Annual Report 2014 CONTENTS Chairman’s and CEO’s Report Management Discussion and Analysis Directors’ Report Remuneration Report Corporate Governance Statement Annual Financial Statements Directors’ Declaration Independent Auditor’s Report Share and Shareholder Information 2 4 16 22 32 36 100 101 103 Corporate Directory Inside Back Cover ERM Power Limited (ERM Power, Company, Group, we, our) was listed on the Australian Securities Exchange on 10 December 2010. This review is for the year ended 30 June 2014 with comparison against the previous corresponding period ended 30 June 2013 (previous year or previous period). All reference to $ is a reference to Australian dollars unless otherwise stated. Individual items totals and percentages are rounded to the nearest approximate number or decimal. Some totals may not add down the page due to rounding of individual components. CHAIRMAN’S AND CEO’S REPORT PAGE 2 CONTINUED SUCCESS It is our pleasure to record another successful year for ERM Power, one in which we operated safely and delivered record sales and profits, built the foundations for further growth and consolidated our position as one of the four pillars of the Australian energy sector. Operating in a competitive and dynamic environment, we delivered higher underlying earnings and dividends as our electricity sales business continued to grow strongly, our generation business delivered another year of solid contribution and our gas business delivered its first operating profits. We also participated in the sale process for the assets of Macquarie Generation and established a new electricity metering business, which will grow and further diversify our earnings. HIGHER EARNINGS Our strong performance continued in FY 2014 with underlying NPAT1 32% higher than FY 2013 when a number of significant items2 are excluded. Pleasingly, the Board has approved another increase in dividends for the full year. BUSINESS ENERGY GROWTH Our electricity sales business, which trades as ERM Business Energy, experienced another record year, increasing volumes by 27% to 14.1 terawatt hours (TWh) and increasing revenue and earnings as we continued to expand our share of the business market in Australia. The business, which operates in every state and the Australian Capital Territory, remained Australia’s fourth largest electricity retailer accounting for 8.7% of all sales in the National Electricity Market. We maintained our growth in the large business market, particularly in New South Wales and Victoria where sales volumes rose by 56% and 31% respectively. This growth was supplemented by our entry into the small business market which began on 1 July 2013 with more than 10,000 sites in New South Wales contracted. We have signed ‘multi-site’ contracts and aim for similar success with ‘single site’ customers as marketing drives traffic to our online sign-up portal. We finished FY 2014 billing with more than 24,000 customer sites including more than 14,000 small business sites. Our forward contract sales over the next two years are 23.6TWh, including a $900m contract with the NSW Government and $100m contract extension with the Federal Government, both signed in FY 2014 and to commence in FY 2016. The working capital component of our financing facility from Macquarie Bank Ltd was increased to $160m from $100m to support the continued growth of our electricity sales business. For the third successive year ERM Business Energy was ranked number 1 for customer satisfaction3 in business electricity and we maintained our operational excellence with billing accuracy and billing collection rates above 99%, which were achieved with our industry-leading, internally-developed systems and processes. We have been reviewing a number of new markets in which to expand our successful business energy retail model. The United States had been identified as a possible new market for the Company and a feasibility study commenced during the year to determine the viability of establishing a business in the US. 1 Refer to Glossary of Management Discussion and Analysis. 2 Refer to Appendix A1.2 of the Management Discussion and Analysis for details of the Significant Items. ERM POWER ANNUAL REPORT | 2014 GENERATION PERFORMANCE The Oakey and Neerabup power stations performed safely, delivering consistent revenue and earnings with continued high availability and reliability and no environmental breaches. We moved to full ownership of Oakey after buying the remaining 16.67% we did not own and repaid its remaining debt using funds raised in a $75m share placement. We recognised a $39.1m income tax benefit as a result of Oakey joining the ERM Power tax consolidated group with our move to 100% ownership. This benefit will be realised over the depreciable lives of the assets. A range of options are available for Oakey when it comes off contract from January 2015 including internal use by our electricity sales business, selling financial products in the wholesale market and selling specialised financial/physical products such as gas tolling agreements to gas and/or electricity market participants. We remain confident about the long term value of this high quality asset which was purchased at a discount to its replacement value and is well located to benefit from growth in south-east Queensland. Neerabup power station is in the early years of a long term contract and is expected to grow in value as its operations more than cover its debt servicing obligations. We retain development approval for a number of sites on the east coast and in Western Australia for future power stations but demand for new generation remains low and development will proceed only when the market improves. MACQUARIE GENERATION BID During the year, we pursued one of the largest transaction opportunities in our history with a bid for the assets of Macquarie Generation being sold by the NSW Government. We conducted a disciplined due diligence process with careful consideration of the medium and long term outlook for electricity demand from the grid. This included assessments of aluminium industry risk and emissions policy risk for coal-fired generation and we priced our bid accordingly. While we enjoyed strong support for our participation in the process from shareholders and financiers, ultimately our bid was not successful. Shareholders can be assured that the company employed robust processes and maintained a disciplined approach throughout. Nevertheless, during the course of our preparation for the bid, the company’s share price was subdued over a lengthy period. This was as a result of preparations to secure financing and market speculation that the funding of a successful bid would significantly dilute our share capital. Fortunately, our business has continued to perform strongly, setting new sales and profit records, and the share price has started to recover. GAS Our gas business became operationally profitable with the start of gas and condensate sales from the Red Gully facility in Western Australia, which is jointly owned with, and operated by, Empire Oil & Gas (Empire). Changes to Empire’s board and management have strengthened its governance and the recruitment of experienced production and exploration personnel has helped it to manage early production and operational challenges at Red Gully. A perforation of the primary resource was completed in June 2014 and we are well positioned to obtain a certified reserve estimate in the short term. A seismic survey has been completed in the area surrounding the Red Gully discovery and production facility which has highlighted a number of significant prospects for low cost expansion. Since balance date we have announced the sale of our West Australian gas assets to Empire (including our interest in Red Gully) and agreed to participate in a subscription and rights issue to recapitalise that company. The transaction is subject to Empire shareholder approval being obtained in the first half of FY 2015. The restructure of our West Australian gas assets into a more capital efficient ownership model will allow us to focus on electricity retailing and generation. It will give Empire access to funding and investors with which to commercialise the Red Gully and Gingin West wells and continue exploration. Our east coast gas interests comprise a passive interest in Metgasco Limited and exploration areas in NSW. These assets have been impacted by ongoing regulatory and public policy uncertainty in NSW. We will continue to keep these assets on hold until investment conditions materially improve. PEOPLE AND COMMUNITY We maintained our excellent safety performance with no recordable or lost time injuries and no reportable environmental incidents or breaches of environmental licence conditions. Through partnership and sponsorship programs, we also supported sporting groups, the arts, youth education, community and charitable organisations. As we look back on another successful year, we recognise the dedication and hard work of our people led by the executive management team together with the contribution and support of our fellow directors. OUTLOOK We ended the year in a stronger financial position and with more growth opportunities than a year ago. Our priorities include: • delivering our FY 2015 results • growing our electricity sales to large businesses • building scale in the small business segment • establishing a metering business • restructuring our gas assets • optimising returns from the Oakey power station • continuing to reduce unit costs, and • assessing international expansion for our business energy retail model. We remain focussed on achieving our goal of being the preferred energy supplier to businesses across Australia and delivering value for shareholders. 3 Utility Market Intelligence (UMI) survey of retail electricity industry by independent research company NTF Group in 2013 (18th year of survey). Research based on survey of 414 business electricity customers in October/November 2013. Four major electricity retailers benchmarked. Tony Bellas Chairman Philip St Baker CEO PAGE 3 MANAGEMENT DISCUSSION AND ANALYSIS FOR THE YEAR ENDED 30 JUNE 2014 1. FY 2014 HIGHLIGHTS AND FY 2015 GUIDANCE Electricity sold (TWh) 14.1 11.1 8.3 FY 2014 FY 2013 FY 2012 EBITDAIF excluding significant items2 ($m) Statutory EBITDAIF ($m) Underlying NPAT excluding significant items2 ($m) Underlying NPAT ($m) Dividends paid (cents per share) 84.6 74.2 26.3 57.0 78.4 69.8 20.0 15.7 70.1 85.4 13.9 30.3 11.5 9.5 7.5 Rated number 1 for customer satisfaction in the electricity business customer market For the third year in a row, we were rated number 11 for customer satisfaction in the sale of electricity to the commercial and industrial (C&I) business customer market. Electricity sales up 27% to 14.1 TWh Electricity sales continued to grow strongly, up 27% to 14.1TWh for the year, from 11.1TWh in the previous year. Record forward sales contracts in place, greater than double total FY 2014 sales As of 30 June 2014, forward contracted electricity sales were a record 29.7TWh locking in the continuing strong growth of electricity sales. This figure comprises more than 14.4TWh for FY 2015 and a total of 23.6TWh over the two years to June 2016. Electricity sales revenue up 34% to $2 billion, with contestable revenue up 25% to $1.12 billion Electricity sales revenue for the year increased by 34% over the previous year, from $1,493m to $1,996m. The increase in electricity sales revenue over and above the sales volume increase was the result of increased unit costs for legislated environmental products and increased network costs (passed through to customers without transaction margin). Generation EBITDAIF up 19% to $51.8m, with revenue steady at $73.5m The Generation business continued to deliver steady revenue, but with improved EBITDAIF, up 19% from $43.8m to $51.8m. The purchase of the final 3rd party minority shareholding in Oakey power station represented a 12% increase in ERM Power-owned generation capacity. New generation developments remain on hold as a result of declining electricity demands. PAGE 4 1 Based on UMI survey results – refer glossary for further details. 2 Refer Appendix A1.2 for reconciliation and summary of significant items, and glossary for definition of EBITDAIF and underlying earnings. ERM POWER ANNUAL REPORT | 2014 Group EBITDAIF2 (adjusted for significant items) up 8% to $84.6m Group EBITDAIF for the year, which contains a number of significant items, was $74.2m compared to $69.8m in the previous year. EBITDAIF excluding significant items was up 8% to $84.6m from $78.4m in the previous year. Appendix A1.2 contains a reconciliation of the significant items. Our electricity sales business increased its EBITDAIF by 9% to $41.8m, from $38.3m in the previous year, and our generation business by 19% to $51.8m from $43.5m. Underlying Profit2 (adjusted for significant items) up 32% to $26.3m Underlying profit after tax includes various items that were not part of general operations. Excluding these, Underlying Profit was $26.3m compared to $20.0m in the previous year, an increase of 32%. Within the excluded significant items is the one-off accounting tax benefit of $39.1m resulting from achieving 100% ownership of the Oakey power station. Whilst the accounting tax treatment is a one-off benefit, the cash flow benefit will continue to be realised over the operating life of the power station through higher tax depreciation deductions, which on a tax effected basis have a nominal cash value of $39.1m. Final dividend of 6.0 cents per share to be paid on 13 October 2014 A fully franked final dividend of 6.0 cents per share has been declared and will be paid on 13 October 2014. The record date is 11 September 2014. The Company’s shares will trade ex-dividend from 5 September 2014. This dividend is 9% higher than last year’s final dividend. FY 2015 Guidance There is no change to the FY 2015 forecast provided earlier in 2014 with EBITDAIF of $94m – $98m and Underlying Net Profit after Tax of $30m – $33m. 2. GROUP OVERVIEW ERM Power Limited is a diversified energy company that operates electricity sales, electricity generation, and gas exploration and production businesses. Our aspiration is to be the preferred supplier of energy to Australian business customers. We are licensed to sell electricity in all Australian states and territories and are the 4th largest seller3 of electricity by volume in Australia. We focus on selling electricity exclusively to business customers, with this segment of the market comprising approximately 12% of all customers and 70% of all electricity sold in Australia. We own 497MW of low emission gas-fired power generation power stations, comprising 100% of the 332MW Oakey Power Station (Oakey) and 50% of the 330MW Neerabup Power Station (Neerabup) both of which we operate. We are one of Australia’s largest power development companies having led the development of more than 2,000MW of gas-fired power generation. Completed projects include the Oakey, Braemar 1 and Braemar 2 power stations in Queensland, the Uranquinty power station in New South Wales and Neerabup and the Kwinana power station in Western Australia. 3 ERM Power’s forecast league table for volume of electricity sold in the National Electricity Market (NEM) for FY 2014. The analysis draws on 2011 SRES scheme liability data, ERM Power signed contracts and broad assumptions about the market and participants. This is not an independently verified forecast. We have participated in two successive commercial gas/ condensate discoveries, which are now in production, and have equity interests in over 10,000 km² of gas exploration acreage across Australia. Exploration tenements include conventional gas, condensate, oil and shale gas prospects. We also hold strategic shareholdings in gas exploration companies. The diverse nature of the Group necessitates different measures to be applied to each of its operating businesses in assessing performance. The strategic priorities of each operating business and key performance indicators and operating metrics are set out below. Electricity sales Generation Other (Gas, Metering and Corporate) Strategic priorities Strategic priorities Strategic priorities – Increase earnings – Increase earnings – Increase earnings – Increase market penetration – Safe and reliable operations – Generate appropriate average gross margins – Enter new energy markets and segments – Maintain leading customer satisfaction position with customers – Demand response – Exploit merchant opportunities – Generate a stable return on assets – Identify and where appropriate, develop or acquire generation assets – Utilise industry expertise in operating power stations and gas pipelines – Investment opportunities – Enhance value of existing gas assets – Attract external capital as required – Identify and pursue investment opportunities that have strategic and commercial value – Establish an electricity metering business – Investment opportunities Key performance indicators and operating metrics Key performance indicators and operating metrics Key performance indicators and operating metrics – Earnings – Safety – Sales (load sold) – Earnings – Safety – Earnings – Reliability – Availability – Production volumes – Reliability – Availability – Operating income – Fuel and – Gross margin in $ per MWh – Operating cost in $ per MWh – Collection rate – Billing accuracy – Customer satisfaction operating costs – Operating cost – Reserves – Penetration of electricity metering market PAGE 5 MANAGEMENT DISCUSSION AND ANALYSIS (CONT.) FOR THE YEAR ENDED 30 JUNE 2014 3. REVIEW OF OPERATING RESULTS 3.1 Summary of Group financial results FY 2014 FY 2013 Change Change % 2,076.5 1,569.6 506.9 32% (2,002.3) (1,499.8) (502.5) -34% 74.2 69.8 4.4 6% (18.0) (14.0) (4.0) -29% $m Revenue Expenses EBITDAIF Depreciation and amortisation Net fair value (loss) / gain on financial instruments (115.6) 29.8 (145.4) Finance expense (29.3) (31.8) 2.5 (Loss) / profit before tax (88.7) 53.8 (142.5) Tax benefit / (expense) 65.6 (15.3) 80.9 N/A 8% N/A N/A Statutory net (loss) / profit after tax (NPAT) (23.1) 38.5 (61.6) N/A Non-controlling interest (0.8) (1.9) 1.1 58% Group EBITDAIF for the year was $74.2m compared to $69.8m in the previous year. On a like for like basis, EBITDAIF (i.e. excluding significant items4 ) was 8% higher at $84.6m. The increase is attributable to increases across all operating segments. Depreciation and amortisation increased by $4.0m primarily as a result of the commencement of operations from the Red Gully processing facility of which we are a joint venture participant and depreciation of new software development spend associated with serving the extended business market (SME). Finance charges include an additional $1.6m of one-off costs associated with the repayment of the Oakey term debt ahead of the scheduled date in FY 2015. The tax benefit includes a one-off permanent adjustment of $39.1m resulting from the reset of the Oakey tax base. This benefit will be realised over the depreciable lives of the assets involved. Group underlying earnings for the year were $57.0m compared to $15.7m in the previous year. On a like for like basis, Underlying Profit (i.e. excluding the significant items) was 32% higher at $26.3m up from $20.0m. Dividends paid during the year per share were 21% higher than the prior year and were broadly in line with underlying earnings excluding significant items associated with the Oakey transaction. 80.9 (20.9) 101.8 N/A 3.2.1 Electricity sales 3.2 Operating division results Underlying NPAT 57.0 15.7 41.3 263% $m FY 2014 FY 2013 Change EBITDAIF5 ($m) Sales load (TWh) Change % Statutory EBITDAIF 74.2 69.8 4.4 6% FY 2014 FY 2013 Change Change % (0.9) -24% 2.8 44.6 14.1 3.7 42.0 11.1 2.6 3.0 6% 27% 34% 25% 14% 25.2 8.9 16.3 183% EBITDAIF ($m) 41.8 38.3 3.5 9% 11.5 9.5 2.0 21% Significant items (refer Appendix A1.2) ($m) 10.4 8.6 1.8 21% Total revenue excluding interest income ($m) 1,992.4 1,490.1 502.3 Contestable revenue ($m) 1,118.7 894.4 224.3 Gross margin ($m) 59.1 51.7 7.4 84.6 57.0 78.4 6.2 8% Operating expenses5 ($m) (17.9) (12.5) (5.4) -43% 15.7 41.3 263% Gross margin $ per MWh 4.20 4.67 (0.47) -10% (39.1) – (39.1) -100% Operating expenses5 $ per MWh (1.27) (1.13) (0.14) -12% 1.1 – 1.1 100% 19.0 15.7 3.3 21% 7.3 4.3 3.0 70% 26.3 20.0 6.3 32% 4 Refer Appendix A1.2 for reconciliation and summary of significant items. 5 Adjusted for significant items. Refer Appendix A1.2 for summary of significant items. Add back: Net fair value loss / (gain) on financial instruments after tax Underlying EPS (cents per share) Dividends paid (cents per share) Significant items (refer Appendix A1.2) EBITDAIF excluding significant items Underlying earnings Oakey tax benefit (refer Appendix A1.2) Finance costs on termination of Oakey debt (refer Appendix A1.2) Underlying earnings excluding Oakey transaction Other significant items (refer Appendix A1.2) Underlying earnings excluding all significant items PAGE 6 ERM POWER ANNUAL REPORT | 2014 FY 2014 financial performance Revenue figures have two components, contestable and pass- through. Contestable is that component on which we earn a margin and pass-through (being network charges) on which we do not. Contestable revenue per MWh remained steady at approximately $80 per MWh. During the year, gross margin per MWh decreased to $4.20 from $4.67 in the previous year reflecting a temporary softening in gross margins primarily associated with the impact of the carbon scheme and its retrospective repeal. Operating costs5 per MWh have increased reflecting the establishment our Small to Medium Enterprise (SME) business. As the SME business scales up, the operating expenses will reduce on a per MWh basis. During the year we also incurred some further non-recurring costs associated with developing new business streams such as gas retailing and energy management services. Sales volume continues to grow strongly. This, combined with the 25% increase in forward contracted sales for the next two financial years, positions us for continued growth in the future. The geographic diversification continues with sales volumes outside Queensland rising by 2.6TWh (40%) from 6.5TWh to 9.1TWh. During the year we achieved growth in Victoria of 31% and 56% in NSW. Sales volumes in Queensland increased by 9% to 5TWh, and sales in the residual states increased by 25% to 1.5TWh. Entry into the SME market On 1 July 2013, we served our first customer in the SME business customer market and we now have over 17,500 sites under contract across four states. We have built a robust operating system capable of delivering continued growth in customer numbers. Customer satisfaction During the year we maintained our number one customer satisfaction rating with 87% of customers very satisfied with ERM Power’s service compared to 42% for our competitors6. In July 2014, we released our new customer portal, providing an enhanced platform for our customers to access information relating to their account, usage data and general market information. Operational performance Our billing accuracy exceeded 99.95% for the year and our billing collection rate exceeded 99.88%. We have achieved these industry leading performance levels by designing, building, owning and operating our own retailing processes and IT systems and enforcing our conservative risk management policies. During the year we invested $4.2m on improvements to these IT systems to facilitate future growth. 