Financial Results Year ended 30 June 2016 FRASER WHINERAY Chief Executive 23 August 2016 WILLIAM MEEK Chief Financial Officer DISCLAIMER The information in this presentation has been prepared by Mercury NZ Limited (formerly known as Mighty River Power Limited) with due care and attention. However, neither the company nor any of its directors, employees, shareholders nor any other person shall have any liability whatsoever to any person for any loss (including, without limitation, arising from any fault or negligence) arising from this presentation or any information supplied in connection with it. This presentation may contain projections or forward-looking statements regarding a variety of items. Such projections or forwardlooking statements are based on current expectations, estimates and assumptions and are subject to a number of risks, uncertainties and assumptions. There is no assurance that results contemplated in any projections and forward-looking statements in this presentation will be realised. Actual results may differ materially from those projected in this presentation. No person is under any obligation to update this presentation at any time after its release to you or to provide you with further information about Mercury NZ Limited. A number of non-GAAP financial measures are used in this presentation, which are outlined in the appendix of the presentation. You should not consider any of these in isolation from, or as a substitute for, the information provided in the audited consolidated financial statements for the twelve months ended 30 June 2016, which are available at www.mercury.co.nz. Forward-looking statements are subject to any material adverse events, significant one-off expenses or other unforeseeable circumstances including hydrological conditions. The information in this presentation is of a general nature and does not constitute financial product advice, investment advice or any recommendation. Nothing in this presentation constitutes legal, financial, tax or other advice. 2 FINANCIAL RESULTS AGENDA Business & Strategy 4–8 FY2016 Highlights 9 – 14 Market Dynamics 15 – 22 Operational Summary 23 – 27 Financial Summary 28 – 35 Appendix 36 – 45 3 FINANCIAL RESULTS 4 BUSINESS STRATEGY ONE BRAND > On 29 July the company came together under one brand, Mercury > The change is another significant strategic step forward for the company, allowing all of our energy and focus to be behind a single brand for the first time > Mercury brings together the company‟s near centurylong heritage with our customer-driven innovation > The new Mercury brand will allow us to focus on what matters most; inspiring and rewarding our customers and owners The Mercury bee > Symbolises all the wonderful things we want to be and do for New Zealanders > Bees are the ultimate symbol of life-giving energy. They are optimistic, energetic and are quietly busy making the world a better place > Like our bee, renewable energy is natural and essential to the planet, promoting well-being and real sustainability for future generations 5 BUSINESS & STRATEGY Auckland, New Zealand 29 July 2016 OUR GOAL OUR PURPOSE To be New Zealand’s leading energy brand Inspiring New Zealanders to enjoy energy in more wonderful ways OUR STRATEGY Inspiring New Zealanders We want to inspire New Zealanders by delivering value, innovation and outstanding experiences Mercury will create long term value for our owners by: 1 2 3 Delivering customer advocacy Leveraging core strengths Delivering sustainable growth Outstanding customer experience Operational efficiency Executing relevant strategic opportunities Leading digital offerings Astute portfolio management Being ready for domestic growth Culture-driven innovation Efficient capital allocation Embracing emerging technologies To enjoy energy We want our customers to enjoy what energy does for them and choose Mercury because we make a positive difference in their lives In more