EDB Information Disclosure Requirements Information Templates for Schedules 1 10

Transcription

1 EDB Information Disclosure Requirements Information Templates for Schedules 1 10 Disclosure Date 29 August 2018 Disclosure Year (year ended) Templates for Schedules 1 10 excluding 5f 5g Template Version 4.1. Prepared 24 March 2015 EDB-ID-determination-templates-for-schedules-1-to-10-v March-2.xlsx 1 CoverSheet

2 Table of Contents Schedule Schedule name 1 ANALYTICAL RATIOS 2 REPORT ON RETURN ON INVESTMENT 3 REPORT ON REGULATORY PROFIT 4 REPORT ON VALUE OF THE REGULATORY ASSET BASE (ROLLED FORWARD) 5a REPORT ON REGULATORY TAX ALLOWANCE 5b REPORT ON RELATED PARTY TRANSACTIONS 5c REPORT ON TERM CREDIT SPREAD DIFFERENTIAL ALLOWANCE 5d REPORT ON COST ALLOCATIONS 5e REPORT ON ASSET ALLOCATIONS 6a REPORT ON CAPITAL EXPENDITURE FOR THE DISCLOSURE YEAR 6b REPORT ON OPERATIONAL EXPENDITURE FOR THE DISCLOSURE YEAR 7 COMPARISON OF FORECASTS TO ACTUAL EXPENDITURE 8 REPORT ON BILLED QUANTITIES AND LINE CHARGE REVENUES 9a ASSET REGISTER 9b ASSET AGE PROFILE 9c REPORT ON OVERHEAD LINES AND UNDERGROUND CABLES 9d REPORT ON EMBEDDED NETWORKS 9e REPORT ON NETWORK DEMAND 10 REPORT ON NETWORK RELIABILITY EDB-ID-determination-templates-for-schedules-1-to-10-v March-2.xlsx 2 TOC

3 SCHEDULE 1: ANALYTICAL RATIOS This schedule calculates expenditure, revenue and service ratios from the information disclosed. The disclosed ratios may vary for reasons that are company specific and, as a result, must be interpreted with care. The Commerce Commission will publish a summary and analysis of information disclosed in accordance with the ID determination. This will include information disclosed in accordance with this and other schedules, and information disclosed under the other requirements of the determination. This information is part of audited disclosure information (as defined in section 1.4 of the ID determination), and so is subject to the assurance report required by section (i): Expenditure metrics 8 Expenditure per GWh energy delivered to ICPs ($/GWh) Expenditure per average no. of ICPs ($/ICP) Expenditure per MW maximum coincident system demand ($/MW) Expenditure per km circuit length ($/km) Expenditure per MVA of capacity from EDBowned distribution transformers ($/MVA) 9 Operational expenditure 22, ,598 3,861 20, Network 6, ,518 1,132 5, Non-network 15, ,080 2,730 14, Expenditure on assets 30, ,640 5,255 27, Network 28, ,357 4,949 25, Non-network 1, , , (ii): Revenue metrics 18 Revenue per GWh energy delivered to ICPs ($/GWh) Revenue per average no. of ICPs ($/ICP) 19 Total consumer line charge revenue 89,324 2, Standard consumer line charge revenue 89,324 2, Non-standard consumer line charge revenue (iii): Service intensity measures Demand density 58 Maximum coincident system demand per km of circuit length (for supply) (kw/km) 26 Volume density 174 Total energy delivered to ICPs per km of circuit length (for supply) (MWh/km) 27 Connection point density 6 Average number of ICPs per km of circuit length (for supply) (ICPs/km) 28 Energy intensity 28,269 Total energy delivered to ICPs per average number of ICPs (kwh/icp) (iv): Composition of regulatory income 31 ($000) % of revenue 32 Operational expenditure 12, % 33 Pass-through and recoverable costs excluding financial incentives and wash-ups 13, % 34 Total depreciation 9, % 35 Total revaluations 2, % 36 Regulatory tax allowance 2, % 37 Regulatory profit/(loss) including financial incentives and wash-ups 14, % 38 Total regulatory income 49, (v): Reliability Interruption rate Interruptions per 100 circuit km EDB-ID-determination-templates-for-schedules-1-to-10-v March-2.xlsx 3 S1.Analytical Ratios

4 SCHEDULE 2: REPORT ON RETURN ON INVESTMENT 7 2(i): Return on Investment CY-2 CY-1 Current Year CY 8 31 Mar Mar Mar 18 9 ROI comparable to a post tax WACC % % % 10 Reflecting all revenue earned 5.71% 5.86% 5.58% 11 Excluding revenue earned from financial incentives 5.71% 5.86% 5.51% 12 Excluding revenue earned from financial incentives and wash-ups 5.71% 5.91% 5.56% Mid-point estimate of post tax WACC 5.37% 4.77% 5.04% 15 25th percentile estimate 4.66% 4.05% 4.36% 16 75th percentile estimate 6.09% 5.48% 5.72% ROI comparable to a vanilla WACC 20 Reflecting all revenue earned 6.36% 6.41% 6.17% 21 Excluding revenue earned from financial incentives 6.36% 6.41% 6.11% 22 Excluding revenue earned from financial incentives and wash-ups 6.36% 6.45% 6.15% WACC rate used to set regulatory price path 7.19% 7.19% 7.19% Mid-point estimate of vanilla WACC 6.02% 5.31% 5.60% 27 25th percentile estimate 5.30% 4.59% 4.92% 28 75th percentile estimate 6.74% 6.03% 6.29% (ii): Information Supporting the ROI ($000) Total opening RAB value 251, plus Opening deferred tax (10,975) 34 Opening RIV 240, Line charge revenue 48, Expenses cash outflow 25, add Assets commissioned 14, less Asset disposals add Tax payments 1, less Other regulated income Mid-year net cash outflows 40, Term credit spread differential allowance Total closing RAB value 259, less Adjustment resulting from asset allocation (0) 49 less Lost and found assets adjustment 50 plus Closing deferred tax (12,615) 51 Closing RIV 246, ROI comparable to a vanilla WACC 6.17% Leverage (%) 44% 56 Cost of debt assumption (%) 4.80% 57 Corporate tax rate (%) 28% ROI comparable to a post tax WACC 5.58% (iii): Information Supporting the Monthly ROI Opening RIV N/A Line charge Expenses cash Assets Asset Other regulated Monthly net cash 66 revenue outflow commissioned disposals income outflows 67 April 68 May 69 June 70 July 71 August 72 September 73 October 74 November 75 December 76 January 77 February 78 March 79 Total Tax payments N/A Term credit spread differential allowance N/A Closing RIV N/A Monthly ROI comparable to a vanilla WACC N/A Monthly ROI comparable to a post tax WACC N/A (iv): Year-End ROI Rates for Comparison Purposes Year-end ROI comparable to a vanilla WACC 5.97% Year-end ROI comparable to a post tax WACC 5.38% * these year-end ROI values are comparable to the ROI reported in pre 2012 disclosures by EDBs and do not represent the Commission's current view on ROI (v): Financial Incentives and Wash-Ups Net recoverable costs allowed under incremental rolling incentive scheme 103 Purchased assets avoided transmission charge 104 Energy efficiency and demand incentive allowance 105 Quality incentive adjustment Other financial incentives 107 Financial incentives This schedule requires information on the Return on Investment (ROI) for the EDB relative to the Commerce Commission's estimates of post tax WACC and vanilla WACC. EDBs must calculate their ROI based on a monthly basis if required by clause of the ID Determination or if they elect to. If an EDB makes this election, information supporting this calculation must be provided in 2(iii). EDBs must provide explanatory comment on their ROI in Schedule 14 (Mandatory Explanatory Notes). This information is part of audited disclosure information (as defined in section 1.4 of the ID determination), and so is subject to the assurance report required by section Impact of financial incentives on ROI 0.06% Input methodology claw-back 112 Recoverable customised price-quality path costs 113 Catastrophic event allowance 114 Capex wash-up adjustment (146) 115 Transmission asset wash-up adjustment NPV wash-up allowance 117 Reconsideration event allowance 118 Other wash-ups 119 Wash-up costs (146) Impact of wash-up costs on ROI 0.04% EDB-ID-determination-templates-for-schedules-1-to-10-v March-2.xlsx 4 S2.Return on Investment

