Information Disclosure Reports prepared according to Part 4 of the Commerce Act 1986

Information Disclosure Reports prepared according to Part 4 of the Commerce Act 1986 For the Year Ended

CONTENTS INTRODUCTION REPORTS DESCRIPTION 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 5B 5C 5D 5E 6A 6B REPORT ON REGULATORY TAX ALLOWANCE REPORT ON RELATED PARTY TRANSACTIONS REPORT ON TERM CREDIT SPREAD DIFFERENTIAL ALLOWANCE REPORT ON COST ALLOCATIONS REPORT ON ASSET ALLOCATIONS REPORT ON CAPITAL EXPENDITURE FOR THE DISCLOSURE YEAR 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 9B 9C 9D 9E ASSET REGISTER ASSET AGE PROFILE REPORT ON OVERHEAD LINES REPORT ON EMBEDDED NETWORKS REPORT ON DEMAND 10 REPORT ON NETWORK RELIABILITY 14 MANDATORY EXPLANATORY NOTES 15 VOLUNTARY EXPLANATORY NOTES INDEPENDENT AUDITOR S ASSURANCE REPORT DIRECTOR S CERTIFICATE

INTRODUCTION These Information Disclosure Reports are dislosed by pursuant to Part 4 of the Commerce Act 1986 in accordance with: Electricity Distribution Information Disclosure Determination 2012 (consolidated in 2015)

REPORTS SCHEDULE 1: ANALYTICAL RATIOS 7 1(i): Expenditure metrics 8 Expenditure per GWh energy delivered to ICPs ($/GWh) This schedule calculates expenditure, revenue and service ratios from the information disclosed. The disclosed ratios may vary for reasons that are company specific and, as a result, must be interpreted with care. The Commerce Commission will publish a summary and analysis of information disclosed in accordance with the ID determination. This will include information disclosed in accordance with this and other schedules, and information disclosed under the other requirements of the determination. This information is part of audited disclosure information (as defined in section 1.4 of the ID determination), and so is subject to the assurance report required by section 2.8. Expenditure per average no. of ICPs ($/ICP) Expenditure per MW maximum coincident system demand ($/MW) Expenditure per km circuit length ($/km) Expenditure per MVA of capacity from EDBowned distribution transformers ($/MVA) 9 Operational expenditure 17,081 363 102,241 3,582 39,319 10 Network 6,714 143 40,190 1,408 15,456 11 Non-network 10,367 220 62,051 2,174 23,863 12 13 Expenditure on assets 13,901 295 83,204 2,915 31,998 14 Network 12,938 275 77,439 2,713 29,781 15 Non-network 963 20 5,765 202 2,217 16 17 1(ii): Revenue metrics 18 Revenue per GWh energy delivered to ICPs ($/GWh) Revenue per average no. of ICPs ($/ICP) 19 Total consumer line charge revenue 58,188 1,236 20 Standard consumer line charge revenue 105,795 1,072 21 Non-standard consumer line charge revenue 14,771 339,382 22 23 1(iii): Service intensity measures 24 25 Demand density 35 Maximum coincident system demand per km of circuit length (for supply) (kw/km) 26 Volume density 210 Total energy delivered to ICPs per km of circuit length (for supply) (MWh/km) 27 Connection point density 10 Average number of ICPs per km of circuit length (for supply) (ICPs/km) 28 Energy intensity 21,241 Total energy delivered to ICPs per average number of ICPs (kwh/icp) 29 30 1(iv): Composition of regulatory income 31 ($000) % of revenue 32 Operational expenditure 9,005 28.98% 33 Pass-through and recoverable costs excluding financial incentives and wash-ups 9,153 29.46% 34 Total depreciation 5,526 17.78% 35 Total revaluations 663 2.13% 36 Regulatory tax allowance 823 2.65% 37 Regulatory profit/(loss) including financial incentives and wash-ups 7,230 23.27% 38 Total regulatory income 31,074 39 40 1(v): Reliability 41 42 Interruption rate 9.39 Interruptions per 100 circuit km

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 2.3.3 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 2.8. 7 2(i): Return on Investment CY-2 CY-1 Current Year CY 8 31 Mar 14 31 Mar 15 31 Mar 16 9 ROI comparable to a post tax WACC % % % 10 Reflecting all revenue earned 6.60% 4.16% 6.32% 11 Excluding revenue earned from financial incentives 6.60% 4.16% 6.32% 12 Excluding revenue earned from financial incentives and wash-ups 6.60% 4.60% 6.32% 13 14 Mid-point estimate of post tax WACC 5.43% 6.10% 5.37% 15 25th percentile estimate 4.71% 5.39% 4.66% 16 75th percentile estimate 6.14% 6.82% 6.09% 17 18 19 ROI comparable to a vanilla WACC 20 Reflecting all revenue earned 7.28% 4.94% 6.51% 21 Excluding revenue earned from financial incentives 7.28% 4.94% 6.51% 22 Excluding revenue earned from financial incentives and wash-ups 7.28% 5.39% 6.51% 23 24 WACC rate used to set regulatory price path 8.77% 8.77% 7.19% 25 26 Mid-point estimate of vanilla WACC 6.11% 6.89% 6.02% 27 25th percentile estimate 5.39% 6.17% 5.30% 28 75th percentile estimate 6.83% 7.60% 6.74% 29 30 2(ii): Information Supporting the ROI ($000) 31 32 Total opening RAB value 113,283 33 plus Opening deferred tax (4,663) 34 Opening RIV 108,619 35 36 Line charge revenue 30,675 37 38 Expenses cash outflow 18,158 39 add Assets commissioned 6,488 40 less Asset disposals 51 41 add Tax payments 5,486 42 less Other regulated income 399 43 Mid-year net cash outflows 29,682 44 45 Term credit spread differential allowance 46 47 Total closing RAB value 114,857 48 less Adjustment resulting from asset allocation 0 49 less Lost and found assets adjustment 50 plus Closing deferred tax (0) 51 Closing RIV 114,857 52 53 ROI comparable to a vanilla WACC 6.51% 54 55 Leverage (%) 44% 56 Cost of debt assumption (%) 5.26% 57 Corporate tax rate (%) 9% 58 59 ROI comparable to a post tax WACC 6.32% 60

