EDB Information Disclosure Requirements Information Templates for Schedules 1 10

Transcription

1 EDB Information Disclosure Requirements Information Templates for Schedules 1 10 Disclosure Date 31 August 2018 Disclosure Year (year ended) Templates for Schedules 1 10 excluding 5f 5g Template Version 4.1. Prepared 24 March 2015 Unison - ID Schedule Templates 1 to 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 Unison - ID Schedule Templates 1 to XLSX 2 TOC

3 Disclosure Template Instructions These templates have been prepared for use by EDBs when making disclosures under clauses 2.3.1, , , 2.5.1, and of the Electricity Distribution Information Disclosure Determination and Dates To prepare the templates for disclosure, the supplier's company name should be entered in cell C8, the date of the last day of the current (disclosure) year should be entered in cell C12, and the date on which the information is disclosed should be entered in cell C10 of the CoverSheet worksheet. The cell C12 entry (current year) is used to calculate disclosure years in the column headings that show above some of the tables and in labels adjacent to some entry cells. It is also used to calculate the For year ended date in the template title blocks (the title blocks are the light green shaded areas at the top of each template). The cell C8 entry (company name) is used in the template title blocks. Dates should be entered in day/month/year order (Example -"1 April 2013"). Data Entry Cells and Calculated Cells Data entered into this workbook may be entered only into the data entry cells. Data entry cells are the bordered, unshaded areas (white cells) in each template. Under no circumstances should data be entered into the workbook outside a data entry cell. In some cases, where the information for disclosure is able to be ascertained from disclosures elsewhere in the workbook, such information is disclosed in a calculated cell. Validation Settings on Data Entry Cells To maintain a consistency of format and to help guard against errors in data entry, some data entry cells test keyboard entries for validity and accept only a limited range of values. For example, entries may be limited to a list of category names, to values between 0% and 100%, or either a numeric entry or the text entry N/A. Where this occurs, a validation message will appear when data is being entered. These checks are applied to keyboard entries only and not, for example, to entries made using Excel s copy and paste facility. Conditional Formatting Settings on Data Entry Cells Schedule 2 cells G79 and I79:L79 will change colour if the total cashflows do not equal the corresponding values in table 2(ii). Schedule 4 cells P99:P105 and P107 will change colour if the RAB values do not equal the corresponding values in table 4(ii). Schedule 9b columns AA to AE (2013 to 2017) contain conditional formatting. The data entry cells for future years are hidden (are changed from white to yellow). Schedule 9b cells AG10 to AG60 will change colour if the total assets at year end for each asset class does not equal the corresponding values in column I in Schedule 9a. Schedule 9c cell G30 will change colour if G30 (overhead circuit length by terrain) does not equal G18 (overhead circuit length by operating voltage). Inserting Additional Rows and Columns The templates for schedules 4, 5b, 5c, 5d, 5e, 6a, 8, 9d, and 9e may require additional rows to be inserted in tables marked 'include additional rows if needed' or similar. Column A schedule references should not be entered in additional rows, and should be deleted from additional rows that are created by copying and pasting rows that have schedule references. Additional rows in schedules 5c, 6a, and 9e must not be inserted directly above the first row or below the last row of a table. This is to ensure that entries made in the new row are included in the totals. Schedules 5d and 5e may require new cost or asset category rows to be inserted in allocation change tables 5d(iii) and 5e(ii). Accordingly, cell protection has been removed from rows 77 and 78 of the respective templates to allow blocks of rows to be copied. The four steps to add new cost category rows to table 5d(iii) are: Select Excel rows 69:77, copy, select Excel row 78, insert copied cells. Similarly, for table 5e(ii): Select Excel rows 70:78, copy, select Excel row 79, then insert copied cells. The template for schedule 8 may require additional columns to be inserted between column P and U. To avoid interfering with the title block entries, these should be inserted to the left of column S. If inserting additional columns, the formulas for standard consumers total, non-standard consumers totals and total for all consumers will need to be copied into the cells of the added columns. The formulas can be found in the equivalent cells of the existing columns. Unison - ID Schedule Templates 1 to XLSX 3 Instructions

4 Disclosures by Sub-Network If the supplier has sub-networks, schedules 8, 9a, 9b, 9c, 9e, and 10 must be completed for the network and for each sub-network. A copy of the schedule worksheet(s) must be made for each sub-network and named accordingly. Schedule References The references labelled '' in the leftmost column of each template are consistent with the row references in the Electricity Distribution ID Determination 2012 (as issued on 24 March 2015). They provide a common reference between the rows in the determination and the template. Description of Calculation References Calculation cell formulas contain links to other cells within the same template or elsewhere in the workbook. Key cell references are described in a column to the right of each template. These descriptions are provided to assist data entry. Cell references refer to the row of the template and not the schedule reference. Worksheet Completion Sequence Calculation cells may show an incorrect value until precedent cell entries have been completed. Data entry may be assisted by completing the schedules in the following order: 1. Coversheet 2. Schedules 5a 5e 3. Schedules 6a 6b 4. Schedule 8 5. Schedule 3 6. Schedule 4 7. Schedule 2 8. Schedule 7 9. Schedules 9a 9e 10. Schedule 10 Unison - ID Schedule Templates 1 to XLSX 4 Instructions

5 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 ($/MVA) 9 Operational expenditure 23, ,979 4,163 33, Network 6, ,178 1,110 9, Non-network 17, ,801 3,053 24, Expenditure on assets 25, ,817 4,513 36, Network 20, ,511 3,648 29, Non-network 4, , , (ii): Revenue metrics 18 Revenue per GWh energy delivered to ICPs ($/GWh) Revenue per average no. of ICPs ($/ICP) 19 Total consumer line charge revenue 94,575 1, Standard consumer line charge revenue 95,751 1, Non-standard consumer line charge revenue 61, , (iii): Service intensity measures Demand density 36 Maximum coincident system demand per km of circuit length (for supply) (kw/km) 26 Volume density 175 Total energy delivered to ICPs per km of circuit length (for supply) (MWh/km) 27 Connection point density 12 Average number of ICPs per km of circuit length (for supply) (ICPs/km) 28 Energy intensity 14,322 Total energy delivered to ICPs per average number of ICPs (kwh/icp) (iv): Composition of regulatory income 31 ($000) % of revenue 32 Operational expenditure 38, % 33 Pass-through and recoverable costs excluding financial incentives and wash-ups 43, % 34 Total depreciation 26, % 35 Total revaluations 6, % 36 Regulatory tax allowance 11, % 37 Regulatory profit/(loss) including financial incentives and wash-ups 39, % 38 Total regulatory income 153, (v): Reliability Interruption rate Interruptions per 100 circuit km Unison - ID Schedule Templates 1 to XLSX 5 S1.Analytical Ratios

6 SCHEDULE 2: REPORT ON RETURN ON INVESTMENT 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 (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 6.48% 8.12% 6.59% 11 Excluding revenue earned from financial incentives 6.43% 8.10% 6.51% 12 Excluding revenue earned from financial incentives and wash-ups 6.14% 7.87% 6.28% 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 7.13% 8.66% 7.18% 21 Excluding revenue earned from financial incentives 7.08% 8.64% 7.11% 22 Excluding revenue earned from financial incentives and wash-ups 6.79% 8.41% 6.87% 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 581, plus Opening deferred tax (27,133) 34 Opening RIV 554, Line charge revenue 152, Expenses cash outflow 82, add Assets commissioned 27, less Asset disposals 2, add Tax payments 8, less Other regulated income Mid-year net cash outflows 115, Term credit spread differential allowance Total closing RAB value 586, less Adjustment resulting from asset allocation (1) 49 less Lost and found assets adjustment (44) 50 plus Closing deferred tax (29,786) 51 Closing RIV 556, ROI comparable to a vanilla WACC 7.18% Leverage (%) 44% 56 Cost of debt assumption (%) 4.80% 57 Corporate tax rate (%) 28% ROI comparable to a post tax WACC 6.59% 60 Unison - ID Schedule Templates 1 to XLSX 6 S2.Return on Investment

7 SCHEDULE 2: REPORT ON RETURN ON INVESTMENT 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 (iii): Information Supporting the Monthly ROI Opening RIV N/A Line charge revenue Expenses cash outflow Assets commissioned Asset disposals Other regulated income Monthly net cash 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 6.54% Year-end ROI comparable to a post tax WACC 5.95% * 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 Impact of financial incentives on ROI 0.08% Input methodology claw-back 2, Recoverable customised price-quality path costs 113 Catastrophic event allowance 114 Capex wash-up adjustment (492) 115 Transmission asset wash-up adjustment NPV wash-up allowance 117 Reconsideration event allowance 118 Other wash-ups 119 Wash-up costs 1, Impact of wash-up costs on ROI 0.24% Unison - ID Schedule Templates 1 to XLSX 7 S2.Return on Investment

8 SCHEDULE 3: REPORT ON REGULATORY PROFIT 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 (i): Regulatory Profit ($000) 8 Income 9 Line charge revenue 152, plus Gains / (losses) on asset disposals (1,156) 11 plus Other regulated income (other than gains / (losses) on asset disposals) 1, Total regulatory income 153, Expenses 15 less Operational expenditure 38, less Pass-through and recoverable costs excluding financial incentives and wash-ups 43, Operating surplus / (deficit) 70, less Total depreciation 26, plus Total revaluations 6, Regulatory profit / (loss) before tax 51, less Term credit spread differential allowance less Regulatory tax allowance 11, Regulatory profit/(loss) including financial incentives and wash-ups 39, (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 33, Transpower new investment contract charges System operator services 43 Distributed generation allowance 7, 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 43, Unison - ID Schedule Templates 1 to XLSX 8 S3.Regulatory Profit

9 SCHEDULE 3: REPORT ON REGULATORY PROFIT 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 (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 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) 69 3(v): Other Disclosures Self-insurance allowance ($000) ($000) Unison - ID Schedule Templates 1 to XLSX 9 S3.Regulatory Profit

10 SCHEDULE 4: REPORT ON VALUE OF THE REGULATORY ASSET BASE (ROLLED FORWARD) 7 4(i): Regulatory Asset Base Value (Rolled Forward) RAB RAB RAB RAB RAB 8 for year ended 31 Mar Mar Mar Mar Mar 18 9 ($000) ($000) ($000) ($000) ($000) 10 Total opening RAB value 491, , , , , less Total depreciation 21,312 22,846 24,802 25,277 26, plus Total revaluations 7, ,129 11,807 6, plus Assets commissioned 48,677 43,840 33,577 47,961 27, less Asset disposals 5,462 3,565 2,815 1,493 2, plus Lost and found assets adjustment 139 (44) plus Adjustment resulting from asset allocation (1) Total closing RAB value 521, , , , , (ii): Unallocated Regulatory Asset Base Unallocated RAB * RAB ($000) ($000) ($000) ($000) 29 Total opening RAB value 581, , less 31 Total depreciation 26,196 26, plus 33 Total revaluations 6,329 6, plus 35 Assets commissioned (other than below) 17,272 17, Assets acquired from a regulated supplier 37 Assets acquired from a related party 10,530 10, Assets commissioned 27,802 27, less 40 Asset disposals (other than below) 2,831 2, Asset disposals to a regulated supplier 42 Asset disposals to a related party 43 Asset disposals 2,831 2, plus Lost and found assets adjustment (44) (44) plus Adjustment resulting from asset allocation (1) Total closing RAB value 586, , 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 2.8. * 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. Unison - ID Schedule Templates 1 to XLSX 10 S4.RAB Value (Rolled Forward)