6 Based on UMI survey results – refer glossary for further details. 3.2.2 Generation $m FY 2014 FY 2013 Change Change % Revenue and other income Oakey Neerabup Generation development and operations Total revenue EBITDAIF Oakey Neerabup Generation development and operations Total EBITDAIF Significant items (refer Appendix A1.2) EBITDAIF excluding significant items 35.7 29.9 7.9 73.5 28.8 23.7 (0.7) 51.8 39.2 26.6 6.9 72.7 28.8 21.7 (7.0) 43.5 (3.5) 3.3 1.0 0.8 0.0 2.0 6.3 8.3 -9% 12% 14% 1% 0% 9% 90% 19% (0.5) 4.8 (5.3) -110% 51.3 48.3 3.0 6% FY 2014 financial performance Generation revenue for Oakey and generation development and operations revenue was consistent with the previous year whilst revenue from Neerabup increased principally as a result of additional operation of energy sales to third parties. Both revenue and operating costs for Oakey include distillate fuel costs which are fully recovered under its off-take agreement. The amount of diesel used in FY 2013 was higher than this year. Prior year EBITDAIF from generation development and operations includes $4.4m in costs associated with the Neerabup contractor arbitration plus staff restructuring costs. During the year $0.3m of costs were incurred in respect of the arbitration. Further financial information on the power station assets is contained in Appendix A1.4. Acquisition of minority interest During the year we acquired the remaining 16.7% interest in Oakey for a cash price of $30.0m. As part of the purchase, funds previously advanced by the minority interest were also repaid. On acquisition the tax base of Oakey’s assets were reset and the resulting benefit has been calculated as $39.1m. This benefit will be realised over the depreciable lives of the assets. Generation development activities Development opportunities continue to be limited by low demand. Our East coast projects are well positioned to support electricity sales growth as an alternative to buying market product. In Western Australia, we are well positioned in the mid-west minerals province. We also maintain an interest in pursuing well-priced assets in the NEM. PAGE 7 MANAGEMENT DISCUSSION AND ANALYSIS (CONT.) FOR THE YEAR ENDED 30 JUNE 2014 Power station operating performance Oakey continues to operate as a peaking plant and runs only in response to dispatch directions under its off-take agreement. During the year it operated for less than 2% of the time. Oakey maintained its outstanding availability and overall performance record, with 99% availability during the period. Neerabup operated for 2.6% of the period and also maintained its outstanding availability and overall performance record with availability of 99%. Safety During the year we continued to maintain an outstanding safety record with no lost-time injuries from any staff or contractors on the facilities during commercial operation. 3.2.3 Gas $m FY 2014 FY 2013 Change Change % Exploration expenditure capitalised Development expenditure capitalised EBITDAIF 2.9 7.4 (4.5) -61% 1.3 0.9 8.3 (0.8) (7.0) 1.7 -84% 213% FY 2014 performance Our gas business moved into profitability with the start of gas and condensate sales from the Red Gully facility in Western Australia which is jointly owned with, and operated by, Empire Oil & Gas NL. Changes to Empire’s board and management and the recruitment of experienced production and exploration personnel has helped it to manage early production and operational challenges at Red Gully. Perforation of the primary resource was completed in June 2014 and we are expecting to obtain a certified reserve estimate in FY 2015. A seismic survey has been completed in the area surrounding Red Gully which has highlighted a number of significant prospects for low cost expansion. Our East coast gas interests comprise a passive interest in Metgasco Limited together with exploration areas in NSW. These assets have been impacted by regulatory uncertainty in NSW which, at this point, seems far from being resolved. We will continue to keep these assets on hold until investment conditions materially improve. We are actively working on a restructure of our gas exploration assets as they are no longer strategically critical for us and are better held in a different structure which can attract external sources of capital. We hope to complete this restructure in FY 2015 and significantly reduce capital requirements from FY 2016. 3.2.4 Corporate $m FY 2014 FY 2013 Change Change % Interest revenue Other revenue Revenue Office and property expenses Other expenses Payroll and related expenses Expenses EBITDAIF before significant items Significant items New business establishment costs Macquarie generation bid costs Legal fees in relation to Empire Oil actions Restructuring costs 2.2 1.6 3.8 (4.7) (1.5) 2.3 1.5 3.8 (3.6) (1.7) (0.1) -4% 0.1 0.0 7% 0% (1.1) -31% 0.2 12% (9.6) (9.7) (15.8) (15.0) 0.1 (0.8) 1% -5% (12.0) (11.2) (0.8) -7% (1.1) 0.0 (1.1) -100% (6.1) 0.0 (6.1) -100% (0.9) – 0.0 (0.1) (0.9) -100% 0.1 100% Total corporate EBITDAIF (20.1) (11.3) (8.8) -78% FY 2014 financial performance Corporate revenue was the same as the prior year whilst expenses excluding significant items showed a modest increase of 5% from $15.0m to $15.8m. Office and property expenses increased following the move to different premises in March 2013 in Brisbane, Melbourne and Sydney. Overall, these costs are lower on a unit basis than those they replaced. The various moves provided for future growth. 3.3 Cash flow $m FY 2014 FY 2013 Change EBITDAIF net of non-cash items Tax paid Operating cashflow before working capital changes Working capital changes Operating cashflow Investing cashflow Financing cashflow Total net change in cash 76.0 (4.2) 71.8 (46.4) 25.4 (20.0) 26.9 32.3 70.6 (6.6) 64.0 40.7 104.7 (40.7) 11.7 75.7 5.4 2.4 7.8 (87.1) (79.3) 20.7 15.2 (43.4) PAGE 8 ERM POWER ANNUAL REPORT | 2014 Net cash flow from operating activities for the year was $25.4m compared to $104.7m in the previous year. This decrease is a result of unfavourable working capital movements and timing between the two periods. A reconciliation is provided in Appendix A1.3. The previous year had unusually low purchases of renewable energy certificates due to the sale and re-purchase arrangement with Macquarie Bank, whilst the current year had the repurchase cost of these certificates as well as the costs of acquiring further certificates on the higher sold volume of electricity. The reconciliation of EBITDAIF to operating cash flows, together with a summary of cash flows, is shown in Appendix A1.3. Investing cash flows in the prior year included higher cash outflows due to higher investment in gas development and exploration. Financing cash flows included net proceeds of $83.7m from capital raisings, the purchase of the minority interest in Oakey for $30.0m and the early repayment of the Oakey term debt. 3.4 Review of financial position 3.4.1 Significant balance sheet movements $m FY 2014 FY 2013 Change Change % Cash and cash equivalents 247.7 215.4 Net working capital 17.8 6.7 32.3 11.1 15% 166% PPE, gas and intangible assets Net derivative financial instruments Net deferred tax assets / (liabilities) 478.2 482.0 (3.8) -1% (151.9) (37.3) (114.6) -307% 9.8 (60.7) 70.5 Borrowings (331.5) (338.9) Other assets and liabilities 7.1 4.7 Net assets 277.2 271.9 7.4 2.4 5.3 N/A 2% 51% 2% Net assets increased by $5.3m during the period, but exclude the increased mark to market value of the electricity sales book. The movement in the mark to market value of derivative financial instruments was offset by capital raised during the year and earnings generated, including the Oakey minority interest acquisition tax benefit. A full reconciliation of the $32.3m cash movement to EBITDAIF is provided in Appendix A1.3. Contracts to sell electricity to consumers do not presently meet the definition of a financial instrument. This precludes the recognition of mark to market movements of opposing sell side contracts to an economic hedge being recognised in the statutory accounts. Only the buy side hedge contracts may be recognised for accounting purposes. The value of these customer contracts, together with internally generated intellectual property in respect of systems used as part of the electricity sales operation represent the main assets not recognised for accounting purposes. The un-audited value of our customer contracts at 30 June 2014 was $174.5m. A significant portion of tangible property, plant and equipment and borrowings continues to relate to the generation business, whilst the less capital intensive electricity sales business continues to require further cash and cash equivalent prudential support as sales volumes increase. 3.4.2 Net debt and capital structure $m FY 2014 FY 2013 Change Electricity sales working capital facility Electricity sales environmental certificate financing Term debt – recourse to Oakey Power Station project only Term debt – recourse to Neerabup Power Station project only Convertible notes – recourse to Neerabup Power Station project only Convertible notes redemption premium* Capitalised borrowing costs** 129.9 59.1 70.8 – – 36.4 (36.4) 40.5 (40.5) 156.3 160.8 (4.5) 40.0 40.0 – 6.5 (1.2) 5.2 (3.1) 1.3 1.9 331.5 338.9 (7.4) * Redemption premium payable on maturity of notes in February 2023 of $20m. A lower redemption premium is payable on early redemption up until 30 September 2016. Early redemption is at the option of ERM. For accounting purposes, the maximum redemption premium of $20m is accumulated up until February 2023 using the effective interest rate method. The effective interest rate is the rate that exactly discounts the $20m through the expected life of the convertible note. ** For accounting purposes the cost associated with establishing term and other long-term debt facilities is amortised over the life of the respective financial liability. During the year the debt on Oakey was fully repaid. In the prior year an additional financial liability relating to a sale and repurchase agreement for renewable energy certificates was recognised. This arrangement settled in January 2014. A significant portion of the Group debt relates to long-term funding of Neerabup. This debt is recourse only to the Neerabup assets. The financing of the power station is under-pinned by an off-take agreement with a Western Australian government entity. To consider the risk of the Company’s capital structure it is appropriate to segregate the projects (together with their project debt) from the rest of the Group. The table below illustrates the gearing and interest cover for the Group. When the Oakey and Neerabup assets and associated non-recourse debt are excluded the Group has no net debt. PAGE 9 MANAGEMENT DISCUSSION AND ANALYSIS (CONT.) FOR THE YEAR ENDED 30 JUNE 2014 $m FY 2014 FY 2013 Change Capital Risk Management Current borrowings 138.0 122.3 15.7 Non-current borrowings 193.5 216.6 (23.1) Total debt 331.5 338.9 (7.4) Cash and cash equivalents (247.7) (215.4) (32.3) Net debt 83.8 123.5 (39.7) Total equity excluding reserves 323.5 306.6 16.9 Total capital 407.3 430.1 (22.8) Gearing percentage 21% 29% Gearing percentage excluding Oakey and Neerabup 0% 0% 8% 0% EBITDA interest cover ratio 2.54 2.19 0.35 Gearing percentage is calculated as net debt divided by total capital. Net debt is calculated as total interest-bearing borrowings less cash and cash equivalents. Total capital is calculated as ‘equity’ as shown in the statement of financial position plus net debt less reserves attributable to fair value adjustments. 3.4.3 Dividend strategy and history A fully franked dividend of 6.0 cents per share for FY 2014 was declared on 21 August 2014 equating to an annualised dividend yield of 6.6% at 30 June 2014. Dividends to shareholders have been at or above the 2 year forecast in the 2010 prospectus increasing at 0.5 cents per half year. This reflects the growth in the electricity sales business and the fact that the power stations are self-funding their project finance obligations. Total shareholder return over the period since the IPO on 10 December 2010 is more than 20.3% based on a closing share price of $1.82 at 30 June 2014. We have a progressive dividend policy with consideration of current and future cash flow and growth capital requirements. When determining the dividend payable, the directors take into consideration any significant non-recurring items in respect of either earnings or capital expenditure. Directors intend to pay dividends bi-annually after the respective period results are published. The final decision to pay a dividend will be made subject to actual results and other considerations with reference to the underlying cash flow requirements of the business. PAGE 10 4. BUSINESS STRATEGIES AND FUTURE PROSPECTS 4.1 Electricity sales Since our electricity sales business was established in 2007, we have grown to be the 4th largest electricity supplier in Australia with our market share at approximately 8.7%7. We remain the only retailer licensed in all active Australian markets with a portfolio well balanced across the states. We see opportunity to increase our market share in all states in FY 2015. We started serving the small business segment on 1 July 2013. We secured a multi-site base load of approximately 10,000 small customers in NSW with a 3 year term and we continue to target further multi-site customers as part of our growth plans. In addition, we launched an online single site offering to small business customers in October 2013 which will be further leveraged with increased marketing spend in FY 2015. We now have 17,500 sites under contract across four states and expect similar levels of growth in FY 2015. We plan to replicate our large business success in the small business market by providing the same high quality service and value. We have established a gas retailing operation in Victoria and have signed our first customers. We will run this business on a trial basis over FY 2015 and if successful will roll this business out across other suitable markets. Gas retailing is a natural extension of our business customer retailing activities. We are leveraging our existing customer and intermediary network to access the market and are utilising our existing account management, operations and trading staff which will deliver a low cost entry. During the year, we undertook some benchmarking to identify prospective markets for expansion of our Business Energy model. We are currently undertaking a detailed feasibility study into expanding our electricity retail model to the United States market, which is approximately 8 times the size of the Australian market with similar structures and characteristics and active participation by foreign owned companies. The feasibility report is to be finalised by the end of 2014. 4.2 Generation The Oakey and Neerabup power stations occupy strategic peaking electricity supply positions in the markets in which they operate. Both plants are fully contracted to investment grade counterparties. Oakey will come off contract in January 2015 and became debt free in December 2013. We will utilise Oakey’s products internally and leverage vertical integration benefits, in addition to merchant sale and tolling opportunities. Neerabup is in the early years of its off-take and project financing arrangements and is expected to continue to operate and self- fund its debt servicing obligations until it too reaches the stage that Oakey is about to reach and be uncontracted and debt free. 7 ERM Power’s forecast league table for volume of electricity sold in the National Electricity Market (NEM) for FY 2014. The analysis draws on 2012 SRES scheme liability data, ERM Power signed contracts and broad assumptions about the market and participants. This is not an independently verified forecast. ERM POWER ANNUAL REPORT | 2014 4.3 Other (Gas, Metering and Corporate) Gas We continue to consider opportunities to realise full value from our gas business including transactions that will result in the business being able to attract external capital for future growth. Metering We have established a new business subsidiary Powermetric Metering Pty Ltd (“Powermetric”) to provide electricity metering services to C&I customers. During the year, the focus of our efforts has been on implementing the necessary information and data management systems, establishing key supplier relationships for meter provision and telecommunications and obtaining the necessary accreditation from the Australian Energy Market Operator. It is expected that operations will commence in the first half of FY 2015 once this accreditation is obtained. Initially this business will target our own customers but it is expected over time that we will offer services to all C&I customers irrespective of their chosen retailer. To ensure confidentiality of customer data and thereby enable the business to service other retailers and their customers, Powermetric is appropriately ring-fenced from our electricity sales business. 5. SAFETY, ENVIRONMENT AND COMMUNITY 5.1 Safety Our key safety vision is to achieve “Zero Harm” to any employee or contractor. Our safety performance is measured by recording the number of injuries experienced in a year. Our employees did not incur any lost time or permanent injuries during the year. This is an excellent achievement. One medical treatment injury to an employee, associated with manual handling, resulted in reduced duties for the employee for a period of two weeks. There were no injuries to contractors during the year. Our safety performance is the result of a commitment to implementing safety programs that focus on the key factors that could potentially lead to injuries. Our Health, Safety, Environment and Sustainability Policy provides a pathway to achieving “Zero Harm” in the workplace. 5.2 Environment Our key environmental value is to care for people and the planet, and our environmental performance is measured by recording the number of environmental incidents in a year, and monitoring carbon emissions and water usage. During the year we did not receive any penalty or correction notices from environmental authorities. Neerabup and Oakey’s carbon dioxide emissions were in line with expectations and the carbon emission intensity of the facilities were less than the average carbon emissions intensity in each state. An audit by the Clean Energy Regulator of our National Greenhouse and Energy Reporting (NGERs) for FY 2013 achieved a positive result. Water usage at our power stations is low in comparison to other technologies, with little domestic fresh water used in the operation of the facilities. There were no unexpected changes in water usage at Oakey and Neerabup during the year. 5.3 Community We are proud to contribute to the communities in which we operate through partnership and sponsorship programs. We have developed relationships and community partnership programs with local communities through resource donation, event sponsorship and the creation and support of local community initiatives. We are committed to building positive and long lasting relationships that harness community spirit, build local skills and leverage combined expertise to deliver tangible outcomes. We proudly support sporting groups, the arts, youth education, community and charitable organisations, both directly and through our partners. We are also passionately and directly involved in fundraising across the country for many of the community causes that are both close to home and close to our hearts. NON-IFRS FINANCIAL INFORMATION The directors believe the presentation of certain non-IFRS financial measures is useful for the users of this document as they reflect the underlying financial performance of the business. The non-IFRS financial measures include but are not limited to: 1. 