 350 Per kW Per Month 7.50 kVAh 8.64 29.73 38.37 10.75 Total PWW 917 20562.93 35.67 8.64 29.73 38.37 10.75 Street Light Services SS-Metered 157 1063.91 6.88 50 Per kW Per Month 7.00 kWh 0.05 5.35 5.40 7.86 SS-Unmetered 125 2576.70 9.96 3,750 Per kW Per Month 0.00 kWh 9.86 0.00 9.86 9.90 Total - Street Light 281 3640.61 16.83 9.91 5.35 15.26 9.06 HTS-I (11 kV) 1037 225715.04 434.39 300 Per kVA Per Month 5.98 kVAh 76.74 288.63 365.37 8.41 HTS-II (33 kV) 40 68017.90 149.33 300 Per kVA Per Month 5.76 kVAh 23.13 95.57 118.69 7.95 HTS-III (132 kV) 2 34853.40 65.95 300 Per kVA Per Month 5.66 kVAh 11.85 41.47 53.32 8.09 HTS-IV (220 kV) 0 0.00 0.00 300 Per kVA Per Month 5.49 kVAh 0.00 0.00 0.00 0.00 HTSS (33 / 11 kV) 5 10951.74 66.49 700 Per kVA Per Month 3.37 kVAh 8.69 24.90 33.58 5.05 Total - HTS & HTSS 1084 339538.08 716.15 120.41 450.57 570.97 7.97 RTS (132 kV) 7 54900.00 62.67 280 Per kVA Per Month 6.35 kVAh 17.42 44.22 61.64 9.84 DF 349042 468498.32 1058.00 0.00 4.58 484.56 484.56 4.58 Nepal 1 0.00 1188.89 5.60 665.39 665.39 5.60 Grand Total 8062057 8091825 10131 881 3971 4851.30 4.79
North Bihar Power Distribution Company Limited 202 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
A.21. Proforma- I: Month-wise, Category-Wise energy sales during FY 2015-16
Sl.No. Consumer Category Apr- May- Jun- Jul-15 Aug- Sep- Oct- Nov- Dec- Jan- Feb- Mar- Total Revis Final 15 15 15 15 15 15 15 15 16 16 16 for 15- ed sales 16 Differ after ence revisi on 1 Domestic Kutir Jyoti- BPL 45.20 119.82 43.88 111.07 51.43 63.45 67.78 51.64 45.64 55.95 51.59 99.12 806.56 Consumers 4.61 811.1 7 Domestic-I 69.57 57.53 72.62 72.58 79.97 82.69 79.03 78.82 85.43 90.59 101.78 176.15 1,046. 75 21.02 1,067. 76 Domestic-II 116.80 172.37 88.39 103.91 116.47 115.98 121.57 98.25 75.93 79.80 101.78 122.45 1,313. 70 16.14 1,329. 85 Domestic-III 0.06 0.07 0.05 0.10 0.05 0.08 0.03 0.04 0.09 0.04 0.06 0.03 0.72 (0.02) 0.70 2 Commercial ------Non-Domestic-I 2.96 2.35 3.21 2.81 3.37 2.93 3.13 3.00 3.62 4.02 4.25 6.35 42.02 1.01 43.02 Non-Domestic-II 47.89 43.29 39.36 35.77 37.35 42.08 39.56 39.03 31.53 35.75 44.36 49.71 485.67 3.96 489.6 3 Non-Domestic-III 0.06 0.05 0.06 0.07 0.06 0.06 0.13 0.03 0.09 0.11 0.06 0.07 0.85 (0.01) 0.84 3 Public Lighting ------StreetLight-I 0.72 0.72 0.53 0.88 0.59 0.73 0.67 0.50 0.54 0.30 0.32 2.43 8.92 1.63 10.55 StreetLight-II 0.36 0.09 7.71 0.48 0.17 0.17 0.17 0.17 0.21 0.21 0.45 0.25 10.45 (0.09) 10.36 4 Irrigation ------IAS-I 0.82 0.94 0.62 0.73 0.78 0.73 0.69 0.61 1.02 1.13 0.74 8.29 17.08 7.10 24.19 IAS-II 8.05 7.96 8.00 7.50 7.45 9.43 7.06 6.78 7.36 7.87 7.89 20.75 106.09 0.60 106.6 9 5 Public Water Works 2.05 2.09 2.07 1.94 2.43 2.03 2.00 1.80 1.78 1.97 3.04 3.01 26.21 0.21 26.43
North Bihar Power Distribution Company Limited 203 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19 6 Industrial LT ------LTIS-I 7.48 6.38 6.79 6.28 5.97 6.40 6.13 6.57 6.59 6.76 7.01 12.60 0.70 0.70 85.65 LTIS-II 3.92 3.93 3.64 5.75 3.68 3.88 3.16 3.00 3.03 3.06 4.61 4.41 0.97 0.97 47.06 7 Industrial HT ------HTS-I 19.32 24.82 20.43 19.71 19.65 28.02 21.47 24.61 16.45 17.39 17.32 17.70 3.71 250.6 3.71 0 HTS-II 7.56 7.69 7.88 8.22 7.08 6.92 7.91 6.86 5.28 6.95 7.59 7.15 0.50 0.50 87.59 HTS-III 4.67 4.62 4.34 4.62 4.62 3.66 5.90 4.40 5.42 5.38 26.82 4.96 1.01 1.01 80.42 HTSS 1.81 0.86 1.77 1.78 2.90 0.68 0.84 0.89 0.70 0.65 1.92 0.87 (0.86) (0.86) 14.80 8 Railway 2.19 1.28 1.90 1.91 1.94 1.99 1.84 1.95 1.99 1.50 1.94 1.93 22.37 (0.12) 22.26 9 Nepal 96.72 87.62 96.95 106.96 101.07 95.96 68.82 74.45 127.88 125.96 115.21 123.43 1,221. 02 - 1,221. 02 10 UI - - 28.06 12.95 1.47 1.72 15.12 4.26 3.19 1.76 9.10 - 77.64 - 77.64 11 DF 47.97 54.90 56.71 61.40 64.31 62.90 61.81 55.27 56.58 58.62 59.31 57.01 696.79 - 696.7 9 Total 486.18 599.37 494.96 567.41 512.78 532.48 514.84 462.95 480.35 505.80 567.15 718.67 6,442. 95 62.08 6,505. 03
North Bihar Power Distribution Company Limited 204 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
A.22. Proforma-II: Month-wise, Category-Wise energy sales during FY 2016-17
Sl.No Consumer Category Apr- May- Jun- Jul-16 Aug- Sep- Oct- Nov- Dec- Jan- Feb- Mar- Total . 16 16 16 16 16 16 16 16 17 17 17 1 Domestic Kutir Jyoti- BPL 57.40 71.63 69.75 72.81 58.20 54.78 47.96 39.06 37.52 81.11 184.88 73.59 848.69 Consumers Domestic - I 108.65 94.62 105.72 154.06 101.08 112.13 96.86 108.06 165.35 135.69 223.55 116.53 1,522.2 9 Domestic - II 113.90 113.65 112.93 112.35 108.63 112.53 82.10 71.93 100.80 112.81 39.70 114.38 1,195.7 1 Domestic - III 0.09 0.02 0.03 0.02 0.03 0.04 0.02 0.03 0.03 0.03 0.01 0.01 0.35 2 Commercial ------Non-Domestic - I 4.38 3.50 3.98 5.44 8.54 3.38 4.23 6.92 8.44 5.26 9.57 4.05 67.70 Non-Domestic - II 54.57 58.28 169.28 (57.02 108.93 38.29 50.05 50.26 44.44 41.86 41.33 33.36 633.64 ) Non-Domestic - III 0.06 0.06 0.18 0.13 0.11 0.10 2.31 0.85 0.86 0.07 0.07 0.05 4.87 Non-Domestic - IV - - - 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 - 3 Public Lighting ------Street Light - I 0.41 0.69 0.41 0.11 0.77 0.13 1.69 0.36 0.34 1.16 0.08 0.10 6.25 Street Light - II 1.21 1.06 0.56 0.62 0.36 0.42 0.58 0.77 0.57 1.09 0.65 1.12 9.02 4 Irrigation ------IAS - I 0.88 0.51 0.63 0.60 0.70 0.56 0.73 0.67 0.58 0.51 0.51 0.52 7.41 IAS - II 10.15 10.00 8.30 9.18 10.48 8.32 14.36 8.90 30.70 13.21 24.49 4.71 152.80 5 Public Water Works 2.55 2.36 1.97 2.20 2.62 2.36 2.17 1.89 2.99 3.89 2.68 2.47 30.16 6 Industrial LT LTIS - I 9.51 8.96 10.83 10.94 9.57 11.66 11.62 11.14 13.15 13.87 17.13 17.02 145.40 LTIS - II 1.74 2.42 (0.05) 1.40 1.74 1.72 1.21 1.45 1.46 1.28 1.93 1.64 17.94 7 Industrial HT ------HTS - I 23.03 24.45 24.21 24.15 23.79 23.84 23.12 22.76 19.98 20.37 20.04 19.69 269.42 HTS - II 8.06 6.85 7.42 8.13 7.67 10.82 7.43 7.52 6.69 7.66 7.71 7.28 93.24 HTS - III 5.69 6.01 6.83 6.15 4.32 4.41 5.29 6.00 6.59 6.21 5.29 3.20 65.98 HTSS 2.90 4.63 3.91 4.06 4.10 3.30 3.25 3.53 3.15 3.90 4.95 3.90 45.59
North Bihar Power Distribution Company Limited 205 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19 8 Railway 3.27 3.93 3.20 3.90 3.47 3.95 5.81 7.16 7.71 6.82 7.19 6.27 62.68 9 Nepal 127.63 114.73 95.76 97.23 101.67 78.05 75.75 45.73 104.45 116.06 114.88 116.95 1,188.8 9 10 UI - 0.00 6.21 14.28 3.78 0.48 17.40 8.50 5.35 6.21 0.00 15.13 77.35 11 DF 62.55 62.84 73.48 70.60 72.95 67.20 68.15 55.39 55.00 56.43 49.11 56.17 749.87 Total 598.62 591.22 705.53 541.35 633.52 538.47 522.11 458.88 616.15 635.52 755.77 598.13 7,195.2 6
North Bihar Power Distribution Company Limited 206 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
A.23. Proforma-III: Month-wise, Category-Wise energy sales during FY 2017-18
Sl.No. Consumer Category Apr-17 May-17 Jun-17 Jul-17 Aug-17 Sep-17 A Domestic 1 Kutir Jyoti KJ rural(Unmetered) 1.29 1.66 1.58 1.62 1.79 2.01 KJ rural(metered) ------First 30 units 12.32 15.80 15.06 15.44 17.03 19.14 31-50 units 5.55 7.12 6.79 6.96 7.68 8.63 51 - 100 Units 8.80 11.29 10.76 11.03 12.17 13.68 KJ urban(metered) ------First 30 units 5.95 7.63 7.28 7.46 8.23 9.25 31-50 3.15 4.04 3.85 3.95 4.36 4.90 51 - 100 U/Month 3.28 4.21 4.02 4.12 4.54 5.10 SubTotal ------2 DS-I ------Unmetered 28.98 37.17 35.43 36.33 40.08 45.03 Metered ------First 50 Units 43.11 55.31 52.72 54.05 59.63 67.00 51 - 100 Units 14.01 17.97 17.13 17.56 19.37 21.76 Above 100 Units 55.64 71.38 68.04 69.75 76.96 86.46 SubTotal ------3 DS - ll ------Single Phase ------1-100 U/Month ------101 - 200 U/Month ------201 -300 U/Month ------above 300 U/Month ------Three Phase ------1-100 U/Month ------101 - 200 U/Month ------201 -300 U/Month ------above 300 U/Month ------SubTotal ------4 DS-II(Demand Based) ------Single Phase ------