11 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 (iii): Calculation of Revaluation Rate and Revaluation of Assets CPI 4 1, CPI 4 1, Revaluation rate (%) 1.10% Unallocated RAB * RAB 59 ($000) ($000) ($000) ($000) 60 Total opening RAB value 581, , less Opening value of fully depreciated, disposed and lost assets 5,728 5, Total opening RAB value subject to revaluation 575, , Total revaluations 6,329 6, (iv): Roll Forward of Works Under Construction Unallocated works under Works under construction preceding disclosure year construction 12,713 Allocated works under construction 12, plus Capital expenditure 35,141 35, less Assets commissioned 27,802 27, plus Adjustment resulting from asset allocation 72 Works under construction - current disclosure year 20,052 20, Highest rate of capitalised finance applied 6.02% 75 Unison - ID Schedule Templates 1 to XLSX 11 S4.RAB Value (Rolled Forward)

12 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 (v): Regulatory Depreciation Unallocated RAB * RAB ($000) ($000) ($000) ($000) 79 Depreciation - standard 26,196 26, Depreciation - no standard life assets 81 Depreciation - modified life assets 82 Depreciation - alternative depreciation in accordance with CPP 83 Total depreciation 26,196 26, (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' depreciation Closing RAB value under 'standard' depreciation 96 4(vii): Disclosure by Asset Category 97 ($000 unless otherwise specified) 98 Subtransmission lines Subtransmission cables Zone substations Distribution and LV lines Distribution and LV cables Distribution substations and transformers Distribution switchgear Other network assets Non-network assets 99 Total opening RAB value 21,047 23,645 78, , ,431 90,507 50,233 23,432 39, , less Total depreciation 1, ,439 4,801 4,272 3,969 1,651 1,929 5,571 26, plus Total revaluations ,325 1, , plus Assets commissioned ,696 4,942 4,131 3,786 2, ,990 27, less Asset disposals ,687 2, plus Lost and found assets adjustment (2) (5) (4) (33) (44) 105 plus Adjustment resulting from asset allocation 106 plus Asset category transfers (194) 5,009 (4,342) (473) 107 Total closing RAB value 20,404 23,606 79, , ,421 90,565 51,130 21,894 41, , Asset Life 110 Weighted average remaining asset life (years) 111 Weighted average expected total asset life (years) Total Unison - ID Schedule Templates 1 to XLSX 12 S4.RAB Value (Rolled Forward)

13 SCHEDULE 5a: REPORT ON REGULATORY TAX ALLOWANCE 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 sch 2.8. ref 7 5a(i): Regulatory Tax Allowance ($000) 8 Regulatory profit / (loss) before tax 51, plus Income not included in regulatory profit / (loss) before tax but taxable * 11 Expenditure or loss in regulatory profit / (loss) before tax but not deductible 22 * 12 Amortisation of initial differences in asset values 5, Amortisation of revaluations 2, , less Total revaluations 6, Income included in regulatory profit / (loss) before tax but not taxable * 18 Discretionary discounts and customer rebates 19 Expenditure or loss deductible but not in regulatory profit / (loss) before tax * 20 Notional deductible interest 11, , Regulatory taxable income 41, less Utilised tax losses 26 Regulatory net taxable income 41, Corporate tax rate (%) 28% 29 Regulatory tax allowance 11, * 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). 34 5a(iii): Amortisation of Initial Difference in Asset Values ($000) Opening unamortised initial differences in asset values 119, less Amortisation of initial differences in asset values 5, plus Adjustment for unamortised initial differences in assets acquired 39 less Adjustment for unamortised initial differences in assets disposed 40 Closing unamortised initial differences in asset values 113, Opening weighted average remaining useful life of relevant assets (years) Unison - ID Schedule Templates 1 to XLSX 13 S5a.Regulatory Tax Allowance

14 SCHEDULE 5a: REPORT ON REGULATORY TAX ALLOWANCE 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 sch 2.8. ref 44 5a(iv): Amortisation of Revaluations ($000) Opening sum of RAB values without revaluations 535, Adjusted depreciation 23, Total depreciation 26, Amortisation of revaluations 2, 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 (27,133) plus Tax effect of adjusted depreciation 6, less Tax effect of tax depreciation 8, plus Tax effect of other temporary differences* less Tax effect of amortisation of initial differences in asset values 1, plus Deferred tax balance relating to assets acquired in the disclosure year less Deferred tax balance relating to assets disposed in the disclosure year (226) plus Deferred tax cost allocation adjustment Closing deferred tax (29,786) 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 317, less Tax depreciation 29, plus Regulatory tax asset value of assets commissioned 27, less Regulatory tax asset value of asset disposals 2, 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 313,784 Unison - ID Schedule Templates 1 to XLSX 14 S5a.Regulatory Tax Allowance

15 SCHEDULE 5b: REPORT ON RELATED PARTY TRANSACTIONS 7 5b(i): Summary Related Party Transactions ($000) 8 Total regulatory income 9 Operational expenditure 15, Capital expenditure 24, Market value of asset disposals 12 Other related party transactions 13 5b(ii): Entities Involved in 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 Name of related party 15 Unison Fibre Limited 16 Unison Insurance Limited 17 ETEL Limited 18 Unison Contracting Services Limited * include additional rows if needed Related party relationship A wholly owned subsidiary of A wholly owned subsidiary of A wholly owned subsidiary of A wholly owned subsidiary of 21 5b(iii): Related Party Transactions Value of 22 Name of related party Related party transaction type Description of transaction transaction ($000) Basis for determining value 23 Unison Insurance Limited Opex Insurance Policy - Transmission and Distribution policy 770 ID clause 2.3.6(1)(f) 24 Unison Fibre Limited Opex Fibre Optic interconnections 824 ID clause 2.3.6(1)(a) Purchase of electrical distribution transformers and other 25 ETEL Limited Capex electrical components 2,773 IM clause (5)(b)(i) 26 Unison Contracting Services Limited Capex Construction of new network equipment 16,642 IM clause (5)(g) 27 Unison Contracting Services Limited Capex Non network asset purchases 4,755 IM clause (5)(g) 28 Unison Contracting Services Limited Opex Service Interruptions and emergencies 3,269 ID clause 2.3.6(1)(b) 29 Unison Contracting Services Limited Opex Vegetation Management 1,656 ID clause 2.3.6(1)(b) 30 Unison Contracting Services Limited Opex Routine and corrective maintenance and inspection 2,481 ID clause 2.3.6(1)(b) 31 Unison Contracting Services Limited Opex Asset replacement and renewal 1,373 ID clause 2.3.6(1)(b) 32 Unison Contracting Services Limited Opex Systems operations and network support 255 ID clause 2.3.6(1)(b) 33 Unison Contracting Services Limited Opex Business support 4,678 ID clause 2.3.6(1)(b) * include additional rows if needed Unison - ID Schedule Templates 1 to XLSX 15 S5b.Related Party Transactions

16 SCHEDULE 5c: REPORT ON TERM CREDIT SPREAD DIFFERENTIAL ALLOWANCE 7 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 11 31/10/ /8/ % 58,997 68, (103) 12 31/10/ /8/ % 58,997 68, (120) * include additional rows if needed 136, (223) c(ii): Attribution of Term Credit Spread Differential Gross term credit spread differential Total book value of interest bearing debt 225, Leverage 44% 24 Average opening and closing RAB values 583, Attribution Rate (%) 114% Term credit spread differential allowance 1 Unison - ID Schedule Templates 1 to XLSX 16 S5c.TCSD Allowance

17 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 10 Service interruptions and emergencies 11 Directly attributable 3, Not directly attributable 13 Total attributable to regulated service 3, Vegetation management 15 Directly attributable 1, Not directly attributable 17 Total attributable to regulated service 1, Routine and corrective maintenance and inspection 19 Directly attributable 2, Not directly attributable 21 Total attributable to regulated service 2, 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 4, Not directly attributable 3,194 3,194 Total OVABAA allocation increase ($000s) 29 Total attributable to regulated service 8, Business support 31 Directly attributable 8, Not directly attributable 11,771 2,075 13, Total attributable to regulated service 20, Operating costs directly attributable 23, Operating costs not directly attributable 14,965 2,075 17, Operational expenditure 38, 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. Unison - ID Schedule Templates 1 to XLSX 17 S5d.Cost Allocations

18 SCHEDULE 5d: REPORT ON COST ALLOCATIONS 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 d(ii): Other Cost Allocations 40 Pass through and recoverable costs ($000) 41 Pass through costs 42 Directly attributable 1, Not directly attributable 44 Total attributable to regulated service 1, Recoverable costs 46 Directly attributable 42, Not directly attributable 48 Total attributable to regulated service 42, 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 Unison - ID Schedule Templates 1 to XLSX 18 S5d.Cost Allocations

19 SCHEDULE 5e: REPORT ON ASSET ALLOCATIONS 7 5e(i): Regulated Service Asset Values 8 9 Value allocated ($000s) Electricity distribution services 10 Subtransmission lines 11 Directly attributable 20, Not directly attributable 13 Total attributable to regulated service 20, Subtransmission cables 15 Directly attributable 23, Not directly attributable 17 Total attributable to regulated service 23, Zone substations 19 Directly attributable 79, Not directly attributable 21 Total attributable to regulated service 79, Distribution and LV lines 23 Directly attributable 121, Not directly attributable 25 Total attributable to regulated service 121, Distribution and LV cables 27 Directly attributable 135, Not directly attributable 29 Total attributable to regulated service 135, Distribution substations and transformers 31 Directly attributable 90, Not directly attributable 33 Total attributable to regulated service 90, Distribution switchgear 35 Directly attributable 51, Not directly attributable 37 Total attributable to regulated service 51, Other network assets 39 Directly attributable 21, Not directly attributable 41 Total attributable to regulated service 21, Non-network assets 43 Directly attributable 41, Not directly attributable 45 Total attributable to regulated service 41, Regulated service asset value directly attributable 586, Regulated service asset value not directly attributable 49 Total closing RAB value 586, 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) Unison - ID Schedule Templates 1 to XLSX 19 S5e.Asset Allocations

20 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 11,530 9 System growth 1, Asset replacement and renewal 17, Asset relocations Reliability, safety and environment: 13 Quality of supply Legislative and regulatory Other reliability, safety and environment 1, Total reliability, safety and environment 2, Expenditure on network assets 33, Expenditure on non-network assets 7, Expenditure on assets 41, plus Cost of financing less Value of capital contributions 6, plus Value of vested assets Capital expenditure 35, 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 Research and development 30 6a(iii): Consumer Connection 31 Consumer types defined by EDB* ($000) ($000) 32 Simple Customer Connection 3, Complex Customer Connection 7, Special Customer Connection * include additional rows if needed 38 Consumer connection expenditure 11, less Capital contributions funding consumer connection expenditure 5, Consumer connection less capital contributions 5, a(iv): System Growth and Asset Replacement and Renewal Asset Replacement and System Growth Renewal ($000) ($000) 45 Subtransmission 46 Zone substations 313 3, Distribution and LV lines 976 5, Distribution and LV cables 161 2, Distribution substations and transformers 1, Distribution switchgear 2, Other network assets 1, System growth and asset replacement and renewal expenditure 1,450 17, less Capital contributions funding system growth and asset replacement and renewal 3 54 System growth and asset replacement and renewal less capital contributions 1,450 17, a(v): Asset Relocations 57 Project or programme* ($000) ($000) 58 Asset Relocations * include additional rows if needed 64 All other projects or programmes - asset relocations 65 Asset relocations expenditure less Capital contributions funding asset relocations 1, Asset relocations less capital contributions (260) Unison - ID Schedule Templates 1 to XLSX 20 S6a.Actual Expenditure Capex