5 SCHEDULE 3: REPORT ON REGULATORY PROFIT 7 3(i): Regulatory Profit ($000) 8 Income 9 Line charge revenue 48, plus Gains / (losses) on asset disposals (184) 11 plus Other regulated income (other than gains / (losses) on asset disposals) 1, Total regulatory income 49, Expenses 15 less Operational expenditure 12, less Pass-through and recoverable costs excluding financial incentives and wash-ups 13, Operating surplus / (deficit) 24, less Total depreciation 9, plus Total revaluations 2, Regulatory profit / (loss) before tax 17, less Term credit spread differential allowance less Regulatory tax allowance 2, Regulatory profit/(loss) including financial incentives and wash-ups 14, (ii): Pass-through and Recoverable Costs excluding Financial Incentives and Wash-Ups ($000) 34 Pass through costs 35 Rates Commerce Act levies Industry levies CPP specified pass through costs 39 Recoverable costs excluding financial incentives and wash-ups 40 Electricity lines service charge payable to Transpower 10, Transpower new investment contract charges 1, System operator services 43 Distributed generation allowance Extended reserves allowance 45 Other recoverable costs excluding financial incentives and wash-ups 46 Pass-through and recoverable costs excluding financial incentives and wash-ups 13, (iii): Incremental Rolling Incentive Scheme ($000) 49 CY-1 CY Mar Mar Allowed controllable opex 52 Actual controllable opex Incremental change in year Previous years' incremental change Previous years' incremental change adjusted for inflation 57 CY-5 31 Mar CY-4 31 Mar CY-3 31 Mar CY-2 31 Mar CY-1 31 Mar Net incremental rolling incentive scheme Net recoverable costs allowed under incremental rolling incentive scheme 65 3(iv): Merger and Acquisition Expenditure Merger and acquisition expenditure (v): Other Disclosures Self-insurance allowance This schedule requires information on the calculation of regulatory profit for the EDB for the disclosure year. All EDBs must complete all sections and provide explanatory comment on their regulatory profit in Schedule 14 (Mandatory Explanatory Notes). This information is part of audited disclosure information (as defined in section 1.4 of the ID determination), and so is subject to the assurance report required by section 2.8. Provide commentary on the benefits of merger and acquisition expenditure to the electricity distribution business, including required disclosures in accordance with section 2.7, in Schedule 14 (Mandatory Explanatory Notes) ($000) ($000) EDB-ID-determination-templates-for-schedules-1-to-10-v March-2.xlsx 5 S3.Regulatory Profit