2. EBITDAIF – Earnings before interest, tax, depreciation, amortisation, impairment and net fair value gains / losses on financial instruments designated at fair value through profit and loss and gains/losses on onerous contracts. Underlying Profit – Statutory net profit after tax attributable to equity holders of the Company after excluding the after tax effect of unrealised marked to market changes in the fair value of financial instruments, impairment and gains/losses on onerous contracts. A reconciliation of Underlying Profit and EBITDAIF is detailed in Appendix A1.1 of this document. The above non-IFRS financial measures have not been subject to review or audit. However, the Company’s auditor, PricewaterhouseCoopers, have separately undertaken a set of procedures to agree the non-IFRS financial measures disclosed to the books and records of the consolidated entity. The directors believe that EBITDAIF and Underlying Profit provide the most meaningful indicators of the Group’s underlying business performance. The Group is required to value its forward electricity purchase contracts at market prices at each reporting date. Changes in values between reporting dates are recognised as unrealised gains or losses in the particular reporting period. These fair value gains net of tax are the only adjustments made to Statutory Profit to arrive at statutory underlying profit for each of the years presented. PAGE 11 MANAGEMENT DISCUSSION AND ANALYSIS (CONT.) FOR THE YEAR ENDED 30 JUNE 2014 APPENDICES A1.1 Reconciliation of EBITDAIF to Underlying Profit FY 2014 $m Electricity sales Generation Other Group $m EBITDAIF Depreciation and amortisation FY 2014 FY 2013 Change Change % 74.2 69.8 4.4 6% Statutory EBITDAIF 41.8 51.8 (19.4) 74.2 Significant items a) New business (18.0) (14.0) (4.0) -29% establishment costs 2.8 – 1.1 3.9 Finance expense (29.3) (31.8) Underlying profit before tax 26.9 24.0 2.5 2.9 8% 12% Income tax benefit / (expense) attributed to underlying profit 30.9 (6.4) 37.3 N/A Non-controlling interest (0.8) (1.9) 1.1 58% Underlying profit after tax attributable to equity holders of the Company 57.0 15.7 41.3 263% Items excluded from underlying profit: – Net fair value gain on financial instruments (115.6) 29.8 (145.4) N/A – Tax credit on items excluded from underlying profit 34.7 (8.9) 43.6 N/A – Non-controlling interest 0.8 1.9 (1.1) -58% Statutory (loss) / profit after tax (23.1) 38.5 (61.6) N/A The reconciling items shown above are the unrealised changes in market values of financial instruments that the Group routinely enters into as part of risk management. A1.2 Reconciliation of significant items To allow shareholders to make an informed assessment of operating performance for the period, a number of significant items of revenue or expense in each period have been identified and excluded to calculate an adjusted underlying EBITDAIF and NPAT measure. These items may relate to one-off transactions or revenue or costs recognised during the period that are not expected to routinely occur as part of the Group’s normal operations. A reconciliation of adjusted EBITDAIF and adjusted underlying NPAT are shown in the tables following. b) Macquarie Generation bid costs c) Arbitration costs d) Legal fees in relation to Empire Oil action – – – – 6.1 6.1 (0.5) – (0.5) – 0.9 0.9 Total significant items Adjusted EBITDAIF 2.8 44.6 (0.5) 8.1 10.4 51.3 (11.3) 84.6 Statutory underlying NPAT Significant items EBITDAIF adjustments (above) e) Oakey term debt repayment costs f) Tax effect of Oakey minority interest buy out Tax effect of significant item adjustments Total significant items Adjusted underlying NPAT 22.0 52.0 (17.0) 57.0 2.8 (0.5) 8.1 10.4 – – 1.6 – 1.6 (39.1) – (39.1) (0.8) 2.0 (0.3) (2.4) (3.6) (38.3) 5.7 (30.7) 24.0 13.7 (11.3) 26.3 a) b) c) d) e) f) Costs incurred in respect of developing our capability to retail gas, serve the SME market and establish our metering business. Costs in respect to the bid for the Macquarie Generation assets. Costs net of contributions received in respect of the Neerabup contractor arbitration. Legal fees incurred in respect of changing the board of Empire Oil & Gas NL. Accelerated amortisation of capitalised debt establishment costs and swap break fee resulting from early repayment of Oakey term debt. Tax benefit resulting from buyout of Oakey minority interest resulting in the reset of tax cost base upon entry to ERM Power tax consolidated group. PAGE 12 ERM POWER ANNUAL REPORT | 2014 FY 2013 $m Electricity $m FY 2014 FY 2013 Change Change % sales Generation Other Group Development Investing Activities Statutory EBITDAIF 38.3 43.5 (12.0) 69.8 Significant items a) New business establishment costs b) Restructuring costs c) Arbitration costs Total significant items 3.4 0.3 – 3.7 – – 3.4 0.4 0.1 0.8 4.4 – 4.4 4.8 0.1 8.6 Adjusted EBITDAIF 42.0 48.3 (11.9) 78.4 Statutory underlying NPAT 21.5 4.4 (10.2) 15.7 Significant items EBITDAIF adjustments (above) d) Prospective depreciation adjustment Tax effect of significant item adjustments Total significant items 3.7 4.8 0.1 8.6 – (2.4) – (2.4) (1.1) 2.6 (0.7) (0.1) (1.9) 1.7 – 4.3 Adjusted underlying NPAT 24.1 6.1 (10.2) 20.0 a) Costs incurred in respect of developing our capability to sell electricity to SME customers and advertising and branding expenditure in respect of the advertising campaign and brand launch earlier in the financial year. b) Staff rationalisation costs. c) Costs in respect of the Neerabup contractor arbitration. d) Revision to the estimated useful lives of certain components of the power generation assets, which was applied prospectively from 1 July 2012. A1.3 Reconciliation of movements in cash and cash equivalents $m FY 2014 FY 2013 Change Change % Operating Activities EBITDAIF 74.2 69.8 4.4 6% Share-based payments 1.9 0.8 1.1 138% Net change in working capital (46.5) 40.7 (87.2) N/A Net tax paid (4.2) (6.6) 2.4 36% Net operating cash flows 25.4 104.7 (79.3) -76% Capital expenditure – development projects Capital expenditure – gas development Capital expenditure – gas exploration Capital expenditure – other PPE and Intangibles Net capital expenditure cash flows (1.9) (3.5) 1.6 46% (1.7) (8.0) 6.3 79% (3.0) (7.9) 4.9 62% (8.2) (14.6) 6.4 44% (14.8) (34.0) 19.2 56% Financing and other Investing Activities Repayment of corporate borrowings Drawdown of project borrowings Repayment of project borrowings Loan to Empire Oil & Gas NL Net drawdown of Electricity Sales borrowings Proceeds from issue of shares (1.5) (15.6) 14.1 90% – 1.5 (1.5) -100% (44.9) (19.8) (25.1) -127% (2.0) – (2.0) -100% 70.8 24.8 46.0 185% Purchase of shares (5.4) (6.7) 1.3 83.7 64.9 18.8 29% 19% Dividends paid (23.7) (15.5) (8.2) -53% Net cash cost of additional interest acquired in Oakey (30.0) – (30.0) -100% Net interest paid (25.3) (28.6) 3.3 12% Other financing and investing cash flows Net increase in cash Closing cash balances Free cash held in ERM Power 21.7 32.3 5.0 16.7 334% 75.7 (43.4) -57% 82.2 92.8 (10.6) -11% Free cash held in projects 5.0 2.1 2.9 138% Total free cash Restricted cash Total closing cash balances 87.2 94.9 (7.7) 160.5 120.5 40.0 -8% 33% 247.7 215.4 32.3 15% PAGE 13 MANAGEMENT DISCUSSION AND ANALYSIS (CONT.) FOR THE YEAR ENDED 30 JUNE 2014 A1.4 Power station assets $m FY 2014 FY 2013 Change Oakey power station (100% interest) Property, plant and equipment 226.8 234.1 (7.3) Net tangible assets 240.8 209.3 31.5 Change % -3% 15% Borrowings EBITDA EBIT – 38.9 (38.9) -100% 28.8 28.8 – 21.0 21.2 (0.2) Interest expense (3.3) (4.7) 1.4 Depreciation (7.8) (7.7) (0.1) $m FY 2014 FY 2013 Change Neerabup power station (50% interest) Property, plant and equipment 173.9 177.8 (3.9) Net tangible liabilities (8.6) (10.5) 1.9 Borrowings 201.6 204.5 (2.9) EBITDA EBIT 23.0 21.7 18.7 17.4 Interest expense (17.4) (17.8) Depreciation (4.3) (4.3) 1.3 1.3 0.4 – 0% -1% 30% -1% Change % -2% 18% -1% 6% 7% -2% 0% $m (unless indiciated) FY 2014 FY 2013 FY 2012 FY 2011 Electricity sales division statistics Load (TWh) 14.1 11.1 8.3 5.6 Total revenue excluding interest revenue 1,992.4 1,490.1 838.8 484.1 Contestable revenue 1,118.7 894.4 521.9 341.3 Gross margin 59.1 51.7 36.8 26.8 Operating expenses1 (17.9) (12.5) (8.7) (6.9) Gross margin ($) per MWh1 Operating expenses ($) per MWh1 4.20 4.67 4.45 4.79 (1.27) (1.13) (1.06) (1.24) EBITDAIF 41.8 38.3 30.9 22.5 Gas division statistics Exploration expenditure capitalised Development expenditure capitalised EBITDAIF Generation division statistics Revenue Oakey Neerabup 2.9 7.4 2.6 4.9 1.3 0.9 8.3 – – (0.8) (1.0) (0.5) 35.7 39.2 34.0 – 29.9 26.6 28.9 26.2 A1.5 Historical figures Generation Development and operations 7.9 6.9 8.1 29.6 $m (unless indiciated) FY 2014 FY 2013 FY 2012 FY 2011 Total revenue 73.5 72.7 71.0 55.8 Interest income by business division Electricity sales Generation Other Total interest income 3.3 0.8 2.2 6.3 2.9 0.7 2.3 5.9 3.6 1.0 2.8 7.4 2.6 0.7 1.3 4.6 Oakey2 Neerabup 28.8 28.8 27.4 1.4 23.7 21.7 23.6 21.5 Generation Development and operations (0.7) (7.0) (6.7) Discount on acquisition – – 19.1 6.1 – EBITDAIF 51.8 43.5 63.4 29.0 Corporate division statistics Revenue Interest revenue Other revenue Total Revenue Expenses EBITDAIF 2.2 1.6 3.8 2.3 1.5 3.8 2.8 2.6 5.4 1.3 6.0 7.3 (15.8) (15.0) (13.3) (11.9) (12.0) (11.2) (7.9) (4.6) 1 Excludes significant items - refer to MD&A for relevant financial year for further details. 2 Accounted for as an associate in FY 2011. PAGE 14 ERM POWER ANNUAL REPORT | 2014 GLOSSARY $m C&I Millions of dollars Commercial and Industrial Contestable Revenue EBITDAIF EBIT FY GWh IFRS MWh NEM NPAT Contestable revenue is the electricity sales revenue component on which we earn a margin and excludes pass-through items such as network charges. Earnings before interest, tax, depreciation, amortisation, impairment and net fair value gains / losses on financial instruments designated at fair value through profit and loss and gains/losses on onerous contracts. Earnings before interest and taxes Financial year ended or ending 30 June Gigawatt hours, abbreviated as GWh, is a unit of energy representing one billion watt hours International Financial Reporting Standards Megawatt hours, abbreviated as MWh, is a unit of energy representing one million watt hours The National Electricity Market Net profit after tax Oakey Tax Benefit Tax benefit resulting from buyout of Oakey minority interest allowing reset of tax cost base upon entry to ERM Power tax consolidated group SME TWh UMI Survey Underlying Profit Small to Medium Enterprise Terawatt hours, abbreviated as TWh, is a unit of energy representing one thousand gigawatt hours (GWh) Utility Market Intelligence (UMI) 2013 survey of retail electricity industry by independent research company The NTF Group in October and November 2013 (18th year of Survey). The 2013 UMI survey was based on a survey of 414 C&I customers, drawn in approximately equal proportions from the four major energy retailers. Statutory net profit after tax attributable to equity holders of the Company after excluding the after tax effect of unrealised marked to market changes in the fair value of financial instruments, impairment and gains/losses on onerous contracts. PAGE 15 In accordance with the Corporations Act 2001, the directors of ERM Power Limited (“Company”) report on the Company and the consolidated entity ERM Power Group (“Group”), being the Company and its controlled entities, for the year ended 30 June 2014 (“the year”). 1. PRINCIPAL ACTIVITIES The principal activities of the Group during the year were: • electricity sales to business; • generation of electricity; and • gas production and exploration. 2. OPERATING RESULTS FOR THE YEAR A review of the operating results of the Group can be found in the Management Discussion and Analysis (“MD&A”) on pages 4 to 15. 3. REVIEW OF OPERATIONS A review of the operations of the Group can be found in the MD&A on pages 4 to 15. 4. BUSINESS STRATEGIES AND PROSPECTS A review of the business strategies and prospects of the Group can be found in the MD&A on pages 4 to 15. 5. SIGNIFICANT CHANGES IN THE STATE OF AFFAIRS 5.1 Purchase of Oakey non-controlling interest and repayment of debt In December 2013 ERM Power successfully completed the acquisition of the remaining 16.67% interest in the Oakey Power Station (Oakey) that it did not already hold for $31.5m by exercising its option to acquire the interest. As a result of the completion of the acquisition, ERM Power has moved to full ownership of Oakey. Following acquisition of the remaining interest ERM repaid the associated term debt facility at a cost of $36.2m providing flexibility for funding growth in the future. ERM Power funded the acquisition and debt repayment through a $74.7m capital raising in November 2013. 6. EVENTS AFTER BALANCE DATE Since 30 June 2014 there have been no matters or circumstances not otherwise dealt with in the Financial Report that have significantly or may significantly affect the Group. DIRECTORS’ REPORT PAGE 16 ERM POWER ANNUAL REPORT | 2014 7. LIKELY DEVELOPMENTS AND EXPECTED RESULTS Apart from the matters referred to in the MD&A on 4 to 15, information as to other likely developments in the operations of the Group and the expected results of those operations in subsequent financial years has not been included in this report because the directors believe this could result in unreasonable prejudice to the Group. 8. PROCEEDINGS ON BEHALF OF THE COMPANY 11. DIRECTORS AND COMPANY SECRETARIES The directors of the Company during the year and up to the date of this report are: Anthony (Tony) Bellas Independent Non-Executive Chairman Trevor St Baker Non-Executive Deputy Chairman and Founder Martin Greenberg Independent Non-Executive Director Antonino (Tony) Iannello Independent Non-Executive Director No person has brought or intervened in on behalf of the Company with an application for leave under section 237 of the Corporations Act (2001). Philip St Baker Managing Director and CEO Brett Heading was a director from the beginning of the financial year until his resignation on 12 December 2013. 9. DIVIDENDS Subsequent to year end, the directors have declared a final dividend in respect of the 2014 financial year as follows: Amount: 6.0 cents per share Franking: Fully franked Date Payable: 13 October 2014 The dividend has not been provided for in the 2014 financial statements. During the year the Company paid an interim fully franked dividend of 6.0 cents per share (2013: 5.0 cents), together with a fully franked final dividend of 5.5 cents per share in respect of the previous year. 10. SHARE OPTIONS 10.1 Unissued shares As at the date of this report, there were 1,477,794 options on issue, exercisable into fully paid ordinary shares. The options do not carry any entitlement to participate in any share issue of the Company. In respect of those options with a 2017 expiry date, the options lapse on termination of employment, unless otherwise determined by the board. Expiry date Quantity Exercise price 1 November 2017 1,235,088 8 November 2017 242,706 275 cents 275 cents Information on Directors and Company Secretaries Anthony Bellas MBA, BEc, DipEd, ASA, FAIM, MAICD Tony was appointed as Chairman of the Company on 21 October 2011, having served as director since December 2009. He brings over 25 years of policy and operational experience in the energy industry to the business. Tony was previously CEO of the Seymour Group, one of Queensland’s largest private investment and development companies. Prior to joining the Seymour Group, Tony held the position of CEO of Ergon Energy, a Queensland Government- owned corporation involved in electricity distribution and retailing. Before that, he was CEO of CS Energy, also a Queensland Government-owned corporation and the State’s largest electricity generation company, operating over 3,500 MW of gas-fired and coal-fired plant at four locations. Tony had a long career with Queensland Treasury, achieving the position of Deputy Under Treasurer. In 2000, as an Assistant Under Treasurer, he was responsible for the Industry and Energy Division of Queensland Treasury and was heavily involved in formulating the State Government’s energy strategy. Tony is a director of the listed companies shown below and is also a director of Loch Explorations Pty Ltd, West Bengal Resources (Australia) Pty Ltd and the Endeavour Foundation. Other listed company directorships in the last three years: Shine Corporate Ltd Since March 2013 10.2 Shares issued on exercise of options No shares were issued during the year on the exercise of any options. Corporate Travel Management Limited Since June 2010 Guilford Coal Limited (December 2010 – June 2012) Special Responsibilities Chairman of the Nomination Committee and a member of the Audit and Risk Committee, the Remuneration Committee and the Health, Safety, Environment and Sustainability Committee. PAGE 17 DIRECTORS’ REPORT (CONT.) FOR THE YEAR ENDED 30 JUNE 2014 Trevor St Baker Martin Greenberg BEng, BA, FAusIMM, FIEAust, FAIE, MAICD Trevor founded ERM Power and is currently a Non-Executive Director and Deputy Chairman. Trevor has over 50 years of experience in the energy industry, including 23 years in planning and leadership roles within NSW and Queensland public utilities. These roles incorporated the establishment of the first Energy Resources Division in Queensland in 1975 and subsequent deregulation of power station fuel procurement in the State, development of Blackwater and Curragh steaming coal developments, and long term coal procurement to underpin the Gladstone, Tarong, Callide B and Stanwell power station developments. In 1980 Trevor founded companies which have evolved into ERM Power. For the first 15 years, as principal of ERM Consultants Pty Ltd, Trevor created a successful boutique energy consulting and advisory firm. In the late 1990’s, as Executive Chairman of Energy Resource Managers Pty Ltd, Trevor established one of Australia’s first private power development companies, developing firstly the Oakey power station, in Queensland, and then a further five new gas-fired power stations, in Western Australia, NSW and Queensland. Since 2006, ERM Power has successfully diversified to become an integrated energy company which operates electricity sales, generation and gas businesses. Trevor plays an active role in the broader energy industry with current positions including non-executive director roles on the boards of National Generators Forum Limited, Energy Policy Institute of Australia Limited, Queensland Resources Council Ltd, Sunset Power Ltd, Energy Resource Managers Holdings Pty Ltd, as well as new-start energy R&D companies: SMR Nuclear Technology Pty Ltd, Kortek Industries Pty Ltd, United States company NthDegree Technologies Worldwide Inc. and Tritium Pty Ltd (of which he is the Chairman). He also co-founded the St Baker Wilkes Indigenous Educational Foundation Limited, of which he is the Chairman. Special Responsibilities Member of the Audit and Risk Committee, and the Nomination Committee, and Chairman of the operating committee of NewGen Neerabup Partnership. BBus, DipCom, FCPA, JP, MAICD Martin was appointed as a director in July 2007, bringing finance credentials and business experience spanning 35 years. Martin is currently the Managing Director of Apollan Investments Group, a Sydney based company specialising in venture capital, corporate finance, securities, and general investment. He is also the current Chairman of Selector Funds Management Ltd. From 1986 to 1999, Martin was a director of Babcock & Brown, an international investment bank. Prior to this he was a director of Morgan Grenfell Australia Limited and a Senior Vice President with Security Pacific Group in London. Martin has been a director of several companies in Australia and New Zealand and has an extensive range of national and international contacts and experience, accumulated over the past 35 years. Special Responsibilities Chairman of the Audit and Risk Committee, and member of the Remuneration Committee and the Nomination Committee. Antonino Iannello BCom, FCPA, SFFSIA, Harvard Business School Advanced Management Program, FAICD Tony was appointed as a director in July 2010, bringing to the business more than 30 years of banking and energy experience. He is a director of the listed companies shown below. He is the Non-Executive Chairman of HBF Health Ltd, MG Kailis Group, and D’Orsogna Ltd. He is a director of St Baker Wilkes Indigenous Educational Foundation Limited, Water Corporation of Western Australia, and a member of The Murdoch University Senate. Prior to embarking on a career as a non-executive director, Tony was the Managing Director of Western Power Corporation until its separation into four separate businesses. Previously he held a number of senior executive positions at BankWest. Other listed company directorships in the last three years: Chairman of Empire Oil & Gas NL Since November 2013 Chairman of Energia Minerals Limited Since March 2010 SP Ausnet* Since June 2006 * The SP Ausnet “stapled group” of companies comprises SP Australia Networks (Distribution) Ltd, SP Australia Networks (Transmission) Ltd & SP Australia Networks (Finance) Trust. Special Responsibilities Chairman of the Remuneration Committee and member of the Audit and Risk Committee and Nomination Committee. PAGE 18 ERM POWER ANNUAL REPORT | 2014 Philip St Baker BEng, MAICD Philip was appointed as Managing Director and CEO in July 2006. Since this time the Group has transformed from a private power development company with annual turnover under $10m, into one of Australia’s fastest growing diversified energy companies listed on the Australian Securities Exchange with annual turnover in excess of $2 billion. Today the Group operates electricity sales, generation and gas businesses, and is well on its way to achieving its aspiration to become the preferred energy supplier to business customers across Australia. Philip has more than 20 years of international experience in the resources and energy industry including exploration, mining, processing, smelting, refining, power and gas. Prior roles also include Vice President of QNI, CEO of NewGen Power and Global Maintenance Manager of BHP Billiton. Special Responsibilities Chairman of the Heath, Safety, Environment and Sustainability Committee, the Group Operational Risk Committee and the Group IT Steering Committee. Former Director Brett Heading BCom, LLB (Hons), FAICD Brett was appointed as a director in October 2010 bringing extensive experience as a corporate lawyer and company director until his resignation on 12 December 2013. Brett has been a director of the listed companies shown below and a number of unlisted companies. Other listed company directorships in the last three years: Empire Oil & Gas NL Since November 2013 Invion Limited Since February 2012 Chairman of Trinity Limited Since August 2009 ChemGenex Pharmaceuticals Limited (June 2002 – July 2011) Special Responsibilities Member of the Remuneration Committee and Nomination Committee until 12 December 2013. Company Secretaries Peter Jans LLB (Hons), MA Peter joined the Group in July 2007 and was appointed as Company Secretary in March 2008. He is a member of the Queensland Law Society, Barrister and a Solicitor of the Supreme Court of Victoria and a Solicitor of the Supreme Court of Queensland and the High Court of Australia. He has practised as a lawyer for over 30 years in the corporate, property, international investment, energy and resource sectors. After an active career in private practice, Peter became General Counsel of CS Energy in the late 1990s and was involved in major electricity generation projects, including Callide C, Swanbank E and Kogan Creek. Peter was General Counsel and Company Secretary of Queensland Gas Company Limited from April 2005 until July 2007, during which period the company transformed from junior explorer to a major gas producer. Special Responsibilities Peter’s role and responsibility covers the whole of the Group’s broader business plans and portfolios, including business development, construction and operations, sales and gas activities. Peter is responsible for all aspects of the Group’s legal dealings, and for compliance and corporate governance. Graeme Walker BCom, CA, CA(SA), FAICD Graeme joined the Group in April 2009 and was appointed as joint Company Secretary in December 2009. As Chief Financial Officer, he is responsible for the financial management and control of the Group. Graeme has served as CFO of a number of major ASX-listed companies in the resources sector, including Normandy Mining Limited and Ampolex Limited, where he was involved in significant business growth and corporate activity. He subsequently provided consulting services to a number of companies, advising on financial and commercial services, as well as interim management. During this time he was also involved in the listing of a number of resource companies, as a non-executive director. PAGE 19 DIRECTORS’ REPORT (CONT.) FOR THE YEAR ENDED 30 JUNE 2014 12. MEETINGS OF DIRECTORS The number of meetings of the board of directors and each board committee held during the financial year, and the numbers of meetings attended by each director are as follows: Meetings of committees Board meetings Audit & Risk Nomination Remuneration A 20 18 19 7 18 20 B 20 20 20 8 20 20 A 7 7 8 ** 8 ** B 8 8 8 ** 8 ** A 2 2 2 1 2 ** B 2 2 2 1 2 ** A 4 ** 4 2 4 ** B 4 ** 4 3 4 ** Tony Bellas Trevor St Baker Martin Greenberg Brett Heading Tony Iannello Philip St Baker A = number of meetings attended. B = number of meetings held during the time the director held office during the year. ** = Not a member of the relevant committee. The Group has a Health, Safety, Environment and Sustainability Committee. Committee members include the Chairman, the Managing Director and other senior management. This committee met three times during the financial year. 13. DIRECTORS’ INTERESTS The relevant interest of each director in the share capital of the Company at the date of this report, as notified by directors to the ASX in accordance with Section 205G of the Corporations Act, is a follows: Tony Bellas Trevor St Baker Martin Greenberg Tony Iannello Philip St Baker Ordinary shares 106,250 85,610,647 571,794 131,644 Options to acquire ordinary shares – – – – 5,775,334 242,706 14. ENVIRONMENTAL REGULATION AND PERFORMANCE The Group’s environmental obligations are regulated by relevant federal, state and local government ordinances. During the year ended 30 June 2014, the Group did not experience any reportable environmental incidents and nor were there any breaches of any environmental licence conditions. 