North Bihar Power Distribution Company Limited 207 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19 1-100 U/Month 25.56 32.79 31.25 32.04 35.35 39.72 101 - 200 U/Month 18.31 23.49 22.39 22.96 25.33 28.46 201 -300 U/Month 11.34 14.55 13.87 14.22 15.69 17.63 above 300 U/Month 71.35 91.53 87.24 89.44 98.68 110.87 Three Phase ------1-100 U/Month 0.00 0.00 0.00 0.00 0.00 0.01 101 - 200 U/Month 0.04 0.06 0.05 0.05 0.06 0.07 201 -300 U/Month 0.03 0.04 0.04 0.04 0.05 0.05 above 300 U/Month 0.29 0.37 0.35 0.36 0.40 0.45 SubTotal ------5 DS-III ------6 DS-III (Demand based) ------B NON-DOMESTIC SERVICES ------1 NDS - I ------Unmetered 0.67 0.87 0.83 0.85 0.93 1.05 Metered ------1-100 U/Month 1.72 2.21 2.11 2.16 2.38 2.68 101 - 200 U/Month 0.66 0.84 0.80 0.82 0.91 1.02 above 200 U/Month 3.10 3.98 3.79 3.89 4.29 4.82 2 NDS - II - Single phase ------upto 0.5 kW ------1-100U/m ------101-200 U/m ------above 200 U/m ------above 0.5kW ------1-100U/m ------101-200 U/m ------above 200 U/m ------3 NDS - II(D)-Single Phase ------1-100U/m 2.34 3.00 2.86 2.93 3.23 3.63 101-200 U/m 1.20 1.54 1.46 1.50 1.66 1.86 above 200 U/m 4.75 6.09 5.80 5.95 6.56 7.38 4 NDS - II(D)-Three Phase ------1-100U/m 1.93 2.47 2.36 2.42 2.67 3.00 101-200 U/m 1.46 1.87 1.78 1.83 2.01 2.26 above 200 U/m 36.15 46.37 44.20 45.31 49.99 56.17 5 NDS-III -Single Phase ------1-100U/M ------101-200U/M ------
North Bihar Power Distribution Company Limited 208 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19 Above 200U/M ------6 NDS-III(D)- Single phase ------1-100U/M ------101-200U/M ------Above 200U/M ------7 NDS-III(D)- Three phase ------1-100U/M ------101-200U/M ------Above 200U/M ------8 NDS-IV ------Single phase ------Three phase ------C Street Light Services ------1 SS-I GP 0.12 0.15 0.15 0.15 0.17 0.19 2 SS-I NP/NAC/M ------3 SS-I MC ------4 SS-II GP ------5 SS-II NP/NAC/M ------6 SS-II MC ------SubTotal ------D IAS ------1 IAS-I Unmetered Rural 0.28 0.35 0.34 0.35 0.38 0.43 2 IAS-I Unmetered Urban 0.01 0.02 0.02 0.02 0.02 0.02 3 IAS-I Metered Rural 0.32 0.41 0.39 0.40 0.44 0.50 4 IAS-I Metered Urban 0.33 0.43 0.41 0.42 0.46 0.52 5 IAS-II Unmetered Rural 4.30 5.52 5.26 5.39 5.95 6.69 6 IAS-II Unmetered Urban 1.36 1.74 1.66 1.70 1.88 2.11 7 IAS-II Metered Rural 4.72 6.05 5.77 5.91 6.52 7.33 8 IAS-II Metered Urban 2.23 2.86 2.73 2.80 3.08 3.47 SubTotal ------E PWW 1.61 2.06 1.97 2.02 2.23 2.50 ------F Low tension industrial ------1 LTIS-I ------2 LTIS-I (D) 13.55 17.38 16.56 16.98 18.73 21.05 3 LTIS-II ------4 LTIS-II (D) 1.97 2.53 2.41 2.47 2.73 3.07 SubTotal ------G High Tension Supply ------1 HTS - I 16.35 20.97 19.99 20.49 22.61 25.40
North Bihar Power Distribution Company Limited 209 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19 2 HTS - II 6.46 8.29 7.90 8.10 8.94 10.04 3 HTS - III ------4 HTS - IV ------5 HTSS 1.87 2.41 2.29 2.35 2.59 2.91 SubTotal ------H Railways ------1 RTS (132kV) 7.45 9.56 9.11 9.34 10.31 11.58 2 RTS (25kV) ------SubTotal ------I DF ------J Nepal 116.95 116.44 89.33 71.76 69.52 76.62 K Other bilateral sales(Please specify) ------Grand Total 542.88 662.86 610.14 605.71 658.61 738.50
North Bihar Power Distribution Company Limited 210 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
A.24. Proforma- IV: Month-wise, Station/source-Wise energy procurement during FY 2015-16
Sr. No Source Units Purchased (MU) Apr'15 May'15 Jun'15 Jul'15 Aug'15 Sept'15 Oct'15 Nov'15 Dec'15 Jan'16 Feb'16 Mar'16 1 Central Sector Stations 2 NTPC Stations 3 Farakka 1&2 134.8 114.9 104.6 103.4 100.2 86.8 85.3 120.7 135.8 134.7 118.6 70.8 4 Farakka 3 4.4 18.9 25.3 21.8 26.4 33.6 49.5 44.8 51.8 57.7 52.0 35.7 5 Kahalgoan 1 70.2 83.7 66.3 82.9 87.0 81.6 89.3 93.0 101.8 91.7 74.5 78.3 6 Kahalgoan 2 20.1 17.4 17.7 13.0 14.8 19.3 17.9 19.0 25.6 23.1 23.4 23.2 7 Talchar 106.3 106.2 103.0 106.8 107.4 50.5 88.8 114.3 120.5 112.0 112.7 123.5 8 Dadri-1 42.2 37.1 38.7 33.7 34.8 0.0 0.0 0.0 0.0 0.0 0.0 0.0 9 Korba 0.0 0.0 0.0 0.0 0.0 6.0 20.5 21.0 20.9 23.0 20.5 22.7 10 Barh-2 58.7 116.7 115.9 113.5 120.9 125.3 122.1 114.8 124.9 134.8 150.7 256.8 11 NHPC Stations 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 12 Rangit 1.1 1.3 4.6 5.7 5.9 5.2 5.6 3.8 2.7 2.2 1.8 2.0 13 Teesta 5.4 7.9 21.3 32.4 30.0 28.9 21.0 13.1 9.8 8.1 7.6 11.6 14 PTC Stations 0.0 0.0 0.0 0.0 15 Chukka 17.0 18.0 26.0 33.4 32.5 31.5 24.3 12.3 7.1 4.8 2.4 4.1 16 Tala 7.6 24.7 44.0 70.1 70.6 65.2 32.7 13.1 4.1 0.5 0.0 0.8 17 IEX(JPL) 0.0 0.0 0.0 0.0 2.8 10.1 0.0 0.0 0.0 0.0 0.0 0.0 18 IEX(JSPL) 0.0 0.0 0.0 0.0 2.2 5.2 0.0 0.0 0.0 0.0 0.0 0.0 19 State Generating Stations 20 KBUNL Stage 1 U# 1 20.6 34.8 28.2 23.5 18.4 8.9 16.2 16.2 30.1 29.2 31.6 23.0 & 2 21 Medium/ Short Term/ 0.0 0.0 0.0 0.0 Others 22 Adani 44.3 55.3 53.4 32.4 30.2 52.5 86.2 68.8 42.9 52.9 25.4 0.0 23 GMR 50.2 47.7 48.3 55.9 44.3 43.2 63.2 70.1 67.0 61.4 62.3 82.3 24 NEA 0.0 0.0 4.3 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 25 IEX/PXIL 22.7 14.6 35.8 39.4 53.6 117.9 110.6 87.3 146.7 167.9 122.4 111.1 26 Open Market 0.0 0.0 0.0 0.0 2.1 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Purchase 27 UI 12.9 6.4 4.3 3.5 10.5 10.1 0.0 3.2 5.5 1.8 8.5 13.3 28 PVVNL 0.0 0.0 0.0 0.1 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 29 Renewable Power 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Purchase
North Bihar Power Distribution Company Limited 211 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19 30 BSHPC 0.0 0.0 1.1 2.0 1.7 2.0 2.0 0.3 0.2 1.4 1.4 1.0 31 Sugar Mills 6.2 2.0 0.0 0.0 0.0 0.0 0.0 1.2 11.3 13.6 13.5 9.7 32 Solar Power 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.2 0.6 0.7 0.7 0.8 Purchase 33 PGCIL Charges 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 34 BSPTCL Charges 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 35 SLDC Charges 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 36 Posoco Charges 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 37 Total Power Purchase 624.5 707.7 742.9 773.4 796.4 783.9 835.3 817.1 909.2 921.6 829.9 870.9
North Bihar Power Distribution Company Limited 212 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
A.25. Proforma-V: Month-wise, Station/source-Wise energy procurement during FY 2016-17
Sr. No Source Units Purchased (MU) Apr'15 May'15 Jun'15 Jul'15 Aug'15 Sept'15 Oct'15 Nov'15 Dec'15 Jan'16 Feb'16 Mar'16 1 Central Sector Stations 512.6 647.5 680.5 748.3 771.7 596.0 697.5 592.4 638.8 688.4 607.8 634.4 2 Talcher – I ( 2 x 500 MW) 110.1 110.5 105.3 112.0 110.9 106.5 94.4 81.8 66.6 119.3 95.1 104.4 3 Farakka – I & II (1600 MW) 45.9 102.4 126.9 118.2 127.3 117.8 120.2 121.2 137.0 142.4 126.7 114.5 4 Farakka – III (500 MW) 50.9 51.3 48.4 45.7 46.9 26.4 27.6 28.2 32.0 30.9 25.5 27.2 5 Kahalgaon – I (840 MW) 83.1 81.3 81.3 83.1 84.4 66.3 87.1 82.6 96.6 93.9 87.3 96.8 6 Kahalgaon – II (1500 MW) 25.8 17.1 18.4 13.0 23.9 19.3 19.6 18.5 22.6 13.9 18.0 20.9 7 Barh-II 138.4 210.8 188.7 213.4 214.1 117.2 213.2 198.7 249.9 270.1 243.9 249.7 8 Korba 21.1 21.2 21.1 21.6 21.6 ------9 Rangit – HEP 1.9 3.4 5.2 5.7 6.3 5.9 6.4 4.3 2.8 2.2 1.7 1.9 10 Teesta - HEP 18.8 22.5 26.7 30.7 29.0 31.6 29.6 13.9 9.8 7.4 6.3 10.5 11 Chukka 11.8 12.6 23.8 37.4 37.6 36.8 44.1 22.9 12.4 6.1 2.6 5.4 12 Tala 4.8 14.3 34.8 67.5 69.7 68.1 55.4 20.4 8.9 2.4 0.7 3.0 13 Barh Stage I 14 State Generating Stations 42.5 44.4 36.7 32.4 20.2 14.2 29.4 31.2 24.6 30.3 10.6 23.8 15 KBUNL 1 42.5 44.2 36.4 31.7 19.3 13.2 25.1 22.4 11.9 12.4 4.2 16.2 16 KBUNL 2 17 Small Hydro (BSHPCL) - 0.1 0.2 0.7 0.9 1.0 0.8 0.1 0.1 0.5 0.6 0.1 18 Barauni Stage I ------3.5 8.6 12.6 17.4 5.9 7.5 19 Barauni Stage II 20 IPP 72.7 66.7 77.3 72.4 35.1 67.4 80.1 75.6 49.0 70.1 71.3 80.1 21 GMR Kamalanga Energy 67.2 64.8 77.3 72.4 35.1 67.4 80.1 75.6 49.0 70.1 71.3 80.1 22 Adani Enterprises Limited 5.6 1.9 ------23 JV projects ------24 Nabinagar Railway (4 X 250 Mw) 25 Nabinagar Stage-I (3 X 660 26 Nabinagar JV (3 X 660 MW) Stage-II 27 Renewable 4.3 3.9 0.8 1.2 2.3 2.7 3.6 4.6 16.1 19.2 21.7 19.4 28 SECI 0.8 0.9 0.8 0.7 0.4 0.7 0.7 0.7 0.8 0.7 0.8 0.8 29 ACME Magadh - - 0.0 0.3 0.4 0.4 0.6 0.5 0.5 0.6 0.6 0.6 30 ACME Nalanda - - (0.0) 0.3 0.6 0.5 0.7 0.7 0.6 0.8 0.8 0.8 31 Sunmark ------0.0 0.3 0.5 0.6 0.6 32 Avantika 0.2 0.2 0.1 0.1 0.2 0.2 0.3 0.2 0.1 0.2 0.2 0.2 33 AZURE - - - 0.0 0.4 0.4 0.5 0.5 0.3 0.4 0.5 0.6 34 Udipta Energy & Equipment Pvt ltd ------0.0 0.1 0.1