6 SCHEDULE 4: REPORT ON VALUE OF THE REGULATORY ASSET BASE (ROLLED FORWARD) This schedule requires information on the calculation of the Regulatory Asset Base (RAB) value to the end of this disclosure year. This informs the ROI calculation in Schedule 2. EDBs must provide explanatory comment on the value of their RAB in Schedule 14 (Mandatory Explanatory Notes). This information is part of audited disclosure information (as defined in section 1.4 of the ID determination), and so is subject to the assurance report required by section (i): Regulatory Asset Base Value (Rolled Forward) RAB RAB RAB RAB RAB 8 Mar Mar Mar Mar Mar for year ended ($000) ($000) ($000) ($000) ($000) , , , , ,141 Total opening RAB value less Total depreciation 6,958 7,375 7,616 8,152 9, plus Total revaluations 3, ,324 5,072 2, plus Assets commissioned 19,136 13,834 17,848 19,679 14, less Asset disposals 1, , plus Lost and found assets adjustment plus Adjustment resulting from asset allocation (1,031) (0) (0) (0) Total closing RAB value 220, , , , , (ii): Unallocated Regulatory Asset Base 27 Unallocated RAB * RAB 28 ($000) ($000) ($000) ($000) , ,141 Total opening RAB value 30 less 31 Total depreciation 9,240 9, plus 33 Total revaluations 2,756 2, plus 35 Assets commissioned (other than below) 10,196 10, Assets acquired from a regulated supplier 37 Assets acquired from a related party 4,724 4, Assets commissioned 14,921 14, less 40 Asset disposals (other than below) Asset disposals to a regulated supplier 42 Asset disposals to a related party 43 Asset disposals plus Lost and found assets adjustment plus Adjustment resulting from asset allocation (0) Total closing RAB value 259, , * The 'unallocated RAB' is the total value of those assets used wholly or partially to provide electricity distribution services without any allowance being made for the allocation of costs to services provided by the supplier that are not electricity distribution services. The RAB value represents the value of these assets after applying this cost allocation. Neither value includes works under construction. 52 4(iii): Calculation of Revaluation Rate and Revaluation of Assets CPI 1, CPI 4 1, Revaluation rate (%) 1.10% Unallocated RAB * RAB 59 ($000) ($000) ($000) ($000) , ,141 Total opening RAB value 61 less Opening value of fully depreciated, disposed and lost assets Total opening RAB value subject to revaluation 250, , Total revaluations 2,756 2, (iv): Roll Forward of Works Under Construction Unallocated works under 67 construction Allocated works under construction 68 Works under construction preceding disclosure year 2,555 2, plus Capital expenditure 16,215 16, less Assets commissioned 14,921 14, plus Adjustment resulting from asset allocation 72 Works under construction - current disclosure year 3,850 3, Highest rate of capitalised finance applied (v): Regulatory Depreciation 77 Unallocated RAB * RAB 78 ($000) ($000) ($000) ($000) 79 8,154 8,154 Depreciation - standard 80 Depreciation - no standard life assets 1,086 1, Depreciation - modified life assets 82 Depreciation - alternative depreciation in accordance with CPP 83 Total depreciation 9,240 9, (vi): Disclosure of Changes to Depreciation Profiles ($000 unless otherwise specified) 86 Asset or assets with changes to depreciation* Reason for non-standard depreciation (text entry) * include additional rows if needed Depreciation charge for the period (RAB) Closing RAB value under 'nonstandard' under 'standard' Closing RAB value depreciation depreciation 96 4(vii): Disclosure by Asset Category 97 ($000 unless otherwise specified) Distribution Subtransmission Subtransmission Distribution and Distribution and substations and Distribution Other network Non-network 98 lines cables Zone substations LV lines LV cables transformers switchgear assets assets Total 99 Total opening RAB value 13, ,459 46,954 60,538 55,597 35,300 1,138 15, , less Total depreciation ,064 1,785 1,447 1,812 1, ,112 9, plus Total revaluations , plus Assets commissioned ,433 6,950 3, , less Asset disposals plus Lost and found assets adjustment 105 plus Adjustment resulting from asset allocation 106 plus Asset category transfers (0) 1, (0) (510) (706) (245) Total closing RAB value 12, ,431 48,050 66,678 57,735 34, , , Asset Life 110 Weighted average remaining asset life (years) 111 Weighted average expected total asset life (years) EDB-ID-determination-templates-for-schedules-1-to-10-v March-2.xlsx 6 S4.RAB Value (Rolled Forward)

7 SCHEDULE 5a: REPORT ON REGULATORY TAX ALLOWANCE 7 5a(i): Regulatory Tax Allowance ($000) 8 Regulatory profit / (loss) before tax 17, plus Income not included in regulatory profit / (loss) before tax but taxable 188 * 11 Expenditure or loss in regulatory profit / (loss) before tax but not deductible 192 * 12 Amortisation of initial differences in asset values 2, Amortisation of revaluations , less Total revaluations 2, Income included in regulatory profit / (loss) before tax but not taxable * 18 Discretionary discounts and customer rebates 2, Expenditure or loss deductible but not in regulatory profit / (loss) before tax 398 * 20 Notional deductible interest 4, , Regulatory taxable income 9, less Utilised tax losses 26 Regulatory net taxable income 9, Corporate tax rate (%) 28% 29 Regulatory tax allowance 2, * Workings to be provided in Schedule a(ii): Disclosure of Permanent Differences 33 In Schedule 14, Box 5, provide descriptions and workings of items recorded in the asterisked categories in Schedule 5a(i). This schedule requires information on the calculation of the regulatory tax allowance. This information is used to calculate regulatory profit/loss in Schedule 3 (regulatory profit). EDBs must provide explanatory commentary on the information disclosed in this schedule, in Schedule 14 (Mandatory Explanatory Notes). This information is part of audited disclosure information (as defined in section 1.4 of the ID determination), and so is subject to the assurance report required by section a(iii): Amortisation of Initial Difference in Asset Values ($000) Opening unamortised initial differences in asset values 62, less Amortisation of initial differences in asset values 2, plus Adjustment for unamortised initial differences in assets acquired 39 less Adjustment for unamortised initial differences in assets disposed Closing unamortised initial differences in asset values 59, Opening weighted average remaining useful life of relevant assets (years) a(iv): Amortisation of Revaluations ($000) Opening sum of RAB values without revaluations 233, Adjusted depreciation 8, Total depreciation 9, Amortisation of revaluations a(v): Reconciliation of Tax Losses ($000) Opening tax losses 55 plus Current period tax losses 56 less Utilised tax losses 57 Closing tax losses 58 5a(vi): Calculation of Deferred Tax Balance ($000) Opening deferred tax (10,975) plus Tax effect of adjusted depreciation 2, less Tax effect of tax depreciation 3, plus Tax effect of other temporary differences* less Tax effect of amortisation of initial differences in asset values plus Deferred tax balance relating to assets acquired in the disclosure year less Deferred tax balance relating to assets disposed in the disclosure year plus Deferred tax cost allocation adjustment Closing deferred tax (12,615) a(vii): Disclosure of Temporary Differences In Schedule 14, Box 6, provide descriptions and workings of items recorded in the asterisked category in Schedule 5a(vi) (Tax effect of other temporary differences). 81 5a(viii): Regulatory Tax Asset Base Roll-Forward 82 ($000) 83 Opening sum of regulatory tax asset values 132, less Tax depreciation 11, plus Regulatory tax asset value of assets commissioned 14, less Regulatory tax asset value of asset disposals plus Lost and found assets adjustment 88 plus Adjustment resulting from asset allocation 89 plus Other adjustments to the RAB tax value 90 Closing sum of regulatory tax asset values 134,592 EDB-ID-determination-templates-for-schedules-1-to-10-v March-2.xlsx 7 S5a.Regulatory Tax Allowance