15. INDEMNIFICATION AND INSURANCE OF OFFICERS Insurance and indemnity arrangements are in place for directors and officers of the Group. Disclosure of premiums and coverage is not permitted by the contract of insurance. To the extent permitted by law, the Group indemnifies every person who is or has been an officer against: • any liability to any person (other than the Company, related entities or a major shareholder) incurred whilst acting in that capacity and in good faith, and • costs and expenses incurred by that person in that capacity in successfully defending legal proceedings and ancillary matters. For this purpose, “officer” means any company secretary or any person who makes or participates in making decisions that affect the whole, or a substantial part of the business of the Company or Group. PAGE 20 ERM POWER ANNUAL REPORT | 2014 16. AUDITOR’S INDEPENDENCE DECLARATION A copy of the auditor’s independence declaration as required under section 307C of the Corporations Act 2001 is included in the Annual Financial Statements which accompany this report. 17. NON AUDIT SERVICES Non-audit services provided by the Group’s auditors PricewaterhouseCoopers were in relation to advice and certain agreed upon procedures. The directors are satisfied that the provision of non-audit services is compatible with the general standard of independence for auditors imposed by the Corporations Act 2001. Amounts received or due and receivable by PricewaterhouseCoopers Australia for non-audit services: FY 2014 $ FY 2013 $ Other agreed-upon procedures in relation to the entity and any other entity in the consolidated Group1 1,196,808 199,930 1 For the year ended 30 June 2014 these services include due diligence services in relation to the Company’s bid to acquire the Macquarie Generation assets. 18. ROUNDING OF AMOUNTS The amounts contained in this report and in the financial report have been rounded to the nearest thousand dollars (where rounding is applicable) under the option available to the Group and the Company under ASIC Class Order 98/100. The Group and the Company are entities to which the class order applies. 19. REMUNERATION REPORT The Remuneration Report is attached and forms part of this report. This report is made in accordance with a resolution of the board of directors. Tony Bellas Chairman 21 August 2014 PAGE 21 The directors present the Remuneration Report for ERM Power Limited (“Company”) and its consolidated entities (“Group”) for the year ended 30 June 2014. 1. REMUNERATION FRAMEWORK 1.1 Role of the Remuneration Committee The Remuneration Committee ensures that the remuneration of directors and senior executives is consistent with market practice and is sufficient to ensure that the Company can attract, develop and retain the best individuals. The committee reviews the remuneration of the Managing Director and senior executives against the market, and against Group and individual performance. It also reviews non-executive directors’ fees against the market, with due regard to responsibilities and demands on time. The committee oversees governance procedures and policy on remuneration including: • General remuneration practices, • Performance management, • Equity plans and incentive schemes, and • Recruitment and termination. Through the committee, the board ensures that the Company’s remuneration philosophy and strategy continues to be focused to: • Attract, develop and retain first class director and executive talent, • Create a high performance culture by driving and rewarding executives for achievement of the Group’s strategy and business objectives, and • Link incentives to the creation of shareholder value. In undertaking its work, the committee seeks the advice of external remuneration consultants who provide analysis to ensure remuneration levels are set to reflect the market for comparable roles. In May 2013, the committee employed the services of Ernst & Young (“EY”) to provide benchmarking analysis and review the remuneration framework of the non-executive directors, the Managing Director and senior executives. While EY did not act as a Remuneration Consultant for the purposes of the Corporations Amendment (Improving Accountability on Director and Executive Remuneration) Act 2011, it provided benchmarking information and data to provide a frame of reference against which the committee could evaluate current remuneration levels. 1.2 Key Management Personnel Key Management Personnel (“KMP”) are those persons having authority and responsibility for planning, directing and controlling the activities of the Group, directly or indirectly and include directors of the Company. The term KMP refers to the following persons who were KMPs during the financial year. Unless otherwise indicated, they were KMPs for the entire year. REMUNERATION REPORT PAGE 22 ERM POWER ANNUAL REPORT | 2014 Non-Executive Directors Tony Bellas Trevor St Baker Martin Greenberg Tony Iannello Brett Heading (until 12 December 2013) Senior Executives Philip St Baker Managing Director and CEO William (Mitch) Anderson CEO – Electricity Sales Peter Jans Group General Counsel and Company Secretary Derek McKay CEO – Generation Graeme Walker Chief Financial Officer 2. REMUNERATION 2.1 Fees payable to Non-Executive Directors Fees are determined by the demands on, and responsibilities of directors and are reviewed annually by the board. Independent advice has previously been sought from remuneration consultants to ensure directors’ fees are appropriate and in line with the market. The latest review of fees was conducted in June 2014. Non-Executive directors’ fees are determined within an aggregate fee pool limit of $1,100,000, which was approved by shareholders at the Annual General Meeting held on 31 October 2013. Fees received by each director comprise a base fee together with additional fees dependent on the various offices they hold as set out in Table 1, with superannuation contributions made at the rates and limits prescribed from time to time by legislation. Non-Executive directors do not receive any performance-related remuneration. The May 2013 benchmarking evaluation resulted in an increase to the Chairman’s fees for financial year 2014 to align with the remuneration for that position in comparator group companies based on market capitalisation. The accounting value of fees paid to each non-executive director is shown in Table 2. Table 1 – Directors’ Fees Structure Non-Executive Director Fees (excluding superannuation) 2014 $ 2013 $ Table 2 – Directors’ Fees Short-term benefits Post- employment benefits Cash salary and fees $ Non- monetary benefits1 $ Super- annuation entitlement $ Total remuneration per income statement3 $ Tony Bellas 2014 200,000 10,510 17,775 228,285 2013 175,000 9,940 15,750 200,690 Trevor St Baker 2014 152,500 21,739 14,106 188,345 2013 165,000 19,910 14,850 199,760 Martin Greenberg 2014 130,000 2013 130,000 Brett Heading2 2014 53,826 2013 119,900 Tony Iannello 2014 125,000 2013 125,000 – – – – – – 12,025 142,025 11,700 141,700 – – 53,826 119,900 11,562 136,562 11,250 136,250 Total 2014 661,326 32,249 55,468 749,043 2013 714,900 29,850 53,550 798,300 1 Non-monetary benefits include car parking benefits and FBT. 2 From 1 July 2013 to 12 December 2013. 3 The value of remuneration consisting of options was nil in both FY 2014 and FY 2013. 2.2 Remuneration of Managing Director and Senior Executives The objective of the Company’s executive remuneration framework is to ensure that reward for performance is competitive and appropriate for the results delivered. The framework aligns executive remuneration with the achievement of strategic objectives and the creation of value for shareholders, and conforms to market practice. The board ensures that executive reward satisfies the following key criteria for good reward governance practices: • Competitiveness and reasonableness, • Acceptability to shareholders, • Performance linkage/alignment of executive remuneration, and Chairman 185,000 160,000 • Transparency. Non-Executive directors 105,000 105,000 Additional fees Audit Committee – chairman Audit Committee – member Remuneration Committee – chairman Remuneration Committee – member Representation on non-wholly owned subsidiary boards 20,000 10,000 10,000 5,000 Senior executives are remunerated by way of a mix of fixed and variable remuneration in a manner that motivates them to pursue the long term growth and success of the Group. The components of remuneration are: 20,000 10,000 • Base pay and benefits, including superannuation, 10,000 5,000 • Short term and long term incentives, and • Other cash or equity based discretionary incentives. 25,000 each 25,000 each PAGE 23 REMUNERATION REPORT (CONT.) FOR THE YEAR ENDED 30 JUNE 2014 Short term incentives are focused on achieving annual profit and operational targets, whilst long term incentives are focused on achieving long term growth. The board considers this combination an effective way to align incentives to shareholder value. In accordance with the objective of ensuring that executive remuneration is aligned to Group performance, a significant portion of executives target pay is at risk. The remuneration target is for a fixed remuneration level around the mean and a total remuneration close to or above the 75th percentile of comparator groups on achieving strong performance. Table 3 sets out the executives’ target remuneration mix for the 2014 financial year. Table 3 – Executive Target Remuneration Mix The trading of equities which vest under incentive schemes is required to comply with the Company’s Securities Trading Policy. This policy prohibits any employees or directors from entering into any scheme, arrangement or agreement under which the economic benefit derived by the employee or director, in relation to an equity– based incentive award or grant made by the Company is altered, irrespective of the outcome under that incentive award or grant, other than as permitted in any approved share or option plan, or as authorised by the board. For shareholders, benefits associated with the incentive schemes include: • Focus on performance improvement at all levels of the Group, with year-on-year earnings growth a core component, Base pay and super- annuation Target short term incentive Target long term incentive Total target remuneration • Focus on sustained growth in shareholder wealth, consisting share price growth, and delivering the greatest returns on assets, and Managing Director and CEO Other Senior Executives (ranges) 45% 25% 30% 100% 56-78% 18-29% 0-21% 100% 2.2.1 Base salary and benefits Remuneration and other terms of employment for the Managing Director and the other senior executives are formalised in service agreements. Each of these agreements specify the components of remuneration to which they are entitled and outline base salary, the provision of incentives, and other benefits including superannuation and salary continuance insurance. Remuneration is reviewed annually and external remuneration consultants are engaged periodically to provide analysis and advice to ensure executive remuneration is set at levels that reflect the market for comparable positions. Remuneration is also reviewed on promotion or change of role. There are no guaranteed base salary increases included in executive service agreements. Increases in base salary for the 2014 financial year were based on the expanded role and increased responsibilities assumed by some senior executives in line with the growth of the Company. The May 2013 benchmarking evaluation from EY formed the frame of reference against which the Remuneration Committee evaluated any proposed increases for senior executives. Table 5 at the end of this section provides details of total remuneration during the financial year to the Managing Director and each of the named executives. 2.2.2 Incentive Schemes Variable remuneration is in the form of short term (“STI”) and long term (“LTI”) incentives which represent at risk remuneration. STIs are paid annually against agreed key performance indicators (“KPIs”) which are designed to align the interests of the Company and its shareholders. Achievement is assessed annually. LTIs are accrued over a number of years and earned through satisfaction of performance and service conditions. STIs are paid in the form of cash or equity, or a combination of these. LTIs are paid in the form of equity. • The ability to attract and retain high calibre executives. For employees, benefits associated with the incentive schemes include: • Provision of clear targets, stretch targets and structures for achieving rewards, • Recognition and reward for achievement, capability and experience, and • Delivery of reward for contribution to growth in shareholder wealth. KPIs include both financial and non-financial measures using a balanced scorecard approach, and reflect the key measures of success as determined by the board. These include, but are not limited to, a range of measures such as: • Zero Harm – safety and environment performance measures, including lost time and medically treated injury frequency rates, • Financial Measures – including earnings before interest, tax, depreciation, amortisation and net fair value changes in financial instruments, cash flow management, etc., and • Market based – shareholder returns, earnings per share, etc. Short term incentives STIs are provided to most employees. They have three components; individual, team and corporate. Each of these components is allocated a weighting and include both targets and stretch targets that are set at the beginning of each financial year. The Managing Director’s targets and the corporate targets are set by the board, whilst the individual and team targets are set under the direction of the Managing Director. At the end of each financial year, achievement of targets is measured and applied against the target rate determined for each individual. These rates range between 10% and 40% of annual average base salary, with the potential to achieve up to 150% of these levels (i.e. 15% to 60%). STIs are calculated and paid following adoption of the Group’s annual financial results. Payment may be offered by way of cash and/or equity at the election of the board. Any equity vests immediately. PAGE 24 ERM POWER ANNUAL REPORT | 2014 Based on the achievements of the Group’s results for year ending 2013, the remuneration committee determined that the financial performance exceeded targets and awarded 108% of the target opportunity for the Managing Director. The corporate target award for the 2013 STI was also 108%. In making this assessment, the committee included the following factors in its considerations: • achievement of Underlying NPAT above expectations, • continuing strong growth in the electricity sales business, • successful execution of strategic initiatives, • successful restructuring and overhead reduction, • restructure of the Group’s gas businesses, and streamlining board reporting activities. Table 4 provides details of the STIs paid to KMPs in the current financial year following the outcome of 2013 results and the comparatives for the 2012 STI paid in the 2013 financial year. Table 4 – STI Achievement Long term incentives LTIs are provided to selected employees in the form of equity via the Company’s Long Term Incentive Share Trust (“LTIST”). If a participant’s employment ceases prior to the shares vesting, the board will determine if the participant’s units in the LTIST will continue to be held to the end of the performance period. This may occur depending on the circumstances of ceasing employment (redundancy, retirement, death or permanent disability, or in circumstances that the board determines appropriate). Units are forfeit on voluntary resignation. An LTI issue was made in the 2014 financial year with vesting subject to continuation of employment through to 30 June 2016 and total security holder return (“TSR”) performance. The TSR vesting condition will be determined by ERM Power’s relative TSR performance over the three year period commencing 1 July 2013, measured against the TSR performance of a comparator group being those companies in the Standard & Poor’s (S&P) ASX 300 index. At the end of the three year period, TSR vesting is granted on the following basis: 2013 STI Paid in FY 2014 2012 STI Paid in FY 2013 • Less than or equal to 50th percentile = 0% • Greater than 50th to less than the 75th percentile = 50% Actual Maximum Actual Maximum to 100% (linear) • 75th percentile and higher = 100%. The LTI target rate determined for each individual is based on a percentage of annual average base salary, and for the 2014 financial year it was based on the maximum awards of 75% for the Managing Director, 40% for other executive KMP and 30% for other selected senior executives. The corresponding equity is issued into the LTIST and will vest subject to evaluation of the performance condition assessed at 30 June 2016. Early vesting may occur on a change of control of the Company, being a material change in the composition of the board initiated as a result of a change of ownership of shares and the purchaser of the shares requiring (or agreeing with other shareholders to require) that change in board composition, or in other circumstances that the board determines appropriate. Section 3.1 details the equity allocated to executive KMP in the current and prior financial year, and for which the allocation to Philip St Baker was approved by shareholders at the 2013 and 2012 Annual General Meetings respectively. For accounting purposes, long term incentives are expensed over the performance period and incorporated within tables 5 and 7. Philip St Baker Mitch Anderson Peter Jans Derek McKay Graeme Walker 43% 33% 32% 33% 33% 60% 45% 45% 45% 45% 51% 38% 38% 42% 37% 60% 45% 45% 45% 45% The Managing Director’s corporate target for the 2014 financial year includes the following elements and weightings as set by the remuneration committee at the beginning of the financial year, and align to the Group’s strategic and business objectives. These objectives and weightings are reviewed annually: • 40% profit delivery against guidance expectations, • 20% positioning of the Company by increases in customer growth, • 25% execution of board approved strategies, • 10% improved stock liquidity and broader investor base, • 5% for successful talent management including succession plans and board reporting activities, and • Deductions of 30% may apply if safety or compliance targets or other governance standards are not met. The remuneration committee is responsible for determining the STI to be paid based on an assessment of whether the KPIs are met. To assist in this assessment, the committee receives detailed reports on performance from management. The committee has the discretion to adjust short-term incentives downwards in light of unexpected or unintended circumstances. Although a general provision has been made for incentive payments for FY 2014, to be paid in FY 2015, the allocation of payments to specific individuals and the form, whether to be taken in cash or equity, has not yet been determined. Any equity grants to the Managing Director will be subject to shareholder approval at the 2014 Annual General Meeting. PAGE 25 REMUNERATION REPORT (CONT.) FOR THE YEAR ENDED 30 JUNE 2014 Table 5 – Executive Remuneration Expensed in Income Statement Supplementary Information6 Short term benefits Non monetary benefits and annual leave accrual3 $ Base salary cash2 $ Post- employment benefits Long term benefits Short-term incentive4 $ Super- annuation entitlement $ Other equity benefits5 $ LSL Accrual $ Total remuneration per income statement6 $ % related to the value of options Less: Long term benefits and annual leave accounting accruals $ Add: Vested Other equity-based payments $ Total remuneration vested $ Philip St Baker1 Mitch Anderson 2014 660,031 45,286 257,96 c 61,053 352,787 19,904 1,397,022 0% (411,903) 94,388 1,079,507 2013 597,133 57,235 297,110 c 53,742 253,917 22,563 1,281,700 0% (322,078) 72,508 1,032,130 2014 439,725 33,875 121,293 e 40,675 128,773 17,223 781,564 0% (142,641) 41,367 680,290 2013 366,438 18,545 136,741 c 32,979 97,438 7,125 659,266 0% (93,770) 31,779 597,275 Peter Jans 2014 374,004 8,610 118,974 c 34,595 124,172 10,146 670,501 0% (140,636) 41,454 571,319 Derek McKay Graeme Walker 2013 367,211 6,390 137,033 c 33,049 97,644 14,602 655,929 0% (116,375) 31,844 571,398 2014 373,216 24,758 119,459 c&e 34,522 123,911 9,785 685,651 0% (155,781) 41,367 571,237 2013 366,438 4,667 149,257 c 32,979 97,438 16,521 667,300 0% (116,039) 31,779 583,040 2014 363,000 4,007 109,231 e 33,578 110,794 15,781 636,391 0% (128,291) 36,050 544,150 2013 330,000 (2,743) 111,261 c 29,700 84,550 643 553,411 0% (80,190) 27,694 500,915 1 Managing Director & CEO. 2 Each executive is employed under an on-going employment contract, for which the termination benefits are payable at the option of the Company in lieu of notice (other than termination for cause) on the basis of 6 months’ salary, with the exception of the Managing Director, whose termination benefit is provided as 12 months salary in lieu of notice. 3 Non monetary benefits include salary continuance insurance premiums, use of company vehicle, car parking and other benefits with associated FBT. 4 The short term incentive paid relates to performance in the previous year. Payments were made in cash(“c”) or equity (“e”). 5 Other equity benefits refer to the accounting value of retention awards or long term incentives paid in equity which will vest subject to service and performance conditions. 