North Bihar Power Distribution Company Limited 213 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19 35 Glatt ------0.0 36 Welspun 2 - - - 0.0 0.3 0.4 0.6 0.5 0.4 0.7 0.8 1.0 37 Welspun 1 - - - 0.0 0.0 0.1 0.2 0.2 0.3 0.5 0.5 0.6 38 Alpha Infraprop 39 Welspun 3 - - - 0.0 0.2 0.3 0.4 0.4 0.5 0.7 0.8 1.0 40 Response Renewable energy 41 New Swadeshi Sugar (0.0) (0.1) (0.1) (0.1) (0.1) (0.1) (0.2) 0.1 1.3 1.3 1.3 0.9 Mill,Narkatiaganj 42 Harinagar Sugar Mills,Harinagar 2.9 3.0 (0.0) (0.0) (0.2) (0.1) (0.1) 0.9 3.8 3.8 3.3 3.4 43 Bharat (0.0) (0.0) (0.0) (0.0) (0.0) (0.0) (0.0) (0.1) 3.3 3.2 3.0 3.6 SugarMills,SidhiwaliaGopalganj 44 Lauriya Sugar Mill (0.0) (0.0) (0.0) (0.0) (0.0) (0.0) (0.0) (0.1) 2.0 2.8 3.6 2.4 45 Sugauli Sugar Mill (0.0) (0.0) (0.0) (0.0) (0.0) (0.0) (0.0) (0.0) 0.6 1.4 3.0 1.6 46 Hasanpur Sugar Mills,Samastipur 0.4 (0.0) (0.0) (0.0) (0.0) (0.0) (0.0) (0.0) 0.8 1.1 1.0 0.1 47 Riga Sugar Company (0.0) (0.0) - (0.0) (0.0) (0.0) (0.0) (0.0) 0.3 0.2 0.3 0.0 Ltd,Sitamarhi 48 Siddhashram Rice Mill Cluster Pvt ------0.0 0.3 0.3 0.3 0.2 Ltd 49 BDBPL ------0.4 0.7 50 Open Market Purchase 216.0 80.8 79.5 45.3 95.1 184.2 112.7 108.7 104.4 63.2 60.7 85.6 51 IEX/PXIL 191.0 91.5 44.1 21.5 43.0 123.6 65.2 65.0 63.3 33.5 29.8 38.4 52 DB Power - - 25.2 - 27.4 - - 28.8 - - - - 53 JAYPEE NIGRIE - - - - 22.1 - 22.2 - 15.8 14.6 12.2 13.9 54 JPL ------3.9 3.9 3.5 - 55 GMR ETL - - 6.4 31.3 - 53.7 ------56 TATA ETL - - - 9.1 - - 40.4 19.6 11.8 3.9 - - 57 Manikaran Power 58 NEA ------0.0 0.0 - - - - 59 NVVNL ------4.0 4.0 3.6 15.8 60 PVVNL 0.0 0.0 0.0 0.0 0.1 0.0 0.0 0.0 0.0 0.1 0.1 0.1 61 Adani Short Term 62 UI 25.0 (10.7) 3.7 (16.6) 2.6 6.8 (15.1) (4.7) 5.5 3.2 11.6 17.5 63 Total Power Purchase 848.0 843.3 874.6 899.7 924.3 864.4 923.3 812.5 832.9 871.3 772.3 843.2
North Bihar Power Distribution Company Limited 214 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
A.26. Proforma-VI: Month-wise, Station/source-Wise energy procurement during FY 2017-18
Name of The Source Apr-15 May-15 Jun-15 Jul-15 Aug-15 Sep-15 Oct-15 Nov-15 Dec-15 Jan-16 Feb-16 Mar-16 Total
8,844.8 Central Sector Stations 601.45 646.98 699.97 712.32 691.25 619.19 890.64 792.24 828.92 843.46 733.88 784.52 2 Talcher – I ( 2 x 500 MW) 93.81 92.46 105.16 106.69 113.50 111.66 121.16 117.25 121.16 137.16 109.44 117.25 1346.71 Farakka – I & II (1600 MW) 71.01 107.71 113.47 105.12 94.27 99.48 148.01 143.24 157.60 163.71 140.64 143.24 1487.50 Farakka – III (500 MW) 26.09 23.86 22.60 20.47 20.41 21.50 31.88 32.59 36.98 35.69 28.42 30.40 330.89 Kahalgaon – I (840 MW) 88.24 87.41 71.29 82.77 87.73 85.88 103.24 99.91 111.13 107.97 96.95 107.73 1130.23 Kahalgaon – II (1500 MW) 20.06 24.54 27.59 21.75 26.32 16.00 22.51 21.28 26.00 21.73 20.01 23.29 271.07 Barh-II 258.11 251.27 270.18 229.06 203.76 149.77 308.07 298.13 308.07 310.57 278.25 298.13 3163.36 Korba 0.00 0.00 0.00 0.00 0.00 0.95 0.00 0.00 0.00 0.00 0.00 0.00 0.95 Rangit – HEP 2.67 3.42 5.29 6.08 6.00 6.07 7.32 4.89 3.56 3.56 3.21 3.44 55.52 Teesta - HEP 19.00 22.85 29.59 31.51 31.26 32.23 34.03 16.79 17.35 17.35 15.67 16.79 284.42 Chukha 15.85 15.39 22.57 39.11 37.94 34.60 50.68 26.37 14.23 12.87 11.62 12.45 293.69 Tala 6.61 18.09 32.24 69.77 70.04 61.05 63.74 31.79 32.85 32.85 29.67 31.79 480.48 Barh Stage-I (3 X 660 MW) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 State Generating Stations 22.80 32.54 31.21 30.17 50.29 72.25 66.26 82.32 89.29 94.77 81.17 89.01 742.07 KBUNL 1 2.79 28.29 30.74 11.84 11.87 37.77 30.12 29.15 30.12 30.12 27.20 29.15 299.15 KBUNL 2 11.44 0.00 0.00 17.48 38.00 34.18 36.14 34.97 36.14 36.14 32.64 34.97 312.11 Small Hydro (BSHPCL) -0.01 -0.01 0.47 0.85 0.43 0.29 0.00 0.00 0.00 0.00 0.00 0.00 2.01 Barauni Stage I 8.58 4.26 0.00 0.00 0.00 0.00 0.00 9.92 14.47 19.96 13.60 16.61 87.40 Barauni Stage II 0.00 0.00 0.00 0.00 0.00 0.00 0.00 8.28 8.56 8.56 7.73 8.28 41.40 IPP 63.28 55.66 58.73 67.87 58.65 40.35 92.12 86.95 75.64 80.60 79.22 89.09 848.15 GMR Kamalanga Energy 63.28 55.66 58.73 67.87 58.65 40.35 92.12 86.95 75.64 80.60 79.22 89.09 848.15 Adani Enterprises Limited 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 JV projects 0.00 0.00 0.00 0.00 4.56 5.50 7.27 7.04 14.55 14.55 13.14 14.08 80.67 Nabinagar Railway (4 X 250 Mw) 0.00 0.00 0.00 0.00 4.56 5.50 7.27 7.04 14.55 14.55 13.14 14.08 80.67 Nabinagar Stage-I (3 X 660 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
North Bihar Power Distribution Company Limited 215 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19 Nabinagar JV (3 X 660 MW) Stage-II 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Renewable 7.64 6.54 7.40 4.45 4.74 5.00 23.42 22.72 29.19 29.23 27.23 28.91 196.46 SECI 0.78 0.81 0.75 0.47 0.54 0.61 0.80 0.82 0.88 0.84 0.83 0.93 9.07 ACME Magadh 0.55 0.58 0.55 0.44 0.54 0.55 0.65 0.63 0.65 0.69 0.67 0.67 7.17 ACME Nalanda 0.78 0.72 0.78 0.62 0.75 0.77 0.98 0.94 0.98 0.98 0.93 0.94 10.17 Sunmark 0.50 0.62 0.59 0.40 0.52 0.57 0.65 0.63 0.65 0.65 0.67 0.69 7.14 Avantika 0.17 0.17 0.19 0.20 0.05 0.00 0.33 0.31 0.33 0.33 0.29 0.31 2.67 AZURE 0.50 0.56 0.56 0.44 0.03 0.00 0.65 0.63 0.65 0.65 0.59 0.64 5.90 Udipta Energy & Equipment Pvt ltd 0.13 0.18 0.18 0.13 0.15 0.15 0.33 0.31 0.33 0.33 0.29 0.31 2.81 Glatt 0.09 0.04 0.04 0.03 0.03 0.06 0.20 0.19 0.20 0.20 0.18 0.19 1.42 Welspun 2 0.78 0.90 0.84 0.55 0.72 0.80 0.98 0.94 0.98 0.98 0.88 1.07 10.41 Welspun 1 0.54 0.61 0.56 0.37 0.47 0.33 0.65 0.63 0.65 0.65 0.59 0.70 6.75 Alpha Infra pop 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 1.30 1.30 1.17 1.26 5.03 Welspun 3 0.83 0.94 0.86 0.58 0.69 0.51 0.98 0.94 0.98 0.98 0.91 1.09 10.27 Response 0.00 0.00 0.07 0.12 0.25 0.47 0.65 0.63 0.65 0.65 0.59 0.63 4.71 New Swadeshi Sugar Mill,Narkatiaganj 0.00 0.00 0.00 0.00 0.00 0.00 1.27 1.23 1.45 1.47 1.40 1.23 8.05 Harinagar Sugar Mills,Harinagar 1.45 0.20 1.30 0.00 0.00 0.07 2.00 1.93 4.32 4.34 3.72 3.83 23.16 Bharat SugarMills,SidhiwaliaGopa lganj 0.35 0.00 0.00 0.00 0.00 0.00 2.00 1.93 3.74 3.72 3.28 4.06 19.08 Lauriya Sugar Mill 0.00 0.00 0.00 0.00 0.00 0.00 3.63 3.51 3.63 3.63 4.03 3.51 21.94 Sugauli Sugar Mill 0.00 0.00 0.00 0.00 0.00 0.00 3.63 3.51 3.63 3.63 3.30 3.51 21.20 Hasanpur Sugar Mills,Samastipur 0.00 0.00 0.00 0.00 0.00 0.00 1.81 1.76 1.81 1.81 1.64 1.76 10.59 Riga Sugar Company Ltd,Sitamarhi 0.00 0.00 0.00 0.00 0.00 0.00 0.54 0.53 0.54 0.54 0.49 0.53 3.18 Siddhashram Rice Mill Cluster Pvt Ltd 0.17 0.22 0.14 0.09 0.00 0.11 0.18 0.18 0.32 0.34 0.29 0.24 2.27 BDBPL 0.00 0.00 0.00 0.00 0.00 0.00 0.54 0.53 0.54 0.54 0.49 0.81 3.46 Open Market Purchase 141.28 203.44 216.23 151.77 205.67 349.46 0.00 0.00 0.00 0.00 0.00 0.00 1267.85 IEX/PXIL 89.87 99.12 106.72 63.65 141.38 281.37 0.00 0.00 0.00 0.00 0.00 0.00 782.11