21 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(vi): Quality of Supply 70 Project or programme* ($000) ($000) 71 Rotoma Reliability Improvements Waimarama Reliability Improvements * include additional rows if needed 77 All other projects programmes - quality of supply Quality of supply expenditure less Capital contributions funding quality of supply 80 Quality of supply less capital contributions a(vii): Legislative and Regulatory 82 Project or programme* ($000) ($000) * include additional rows if needed 89 All other projects or programmes - legislative and regulatory Legislative and regulatory expenditure less Capital contributions funding legislative and regulatory 2 92 Legislative and regulatory less capital contributions a(viii): Other Reliability, Safety and Environment 94 Project or programme* ($000) ($000) 95 Runanga Substation Substation Fire/Security upgrade - Hastings Waimarama Feeder - Security of supply * include additional rows if needed 101 All other projects or programmes - other reliability, safety and environment Other reliability, safety and environment expenditure 1, less Capital contributions funding other reliability, safety and environment Other reliability, safety and environment less capital contributions 1, a(ix): Non-Network Assets 107 Routine expenditure 108 Project or programme* ($000) ($000) 109 Motor Vehicles 4, Office Furniture Plant, Equipment and Tools 1, Land and Buildings Information Technology 2, * include additional rows if needed 115 All other projects or programmes - routine expenditure 116 Routine expenditure 7, Atypical expenditure 118 Project or programme* ($000) ($000) * include additional rows if needed 125 All other projects or programmes - atypical expenditure 126 Atypical expenditure Expenditure on non-network assets 7,997 Unison - ID Schedule Templates 1 to XLSX 21 S6a.Actual Expenditure Capex

22 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 3,659 9 Vegetation management 1, Routine and corrective maintenance and inspection 2, Asset replacement and renewal 1, Network opex 10, System operations and network support 8, Business support 20, Non-network opex 28, Operational expenditure 38, b(ii): Subcomponents of Operational Expenditure (where known) 19 Energy efficiency and demand side management, reduction of energy losses 20 Direct billing* 21 Research and development 22 Insurance 1, * Direct billing expenditure by suppliers that directly bill the majority of their consumers Unison - ID Schedule Templates 1 to XLSX 22 S6b.Actual Expenditure Opex

23 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 150, ,768 2% 9 7(ii): Expenditure on Assets Forecast ($000) ² Actual ($000) % variance 10 Consumer connection 9,875 11,530 17% 11 System growth 1,617 1,450 (10%) 12 Asset replacement and renewal 18,876 17,649 (7%) 13 Asset relocations 1, (11%) 14 Reliability, safety and environment: 15 Quality of supply 1, (19%) 16 Legislative and regulatory (9%) 17 Other reliability, safety and environment 686 1,212 77% 18 Total reliability, safety and environment 1,850 2,159 17% 19 Expenditure on network assets 33,275 33,726 1% 20 Expenditure on non-network assets 8,346 7,997 (4%) 21 Expenditure on assets 41,621 41,723 0% 22 7(iii): Operational Expenditure 23 Service interruptions and emergencies 2,496 3,659 47% 24 Vegetation management 1,370 1,657 21% 25 Routine and corrective maintenance and inspection 3,062 2,965 (3%) 26 Asset replacement and renewal 1,789 1,977 11% 27 Network opex 8,716 10,258 18% 28 System operations and network support 8,644 8,095 (6%) 29 Business support 20,170 20,134 (0%) 30 Non-network opex 28,814 28,228 (2%) 31 Operational expenditure 37,530 38,486 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 1, (82%) 35 Research and development (v): Subcomponents of Operational Expenditure (where known) 38 Energy efficiency and demand side management, reduction of energy losses 39 Direct billing 40 Research and development 41 Insurance 1,471 1,576 7% 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) Unison - ID Schedule Templates 1 to XLSX 23 S7.Actual vs Forecast

24 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 8 8(i): Billed Quantities by Price Component Billed quantities by price component Price component 24UC AICO CTRL CTUD NITE DEFT OFPK ONPK PROJ TAIC Fixed KVAR RKVAR DMND SOPD WOPD T020 T030 T050 T075 T100 T150 COAD UNMT DGEN 12 Unit charging basis (eg, days, kw of demand, Consumer group name or price Consumer type or types (eg, Standard or non-standard Average no. of ICPs in Energy delivered to ICPs kva of capacity, etc.) kwh kwh kwh kwh kwh kwh kwh kwh kwh kwh Daily kvar kvar Demand Demand Demand Daily Daily Daily Daily Daily Daily Daily kwh Free 13 category code residential, commercial etc.) consumer group (specify) disclosure year in disclosure year (MWh) DNR Residential Standard 3,867 13,518 6,848,140 4,843,638 1,174, , ,346 13,750 1,400,823 7, Distributed Generation - G11 Residential Standard , ,082 9, (192) 6,241 51, , Distributed Generation - G12 Residential Standard 154 1, , ,402 20,916 5,064 2,162 16,393 55, , Residential Low Fixed - M11 Residential Standard 45, , ,432,412 98,403,942 28,940,583 1,336,060 1,571, ,962 16,427, , Residential - M12 Residential Standard 45, , ,113, ,605,100 46,043,401 3,618,878 3,563,400 1,230,869 16,114, , Commercial - MC1 Commercial Standard 7, , ,218,562 2,272,815 14,789,427 6,892, ,974 6,630,628 2,462,445 2,778 21,913 11,952 8,670 1,095 1, , Commercial - MC2 Commercial Standard ,516 46,852, ,502 3,007,794 1,448,560 68,090 23,674, ,396 6,245 67,133 35,786 28,788 4, , Commercial - MC3 Commercial Standard , ,504 9,819, ,450, ,198 39, , , ,327 23,418 18,948 3, , Commercial - MC5 Commercial Standard , ,171 71,990,905 38,138 23, , ,647 94, ,555 16,466 2,280 1,095 Commercial - MC6 Commercial Standard 49 52,732 7,291 52,725,128 17,444 10, ,683 77,158 62,079 8,304 3, Commercial - MC7 Commercial Standard 18 23, ,651 23,517,671 6,488 4,215 69,227 38,192 22, , Commercial - MC8 Commercial Standard 22 27,822 27,821,554 7,719 6,341 90,472 49,459 34, ,095 4,380 1, Commercial - MC9 Commercial Standard 18 36,893 36,892,878 6,281 47,260 40, ,526 56,585 41,413 1,095 2,555 3, , General High User - NDH Commercial Standard 3,261 48,022 42,680,160 (22,204) 1,195, , ,975 2,889,538 1,155,857 38,798 General Low User - NDL Commercial Standard 5,269 12,085 11,097,271 (2,155) 206, ,365 71, ,152 1,762, Temporary Supply - T1P Commercial Standard , ,425 Temporary Supply - T3P Commercial Standard 18 (321) (311,938) (8,770) 3,699 General TOU - TCU Commercial Standard 1 3 2, Residential TOU - THU Residential Standard 207 1, ,783 1,055, ,850 10,518 73,200 4,187 Residential TOU - TLU Residential Standard 425 2, , ,248, ,744 10, ,635 8,710 Unmetered - U01 Commercial Standard ,119 Unmetered - U02 Commercial Standard ,676 Unmetered - U03 Commercial Standard 17 12,429 9,827,135 12,428,961 Industrial - I60 Industrial Standard , ,071,121 19,955 23,522 2, ,074 Industrial - I60 Industrial Non-standard 32 55,156 55,155,709 14,566 26,985 6, ,889 Unison Commercial Standard , [Select one] 25 Add extra rows for additional consumer groups or price category codes as necessary 26 Standard consumer totals 112,749 1,560, ,119, ,281,806 80,902,868 24,062,832 14,270,080 10,773,196 2,306,408 1,042,431 5,618, ,905,819 50,028, ,079 43,342 1,561, , ,113 31,124 26,278 34,520 15,106 6,456 1,095 1,460 13,865,756 2,079, Non-standard consumer totals 32 55,156 55,155,709 14,566 26,985 6, , Total for all consumers 112,781 1,615, ,119, ,281,806 80,902,868 24,062,832 14,270,080 10,773,196 2,306,408 1,042,431 5,618, ,061,528 50,043, ,064 49,388 1,750, , ,113 31,124 26,278 34,520 15,106 6,456 1,095 1,460 13,865,756 2,079,023 Add extra columns for additional billed quantities by price component as necessary Unison - ID Schedule Templates 1 to XLSX 24 S8.Billed Quantities+Revenues

25 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 31 8(ii): Line Charge Revenues ($000) by Price Component Line charge revenues ($000) by price component Price component 24UC AICO CTRL CTUD NITE DEFT OFPK ONPK PROJ TAIC Fixed KVAR RKVAR DMND SOPD WOPD T020 T030 T050 T075 T100 T150 COAD UNMT DGEN 34 Total transmission Notional revenue Total distribution line charge Rate (eg, $ per day, $ per kwh kwh kwh kwh kwh kwh kwh kwh kwh kwh Daily kvar kvar Demand Demand Demand Daily Daily Daily Daily Daily Daily Daily kwh Free 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 kwh, etc.) 35 category code residential, commercial etc.) consumer group (specify) in disclosure year discounts (if applicable) revenue available) DNR Residential Standard $3,151 $3,151 $620 $333 $44 $44 $8 $1 $2, Distributed Generation - G11 Residential Standard $132 $132 $99 $23 $1 $1 $8 39 Distributed Generation - G12 Residential Standard $217 $217 $94 $21 $1 $1 $1 $99 40 Residential Low Fixed - M11 Residential Standard $32,560 $32,560 $15,660 $11,584 $2,484 $229 $75 $64 $2, Residential - M12 Residential Standard $50,307 $50,307 $18,210 $11,067 $1,856 $410 $113 $119 $18, Commercial - MC1 Commercial Standard $23,207 $23,207 $12,788 $74 $1,329 $164 $22 $8,604 $21 $59 $43 $84 $5 $7 $8 ($1) 43 Commercial - MC2 Commercial Standard $6,256 $6,256 $3,299 $15 $271 $35 $5 $1,963 $47 $179 $129 $281 $24 $5 $3 44 Commercial - MC3 Commercial Standard $6,572 $6,572 $16 $850 $2,110 $301 $953 $684 $1,381 $117 $125 $32 $4 ($1) 45 Commercial - MC5 Commercial Standard $3,449 $3,449 $46 $1,047 $178 $610 $442 $924 $4 $17 $142 $25 $14 Commercial - MC6 Commercial Standard $2,066 $2,066 $1 $604 $77 $391 $274 $598 $72 $39 $5 $5 Commercial - MC7 Commercial Standard $927 $927 $37 $267 $32 $186 $135 $214 $2 $44 $11 ($1) Commercial - MC8 Commercial Standard $1,265 $1,265 $384 $48 $242 $177 $337 $2 $9 $47 $14 $5 Commercial - MC9 Commercial Standard $1,384 $1,384 $356 $357 ($305) $277 $201 $400 $5 $17 $29 $4 $39 $5 ($1) General High User - NDH Commercial Standard $5,652 $5,652 $3,891 ($2) $56 $93 $14 $271 $1,329 General Low User - NDL Commercial Standard $3,532 $3,532 $740 $7 $9 $2 $42 $2,732 Temporary Supply - T1P Commercial Standard $181 $181 $41 $140 Temporary Supply - T3P Commercial Standard ($10) ($10) ($23) ($1) $14 General TOU - TCU Commercial Standard Residential TOU - THU Residential Standard $211 $211 $8 $41 $76 $2 $84 Residential TOU - TLU Residential Standard $259 $259 $23 $78 $132 $3 $23 Unmetered - U01 Commercial Standard $113 $113 $113 Unmetered - U02 Commercial Standard $85 $85 $85 Unmetered - U03 Commercial Standard $1,516 $1,516 $983 $533 Industrial - I60 Industrial Standard $6,354 $6,354 $6,199 $177 ($22) Industrial - I60 Industrial Non-standard $3,382 $3,382 $3,224 $203 ($45) Unison Commercial Standard 46 [Select one] 47 Add extra rows for additional consumer groups or price category codes as necessary 48 Standard consumer totals $149,386 $149,386 $55,435 $23,026 $4,569 $2,386 $411 $934 $119 $208 $530 $50,043 $1,238 ($327) $2,897 $2,085 $4,219 $155 $173 $297 $163 $83 $15 ($4) $ Non-standard consumer totals $3,382 $3,382 $3,224 $203 ($45) 50 Total for all consumers $152,768 $152,768 $55,435 $23,026 $4,569 $2,386 $411 $934 $119 $208 $530 $53,267 $1,441 ($372) $2,897 $2,085 $4,219 $155 $173 $297 $163 $83 $15 ($4) $731 Add extra columns for additional line charge revenues by price component as necessary (iii): Number of ICPs directly billed Check OK 53 Number of directly billed ICPs at year end 7 Unison - ID Schedule Templates 1 to XLSX 25 S8.Billed Quantities+Revenues