6 The amounts shown are as expensed in the income statement may not reflect the benefit actually received by the executive in that year. In accordance with AASB2, Other equity benefits include a portion of the value of equity that has not vested during the financial year as well as the present value of expected dividends over the vesting period. The amount included as remuneration does not necessarily reflect the benefit (if any) that may ultimately be realised by the executive if vesting occurs. Supplementary Information is provided to reflect the value of vested remuneration actually received by the executive in that year. Table 6 – Terms and conditions of equity grants The terms and conditions of each grant of a cash bonus, performance-related bonus or share-based compensation benefit affecting compensation of disclosed executives in the current or a future reporting period are as follows: Grant date Nature of compensation Service and performance criteria Changes in terms or conditions since grant date % Paid in FY 2014 % Vested in FY 2014 % Forfeited in FY 2014 Vesting Nov-13 Long term incentive LTIST See Remuneration Report section 2.2.2 Sept-13 Short term incentive 2013 Cash or STIST See Remuneration Report section 2.2.2 N/A 100% – N/A 100% 100% – – – – After 30 June 2016 Vested After 30 June 2015 After 2014 Financial Statements are signed. N/A – 0% N/A N/A – – 0% 100% 0% Vested Nov-12 Long term incentive Nov-11 Long term incentive LTIST LTIST See 2013 Remuneration Report section 2.2.2 See 2012 Remuneration Report section 2.2.2 Nov-10 Other incentive IPO Retention Service condition only PAGE 26 ERM POWER ANNUAL REPORT | 2014 A detailed breakdown of the accounting expense of long term equity benefits to disclosed executives, and the maximum value of the grant that may vest in future financial years is shown in Table 7. Table 7 – Long Term Equity Benefits Executive Remuneration Expensed in Income statement2 Supplementary Information2 Long-term Equity Benefits Philip St Baker1 FY 2017 2016 2015 2014 2013 Mitch Anderson 2017 Peter Jans Derek McKay 2016 2015 2014 2013 2017 2016 2015 2014 2013 2017 2016 2015 2014 2013 Graeme Walker 2017 2016 2015 2014 2013 1 Managing Director & CEO. Long-term Incentive Other Incentives: IPO Retention Remuneration per income statement Long-term Incentive Other Incentives: IPO Retention Long Term Equity Benefits Vesting $ – 140,841 275,067 346,992 213,428 – 50,286 94,206 126,255 79,862 – 42,771 86,804 121,649 80,031 – 42,681 86,621 121,393 79,862 – 41,512 81,074 108,600 69,233 $ – – – 5,796 40,489 – – – 2,518 17,576 – – – 2,523 17,613 – – – 2,518 17,576 – – – 2,194 15,317 $ – 140,841 275,067 352,788 253,917 – 50,286 94,206 128,773 97,438 – 42,771 86,804 124,172 97,644 – 42,681 86,621 123,911 97,438 – 41,512 81,074 110,794 84,550 $ 371,342 360,314 316,396 – – 132,586 117,927 129,440 – – 112,769 118,176 129,713 – – 112,533 117,927 129,440 – – 109,450 106,200 109,617 $ – – – 94,388 72,508 – – – 41,367 31,779 – – – 41,454 31,844 – – – 41,367 31,779 – – – – – 36,050 27,694 $ 371,342 360,314 316,396 94,388 72,508 132,586 117,927 129,440 41,367 31,779 112,769 118,176 129,713 41,454 31,844 112,533 117,927 129,440 41,367 31,779 109,450 106,200 109,617 36,050 27,694 2 The amounts shown are as expensed in the income statement but do not reflect the benefit actually received by the executive in each respective year. In accordance with AASB2, these amounts represent a portion of the value of equity that has not vested during financial year as well as the present value of expected dividends over the vesting period. The amount included as remuneration does not necessarily reflect the benefit (if any) that may ultimately be realised by each executive if vesting occurs. Supplementary Information is provided to reflect the maximum vested long-term equity benefit receivable by each executive. PAGE 27 REMUNERATION REPORT (CONT.) FOR THE YEAR ENDED 30 JUNE 2014 3. ADDITIONAL REMUNERATION DISCLOSURES Details of shares, options and rights 3.1 The number of shares and options held at the date of this report by each director of the Group are disclosed in Section 13 of the Directors’ Report. No options were issued, lapsed nor exercised during financial year 2014. The numbers of options over ordinary shares in the Company granted under the executive incentive schemes that were held during the financial year by each director and other disclosed executives of the Group, including their related parties, are set out below: Balance at the start of the year Balance at the end of the year Vested and exercisable Unvested Granted as compensation Options Exercised Other Changes1 Vested and exercisable Unvested – – – 354,726 242,706 – – – – – 833,870 242,706 106,364 – 196,872 106,364 106,590 – 429,754 106,590 106,364 – 125,000 106,364 92,700 30,000 – 92,700 – – – – – – – – – – – – – – – – – (833,870) – – – – – – – – – – (10,000) 10,000 – (354,726) – – – – – – – 242,706 242,706 106,364 (196,872) 106,364 – 106,590 (429,754) 106,590 – 106,364 (125,000) 106,364 – (30,000) 92,700 92,700 – – – – – – – – – – – – – – Table 8 – Option holdings Trevor St Baker1 Martin Greenberg Philip St Baker Mitch Anderson Peter Jans Derek McKay Graeme Walker 2014 2013 2014 2013 2014 2013 2014 2013 2014 2013 2014 2013 2014 2013 1 Options bought or sold. PAGE 28 ERM POWER ANNUAL REPORT | 2014 The numbers of shares in the Company held during the financial year by each director and other disclosed executives of the Group, including their related parties, are set out below: Table 9 – Share holdings Balance at the start of the year Vested Unvested Granted as compensation Options Exercised Other Changes1 Balance at the end of the year Vested Unvested Balance at the end of the year held nominally Tony Bellas Trevor St Baker Martin Greenberg Brett Heading Tony Iannello Philip St Baker Mitch Anderson Peter Jans Derek McKay Graeme Walker 2014 2013 2014 2013 2014 2013 2014 2013 2014 2013 2014 2013 2014 2013 2014 2013 2014 2013 2014 2013 106,250 100,000 85,200,647 85,752,905 571,794 571,794 14,285 14,285 125,694 114,285 – – – – – – – – – – – – – – – – – – – – – – – – 106,250 6,250 106,250 410,000 85,610,647 10,000 (562,258) 85,200,647 – – – – – – 571,794 571,794 (14,285) – – 14,285 5,950 131,644 11,409 125,694 – – – – – – – – – – 5,436,583 531,439 186,604 – (379,292) 5,111,227 664,107 4,176,926 319,630 238,777 833,870 398,819 5,436,583 531,439 979,672 199,452 116,955 967,852 133,123 224 199,873 205,885 133,403 272,014 199,452 260,194 133,123 – 173,686 467,446 113,608 78,149 56,668 78,314 66,698 78,149 100,324 70,378 – – – – – – – – 6,250 1,059,889 242,440 – – 979,672 199,452 23,912 232,853 (217,505) 224 199,873 – – – 305,801 232,363 272,014 199,452 65,834 208,176 (477,746) – 173,686 1 On and off market movements, dividend reinvestment plan, cessation of directorship, etc. – – 1,025,242 1,025,242 – – – – – – – 804,288 798,038 – – – – – – PAGE 29 REMUNERATION REPORT (CONT.) FOR THE YEAR ENDED 30 JUNE 2014 3.2 Loans to directors and employees Details of loans made to key management personnel and related parties of the Group, are set out below: Aggregate amounts 2014 2013 Individuals with loans above $100,000 during the financial year 2014 Philip St Baker Mitch Anderson 2014 Total 2013 Philip St Baker Mitch Anderson 2013 Total Balance at the start of the year Interest paid and payable for the year Interest not charged Balance at the end of the year $ 1,029,380 1,167,039 $ 47,523 75,854 $ – – $ 670,444 1,029,380 Balance at the start of the year Interest paid and payable for the year Interest not charged Balance at the end of the year Number in Group at the end of the year 4 4 Highest indebtedness during the year $ $ 589,331 212,240 801,571 687,254 223,853 911,107 23,863 12,651 36,514 44,842 14,326 59,168 $ – – – – – – $ $ 308,368 203,568 511,936 589,331 212,240 801,571 589,331 215,492 699,210 227,583 The above loans represent employee shareholder loans that were offered to certain senior executives in 2007 and 2008 to participate in a share loan incentive plan which enabled them to subscribe for shares. The loans are subject to loan deeds and are interest bearing at either the FBT or Division 7A benchmark rates with recourse limited to the value of the shares. The loans are repayable in the event of cessation of employment or otherwise between seven and ten years from the date of advance. No write-downs or allowances for doubtful receivables have been recognised in relation to any of these loans. PAGE 30 ERM POWER ANNUAL REPORT | 2014 3.3 Share price and consequences of performance on shareholder wealth The Company’s shares were listed on the ASX in December 2010 at a listing price of $1.75. Table 10 shows selected Group financial data for the current and previous years, and the effect of the Group’s performance on shareholder value. Table 10 – Shareholder Wealth Financial Data Revenue and other income EBITDAIF1 Net (Loss) / Profit After Tax2 Underlying Net Profit After Tax2 Basic (Loss) / Earnings per Share Underlying Earnings per Share3 Dividend per share Closing share price at 30 June ($’000) ($’000) ($’000) ($’000) (cents) (cents) (cents) ($) Year ended 30 June 2014 Year ended 30 June 2013 Year ended 30 June 2012 Year ended 30 June 2011 Actual 2,076,537 74,238 (23,897) 57,001 (10.56) 25.2 12.0 1.82 Actual 1,569,570 69,821 36,539 15,671 20.8 8.9 10.5 2.50 Actual 937,926 85,390 34,156 30,311 20.7 18.4 8.5 2.00 Actual 549,814 46,407 16,176 6,245 11.7 4.5 3.5 1.57 1 EBITDAIF is Earnings Before Interest, Tax, Depreciation, Amortisation, Impairment and fair value gains/losses on Financial instruments. 2 NPAT and Underlying Net Profit After Tax attributable to equity holders of the Company. 3 Includes the $39.1m Oakey tax benefit in 2014 and the $19.1m discount on acquisition in 2012. 3.4 Voting and comments received at the 2013 Annual General Meeting The Company’s Remuneration Report for the 2013 financial year was approved by shareholders at the 2013 Annual General Meeting by a show of hands. The Company did not receive any specific feedback at the AGM or during the year on its remuneration practices. PAGE 31 CORPORATE GOVERNANCE STATEMENT COMPLIANCE WITH ASX CORPORATE GOVERNANCE PRINCIPLES AND RECOMMENDATIONS PAGE 32 ERM Power Limited’s (“Company”) board and management are committed to achieving and demonstrating the highest standards of corporate governance. The board continues to review the framework and practices to ensure they meet the interests of shareholders. The Company and its controlled entities together are referred to as the ERM Power Group (“Group”) in this statement. A description of the Group’s main corporate governance practices is set out below. All these practices, unless otherwise stated, were in place for the entire year. The Company complies with all of the ASX Corporate Governance Principles and Recommendations (“Guidelines”). Principle 1 – Lay solid foundations for management and oversight The role of the board and ability to delegate to management has been formalised in the Company’s Board Charter. The Board Charter, along with other charters and policies, can be found on the Company’s website. The charter is reviewed and amended from time to time taking into consideration practical experience gained in operating as an ASX listed company. The Company complies with this Principle of the Guidelines. The Managing Director has made delegations to senior executives related to the Company’s day to day affairs, within set limits and which delegations may be withdrawn or amended by the Managing Director at any time, within Legal, Financial, Electricity Sales and Generation areas. At the time of joining the Company, directors and senior executives are provided with letters of appointment, together with key Company documents and information setting out their term of office, duties, rights and responsibilities, and entitlements on termination. The performance of all senior executives, including the Managing Director, is reviewed annually against: a) A set of personal, financial and non-financial goals; b) Company goals; and c) Adherence to the Company’s policies, commitments, values and principles. The Remuneration Committee reviews and recommends the Managing Director’s remuneration package and incentive payments. The Remuneration Committee also approves the fixed remuneration and incentive packages for all senior executives (the “Executive Management Team”) with reference to external benchmarking indicators. Further information on senior executive remuneration is contained in the Remuneration Report. Principle 2 – Structure the board to add value At the end of the 2014 financial year, the Company had a five member board comprising an independent non-executive Chairman, two independent non-executive directors, a fourth non-executive director and a Managing Director. The Company seeks to have directors with a broad range of experience, expertise, skills, qualifications and an understanding of, and competence to deal with, current and emerging issues of the Company’s business. The Company’s succession plans are designed to maintain an appropriate balance of skills, experience and expertise on the board. The director’s profiles, period in office, and details of their skills, experience, and special expertise are set in the Directors’ Report. ERM POWER ANNUAL REPORT | 2014 Principle 2.1 of the Guidelines states that the majority of the board should be independent directors. The board considers each director’s independence on a regular basis and formed the view that for the FY 2014 reporting period, Tony Bellas, Martin Greenberg, Tony Iannello and Brett Heading1 were independent. In defining the characteristics of an independent director, the board uses the Guidelines, together with its own consideration of the Company’s operations and businesses and appropriate materiality thresholds in any relationship that could materially interfere, or be perceived as interfering with the exercise of an unfettered independent judgement in relation to matters concerning the Company. Despite being a partner of a law firm that provides material professional advice to ERM Power and its related entities, the board nevertheless considered Brett Heading to be independent as he had not been directly involved in the provision of any legal advice, or the management of any legal matters involving the Company. The board schedules a minimum of six meetings a year. If required, additional unscheduled meetings are held to deal with urgent matters. An agenda is prepared for each board meeting by the Company Secretary to ensure operational, financial, strategic, regulatory and major risk areas are addressed. Executive management also provide the board each month with an operations report, a health, safety, environment and sustainability report, financial reports and reports on major projects under construction and, as appropriate, on other Company and operational matters. All directors have unfettered access to any of the Company’s records and information they consider necessary to fulfil their responsibilities, and the board may invite external advisers to attend board meetings where necessary or desirable. The Audit & Risk Committee, Remuneration Committee, Health, Safety, Environment & Sustainability Committee and Nomination Committee each has a charter which sets out its roles and responsibilities, composition, structure, membership requirements and operation. These are available on the Company’s website. Committee meeting minutes are tabled at the following board meeting. A list of the members of each committee and their attendance at committee meetings is set out in the Directors’ Report. The Nomination Committee provides advice and makes recommendations to the board to ensure that it is comprised of individuals who are best able to discharge the responsibilities of directors, having regard to the law and the highest standards of governance by: • assessing the skills required by the board and the extent to which the required skills are represented on the board; • establishing processes for the review of the individual directors and the Chairman specifically, and the board as a whole; • establishing processes for the identification of suitable candidates for appointment to the board as additional members or to succeed existing members and reviewing board succession plans; • reviewing and reporting, at least annually, on the relative proportion of women and men on the board; and • making recommendations to the board on directors’ appointments or board and committee structures. 1 Resigned in December 2013 Each year, one-third of the board, other than the Managing Director, retires in accordance with the constitution, and is eligible for re-election by shareholders at the annual general meeting (AGM). At the Company’s AGM, on 30 October 2014, Tony Bellas and Martin Greenberg will be retiring and standing for re-election. The board unanimously supports their re-election. Prior to the AGM each year the Nomination Committee evaluates any new directorship nominations, and evaluates the performance of those directors retiring by rotation; the results of which form the basis of the boards’ recommendation to shareholders. The board’s recommendation on the re-election of Tony Bellas and Martin Greenberg will be included in the Notice convening the AGM. Every year, through the Nomination Committee, the directors review the performance of the whole board and board committees. The review considers a director’s expertise, skill and experience, along with his/her understanding of the Company’s business, preparation for meetings, relationships with other directors and management, awareness of ethical and governance issues, and overall contribution. In July 2013 a full review was undertaken covering the board’s activities and work program, time commitments, meeting efficiency and board contribution to Company strategy, monitoring, compliance and governance. Principle 3 – Promote ethical and responsible decision making The board strongly encourages ethical and responsible decision making and has implemented policies to achieve this while in pursuit of the Company’s objectives. In particular, the Code of Business Conduct (“the Code”) and the Securities Trading Policy that have been fully endorsed by the board continue to apply to all directors and employees. The Company encourages employees to report known or suspected instances of inappropriate conduct, including breaches of the Code or the Securities Trading Policy. There are policies in place to protect employees from any reprisal, discrimination or being personally disadvantaged as a result of their reporting of a concern. A copy of the Code and the Securities Trading Policy are available on the Company’s website along with other corporate governance policies of the Company. The purpose of these documents and all Company policies are to guide directors and employees in the performance of their duties, set appropriate restrictions on the trading of securities by directors, employees and their associates, and to the Company’s employees who wish to report in good faith inappropriate behaviour or wrongful acts without fear of retaliation or punishment. Responsibility for diversity has been included in the Nomination Committee charter (board diversity) and the Remuneration Committee charter (diversity at all levels of the Company, excluding the board). The board has adopted a Diversity Policy which is available on the Company’s website with the following measurable objectives: • ensure diversity programs reflect the Company’s policy and approach to diversity and ensure they are communicated to all employees; • review all recruitment and remuneration practices to ensure they are free from gender bias and encourage greater female participation and opportunity; PAGE 33 CORPORATE GOVERNANCE STATEMENT (CONT.) • identify high talent women at low to middle management level and implement specific strategies to enhance the skills and experience of these people to prepare them for advancement; and • encourage female applicants for all roles, but specifically technical roles where representation is low, and seek at least one female candidate for the shortlist for each technical role. During FY 2014, the Company has developed a comprehensive guide on key policy and process administration which incorporates specific diversity compliance. Diversity based conversations within the Executive Management Team have been fostered and a review of remuneration by gender identified differences to be related to other factors, such as experience, tenure and complexity of the role. The effectiveness of these and other activities taken during FY 2014 can be assessed by the increase in the proportion of women employed by the Company and at senior executive levels at the end of the financial year as shown below: Board (excluding the MD) Senior executives2 TOTAL FY 2014 FY 2013 Change 0% 12% 35% 0% 10% 30% 0% 2% 5% New reporting requirements began on 1 April 2013 which incorporate a revised workplace profile and a reporting questionnaire for each of the ‘gender equality indicators’ (GEIs). A copy of the Company’s public report for the year ended March 2014 that was lodged with the Workplace Gender Equality Agency is available on the Company’s website. Principle 4 – Safeguard integrity in financial reporting The Company has an Audit and Risk Committee compliant with Principle 4 which consists of four non-executive directors, Tony Bellas, Martin Greenberg (Chairman), Tony Iannello and Trevor St Baker, three of which are independent directors. The charter is available on the Company’s website and contains information on the procedures for the selection and appointment of external auditors and for the rotation of external audit engagement partners. The Audit and Risk Committee reviews and discusses with management and the external auditors the half-yearly and annual financial reports including notes to the financial accounts and other disclosures and recommends to the board whether the financial reports should be approved. The Audit and Risk Committee monitors the adequacy, integrity, and the effectiveness of, management processes that support financial reporting. It also maintains and oversees a sound system of internal controls based on the adoption by the board of a risk- based approach to the identification, assessment, monitoring and management of risks that are significant to the fulfilment of the Company’s business objectives. The qualifications of the members of the Audit and Risk Committee and their attendance at meetings of the Committee are set out in the Directors’ Report. 