wonderful ways We will bring new technology and ideas to create wonderful experiences for our customers in a uniquely New Zealand context 6 BUSINESS & STRATEGY NEW ZEALAND’S COMPETITIVE ADVANTAGE IN ELECTRICITY RENEWABILITY 4th NZ highest level of renewable electricity generation in OECD COMPETITIVENESS ‘Among the most competitive markets in the world’ RELIABILITY NZ ranks 3rd lowest out of 25 large energy-consuming countries for energy security risk Source: Accenture, Ministry of Business, Innovation & Employment, United States Chamber of Commerce 7 BUSINESS & STRATEGY MERCURY’S COMPETITIVE ADVANTAGE 100% renewable generation with two low-cost complementary fuel sources in base-load geothermal and peaking hydro North Island generation is uniquely located close to major load centres and not dependent on HVDC Waikato Hydro System is the largest series of peaking stations in the North Island 8 BUSINESS & STRATEGY Rain-fed North Island hydro catchment with inflows correlated with winter peak demand (unlike South Island) Building a track record of customerled innovation and rewarding loyalty Long-term commercial partnerships with Maori landowners and strong relationships with iwi and other key stakeholders 9 FY2016 HIGHLIGHTS HIGHLIGHTS Coming together under one brand, MERCURY EBITDAF $11m Bringing together our heritage and our customer-driven innovation to $493m, reflecting increased generation though lower wholesale market volatility and commercial pricing BETTER SUPPLY & DEMAND BALANCE MOVED TO 100% RENEWABLE GENERATION not currently translating to more volatile wholesale prices due to above average inflows and short term fuel management with complementary base-load geothermal and peaking hydro generation, as well as in-house solar capability 10 FY2016 HIGHLIGHTS ACTIVE CAPITAL MANAGEMENT Fully-imputed ordinary dividend of 14.3cps and a non-imputed special dividend of 4.0cps declared FY2017 EBITDAF guidance of $490M FY2017 normal dividend guidance 2% to 14.6CPS DELIVERABLES & OUTCOMES DELIVERABLES INDUSTRY OUTCOMES • • • • • • • • • • • No high severity incidents Single new Mercury brand Successful transition of information systems to new brand Leadership changes to deliver greater product and service innovation to customers Continued customer product innovation using smart meters e.g. „Free Power Days‟ In house solar installation capability with acquisition of solar business Nga Awa Purua turbine replaced Closure of Southdown gas-fired power station Site works completed as part of Chile geothermal exit Continued focus on capital management with a 4.0cps special dividend declared 11 FY2016 HIGHLIGHTS • • • “Most likely outcome for NZAS is to contract for 572MW” 18-May-2015 “Market will resolve emerging security of supply concerns post 2019” 21-Oct-2015 “Positive signs for continued demand growth” 21-Oct-2015 “Wholesale price volatility likely to increase due to recent reductions in contracted fuel supply and plant closures” 23-Feb-16 HEALTH & SAFETY > Zero harm is our goal > FY2016 demonstrates continued improvement in achieving our goal > no high severity incidents involving employees, contractors or visitors on Mercury controlled sites > reduction of lost time (moderate severity) incidents from 5 to 3 > continued high engagement survey rating reflecting commitment to the health and safety of Mercury‟s people > Continuous process development > Bow-tie methodology used to map process safety risks beyond regulatory requirements > mobile app used across the company for reporting of health and safety incidents > new online learning management system launched > Collaboration to improve industry-wide safety with initiatives such as StayLive 12 FY2016 HIGHLIGHTS TOTAL RECORDABLE INJURY FREQUENCY RATE (TRIFR) (per 200,000 hours; includes onsite employees and contractors) 2.0 Low Severity Incidents 1.8 Moderate Severity Incidents 1.6 High Severity Incidents 1.4 1.2 1.0 0.8 0.6 0.4 0.2 0.0 2012 2013 2014 