SCHEDULE 2: REPORT ON RETURN ON INVESTMENT 61 2(iii): Information Supporting the Monthly ROI 62 63 Opening RIV N/A 64 65 Line charge revenue Expenses cash Assets Asset Other regulated Monthly net cash 66 outflow commissioned disposals income outflows 67 April 68 May 69 June 70 July 71 August 72 September 73 October 74 November 75 December 76 January 77 February 78 March 79 Total 80 81 Tax payments N/A 82 83 Term credit spread differential allowance N/A 84 85 Closing RIV N/A 86 87 88 Monthly ROI comparable to a vanilla WACC N/A 89 90 Monthly ROI comparable to a post tax WACC N/A 91 92 2(iv): Year-End ROI Rates for Comparison Purposes 93 94 Year-end ROI comparable to a vanilla WACC 6.46% 95 96 Year-end ROI comparable to a post tax WACC 6.26% 97 98 * 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. 99 100 2(v): Financial Incentives and Wash-Ups 101 102 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 106 Other financial incentives 107 Financial incentives 108 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 2.3.3 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 2.8. 109 Impact of financial incentives on ROI 110 111 Input methodology claw-back 112 Recoverable customised price-quality path costs 113 Catastrophic event allowance 114 Capex wash-up adjustment 115 Transmission asset wash-up adjustment 116 2013 2015 NPV wash-up allowance 117 Reconsideration event allowance 118 Other wash-ups 119 Wash-up costs 120 121 Impact of wash-up costs on ROI

SCHEDULE 3: REPORT ON REGULATORY PROFIT 7 3(i): Regulatory Profit ($000) 8 Income 9 Line charge revenue 30,675 10 plus Gains / (losses) on asset disposals 39 11 plus Other regulated income (other than gains / (losses) on asset disposals) 360 12 13 Total regulatory income 31,074 14 Expenses 15 less Operational expenditure 9,005 16 17 less Pass-through and recoverable costs excluding financial incentives and wash-ups 9,153 18 19 Operating surplus / (deficit) 12,916 20 21 less Total depreciation 5,526 22 23 plus Total revaluations 663 24 25 Regulatory profit / (loss) before tax 8,053 26 27 less Term credit spread differential allowance 28 29 less Regulatory tax allowance 823 30 31 Regulatory profit/(loss) including financial incentives and wash-ups 7,230 32 33 3(ii): Pass-through and Recoverable Costs excluding Financial Incentives and Wash-Ups ($000) 34 Pass through costs 35 Rates 208 36 Commerce Act levies 39 37 Industry levies 92 38 CPP specified pass through costs 39 Recoverable costs excluding financial incentives and wash-ups This schedule requires information on the calculation of regulatory profit for the EDB for the disclosure year. All EDBs must complete all sections and provide explanatory comment on their regulatory profit in Schedule 14 (Mandatory Explanatory Notes). This information is part of audited disclosure information (as defined in section 1.4 of the ID determination), and so is subject to the assurance report required by section 2.8. 40 Electricity lines service charge payable to Transpower 6,630 41 Transpower new investment contract charges 42 System operator services 43 Distributed generation allowance 2,184 44 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 9,153 47

SCHEDULE 3: REPORT ON REGULATORY PROFIT 48 3(iii): Incremental Rolling Incentive Scheme ($000) 49 CY-1 CY 50 31 Mar 15 31 Mar 16 51 Allowed controllable opex 52 Actual controllable opex 53 54 Incremental change in year 55 56 Previous years' incremental change Previous years' adjusted for incremental change inflation 57 CY-5 31 Mar 11 58 CY-4 31 Mar 12 59 CY-3 31 Mar 13 60 CY-2 31 Mar 14 61 CY-1 31 Mar 15 62 Net incremental rolling incentive scheme 63 64 Net recoverable costs allowed under incremental rolling incentive scheme 65 3(iv): Merger and Acquisition Expenditure 70 66 Merger and acquisition expenditure 67 68 69 3(v): Other Disclosures 70 This schedule requires information on the calculation of regulatory profit for the EDB for the disclosure year. All EDBs must complete all sections and provide explanatory comment on their regulatory profit in Schedule 14 (Mandatory Explanatory Notes). This information is part of audited disclosure information (as defined in section 1.4 of the ID determination), and so is subject to the assurance report required by section 2.8. Provide commentary on the benefits of merger and acquisition expenditure to the electricity distribution business, including required disclosures in accordance with section 2.7, in Schedule 14 (Mandatory Explanatory Notes) 71 Self-insurance allowance ($000) ($000)