2 Senior executives include the CEO, other executives/general managers and senior managers as defined by the Workplace Gender Equality Agency (WGEA) management categories. PAGE 34 Principle 5 – Make timely and balanced disclosure The Company’s current practice on disclosure is consistent with the Guidelines. The board has adopted a Continuous Disclosure Policy and procedures are in place to ensure compliance with ASX Listing Rule disclosure requirements. The Continuous Disclosure Policy and the Shareholder Communication Policy are available on the Company’s website. All material presentations by the Company are released to the ASX and posted on the Company’s website. Principle 6 – Respect the rights of shareholders The Company is committed to providing regular communication to shareholders about the financial performance of ERM Power and its business and operations. Annual reports are able to be accessed by shareholders via the Company’s website, with a hardcopy able to be mailed out on request. The board will communicate with shareholders regularly and clearly by electronic means as well as by traditional methods. Shareholders are encouraged to attend and participate at general meetings. The Company’s auditor will attend the annual general meeting and will be available to answer shareholders’ questions. The Company’s policies comply with the Guidelines in relation to the rights of shareholders. All announcements to the ASX are posted on the Company’s website. The Company attempts to keep its website as current and informative as possible for shareholders and other stakeholders, including any update on its current projects. The Shareholder Communication Policy is available on the Company’s website. Principle 7 – Recognise and manage risks The board, through the Audit and Risk Committee, has an overarching policy governing the Company’s approach to risk oversight and management and internal control systems, the Risk Management Framework Policy which is available on the Company’s website. The board is also responsible for ensuring that there are other appropriate policies in relation to risk management and internal control systems. The Company’s policies are designed to identify, assess, address and monitor strategic, operational, legal, reputational, commodity and financial risks to enable it to achieve its business objectives. Where appropriate, certain risks are covered by insurance or by board-approved policies for hedging of interest rates, foreign exchange rates and commodities. In this respect, the Company complies with Principle 7.1. Board, executive and business unit level controls are designed to safeguard Company and stakeholders’ interests in respect of those risks mentioned above. Each Executive Management Team member is responsible for communicating to their team the risk framework and structure required by the board and the Audit and Risk Committee. The Chief Financial Officer is responsible for reporting to the board and the Audit and Risk Committee about the management of the Company’s material business risks, and the board has received a report from the Chief Financial Officer that as at 30 June 2014 its material business risks are being managed effectively. ERM POWER ANNUAL REPORT | 2014 The Company undertakes reviews of projects and business units for major risks and seeks to maintain strong controls across all corporate and operational activities in compliance with Principle 7.2. When presenting financial statements for board approval, the Managing Director and Chief Financial Officer provide a formal statement in accordance with section 295A of the Corporations Act 2001 (Cth) with an assurance that the statement is founded upon a sound system of risk management and internal control that is operating effectively in all material respects in relation to financial reporting risks. Principle 8 – Remunerate fairly and responsibly The Remuneration Committee ensures that remuneration is consistent with current market practices and that the Company can attract, retain and develop valued employees. In this regard, the Company complies with Principle 8.1. The Remuneration Committee Charter can be found on the Company’s website. The Remuneration Committee reviews and reports, at least annually, on the relative proportion of women and men in the workforce at all levels of the ERM Power group, excluding the board (which is the responsibility of the Nomination Committee). These proportions are contained in the commentary on Principle 3 above. In compliance with Principle 8.2, the Remuneration Committee was comprised of the Company’s four independent non-executive directors; Tony Iannello (as Chairman), Tony Bellas, Martin Greenberg and Brett Heading (until his resignation in December 2013). Their attendance at meetings of the Committee is set out in the Directors’ Report. The remuneration of non-executive directors is structured separately from that of the Managing Director and the Executive Management Team. The Managing Director and the Executive Management Team are remunerated by way of a mix of fixed and variable remuneration in a manner that motivates them to pursue the long term growth and success of the ERM Power Group. The Securities Trading Policy contains a prohibition against directors and employees altering the economic benefit derived by the director or employee in relation to an equity-based incentive award or grant made by the Company. Information on remuneration of directors and senior executives is contained in the Remuneration Report. All information referred to in this Corporate Governance Statement as being on the Company’s website can be found at the web address: www.ermpower.com.au within the “Investor Centre” tab, under “ASX Announcements” or within the “About Us” tab under “Governance”. More information on ERM Power’s Corporate Governance can be found in these locations. PAGE 35 ERM POWER LIMITED ANNUAL FINANCIAL STATEMENTS FOR THE YEAR ENDED 30 JUNE 2014 CONTENTS Auditor’s Independence Declaration Financial Statements Consolidated Income Statement Consolidated Statement of Comprehensive Income Consolidated Statement of Financial Position Consolidated Statement of Changes in Equity Consolidated Statement of Cash Flows Notes to the Consolidated Financial Statements Directors’ Declaration Independent Auditor’s Report 37 38 39 40 41 42 43 100 101 The financial statements were authorised for issue by the directors on 21 August 2014. The directors have the power to amend and reissue the financial statements. These financial statements cover ERM Power Limited as a consolidated entity comprising ERM Power Limited and its controlled entities. The Group’s functional and presentation currency is Australian dollars (AUD). ERM Power Limited is a company limited by shares, incorporated and domiciled in Australia. Its registered office and principal place of business is set out on page 44. A description of the Group’s operations and of its principal activities is included in the review of operations and activities in the Directors’ Report on pages 16 to 21. The Directors’ Report does not form part of the annual financial statements. ABN 28 122 259 223 PAGE 36 ERM POWER ANNUAL REPORT | 2014 ERM POWER LIMITED AUDITORS’ INDEPENDENCE DECLARATION FOR THE YEAR ENDED 30 JUNE 2014 Auditor’s Independence Declaration As lead auditor for the audit of ERM Power Limited for the year ended 30 June 2014, I declare that to the best of my knowledge and belief, there have been: a) no contraventions of the auditor independence requirements of the Corporations Act 2001 in relation to the audit; and b) no contraventions of any applicable code of professional conduct in relation to the audit. This declaration is in respect of ERM Power Limited and the entities it controlled during the period. Tim Allman Partner PricewaterhouseCoopers Brisbane 21 August 2014 PricewaterhouseCoopers, ABN 52 780 433 757 Riverside Centre, 123 Eagle Street, BRISBANE QLD 4000, GPO Box 150, BRISBANE QLD 4001 T: +61 7 3257 5000, F: +61 7 3257 5999, www.pwc.com.au Liability limited by a scheme approved under Professional Standards Legislation. PAGE 37 ERM POWER LIMITED CONSOLIDATED INCOME STATEMENT FOR THE YEAR ENDED 30 JUNE 2014 CONTINUING OPERATIONS Revenue Other income Total revenue Expenses EBITDAIF Depreciation and amortisation Net fair value (loss) / gain on financial instruments designated at fair value through profit or loss Results from operating activities Finance expense (Loss) / profit before income tax Income tax benefit / (expense) Statutory (loss) / profit for the year Non-controlling interest Statutory (loss) / profit for the year attributable to equity holders of the Company Note 2014 $’000 2013 $’000 5 6 7 8 9 2,075,548 1,569,322 989 248 2,076,537 1,569,570 (2,002,299) (1,499,749) 74,238 (18,044) (115,568) (59,374) (29,284) (88,658) 65,583 (23,075) (822) (23,897) 69,821 (14,037) 29,812 85,596 (31,853) 53,743 (15,274) 38,469 (1,930) 36,539 Cents Cents Statutory (loss) / earnings per share based on earnings attributable to the ordinary equity holders of the Company Basic (loss) / earnings per share Diluted (loss) / earnings per share 34 34 (10.56) (10.56) 20.80 20.80 The above Consolidated Income Statement should be read in conjunction with the accompanying notes. Operational business segment performance and underlying profit of the consolidated entity is presented in note 2 together with a reconciliation between statutory profit attributable to members of the parent entity and underlying profit. PAGE 38 ERM POWER ANNUAL REPORT | 2014 ERM POWER LIMITED CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME FOR THE YEAR ENDED 30 JUNE 2014 Statutory (loss) / profit for the year Other comprehensive (loss) / income Items that may be reclassified subsequently to profit and loss Changes in the fair value of cash flow hedges (net of tax) Items that will not be reclassified subsequently to profit and loss Changes in the fair value of financial assets at fair value through other comprehensive income (net of tax) Other comprehensive (loss) / income for the year, net of tax Non-controlling interest Other comprehensive (loss) / income for the year attributable to equity holders of the Company Note 26 26 2014 $’000 (23,075) 2013 $’000 38,469 107 5,459 (2,750) (2,643) – (2,643) (4,472) 987 28 959 Total comprehensive (loss) / income for the year (25,718) 39,456 Non-controlling interest Total comprehensive (loss) / income for the year attributable to equity holders of the Company (822) (1,958) (26,540) 37,498 The above Consolidated Statement of Comprehensive Income should be read in conjunction with the accompanying notes. PAGE 39 ERM POWER LIMITED CONSOLIDATED STATEMENT OF FINANCIAL POSITION AS AT 30 JUNE 2014 ASSETS Current Assets Cash and cash equivalents Trade and other receivables at amortised cost Inventories Other assets Derivative financial instruments Total Current Assets Non-Current Assets Trade and other receivables at amortised cost Financial assets at fair value through other comprehensive income Derivative financial instruments Property, plant and equipment Exploration and evaluation costs Gas assets Deferred tax assets Intangible assets Total Non-Current Assets TOTAL ASSETS LIABILITIES Current Liabilities Trade and other payables Current tax liabilities Borrowings Borrowings – limited recourse Derivative financial instruments Provisions Total Current Liabilities Non-Current Liabilities Borrowings – limited recourse Derivative financial instruments Deferred tax liabilities Provisions Total Non-Current Liabilities TOTAL LIABILITIES NET ASSETS EQUITY Contributed equity Reserves Retained earnings Capital and reserves attributable to equity holders of the Company Non-controlling interest TOTAL EQUITY Note 2014 $’000 2013 $’000 11 13 14 15 17 13 16 17 18 19 20 9 21 22 9 23 23 17 24 23 17 9 24 25 26 247,687 202,357 56,396 10,721 2,133 519,294 682 7,636 837 435,691 15,313 16,308 9,789 10,924 497,180 1,016,474 249,402 564 129,949 8,079 114,367 2,014 504,375 193,518 40,479 – 897 234,894 739,269 277,205 322,337 (46,283) 1,151 277,205 – 277,205 215,355 157,338 63,453 8,474 27,622 472,242 1,446 6,187 20 446,392 12,448 17,309 5,845 5,851 495,498 967,740 221,624 1,498 95,498 26,790 17,757 1,818 364,985 216,563 47,167 66,588 594 330,912 695,897 271,843 233,291 (34,776) 50,820 249,335 22,508 271,843 The above Consolidated Statement of Financial Position should be read in conjunction with the accompanying notes. PAGE 40 ERM POWER ANNUAL REPORT | 2014 ERM POWER LIMITED CONSOLIDATED STATEMENT OF CHANGES IN EQUITY FOR THE YEAR ENDED 30 JUNE 2014 Contributed equity $’000 Reserves $’000 Retained earnings $’000 Total $’000 Note Non- controlling interests $’000 Total equity $’000 166,660 (36,313) 30,859 161,206 20,550 181,756 – – – – 959 959 36,539 36,539 1,930 38,469 – 959 28 987 36,539 37,498 1,958 39,456 10 25 25 25 25 27 1,104 – (16,578) (15,474) 8,959 (175) 60,000 (1,489) (1,943) – – – – 753 – – – – – 8,784 60,000 (1,489) (1,943) 753 – – – – – – (15,474) 8,784 60,000 (1,489) (1,943) 753 233,291 (34,776) 50,820 249,335 22,508 271,843 – – – – (23,897) (23,897) 822 (23,075) (2,643) – (2,643) – (2,643) (2,643) (23,897) (26,540) 822 (25,718) Balance at 1 July 2012 Profit for the period Other comprehensive income Total comprehensive income for the year Transactions with owners in their capacity as owners: Dividends paid Issue of shares and share options exercised pursuant to employee incentive scheme Contribution of equity from capital raising Transaction costs arising on share issue (net of tax) Purchase of treasury shares Share based payment expense Balance at 30 June 2013 (Loss) / profit for the period Other comprehensive loss Total comprehensive (loss) / income for the year Transactions with owners in their capacity as owners: Dividends paid 10 2,040 – (25,772) (23,732) Issue of shares and share options exercised pursuant to employee incentive scheme Contribution of equity from capital raising Transaction costs arising on share issue (net of tax) Purchase of treasury shares Share based payment expense Cash flow hedges transferred to profit and loss (net of tax) 25 25 25 27 26 25/26 6,064 (2,498) 84,700 (1,680) (2,078) – – – – – – 1,890 348 (8,604) 3,566 84,700 (1,680) (2,078) 1,890 348 – – – – – – – Transactions with non-controlling interests 30(d) (8,604) (23,330) (31,934) Balance at 30 June 2014 322,337 (46,283) 1,151 277,205 – 277,205 The above Consolidated Statement of Changes in Equity should be read in conjunction with the accompanying notes. PAGE 41 – – – – – – – (23,732) 3,566 84,700 (1,680) (2,078) 1,890 348 ERM POWER LIMITED CONSOLIDATED STATEMENT OF CASH FLOWS FOR THE YEAR ENDED 30 JUNE 2014 Cash flows from operating activities Receipts from customers (inclusive of goods and services tax) Payments to suppliers and employees (inclusive of goods and services tax) Interest received Income tax paid Net cash flows from operating activities 12 Cash flows from investing activities Payments for gas exploration and evaluation Payments for gas development assets Payments for plant and equipment Payments for intangible assets Purchase of shares in listed companies Net cash acquired as part of acquiring non-controlling interest 30(d) Note 2014 $’000 2013 $’000 2,191,919 1,652,153 (2,169,114) (1,546,529) 6,857 (4,183) 25,479 (2,962) (1,670) (1,755) (8,315) (5,377) 62 5,745 (6,627) 104,742 (7,853) (8,019) (13,494) (4,634) (6,720) - Net cash flows used in investing activities (20,017) (40,720) Cash flows from financing activities Proceeds from borrowings including receivables financing facility Repayments of borrowings including receivables financing facility Proceeds from borrowings – limited recourse Repayments of borrowings – limited recourse Loans to investees Payment for acquisition of non-controlling interest Finance costs Dividends paid Issue of shares on capital raising net of transaction costs Cash received on exercise of share options Net cash flows from financing activities Net increase in cash and cash equivalents Cash and cash equivalents at the beginning of the year Cash and cash equivalents at the end of the year 2,594,290 1,755,457 (2,524,911) (1,746,150) – (44,919) (2,000) (30,000) (25,496) (23,730) 83,636 – 26,870 32,332 215,355 247,687 1,500 (19,793) – – (28,686) (15,474) 58,023 6,841 11,718 75,740 139,615 215,355 13(ii) 30(d) 10 25 25 11 The above Consolidated Statement of Cash Flows should be read in conjunction with the accompanying notes. PAGE 42 ERM POWER ANNUAL REPORT | 2014 INDEX TO NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS PAGE 1 2 3 4 5 6 7 8 9 SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES SEGMENT REPORT FINANCIAL RISK MANAGEMENT CRITICAL ACCOUNTING ESTIMATES AND JUDGEMENTS REVENUE EXPENSES NET FAIR VALUE (LOSS) / GAIN ON FINANCIAL INSTRUMENTS DESIGNATED AT FAIR VALUE THROUGH PROFIT AND LOSS FINANCE EXPENSE INCOME TAX 10 DIVIDENDS PAID AND PROPOSED 11 CASH AND CASH EQUIVALENTS 12 RECONCILIATION OF CASH FLOWS FROM OPERATING ACTIVITIES 13 TRADE AND OTHER RECEIVABLES AT AMORTISED COST 14 INVENTORIES 15 OTHER ASSETS 16 FINANCIAL ASSETS AT FAIR VALUE THROUGH OTHER COMPREHENSIVE INCOME 17 DERIVATIVE FINANCIAL INSTRUMENTS 18 PROPERTY, PLANT AND EQUIPMENT 19 EXPLORATION AND EVALUATION COSTS 20 GAS ASSETS 21 INTANGIBLE ASSETS 22 TRADE AND OTHER PAYABLES 23 BORROWINGS 24 PROVISIONS 25 CONTRIBUTED EQUITY 26 RESERVES 27 SHARE BASED PAYMENTS 28 PARENT ENTITY FINANCIAL INFORMATION 29 COMMITMENTS AND CONTINGENCIES 30 INTERESTS IN OTHER ENTITIES 31 RELATED PARTY DISCLOSURES 32 KEY MANAGEMENT PERSONNEL 33 AUDITORS’ REMUNERATION 34 EARNINGS PER SHARE 35 EVENTS AFTER THE REPORTING PERIOD 44 57 59 68 69 69 70 70 71 74 74 75 76 77 77 77 78 80 81 81 82 82 83 84 85 86 88 90 91 93 96 98 98 99 99 PAGE 43 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014 These financial statements cover ERM Power Limited the consolidated entity (‘Group’ or ‘consolidated entity’) consisting of ERM Power Limited (the ‘Company’) and its subsidiaries. The report is presented in Australian dollars. The Company is incorporated and domiciled in Australia. Its registered office and place of business is Level 52, 111 Eagle Street, Brisbane, Queensland 4000. Critical accounting estimates The preparation of financial statements requires the use of certain critical accounting estimates. It also requires management to exercise its judgement in the process of applying the Group’s accounting policies. Information regarding critical accounting estimates is provided in note 4. Changes in accounting policies A description of the nature of the Group’s operations and of its principal activities is included in the review of operations and activities in the Directors’ Report on pages 16 to 21. The Group had to change some of its accounting policies as the result of new or revised accounting standards which became effective for the annual reporting period commencing on 1 July 2013. This report was authorised for issue by the directors on 21 August 2014. 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES The principal accounting policies adopted in the preparation of the financial report are set out below. These policies have been consistently applied to all the years presented, unless otherwise stated. The Company is a for-profit entity for the purpose of preparing the financial statements. (a) Basis of preparation This general purpose financial report has been prepared in accordance with Australian Accounting Standards, other authoritative pronouncements of the Australian Accounting Standards Board and the Corporations Act 2001. Compliance with IFRS The consolidated financial statements of the Group comply with International Financial Reporting Standards (IFRS) as issued by the International Accounting Standards Board (IASB). Historical cost convention These financial statements have been prepared under the historical cost convention, as modified by the revaluation of financial assets and liabilities (including derivative financial instruments) at fair value through profit and loss and other comprehensive income. Early adoption of Australian Accounting Standards The Group has not elected to apply any pronouncements before their operative date in the annual reporting period beginning 1 July 2013. The affected policies and standards are: (i) (ii) (iii) Principles of consolidation – new standards AASB 10 Consolidated Financial Statements and AASB 11 Joint Arrangements, AASB 12 Disclosure of Interests in Other Entities, AASB 128 Investments in Associates and Joint Ventures, AASB 127 Separate Financial Statements and AASB 2011-7 Amendments to Australian Accounting Standards arising from the Consolidation and Joint Arrangements Standards; AASB 13 Fair Value Measurement, AASB 2011-8 Amendments to Australian Accounting Standards arising from AASB13, AASB 2012-2 Amendments to Australian Accounting Standards – Disclosures – Offsetting Financial Assets and Financial Liabilities; and Accounting for employee benefits – revised AASB 119 Employee Benefits (September 2011) and AASB 2011-10 Amendments to Australian Accounting Standards arising from AASB 119 (September 2011). Another new standard that is applicable for the first time for the June 2014 annual report is AASB 2012-5 Amendments to Australian Accounting Standards arising from Annual Improvements 2009-2011 Cycle. This standard has introduced new disclosure requirements for the Group but did not affect the Group’s accounting policies or any of the amounts recognised in the financial statements. (i) Principles of consolidation – subsidiaries and joint arrangements AASB 10 was issued in August 2011 and replaces the guidance on control and consolidation in AASB 127 Consolidated and Separate Financial Statements and in Interpretation 112 Consolidation – Special Purpose Entities. Under the new principles, the Group controls an entity when the Group is exposed to, or has rights to, variable returns from its involvement with the entity and has the ability to affect those returns through its power over the entity. PAGE 44 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014ERM POWER ANNUAL REPORT | 2014 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (CONT.) (a) Basis of preparation (cont.) The Group has reviewed its investments in other entities to assess whether the consolidation conclusion in relation to these entities is different under AASB 10 than under AASB 127. No differences were found and therefore no adjustments to any of the carrying amounts in the financial statements are required as a result of the adoption of AASB 10. Under AASB 11 investments in joint arrangements are classified as either joint operations or joint ventures depending on the contractual rights and obligations each investor has, rather than the legal structure of the joint arrangement. The Group has assessed the nature of its joint arrangements and determined to only have joint operations and no joint ventures. The accounting for the Group’s joint operations has not changed as a result of the adoption of AASB 11. The Group continues to recognise its direct right to and its share of jointly held assets, liabilities, revenues and expenses of joint operations. These have been incorporated in the financial statements under the appropriate headings. (ii) AASB 13 Fair Value Measurement, AASB 2011-8 Amendments to Australian Accounting Standards arising from AASB13, AASB 2012-2 Amendments to Australian Accounting Standards – Disclosures – Offsetting Financial Assets and Financial Liabilities Application of the new standards impacts the type of information disclosed in the notes to the financial statements and requires financial instrument valuations to include counterparty credit risk. On 1 July 2013, the Group adopted AASB 2012-2 Disclosures – Offsetting Financial Assets and Financial Liabilities. AASB 2012-2 amends the disclosures requirements in AASB 7 Financial Instruments so that more extensive disclosures are required. The disclosures focus on quantitative information about recognised financial instruments that are offset in the statement of financial position, as well as those recognised financial instruments that are subject to master netting or similar arrangement irrespective of whether they are offset. Refer to Note 3D for further details on offsetting disclosures. AASB 13 Fair Value Measurement aims to improve consistency and reduce complexity by providing a precise definition of fair value and a single source of fair value measurement and disclosure requirements for use across Australian Accounting Standards. The standard does not extend the use of fair value accounting but provides guidance on how it should be applied where its use is already required or permitted by other Australian Accounting Standards. Previously the fair value of financial liabilities (including derivatives) was measured on the basis that the financial liability would be settled or extinguished with the counterparty. The adoption of AASB 13 has clarified that fair value is an exit price notion, and as such, the fair value of financial liabilities should be determined based on a transfer value