Financial Year 2015 2016 FY2016 vs. FY2015 700 FY2015 600 FY2016 $m 500 400 300 200 100 0 Energy Margin EBITDAF NPAT Underlying Earnings Free Cash Flow Capital Expenditure Total Declared Ordinary Dividend > Energy Margin, EBITDAF and Underlying Earnings up reflecting higher generation partially offset by lower relative generation prices (GWAP) and the continued roll-off of higher priced commercial contracts put in place through FY2013 > Net Profit up reflecting lower non-cash impairments relating to the decision to exit international geothermal development and the decommissioning of Southdown in the prior period > Free cash flow down reflecting a short-term prepayment of tax offset by lower stay-in-business capital expenditure 13 FY2016 HIGHLIGHTS DIVIDENDS > Focus remains on appropriate capital management DIVIDEND > Fully imputed ordinary final dividend of 8.6cps > Non-imputed special dividend of 4.0cps > Increasing total distributions to 100% of Free Cash Flow; and > Distributing proceeds from land sales within FY2015 and FY2016 > FY2017 ordinary dividend guidance is an increase of 2% to 14.6cps, the sixth year of consecutive ordinary dividend growth Final Specials 20 15 10 5 0 2012 2013 2014 2015 Financial Year 14 FY2016 HIGHLIGHTS Ordinary guidance 25 Cents per share > Ordinary dividend for FY2016 up 2% to 14.3cps, in line with guidance > Full year ordinary dividend consistent with Dividend Policy to pay out 70-85% of normalised Free Cash Flow on average through time Interim 2016 2017F 15 MARKET DYNAMICS INTERPRETING MARKET DYNAMICS DYNAMIC: DEMAND GROWTH AND THERMAL RATIONALISATION FUNDAMENTALS: SUPPLY AND DEMAND BETTER BALANCED EXPECTED MARKET RESPONSE OBSERVED MARKET RESPONSE      Futures pricing flat  Customer churn remains at high levels  Growing number of new entrant retailers Increased wholesale price volatility Futures price increase Commercial and Industrial (C&I) pricing increase Retail margin reduction in the absence of energy price increases MITIGATING FACTORS  Benign wholesale prices due to generally above average inflows into South Island catchments and short-term management of thermal fuel positions  NZAS closure uncertainty 16 MARKET DYNAMICS DEMAND > Highest demand on record and increases over the past two financial years relative to pcp DEMAND 14,000 > up 0.3% in FY2016, 0.6% after normalising for temperature FY2013 > Despite normalised demand in Q4 FY2016 being flat relative to pcp, the fundamentals underpinning demand growth remain positive FY2016 DEMAND GROWTH BY SECTOR1 Sector GWh % Urban* +130 0.8% Rural* +98 1.5% Dairy processing +57 0.9% Irrigation +1 0.1% Industrial -44 -0.5% 12,000 FY2014 FY2015 10,000 GWh > High net migration and growth in GDP per capita FY2012 FY2016 8,000 6,000 4,000 2,000 0 (Industrial includes Pacific Steel mill closure in 1HY2016) 17 MARKET DYNAMICS Urban* Rural* Dairy Tiwai Industrial (excluding Tiwai) * normalised for temperature 1 Sector allocations revised in August 2016 Irrigation SUPPLY > Rationalisation of thermal capacity within FY2016 has resulted in supply and demand being better balanced > Short term supply drivers have limited how this has translated through to wholesale prices > 75th percentile South Island inflows for FY2016 (1,400GWh above average) > Genesis‟ coal stockpile has reduced to 408kT (circa 840GWh) as at 30 June 2016 relative to 721kT 12 months earlier NZ ENERGY MARGIN NZ Energy Margin 25% MONTHLY HYDRO STORAGE AND PRICE Margin - Likely Generation Development Margin - 2 Huntly Rankine Units Margin 20% 15% Security Standard 10% 5% 0% 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 Calendar Year OTA Wholesale Price ($/MWh) 30% $300 FY2008 FY2015 $250 FY2016 $200 $150 $100 $50 $0 -1500 -1000 -500 0 500 1000 Delta to Average National Storage (GWh) Source: Transpower, Mercury 18 MARKET DYNAMICS 1500 CUSTOMER > Industry retail energy prices fell through FY2016, reflecting strong competition > MBIE „Residential