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 2.8. 7 4(i): Regulatory Asset Base Value (Rolled Forward) RAB RAB RAB RAB RAB 8 Mar Mar Mar Mar Mar for year ended 31 12 31 13 31 14 31 15 31 16 9 ($000) ($000) ($000) ($000) ($000) 10 101,071 101,722 104,498 110,624 113,283 Total opening RAB value 11 12 less Total depreciation 4,483 4,378 4,656 5,001 5,526 13 14 plus Total revaluations 1,578 870 1,604 93 663 15 16 plus Assets commissioned 3,976 6,688 9,279 7,726 6,488 17 18 less Asset disposals 420 404 100 158 51 19 20 plus Lost and found assets adjustment 21 22 plus Adjustment resulting from asset allocation 0 0 (0) 0 23 24 Total closing RAB value 101,722 104,498 110,624 113,283 114,857 25 26 4(ii): Unallocated Regulatory Asset Base 27 Unallocated RAB * RAB 28 ($000) ($000) ($000) ($000) 113,283 113,283 29 Total opening RAB value 30 less 31 Total depreciation 5,526 5,526 32 plus 33 Total revaluations 663 663 34 plus 35 Assets commissioned (other than below) 1,033 1,033 36 Assets acquired from a regulated supplier 37 Assets acquired from a related party 5,455 5,455 38 Assets commissioned 6,488 6,488 39 less 40 Asset disposals (other than below) 51 51 41 Asset disposals to a regulated supplier 42 Asset disposals to a related party 43 Asset disposals 51 51 44 45 plus Lost and found assets adjustment 46 47 plus Adjustment resulting from asset allocation 0 48 49 Total closing RAB value 114,857 114,857 50 * 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. 51 52 4(iii): Calculation of Revaluation Rate and Revaluation of Assets 53 54 1,200 CPI4 55 CPI4-4 1,193 56 Revaluation rate (%) 0.59% 57 58 Unallocated RAB * RAB 59 ($000) ($000) ($000) ($000) 113,283 113,283 60 Total opening RAB value 61 less Opening value of fully depreciated, disposed and lost assets 279 279 62 63 Total opening RAB value subject to revaluation 113,004 113,004 64 Total revaluations 663 663 65 66 4(iv): Roll Forward of Works Under Construction 67 Unallocated works under construction Allocated works under construction 68 Works under construction preceding disclosure year 1,614 1,614 69 Capital expenditure 7,136 plus 7,136 70 less Assets commissioned 6,488 6,488 71 plus Adjustment resulting from asset allocation 72 Works under construction - current disclosure year 2,261 2,261 73 74 Highest rate of capitalised finance applied 1.30% 75

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 2.8. 76 4(v): Regulatory Depreciation 77 Unallocated RAB * RAB 78 ($000) ($000) ($000) ($000) 79 Depreciation - standard 4,839 4,839 80 Depreciation - no standard life assets 687 687 81 Depreciation - modified life assets 82 Depreciation - alternative depreciation in accordance with CPP 83 Total depreciation 5,526 5,526 84 85 4(vi): Disclosure of Changes to Depreciation Profiles ($000 unless otherwise specified) Closing RAB value Depreciation under 'nonstandard' under 'standard' Closing RAB value charge for the 86 Asset or assets with changes to depreciation* Reason for non-standard depreciation (text entry) period (RAB) depreciation depreciation 87 0 88 0 89 0 90 0 91 0 92 0 93 0 94 0 95 * include additional rows if needed 96 4(vii): Disclosure by Asset Category 97 ($000 unless otherwise specified) Distribution Subtransmission Subtransmission Distribution and LV Distribution and LV substations and Distribution Other network Non-network 98 lines cables Zone substations lines cables transformers switchgear assets assets Total 99 Total opening RAB value 5,177 646 7,402 25,741 28,193 22,538 12,397 7,540 3,649 113,283 100 less Total depreciation 223 24 291 1,187 1,091 731 568 704 707 5,526 101 plus Total revaluations 30 4 43 151 165 132 73 44 21 663 102 plus Assets commissioned 14 101 (469) 228 1,755 1,753 1,477 893 736 6,488 103 less Asset disposals 19 3 20 9 51 104 plus Lost and found assets adjustment 105 plus Adjustment resulting from asset allocation 106 plus Asset category transfers 107 Total closing RAB value 4,998 726 6,686 24,933 29,003 23,690 13,358 7,773 3,690 114,857 108 109 Asset Life 110 Weighted average remaining asset life 27.0 35.2 31.5 26.7 32.7 36.9 29.9 20.2 6.9 (years) 111 Weighted average expected total asset life 57.2 50.3 49.7 58.7 49.3 52.4 38.3 31.6 9.3 (years)

SCHEDULE 5a: REPORT ON REGULATORY TAX ALLOWANCE 7 5a(i): Regulatory Tax Allowance ($000) 8 Regulatory profit / (loss) before tax 8,053 9 10 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 4 * 12 Amortisation of initial differences in asset values 4,219 13 Amortisation of revaluations 433 14 4,656 15 16 less Total revaluations 663 17 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 2,450 21 3,113 22 23 Regulatory taxable income 9,595 24 25 less Utilised tax losses 26 Regulatory net taxable income 9,595 27 28 Corporate tax rate (%) 9% 29 Regulatory tax allowance 823 30 31 * Workings to be provided in Schedule 14 32 5a(ii): Disclosure of Permanent Differences 33 In Schedule 14, Box 5, provide descriptions and workings of items recorded in the asterisked categories in Schedule 5a(i). This schedule requires information on the calculation of the regulatory tax allowance. This information is used to calculate regulatory profit/loss in Schedule 3 (regulatory profit). EDBs must provide explanatory commentary on the information disclosed in this schedule, in Schedule 14 (Mandatory Explanatory Notes). This information is part of audited disclosure information (as defined in section 1.4 of the ID determination), and so is subject to the assurance report required by section 2.8. 34 5a(iii): Amortisation of Initial Difference in Asset Values ($000) 35 36 Opening unamortised initial differences in asset values 52,653 37 less Amortisation of initial differences in asset values 4,219 38 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 48,434 41 42 Opening weighted average remaining useful life of relevant assets (years) 12 43