8 SCHEDULE 5b: REPORT ON RELATED PARTY TRANSACTIONS 7 5b(i): Summary Related Party Transactions ($000) 8 Total regulatory income 9 Operational expenditure 3, Capital expenditure 4, Market value of asset disposals 12 Other related party transactions This schedule provides information on the valuation of related party transactions, in accordance with section and of the ID determination. This information is part of audited disclosure information (as defined in section 1.4 of the ID determination), and so is subject to the assurance report required by section b(ii): Entities Involved in Related Party Transactions 14 Name of related party 15 field services 16 Fibre 17 Ashburton District Council * include additional rows if needed Related party relationship A division of which supplies electricity distribution contracting services A division of which supplies fibre communication services Significant shareholder 21 5b(iii): Related Party Transactions 22 Name of related party Related party transaction type Description of transaction Value of transaction ($000) Basis for determining value 23 field services Opex Service interruptions and emergencies 774 ID clause 2.3.6(1)(b) 24 field services Opex Vegetation management 138 ID clause 2.3.6(1)(b) 25 field services Opex Network maintenance 1,640 ID clause 2.3.6(1)(b) 26 field services Opex System operations and network support 301 ID clause 2.3.6(1)(b) 27 field services Opex Business support 135 ID clause 2.3.6(1)(b) 28 field services Capex RAB assets 4,724 IM clause (5)(g) 29 [Select one] [Select one] 30 Fibre Opex System operations and network support 776 ID clause 2.3.6(1)(f) 31 [Select one] [Select one] 32 Ashburton District Council Opex Rates 178 ID clause 2.3.6(1)(a) 37 [Select one] [Select one] 38 * include additional rows if needed EDB-ID-determination-templates-for-schedules-1-to-10-v March-2.xlsx 8 S5b.Related Party Transactions

9 7 SCHEDULE 5c: REPORT ON TERM CREDIT SPREAD DIFFERENTIAL ALLOWANCE 8 5c(i): Qualifying Debt (may be Commission only) 9 This schedule is only to be completed if, as at the date of the most recently published financial statements, the weighted average original tenor of the debt portfolio (both qualifying debt and non-qualifying debt) is greater than five years. This information is part of audited disclosure information (as defined in section 1.4 of the ID determination), and so is subject to the assurance report required by section Issuing party Issue date Pricing date Original tenor (in years) Coupon rate (%) Book value at issue date (NZD) Book value at date of financial statements (NZD) Term Credit Spread Difference Cost of executing an interest rate swap Debt issue cost readjustment * include additional rows if needed c(ii): Attribution of Term Credit Spread Differential Gross term credit spread differential Total book value of interest bearing debt 23 Leverage 44% 24 Average opening and closing RAB values 25 Attribution Rate (%) Term credit spread differential allowance EDB-ID-determination-templates-for-schedules-1-to-10-v March-2.xlsx 9 S5c.TCSD Allowance

10 SCHEDULE 5d: REPORT ON COST ALLOCATIONS 7 5d(i): Operating Cost Allocations 8 Value allocated ($000s) 9 Arm's length deduction Electricity distribution services Non-electricity distribution services Total 10 Service interruptions and emergencies 11 Directly attributable Not directly attributable 13 Total attributable to regulated service Vegetation management 15 Directly attributable Not directly attributable 17 Total attributable to regulated service Routine and corrective maintenance and inspection 19 Directly attributable Not directly attributable 21 Total attributable to regulated service Asset replacement and renewal 23 Directly attributable 1, Not directly attributable 25 Total attributable to regulated service 1, System operations and network support 27 Directly attributable 3, Not directly attributable OVABAA allocation increase ($000s) 29 Total attributable to regulated service 3, Business support 31 Directly attributable 5, Not directly attributable 33 Total attributable to regulated service 5, Operating costs directly attributable 12, Operating costs not directly attributable 37 Operational expenditure 12, d(ii): Other Cost Allocations 40 Pass through and recoverable costs ($000) 41 Pass through costs 42 Directly attributable Not directly attributable 44 Total attributable to regulated service Recoverable costs 46 Directly attributable 12, Not directly attributable 48 Total attributable to regulated service 12, d(iii): Changes in Cost Allocations* 51 ($000) 52 Change in cost allocation 1 CY-1 Current Year (CY) 53 Cost category Original allocation 54 Original allocator or line items New allocation 55 New allocator or line items Difference Rationale for change Change in cost allocation 2 CY-1 ($000) Current Year (CY) 62 Cost category Original allocation 63 Original allocator or line items New allocation 64 New allocator or line items Difference Rationale for change ($000) 70 Change in cost allocation 3 CY-1 Current Year (CY) 71 Cost category Original allocation 72 Original allocator or line items New allocation 73 New allocator or line items Difference Rationale for change * a change in cost allocation must be completed for each cost allocator change that has occurred in the disclosure year. A movement in an allocator metric is not a change in allocator or component. 79 include additional rows if needed This schedule provides information on the allocation of operational costs. EDBs must provide explanatory comment on their cost allocation in Schedule 14 (Mandatory Explanatory Notes), including on the impact of any reclassifications. This information is part of audited disclosure information (as defined in section 1.4 of the ID determination), and so is subject to the assurance report required by section 2.8. EDB-ID-determination-templates-for-schedules-1-to-10-v March-2.xlsx 10 S5d.Cost Allocations