sales-based electricity cost‟ reduced (-2.5% energy and -0.4% lines) for 12 months to 31 March 20161 > Churn remains high relative to international benchmarks > Major centres (such as Auckland) observing slightly higher churn due to customer density > Historic incumbencies (such as Mercury in Auckland) showing churn advantage > Churn rates of niche brands (such as Globug and Bosco) higher reflecting behaviours of customer bases NATIONAL CHURN AUCKLAND CHURN All Retailers (excl. Mercury) Mercury (excl. Globug and Bosco)* Mercury* 30% 30% 25% Total switches } Trader switches2 Jan-16 Jul-15 Jan-15 Jul-14 Jul-11 Jan-16 Jul-15 Jan-15 Jul-14 Jan-14 Jul-13 0% Jan-13 0% Jul-12 5% Jan-12 5% Jan-14 10% Jul-13 10% } 15% Jan-13 15% 20% Jul-12 20% Jan-12 Annual Churn 25% Jul-11 Annual Churn All Retailers (excl. Mercury) Mercury (excl. Globug and Bosco) Mercury *Step up in Mercury trader churn from May 2015 partially related to consolidation of niche brands (i.e. switching between Mercury brands) 19 MARKET DYNAMICS Source: Electricity Authority 1 Sales-based costs are after discount costs which reflect actual uptake of prompt payment discounts, dual fuel discounts, and incentive discounts for attracting or retaining a customer 2 A trader switch is where a customer changes retailer without changing house CUSTOMER 65% 60% 55% 50% 45% *Based on Mercury‟s monthly survey 20 MARKET DYNAMICS Jun-16 Apr-16 May-16 Mar-16 Jan-16 Feb-16 Dec-15 Oct-15 Nov-15 Sep-15 Jul-15 Aug-15 Jun-15 Apr-15 May-15 Mar-15 Jan-15 Feb-15 Dec-14 40% Oct-14 > The acquisition of in-house solar capability through the purchase of What Power Crisis (WPC) adds to innovative customer solutions available – GLOBUG, Good Energy Monitor (GEM) and fixed-price contracts > Enabling customers to utilise electricity as a transport fuel – EV fuel package and customer discounts for e-bikes Mercury Largest 4 Brands (excl. Mercury) 70% Nov-14 > On-going focus on increasing depth of customer relationships through innovative propositions Rolling 3 months Sep-14 > Free Power Day – a loyalty product which helps customers appreciate the value of electricity > Airpoints – Mercury has partnered with Air New Zealand to enable customers to earn Airpoints dollars from later this year > 42% of Mercury residential customers on fixed-price contracts with customers taking up a two-year offer in preference to an energy price increase in 2016 > Through FY2016 61% of Mercury customers responded as highly satisfied in the Company‟s regular survey – the highest of the five large retailers CUSTOMERS HIGHLY SATISFIED* Percentage of Customers > Rewarding loyalty leading to increased customer satisfaction NEW ZEALAND’S ALUMINIUM SMELTER (NZAS) > Mercury best placed in the event of NZAS closure > 100% renewable North Island generation with flexible hydro capacity which is a primary provider of reserves to the market > Thermal rationalisation in the North Island likely when NZAS closes > Industry has demonstrated ability to quickly respond to changes in supply and demand > Second order material impacts of closure due to HVDC capability include: (1) price separation between North and South Islands, (2) South Island hydro dispatch and spill, (3) beneficiaries of HVDC under proposed TPM HVDC TRANSFER HAY - BEN price difference (RHS) North Transfer North Transfer without NZAS FY2016 maximum daily transfer and associated locational price differences 1600 1400 $140 $120 HVDC capability subject to NI reserves availability 1000 $100 800 $80 600 $60 400 $40 200 $20 21 MARKET DYNAMICS Jun-16 May-16 Apr-16 Mar-16 Feb-16 Jan-16 Dec-15 Nov-15 Oct-15 Sep-15 Aug-15 $0 Jul-15 0 $/MWh 1200 MW $160 FY2016 average transfer: >340MW north FY2016 average transfer without NZAS: >850MW north REGULATION > Government and opposition parties constructively engaged in policy development > Electricity Authority (EA) has released second issues paper on Transmission Pricing Methodology (TPM) with proposal to move