SCHEDULE 5a: REPORT ON REGULATORY TAX ALLOWANCE 44 5a(iv): Amortisation of Revaluations ($000) 45 46 Opening sum of RAB values without revaluations 105,955 47 48 Adjusted depreciation 5,094 49 Total depreciation 5,526 50 Amortisation of revaluations 433 51 52 5a(v): Reconciliation of Tax Losses ($000) 53 54 Opening tax losses 55 plus Current period tax losses 56 less Utilised tax losses 57 Closing tax losses 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 2.8. 58 5a(vi): Calculation of Deferred Tax Balance ($000) 59 60 Opening deferred tax (4,663) 61 62 plus Tax effect of adjusted depreciation 475 63 64 less Tax effect of tax depreciation 434 65 66 plus Tax effect of other temporary differences* (67) 67 68 less Tax effect of amortisation of initial differences in asset values 394 69 70 plus Deferred tax balance relating to assets acquired in the disclosure year 71 72 less Deferred tax balance relating to assets disposed in the disclosure year 73 74 plus Deferred tax cost allocation adjustment 5,083 75 76 Closing deferred tax (0) 77 78 5a(vii): Disclosure of Temporary Differences 79 80 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 83 Opening sum of regulatory tax asset values 40,577 84 less Tax depreciation 4,652 85 plus Regulatory tax asset value of assets commissioned 6,411 86 less Regulatory tax asset value of asset disposals 39 87 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 42,296 ($000)

SCHEDULE 5b: REPORT ON RELATED PARTY TRANSACTIONS This schedule provides information on the valuation of related party transactions, in accordance with section 2.3.6 and 2.3.7 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 2.8. 7 5b(i): Summary Related Party Transactions ($000) 8 Total regulatory income 9 Operational expenditure 3,078 10 Capital expenditure 5,747 11 Market value of asset disposals 12 Other related party transactions (71) 13 5b(ii): Entities Involved in Related Party Transactions 14 Name of related party 15 Horizon Services Limited 16 Aquaheat New Zealand Limited 17 Eastern Bay Energy Trust 20 * include additional rows if needed 21 5b(iii): Related Party Transactions 100% Owned 100% Owned 100% Shareholder Related party relationship 22 Name of related party Related party transaction type Value of transaction ($000) Basis for determining value 23 Horizon Services Limited Capex Construction of Network Assets 5,747 IM clause 2.2.11(5)(g) 24 Horizon Services Limited Opex Maintenance of Network Assets 3,018 ID clause 2.3.6(1)(b) 25 Horizon Services Limited Opex Rental Expense 60 ID clause 2.3.6(1)(a) 29 Eastern Bay Energy Trust Capex Contribution towards Undergrounding Works (71) IM clause 2.2.11(5)(g) 38 * include additional rows if needed Description of transaction 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 2.8. Book value at date Cost of executing Original tenor (in Book value at issue of financial Term Credit Spread an interest rate Debt issue cost readjustment 10 Issuing party Issue date Pricing date years) Coupon rate (%) date (NZD) statements (NZD) Difference swap 11 12 13 14 15 16 * include additional rows if needed 17 18 5c(ii): Attribution of Term Credit Spread Differential 19 20 Gross term credit spread differential 21 22 Total book value of interest bearing debt 23 Leverage 44% 24 Average opening and closing RAB values 25 Attribution Rate (%) 26 27 Term credit spread differential allowance

SCHEDULE 5d: REPORT ON COST ALLOCATIONS 7 5d(i): Operating Cost Allocations 8 Value allocated ($000s) 9 Arm's length deduction 10 Service interruptions and emergencies 11 Directly attributable 789 Electricity Non-electricity distribution services distribution services Total OVABAA allocation increase ($000s) 12 Not directly attributable 13 Total attributable to regulated service 789 14 Vegetation management 15 Directly attributable 521 16 Not directly attributable 17 Total attributable to regulated service 521 18 Routine and corrective maintenance and inspection 19 Directly attributable 1,314 20 Not directly attributable 21 Total attributable to regulated service 1,314 22 Asset replacement and renewal 23 Directly attributable 916 24 Not directly attributable 25 Total attributable to regulated service 916 26 System operations and network support 27 Directly attributable 2,267 28 Not directly attributable 29 Total attributable to regulated service 2,267 30 Business support 31 Directly attributable 32 Not directly attributable 3,198 2,079 5,277 33 Total attributable to regulated service 3,198 34 35 Operating costs directly attributable 5,806 36 Operating costs not directly attributable 3,198 2,079 5,277 37 Operational expenditure 9,005 38 39 5d(ii): Other Cost Allocations 40 Pass through and recoverable costs ($000) 41 Pass through costs 42 Directly attributable 339 43 Not directly attributable 44 Total attributable to regulated service 339 45 Recoverable costs 46 Directly attributable 8,814 47 Not directly attributable 48 Total attributable to regulated service 8,814 49 50 5d(iii): Changes in Cost Allocations* 51 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 56 57 Rationale for change 58 59 60 61 Change in cost allocation 2 CY-1 Current Year (CY) 62 Cost category Original allocation 63 Original allocator or line items New allocation 64 New allocator or line items Difference 65 66 Rationale for change 67 68 69 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 74 75 Rationale for change 76 77 78 79 include additional rows if needed This schedule provides information on the allocation of operational costs. EDBs must provide explanatory comment on their cost allocation in Schedule 14 (Mandatory Explanatory Notes), including on the impact of any reclassifications. This information is part of audited disclosure information (as defined in section 1.4 of the ID determination), and so is subject to the assurance report required by section 2.8. * 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. ($000) ($000) ($000)