26 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 Hawke's Bay 8 8(i): Billed Quantities by Price Component Billed quantities by price component Price component 24UC AICO CTRL CTUD NITE DEFT OFPK ONPK PROJ TAIC Fixed KVAR RKVAR DMND SOPD WOPD T020 T030 T050 T075 T100 T150 COAD UNMT DGEN 12 Unit charging basis (eg, days, kw of demand, Consumer group name or price Consumer type or types (eg, Standard or non-standard Average no. of ICPs in Energy delivered to ICPs kva of capacity, etc.) kwh kwh kwh kwh kwh kwh kwh kwh kwh kwh Daily kvar kvar Demand Demand Demand Daily Daily Daily Daily Daily Daily Daily kwh Free 13 category code residential, commercial etc.) consumer group (specify) disclosure year in disclosure year (MWh) DNR Residential Standard 610 2,158 1,292, , , ,321 3, ,992 (64) 16 Distributed Generation - G11 Residential Standard ,546 80,575 9,424 (199) 4,352 33, , Distributed Generation - G12 Residential Standard , ,657 17,899 5, ,411 34, , Residential Low Fixed - M11 Residential Standard 26, ,401 66,222,161 51,595,215 22,072,448 14, , ,863 9,595, , Residential - M12 Residential Standard 26, , ,092,422 85,046,080 31,900,063 97, , ,262 9,433, , Commercial - MC1 Commercial Standard 3,018 97,439 88,934, ,577 3,064,191 1,362, ,485 3,284,643 1,061,882 1,198 12,555 6,720 5,037 1, , Commercial - MC2 Commercial Standard ,523 25,395,139 45, , ,786 61,620 10,926, ,974 2,566 31,953 17,035 13,727 2, , Commercial - MC3 Commercial Standard , ,504 3,949,321 74,474,694 81,386 29, , , ,086 17,578 13,090 3, , Commercial - MC5 Commercial Standard 51 32, ,972 32,619,757 18,200 12, ,922 60,546 47, , Commercial - MC6 Commercial Standard 33 37,143 7,291 37,135,220 11,849 6, ,417 55,915 45,151 5,019 3, Commercial - MC7 Commercial Standard 17 21, ,651 21,338,809 6,002 3,321 61,978 33,392 20, , Commercial - MC8 Commercial Standard 12 18,022 18,021,878 4,434 4,191 56,109 31,625 20, ,190 1, Commercial - MC9 Commercial Standard 12 29,180 29,180,312 4,091 2,628 71,742 40,364 28, , , General High User - NDH Commercial Standard 2,199 31,467 27,520,916 (19,557) 692, , ,422 2,748, ,082 General Low User - NDL Commercial Standard 3,633 8,350 7,475,133 (2,155) 144,250 93,455 48, ,221 1,220,847 Temporary Supply - T1P Commercial Standard , ,616 Temporary Supply - T3P Commercial Standard ,137 2,959 General TOU - TCU Commercial Standard Residential TOU - THU Residential Standard , , ,869 6,301 37,486 Residential TOU - TLU Residential Standard 237 1, , , ,278 6,661 84,734 Unmetered - U01 Commercial Standard ,336 Unmetered - U02 Commercial Standard ,231 Unmetered - U03 Commercial Standard 8 7,335 6,057,899 7,335,308 Industrial - I60 Industrial Standard , ,093,697 15,940 12,085 2, ,857 Industrial - I60 Industrial Non-standard 4 17,077 17,077,134 2,190 18,069 64,339 Unison Commercial Standard 24 [Select one] 25 Add extra rows for additional consumer groups or price category codes as necessary 26 Standard consumer totals 64, , ,352, ,533,525 56,070,349 4,371,290 2,590,140 4,672,235 1,207, ,147 4,758, ,075,410 28,877,799 74,704 2,960 1,069, , ,307 21,593 15,310 16,102 10,515 4,996 1, ,400,875 1,440, Non-standard consumer totals 4 17,077 17,077,134 2,190 18,069 64, Total for all consumers 64, , ,352, ,533,525 56,070,349 4,371,290 2,590,140 4,672,235 1,207, ,147 4,758, ,152,544 28,879,989 92,773 2,960 1,133, , ,307 21,593 15,310 16,102 10,515 4,996 1, ,400,875 1,440,272 Add extra columns for additional billed quantities by price component as necessary Unison - ID Schedule Templates 1 to XLSX 26 S8.Billed Q+Rev HB

27 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 Hawke's Bay 31 8(ii): Line Charge Revenues ($000) by Price Component Line charge revenues ($000) by price component Price component 24UC AICO CTRL CTUD NITE DEFT OFPK ONPK PROJ TAIC Fixed KVAR RKVAR DMND SOPD WOPD T020 T030 T050 T075 T100 T150 COAD UNMT DGEN 34 Total transmission Notional revenue Total distribution line charge Rate (eg, $ per day, $ per kwh kwh kwh kwh kwh kwh kwh kwh kwh kwh Daily kvar kvar Demand Demand Demand Daily Daily Daily Daily Daily Daily Daily kwh Free 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 kwh, etc.) 35 category code residential, commercial etc.) consumer group (specify) in disclosure year discounts (if applicable) revenue available) DNR Residential Standard $516 $516 $129 $51 $8 $ Distributed Generation - G11 Residential Standard $86 $86 $67 $12 $1 $1 $5 39 Distributed Generation - G12 Residential Standard $137 $137 $60 $13 $1 $1 $62 40 Residential Low Fixed - M11 Residential Standard $19,311 $19,311 $9,601 $6,295 $1,920 $3 $10 $43 $1, Residential - M12 Residential Standard $30,558 $30,558 $11,748 $6,506 $1,340 $12 $16 $88 $10, Commercial - MC1 Commercial Standard $10,799 $10,799 $6,590 $24 $297 $37 $11 $3,716 $9 $34 $24 $48 $5 $2 $3 ($1) 43 Commercial - MC2 Commercial Standard $3,259 $3,259 $1,880 $2 $71 $10 $5 $981 $19 $86 $60 $130 $13 $2 44 Commercial - MC3 Commercial Standard $4,324 $4,324 $16 $352 $1,343 $224 $698 $495 $989 $88 $86 $29 $4 45 Commercial - MC5 Commercial Standard $1,652 $1,652 $27 $489 $93 $313 $212 $454 $2 $53 $4 $5 Commercial - MC6 Commercial Standard $1,458 $1,458 $1 $403 $50 $287 $196 $429 $43 $39 $5 $5 Commercial - MC7 Commercial Standard $832 $832 $37 $246 $25 $167 $117 $191 $39 $11 ($1) Commercial - MC8 Commercial Standard $748 $748 $213 $32 $151 $111 $192 $6 $24 $14 $5 Commercial - MC9 Commercial Standard $899 $899 $225 $20 $194 $141 $268 $2 $7 $4 $4 $29 $5 General High User - NDH Commercial Standard $3,820 $3,820 $2,587 ($2) $33 $44 $5 $258 $895 General Low User - NDL Commercial Standard $2,463 $2,463 $516 $5 $8 $1 $41 $1,892 Temporary Supply - T1P Commercial Standard $103 $103 $16 $87 Temporary Supply - T3P Commercial Standard $16 $16 $5 $11 General TOU - TCU Commercial Standard Residential TOU - THU Residential Standard $113 $113 $5 $22 $42 $1 $43 Residential TOU - TLU Industrial Standard $146 $146 $16 $43 $72 $2 $13 Unmetered - U01 Commercial Standard $59 $59 $59 Unmetered - U02 Commercial Standard $67 $67 $67 Unmetered - U03 Commercial Standard $899 $899 $606 $293 Industrial - I60 Industrial Standard $4,872 $4,872 $4,803 $91 ($22) Industrial - I60 Industrial Non-standard $881 $881 $745 $136 Unison Commercial Standard 46 [Select one] 47 Add extra rows for additional consumer groups or price category codes as necessary 48 Standard consumer totals $87,137 $87,137 $33,215 ($2) $ Non-standard consumer totals $881 $ Total for all consumers $88,018 $88,018 $33,215 ($2) $419 Add extra columns for additional line charge revenues by price component as necessary (iii): Number of ICPs directly billed Check OK 53 Number of directly billed ICPs at year end 4 Unison - ID Schedule Templates 1 to XLSX 27 S8.Billed Q+Rev HB

28 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 Central Region 8 8(i): Billed Quantities by Price Component Billed quantities by price component Price component 24UC AICO CTRL CTUD NITE DEFT OFPK ONPK PROJ TAIC Fixed KVAR RKVAR DMND SOPD WOPD T020 T030 T050 T075 T100 T150 COAD UNMT DGEN 12 Unit charging basis (eg, days, kw of demand, Consumer group name or price Consumer type or types (eg, Standard or non-standard Average no. of ICPs in Energy delivered to ICPs kva of capacity, etc.) kwh kwh kwh kwh kwh kwh kwh kwh kwh kwh Daily kvar kvar Demand Demand Demand Daily Daily Daily Daily Daily Daily Daily kwh Free 13 category code residential, commercial etc.) consumer group (specify) disclosure year in disclosure year (MWh) DNR Residential Standard 3,257 11,360 5,555,775 4,174, , , ,025 10,293 1,181,831 7, Distributed Generation - G11 Residential Standard ,594 79, ,889 18,360 84, Distributed Generation - G12 Residential Standard , ,745 3,017 1,927 11,982 21, , Residential Low Fixed - M11 Residential Standard 18, ,740 45,210,251 46,808,728 6,868,136 1,321,781 1,374, ,099 6,831, , Residential - M12 Residential Standard 18, ,698 73,021,094 67,559,020 14,143,338 3,521,385 3,104, ,607 6,680, , Commercial - MC1 Commercial Standard 4, ,315 93,898,654 1,634,663 11,728,878 5,531,130 6, ,070 3,345,985 1,400,563 1,580 9,358 5,232 3, , Commercial - MC2 Commercial Standard ,044 21,509, ,331 2,272,064 1,089,773 6,470 12,748, ,422 3,679 35,180 18,751 15,061 2, , Commercial - MC3 Commercial Standard ,845 5,869,762 30,975,470 43,812 10,226 96,734 51,128 39,241 5,840 5, Commercial - MC5 Commercial Standard 56 39, ,199 39,371,148 19,938 11, ,627 62,101 46, ,190 10,310 1, Commercial - MC6 Commercial Standard 16 15,590 15,589,908 5,595 3,559 39,266 21,243 16,927 3,285 Commercial - MC7 Commercial Standard 1 2,179 2,178, ,249 4,799 2, Commercial - MC8 Commercial Standard 10 9,800 9,799,676 3,285 2,149 34,363 17,834 14, ,190 Commercial - MC9 Commercial Standard 6 7,713 7,712,566 2,190 44,631 40,382 31,784 16,221 13, ,460 2, General High User - NDH Commercial Standard 1,062 16,555 15,159,244 (2,647) 503, , , , ,775 5,994 General Low User - NDL Commercial Standard 1,636 3,735 3,622,138 61,813 15,910 23,041 11, ,781 Temporary Supply - T1P Commercial Standard , ,809 Temporary Supply - T3P Commercial Standard 5 (389) (380,075) (8,770) 740 General TOU - TCU Commercial Standard 1 3 2, Residential TOU - THU Residential Standard , , ,981 4,217 35,714 Residential TOU - TLU Residential Standard , , ,467 4,325 67,901 1,153 Unmetered - U01 Commercial Standard ,168 Unmetered - U02 Commercial Standard ,325 Unmetered - U03 Commercial Standard 9 5,110 3,769,236 5,109,807 Industrial - I60 Industrial Standard 10 52,977 52,977,424 4,015 11, ,217 Industrial - I60 Industrial Non-standard 28 38,079 38,078,575 12,376 8,916 6, ,550 Unison Commercial Standard , [Select one] 25 Add extra rows for additional consumer groups or price category codes as necessary 26 Standard consumer totals 48, , ,432, ,748,281 24,836,943 19,695,185 11,681,169 6,107,280 1,099, , , ,830,409 21,150,768 89,375 40, , , ,806 9,531 10,968 18,418 4,591 1, ,621, , Non-standard consumer totals 28 38,079 38,078,575 12,376 8,916 6, , Total for all consumers 48, , ,432, ,748,281 24,836,943 19,695,185 11,681,169 6,107,280 1,099, , , ,908,984 21,163,144 98,291 46, , , ,806 9,531 10,968 18,418 4,591 1, ,621, ,630 Add extra columns for additional billed quantities by price component as necessary Unison - ID Schedule Templates 1 to XLSX 28 S8.Billed Q+Rev CR