to a two part charge (Area-of-Benefit and Residual) with implementation likely beyond 2019 > Additional Mercury charges indicatively assessed by EA at ~$5m/annum (broadly in line with 2015 proposal) > Transpower is proposing alternatives to the EA‟s TPM which could have differential impacts from those assessed in the recent proposal > Trustpower plans to seek a High Court review of the EA consultation process on its proposed changes > Significant regulatory focus on reforms to distribution pricing in response to emerging technology Water > Government has established a technical advisory group to advise on water allocation approaches to address Maori rights and interests. > Consultation in progress on the national water quality standards > Waikato Regional Council consulting with stakeholders regarding long-term water management in the Waikato region Climate > Carbon pricing has increased 250% through FY2016 to circa $18 per tonne > Carbon cost expected to increase with the removal of the transitional 2-for-1 surrender obligations under the NZ ETS > Government announced policy package to promote the adoption of EVs - target 64,000 vehicles by 2021 22 MARKET DYNAMICS 23 OPERATIONAL SUMMARY ELECTRICITY SALES RESIDENTIAL SALES (FPVV) BUSINESS SALES 5,000 5,000 4,000 4,000 $80 3,000 3,000 $60 2,000 $40 1,000 $20 2,000 1,000 0 Business (end-user CFD excluding Norske Skog) Business (FPVV) OTA Forward 6 mth 2 yr ASX $100 0 2012 2013 2014 Financial Year 24 OPERATIONAL SUMMARY 2015 2016 $0 2012 2013 2014 Financial Year 2015 2016 $/MWh GWh GWh > Residential sales down 59GWh > Business (FPVV) and Industrial (CFD) sales down 205GWh due to multi-year portfolio decisions to maximise value > Average FPVV price down 2.0% to $114.83 as high priced Business and Industrial sales contracts secured between FY2011 and FY2013 mature and are partially replaced at current market prices > Unlikely that ASX prices fully reflect changes in supply and demand through FY2016 ELECTRICITY GENERATION > Generation 279 GWh higher than FY2015 > Geothermal generation was the highest ever, up 58GWh (2%) and reflecting 95.5% availability across all stations and successful replacement of the Nga Awa Purua turbine > Hydro generation was 539GWh (16%) higher than FY2015 however remains below the annual average of 4,000GWh due to inflows being 34th percentile for the year > Thermal generation was down 318GWh as Southdown was closed in December 2015 > Mercury‟s generation portfolio is now 100% renewable with the closure of Southdown HYDRO GEOTHERMAL 5,000 5,000 AVERAGE 3,000 4,000 GWh GWh 4,000 2,000 1,000 3,000 2,000 1,000 0 0 2012 2013 2014 Financial Year 25 OPERATIONAL SUMMARY 2015 2016 2012 2013 2014 Financial Year 2015 2016 LWAP/GWAP > LWAP/GWAP unfavourably higher to 1.03 > Low wholesale price volatility impacted both prices received for generation (GWAP) and electricity purchase prices (LWAP) > Location factors between generation (reference WKM) and purchase (reference OTA) widened due to thermal plant closures in the Auckland region and changes made by Transpower in 2015 to how transmission losses are modelled for wholesale pricing > GWAP continues to be favourable to peers reflecting the flexibility and location of Mercury‟s North Island renewable generation portfolio AVERAGE MONTHLY GWAP Mercury GWAP LWAP/GWAP LWAP/GWAP 160 Peer GWAP 1.10 OTA/WKM 140 LWAP/GWAP or Location Factor 1.08 $/MWh 120 100 80 60 40 1.06 1.04 1.02 1.00 26 OPERATIONAL SUMMARY Jul 16 Jan 16 Jul 15 Jan 15 Jul 14 Jan 14 Jul 13 Jan 13 Jul 12 0.96 Jan 12 0 Jul 11 0.98 Jan 11 20 2012 2013 2014 Financial Year 2015 2016 METRIX > Smart meter deployment has enabled customer-led product development NATIONAL MARKET SHARE June 2016 2% 2% > Broadly utilised by retailers with products such as Mercury‟s Free Power Days, GEM and GLOBUG 7% Vector Metrix 5% > Metrix 2nd largest NZ meter data and services provider with 436k meters owned or under management1 TrustPower 