SCHEDULE 5e: REPORT ON ASSET ALLOCATIONS 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 2.8. 7 5e(i): Regulated Service Asset Values 8 Value allocated ($000s) Electricity distribution 9 services 10 Subtransmission lines 11 Directly attributable 4,998 12 Not directly attributable 13 Total attributable to regulated service 4,998 14 Subtransmission cables 15 Directly attributable 726 16 Not directly attributable 17 Total attributable to regulated service 726 18 Zone substations 19 Directly attributable 6,686 20 Not directly attributable 21 Total attributable to regulated service 6,686 22 Distribution and LV lines 23 Directly attributable 24,933 24 Not directly attributable 25 Total attributable to regulated service 24,933 26 Distribution and LV cables 27 Directly attributable 29,003 28 Not directly attributable 29 Total attributable to regulated service 29,003 30 Distribution substations and transformers 31 Directly attributable 23,690 32 Not directly attributable 33 Total attributable to regulated service 23,690 34 Distribution switchgear 35 Directly attributable 13,358 36 Not directly attributable 37 Total attributable to regulated service 13,358 38 Other network assets 39 Directly attributable 7,773 40 Not directly attributable 41 Total attributable to regulated service 7,773 42 Non-network assets 43 Directly attributable 44 Not directly attributable 3,690 45 Total attributable to regulated service 3,690 46 47 Regulated service asset value directly attributable 111,166 48 Regulated service asset value not directly attributable 3,690 49 Total closing RAB value 114,857 50 51 5e(ii): Changes in Asset Allocations* 52 53 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 57 58 Rationale for change 59 60 61 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 66 67 Rationale for change 68 69 70 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 75 76 Rationale for change 77 78 79 * 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. 80 include additional rows if needed ($000) ($000) ($000)

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 2.8. 7 6a(i): Expenditure on Assets ($000) ($000) 8 Consumer connection 144 9 System growth 234 10 Asset replacement and renewal 5,594 11 Asset relocations 12 Reliability, safety and environment: 13 Quality of supply 427 14 Legislative and regulatory 108 15 Other reliability, safety and environment 313 16 Total reliability, safety and environment 848 17 Expenditure on network assets 6,820 18 Expenditure on non-network assets 508 19 20 Expenditure on assets 7,328 21 plus Cost of financing 78 22 less Value of capital contributions 270 23 plus Value of vested assets 24 25 Capital expenditure 7,136 26 6a(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 618 29 Research and development 30 6a(iii): Consumer Connection 31 Consumer types defined by EDB* ($000) ($000) 32 130 - Customer Connection - NC1 assets created 144 33 34 35 36 37 * include additional rows if needed 38 Consumer connection expenditure 144 39 40 less Capital contributions funding consumer connection expenditure 2 41 Consumer connection less capital contributions 143 42 6a(iv): System Growth and Asset Replacement and Renewal 43 44 ($000) ($000) 45 Subtransmission 46 Zone substations 79 1,049 47 Distribution and LV lines 4 207 48 Distribution and LV cables 10 1,454 49 Distribution substations and transformers 93 1,224 50 Distribution switchgear 46 1,063 51 Other network assets 2 598 52 System growth and asset replacement and renewal expenditure 234 5,594 53 less Capital contributions funding system growth and asset replacement and renewal 234 54 System growth and asset replacement and renewal less capital contributions 234 5,361 55 56 6a(v): Asset Relocations 57 Project or programme* ($000) ($000) 58 59 60 61 62 63 * include additional rows if needed 64 All other projects or programmes - asset relocations 65 Asset relocations expenditure 66 less Capital contributions funding asset relocations 67 Asset relocations less capital contributions 68 System Growth Asset Replacement and Renewal

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 2.8. 69 6a(vi): Quality of Supply 70 Project or programme* ($000) ($000) 71 72 73 74 75 76 * include additional rows if needed 77 All other projects programmes - quality of supply 427 78 Quality of supply expenditure 427 79 less Capital contributions funding quality of supply 80 Quality of supply less capital contributions 427 81 6a(vii): Legislative and Regulatory 82 Project or programme* ($000) ($000) 83 84 85 86 87 88 * include additional rows if needed 89 All other projects or programmes - legislative and regulatory 108 90 Legislative and regulatory expenditure 108 91 less Capital contributions funding legislative and regulatory 92 Legislative and regulatory less capital contributions 108 93 6a(viii): Other Reliability, Safety and Environment 94 Project or programme* ($000) ($000) 95 96 97 98 99 100 * include additional rows if needed 101 All other projects or programmes - other reliability, safety and environment 313 102 Other reliability, safety and environment expenditure 313 103 less Capital contributions funding other reliability, safety and environment 35 104 Other reliability, safety and environment less capital contributions 278 105 106 6a(ix): Non-Network Assets 107 Routine expenditure 108 Project or programme* ($000) ($000) 109 Plant & Equipment 6 110 Vehicles 56 111 Intangible - Software 246 112 Other Information Technology 200 113 114 * include additional rows if needed 115 All other projects or programmes - routine expenditure 116 Routine expenditure 508 117 Atypical expenditure 118 Project or programme* ($000) ($000) 119 120 121 122 123 124 * include additional rows if needed 125 All other projects or programmes - atypical expenditure 126 Atypical expenditure 127 128 Expenditure on non-network assets 508

SCHEDULE 6b: REPORT ON OPERATIONAL EXPENDITURE FOR THE DISCLOSURE YEAR orizon Energy Distribution Limite 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 2.8. 7 6b(i): Operational Expenditure ($000) ($000) 8 Service interruptions and emergencies 789 9 Vegetation management 521 10 Routine and corrective maintenance and inspection 1,314 11 Asset replacement and renewal 916 12 Network opex 3,540 13 System operations and network support 2,267 14 Business support 3,198 15 Non-network opex 5,465 16 17 Operational expenditure 9,005 18 6b(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 23 * Direct billing expenditure by suppliers that directly bill the majority of their consumers