North Bihar Power Distribution Company Limited 216 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19 DB Power 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 JAYPEE NIGRIE 30.28 31.16 29.22 25.79 0.00 1.35 0.00 0.00 0.00 0.00 0.00 0.00 117.81 JPL 7.11 3.38 3.16 6.63 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 20.28 GMR ETL 6.76 0.00 0.00 0.00 0.00 1.25 0.00 0.00 0.00 0.00 0.00 0.00 8.01 TATA ETL 0.00 5.04 9.43 5.76 3.72 12.80 0.00 0.00 0.00 0.00 0.00 0.00 36.74 Manikaran Power 0.00 47.66 45.44 46.19 46.76 46.22 0.00 0.00 0.00 0.00 0.00 0.00 232.27 NEA 0.00 0.00 0.01 0.09 0.01 0.38 0.00 0.00 0.00 0.00 0.00 0.00 0.48 NVVNL 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 PVVNL 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Adani Short Term 0.00 0.00 0.00 0.00 0.00 9.07 0.00 0.00 0.00 0.00 0.00 0.00 9.07 Net UI 7.26 17.09 22.24 3.67 13.81 -2.98 0.00 0.00 0.00 0.00 0.00 0.00 61.09 11980.0 Sub Total Power Purchase 836.45 945.16 1013.53 966.58 1015.17 1091.75 1079.71 991.27 1037.57 1062.60 934.64 1005.60 3 Transmission charges 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 PGCIL Losses 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 POSOCO Charges 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 BSPTCL charges 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 BGCL Charges 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 11980.0 Total Power Purchase 836.45 945.16 1013.53 966.58 1015.17 1091.75 1079.71 991.27 1037.57 1062.60 934.64 1005.60 3
North Bihar Power Distribution Company Limited 217 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
A.27. Proforma- VII: Month-wise, Station/source-Wise energy procurement during FY 2018-19
Name of The Source Apr-15 May-15 Jun-15 Jul-15 Aug-15 Sep-15 Oct-15 Nov-15 Dec-15 Jan-16 Feb-16 Mar-16 Total
10,351.3 Central Sector Stations 780.05 813.17 806.21 885.73 889.19 843.91 890.64 792.24 828.92 992.69 868.67 959.90 2 Talcher – I ( 2 x 500 MW) 117.25 121.16 117.25 121.16 121.16 117.25 121.16 117.25 121.16 137.16 109.44 121.16 1442.58 Farakka – I & II (1600 MW) 143.24 148.01 143.24 148.01 148.01 143.24 148.01 143.24 157.60 163.71 140.64 148.01 1774.96 Farakka – III (500 MW) 30.40 31.42 30.40 31.42 31.42 30.40 31.88 32.59 36.98 35.69 28.42 31.42 382.44 Kahalgaon – I (840 MW) 99.91 103.24 99.91 103.24 103.24 99.91 103.24 99.91 111.13 107.97 96.95 111.32 1239.97 Kahalgaon – II (1500 MW) 21.03 25.35 27.59 22.48 27.20 21.03 22.51 21.28 26.00 21.73 20.01 24.07 280.26 Barh-II 298.13 308.07 298.13 308.07 308.07 298.13 308.07 298.13 308.07 310.57 278.25 308.07 3629.75 Korba 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Rangit – HEP 3.44 3.56 5.29 6.29 6.20 6.07 7.32 4.89 3.56 3.56 3.21 3.56 56.95 Teesta - HEP 19.00 23.61 29.59 32.56 32.31 32.23 34.03 16.79 17.35 17.35 15.67 17.35 287.83 Chukha 15.85 15.91 22.57 40.41 39.20 34.60 50.68 26.37 14.23 12.87 11.62 12.87 297.19 Tala 31.79 32.85 32.24 72.09 72.38 61.05 63.74 31.79 32.85 32.85 29.67 32.85 526.14 Barh Stage-I (3 X 660 MW) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 149.23 134.79 149.23 433.26 State Generating Stations 126.39 130.60 127.98 130.77 134.07 135.35 130.94 126.72 130.94 140.74 118.27 130.94 1563.69 KBUNL 1 29.15 30.12 30.74 30.12 30.12 37.77 30.12 29.15 30.12 30.12 27.20 30.12 364.83 KBUNL 2 34.97 36.14 34.97 36.14 39.26 34.97 36.14 34.97 36.14 36.14 32.64 36.14 428.65 Small Hydro (BSHPCL) 0.00 0.00 0.00 0.17 0.34 0.33 0.34 0.33 0.34 0.34 0.31 0.34 2.85 Barauni Stage I 29.15 30.12 29.15 30.12 30.12 29.15 30.12 29.15 30.12 39.91 27.20 30.12 364.40 Barauni Stage II 33.12 34.22 33.12 34.22 34.22 33.12 34.22 33.12 34.22 34.22 30.91 34.22 402.96 IPP 73.20 75.64 73.20 75.64 75.64 73.20 92.12 86.95 75.64 80.60 79.22 92.06 953.08 GMR Kamalanga Energy 73.20 75.64 73.20 75.64 75.64 73.20 92.12 86.95 75.64 80.60 79.22 92.06 953.08 Adani Enterprises Limited 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 JV projects 14.08 14.55 14.08 21.82 21.82 21.11 21.82 21.11 21.82 29.09 122.29 135.39 458.96 Nabinagar Railway (4 X 250Mw) 14.08 14.55 14.08 21.82 21.82 21.11 21.82 21.11 21.82 29.09 26.28 29.09 256.65 Nabinagar Stage-I (3 X 660 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 96.01 106.30 202.31
North Bihar Power Distribution Company Limited 218 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19 Nabinagar JV (3 X 660 MW) Stage-II 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Renewable 23.93 22.77 23.90 24.57 24.57 23.78 24.72 23.98 29.19 29.23 27.23 29.88 307.73 SECI 0.78 0.84 0.75 0.65 0.65 0.63 0.80 0.82 0.88 0.84 0.83 0.96 9.43 ACME Magadh 0.63 0.65 0.63 0.65 0.65 0.63 0.65 0.63 0.65 0.69 0.67 0.69 7.81 ACME Nalanda 0.94 0.98 0.94 0.98 0.98 0.94 0.98 0.94 0.98 0.98 0.93 0.98 11.54 Sunmark 0.63 0.65 0.63 0.65 0.65 0.63 0.65 0.63 0.65 0.65 0.67 0.72 7.80 Avantika 0.31 0.33 0.31 0.33 0.33 0.31 0.33 0.31 0.33 0.33 0.29 0.33 3.83 AZURE 0.63 0.65 0.63 0.65 0.65 0.63 0.65 0.63 0.65 0.65 0.59 0.66 7.67 Udipta Energy & Equipment Pvt ltd 0.31 0.33 0.31 0.33 0.33 0.31 0.33 0.31 0.33 0.33 0.29 0.33 3.83 Glatt 0.19 0.20 0.19 0.20 0.20 0.19 0.20 0.19 0.20 0.20 0.18 0.20 2.30 Welspun 2 0.94 0.98 0.94 0.98 0.98 0.94 0.98 0.94 0.98 0.98 0.88 1.10 11.61 Welspun 1 0.63 0.65 0.63 0.65 0.65 0.63 0.65 0.63 0.65 0.65 0.59 0.73 7.73 Alpha Infra pop 1.26 1.30 1.26 1.30 1.30 1.26 1.30 1.26 1.30 1.30 1.17 1.30 15.31 Welspun 3 0.94 0.98 0.94 0.98 0.98 0.94 0.98 0.94 0.98 0.98 0.91 1.12 11.66 Response 0.63 0.65 0.63 0.65 0.65 0.63 0.65 0.63 0.65 0.65 0.59 0.65 7.66 New Swadeshi Sugar Mill,Narkatiaganj 1.23 1.10 1.23 1.27 1.27 1.23 1.27 1.23 1.45 1.47 1.40 1.27 15.42 Harinagar Sugar Mills,Harinagar 1.93 1.74 1.93 2.00 2.00 1.93 2.00 1.93 4.32 4.34 3.72 3.96 31.78 Bharat SugarMills,SidhiwaliaGop alganj 1.93 1.74 1.93 2.00 2.00 1.93 2.00 1.93 3.74 3.72 3.28 4.19 30.38 Lauriya Sugar Mill 3.51 3.15 3.51 3.63 3.63 3.51 3.63 3.51 3.63 3.63 4.03 3.63 43.00 Sugauli Sugar Mill 3.51 3.15 3.51 3.63 3.63 3.51 3.63 3.51 3.63 3.63 3.30 3.63 42.26 Hasanpur Sugar Mills,Samastipur 1.76 1.58 1.76 1.81 1.81 1.76 1.81 1.76 1.81 1.81 1.64 1.81 21.12 Riga Sugar Company Ltd,Sitamarhi 0.53 0.47 0.53 0.54 0.54 0.53 0.54 0.53 0.54 0.54 0.49 0.54 6.34 Siddhashram Rice Mill Cluster Pvt Ltd 0.18 0.19 0.18 0.18 0.18 0.18 0.18 0.18 0.32 0.34 0.29 0.24 2.63 BDBPL 0.53 0.47 0.53 0.54 0.54 0.53 0.54 0.53 0.54 0.54 0.49 0.84 6.63 Open Market Purchase 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 IEX/PXIL 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
North Bihar Power Distribution Company Limited 219 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19 DB Power 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 JAYPEE NIGRIE 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 JPL 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 GMR ETL 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TATA ETL 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Manikaran Power 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 NEA 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 NVVNL 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 PVVNL 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Adani Short Term 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Net UI 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 13634.7 Sub Total Power Purchase 1017.63 1056.72 1045.36 1138.52 1145.28 1097.35 1160.24 1051.00 1086.50 1272.34 1215.67 1348.17 9 Transmission charges 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 PGCIL Losses 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 POSOCO Charges 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 BSPTCL charges 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 BGCL Charges 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 13634.7 Total Power Purchase 1017.63 1056.72 1045.36 1138.52 1145.28 1097.35 1160.24 1051.00 1086.50 1272.34 1215.67 1348.17 9