29 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 Central Region 31 8(ii): Line Charge Revenues ($000) by Price Component Line charge revenues ($000) by price component Price component 24UC AICO CTRL CTUD NITE DEFT OFPK ONPK PROJ TAIC Fixed KVAR RKVAR DMND SOPD WOPD T020 T030 T050 T075 T100 T150 COAD UNMT DGEN 34 Total transmission Notional revenue Total distribution line charge Rate (eg, $ per day, $ per kwh kwh kwh kwh kwh kwh kwh kwh kwh kwh Daily kvar kvar Demand Demand Demand Daily Daily Daily Daily Daily Daily Daily kwh Free 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 kwh, etc.) 35 category code residential, commercial etc.) consumer group (specify) in disclosure year discounts (if applicable) revenue available) DNR Residential Standard $2,636 $2,636 $492 $282 $36 $44 $8 $1 $1, Distributed Generation - G11 Residential Standard $46 $46 $32 $11 $3 39 Distributed Generation - G12 Residential Standard $81 $81 $34 $9 $1 $37 40 Residential Low Fixed - M11 Residential Standard $13,247 $13,247 $6,058 $5,289 $563 $226 $65 $21 $1, Residential - M12 Residential Standard $19,746 $19,746 $6,462 $4,560 $516 $398 $96 $31 $7, Commercial - MC1 Commercial Standard $12,413 $12,413 $6,202 $51 $1,032 $127 $11 $4,888 $12 $25 $19 $36 $5 $5 43 Commercial - MC2 Commercial Standard $2,994 $2,994 $1,416 $13 $200 $25 $983 $28 $93 $69 $151 $11 $2 $3 44 Commercial - MC3 Commercial Standard $2,249 $2,249 $499 $767 $77 $255 $189 $392 $29 $39 $3 ($1) 45 Commercial - MC5 Commercial Standard $1,797 $1,797 $20 $558 $85 $297 $230 $470 $4 $14 $89 $21 $9 Commercial - MC6 Commercial Standard $607 $607 $201 $27 $103 $79 $169 $28 Commercial - MC7 Commercial Standard $95 $95 $21 $7 $19 $18 $23 $2 $5 Commercial - MC8 Commercial Standard $517 $517 $171 $16 $90 $66 $145 $2 $3 $24 Commercial - MC9 Commercial Standard $486 $486 $131 $337 ($305) $84 $60 $132 $4 $10 $25 $9 ($1) General High User - NDH Commercial Standard $1,832 $1,832 $1,304 $24 $49 $9 $12 $434 General Low User - NDL Commercial Standard $1,070 $1,070 $225 $2 $1 $1 $1 $840 Temporary Supply - T1P Commercial Standard $77 $77 $24 $53 Temporary Supply - T3P Commercial Standard ($26) ($26) ($28) ($1) $3 General TOU - TCU Commercial Standard Residential TOU - THU Residential Standard $99 $99 $4 $19 $34 $1 $41 Residential TOU - TLU Residential Standard $114 $114 $7 $36 $60 $1 $10 Unmetered - U01 Commercial Standard $54 $54 $54 Unmetered - U02 Commercial Standard $16 $16 $16 Unmetered - U03 Commercial Standard $617 $617 $377 $240 Industrial - I60 Industrial Standard $1,482 $1,482 $1,396 $86 Industrial - I60 Industrial Non-standard $2,501 $2,501 $2,480 $67 ($46) Unison Commercial Standard 46 [Select one] 47 Add extra rows for additional consumer groups or price category codes as necessary 48 Standard consumer totals $62,249 $62,249 $22,221 $10,151 $1,216 $1,950 $331 $519 $55 $94 $79 $21,395 $675 ($305) $966 $730 $1,518 $48 $72 $158 $50 $18 ($2) $ Non-standard consumer totals $2,501 $2,501 $2,480 $67 ($46) 50 Total for all consumers $64,750 $64,750 $22,221 $10,151 $1,216 $1,950 $331 $519 $55 $94 $79 $23,875 $742 ($351) $966 $730 $1,518 $48 $72 $158 $50 $18 ($2) $310 Add extra columns for additional line charge revenues by price component as necessary (iii): Number of ICPs directly billed Check OK 53 Number of directly billed ICPs at year end Unison - ID Schedule Templates 1 to XLSX 29 S8.Billed Q+Rev CR

30 SCHEDULE 9a: ASSET REGISTER Network / Sub-network Name 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. 36,737 37, All Overhead Line Wood poles No. 27,194 27, All Overhead Line Other pole types No HV Subtransmission Line Subtransmission OH up to 66kV conductor km HV Subtransmission Line Subtransmission OH 110kV+ conductor km N/A 14 HV Subtransmission Cable Subtransmission UG up to 66kV (XLPE) km (1) 3 15 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 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. N/A 26 HV Zone substation switchgear 50/66/110kV CB (Outdoor) No. N/A 27 HV Zone substation switchgear 33kV Switch (Ground Mounted) No. N/A 28 HV Zone substation switchgear 33kV Switch (Pole Mounted) No (10) 4 29 HV Zone substation switchgear 33kV RMU No. N/A 30 HV Zone substation switchgear 22/33kV CB (Indoor) No HV Zone substation switchgear 22/33kV CB (Outdoor) No HV Zone substation switchgear 3.3/6.6/11/22kV CB (ground mounted) No (8) 4 33 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 3,776 3,775 (2) 2 36 HV Distribution Line Distribution OH Aerial Cable Conductor km HV Distribution Line SWER conductor km 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 HV Distribution switchgear 3.3/6.6/11/22kV Switches and fuses (pole mounted) No. 10,674 10, HV Distribution switchgear 3.3/6.6/11/22kV Switch (ground mounted) - except RMU No (13) 4 45 HV Distribution switchgear 3.3/6.6/11/22kV RMU No. 1,000 1, HV Distribution Transformer Pole Mounted Transformer No. 6,799 6, HV Distribution Transformer Ground Mounted Transformer No. 2,897 2, HV Distribution Transformer Voltage regulators No HV Distribution Substations Ground Mounted Substation Housing No LV LV Line LV OH Conductor km 1,242 1, LV LV Cable LV UG Cable km 2,743 2, LV LV Street lighting LV OH/UG Streetlight circuit km 1,693 1, LV Connections OH/UG consumer service connections No. 110, , 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 All Load Control Centralised plant Lot All Load Control Relays No 4,886 4, All Civils Cable Tunnels km N/A Unison - ID Schedule Templates 1 to XLSX 30 S9a.Asset Register

31 SCHEDULE 9a: ASSET REGISTER Network / Sub-network Name Hawke's Bay 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. 17,362 17, All Overhead Line Wood poles No. 13,625 13,529 (96) 4 11 All Overhead Line Other pole types No HV Subtransmission Line Subtransmission OH up to 66kV conductor km HV Subtransmission Line Subtransmission OH 110kV+ conductor km N/A 14 HV Subtransmission Cable Subtransmission UG up to 66kV (XLPE) km (1) 3 15 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 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. N/A 26 HV Zone substation switchgear 50/66/110kV CB (Outdoor) No. N/A 27 HV Zone substation switchgear 33kV Switch (Ground Mounted) No. N/A 28 HV Zone substation switchgear 33kV Switch (Pole Mounted) No (1) 4 29 HV Zone substation switchgear 33kV RMU No. N/A 30 HV Zone substation switchgear 22/33kV CB (Indoor) No HV Zone substation switchgear 22/33kV CB (Outdoor) No HV Zone substation switchgear 3.3/6.6/11/22kV CB (ground mounted) No (8) 4 33 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 2,002 2,001 (1) 2 36 HV Distribution Line Distribution OH Aerial Cable Conductor km HV Distribution Line SWER conductor km 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 HV Distribution switchgear 3.3/6.6/11/22kV Switches and fuses (pole mounted) No. 5,930 5, HV Distribution switchgear 3.3/6.6/11/22kV Switch (ground mounted) - except RMU No (6) 4 45 HV Distribution switchgear 3.3/6.6/11/22kV RMU No HV Distribution Transformer Pole Mounted Transformer No. 3,837 3, HV Distribution Transformer Ground Mounted Transformer No. 1,747 1, HV Distribution Transformer Voltage regulators No HV Distribution Substations Ground Mounted Substation Housing No LV LV Line LV OH Conductor km (2) 2 51 LV LV Cable LV UG Cable km 1,990 1, LV LV Street lighting LV OH/UG Streetlight circuit km 1,001 1, LV Connections OH/UG consumer service connections No. 64,797 62,966 (1,831) 3 54 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 All Load Control Centralised plant Lot All Load Control Relays No 3,952 3, All Civils Cable Tunnels km N/A Unison - ID Schedule Templates 1 to XLSX 31 S9a.Asset Register HB

32 SCHEDULE 9a: ASSET REGISTER Network / Sub-network Name Central Region 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. 19,375 19, All Overhead Line Wood poles No. 13,569 13, All Overhead Line Other pole types No HV Subtransmission Line Subtransmission OH up to 66kV conductor km (0) 3 13 HV Subtransmission Line Subtransmission OH 110kV+ conductor km N/A 14 HV Subtransmission Cable Subtransmission UG up to 66kV (XLPE) km (0) 3 15 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 3 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. N/A 26 HV Zone substation switchgear 50/66/110kV CB (Outdoor) No. N/A 27 HV Zone substation switchgear 33kV Switch (Ground Mounted) No. N/A 28 HV Zone substation switchgear 33kV Switch (Pole Mounted) No (9) 4 29 HV Zone substation switchgear 33kV RMU No. N/A 30 HV Zone substation switchgear 22/33kV CB (Indoor) No 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 1,774 1,774 (1) 2 36 HV Distribution Line Distribution OH Aerial Cable Conductor km HV Distribution Line SWER conductor km 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 HV Distribution switchgear 3.3/6.6/11/22kV Switches and fuses (pole mounted) No. 4,744 4, HV Distribution switchgear 3.3/6.6/11/22kV Switch (ground mounted) - except RMU No (7) 4 45 HV Distribution switchgear 3.3/6.6/11/22kV RMU No HV Distribution Transformer Pole Mounted Transformer No. 2,962 3, HV Distribution Transformer Ground Mounted Transformer No. 1,150 1, HV Distribution Transformer Voltage regulators No HV Distribution Substations Ground Mounted Substation Housing No (1) 1 50 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. 45,429 47,953 2, All Protection Protection relays (electromechanical, solid state and numeric) No (2) 4 55 All SCADA and communications SCADA and communications equipment operating as a single system Lot All Capacitor Banks Capacitors including controls No 4 57 All Load Control Centralised plant Lot All Load Control Relays No All Civils Cable Tunnels km N/A Unison - ID Schedule Templates 1 to XLSX 32 S9a.Asset Register CR