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 30,597 30,675 0% 9 7(ii): Expenditure on Assets Forecast ($000) ² Actual ($000) % variance 10 Consumer connection 365 144 (60%) 11 System growth 919 234 (75%) 12 Asset replacement and renewal 5,253 5,594 6% 13 Asset relocations 36 (100%) 14 Reliability, safety and environment: 15 Quality of supply 702 427 (39%) 16 Legislative and regulatory 227 108 (52%) 17 Other reliability, safety and environment 1,304 313 (76%) 18 Total reliability, safety and environment 2,234 848 (62%) 19 Expenditure on network assets 8,808 6,820 (23%) 20 Expenditure on non-network assets 484 508 5% 21 Expenditure on assets 9,291 7,328 (21%) 22 7(iii): Operational Expenditure 23 Service interruptions and emergencies 836 789 (6%) 24 Vegetation management 608 521 (14%) 25 Routine and corrective maintenance and inspection 770 1,314 71% 26 Asset replacement and renewal 664 916 38% 27 Network opex 2,878 3,540 23% 28 System operations and network support 2,404 2,267 (6%) 29 Business support 3,177 3,198 1% 30 Non-network opex 5,581 5,465 (2%) 31 Operational expenditure 8,459 9,005 6% 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 618 35 Research and development 36 37 7(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 42 43 1 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 2.6.6 for the forecast period starting at the beginning of the disclosure year (the second to last disclosure of Schedules 11a and 11b)

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 9 10 11 Billed quantities by price component Price component Fixed Fixed Fixed Fixed Fixed Fixed Variable 12 13 14 Consumer group name or price category code Consumer type or types (eg, residential, commercial etc.) Standard or non-standard consumer group (specify) Average no. of ICPs in disclosure year Energy delivered to ICPs in disclosure year (MWh) Days kva/day kva/month kw/month Light/Month Month kwh 15 (N1R) General Rural N1 Group Capacity Standard 916 3,279 335,267 3,279,085 (N1U) General Urban N1 Group Capacity Standard 621 3,639 227,372 3,638,529 (N2R) General Rural N2 Group Capacity Standard 1,707 24,898 624,776 24,897,665 (N2U) General Urban N2 Group Capacity Standard 802 13,174 293,620 13,174,241 (N3R) General Rural N3 Group Capacity Standard 323 15,266 118,340 15,265,983 (N3U) General Urban N3 Group Capacity Standard 266 10,378 97,422 10,378,469 (N4R) General Rural N4 Group Capacity Standard 36 2,151 13,272 2,151,355 (N4U) General Urban N4 Group Capacity Standard 45 2,462 16,365 2,462,211 (N5R) General Rural N5 Group Capacity Standard 26 1,261 1,694,094 1,261,296 (N5U) General Urban N5 Group Capacity Standard 30 2,343 1,860,546 2,342,652 (LUDR) Domestic LFC Rural Domestic Standard 3,696 19,564 1,352,736 19,563,517 (LUDU) (NSDR) Non Domestic Standard LFC Urban Domestic Domestic Standard 7,763 39,332 2,841,224 39,331,758 Rural (NSDU) Non Standard Domestic Domestic Standard 413 1,087 151,235 1,087,090 Urban Domestic Standard 273 954 99,930 953,985 16 (SDR) Domestic Standard Rural Domestic Standard 3,245 27,851 1,187,574 27,851,382 17 (SDU) Domestic Standard Urban Domestic Standard 4,354 33,454 1,593,659 33,454,388 18 (NMD) Network Maximum Demand Network Maximum Demand Standard 148 48,154 454,590 272,076 48,153,680 19 (EF) Electric Fence Special Standard 15 5,483 20 (PCM24) Telecom 24 hour Special Standard 85 1,017 21 (PCMN) Telecom Night Special Standard 7 78 22 (SL) Streetlight Special Standard 21 2,203 4,690 2,202,760 23 (UV) Underveranda Lighting Special Standard 14 5,124 24 Majors Industrial Non-standard 12 275,711 144 275,711,010 25 Add extra rows for additional consumer groups or price category codes as necessary 26 Standard consumer totals 24,806 251,450 8,963,399 3,554,640 454,590 272,076 4,690 1,095 251,450,046 27 Non-standard consumer totals 12 275,711 144 275,711,010 28 Total for all consumers 24,818 527,161 8,963,399 3,554,640 454,590 272,076 4,690 1,239 527,161,056 29 30 Unit charging basis (eg, days, kw of demand, kva of capacity, etc.) Add extra columns for additional billed quantities by price component as necessary