8% Contact Energy 51% > Market consolidated and initial meter upgrade largely complete or contracted > On-going focus on improving customer service > Customer satisfaction survey initiated for measuring performance > Platform stability and efficiency enhancements successfully executed, including the implementation of service request management capability Smartco Ltd Counties Power 18% Other GREATER AUCKLAND MARKET SHARE2 June 2016 > Growth from new connections and product development 32% > Auckland Unitary Plan indicating demand of 131k new houses over next 7 years > New data-driven products and services to existing customers Metrix Managed 6% 1 2 27 OPERATIONAL SUMMARY Metrix Owned 62% Other 396k meters are owned by Metrix Includes Vector and Counties networks 28 FINANCIAL SUMMARY FINANCIAL HIGHLIGHTS $493m $160m 2.0x EBITDAF, up $11m, reflecting increased generation but lower wholesale market volatility and commercial pricing NPAT, up $113m, reflecting non-cash impairments recognised in prior year Debt/EBITDAF, reflecting BBB+ credit rating and headroom for growth $221m 14.3CPS 4.0CPS Free Cash Flow, reflecting below longterm stay-in-business capex and a short-term tax prepayment Fully-imputed full-year ordinary dividend declared, per guidance Non-imputed special dividend declared with a continued focus on appropriate capital management 29 FINANCIAL SUMMARY EBITDAF (FY2016 vs. FY2015) > Energy margin up $11m > 279GWh more generation offset by lower relative generation prices (LWAP/GWAP) > Lower commercial pricing as higher priced sales contracted through FY2013 mature > Operating expenditure flat but remains $28m below FY2013 levels Improvement Reduction Energy Margin up $10m 600 (35) 500 69 (2) (22) 1 0 $m 400 300 493 482 200 100 0 EBITDAF FY2015 Generation Energy cost CFDs Customer Sales Other revenue Operating Expenditure EBITDAF FY2016 *Energy cost excludes gas generation purchases and volume impacts of end user sales, which are included within generation and customer sales respectively 30 FINANCIAL SUMMARY CAPITAL EXPENDITURE > Capital expenditure of $72m1 (FY2015: $110m2) > New investment of $13m (FY2015: $31m), primarily relating to smart meter deployment > Stay-in-business of $59m (FY2015: $79m), below medium-term guidance of $80m > FY2017 guidance of $125m for stay-in-business and for minimal growth capital expenditure > Stay-in-business includes the drilling of four wells as part of a co-ordinated drilling campaign across multiple reservoirs (circa $55m) and the continuation of the hydro refurbishment programme > Stay-in-business consistent with medium-term guidance (FY2013 to FY2017f average circa $80m) CAPITAL EXPENDITURE New investment Stay-in-business Normalised stay-in-business 400 350 300 $m 250 200 Below normalised stay-in-business guidance due to timing of geothermal makeup wells 288 183 150 100 50 74 69 33 60 2012 2013 2014 0 31 79 13 59 125 2015 2016 2017F Financial Year 1Excludes 31 FINANCIAL SUMMARY 2Excludes $18m in FY2016 relating to remediation capital expenditure in Chile $13m in FY2015 related to the exercise of the Germany geothermal option included in PPE FUNDING PROFILE DEBT MATURITIES AS AT 30 JUNE Undrawn Bank Facilities Capital Bond Domestic Wholesale Bonds US Private Placement 350 300 $m 250 200 150 100 50 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 2045 Financial Year > The average debt maturity profile for committed facilities was 8.9 years at 30 June 2016 > Interest costs elevated due to interest rate hedges put in place in 2008 during the company‟s domestic geothermal investment programme. These hedges roll off progressively from the end of FY2018 with an estimated $20m annual cash flow benefit in FY2019 32 FINANCIAL SUMMARY CAPITAL STRUCTURE > bbb stand alone rating is key reference point for dividend policy and a sustainable capital structure > S&P re-affirmed Mighty River Power‟s credit rating of BBB+/stable on 23 December 2015 > One-notch upgrade