North Bihar Power Distribution Company Limited 220 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
Annexure B – Additional data submission to BERC
B.1 Annexure : Plant Load factor of power generating stations for FY 2016-17
Name of The Source Apr-16 May-16 Jun-16 Jul-16 Aug-16 Sep-16 Oct-16 Nov-16 Dec-16 Jan-17 Feb-17 Mar-17 FY 16 -17 Central Sector Stations 58.05% 70.96% 77.06% 82.01% 87.39% 67.49% 76.44% 67.09% 70.01% 75.45% 71.21% 69.52% 72.55% Talcher – I ( 2 x 500 MW) 91.82% 89.16% 87.80% 90.32% 92.49% 88.77% 76.14% 68.20% 53.74% 96.23% 82.00% 84.19% 83.15% Farakka – I & II (1600 MW) 31.35% 67.65% 86.60% 78.06% 86.88% 80.39% 79.39% 82.68% 90.51% 94.02% 89.42% 75.65% 78.34% Farakka – III (500 MW) 164.22% 160.33% 156.21% 142.86% 151.24% 85.25% 86.25% 91.11% 100.04% 96.57% 85.14% 84.86% 116.69% Kahalgaon – I (840 MW) 81.29% 76.94% 79.55% 78.70% 82.58% 64.86% 82.43% 80.81% 91.49% 88.89% 88.37% 91.65% 82.10% Kahalgaon – II (1500 MW) 119.86% 77.12% 85.61% 58.55% 111.06% 89.90% 88.04% 86.01% 101.69% 62.64% 86.64% 94.15% 88.07% Barh-II 45.38% 66.87% 61.86% 67.71% 70.21% 38.44% 67.65% 65.14% 79.30% 85.69% 82.73% 79.23% 67.40% Korba 97.47% 95.00% 97.60% 96.71% 99.93% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 40.42% Rangit – HEP 30.72% 54.97% 85.78% 90.98% 104.39% 97.92% 101.80% 70.37% 45.22% 34.46% 29.05% 30.92% 64.55% Teesta - HEP 60.27% 69.76% 85.36% 95.09% 92.83% 101.28% 91.71% 44.52% 30.45% 22.97% 20.95% 32.49% 62.16% Chukha 51.27% 52.74% 103.15% 157.08% 163.00% 159.56% 185.09% 99.53% 51.99% 25.44% 11.75% 22.83% 90.13% Tala 6.35% 18.51% 46.39% 87.18% 93.00% 90.88% 71.61% 27.21% 11.52% 3.04% 0.94% 3.89% 38.28% Barh Stage-I (3 X 660 MW) 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% State Generating Stations 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% KBUNL 1 67.08% 67.58% 57.50% 48.41% 30.47% 20.80% 38.37% 35.37% 18.25% 18.97% 6.87% 24.75% 36.18% KBUNL 2 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% Small Hydro (BSHPCL) 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% Barauni Stage I 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 10.64% 27.23% 38.44% 53.01% 19.12% 22.79% 14.32% Barauni Stage II 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% IPP 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% GMR Kamalanga Energy 89.69% 83.77% 103.20% 93.63% 46.84% 89.96% 103.53% 100.97% 63.34% 90.58% 98.57% 103.46% 88.70% Adani Enterprises Limited 9.68% 3.22% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 1.07% JV projects 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% Nabinagar Railway (4 X 250 Mw) 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% Nabinagar Stage-I (3 X 660 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% Nabinagar JV (3 X 660 MW) Stage-II 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% Renewable 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% SECI 27.77% 28.97% 28.11% 22.75% 14.35% 23.56% 23.25% 24.91% 25.71% 24.45% 26.99% 28.18% 24.85% ACME Magadh 0.00% 0.00% 0.08% 9.24% 15.57% 14.12% 18.63% 17.33% 15.14% 20.03% 21.56% 20.20% 12.62% ACME Nalanda 0.00% 0.00% -0.02% 6.14% 13.32% 12.35% 15.58% 15.34% 13.68% 18.50% 20.10% 18.82% 11.11% Sunmark 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.11% 11.03% 17.70% 21.56% 20.92% 5.92% Avantika 14.12% 12.37% 10.37% 9.91% 13.95% 11.97% 17.00% 16.74% 8.36% 12.11% 13.40% 13.75% 12.79% AZURE 0.00% 0.00% 0.00% 0.77% 12.44% 12.41% 17.41% 16.21% 10.10% 13.19% 16.38% 19.36% 9.82% Udipta Energy & Equipment Pvt ltd 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 1.52% 3.62% 4.03% 0.76% Glatt 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 1.42% 0.12%
North Bihar Power Distribution Company Limited 221 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19 Welspun 2 0.00% 0.00% 0.00% 0.43% 7.92% 8.64% 14.36% 11.35% 9.67% 15.22% 18.69% 21.48% 8.95% Welspun 1 0.00% 0.00% 0.00% 0.02% 1.21% 4.94% 6.22% 8.25% 10.69% 15.28% 18.88% 21.20% 7.20% Alpha Infra Prop 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% Welspun 3 0.00% 0.00% 0.00% 0.69% 4.79% 6.64% 9.62% 9.36% 11.06% 16.07% 19.52% 21.89% 8.28% Response Renewable Energy 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% New Swadeshi Sugar Mill,Narkatiaganj -0.71% -2.65% -3.09% -3.32% -3.52% -4.03% -9.92% 5.44% 60.56% 61.48% 64.56% 43.46% 19.58% Harinagar Sugar Mills,Harinagar 92.45% 91.99% -1.50% -1.29% -4.91% -3.07% -3.15% 28.47% 114.83% 115.24% 109.34% 105.12% 54.76% Bharat SugarMills,SidhiwaliaGopalganj -1.39% -1.09% -1.24% -1.21% -1.30% -1.44% -1.33% -1.71% 99.32% 98.76% 96.60% 111.42% 33.87% Lauriya Sugar Mill -0.41% -0.35% -0.36% -0.38% -0.34% -0.40% -0.44% -0.97% 34.14% 47.60% 65.27% 40.96% 15.56% Sugauli Sugar Mill -0.30% -0.26% -0.19% -0.19% -0.16% -0.24% -0.27% -0.75% 10.50% 23.20% 53.32% 26.64% 9.34% Hasanpur Sugar Mills,Samastipur 14.69% -0.60% -0.66% -0.69% -0.72% -0.51% -0.46% -0.55% 26.93% 37.37% 37.64% 2.96% 9.88% Riga Sugar Company Ltd,Sitamarhi -0.03% -0.01% 0.00% -0.02% -0.09% 0.00% -0.95% -1.14% 30.84% 23.49% 33.70% 5.31% 7.72% Siddhashram Rice Mill Cluster Pvt Ltd 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 1.95% 92.31% 100.28% 93.74% 71.29% 29.94% BDBPL 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 45.56% 81.75% 10.53%
North Bihar Power Distribution Company Limited 222 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
B.2 Annexure: Month-wise power purchase capacity (in MU) assumed for Bihar for FY 2017-18
Name of The Source Oct'17 Nov'17 Dec'17 Jan'18 Feb'18 Mar'18 Central Sector Stations 2,991 2,991 2,991 2,991 2,991 2,991 Talcher – I ( 2 x 500 MW) 417 417 417 417 417 417 Farakka – I & II (1600 MW) 509 509 509 509 509 509 Farakka – III (500 MW) 108 108 108 108 108 108 Kahalgaon – I (840 MW) 355 355 355 355 355 355 Kahalgaon – II (1500 MW) 75 75 75 75 75 75 Barh-II 1059 1059 1059 1059 1059 1059 Korba 0 0 0 0 0 0 Rangit – HEP 21 21 21 21 21 21 Teesta - HEP 108 108 108 108 108 108 Chukha 80 80 80 80 80 80 Tala 260 260 260 260 260 260 Barh Stage-I (3 X 660 MW) 0 0 0 0 0 0 State Generating Stations 484 844 844 844 954 954 KBUNL 1 220 220 220 220 220 220 KBUNL 2 264 264 264 264 264 264 Small Hydro (BSHPCL) 0 0 0 0 0 0 Barauni Stage I 0 110 110 110 220 220 Barauni Stage II 0 250 250 250 250 250 IPP 260.00 260.00 260.00 260.00 260.00 260.00 GMR Kamalanga Energy 260 260 260 260 260 260 Adani Enterprises Limited 0 0 0 0 0 0 JV projects 25.00 25.00 50.00 50.00 50.00 50.00 Nabinagar Railway (4 X 250 Mw) 25 25 50 50 50 50 Nabinagar Stage-I (3 X 660 0 0 0 0 0 0 Nabinagar JV (3 X 660 MW) Stage-II 0 0 0 0 0 0 Renewable 204.00 204.00 224.00 224.00 224.00 224.00