33 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 ,883 5,023 11,734 4, ,710 1, , , All Overhead Line Wood poles No ,719 5,898 6,888 3,119 7, , All Overhead Line Other pole types No 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 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. 0 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. N/A 28 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 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 HV Distribution Line SWER conductor km 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 HV Distribution switchgear 3.3/6.6/11/22kV Switches and fuses (pole mounted) No ,561 1,226 1,858 1, , HV Distribution switchgear 3.3/6.6/11/22kV Switch (ground mounted) - except RMU No HV Distribution switchgear 3.3/6.6/11/22kV RMU No , HV Distribution Transformer Pole Mounted Transformer No ,161 1, , 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 ,299 7,210 53,983 1,323 1,192 1,332 1,360 1,391 1,766 1,561 1,537 1,148 1,054 1, ,058 1, , 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 All Load Control Centralised plant Lot All Load Control Relays No , , All Civils Cable Tunnels km N/A Unison - ID Schedule Templates 1 to XLSX 33 S9b.Asset Age Profile

34 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 Hawke's Bay 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 ,115 2,922 7, , All Overhead Line Wood poles No ,114 1,219 5, , All Overhead Line Other pole types No 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 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. N/A 28 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 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 HV Distribution Line SWER conductor km 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 HV Distribution switchgear 3.3/6.6/11/22kV Switches and fuses (pole mounted) No , , HV Distribution switchgear 3.3/6.6/11/22kV Switch (ground mounted) - except RMU No 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. 51, , 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 All Load Control Centralised plant Lot All Load Control Relays No , , All Civils Cable Tunnels km N/A Unison - ID Schedule Templates 1 to XLSX 34 S9b.Asset Age Profile HB

35 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 Central Region 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 ,101 3,776 3, , , All Overhead Line Wood poles No. 1,276 5,455 3,774 1,900 1, , All Overhead Line Other pole types No 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 3 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. N/A 28 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 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 HV Distribution Line SWER conductor km 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 HV Distribution switchgear 3.3/6.6/11/22kV Switches and fuses (pole mounted) No , HV Distribution switchgear 3.3/6.6/11/22kV Switch (ground mounted) - except RMU No 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 ,299 7,210 2, , 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 4 58 All Load Control Centralised plant Lot All Load Control Relays No All Civils Cable Tunnels km N/A Unison - ID Schedule Templates 1 to XLSX 35 S9b.Asset Age Profile CR

36 Network / Sub-network Name SCHEDULE 9c: REPORT ON OVERHEAD LINES AND UNDERGROUND CABLES This schedule requires a summary of the key characteristics of the overhead line and underground cable network. All units relating to cable and line assets, that are expressed in km, refer to circuit lengths Circuit length by operating voltage (at year end) Overhead (km) Underground (km) Total circuit length (km) 11 > 66kV 12 50kV & 66kV 13 33kV SWER (all SWER voltages) kV (other than SWER) kV to 11kV (inclusive other than SWER) 3, , Low voltage (< 1kV) 1,244 2,794 4, Total circuit length (for supply) 5,569 3,676 9, Dedicated street lighting circuit length (km) 360 1,354 1, Circuit in sensitive areas (conservation areas, iwi territory etc) (km) Overhead circuit length by terrain (at year end) Circuit length (km) (% of total overhead length) 24 Urban 1,402 25% 25 Rural 1,263 23% 26 Remote only 251 5% 27 Rugged only 2,654 48% 28 Remote and rugged 29 Unallocated overhead lines 30 Total overhead length 5, % Circuit length (km) (% of total circuit length) 33 Length of circuit within 10km of coastline or geothermal areas (where known) 3,180 34% (% of total 34 Circuit length (km) overhead length) 35 Overhead circuit requiring vegetation management 5, % Unison - ID Schedule Templates 1 to XLSX 36 S9c.Overhead Lines

37 Network / Sub-network Name SCHEDULE 9c: REPORT ON OVERHEAD LINES AND UNDERGROUND CABLES Hawke's Bay This schedule requires a summary of the key characteristics of the overhead line and underground cable network. All units relating to cable and line assets, that are expressed in km, refer to circuit lengths Circuit length by operating voltage (at year end) Overhead (km) Underground (km) Total circuit length (km) 11 > 66kV 12 50kV & 66kV 13 33kV SWER (all SWER voltages) kV (other than SWER) kV to 11kV (inclusive other than SWER) 2, , Low voltage (< 1kV) 738 1,999 2, Total circuit length (for supply) 2,990 2,535 5, Dedicated street lighting circuit length (km) , Circuit in sensitive areas (conservation areas, iwi territory etc) (km) Overhead circuit length by terrain (at year end) Circuit length (km) (% of total overhead length) 24 Urban % 25 Rural % 26 Remote only 15 1% 27 Rugged only 1,253 42% 28 Remote and rugged 29 Unallocated overhead lines 30 Total overhead length 2, % Circuit length (km) (% of total circuit length) 33 Length of circuit within 10km of coastline or geothermal areas (where known) 1,345 24% (% of total 34 Circuit length (km) overhead length) 35 Overhead circuit requiring vegetation management 2, % Unison - ID Schedule Templates 1 to XLSX 37 S9c.Overhead Lines HB

38 Network / Sub-network Name SCHEDULE 9c: REPORT ON OVERHEAD LINES AND UNDERGROUND CABLES Central Region This schedule requires a summary of the key characteristics of the overhead line and underground cable network. All units relating to cable and line assets, that are expressed in km, refer to circuit lengths Circuit length by operating voltage (at year end) Overhead (km) Underground (km) Total circuit length (km) 11 > 66kV 12 50kV & 66kV 13 33kV SWER (all SWER voltages) kV (other than SWER) kV to 11kV (inclusive other than SWER) 1, , Low voltage (< 1kV) , Total circuit length (for supply) 2,580 1,141 3, Dedicated street lighting circuit length (km) Circuit in sensitive areas (conservation areas, iwi territory etc) (km) Overhead circuit length by terrain (at year end) Circuit length (km) (% of total overhead length) 24 Urban % 25 Rural % 26 Remote only 236 9% 27 Rugged only 1,401 54% 28 Remote and rugged 29 Unallocated overhead lines 30 Total overhead length 2, % Circuit length (km) (% of total circuit length) 33 Length of circuit within 10km of coastline or geothermal areas (where known) 1,835 49% (% of total 34 Circuit length (km) overhead length) 35 Overhead circuit requiring vegetation management 2, % Unison - ID Schedule Templates 1 to XLSX 38 S9c.Overhead Lines CR

39 8 Location * 9 Nil SCHEDULE 9d: REPORT ON EMBEDDED NETWORKS This schedule requires information concerning embedded networks owned by an EDB that are embedded in another EDB s network or in another embedded network. Number of ICPs served Line charge revenue ($000) * Extend embedded distribution networks table as necessary to disclose each embedded network owned by the EDB which is embedded in another EDB s network or in another embedded network Unison - ID Schedule Templates 1 to XLSX 39 S9d.Embedded Networks

40 SCHEDULE 9e: REPORT ON NETWORK DEMAND 8 9e(i): Consumer Connections 9 Number of ICPs connected in year by consumer type Network / Sub-network Name 10 Consumer types defined by EDB* Number of connections (ICPs) 11 Residential Commercial Industrial * include additional rows if needed 17 Connections total 1, Distributed generation 20 Number of connections made in year 251 connections 21 Capacity of distributed generation installed in year 0.88 MVA 22 9e(ii): System Demand Maximum coincident system demand 26 GXP demand plus Distributed generation output at HV and above Maximum coincident system demand less Net transfers to (from) other EDBs at HV and above 30 Demand on system for supply to consumers' connection points Electricity volumes carried Energy (GWh) 32 Electricity supplied from GXPs 1, less Electricity exports to GXPs plus Electricity supplied from distributed generation less Net electricity supplied to (from) other EDBs 36 Electricity entering system for supply to consumers' connection points 1, less Total energy delivered to ICPs 1, Electricity losses (loss ratio) % Load factor e(iii): Transformer Capacity This schedule requires a summary of the key measures of network utilisation for the disclosure year (number of new connections including distributed generation, peak demand and electricity volumes conveyed). Demand at time of maximum coincident demand (MW) 42 (MVA) 43 Distribution transformer capacity (EDB owned) 1, Distribution transformer capacity (Non-EDB owned, estimated) Total distribution transformer capacity 1, Zone substation transformer capacity 865 Unison - ID Schedule Templates 1 to XLSX 40 S9e.Demand

41 SCHEDULE 9e: REPORT ON NETWORK DEMAND 8 9e(i): Consumer Connections 9 Number of ICPs connected in year by consumer type Network / Sub-network Name 10 Consumer types defined by EDB* Number of connections (ICPs) 11 Residential Commercial Industrial * include additional rows if needed 17 Connections total Distributed generation 20 Number of connections made in year 141 connections 21 Capacity of distributed generation installed in year 0.56 MVA 22 9e(ii): System Demand Maximum coincident system demand 26 GXP demand plus Distributed generation output at HV and above 3 28 Maximum coincident system demand less Net transfers to (from) other EDBs at HV and above 30 Demand on system for supply to consumers' connection points Electricity volumes carried Energy (GWh) 32 Electricity supplied from GXPs less Electricity exports to GXPs 34 plus Electricity supplied from distributed generation less Net electricity supplied to (from) other EDBs 36 Electricity entering system for supply to consumers' connection points 1, less Total energy delivered to ICPs Electricity losses (loss ratio) % Load factor e(iii): Transformer Capacity Hawke's Bay This schedule requires a summary of the key measures of network utilisation for the disclosure year (number of new connections including distributed generation, peak demand and electricity volumes conveyed). Demand at time of maximum coincident demand (MW) 42 (MVA) 43 Distribution transformer capacity (EDB owned) Distribution transformer capacity (Non-EDB owned, estimated) Total distribution transformer capacity Zone substation transformer capacity 611 Unison - ID Schedule Templates 1 to XLSX 41 S9e.Demand HB

42 SCHEDULE 9e: REPORT ON NETWORK DEMAND 8 9e(i): Consumer Connections 9 Number of ICPs connected in year by consumer type Network / Sub-network Name 10 Consumer types defined by EDB* Number of connections (ICPs) 11 Residential Commercial Industrial * include additional rows if needed 17 Connections total Distributed generation 20 Number of connections made in year 110 connections 21 Capacity of distributed generation installed in year 0.32 MVA 22 9e(ii): System Demand Maximum coincident system demand 26 GXP demand plus Distributed generation output at HV and above Maximum coincident system demand less Net transfers to (from) other EDBs at HV and above 30 Demand on system for supply to consumers' connection points Electricity volumes carried Energy (GWh) 32 Electricity supplied from GXPs less Electricity exports to GXPs plus Electricity supplied from distributed generation less Net electricity supplied to (from) other EDBs 36 Electricity entering system for supply to consumers' connection points less Total energy delivered to ICPs Electricity losses (loss ratio) % Load factor e(iii): Transformer Capacity Central Region This schedule requires a summary of the key measures of network utilisation for the disclosure year (number of new connections including distributed generation, peak demand and electricity volumes conveyed). Demand at time of maximum coincident demand (MW) 42 (MVA) 43 Distribution transformer capacity (EDB owned) Distribution transformer capacity (Non-EDB owned, estimated) 7 45 Total distribution transformer capacity Zone substation transformer capacity 254 Unison - ID Schedule Templates 1 to XLSX 42 S9e.Demand CR