given majority Crown ownership > Key ratio for stand alone S&P credit rating bbb requires Debt / EBITDAF between 2.0x and 2.8x > Capital management continues to be reviewed > Debt/EBITDAF 2.0x at 30 June 2016 > Gearing will be maintained reflecting majority Government ownership 30 June 2016 30 June 2015 30 June 2014 30 June 2013 30 June 2012 1,068 1,082 1,031 1,028 1,116 Gearing ratio (%) 24.4 24.5 24.3 24.4 27.0 Debt/EBITDAF (x) 2.01 2.01 2.1 2.7 2.6 Net debt ($m) 1 33 FINANCIAL SUMMARY Adjusted for S&P treatment of subordinated debt GUIDANCE APPROACH > Mercury will provide point-estimate EBITDAF guidance for the current financial year going forward > To be complemented by updates to expected full-year hydro generation with quarterly operational statistics > The prior guidance range inferred a lower level of earnings volatility than is possible with underlying hydrology fluctuations > The range was principally intended to deal with non-hydrological volatility, however; > Changes in hydro generation expectations have driven all prior guidance revisions HYDROLOGICAL VOLATILITY P25 Hydro generation: FY2000-FY2016 (10%) (-10%) -800 -600 -400 -200 0 200 Hydrology generation (GWh from Median) 34 FINANCIAL SUMMARY P75 400 600 800 FY2017 GUIDANCE > FY2017 EBITDAF guidance is $490m subject to any material events, significant one-off expenses or other unforeseeable circumstances including hydrological conditions > The FY2017 EBITDAF guidance assumes: > > > > > 4,150GWh of hydro production (+$20m relative to FY2016); The continued roll-off of higher priced commercial contracts put in place through FY2013 (-$8m relative to FY2016); Advancing the RK29 well repair into FY2017 as part of the co-ordinated multi-reservoir drilling campaign (-$5m)1; No further material land sales (-$13m relative to FY2016); and No crystallisation of the Group‟s non-cash FX translation reserve loss, which will occur on the completion of the Chile divestments (approx. $10m) > FY2017 ordinary dividend guidance is up 2% to 14.6cps, the sixth year of consecutive ordinary dividend growth > FY2017 stay-in-business capital expenditure guidance is $125m 1 35 FINANCIAL SUMMARY Operating expenditure is expected to be broadly flat to FY2016 with the repair of RK29 offsetting cost savings relating to Southdown decommission and the exit of international geothermal development 36 APPENDIX INDUSTRY MILESTONES FY2013 FY2014 FY2015 FY2016 FY2017+ > > Genesis IPO > > > Trustpower demerger > Meridian IPO > Transpower consultation of TPM implementation > Emissions Trading Scheme review > Water allocation and quality standards review Mercury dual listed on NZX/ASX National party re-elected in general election > > 3rd year of electricity demand decline > > 37 APPENDIX Return of electricity demand growth Mercury decommissions steam turbine at Southdown Origin Energy sells majority stake in Contact EA‟s Final Transmission Pricing Methodology consultation document released > NZAS contract with Meridian renegotiated (backed by other participants) > NZAS 1st option to reduce Meridian contract to 400MW not called (29 July 2016) > Second consecutive year of demand growth > NZAS next option to terminate Meridian contract with 12 months notice (from 1 January 2017) > Mercury closes 140MW Southdown OCGT > Contact closes 400MW Otahuhu CCGT > Genesis terminates coal contract with Solid Energy > Genesis commits to Huntly Rankine units remaining open through 2022 400 350 300 250 200 150 100 38 APPENDIX Used Fully Electric Installations New Hybrid NZ Post fleet announcement New Fully Electric Air NZ fleet announcement 450 Mercury fleet announcement ELECTRIC VEHICLE REGISTRATION Used Hybrid PHOTOVOLTAIC INSTALLATIONS 400 350 300 50 50 0 0 Mercury acquires What Power Crisis 450 Jul-14 Aug-14 Sep-14 Oct-14 Nov-14 Dec-14 Jan-15 Feb-15 Mar-15 Apr-15 May-15 Jun-15 Jul-15 Aug-15 Sep-15 Oct-15 Nov-15 Dec-15 Jan-16 Feb-16 Mar-16 Apr-16 May-16 Jun-16 Jul-14 Aug-14 