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 32 33 Line charge revenues ($000) by price component 34 35 36 Consumer group name or price category code Consumer type or types (eg, residential, commercial etc.) Standard or non-standard consumer group (specify) Total line charge revenue in disclosure year Notional revenue foregone from posted discounts (if applicable) Total distribution line charge revenue Price component Fixed Fixed Fixed Fixed Fixed Fixed Variable Rate (eg, $ per day, $ per kwh, etc.) Days kva/day kva/month kw/month Light/Month Month kwh 37 (N1R) General Rural N1 Group Capacity Standard $695 $555 $139 $611 $84 (N1U) General Urban N1 Group Capacity Standard $508 $414 $95 $414 $94 (N2R) General Rural N2 Group Capacity Standard $3,505 $2,791 $714 $1,894 $1,611 (N2U) General Urban N2 Group Capacity Standard $1,088 $753 $336 $597 $492 (N3R) General Rural N3 Group Capacity Standard $1,536 $1,216 $320 $733 $803 (N3U) General Urban N3 Group Capacity Standard $826 $562 $264 $399 $427 (N4R) General Rural N4 Group Capacity Standard $241 $172 $69 $132 $109 (N4U) General Urban N4 Group Capacity Standard $277 $191 $85 $148 $129 (N5R) General Rural N5 Group Capacity Standard $252 $180 $71 $148 $104 (N5U) General Urban N5 Group Capacity Standard $265 $187 $78 $149 $116 (LUDR) Domestic LFC Rural Domestic Standard $2,162 $1,681 $481 $203 $1,959 (LUDU) (NSDR) Non Domestic Standard LFC Urban Domestic Domestic Standard $4,367 $3,382 $985 $426 $3,941 Rural (NSDU) Non Standard Domestic Domestic Standard $303 $240 $63 $276 $28 Urban Domestic Standard $206 $165 $42 $182 $24 38 (SDR) Domestic Standard Rural Domestic Standard $2,829 $2,233 $596 $2,043 $786 39 (SDU) Domestic Standard Urban Domestic Standard $3,685 $2,885 $800 $2,741 $943 40 (NMD) Network Maximum Demand Network Maximum Demand Standard $3,491 $2,533 $958 $864 $1,547 $1,079 41 (EF) Electric Fence Special Standard $4 $4 $0 $4 42 (PCM24) Telecom 24 hour Special Standard $56 $47 $10 $56 43 (PCMN) Telecom Night Special Standard $2 $2 $0 $2 44 (SL) Streetlight Special Standard $302 $260 $42 $302 45 (UV) Underveranda Lighting Special Standard $4 $3 $0 $4 46 Majors Industrial Non-standard $4,073 $1,009 $3,063 $4,073 47 Add extra rows for additional consumer groups or price category codes as necessary 48 Standard consumer totals $26,602 $20,455 $6,147 $10,806 $297 $864 $1,547 $302 $59 $12,727 49 Non-standard consumer totals $4,073 $1,009 $3,063 $4,073 50 Total for all consumers $30,675 $21,464 $9,211 $10,806 $297 $864 $1,547 $302 $4,131 $12,727 51 52 8(iii): Number of ICPs directly billed Check OK 53 Number of directly billed ICPs at year end 8 Total transmission line charge revenue (if available) Add extra columns for additional line charge revenues by price component as necessary

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. 8 Voltage Asset category Asset class Units Items at start of year (quantity) Items at end of year (quantity) Net change Data accuracy (1 4) 9 All Overhead Line Concrete poles / steel structure No. 18,307 18,318 11 2 10 All Overhead Line Wood poles No. 1,946 1,929 (17) 2 11 All Overhead Line Other pole types No. 46 74 28 2 12 HV Subtransmission Line Subtransmission OH up to 66kV conductor km 179 178 (1) 1 13 HV Subtransmission Line Subtransmission OH 110kV+ conductor km N/A 14 HV Subtransmission Cable Subtransmission UG up to 66kV (XLPE) km 4 4 1 4 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 N/A 18 HV Subtransmission Cable Subtransmission UG 110kV+ (XLPE) km N/A 19 HV Subtransmission Cable Subtransmission UG 110kV+ (Oil pressurised) km N/A 20 HV Subtransmission Cable Subtransmission UG 110kV+ (Gas Pressurised) km N/A 21 HV Subtransmission Cable Subtransmission UG 110kV+ (PILC) km N/A 22 HV Subtransmission Cable Subtransmission submarine cable km N/A 23 HV Zone substation Buildings Zone substations up to 66kV No. 10 10 3 24 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. 4 28 HV Zone substation switchgear 33kV Switch (Pole Mounted) No. 20 21 1 1 29 HV Zone substation switchgear 33kV RMU No. N/A 30 HV Zone substation switchgear 22/33kV CB (Indoor) No. 10 10 2 31 HV Zone substation switchgear 22/33kV CB (Outdoor) No. 9 9 2 32 HV Zone substation switchgear 3.3/6.6/11/22kV CB (ground mounted) No. 54 54 4 33 HV Zone substation switchgear 3.3/6.6/11/22kV CB (pole mounted) No. 6 6 4 34 HV Zone Substation Transformer Zone Substation Transformers No. 15 15 4 35 HV Distribution Line Distribution OH Open Wire Conductor km 1,447 1,446 (2) 3 36 HV Distribution Line Distribution OH Aerial Cable Conductor km N/A 37 HV Distribution Line SWER conductor km 63 63 (0) 3 38 HV Distribution Cable Distribution UG XLPE or PVC km 161 163 2 2 39 HV Distribution Cable Distribution UG PILC km 34 34 0 2 40 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. 102 103 1 3 42 HV Distribution switchgear 3.3/6.6/11/22kV CB (Indoor) No. N/A 43 HV Distribution switchgear 3.3/6.6/11/22kV Switches and fuses (pole mounted) No. 4,157 4,129 (28) 1 44 HV Distribution switchgear 3.3/6.6/11/22kV Switch (ground mounted) - except RMU No. N/A 45 HV Distribution switchgear 3.3/6.6/11/22kV RMU No. 229 240 11 3 46 HV Distribution Transformer Pole Mounted Transformer No. 2,488 2,491 3 3 47 HV Distribution Transformer Ground Mounted Transformer No. 736 750 14 2 48 HV Distribution Transformer Voltage regulators No. 1 1 4 49 HV Distribution Substations Ground Mounted Substation Housing No. 754 765 11 2 50 LV LV Line LV OH Conductor km 265 277 12 2 51 LV LV Cable LV UG Cable km 342 348 6 2 52 LV LV Street lighting LV OH/UG Streetlight circuit km 233 236 3 2 53 LV Connections OH/UG consumer service connections No. 24,820 24,848 28 3 54 All Protection Protection relays (electromechanical, solid state and numeric) No. 99 105 6 3 55 All SCADA and communications SCADA and communications equipment operating as a single system Lot 1 1 4 56 All Capacitor Banks Capacitors including controls No 1 2 1 4 57 All Load Control Centralised plant Lot 4 4 4 58 All Load Control Relays No N/A 59 All Civils Cable Tunnels km N/A