43 SCHEDULE 10: REPORT ON NETWORK RELIABILITY 8 10(i): Interruptions Network / Sub-network Name 9 Interruptions by class Number of interruptions 10 Class A (planned interruptions by Transpower) 3 11 Class B (planned interruptions on the network) Class C (unplanned interruptions on the network) Class D (unplanned interruptions by Transpower) Class E (unplanned interruptions of EDB owned generation) - 15 Class F (unplanned interruptions of generation owned by others) Class G (unplanned interruptions caused by another disclosing entity) - 17 Class H (planned interruptions caused by another disclosing entity) - 18 Class I (interruptions caused by parties not included above) Total 1, Interruption restoration 3Hrs >3hrs 22 Class C interruptions restored within SAIFI and SAIDI by class SAIFI SAIDI 25 Class A (planned interruptions by Transpower) Class B (planned interruptions on the network) Class C (unplanned interruptions on the network) Class D (unplanned interruptions by Transpower) Class E (unplanned interruptions of EDB owned generation) Class F (unplanned interruptions of generation owned by others) Class G (unplanned interruptions caused by another disclosing entity) Class H (planned interruptions caused by another disclosing entity) Class I (interruptions caused by parties not included above) Total This schedule requires a summary of the key measures of network reliability (interruptions, SAIDI, SAIFI and fault rate) for the disclosure year. EDBs must provide explanatory comment on their network reliability for the disclosure year in Schedule 14 (Explanatory notes to templates). The SAIFI and SAIDI 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 Normalised SAIFI and SAIDI Normalised SAIFI Normalised SAIDI 37 Classes B & C (interruptions on the network) SAIFI reliability limit SAIDI reliability limit 39 Quality path normalised reliability limit 40 SAIFI and SAIDI limits applicable to disclosure year* * not applicable to exempt EDBs Unison - ID Schedule Templates 1 to XLSX 43 S10.Reliability

44 SCHEDULE 10: REPORT ON NETWORK RELIABILITY Network / Sub-network Name This schedule requires a summary of the key measures of network reliability (interruptions, SAIDI, SAIFI and fault rate) for the disclosure year. EDBs must provide explanatory comment on their network reliability for the disclosure year in Schedule 14 (Explanatory notes to templates). The SAIFI and SAIDI 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 (ii): Class C Interruptions and Duration by Cause Cause SAIFI SAIDI 45 Lightning Vegetation Adverse weather Adverse environment Third party interference Wildlife Human error Defective equipment Cause unknown (iii): Class B Interruptions and Duration by Main Equipment Involved Main equipment involved SAIFI SAIDI 58 Subtransmission lines Subtransmission cables Subtransmission other 61 Distribution lines (excluding LV) Distribution cables (excluding LV) Distribution other (excluding LV) (iv): Class C Interruptions and Duration by Main Equipment Involved Main equipment involved SAIFI SAIDI 67 Subtransmission lines Subtransmission cables Subtransmission other Distribution lines (excluding LV) Distribution cables (excluding LV) Distribution other (excluding LV) (v): Fault Rate 74 Main equipment involved Number of Faults Circuit length (km) Fault rate (faults per 100km) 75 Subtransmission lines Subtransmission cables Subtransmission other 4 78 Distribution lines (excluding LV) 1,287 3, Distribution cables (excluding LV) Distribution other (excluding LV) Total 1,656 Unison - ID Schedule Templates 1 to XLSX 44 S10.Reliability

45 SCHEDULE 10: REPORT ON NETWORK RELIABILITY 8 10(i): Interruptions Network / Sub-network Name 9 Interruptions by class Number of interruptions 10 Class A (planned interruptions by Transpower) 11 Class B (planned interruptions on the network) Class C (unplanned interruptions on the network) Class D (unplanned interruptions by Transpower) 4 14 Class E (unplanned interruptions of EDB owned generation) - 15 Class F (unplanned interruptions of generation owned by others) 9 16 Class G (unplanned interruptions caused by another disclosing entity) - 17 Class H (planned interruptions caused by another disclosing entity) - 18 Class I (interruptions caused by parties not included above) Total Interruption restoration 3Hrs >3hrs 22 Class C interruptions restored within SAIFI and SAIDI by class SAIFI SAIDI 25 Class A (planned interruptions by Transpower) 26 Class B (planned interruptions on the network) Class C (unplanned interruptions on the network) Class D (unplanned interruptions by Transpower) Class E (unplanned interruptions of EDB owned generation) Class F (unplanned interruptions of generation owned by others) Class G (unplanned interruptions caused by another disclosing entity) Class H (planned interruptions caused by another disclosing entity) Class I (interruptions caused by parties not included above) Total Hawke's Bay This schedule requires a summary of the key measures of network reliability (interruptions, SAIDI, SAIFI and fault rate) for the disclosure year. EDBs must provide explanatory comment on their network reliability for the disclosure year in Schedule 14 (Explanatory notes to templates). The SAIFI and SAIDI 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 Normalised SAIFI and SAIDI Normalised SAIFI Normalised SAIDI 37 Classes B & C (interruptions on the network) SAIFI reliability limit 39 Quality path normalised reliability limit 40 SAIFI and SAIDI limits applicable to disclosure year* N/A N/A 41 * not applicable to exempt EDBs SAIDI reliability limit Unison - ID Schedule Templates 1 to XLSX 45 S10.Reliability HB

46 SCHEDULE 10: REPORT ON NETWORK RELIABILITY Network / Sub-network Name Hawke's Bay This schedule requires a summary of the key measures of network reliability (interruptions, SAIDI, SAIFI and fault rate) for the disclosure year. EDBs must provide explanatory comment on their network reliability for the disclosure year in Schedule 14 (Explanatory notes to templates). The SAIFI and SAIDI 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 (ii): Class C Interruptions and Duration by Cause Cause SAIFI SAIDI 45 Lightning Vegetation Adverse weather Adverse environment Third party interference Wildlife Human error Defective equipment Cause unknown (iii): Class B Interruptions and Duration by Main Equipment Involved Main equipment involved SAIFI SAIDI 58 Subtransmission lines Subtransmission cables Subtransmission other Distribution lines (excluding LV) Distribution cables (excluding LV) Distribution other (excluding LV) (iv): Class C Interruptions and Duration by Main Equipment Involved Main equipment involved SAIFI SAIDI 67 Subtransmission lines Subtransmission cables Subtransmission other Distribution lines (excluding LV) Distribution cables (excluding LV) Distribution other (excluding LV) (v): Fault Rate 74 Main equipment involved Number of Faults Circuit length (km) Fault rate (faults per 100km) 75 Subtransmission lines Subtransmission cables Subtransmission other 2 78 Distribution lines (excluding LV) 684 2, Distribution cables (excluding LV) Distribution other (excluding LV) Total 941 Unison - ID Schedule Templates 1 to XLSX 46 S10.Reliability HB

47 SCHEDULE 10: REPORT ON NETWORK RELIABILITY 8 10(i): Interruptions Network / Sub-network Name 9 Interruptions by class Number of interruptions 10 Class A (planned interruptions by Transpower) 3 11 Class B (planned interruptions on the network) Class C (unplanned interruptions on the network) Class D (unplanned interruptions by Transpower) Class E (unplanned interruptions of EDB owned generation) - 15 Class F (unplanned interruptions of generation owned by others) 1 16 Class G (unplanned interruptions caused by another disclosing entity) - 17 Class H (planned interruptions caused by another disclosing entity) - 18 Class I (interruptions caused by parties not included above) Total Interruption restoration 3Hrs >3hrs 22 Class C interruptions restored within SAIFI and SAIDI by class SAIFI SAIDI 25 Class A (planned interruptions by Transpower) Class B (planned interruptions on the network) Class C (unplanned interruptions on the network) Class D (unplanned interruptions by Transpower) Class E (unplanned interruptions of EDB owned generation) Class F (unplanned interruptions of generation owned by others) Class G (unplanned interruptions caused by another disclosing entity) Class H (planned interruptions caused by another disclosing entity) Class I (interruptions caused by parties not included above) Total Central Region This schedule requires a summary of the key measures of network reliability (interruptions, SAIDI, SAIFI and fault rate) for the disclosure year. EDBs must provide explanatory comment on their network reliability for the disclosure year in Schedule 14 (Explanatory notes to templates). The SAIFI and SAIDI 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 Normalised SAIFI and SAIDI Normalised SAIFI Normalised SAIDI 37 Classes B & C (interruptions on the network) SAIFI reliability limit 39 Quality path normalised reliability limit 40 SAIFI and SAIDI limits applicable to disclosure year* N/A N/A 41 * not applicable to exempt EDBs SAIDI reliability limit Unison - ID Schedule Templates 1 to XLSX 47 S10.Reliability CR

48 SCHEDULE 10: REPORT ON NETWORK RELIABILITY Network / Sub-network Name Central Region This schedule requires a summary of the key measures of network reliability (interruptions, SAIDI, SAIFI and fault rate) for the disclosure year. EDBs must provide explanatory comment on their network reliability for the disclosure year in Schedule 14 (Explanatory notes to templates). The SAIFI and SAIDI 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 (ii): Class C Interruptions and Duration by Cause Cause SAIFI SAIDI 45 Lightning Vegetation Adverse weather Adverse environment Third party interference Wildlife Human error Defective equipment Cause unknown (iii): Class B Interruptions and Duration by Main Equipment Involved Main equipment involved SAIFI SAIDI 58 Subtransmission lines Subtransmission cables Subtransmission other Distribution lines (excluding LV) Distribution cables (excluding LV) Distribution other (excluding LV) (iv): Class C Interruptions and Duration by Main Equipment Involved Main equipment involved SAIFI SAIDI 67 Subtransmission lines Subtransmission cables Subtransmission other 70 Distribution lines (excluding LV) Distribution cables (excluding LV) Distribution other (excluding LV) (v): Fault Rate 74 Main equipment involved Number of Faults Circuit length (km) Fault rate (faults per 100km) 75 Subtransmission lines Subtransmission cables Subtransmission other 2 78 Distribution lines (excluding LV) 603 1, Distribution cables (excluding LV) Distribution other (excluding LV) Total 715 Unison - ID Schedule Templates 1 to XLSX 48 S10.Reliability CR

49 Electricity Distribution Information Disclosure Determination 2012 (consolidated in 2015) Schedules Schedule 14 Mandatory Explanatory Notes 1. This schedule requires EDBs to provide explanatory notes to information provided in accordance with clauses 2.3.1, , , and subclauses 2.5.1(1)(f),and 2.5.2(1)(e). 2. This schedule is mandatory EDBs must provide the explanatory comment specified below, in accordance with clause Information provided in boxes 1 to 12 of this schedule is part of the audited disclosure information, and so is subject to the assurance requirements specified in section Schedule 15 (Voluntary Explanatory Notes to Schedules) provides for EDBs to give additional explanation of disclosed information should they elect to do so. Return on Investment (Schedule 2) 4. In the box below, comment on return on investment as disclosed in Schedule 2. This comment must include information on reclassified items in accordance with subclause 2.7.1(2). Box 1: Explanatory comment on return on investment There has been no material re-classification of items in the disclosure year. Regulatory Profit (Schedule 3) 5. In the box below, comment on regulatory profit for the disclosure year as disclosed in Schedule 3. This comment must include- 5.1 a description of material items included in other regulated income (other than gains / (losses) on asset disposals), as disclosed in 3(i) of Schedule information on reclassified items in accordance with subclause 2.7.1(2). Box 2: Explanatory comment on regulatory profit Other regulatory income includes recovery from damages to the network and connection fees. There has been no material re-classification of items in the disclosure year. Merger and acquisition expenses (3(iv) of Schedule 3) 6. If the EDB incurred merger and acquisitions expenditure during the disclosure year, provide the following information in the box below-