Sep-14 Oct-14 Nov-14 Dec-14 Jan-15 Feb-15 Mar-15 Apr-15 May-15 Jun-15 Jul-15 Aug-15 Sep-15 Oct-15 Nov-15 Dec-15 Jan-16 Feb-16 Mar-16 Apr-16 May-16 Jun-16 Jul-16 Vehicles EV & PV TRENDS > EV uptake has doubled to 808 vehicles per annum through FY2016 > 0.5% of electricity connections have PV at 30 June 2016 250 200 150 100 Source: Ministry of Transport, Electricity Authority OPERATING INFORMATION Year ended 30 June 2016 Electricity Sales FPVV sales to customers Year ended 30 June 2015 VWAP1 ($/MWh) Volume (GWh) VWAP1 ($/MWh) Volume (GWh) 114.83 4,397 117.21 4,486 Residential customers 2,438 2,497 Commercial customers 1,959 1,989 4,643 4,717 950 1,388 FPVV purchases from market Spot customer purchases Total NZEM purchases 65.41 Electricity Customers (000) 5,593 76.26 6,104 376 382 North Island customers 339 348 South Island customers 37 34 41 40 396 388 Dual Fuel customers Metrix AMI Meters (000) 1 39 APPENDIX VWAP is volume weighted average energy-only price sold to FPVV customers after lines, metering and fees OPERATING INFORMATION Year ended 30 June 2016 Year ended 30 June 2015 VWAP ($/MWh) Volume (GWh) VWAP ($/MWh) Volume (GWh) Hydro 64.84 3,866 77.82 3,327 Gas (all 1HY2016) 68.64 146 84.58 4644 Geothermal (consolidated)1 60.84 2,596 70.63 2,545 Geothermal (equity accounted)2 61.44 234 71.94 227 Total 63.29 6,842 75.30 6,563 Electricity Generation LWAP/GWAP 1.03 1.01 VWAP ($/MWh) Volume (GWh) VWAP ($/MWh) Volume (GWh) $/GJ PJ $/GJ PJ Retail purchases3 8.07 1.01 9.22 1.08 Generation purchases (all 1HY2016) 6.21 1.70 5.90 4.72 Gas Purchases Carbon Emissions (‘000 tonnes) 428 Includes Mighty River Power‟s 65% share of Nga Awa Purua generation Tuaropaki Power Company (Mokai) equity share 3 Prices include fixed transmission charges 1 2 40 APPENDIX 647 CONTRACTS FOR DIFFERENCE Year ended 30 June 2016 Year ended 30 June 2015 (1,448) (1,623) (701) (699) Sell - Inter-generator & ASX (1,259) (1,061) Sell CFD (3,408) (3,384) Buy CFD 1,741 1,697 (1,667) (1,686) 27 22 Net Contracts for Difference (Sell)/Buy GWh Sell - End User Sell - VAS1 CFD Energy Margin contribution ($m) 1 41 APPENDIX VAS included on both buy and sell side CFDs BALANCE SHEET As at 30 June 2016 As at 30 June 2015 3,315 3,337 313 287 5,772 5,743 Held for sale 0 28 Total assets 6,085 6,058 310 198 Non-current liabilities 2,460 2,518 Held for sale Total liabilities TOTAL NET ASSETS 0 2,770 3,315 5 2,721 3,337 $m SHAREHOLDERS’ EQUITY Total shareholders’ equity ASSETS Current assets Non-current assets LIABILITIES Current liabilities 42 APPENDIX NON-GAAP MEASURE: ENERGY MARGIN > Energy Margin provides a measure that, unlike sales or total revenue, accounts for the variability of the wholesale spot market and the broadly offsetting impact of wholesale prices on the cost of retail electricity purchases Year ended 30 June 2016 Year ended 30 June 2015 Sales 1,512 1,627 Less: lines charges (419) (422) Less: energy costs (384) (507) Less: other direct cost of sales, excluding third-party metering (28) (26) Less: third party metering (23) (24) Energy Margin 658 648 $m 43 APPENDIX NON-GAAP MEASURE: FREE CASH FLOW > Free Cash Flow is a measure that the Company uses to evaluate the levels of cash available for debt repayments, growth capital expenditure and dividends Year ended 30 June 2016 Year ended 30 June 2015 Net cash provided by operating activities 280 309 Less: Stay-in-business capital expenditure (including accrued costs) (59) (79) Free Cash Flow 221 230 $m 44 APPENDIX NON-GAAP MEASURE: EBITDAF, UNDERLYING EARNINGS AND NET DEBT > EBITDAF is reported in the financial statements and is a measure that allows comparison across the electricity industry > Underlying Earnings is reported in the financial statements and in contrast to net profit, the exclusion of certain items enables a comparison of the underlying performance across time periods > Net Debt is reported in the financial statements and is a measure commonly used by investors 45 APPENDIX