11 SCHEDULE 5e: REPORT ON ASSET ALLOCATIONS 7 5e(i): Regulated Service Asset Values Value allocated 8 ($000s) Electricity distribution 9 services 10 Subtransmission lines 11 Directly attributable 12, Not directly attributable 13 Total attributable to regulated service 12, Subtransmission cables 15 Directly attributable Not directly attributable 17 Total attributable to regulated service Zone substations 19 Directly attributable 23, Not directly attributable 21 Total attributable to regulated service 23, Distribution and LV lines 23 Directly attributable 48, Not directly attributable 25 Total attributable to regulated service 48, Distribution and LV cables 27 Directly attributable 66, Not directly attributable 29 Total attributable to regulated service 66, Distribution substations and transformers 31 Directly attributable 57, Not directly attributable 33 Total attributable to regulated service 57, Distribution switchgear 35 Directly attributable 34, Not directly attributable 37 Total attributable to regulated service 34, Other network assets 39 Directly attributable Not directly attributable 41 Total attributable to regulated service Non-network assets 43 Directly attributable 14, Not directly attributable 45 Total attributable to regulated service 14, Regulated service asset value directly attributable 259, Regulated service asset value not directly attributable 49 Total closing RAB value 259, e(ii): Changes in Asset Allocations* 52 This schedule requires information on the allocation of asset values. This information supports the calculation of the RAB value in Schedule 4. EDBs must provide explanatory comment on their cost allocation in Schedule 14 (Mandatory Explanatory Notes), including on the impact of any changes in asset allocations. This information is part of audited disclosure information (as defined in section 1.4 of the ID determination), and so is subject to the assurance report required by section Change in asset value allocation 1 CY-1 Current Year (CY) 54 Asset category Original allocation 55 Original allocator or line items New allocation 56 New allocator or line items Difference Rationale for change ($000) 62 Change in asset value allocation 2 CY-1 Current Year (CY) 63 Asset category Original allocation 64 Original allocator or line items New allocation 65 New allocator or line items Difference Rationale for change ($000) 71 Change in asset value allocation 3 CY-1 Current Year (CY) 72 Asset category Original allocation 73 Original allocator or line items New allocation 74 New allocator or line items Difference Rationale for change * a change in asset allocation must be completed for each allocator or component change that has occurred in the disclosure year. A movement in an allocator metric is not a change in allocator or component. include additional rows if needed ($000) EDB-ID-determination-templates-for-schedules-1-to-10-v March-2.xlsx 11 S5e.Asset Allocations

12 SCHEDULE 6a: REPORT ON CAPITAL EXPENDITURE FOR THE DISCLOSURE YEAR This schedule requires a breakdown of capital expenditure on assets incurred in the disclosure year, including any assets in respect of which capital contributions are received, but excluding assets that are vested assets. Information on expenditure on assets must be provided on an accounting accruals basis and must exclude finance costs. EDBs must provide explanatory comment on their expenditure on assets in Schedule 14 (Explanatory Notes to Templates). This information is part of audited disclosure information (as defined in section 1.4 of the ID determination), and so is subject to the assurance report required by section a(i): Expenditure on Assets ($000) ($000) 8 Consumer connection 2,178 9 System growth 3, Asset replacement and renewal 8, Asset relocations Reliability, safety and environment: 13 Quality of supply 1, Legislative and regulatory 15 Other reliability, safety and environment Total reliability, safety and environment 1, Expenditure on network assets 15, Expenditure on non-network assets Expenditure on assets 16, plus Cost of financing 22 less Value of capital contributions plus Value of vested assets Capital expenditure 16, a(ii): Subcomponents of Expenditure on Assets (where known) ($000) 27 Energy efficiency and demand side management, reduction of energy losses 28 Overhead to underground conversion 5, Research and development 30 6a(iii): Consumer Connection 31 Consumer types defined by EDB* ($000) ($000) 32 ICP's which have changed their capacity Safety related Large new connections Rural with no transformer new connections 222 Rural with transformer new connections 1,056 Subdivision new connections Urban new connections * include additional rows if needed 38 Consumer connection expenditure 2, less Capital contributions funding consumer connection expenditure Consumer connection less capital contributions 1,993 Asset Replacement 42 6a(iv): System Growth and Asset Replacement and Renewal and 43 System Growth Renewal 44 ($000) ($000) 45 Subtransmission Zone substations Distribution and LV lines 507 1, Distribution and LV cables 561 5, Distribution substations and transformers 1, Distribution switchgear Other network assets 52 System growth and asset replacement and renewal expenditure 3,138 8, less Capital contributions funding system growth and asset replacement and renewal 8 54 System growth and asset replacement and renewal less capital contributions 3,138 8, a(v): Asset Relocations 57 Project or programme* ($000) ($000) 58 [ ] unplanned relocation line requested by customer [Description of material project or programme] 60 [Description of material project or programme] 61 [Description of material project or programme] 62 [Description of material project or programme] 63 * include additional rows if needed 64 All other projects or programmes - asset relocations 65 Asset relocations expenditure less Capital contributions funding asset relocations 8 67 Asset relocations less capital contributions a(vi): Quality of Supply 70 Project or programme* ($000) ($000) 71 [ ][358] ZSS TIN 22/11 Transformer and Switchgear [ ] Rural Ring Main Unit Installations [ ] SCADA - Distribution Automatiom [ ] ZSS - Replace Beckwith VRR - Dorie, Coldstream, Wakanui 52 [ ] ZSS MTV & TIN - Neutral Switch 10 [ ] 66/22kV OH New River Piles Ashburton River North Branch [ ] 22kV UG New Tinwald ZZS Hinds Hwy, Fords Rd Tie Cable * include additional rows if needed 77 All other projects programmes - quality of supply Quality of supply expenditure 1, less Capital contributions funding quality of supply 80 Quality of supply less capital contributions 1, a(vii): Legislative and Regulatory 82 Project or programme* ($000) ($000) 83 [Description of material project or programme] 84 [Description of material project or programme] 85 [Description of material project or programme] 86 [Description of material project or programme] 87 [Description of material project or programme] 88 * include additional rows if needed 89 All other projects or programmes - legislative and regulatory 90 Legislative and regulatory expenditure 91 less Capital contributions funding legislative and regulatory 92 Legislative and regulatory less capital contributions 93 6a(viii): Other Reliability, Safety and Environment 94 Project or programme* ($000) ($000) 95 [ ] ZZ Substation Surveillance Programme 9 96 [ ] Earthing upgrade [Description of material project or programme] 98 [Description of material project or programme] 99 [Description of material project or programme] 100 * include additional rows if needed 101 All other projects or programmes - other reliability, safety and environment Other reliability, safety and environment expenditure less Capital contributions funding other reliability, safety and environment 104 Other reliability, safety and environment less capital contributions a(ix): Non-Network Assets 107 Routine expenditure 108 Project or programme* ($000) ($000) 109 [ ] Routine Vehicles [ ] Routine Info Tech [ ] Routine Building Work [ ] Routine Plant All other projects or programmes - routine expenditure 116 Routine expenditure Atypical expenditure 118 Project or programme* ($000) ($000) 119 [ ] DMR Repeater Stations for Rakaia Gorge [ ] Software - ICP Management [ ] Software - ERP Development [ ] Software/Hardware - IT Field Mobility 18 [ ] Hardware (IT) - New and Upgraded [ ] Transformer Test Equipment * include additional rows if needed 125 All other projects or programmes - atypical expenditure Atypical expenditure Expenditure on non-network assets 957 EDB-ID-determination-templates-for-schedules-1-to-10-v March-2.xlsx 12 S6a.Actual Expenditure Capex