North Bihar Power Distribution Company Limited 223 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19 SECI 10.00 10.00 10.00 10.00 10.00 10.00 ACME Magadh 10.00 10.00 10.00 10.00 10.00 10.00 ACME Nalanda 15.00 15.00 15.00 15.00 15.00 15.00 Sunmark 10.00 10.00 10.00 10.00 10.00 10.00 Avantika 5.00 5.00 5.00 5.00 5.00 5.00 AZURE 10.00 10.00 10.00 10.00 10.00 10.00 Udipta Energy & Equipment Pvt ltd 5.00 5.00 5.00 5.00 5.00 5.00 Glatt 3.00 3.00 3.00 3.00 3.00 3.00 Welspun 2 15.00 15.00 15.00 15.00 15.00 15.00 Welspun 1 10.00 10.00 10.00 10.00 10.00 10.00 Alpha Infra Prop 0.00 0.00 20.00 20.00 20.00 20.00 Welspun 3 15.00 15.00 15.00 15.00 15.00 15.00 Response Renewable energy 10.00 10.00 10.00 10.00 10.00 10.00 New Swadeshi Sugar Mill,Narkatiaganj 7.00 7.00 7.00 7.00 7.00 7.00 Harinagar Sugar Mills,Harinagar 11.00 11.00 11.00 11.00 11.00 11.00 Bharat SugarMills,SidhiwaliaGopalganj 11.00 11.00 11.00 11.00 11.00 11.00 Lauriya Sugar Mill 20.00 20.00 20.00 20.00 20.00 20.00 Sugauli Sugar Mill 20.00 20.00 20.00 20.00 20.00 20.00 Hasanpur Sugar Mills,Samastipur 10.00 10.00 10.00 10.00 10.00 10.00 Riga Sugar Company Ltd,Sitamarhi 3.00 3.00 3.00 3.00 3.00 3.00 Siddhashram Rice Mill Cluster Pvt Ltd 1.00 1.00 1.00 1.00 1.00 1.00 BDBPL 3.00 3.00 3.00 3.00 3.00 3.00 Grand Total 3,964.43 4,324.43 4,369.43 4,369.43 4,479.43 4,479.43
North Bihar Power Distribution Company Limited 224 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
B.3 Annexure: Normative PLF and Auxiliary Consumption assumed for FY 2017-18 and FY 2018-19
FY 2017-18 Oct to March FY 2018 - 19 Name of The Source PLF(%) Aux(%) PLF (%) Aux(%) Central Sector Stations Talcher – I ( 2 x 500 MW) 85% 0% 85% 0% Farakka – I & II (1600 MW) 85% 0% 85% 0% Farakka – III (500 MW) 85% 0% 85% 0% Kahalgaon – I (840 MW) 85% 0% 85% 0% Kahalgaon – II (1500 MW) 85% 0% 85% 0% Barh-II 85% 0% 85% 0% Korba 85% 0% 85% 0% Rangit – HEP 50% 0% 50% 0% Teesta-HEP 47% 0% 47% 0% Chukha 47% 0% 47% 0% Tala 37% 0% 37% 0% Barh Stage-I (3 X 660 MW) 85% 0% 85% 0% State Generating Stations 0% 0% KBUNL 1 40% 0% 40% 0% KBUNL 2 40% 0% 40% 0% Small Hydro (BSHPCL) 10% 0% 10% 0% Barauni Stage I 20% 0% 40% 0% Barauni Stage II 10% 0% 40% 0% IPP 0% 0% GMR Kamalanga Energy 85% 0% 85% 0% Adani Enterprises Limited 85% 0% 85% 0% JV projects 0% 0% Nabinagar Railway (4 X 250 Mw) 85% 0% 85% 0% Nabinagar Stage-I (3 X 660 60% 0% 60% 0% Nabinagar JV (3 X 660 MW) Stage-II 85% 0% 85% 0% Renewable 0% 0% SECI 19% 0% 19% 0%
North Bihar Power Distribution Company Limited 225 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19 ACME Magadh 19% 0% 19% 0% ACME Nalanda 19% 0% 19% 0% Sunmark 19% 0% 19% 0% Avantika 19% 0% 19% 0% AZURE 19% 0% 19% 0% Udipta Energy & Equipment Pvt ltd 19% 0% 19% 0% Glatt 19% 0% 19% 0% Welspun 2 19% 0% 19% 0% Welspun 1 19% 0% 19% 0% Alpha Infra Prop 19% 0% 19% 0% Welspun 3 19% 0% 19% 0% Response Renewable Energy 19% 0% 19% 0% New Swadeshi Sugar Mill,Narkatiaganj 53% 0% 53% 0% Harinagar Sugar Mills,Harinagar 53% 0% 53% 0% Bharat SugarMills,SidhiwaliaGopalganj 53% 0% 53% 0% Lauriya Sugar Mill 53% 0% 53% 0% Sugauli Sugar Mill 53% 0% 53% 0% Hasanpur Sugar Mills,Samastipur 53% 0% 53% 0% Riga Sugar Company Ltd,Sitamarhi 53% 0% 53% 0% Siddhashram Rice Mill Cluster Pvt Ltd 53% 0% 53% 0% BDBPL 53% 0% 53% 0%
North Bihar Power Distribution Company Limited 226 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
B.4 Annexure: Plant Load Factors considered for FY 2017-18
Name of The Source Apr-17 May-17 Jun-17 Jul-17 Aug-17 Sep-17 Oct-17 Nov-17 Dec-17 Jan-18 Feb-18 Mar-18 FY 17-18 Central Sector Stations 68.01% 67.02% 76.23% 77.34% 69.77% 62.50% 76.44% 67.09% 70.01% 75.45% 71.21% 69.52% 74.39% Talcher – I ( 2 x500 MW) 68.01% 67.02% 76.23% 77.34% 82.28% 80.95% 85.00% 85.00% 85.00% 96.23% 85.00% 85.00% 80.02% Farakka – I & II (1600 MW) 42.14% 63.92% 67.34% 62.38% 55.94% 59.03% 85.00% 85.00% 90.51% 94.02% 89.42% 85.00% 72.35% Farakka – III (500 MW) 72.93% 66.70% 63.18% 57.23% 57.06% 60.12% 86.25% 91.11% 100.04% 96.57% 85.14% 85.00% 75.83% Kahalgaon – I (840 MW) 75.07% 74.36% 60.65% 70.42% 74.64% 73.06% 85.00% 85.00% 91.49% 88.89% 88.37% 91.65% 78.82% Kahalgaon – II (1500 MW) 81.08% 99.17% 111.50% 87.92% 106.39% 64.67% 88.04% 86.01% 101.69% 85.00% 86.64% 94.15% 89.81% Barh-II 73.59% 71.64% 77.03% 65.31% 58.09% 42.70% 85.00% 85.00% 85.00% 85.69% 85.00% 85.00% 73.93% Korba 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 0.00% Rangit – HEP 38.34% 49.17% 76.03% 87.47% 86.33% 87.30% 101.80% 70.37% 49.50% 49.50% 49.50% 49.50% 65.43% Teesta - HEP 52.91% 63.62% 82.39% 87.74% 87.06% 89.75% 91.71% 46.75% 46.75% 46.75% 46.75% 46.75% 64.92% Chukha 59.82% 58.10% 85.18% 147.61% 143.18% 130.58% 185.09% 99.53% 51.99% 47.00% 47.00% 47.00% 90.85% Tala 7.68% 21.00% 37.43% 80.99% 81.31% 70.87% 71.61% 36.90% 36.90% 36.90% 36.90% 36.90% 45.72% Barh Stage-I (3 X 660 MW) 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 0.00% State Generating Stations KBUNL 1 3.84% 38.82% 42.19% 16.25% 16.28% 51.84% 40.00% 40.00% 40.00% 40.00% 40.00% 40.00% 33.65% KBUNL 2 13.08% 0.00% 0.00% 19.99% 43.46% 39.10% 40.00% 40.00% 40.00% 40.00% 40.00% 40.00% 29.26% Small Hydro (BSHPCL) 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 10.00% 10.00% 10.00% 10.00% 10.00% 10.00% 0.00% Barauni Stage I 11.78% 5.85% 0.00% 0.00% 0.00% 0.00% 20.00% 27.23% 38.44% 53.01% 20.00% 22.79% 9.83% Barauni Stage II 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 10.00% 10.00% 10.00% 10.00% 10.00% 10.00% 4.10% IPP 68.01% 67.02% 76.23% 77.34% 82.28% 80.95% 87.83% 85.00% 87.83% 99.43% 79.33% 85.00% 19.57% GMR Kamalanga Energy 73.48% 64.63% 68.20% 78.81% 68.11% 46.86% 103.53% 100.97% 85.00% 90.58% 98.57% 103.46% 80.73% Adani Enterprises Limited 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 0.00% JV projects 68.01% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% Nabinagar Railway (4 X 250 Mw) 0.00% 0.00% 0.00% 0.00% 27.51% 33.23% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 39.93% Nabinagar Stage-I (3 X 660 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 60.00% 60.00% 60.00% 60.00% 60.00% 60.00% 0.00% Nabinagar JV (3 X 660 MW) Stage-II 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 0.00% Renewable 68.01% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 40.60% SECI 23.52% 24.58% 22.61% 14.18% 16.31% 18.54% 23.25% 24.91% 25.71% 24.45% 26.99% 28.18% 22.45%
North Bihar Power Distribution Company Limited 227 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19 ACME Magadh 16.75% 17.56% 16.65% 13.39% 16.39% 16.55% 19.00% 19.00% 19.00% 20.03% 21.56% 20.20% 17.75% ACMENalanda 15.70% 14.54% 15.64% 12.48% 15.12% 15.50% 19.00% 19.00% 19.00% 19.00% 20.10% 19.00% 16.77% Sunmark 15.11% 18.80% 17.82% 11.98% 15.74% 17.15% 19.00% 19.00% 19.00% 19.00% 21.56% 20.92% 17.67% Avantika 10.04% 10.05% 11.42% 12.12% 2.77% 0.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 13.20% AZURE 15.14% 16.93% 16.95% 13.22% 0.97% 0.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.36% 14.61% Udipta Energy & Equipment Pvt ltd 8.03% 10.76% 10.64% 8.15% 8.81% 8.92% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 13.93% Glatt 9.15% 3.75% 4.00% 2.73% 3.23% 5.77% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 11.74% Welspun 2 15.76% 18.09% 16.87% 11.16% 14.47% 16.08% 19.00% 19.00% 19.00% 19.00% 19.00% 21.48% 17.18% Welspun 1 16.42% 18.28% 16.81% 11.24% 14.19% 10.09% 19.00% 19.00% 19.00% 19.00% 19.00% 21.20% 16.71% Alpha Infra Prop 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 6.23% Welspun 3 16.78% 18.84% 17.25% 11.62% 13.97% 10.31% 19.00% 19.00% 19.00% 19.00% 19.52% 21.89% 16.95% Response Renewable Energy 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 11.66% New Swadeshi Sugar Mill,Narkatiaganj 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 53.00% 53.00% 60.56% 61.48% 64.56% 53.00% 28.45% Harinagar Sugar Mills,Harinagar 39.79% 5.56% 35.78% 0.00% 0.00% 1.93% 53.00% 53.00% 114.83% 115.24% 109.34% 105.12% 52.11% Bharat SugarMills,SidhiwaliaGopalganj 9.62% 0.00% 0.00% 0.00% 0.00% 0.00% 53.00% 53.00% 99.32% 98.76% 96.60% 111.42% 42.92% Lauriya Sugar Mill 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 53.00% 53.00% 53.00% 53.00% 65.27% 53.00% 27.15% Sugauli Sugar Mill 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 53.00% 53.00% 53.00% 53.00% 53.32% 53.00% 26.23% Hasanpur Sugar Mills,Samastipur 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% 26.21% Riga Sugar Company Ltd,Sitamarhi 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% 26.21% Siddhashram Rice Mill Cluster Pvt Ltd 52.70% 65.16% 41.56% 27.73% 0.00% 32.39% 53.00% 53.00% 92.31% 100.28% 93.74% 71.29% 56.15% BDBPL 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 53.00% 53.00% 53.00% 53.00% 53.00% 81.75% 28.57%