to a third party market participant. As a result of this change, the fair value of derivative liabilities has changed on transition to AASB 13, largely due to incorporating credit risk into the valuation. As required under AASB 13, the change to the fair value of the derivative liabilities is applied prospectively, in the same way as a change in an accounting estimate. As a consequence, the fair value of derivative liabilities held at 1 July 2013 was remeasured under AASB 13. The difference has been recorded as a fair value movement through profit or loss and has resulted in a net decrease of derivative liabilities of approximately $4.8m at 1 July 2013. Comparative amounts have not been restated. (iii) Accounting for employee benefits – revised AASB 119 Employee Benefits The revised standard has changed the accounting application to the Group’s annual leave obligations. However, as the entity expects all annual leave to be taken within 12 months of the respective service being provided, the annual leave obligations continue to be classified as short term employee benefits in their entirety. The annual leave is recognised in the provision for employee benefits and measured as an undiscounted amount of short term employee benefits. Consideration is given to the current wage and salary levels and periods of service. The annual leave obligations are presented as current liabilities in the balance sheet if the entity does not have an unconditional right to defer settlement for at least twelve months after the reporting date, regardless of when the actual settlement is expected to occur. (b) Principles of consolidation Subsidiaries The consolidated financial statements incorporate the assets and liabilities of all subsidiaries of the Company as at 30 June 2014 and the results of all its subsidiaries for the year then ended. Control of an entity exists when the group is exposed to, or has rights to, variable returns from its involvement with the entity and has the ability to affect those returns through its power to direct the activities of the entity. The existence and effect of potential voting rights that are currently exercisable or convertible are considered when assessing whether the Group controls another entity. Subsidiaries are fully consolidated from the date on which control is transferred to the Group. They are de-consolidated from the date that control ceases. PAGE 45 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (CONT.) (b) Principles of consolidation (cont.) The acquisition method of accounting is used to account for the acquisition of subsidiaries by the Group that were not previously under common control. On an acquisition-by-acquisition basis, the Group recognises any non-controlling interest in the acquiree either at fair value or at the non-controlling interest’s proportionate share of the acquiree’s net identifiable assets. Non-controlling interests in the results and equity of subsidiaries are shown separately in the consolidated income statement, statement of comprehensive income, statement of changes in equity and statement of financial position respectively. The financial statements of subsidiaries are prepared for the same reporting period as the parent company, using consistent accounting policies. Intercompany balances, transactions and unrealised gains resulting from intra-group transactions have been eliminated in full. Unrealised losses are also eliminated unless the transaction provides evidence of the impairment of the asset transferred. Investments in subsidiaries are accounted for at cost less any impairment in the individual financial statements of the Company. Changes in ownership interests The Group treats transactions with non-controlling interests that do not result in a loss of control as transactions with equity owners of the Group. A change in ownership interest results in an adjustment between the carrying amounts of the controlling and non-controlling interests to reflect their relative interests in the subsidiary. Any difference between the amount of the adjustment to non-controlling interests and any consideration paid or received is recognised in a separate reserve within equity attributable to owners of the Company. When the Group ceases to have control, joint control or significant influence, any retained interest in the entity is remeasured to its fair value with the change in carrying amount recognised in profit or loss. The fair value is the initial carrying amount for the purposes of subsequently accounting for the retained interest as an associate, jointly controlled entity or financial asset. In addition, any amounts previously recognised in other comprehensive income in respect of that entity are accounted for as if the group had directly disposed of the related assets or liabilities. This may mean that amounts previously recognised in other comprehensive income are reclassified to profit or loss. Associates Associates are all entities over which the Group has significant influence but not control, generally accompanying a shareholding of between 20% and 50% of the voting rights. Investments in associates are accounted for in the consolidated financial statements using the equity method of accounting. The Group’s share of its associates’ post-acquisition profits or losses is recognised in the income statement, and its share of post-acquisition movements in reserves is recognised in reserves. The cumulative post-acquisition movements are adjusted against the carrying amount of the investment. Dividends receivable from associates are recognised in the consolidated financial statements by reducing the carrying amount of the investment. When the Group’s share of losses in an associate equals or exceeds its interest in the associate, including any other unsecured receivables, the Group does not recognise further losses, unless it has incurred obligations or made payments on behalf of the investment. Unrealised gains on transactions between the Group and its associates are eliminated to the extent of the Group’s interest in the associates. Unrealised losses are also eliminated unless the transaction provides evidence of an impairment of the asset transferred. Accounting policies of associates have been changed where necessary to ensure consistency with the policies adopted by the Group. Joint arrangements Under AASB 11 Joint Arrangements investments in joint arrangements are classified as either joint operations or joint ventures. The classification depends on the contractual rights and obligations of each investor, rather than the legal structure of the joint arrangement. The Group has joint operations but no joint ventures. Joint operations The Group recognises its direct right to the assets, liabilities, revenues and expenses of joint operations and its share of any jointly held or incurred assets, liabilities, revenues and expenses. These have been incorporated in the financial statements under the appropriate headings. Details of the joint operation are set out in note 30. Employee share trusts The Group has formed trusts to administer the Group’s employee share schemes. The trusts are consolidated, as the substance of the relationship is that the trusts are controlled by the Group. Shares held by the trusts are disclosed as treasury shares and deducted from contributed equity. PAGE 46 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014ERM POWER ANNUAL REPORT | 2014 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (CONT.) (c) Parent entity financial information The financial information for the parent entity, ERM Power Limited, disclosed in note 28 has been prepared on the same basis as the consolidated financial statements, except as set out below: (i) Investments in subsidiaries, associates and joint arrangements Investments in subsidiaries, associates and joint venture entities are accounted for at cost in the financial statements of the Company. Dividends received from associates are recognised in the parent entity’s profit or loss, rather than being deducted from the carrying amount of these investments. Financial Guarantees (ii) Where the parent entity provides financial guarantees in relation to loans and payables of subsidiaries for no compensation, the fair values of these guarantees are accounted for as contributions and recognised as part of the cost of the investments. (iii) Share-based payments The grant by the Company of options over its equity instruments to the employees of subsidiary undertakings in the Group is treated as a capital contribution to that subsidiary undertaking. The fair value of employee services received, measured by reference to the grant date fair value, is recognised over the vesting period as an increase to investment in subsidiary undertakings, with a corresponding credit to equity. Tax consolidation legislation (iv) The Company and its wholly-owned Australian controlled entities have implemented the tax consolidation legislation. The head entity ERM Power Limited, and the controlled entities in the tax consolidated group, account for their own current and deferred tax amounts. These tax amounts are measured as if each entity in the tax consolidated group continues to be a standalone taxpayer in its own right. In addition to its own current and deferred tax amounts, the Company also recognises the current tax liabilities (or assets) and the deferred tax assets arising from unused tax losses and unused tax credits assumed from controlled entities in the tax consolidated group. Assets or liabilities arising under tax funding agreements with the tax consolidated entities are recognised as amounts receivable from or payable to other entities in the Group. Any difference between the amounts assumed and amounts receivable or payable under the tax funding agreement are recognised as a contribution to (or distribution from) wholly- owned tax consolidated entities. (d) Segment reporting The consolidated entity determines and presents operating segments based on the information that is internally provided to the Managing Director who is the chief operating decision maker. The Managing Director regularly receives financial information on the underlying profit of each operating segment and the statutory profit. An operating segment is a distinguishable component of an entity that engages in business activity from which it may earn revenues and incur expenses (including revenues and expenses relating to transactions with other components of the same entity), and whose operating results are regularly reviewed by the chief operating decision maker to make decisions about resources to be allocated to the segment. (e) Foreign currency translation Functional and presentation currency The consolidated financial statements are presented in Australian dollars, which is the functional and presentation currency of each of the Group companies. Transactions and balances Foreign currency transactions are translated into the functional currency at the rate of exchange at the date of the transaction. Foreign exchange gains and losses resulting from the settlement of such transactions, and from the translation at year end exchange rates of monetary assets and liabilities denominated in foreign currencies, are recognised in the income statement, except when deferred in equity as qualifying cash flow hedges. (f) Cash and cash equivalents Cash and cash equivalents comprise cash on hand, deposits held at call with financial institutions, and other short-term highly liquid investments with original maturities of three months or less that are readily convertible into known amounts of cash and which are subject to an insignificant risk of changes in value, net of any bank overdrafts. These assets are stated at nominal values. Cash that is reserved and its use specifically restricted for maintenance and / or debt servicing under the Group’s borrowing agreements is defined as restricted cash. Cash that is on deposit with counterparties as security deposits and cash that is on deposit with financial institutions as security for bank guarantees issued to various counterparties as credit support, is defined as restricted cash, with a corresponding disclosure in contingent liabilities in Note 29. PAGE 47 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (CONT.) (g) Trade and other receivables All trade and other debtors are recognised initially at fair value and subsequently measured at amortised cost using the original effective interest method less allowances for doubtful debts. Collectability is reviewed on an ongoing basis. An allowance for doubtful debts is made when there is objective evidence that the Group will not be able to collect any amounts due according to original terms. The amount of the allowance is the difference between the asset’s carrying amount and the present value of the estimated future cash flows discounted at the effective interest rate. The amount of the impairment loss is recognised in the income statement. Trade receivables are those due for settlement no more than 30 days from the date of invoice. Inventories (h) Stocks and materials are valued at the lower of cost and estimated net realisable value. Renewable energy certificates Renewable energy certificates held by the Group are accounted for as commodity inventories. The Group participates in the purchase and sale of a range of renewable energy certificates, including both mandatory and voluntary schemes. Purchased renewable energy certificates are initially recognised at cost within inventories on settlement date. Subsequent measurement is at the lower of cost or net realisable value, with losses arising from changes in realisable value being recognised in the income statement in the period of the change. Financial assets (i) Investments are recognised and derecognised on trade date where the purchase or sale of an investment is under a contract whose terms require delivery of the investment within the timeframe established by the market concerned, and are initially measured at fair value. Subsequent to initial recognition, investments in associates are accounted for under the equity method in the consolidated financial statements. Further information regarding equity accounted investments is detailed in note 1(b). From 1 July 2012 the Group classifies its financial assets as either amortised cost or fair value. The classification depends on the Group’s business model for managing the financial assets and the contractual terms of the cash flows. (i) Financial assets – at amortised cost A financial asset is classified as at amortised cost only if both of the following criteria are met: • the asset is held within a business model with the objective to collect the contractual cash flows, and • the contractual terms give rise on specified dates to cash flows that are solely payments of principal and interest on the principal outstanding. The nature of any derivatives embedded in the financial asset are considered in determining whether the cash flows of the investment are solely payment of principal and interest on the principal outstanding and are not accounted for separately. (ii) Financial assets – at fair value through profit or loss If either of the two criteria above are not met, the financial asset is classified as at fair value through profit or loss. The Group has not designated any financial assets as measured at fair value through profit or loss so as to specifically eliminate or significantly reduce an accounting mismatch. The Group is required to reclassify all affected financial assets when and only when its business model for managing those assets changes. (iii) Equity investments All equity investments are measured at fair value. Equity investments that are held for trading are measured at fair value through profit or loss. For all other equity investments, the Group can make an irrevocable election at initial recognition of each investment to recognise changes in fair value through other comprehensive income rather than profit or loss. At initial recognition, the Group measures a financial asset at its fair value plus, in the case of a financial asset not at fair value through profit or loss, transaction costs that are directly attributable to the acquisition of the financial asset. Transaction costs of financial assets carried at fair value through profit or loss are expensed in profit or loss. A gain or loss on a financial asset that is subsequently measured at fair value and is not part of a hedging relationship is recognised in profit or loss and presented net in the income statement within other income or other expenses in the period in which it arises. A gain or loss on a financial asset that is subsequently measured at amortised cost and is not part of a hedging relationship is recognised in profit or loss when the financial asset is derecognised or impaired and through the amortisation process using the effective interest rate method. PAGE 48 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014ERM POWER ANNUAL REPORT | 2014 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (CONT.) (i) Financial assets (cont.) The Group subsequently measures all equity investments at fair value. Where the Group’s management has elected to present fair value gains and losses on equity investments in other comprehensive income, there is no subsequent reclassification of fair value gains and losses to profit or loss. Dividends from such investments continue to be recognised in profit or loss as other revenue when the Group’s right to receive payments is established and as long as they represent a return on investment. Changes in the fair value of financial assets at fair value through profit or loss are recognised in other income or other expenses in the income statement as applicable. Interest income from these financial assets is included in the net gains / losses. Dividend income is presented as other revenue. De-recognition of financial assets The Group derecognises a financial asset only when the contractual rights to the cash flows from the asset expire, or it transfers the financial asset and substantially all the risks and rewards of ownership of the asset to another entity. If the Group neither transfers nor retains substantially all the risks and rewards of ownership and continues to control the transferred asset, the Group recognises its retained interest in the asset and an associated liability for amounts it may have to pay. If the Group retains substantially all the risks and rewards of ownership of a transferred financial asset, the Group continues to recognise the financial asset and also recognises a collateralised borrowing for the proceeds received. Impairment of financial assets Financial assets, other than those at fair value through profit or loss, are assessed for indicators of impairment at each balance date. Financial assets are impaired where there is objective evidence that as a result of one or more events that occurred after the initial recognition of the financial asset the estimated future cash flows of the investment have been impacted. For financial assets carried at amortised cost, the amount of the impairment is the difference between the asset’s carrying amount and the present value of estimated future cash flows, discounted at the original effective interest rate. The carrying amount of financial assets including uncollectable trade receivables is reduced by the impairment loss through the use of an allowance account. Subsequent recoveries of amounts previously written off are credited against the allowance account. Changes in the carrying amount of the allowance account are recognised in profit or loss. With the exception of available-for-sale equity instruments, if in a subsequent period the amount of the impairment loss decreases and the decrease can be related objectively to an event occurring after the impairment was recognised, the previously recognised impairment loss is reversed through profit or loss to the extent the carrying amount of the investment at the date the impairment is reversed does not exceed what the amortised cost would have been had the impairment not been recognised. Effective interest method The effective interest method is a method of calculating the amortised cost of a financial asset and of allocating interest income over the relevant period. The effective interest rate is the rate that exactly discounts estimated future cash receipts (including all transaction costs and other premiums or discounts) through the expected life of the financial asset, or, where appropriate, a shorter period. Income is recognised on an effective interest rate basis for debt instruments other than those financial assets ‘at fair value through profit or loss’. Capitalised work in progress (j) Costs incurred in relation to the development of a project, including the cost of construction, are recorded as capitalised work in progress when these costs are incurred prior to the establishment of a development vehicle. Development expenditure is recorded as capitalised work in progress only if development costs can be measured reliably, the project is technically and commercially feasible, future economic benefits are probable, and the Group intends to and has sufficient resources to complete development and to use or sell the asset. Development costs relating to project costs incurred may include legal fees, insurance costs, independent engineer costs, borrowing costs, environmental impact study fees, and direct labour and overhead costs. Capitalised work in progress is measured at cost less accumulated impairment losses. The recovery of these costs usually occurs at financial close of a project at which time these costs are transferred to a development vehicle. PAGE 49 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (CONT.) (k) Derivative financial instruments ERM Power Retail Pty Ltd, one of the subsidiaries in the Group, routinely enters into forward sales contracts (“Contracts”) related to the provision of electricity in the Australian National Electricity Market (“NEM”). The Contracts are exclusively entered into with industrial, commercial and government entities under term contracts. All of the electricity provided under these Contracts is traded in the NEM spot market. ERM Power Retail Pty Ltd also enters into a variety of electricity derivative transactions (“Derivatives”) as part of an overall strategy to hedge the exposure to Contract prices. ERM Power Retail Pty Ltd manages all of its Contracts and Derivatives as part of an overall commodity trading strategy. Revenue from the Contracts is recognised in accordance with the revenue recognition policy in note 1(y). Derivatives are initially recognised at fair value on the date the derivative contract is entered into, and are subsequently remeasured to their fair value at each balance date. Derivatives are carried in the statement of financial position as assets when the fair value is positive and as liabilities when the fair value is negative. The resulting gain or loss arising from the revaluation is recognised in the income statement in the period it arises. Hedge accounting The Group designates interest rate swaps as cash flow hedges. At