13 SCHEDULE 6b: REPORT ON OPERATIONAL EXPENDITURE FOR THE DISCLOSURE YEAR This schedule requires a breakdown of operational expenditure incurred in the disclosure year. EDBs must provide explanatory comment on their operational expenditure in Schedule 14 (Explanatory notes to templates). This includes explanatory comment on any atypical operational expenditure and assets replaced or renewed as part of asset replacement and renewal operational expenditure, and additional information on insurance. This information is part of audited disclosure information (as defined in section 1.4 of the ID determination), and so is subject to the assurance report required by section b(i): Operational Expenditure ($000) ($000) 8 Service interruptions and emergencies Vegetation management Routine and corrective maintenance and inspection Asset replacement and renewal 1, Network opex 3, System operations and network support 3, Business support 5, Non-network opex 8, Operational expenditure 12, b(ii): Subcomponents of Operational Expenditure (where known) 19 Energy efficiency and demand side management, reduction of energy losses Direct billing* 21 Research and development 22 Insurance * Direct billing expenditure by suppliers that directly bill the majority of their consumers EDB-ID-determination-templates-for-schedules-1-to-10-v March-2.xlsx 13 S6b.Actual Expenditure Opex

14 SCHEDULE 7: COMPARISON OF FORECASTS TO ACTUAL EXPENDITURE This schedule compares actual revenue and expenditure to the previous forecasts that were made for the disclosure year. Accordingly, this schedule requires the forecast revenue and expenditure information from previous disclosures to be inserted. EDBs must provide explanatory comment on the variance between actual and target revenue and forecast expenditure in Schedule 14 (Mandatory Explanatory Notes). This information is part of the audited disclosure information (as defined in section 1.4 of the ID determination), and so is subject to the assurance report required by section 2.8. For the purpose of this audit, target revenue and forecast expenditures only need to be verified back to previous disclosures. 7 7(i): Revenue Target ($000) ¹ Actual ($000) % variance 8 Line charge revenue 47,960 48,524 1% 9 7(ii): Expenditure on Assets Forecast ($000) ² Actual ($000) % variance 10 Consumer connection 2,990 2,178 (27%) 11 System growth 3,312 3,138 (5%) 12 Asset replacement and renewal 10,399 8,398 (19%) 13 Asset relocations Reliability, safety and environment: 15 Quality of supply 2,254 1,668 (26%) 16 Legislative and regulatory 17 Other reliability, safety and environment (91%) 18 Total reliability, safety and environment 2,803 1,718 (39%) 19 Expenditure on network assets 19,504 15,460 (21%) 20 Expenditure on non-network assets 2, (55%) 21 Expenditure on assets 21,633 16,416 (24%) 22 7(iii): Operational Expenditure 23 Service interruptions and emergencies (9%) 24 Vegetation management (53%) 25 Routine and corrective maintenance and inspection % 26 Asset replacement and renewal 846 1,553 84% 27 Network opex 3,115 3,535 13% 28 System operations and network support 3,424 3,317 (3%) 29 Business support 5,188 5,210 0% 30 Non-network opex 8,612 8,527 (1%) 31 Operational expenditure 11,727 12,062 3% 32 7(iv): Subcomponents of Expenditure on Assets (where known) 33 Energy efficiency and demand side management, reduction of energy losses 34 Overhead to underground conversion 9,446 5,352 (43%) 35 Research and development (v): Subcomponents of Operational Expenditure (where known) 38 Energy efficiency and demand side management, reduction of energy losses Direct billing 40 Research and development 41 Insurance From the nominal dollar target revenue for the disclosure year disclosed under clause 2.4.3(3) of this determination 44 2 From the CY+1 nominal dollar expenditure forecasts disclosed in accordance with clause for the forecast period starting at the beginning of the disclosure year (the second to last disclosure of Schedules 11a and 11b) EDB-ID-determination-templates-for-schedules-1-to-10-v March-2.xlsx 14 S7.Actual vs Forecast