North Bihar Power Distribution Company Limited 228 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
B.5 Annexure: Actual power purchase quantum for the first six months of FY 2017-18
April 17 to September 17
Au Fixed Fixed Energy Total Share Units Energy Miscellaneou Miscellaneou Total x Cost charg Cost cost Name of The Source allocate purchase PLF (%) cost (Rs s Cost s cost (Rs Cost (Rs (% (Rs/kWh e (Rs (Rs/kW (Rs/kW d (MW) d (MU) Crs) (Rs/kWh) Crs) Crs) ) ) Crs) h) h)
Central Sector Stations 65.7% 0.02 7.13 1,376.06 3,971.17 1.23 489.30 2.47 980.69 3.72 1,477.12 Talcher–I(2x500MW) 191.59 623.28 74.07% 55.77 99.76 0.05 3.38 158.91 0.89 1.60 2.55 Farakka–I&II(1600MW) 234.05 591.07 57.50% 58.04 166.96 0.05 2.90 227.89 0.98 2.82 3.86 Farakka–III(500MW) 49.68 134.93 61.84% 23.92 38.36 0.09 1.17 63.45 1.77 2.84 4.70 Kahalgaon–I(840MW) 163.25 503.31 70.20% 50.16 125.45 0.00 0.11 175.71 1.00 2.49 3.49 Kahalgaon–II(1500MW) 34.36 136.25 90.28% 11.93 33.11 0.00 0.02 45.06 0.88 2.43 3.31 Barh-II 487.14 1362.15 63.67% 268.97 398.28 (0.00) -0.48 666.77 1.97 2.92 4.90 Korba 0.00 0.95 0.00% 0.13 0.11 0.00 0.00 0.24 1.42 1.15 2.57 Rangit–HEP 9.66 29.53 69.61% 5.20 5.78 0.00 0.01 10.98 1.76 1.96 3.72 Teesta-HEP 49.88 166.44 75.98% 15.19 19.31 0.00 0.04 34.54 0.91 1.16 2.08 Chukha 36.80 165.46 102.37% 0.00 37.89 (0.00) -0.02 37.88 - 2.29 2.29 Tala 119.65 257.80 49.06% 0.00 55.68 - 0.00 55.68 - 2.16 2.16 Barh Stage-I (3 X 660 MW) 0.00 0.00 0.00% 0.00 0.00 - 0.00 0.00 - - - State Generating Stations 16.82% 2.033 3.278 0.000 - 5.311 323.84 239.26 48.64 78.42 127.06 KBUNL 1 101.20 123.30 27.74% 17.34 42.03 - 0.00 59.37 1.41 3.41 4.81 KBUNL 2 121.44 101.09 18.95% 31.30 30.62 - 0.00 61.93 3.10 3.03 6.13
North Bihar Power Distribution Company Limited 229 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
Small Hydro (BSHPCL) 0.00 2.01 0.00% 0.00 0.50 - 0.00 0.50 - 2.49 2.49 Barauni Stage I 101.20 12.84 2.89% 0.00 5.27 - 0.00 5.27 - 4.10 4.10 Barauni Stage II 0.00 0.00 0.00% 0.00 0.00 - 0.00 0.00 - - - IPP 65.59% 1.948 1.126 0.499 17.21 3.573 119.60 344.53 67.12 38.78 123.10 GMRKamalangaEnergy 119.60 344.53 65.59% 67.12 38.78 0.50 17.21 123.10 1.95 1.13 3.57 AdaniEnterprisesLimited 0.00 0.00 0.00% 0.00 0.00 - 0.00 0.00 - - - JV projects 9.96% - - 23.00 10.06 3.69 3.71 1.91 1.92 5.60 5.64 NabinagarRailway(4X250Mw) 23.00 10.06 9.96% 3.71 1.92 - 0.00 5.64 3.69 1.91 5.60 NabinagarStage-I(3X660 0.00 0.00 0.00% 0.00 0.00 - 0.00 0.00 - - - Nabinagar JV (3 X 660 MW) 0.00 0.00 0.00% 0.00 0.00 - 0.00 0.00 Stage-II - - - Renewable 9.27% - - 87.86 35.77 - - 7.73 27.66 7.73 27.66 SECI 4.60 3.97 19.63% 0.00 2.23 - 0.00 2.23 - 5.62 5.62 ACMEMagadh 4.60 3.22 15.95% 0.00 2.81 - 0.00 2.81 - 8.73 8.73 6.90 4.42 14.59% 0.00 3.86 - 0.00 3.86 ACME Nalanda - 8.73 8.73 Sunmark 4.60 3.20 15.83% 0.00 2.25 - 0.00 2.25 - 7.02 7.02 Avantika 2.30 0.77 7.61% 0.00 0.59 - 0.00 0.59 - 7.69 7.69 AZURE 4.60 2.09 10.36% 0.00 1.76 - 0.00 1.76 - 8.39 8.39 Udipta Energy & Equipment Pvt 2.30 0.92 9.07% 0.00 0.73 - 0.00 0.73 ltd - 7.98 7.98 Glatt 1.38 0.28 4.69% 0.00 0.20 - 0.00 0.20 - 7.02 7.02 Welspun2 6.90 4.59 15.15% 0.00 3.97 - 0.00 3.97 - 8.64 8.64 Welspun1 4.60 2.88 14.27% 0.00 2.51 - 0.00 2.51 - 8.70 8.70 Alpha Infraprop 0.00 0.00 0.00% 0.00 0.00 - 0.00 0.00 - - - Welspun3 6.90 4.41 14.55% 0.00 3.78 - 0.00 3.78 - 8.56 8.56
North Bihar Power Distribution Company Limited 230 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
ResponseRenewableEnergy 0.00 0.91 0.00% 0.00 0.64 - 0.00 0.64 - 7.02 7.02 New Swadeshi Sugar 3.22 0.00 0.00% 0.00 0.00 - 0.00 0.00 Mill,Narkatiaganj - - - HarinagarSugarMills,Harinagar 5.06 3.03 13.62% 0.00 1.62 - 0.00 1.62 - 5.34 5.34 Bharat 5.06 0.35 1.58% 0.00 0.18 - 0.00 0.18 SugarMills,SidhiwaliaGopalganj - 5.04 5.04 Lauriya Sugar Mill 9.20 0.00 0.00% 0.00 0.00 - 0.00 0.00 - - - Sugauli Sugar Mill 9.20 0.00 0.00% 0.00 0.00 - 0.00 0.00 - - - HasanpurSugarMills,Samastipur 4.60 0.00 0.00% 0.00 0.01 - 0.00 0.01 - - - Riga Sugar Company 1.38 0.00 0.00% 0.00 0.00 - 0.00 0.00 Ltd,Sitamarhi - - - Siddhashram Rice Mill Cluster Pvt 0.46 0.73 35.99% 0.00 0.54 - 0.00 0.54 Ltd - 7.41 7.41
BDBPL 0.00 0.00 0.00% 0.00 0.00 - 0.00 0.00 - - -
Open Market Purchase 0.02 1.93 1,267.85 - - 4.02 509.10 4.03 511.03 IEX/PXIL 0.00 782.11 0.00 309.32 0.02 1.93 311.25 - 3.95 3.98 DB Power 0.00 0.00 0.00 0.00 - 0.00 0.00 - - - JAYPEE NIGRIE 0.00 117.81 0.00 33.17 - 0.00 33.17 - 2.82 2.82 JPL 0.00 20.28 0.00 5.81 - 0.00 5.81 - 2.87 2.87 GMRETL 0.00 8.01 0.00 2.56 - 0.00 2.56 - 3.19 3.19 TATA ETL 0.00 36.74 0.00 14.05 - 0.00 14.05 - 3.83 3.83 Manikaran Power 0.00 232.27 0.00 108.01 - 0.00 108.01 - 4.65 4.65 NEA 0.00 0.48 0.00 0.13 - 0.00 0.13 - 2.72 2.72 NVVNL 0.00 0.00 0.00 0.00 - 0.00 0.00 - - - PVVNL 0.00 0.00 0.00 0.00 - 0.00 0.00 - - - Adani Short Term 0.00 9.07 0.00 4.33 - 0.00 4.33 - 4.77 4.77
North Bihar Power Distribution Company Limited 231 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
UI 0.00 61.09 0.00 31.73 - 0.00 31.73 - 5.19 5.19 Sub Total Power Purchase 0.04 26.26 1,930.36 5,868.64 1.04 608.77 2.79 1,636.58 3.87 2,271.61 Transmission charges - - - 291.41 PGCIL - - 159.87 POSOCO & SLDC Charges - - - 2.87 BSPTCL charges - - - 128.67 BGCL 42.20 Total Power Purchase 1,930.36 5,868.64 1.04 608.77 2.79 1,636.58 0.04 26.26 4.37 2,563.02
North Bihar Power Distribution Company Limited 232 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
B.6 Annexure: Power Purchase Capacity considered for Bihar for FY 2018-19
Name of The Source April'18 May'18 June'18 Jul'18 Aug'18 Sept'18 Oct'18 Nov'18 Dec'18 Jan'19 Feb'19 Mar'19
Central Sector Stations 2,991 2,991 2,991 2,991 2,991 2,991 2,991 2,991 2,991 3,504 3,504 3,504 Talcher–I(2x500MW) 417 417 417 417 417 417 417 417 417 417 417 417 Farakka–I&II(1600MW) 509 509 509 509 509 509 509 509 509 509 509 509 Farakka–III(500MW) 108 108 108 108 108 108 108 108 108 108 108 108 Kahalgaon–I(840MW) 355 355 355 355 355 355 355 355 355 355 355 355 Kahalgaon–II(1500MW) 75 75 75 75 75 75 75 75 75 75 75 75 Barh-II 1059 1059 1059 1059 1059 1059 1059 1059 1059 1059 1059 1059 Korba 0 0 0 0 0 0 0 0 0 0 0 0 Rangit–HEP 21 21 21 21 21 21 21 21 21 21 21 21 Teesta-HEP 108 108 108 108 108 108 108 108 108 108 108 108 Chukha 80 80 80 80 80 80 80 80 80 80 80 80 Tala 260 260 260 260 260 260 260 260 260 260 260 260 Barh Stage-I (3 X 660 MW) 0 0 0 0 0 0 0 0 0 513 513 513
State Generating Stations 954 954 954 959 964 964 964 964 964 964 964 964 KBUNL1 220 220 220 220 220 220 220 220 220 220 220 220 KBUNL2 264 264 264 264 264 264 264 264 264 264 264 264 Small Hydro (BSHPCL) 0 0 0 5 10 10 10 10 10 10 10 10 BarauniStageI 220 220 220 220 220 220 220 220 220 220 220 220 BarauniStageII 250 250 250 250 250 250 250 250 250 250 250 250