50 Electricity Distribution Information Disclosure Determination 2012 (consolidated in 2015) Schedules information on reclassified items in accordance with subclause 2.7.1(2) 6.2 any other commentary on the benefits of the merger and acquisition expenditure to the EDB. Box 3: Explanatory comment on merger and acquisition expenditure No merger and acquisition expenditure has been incurred during the disclosure year. Value of the Regulatory Asset Base (Schedule 4) 7. In the box below, comment on the value of the regulatory asset base (rolled forward) in Schedule 4. This comment must include information on reclassified items in accordance with subclause 2.7.1(2). Box 4: Explanatory comment on the value of the regulatory asset based (rolled forward) The value of the regulatory asset base has been determined by rolling forward the initial regulatory asset base with allowance made for additions, disposals, depreciation and revaluation in accordance with the Electricity Distribution Services Input Methodologies Determination Disposals: Unison s Electric Vehicle Chargers have been disposed of from the Regulatory Asset Base. This is upon advice from the Commerce Commission that EV chargers are to be treated as non-regulatory assets. Reclassification of Assets: There were minor reclassification of assets to align all asset classes to one category. Streetlights are now classified as Distribution and LV Lines and Other Equipment classified as Zone Substations. Regulatory tax allowance: disclosure of permanent differences (5a(i) of Schedule 5a) 8. In the box below, provide descriptions and workings of the material items recorded in the following asterisked categories of 5a(i) of Schedule 5a- 8.1 Income not included in regulatory profit / (loss) before tax but taxable; 8.2 Expenditure or loss in regulatory profit / (loss) before tax but not deductible; 8.3 Income included in regulatory profit / (loss) before tax but not taxable; 8.4 Expenditure or loss deductible but not in regulatory profit / (loss) before tax. Box 5: Regulatory tax allowance: permanent differences Entertainment Expenditure non-deductible $22k

51 Electricity Distribution Information Disclosure Determination 2012 (consolidated in 2015) Schedules Regulatory tax allowance: disclosure of temporary differences (5a(vi) of Schedule 5a) 9. In the box below, provide descriptions and workings of material items recorded in the asterisked category Tax effect of other temporary differences in 5a(vi) of Schedule 5a. Box 6: Tax effect of other temporary differences (current disclosure year) Other temporary differences: Provision for Doubtful Debts $ 27k Provision for Employee Entitlements $193k Provision for ACC $ 2k Total $222k Related party transactions: disclosure of related party transactions (Schedule 5b) 10. In the box below, provide descriptions of related party transactions beyond those disclosed on Schedule 5b including identification and descriptions as to the nature of directly attributable costs disclosed under subclause 2.3.6(1)(b). Box 7: Related party transactions s wholly owned subsidiary Unison Contracting Services Limited (UCSL) provided electrical contracting services to maintain and develop the network during the 2018 disclosure year. UCSL related party transactions have been prepared on the basis of consolidating and UCSL according to guidance previously provided to Unison from the Commerce Commission, which has been disclosed in previous years. A detailed description of related party transactions has been disclosed in Schedule 5b. There have been no related party transactions within the disclosure year that require further disclosure under clause 2.3.6(1)(b). Cost allocation (Schedule 5d) 11. In the box below, comment on cost allocation as disclosed in Schedule 5d. This comment must include information on reclassified items in accordance with subclause 2.7.1(2). Box 8: Cost allocation Costs are allocated by applying ACAM. Expenses classified as not directly attributable are those which have been allocated to electricity and non-electricity activities. Asset allocation (Schedule 5e)

52 Electricity Distribution Information Disclosure Determination 2012 (consolidated in 2015) Schedules In the box below, comment on asset allocation as disclosed in Schedule 5e. This comment must include information on reclassified items in accordance with subclause 2.7.1(2). Box 9: Commentary on asset allocation There have been no reclassified items. Capital Expenditure for the Disclosure Year (Schedule 6a) 13. In the box below, comment on expenditure on assets for the disclosure year, as disclosed in Schedule 6a. This comment must include a description of the materiality threshold applied to identify material projects and programmes described in Schedule 6a; 13.2 information on reclassified items in accordance with subclause 2.7.1(2), Box 10: Explanation of capital expenditure for the disclosure year 13.1 Material projects are defined by Unison as those projects with significant strategic importance to the network as determined by Unison s engineers, or those projects with total Capital Costs of greater than $250, There have been no reclassified items. Operational Expenditure for the Disclosure Year (Schedule 6b) 14. In the box below, comment on operational expenditure for the disclosure year, as disclosed in Schedule 6b. This comment must include Commentary on assets replaced or renewed with asset replacement and renewal operational expenditure, as reported in 6b(i) of Schedule 6b; 14.2 Information on reclassified items in accordance with subclause 2.7.1(2); 14.3 Commentary on any material atypical expenditure included in operational expenditure disclosed in Schedule 6b, a including the value of the expenditure the purpose of the expenditure, and the operational expenditure categories the expenditure relates to.

53 Electricity Distribution Information Disclosure Determination 2012 (consolidated in 2015) Schedules Box 11: Explanation of operational expenditure for the disclosure year 14.1 The predominant parts of Asset Replacement and Renewal operational expenditure are the costs required for replacing components of assets identified through Unison s planned asset inspection programmes. The major contributor to this category of expenditure is overhead line maintenance, and then zone substation grounds and graffiti removal There have been no reclassified items this disclosure year There was increased expenditure in the Service Interruptions and Emergencies category which was heavily influenced by the increased frequency of storm events experienced during the year. The cost impact of these storms was approximately $486k. Variance between forecast and actual expenditure (Schedule 7) 15. In the box below, comment on variance in actual to forecast expenditure for the disclosure year, as reported in Schedule 7. This comment must include information on reclassified items in accordance with subclause 2.7.1(2).

54 Electricity Distribution Information Disclosure Determination 2012 (consolidated in 2015) Schedules Box 12: Explanatory comment on variance in actual to forecast expenditure 7(ii) Expenditure on Assets (CAPEX) The overall variance for network capital expenditure in the reporting period was 1% over budget which is not considered material. However, there were some variances within categories of expenditure. The key variances were: - an increase in spend on Customer Connections due to several significant industrial connections and residential subdivision developments across the network. - an increase in spend in the Other Reliability, Safety and Environment category associated with the execution of a number of unbudgeted projects to improve network reliability. - a decrease in spend in the Quality of Supply category due to the deferral of a high value project into the following financial year. 7(iii) Operational Expenditure (OPEX) In respect to Network Opex, the variance in spend from the RAMP forecast was 18% overbudget. This was primarily driven by variances within Service Interruptions and Emergencies and Vegetation Management of 47% and 21% respectively. The Service Interruption and Emergencies variance was heavily influenced by the increased frequency of storm events, which typically carry large First Response costs and significant repairs to overhead assets. The Vegetation Management budget was impacted by a decision to recruit and deploy two additional vegetation crews to mitigate the significant impact vegetation was having on network reliability. Information relating to revenues and quantities for the disclosure year 16. In the box below provide a comparison of the target revenue disclosed before the start of the disclosure year, in accordance with clause and subclause 2.4.3(3) to total billed line charge revenue for the disclosure year, as disclosed in Schedule 8; and 16.2 explanatory comment on reasons for any material differences between target revenue and total billed line charge revenue.

55 Electricity Distribution Information Disclosure Determination 2012 (consolidated in 2015) Schedules Box 13: Explanatory comment relating to revenue for the disclosure year Regulated Line Revenue is $2.2 million above budget due to a combination of growth and higher than forecast electricity consumption: Residential consumption was 13 GWh higher than forecast resulting in a variance of $1.5 million. Commercial consumption was $0.3 million higher than forecast. Industrial consumption was 23 GWh higher than forecast and the growth in this sector resulted in a variance of $0.4 million. Network Reliability for the Disclosure Year (Schedule 10) 17. In the box below, comment on network reliability for the disclosure year, as disclosed in Schedule 10. Box 14: Commentary on network reliability for the disclosure year Unison did not comply with the annual reliability assessment for SAIDI for the assessment period 1/4/2017 to 31/3/2018. Non-compliance was due to the following factors: Significant increase in the number extreme weather events compared to historic average. Unison encountered three storms with >140km/h winds that resulted in four (4) Major Event Days. The vast majority of these outages were caused by vegetation. A significant increase in planned outages as a result of the electricity supply industry developing a guideline for live line work. The impact of the guideline is an increase in the number of tasks performed de-energised. Increased restoration times for transient faults due to the EEA s Guide for Manual Reclosing of High Voltage Circuits Following a Fault. This requires waiting 15 minutes before any manual reclose attempts are made. A continued increase in the impact of external influence events including damage by third parties, such as motor accidents. Unison has derived the normalised SAIFI and normalised SAIDI values for each sub-network using the normalised assessment dataset for the network (constructed with boundary values calculated using the reference dataset for the network). The Normalised SAIFI/SAIDI for each event has then been multiplied by (total ICPs divided by sub-network ICPs) for each sub-network to yield the sub-network normalised values. This approach was chosen as the boundary values for the total network have been previously calculated.

56 Electricity Distribution Information Disclosure Determination 2012 (consolidated in 2015) Schedules Insurance cover 18. In the box below, provide details of any insurance cover for the assets used to provide electricity distribution services, including The EDB s approaches and practices in regard to the insurance of assets used to provide electricity distribution services, including the level of insurance; 18.2 In respect of any self insurance, the level of reserves, details of how reserves are managed and invested, and details of any reinsurance. Box 15: Explanation of insurance cover Unison seeks to insure all its assets for material damage and business interruption cover. It employs two policies to achieve this. The MD & BI policy, placed in the retail market, covers all Ground-mounted distribution equipment, substation buildings and substation equipment as well as all corporate buildings and non-network assets. Total sum insured for the policy is $513M (for 2017/18) which includes a $10M component for business interruption cover. The deductible is $10,000 with a $100,000 deductible applying for ground mounted assets. Because no retail cover is available for Unison s T&D assets (poles and wires, pole mounted equipment and underground cables) Unison owns a captive insurance company, Unison Insurance Limited, which provides a self-insurance policy to the value of $15M. This figure includes $3M of business interruption cover. The policy is reviewed annually, along with any changes to the retail T&D market and carries a deductible of $5,000,000. Amendments to previously disclosed information 19. In the box below, provide information about amendments to previously disclosed information disclosed in accordance with clause in the last 7 years, including: 19.1 a description of each error; and 19.2 for each error, reference to the web address where the disclosure made in accordance with clause is publicly disclosed. Box 16: Disclosure of amendment to previously disclosed information N/A

57 Electricity Distribution Information Disclosure Determination 2012 (consolidated in 2015) Schedules Schedule 15 Voluntary Explanatory Notes 1. This schedule enables EDBs to provide, should they wish to- 1.1 additional explanatory comment to reports prepared in accordance with clauses 2.3.1, , , and 2.5.2; 1.2 information on any substantial changes to information disclosed in relation to a prior disclosure year, as a result of final wash-ups. 2. Information in this schedule is not part of the audited disclosure information, and so is not subject to the assurance requirements specified in section Provide additional explanatory comment in the box below. Box 1: Voluntary explanatory comment on disclosed information [Insert text below]

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