15 SCHEDULE 8: REPORT ON BILLED QUANTITIES AND LINE CHARGE REVENUES This schedule requires the billed quantities and associated line charge revenues for each price category code used by the EDB in its pricing schedules. Information is also required on the number of ICPs that are included in each consumer group or price category code, and the energy delivered to these ICPs. Network / Sub-Network Name Total Network 8 8(i): Billed Quantities by Price Component 9 Billed quantities by price component Price component General Supply Uncontrolled Energy Controlled Off- Peak Energy Night Boost 10 Night Rate Under Verandah Floodlight Export kwh Generation Credit Connected kw Connected kw Industrial MD Industrial Peak MD Industrial Large User Industrial Energy Large User Fixed Large User MD Large User Energy Streetlighting Anytime MD Connected kw Energy delivered to Unit charging basis (eg, days, kw of demand, per kva per per kva per per kva per per kva per per fitting per per day per kwh per kwh per kwh per kwh per day per day per kwh per kwh per kw day per kw Consumer group name or price Consumer type or types (eg, Standard or non-standard Average no. of ICPs in ICPs in disclosure year kva of capacity, etc.) per kwh per month per kw day per kwh month month month month day category code residential, commercial etc.) consumer group (specify) disclosure year (MWh) General Supply - 20 kva General Standard 14, ,562 15,027 89,438,401 28,613, ,019 4,490, , ,862 General Supply - 50 kva General Standard 1,600 35,943 1,602 32,969,477 2,283, , , ,647 3,668 General Supply kva General Standard , ,144, ,723 56, , ,182 General Supply kva General Standard , ,642, , ,971 62,336 8,637 kva General Standard Irrigation Irrigation Standard 1, , ,875, , Irrigation Harmonic Penalty Irrigation Standard 7 1,413 1,413, Industrial 400V Supply - kva Industrial Standard 39 52,963 11,570 52,963,028 Direct Supply - Day Demand Industrial Standard 1 1, ,178,061 Direct Supply - Peak Demand Industrial Standard 4 2, ,192,214 CMP Large User Standard 1 34, ,801 34,985,040 Silver Fern Farms Large User Standard 1 5, ,195 5,094,334 Mt Hutt Ski Area Large User Standard 1 2, ,201,622 Highbank Pumps Large User Standard 1 5,712 9,600 5,712,146 Highbank Generation Generation Standard ,855,905 Montalto Generation Generation Standard ,509,598 Cleardale Generation Generation Standard 1 1 3,955,646 Lavington Generation Generation Standard 1 1 3,103,671 Street Lighting Street Lighting Standard 8 1,739 3,352 Standard consumer totals 19, ,235 17, ,483,635 32,063, ,779 5,347, , , , , ,333, ,993 9, ,417,962 3,352 Non-standard consumer totals Total for all consumers 19, ,235 17, ,483,635 32,063, ,779 5,347, , , , , ,333, ,993 9, ,417,962 3,352 8(ii): Line Charge Revenues ($000) by Price Component Line charge revenues ($000) by price component Price component Uncontrolled Controlled Off- Industrial Peak Industrial Large User General Supply Night Boost 10 Night Rate Under Verandah Floodlight Export kwh Generation Credit Connected kw Connected kw Industrial MD Industrial Energy Large User Fixed Large User MD Large User Energy Streetlighting Energy Peak Energy MD Anytime MD Connected kw Total transmission Notional revenue Total distribution line charge Rate (eg, $ per day, $ per kva per per kva per per kva per per kva per per fitting per per day per kwh per kwh per kwh per kwh per day per day per kwh per kwh per kw day per kw per kwh per month per kw day per kwh Consumer group name or price Consumer type or types (eg, Standard or non-standard Total line charge revenue foregone from posted line charge revenue (if per kwh, etc.) month month month month day category code residential, commercial etc.) consumer group (specify) in disclosure year discounts (if applicable) revenue available) General Supply - 20 kva General Standard $9,482 $7,374 $2,108 $823 $8,146 $498 $14 $1 $0 General Supply - 50 kva General Standard $3,225 $2,447 $778 $175 $3,007 $40 $2 $0 $0 General Supply kva General Standard $5,370 $4,022 $1,349 $142 $5,212 $15 $1 $0 $0 General Supply kva General Standard $4,074 $3,044 $1,030 $88 $3,980 $6 kva General Standard $9 $9 $0 $9 $0 Irrigation Irrigation Standard $21,914 $15,352 $6,562 $21,963 ($48) Irrigation Harmonic Penalty Irrigation Standard $128 $97 $31 $128 Industrial 400V Supply - kva Industrial Standard $1,821 $1,193 $629 $1,821 Direct Supply - Day Demand Industrial Standard $35 $23 $12 $35 Direct Supply - Peak Demand Industrial Standard $127 $87 $40 $46 $81 CMP Large User Standard $606 $291 $315 $243 $363 Silver Fern Farms Large User Standard $107 $42 $65 $33 $75 Mt Hutt Ski Area Large User Standard $192 $138 $54 $129 $62 Highbank Pumps Large User Standard $689 $229 $459 $689 Highbank Generation Generation Standard $386 $386 $386 Montalto Generation Generation Standard $34 $34 $34 Cleardale Generation Generation Standard $31 $31 $31 Lavington Generation Generation Standard $8 $8 $8 Street Lighting Street Lighting Standard $285 $285 $285 Standard consumer totals $48,524 $35,092 $13,432 $1,238 $20,345 $558 $17 $2 $1 $22,090 ($48) $1,857 $46 $81 $864 $501 $689 $285 Non-standard consumer totals Total for all consumers $48,524 $35,092 $13,432 $1,238 $20,345 $558 $17 $2 $1 $22,090 ($48) $1,857 $46 $81 $864 $501 $689 $285 8(iii): Number of ICPs directly billed Check OK Number of directly billed ICPs at year end 0 EDB-ID-determination-templates-for-schedules-1-to-10-v March-2.xlsx 15 S8.Billed Quantities+Revenues

16 SCHEDULE 9a: ASSET REGISTER Network / Sub-network Name Total Network This schedule requires a summary of the quantity of assets that make up the network, by asset category and asset class. All units relating to cable and line assets, that are expressed in km, refer to circuit lengths. Items at start of year (quantity) Items at end of year (quantity) Data accuracy (1 4) 8 Voltage Asset category Asset class Units Net change 9 All Overhead Line Concrete poles / steel structure No. 2,458 2, All Overhead Line Wood poles No. 26,690 27, All Overhead Line Other pole types No. N/A 12 HV Subtransmission Line Subtransmission OH up to 66kV conductor km (8) 4 13 HV Subtransmission Line Subtransmission OH 110kV+ conductor km N/A 14 HV Subtransmission Cable Subtransmission UG up to 66kV (XLPE) km HV Subtransmission Cable Subtransmission UG up to 66kV (Oil pressurised) km N/A 16 HV Subtransmission Cable Subtransmission UG up to 66kV (Gas pressurised) km N/A 17 HV Subtransmission Cable Subtransmission UG up to 66kV (PILC) km N/A 18 HV Subtransmission Cable Subtransmission UG 110kV+ (XLPE) km N/A 19 HV Subtransmission Cable Subtransmission UG 110kV+ (Oil pressurised) km N/A 20 HV Subtransmission Cable Subtransmission UG 110kV+ (Gas Pressurised) km N/A 21 HV Subtransmission Cable Subtransmission UG 110kV+ (PILC) km N/A 22 HV Subtransmission Cable Subtransmission submarine cable km N/A 23 HV Zone substation Buildings Zone substations up to 66kV No HV Zone substation Buildings Zone substations 110kV+ No. N/A 25 HV Zone substation switchgear 50/66/110kV CB (Indoor) No. 6 (6) N/A 26 HV Zone substation switchgear 50/66/110kV CB (Outdoor) No HV Zone substation switchgear 33kV Switch (Ground Mounted) No. 124 (124) N/A 28 HV Zone substation switchgear 33kV Switch (Pole Mounted) No HV Zone substation switchgear 33kV RMU No. N/A 30 HV Zone substation switchgear 22/33kV CB (Indoor) No. N/A 31 HV Zone substation switchgear 22/33kV CB (Outdoor) No HV Zone substation switchgear 3.3/6.6/11/22kV CB (ground mounted) No HV Zone substation switchgear 3.3/6.6/11/22kV CB (pole mounted) No HV Zone Substation Transformer Zone Substation Transformers No HV Distribution Line Distribution OH Open Wire Conductor km 2,013 2, HV Distribution Line Distribution OH Aerial Cable Conductor km N/A 37 HV Distribution Line SWER conductor km N/A 38 HV Distribution Cable Distribution UG XLPE or PVC km HV Distribution Cable Distribution UG PILC km HV Distribution Cable Distribution Submarine Cable km N/A 41 HV Distribution switchgear 3.3/6.6/11/22kV CB (pole mounted) - reclosers and sectionalisers No HV Distribution switchgear 3.3/6.6/11/22kV CB (Indoor) No. N/A 43 HV Distribution switchgear 3.3/6.6/11/22kV Switches and fuses (pole mounted) No. 7,618 7, HV Distribution switchgear 3.3/6.6/11/22kV Switch (ground mounted) - except RMU No. 207 (207) N/A 45 HV Distribution switchgear 3.3/6.6/11/22kV RMU No HV Distribution Transformer Pole Mounted Transformer No. 5,280 5,154 (126) 3 47 HV Distribution Transformer Ground Mounted Transformer No. 2,090 2, HV Distribution Transformer Voltage regulators No HV Distribution Substations Ground Mounted Substation Housing No LV LV Line LV OH Conductor km (5) 3 51 LV LV Cable LV UG Cable km (0) 3 52 LV LV Street lighting LV OH/UG Streetlight circuit km LV Connections OH/UG consumer service connections No. 19,449 19, All Protection Protection relays (electromechanical, solid state and numeric) No All SCADA and communications SCADA and communications equipment operating as a single system Lot All Capacitor Banks Capacitors including controls No N/A 57 All Load Control Centralised plant Lot 3 3 N/A 58 All Load Control Relays No All Civils Cable Tunnels km N/A EDB-ID-determination-templates-for-schedules-1-to-10-v March-2.xlsx 16 S9a.Asset Register