IPP 260.00 260.00 260.00 260.00 260.00 260.00 260.00 260.00 260.00 260.00 260.00 260.00 GMRKamalangaEnergy 260 260 260 260 260 260 260 260 260 260 260 260 AdaniEnterprisesLimited 0 0 0 0 0 0 0 0 0 0 0 0
JV projects 50.00 50.00 50.00 75.00 75.00 75.00 75.00 75.00 75.00 100.00 617.67 617.67 NabinagarRailway(4X250Mw) 50 50 50 75 75 75 75 75 75 100 100 100 NabinagarStage-I(3X660 0 0 0 0 0 0 0 0 0 0 518 518 NabinagarJV(3X660MW)Stage-II 0 0 0 0 0 0 0 0 0 0 0 0
North Bihar Power Distribution Company Limited 233 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19 Renewable 224.00 224.00 224.00 224.00 224.00 224.00 224.00 224.00 224.00 224.00 224.00 224.00 SECI 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 ACMEMagadh 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 ACME Nalanda 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 Sunmark 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 Avantika 5.00 5.00 5.00 5.00 5.00 5.00 5.00 5.00 5.00 5.00 5.00 5.00 AZURE 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 UdiptaEnergy&EquipmentPvtltd 5.00 5.00 5.00 5.00 5.00 5.00 5.00 5.00 5.00 5.00 5.00 5.00 Glatt 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 Welspun2 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 Welspun1 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 AlphaInfraProp 20.00 20.00 20.00 20.00 20.00 20.00 20.00 20.00 20.00 20.00 20.00 20.00 Welspun3 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 ResponseRenewableenergy 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 NewSwadeshiSugarMill,Narkatiaganj 7.00 7.00 7.00 7.00 7.00 7.00 7.00 7.00 7.00 7.00 7.00 7.00 HarinagarSugarMills,Harinagar 11.00 11.00 11.00 11.00 11.00 11.00 11.00 11.00 11.00 11.00 11.00 11.00 BharatSugarMills,SidhiwaliaGopalganj 11.00 11.00 11.00 11.00 11.00 11.00 11.00 11.00 11.00 11.00 11.00 11.00 LauriyaSugarMill 20.00 20.00 20.00 20.00 20.00 20.00 20.00 20.00 20.00 20.00 20.00 20.00 SugauliSugarMill 20.00 20.00 20.00 20.00 20.00 20.00 20.00 20.00 20.00 20.00 20.00 20.00 HasanpurSugarMills,Samastipur 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 RigaSugarCompanyLtd,Sitamarhi 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 SiddhashramRiceMillClusterPvtLtd 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 BDBPL 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00
Grand Total 4,479.43 4,479.43 4,479.43 4,509.43 4,514.43 4,514.43 4,514.43 4,514.43 4,514.43 5,052.43 5,570.10 5,570.10
North Bihar Power Distribution Company Limited 234 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
B.7Annexure: Plant Load Factors considered for FY 2018-19
Name of The Source Apr-18 May-18 Jun-18 Jul-18 Aug-18 Sep-18 Oct-18 Nov-18 Dec-18 Jan-19 Feb-19 Mar-19 Talcher – I ( 2 x500 MW) 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 96.23% 85.00% 85.00% Farakka – I & II (1600 MW) 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 90.51% 94.02% 89.42% 85.00% Farakka – III (500 MW) 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 86.25% 91.11% 100.04% 96.57% 85.14% 85.00% Kahalgaon – I (840 MW) 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 91.49% 88.89% 88.37% 91.65% Kahalgaon – II (1500 MW) 85.00% 99.17% 111.50% 87.92% 106.39% 85.00% 88.04% 86.01% 101.69% 85.00% 86.64% 94.15% Barh-II 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.69% 85.00% 85.00% Korba 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% Rangit – HEP 49.50% 49.50% 76.03% 87.47% 86.33% 87.30% 101.80% 70.37% 49.50% 49.50% 49.50% 49.50% Teesta - HEP 52.91% 63.62% 82.39% 87.74% 87.06% 89.75% 91.71% 46.75% 46.75% 46.75% 46.75% 46.75% Chukha 59.82% 58.10% 85.18% 147.61% 143.18% 130.58% 185.09% 99.53% 51.99% 47.00% 47.00% 47.00% Tala 36.90% 36.90% 37.43% 80.99% 81.31% 70.87% 71.61% 36.90% 36.90% 36.90% 36.90% 36.90% Barh Stage-I (3 X 660 MW) 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% KBUNL 1 40.00% 40.00% 42.19% 40.00% 40.00% 51.84% 40.00% 40.00% 40.00% 40.00% 40.00% 40.00% KBUNL 2 40.00% 40.00% 40.00% 40.00% 43.46% 40.00% 40.00% 40.00% 40.00% 40.00% 40.00% 40.00% Small Hydro (BSHPCL) 10.00% 10.00% 10.00% 10.00% 10.00% 10.00% 10.00% 10.00% 10.00% 10.00% 10.00% 10.00% Barauni Stage I 40.00% 40.00% 40.00% 40.00% 40.00% 40.00% 40.00% 40.00% 40.00% 53.01% 40.00% 40.00% Barauni Stage II 40.00% 40.00% 40.00% 40.00% 40.00% 40.00% 40.00% 40.00% 40.00% 40.00% 40.00% 40.00% GMR Kamalanga Energy 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 103.53% 100.97% 85.00% 90.58% 98.57% 103.46% Adani Enterprises Limited 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% Nabinagar Railway (4 X 250 Mw) 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% Nabinagar Stage-I (3 X 660 60.00% 60.00% 60.00% 60.00% 60.00% 60.00% 60.00% 60.00% 60.00% 60.00% 60.00% 60.00% Nabinagar JV (3 X 660 MW) Stage-II 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% 85.00% Renewable 85.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% SECI 23.52% 24.58% 22.61% 19.00% 19.00% 19.00% 23.25% 24.91% 25.71% 24.45% 26.99% 28.18% ACME Magadh 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 20.03% 21.56% 20.20% ACMENalanda 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 20.10% 19.00% Sunmark 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 21.56% 20.92% Avantika 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% AZURE 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.36%
North Bihar Power Distribution Company Limited 235 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19 Udipta Energy & Equipment Pvt ltd 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% Glatt 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% Welspun 2 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 21.48% Welspun 1 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 21.20% Alpha Infra Prop 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% Welspun 3 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.52% 21.89% Response Renewable Energy 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% 19.00% New Swadeshi Sugar Mill,Narkatiaganj 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% 60.56% 61.48% 64.56% 53.00% Harinagar Sugar Mills,Harinagar 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% 114.83% 115.24% 109.34% 105.12% Bharat SugarMills,SidhiwaliaGopalganj 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% 99.32% 98.76% 96.60% 111.42% Lauriya Sugar Mill 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% 65.27% 53.00% Sugauli Sugar Mill 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% 53.32% 53.00% Hasanpur Sugar Mills,Samastipur 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% Riga Sugar Company Ltd,Sitamarhi 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% Siddhashram Rice Mill Cluster Pvt Ltd 53.00% 65.16% 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% 92.31% 100.28% 93.74% 71.29% BDBPL 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% 53.00% 81.75%
North Bihar Power Distribution Company Limited 236 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
B.8Annexure: Government of Bihar notification for capital infusion
North Bihar Power Distribution Company Limited 237 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
North Bihar Power Distribution Company Limited 238 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
B.9Annexure: Board Resolution for admittance and payment of Power Purchase & Transmission charges bills between NBPDCL & SBPDCL
North Bihar Power Distribution Company Limited 239 Petition for True up for FY 2016-17, APR for 2017-18 and ARR for FY 2018-19
North Bihar Power Distribution Company Limited 240