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 Items at No. with 1940 1950 1960 1970 1980 1990 age end of year default Data accuracy 9 Voltage Asset category Asset class Units pre-1940 1949 1959 1969 1979 1989 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 unknown (quantity) dates (1 4) 10 All Overhead Line Concrete poles / steel structure No. 39 705 2,937 5,444 2,899 873 289 121 106 77 92 94 113 81 101 78 83 47 44 113 93 117 139 3,633 18,318 2 11 All Overhead Line Wood poles No. 5 68 93 58 156 101 19 21 22 4 13 15 19 12 15 30 17 46 14 21 31 15 14 1,120 1,929 2 12 All Overhead Line Other pole types No. 6 1 9 4 3 1 50 74 2 13 HV Subtransmission Line Subtransmission OH up to 66kV conductor km 31 35 87 21 0 2 0 1 0 0 1 178 1 14 HV Subtransmission Line Subtransmission OH 110kV+ conductor km N/A 15 HV Subtransmission Cable Subtransmission UG up to 66kV (XLPE) km 0 3 0 1 0 1 4 4 16 HV Subtransmission Cable Subtransmission UG up to 66kV (Oil pressurised) km N/A 17 HV Subtransmission Cable Subtransmission UG up to 66kV (Gas pressurised) km N/A 18 HV Subtransmission Cable Subtransmission UG up to 66kV (PILC) km N/A 19 HV Subtransmission Cable Subtransmission UG 110kV+ (XLPE) km N/A 20 HV Subtransmission Cable Subtransmission UG 110kV+ (Oil pressurised) km N/A 21 HV Subtransmission Cable Subtransmission UG 110kV+ (Gas Pressurised) km N/A 22 HV Subtransmission Cable Subtransmission UG 110kV+ (PILC) km N/A 23 HV Subtransmission Cable Subtransmission submarine cable km N/A 24 HV Zone substation Buildings Zone substations up to 66kV No. 1 2 2 2 1 2 10 3 25 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. 4 29 HV Zone substation switchgear 33kV Switch (Pole Mounted) No. 1 2 2 16 21 1 30 HV Zone substation switchgear 33kV RMU No. N/A 31 HV Zone substation switchgear 22/33kV CB (Indoor) No. 6 4 10 1 32 HV Zone substation switchgear 22/33kV CB (Outdoor) No. 1 1 7 9 1 33 HV Zone substation switchgear 3.3/6.6/11/22kV CB (ground mounted) No. 1 13 1 1 8 30 54 4 34 HV Zone substation switchgear 3.3/6.6/11/22kV CB (pole mounted) No. 3 1 2 6 4 35 HV Zone Substation Transformer Zone Substation Transformers No. 8 3 1 1 2 15 4 36 HV Distribution Line Distribution OH Open Wire Conductor km 1 8 48 241 285 401 266 14 23 19 7 16 10 14 10 14 7 8 10 0 10 4 3 8 18 1,446 3 37 HV Distribution Line Distribution OH Aerial Cable Conductor km N/A 38 HV Distribution Line SWER conductor km 41 3 5 4 1 5 3 1 63 3 39 HV Distribution Cable Distribution UG XLPE or PVC km 0 0 0 2 10 39 26 3 5 2 2 4 4 5 6 5 8 4 4 5 9 7 6 3 2 163 2 40 HV Distribution Cable Distribution UG PILC km 3 8 19 1 1 0 0 0 0 0 0 0 1 0 0 0 1 34 2 41 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. 5 1 2 18 34 16 4 14 2 7 103 3 43 HV Distribution switchgear 3.3/6.6/11/22kV CB (Indoor) No. N/A 44 HV Distribution switchgear 3.3/6.6/11/22kV Switches and fuses (pole mounted) No. 2 2 7 41 112 157 76 9 8 8 4 7 5 9 3 8 18 28 54 76 96 76 131 132 3,060 4,129 1 45 HV Distribution switchgear 3.3/6.6/11/22kV Switch (ground mounted) - except RMU No. N/A 46 HV Distribution switchgear 3.3/6.6/11/22kV RMU No. 2 2 9 19 26 6 9 6 5 9 4 12 4 7 13 7 5 5 22 15 26 21 6 240 3 47 HV Distribution Transformer Pole Mounted Transformer No. 22 6 94 269 428 484 341 43 54 85 51 56 33 80 46 11 5 2 32 44 67 108 58 72 2,491 3 48 HV Distribution Transformer Ground Mounted Transformer No. 8 2 7 53 111 174 43 10 18 15 13 20 29 35 12 3 5 1 5 7 24 23 30 33 69 750 2 49 HV Distribution Transformer Voltage regulators No. 1 1 4 50 HV Distribution Substations Ground Mounted Substation Housing No. 1 1 30 66 225 184 9 16 12 8 19 12 21 12 17 12 10 9 13 17 14 21 26 10 765 2 51 LV LV Line LV OH Conductor km 1 7 43 20 87 43 2 1 1 2 2 0 0 0 1 2 0 1 0 1 1 61 277 2 52 LV LV Cable LV UG Cable km 0 24 55 27 109 36 5 3 5 5 13 6 6 5 4 3 2 2 3 4 5 2 23 348 2 53 LV LV Street lighting LV OH/UG Streetlight circuit km 15 45 24 80 21 3 3 4 3 10 2 5 1 2 1 0 1 2 2 2 1 8 236 2 54 LV Connections OH/UG consumer service connections No. 1 8 37 2,167 4,449 6,578 7,344 621 294 232 279 315 337 334 271 348 237 181 145 132 113 130 114 137 44 24,848 3 55 All Protection Protection relays (electromechanical, solid state and numeric) No. 7 5 2 2 2 16 45 23 3 105 3 56 All SCADA and communications SCADA and communications equipment operating as a single system Lot 1 1 4 57 All Capacitor Banks Capacitors including controls No 1 1 2 4 58 All Load Control Centralised plant Lot 1 2 1 4 4 59 All Load Control Relays No N/A 60 All Civils Cable Tunnels km N/A