17 SCHEDULE 9b: ASSET AGE PROFILE This schedule requires a summary of the age profile (based on year of installation) of the assets that make up the network, by asset category and asset class. All units relating to cable and line assets, that are expressed in km, refer to circuit lengths. Network / Sub-network Name 8 Disclosure Year (year ended) Number of assets at disclosure year end by installation date No. with end of No. with age year default Data accuracy 9 Voltage Asset category Asset class Units pre unknown (quantity) dates (1 4) 10 All Overhead Line Concrete poles / steel structure No , , All Overhead Line Wood poles No ,020 1,229 4,161 6, ,547 1, , , All Overhead Line Other pole types No. N/A 13 HV Subtransmission Line Subtransmission OH up to 66kV conductor km HV Subtransmission Line Subtransmission OH 110kV+ conductor km N/A 15 HV Subtransmission Cable Subtransmission UG up to 66kV (XLPE) km HV Subtransmission Cable Subtransmission UG up to 66kV (Oil pressurised) km N/A 17 HV Subtransmission Cable Subtransmission UG up to 66kV (Gas pressurised) km N/A 18 HV Subtransmission Cable Subtransmission UG up to 66kV (PILC) km N/A 19 HV Subtransmission Cable Subtransmission UG 110kV+ (XLPE) km N/A 20 HV Subtransmission Cable Subtransmission UG 110kV+ (Oil pressurised) km N/A 21 HV Subtransmission Cable Subtransmission UG 110kV+ (Gas Pressurised) km N/A 22 HV Subtransmission Cable Subtransmission UG 110kV+ (PILC) km N/A 23 HV Subtransmission Cable Subtransmission submarine cable km N/A 24 HV Zone substation Buildings Zone substations up to 66kV No HV Zone substation Buildings Zone substations 110kV+ No. N/A 26 HV Zone substation switchgear 50/66/110kV CB (Indoor) No. N/A 27 HV Zone substation switchgear 50/66/110kV CB (Outdoor) No HV Zone substation switchgear 33kV Switch (Ground Mounted) No. N/A 29 HV Zone substation switchgear 33kV Switch (Pole Mounted) No HV Zone substation switchgear 33kV RMU No. N/A 31 HV Zone substation switchgear 22/33kV CB (Indoor) No. N/A 32 HV Zone substation switchgear 22/33kV CB (Outdoor) No HV Zone substation switchgear 3.3/6.6/11/22kV CB (ground mounted) No HV Zone substation switchgear 3.3/6.6/11/22kV CB (pole mounted) No HV Zone Substation Transformer Zone Substation Transformers No HV Distribution Line Distribution OH Open Wire Conductor km , HV Distribution Line Distribution OH Aerial Cable Conductor km N/A 38 HV Distribution Line SWER conductor km N/A 39 HV Distribution Cable Distribution UG XLPE or PVC km HV Distribution Cable Distribution UG PILC km HV Distribution Cable Distribution Submarine Cable km N/A 42 HV Distribution switchgear 3.3/6.6/11/22kV CB (pole mounted) - reclosers and sectionalisers No HV Distribution switchgear 3.3/6.6/11/22kV CB (Indoor) No. N/A 44 HV Distribution switchgear 3.3/6.6/11/22kV Switches and fuses (pole mounted) No ,400 7, HV Distribution switchgear 3.3/6.6/11/22kV Switch (ground mounted) - except RMU No. N/A 46 HV Distribution switchgear 3.3/6.6/11/22kV RMU No HV Distribution Transformer Pole Mounted Transformer No , HV Distribution Transformer Ground Mounted Transformer No , HV Distribution Transformer Voltage regulators No HV Distribution Substations Ground Mounted Substation Housing No LV LV Line LV OH Conductor km LV LV Cable LV UG Cable km LV LV Street lighting LV OH/UG Streetlight circuit km LV Connections OH/UG consumer service connections No. 14, , All Protection Protection relays (electromechanical, solid state and numeric) No All SCADA and communications SCADA and communications equipment operating as a single system Lot All Capacitor Banks Capacitors including controls No N/A 58 All Load Control Centralised plant Lot N/A 59 All Load Control Relays No All Civils Cable Tunnels km N/A EDB-ID-determination-templates-for-schedules-1-to-10-v March-2.xlsx 17 S9b.Asset Age Profile