the inception of the hedge relationship the entity documents the relationship between the hedging instrument and hedged item, along with its risk management objectives and its strategy for undertaking various hedge transactions. Furthermore, at the inception of the hedge and on an ongoing basis, the Group documents whether the hedging instrument that is used in a hedging relationship is highly effective in offsetting changes in cash flows of the hedged item. Cash flow hedge The effective portion of changes in the fair value of derivatives that are designated and qualify as cash flow hedges are deferred in equity. The gain or loss relating to the ineffective portion is recognised immediately in profit or loss. Amounts deferred in equity are recycled in profit or loss in the periods when the hedged item is recognised in profit or loss in the same line as the recognised hedged item. However, when the forecast transaction that is hedged results in the recognition of a non-financial asset or a non- financial liability, the gains and losses previously deferred in equity are transferred from equity and included in the initial measurement of the cost of the asset or liability. Hedge accounting is discontinued when the Group revokes the hedging relationship, the hedging instrument expires or is sold, terminated, or exercised, or no longer qualifies for hedge accounting. Any cumulative gain or loss deferred in equity at that time remains in equity and is recognised when the forecast transaction is ultimately recognised in profit or loss. When a forecast transaction is no longer expected to occur, the cumulative gain or loss that was deferred in equity is recognised immediately in profit or loss. Fair value estimation (l) The fair value of financial assets and financial liabilities must be estimated for recognition and measurement or for disclosure purposes. The fair value of financial instruments traded in active markets (such as publicly traded derivatives, and trading and available-for-sale securities) is based on quoted market prices at the balance date. The quoted market price used for financial assets held by the Group is the current bid price; the appropriate quoted market price for financial liabilities is the current ask price. The fair value of financial instruments that are not traded in an active market is determined using a variety of valuation techniques and assumptions that are based on market conditions existing at each balance date. Quoted market prices or dealer quotes for similar instruments are used for long-term debt instruments held. Other techniques, such as estimated discounted cash flows, are used to determine fair value for the remaining financial instruments. The fair value of forward exchange contracts is determined using market exchange rates and published forward margins at balance date. The nominal value less estimated credit adjustments of trade receivables and payables is assumed to approximate their fair value. For disclosure purposes the fair value of financial liabilities is estimated by discounting the future contractual cash flows at the current market interest rate that is available to the Group for similar financial instruments. (m) Property, plant and equipment Items of property, plant and equipment are initially measured at historical cost less depreciation. Historical cost includes expenditure that is directly attributable to the acquisition of the items. Cost may also include transfers from equity of any gains / losses on qualifying cash flow hedges of foreign currency purchases of property, plant and equipment. Subsequent costs are included in the asset’s carrying amount or recognised as a separate asset, as appropriate, only when it is probable that future economic benefits associated with the item will flow to the Group and the cost of the item can be measured reliably. All repairs and maintenance expenses are charged to the income statement during the financial period in which they are incurred. Subsequent impairment losses are recognised in accordance with note 1(p). PAGE 50 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014ERM POWER ANNUAL REPORT | 2014 Farm-outs The Group does not record any expenditure made by the farmee on its account. It also does not recognise any gain or loss on its exploration and evaluation farm-out arrangements, but redesignates any costs previously capitalised in relation to the whole interest as relating to the partial interest retained. Any cash consideration received directly from the farmee is credited against costs previously capitalised in relation to the whole interest with any excess accounted for by the farmor as a gain on disposal. Development assets At the point in which technical feasibility and commercial viability of extraction of gas is demonstrated or a petroleum lease is granted, an area of interest enters the development phase. Expenditure on the construction, installation or completion of infrastructure facilities such as platforms, pipelines and the drilling of development wells, including unsuccessful development or delineation wells for the relevant area of interest, is capitalised within development assets. Gas assets in production On commencement of commercial production, development assets for production wells are reclassified as gas assets in production. Ongoing costs of continuing to develop production reserves, costs to expand or replace plant and equipment and any associated land and buildings are also capitalised within gas assets. Depreciation Gas assets in production are depreciated using the units of production (UOP) method over total proved developed and undeveloped reserves or resources. Each reserve or resource life, which is assessed annually, has regard to both its physical life limitations and to present assessments of economically recoverable reserves or resources at which the gas asset is located. These calculations require the use of estimates and assumptions, including the amount of recoverable reserves or resources and estimates of future capital expenditure. The calculation of the UOP rate of depreciation could be impacted to the extent that actual production in the future is different from current forecast production based on total proved reserves or resources, or future capital expenditure estimates changes. Changes to reserves or resources could arise due to changes in the factors or assumptions used in estimating reserves or resources. Changes are accounted for prospectively. 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (CONT.) (m) Property, plant and equipment (cont.) Depreciation Land and capital work in progress are not depreciated. Depreciation on the other assets is calculated using the straight-line method to allocate their cost, net of their residual values, over their estimated useful lives, as follows: • Leasehold improvements the lesser of the remaining lease term and the life of the asset • Motor vehicles 3 – 8 years • Plant and equipment 1 – 50 years • IT Equipment 1 – 3 years • Furniture and equipment 1 – 10 years Capital work in progress comprises costs incurred to date on construction of power generation plants. Asset residual values and useful lives are reviewed and adjusted if appropriate at each balance date. Gains and losses on disposals are determined by comparing the proceeds to the carrying amount. These are included in the income statement. (n) Gas assets Exploration and evaluation costs Exploration and evaluation expenditure incurred is accumulated in respect of each identifiable area of interest. Such expenditure comprises net direct costs and an appropriate portion of related overhead expenditure but does not include overheads or administration expenditure not having a specific nexus with a particular area of interest. Exploration and evaluation expenditure is only capitalised from the point when the rights to tenure of the area are granted. All exploration and evaluation costs are capitalised to the extent that they are expected to be recouped through the successful development of the area or where activities in the area have not yet reached a stage which permits reasonable assessment of the existence of economically recoverable reserves and active or significant operations in relation to the area are continuing. The probability of expected future economic benefits is assessed using reasonable and supportable assumptions that represent management’s best estimate of the set of economic conditions that will exist over the useful life of the asset. In this assessment, greater weighting is given to available external evidence. Exploration and evaluation assets will be reclassified as development assets at the point in which technical feasibility and commercial viability of extracting gas are demonstrated or a petroleum lease is granted. Exploration and evaluation assets are assessed for impairment and any impairment loss is recognised before reclassification. Accumulated costs in relation to an abandoned area are written off in full against profit in the year in which the decision to abandon is made. PAGE 51 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (CONT.) (o) Intangible assets Goodwill Goodwill is measured as described in note 1(q). Goodwill on acquisitions of subsidiaries is included in intangible assets. Goodwill on acquisitions of associates is included in investments in associates. Goodwill is allocated to cash-generating units for the purpose of impairment testing. The allocation is made to those cash- generating units or groups of cash-generating units that are expected to benefit from the business combination in which the goodwill arose, identified according to operating segments. Software Computer software is either purchased or developed within the organisation and is recorded at cost less accumulated amortisation and impairment losses. Amortisation is calculated using the straight line method over the estimated useful lives. Depending on the individual software, the estimated useful life ranges between 3 and 10 years. Customer acquisition costs The direct costs of establishing customer contracts are recognised as an asset when the customer contract is expected to provide a future economic benefit to the Group. Direct costs are amortised over the average contract term of 3 years. Impairment of assets (p) Assets that are subject to depreciation are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount may not be recoverable. An impairment loss is recognised for the amount by which the asset’s carrying amount exceeds its recoverable amount. The recoverable amount is the higher of an asset’s fair value less costs to sell and its value in use. For the purposes of assessing impairment, assets are grouped at the lowest levels for which there are separately identifiable cash flows. Intangible assets, including exploration and evaluation assets, are assessed for impairment when facts and circumstances suggest that the carrying amount may exceed its recoverable amount. Goodwill and intangible assets that have an indefinite useful life are not subject to amortisation and are tested annually for impairment, or more frequently if events or changes in circumstances indicate that they might be impaired. (q) Business combinations The acquisition method of accounting is used to account for all business combinations, regardless of whether equity instruments or other assets are acquired. The consideration transferred for the acquisition of a subsidiary comprises the fair values of the assets transferred, the liabilities incurred and the equity interests issued by the Group. The consideration transferred also includes the fair value of any asset or liability resulting from a contingent consideration arrangement and the fair value of any pre-existing equity interest in the subsidiary. Acquisition-related costs are expensed as incurred. Identifiable assets acquired and liabilities and contingent liabilities assumed in a business combination are, with limited exceptions, measured initially at their fair values at the acquisition date. On an acquisition-by-acquisition basis, the Group recognises any non-controlling interest in the acquiree either at fair value or at the non-controlling interest’s proportionate share of the acquiree’s net identifiable assets. The excess of the consideration transferred, the amount of any non- controlling interest in the acquire and the acquisition-date fair value of any previous equity interest in the acquiree over the fair value of the group’s share of the net identifiable assets acquired is recorded as goodwill. If those amounts are less than the fair value of the net identifiable assets of the subsidiary acquired and the measurement of all amounts has been reviewed, the difference is recognised directly in profit or loss as a discount on acquisition. Where settlement of any part of cash consideration is deferred, the amounts payable in the future are discounted to their present value as at the date of exchange. The discount rate used is the entity’s incremental borrowing rate, being the rate at which a similar borrowing could be obtained from an independent financier under comparable terms and conditions. Contingent consideration is classified either as equity or a financial liability. Amounts classified as a financial liability are subsequently remeasured to fair value with changes in fair value recognised in profit or loss. Trade and other payables (r) These amounts represent liabilities for goods and services provided to the Group prior to the end of the financial period and which are unpaid. The amounts are unsecured and are usually paid within 60 days of recognition. PAGE 52 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014ERM POWER ANNUAL REPORT | 2014 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (CONT.) (s) Provisions Onerous contracts Obligations arising under onerous contracts are recognised and measured as a provision. An onerous contract is considered to exist where the Group has a contract under which the unavoidable costs of meeting the obligations under the contract exceed the economic benefits expected to be derived from it. (t) Other financial liabilities Other financial liabilities, including borrowings, are initially recognised at fair value, net of transaction costs. Equity-based compensation benefits Equity-based compensation benefits are provided to employees via employee and executive equity plans. The fair value of options or shares issued to employees is recognised as an employee benefit expense with a corresponding increase in equity. The fair value is measured at grant date and recognised in the option reserve or share-based payment reserve over the period during which the employees become unconditionally entitled to the equity. When the shares are issued, or the options exercised, the value is transferred to contributed equity. The fair value of options at grant date is determined using the Black Scholes method that takes into account the value of the underlying share at grant date, the term of the vesting period, exercise price and expiry date. Other financial liabilities are subsequently measured at amortised cost using the effective interest method, with interest expense recognised on an effective yield basis. The assessed fair value of shares granted to employees is allocated equally over the period from issue to the actual or expected vesting date. The effective interest method is a method of calculating the amortised cost of a financial liability and of allocating interest expense over the relevant period. The effective interest rate is the rate that exactly discounts estimated future cash payments through the expected life of the financial liability, or, where appropriate, a shorter period. (u) Employee benefits Wages and salaries, annual leave and sick leave Liabilities arising in respect of wages and salaries, annual leave and any other employee entitlements expected to be settled within 12 months of balance date are measured at the amounts expected to be paid when the liabilities are settled. Long service leave Long service leave liabilities are measured at the present value of the estimated future cash outflow to be made in respect of services provided by employees up to balance date. Consideration is given to expected future wage and salary levels, projected employee movements and periods of service. Expected future payments are discounted using market yields at balance date on government bonds with terms to maturity that match, as closely as possible, the estimated future cash flows. Refer to note 27 for further details. (v) Assets held for sale Non-current assets and disposal groups are classified as held for sale if their carrying amount will be recovered principally through a sale transaction rather than through continuing use. This condition is regarded as met only when the sale is highly probable and the asset (or disposal group) is available for immediate sale in its present condition. Management must be committed to the sale which should be expected to qualify for recognition as a completed sale within one year from the date of classification. Non-current assets (and disposal groups) classified as held for sale are measured at the lower of their previous carrying amount and fair value less costs to sell. (w) Earnings per share Basic earnings per share are calculated by dividing: • The profit attributable to owners of the Company, excluding any cost of servicing equity other than ordinary shares • By the weighted average number of ordinary shares outstanding during the financial year, adjusted for bonus elements ordinary shares issued during the year and excluding treasury shares. Bonus plans Liabilities for employee benefits in the form of bonus plans are recognised in liabilities when it is probable that the liability will be settled and there are formal terms in place to determine the amount of the benefit. Liabilities for bonus plans are expected to be settled within 12 months and are measured at the amounts expected to be paid when they are settled. Diluted earnings per share Diluted earnings per share adjust the figures used in the determination of basic earnings per share to take into account: • The after income tax effect of interest and other financing cost associated with dilutive potential ordinary shares, and • The weighted average number of additional ordinary shares that would have been outstanding assuming the conversion of all dilutive potential ordinary shares. PAGE 53 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (CONT.) (x) Contributed equity Ordinary shares Ordinary shares are classified as equity. Incremental costs directly attributable to the issue of ordinary shares and share options are recognised as a deduction from equity, net of any tax effects. Preference share capital Preference share capital is classified as equity if it is non-redeemable, or redeemable only at the entity’s option, and any dividends are discretionary. Dividends thereon are recognised as distributions within equity upon declaration by the directors. Preference share capital is classified as a liability if it is redeemable on a specific date or at the option of the shareholders, or if dividend payments are not discretionary. Dividends thereon are recognised as interest expense in profit or loss. (y) Revenue recognition The Group recognises revenue when the amount of revenue can be reliably measured, it is probable that future economic benefits will flow to the entity and specific criteria have been met for each of the Group’s activities as outlined below. Revenue is measured at the fair value of the consideration received or receivable. Amounts disclosed as revenue are net of trade allowances and duties and taxes paid. Electricity sales revenue from sales contracts is recognised on measurement of electrical consumption at the metering point, as specified in each contractual agreement, and is billed monthly in arrears. At each balance date, sales and receivables include an amount of sales delivered to customers but not yet billed and recognised as accrued income. Generation revenue is recognised from the generation of electricity when the electricity has been supplied to customers. Interest revenue is recognised on a time proportional basis taking into account the interest rates applicable to the financial assets. All revenue is stated net of goods and services tax. Project management fees are calculated based on current contractual guidelines and include project success fees earned at financial close. The Group’s share of capitalised project management fees is eliminated on consolidation. (z) Cost of sales Cost of sales is recognised as those costs directly attributable to the goods sold and includes the costs of electricity, materials and associated distribution expenses. Electricity costs are based upon spot prices for electricity as established by the Australian Energy Market Operator (AEMO) and the outcomes of derivative financial instruments entered into for the purpose of risk management (refer to note 1(k)). (aa) Borrowings Borrowings are initially recognised at fair value, net of transaction costs incurred. Borrowings are subsequently measured at amortised cost. Any difference between the proceeds (net of transaction costs) and the redemption amount is recognised in profit or loss over the period of the borrowings using the effective interest method. Fees paid on the establishment of loan facilities are recognised as transaction costs of the loan to the extent that it is probable that some or all of the facility will be drawn down. In this case, the fee is deferred until the draw down occurs. To the extent there is no evidence that it is probable that some or all of the facility will be drawn down, the fee is capitalised as a prepayment for liquidity services and amortised over the period of the facility to which it relates. Preference shares, which are mandatorily redeemable on a specific date, are classified as liabilities. The dividends on these preference shares are recognised in profit or loss as finance costs. The fair value of the liability portion of a convertible bond is determined using a market interest rate for an equivalent non- convertible bond. This amount is recorded as a liability on an amortised cost basis using the effective interest rate method until extinguished on conversion or maturity of the bonds. The remainder of the proceeds is allocated to the conversion option. This is recognised and included in shareholders’ equity, net of income tax effects. Borrowings are removed from the statement of financial position when the obligation specified in the contract is discharged, cancelled or expired. The difference between the carrying amount of a financial liability that has been extinguished or transferred to another party and the consideration paid, including any non-cash assets transferred or liabilities assumed, is recognised in profit or loss as other income or finance costs. Borrowings are classified as current liabilities unless the Group has an unconditional right to defer settlement of the liability for at least 12 months after the reporting period. PAGE 54 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014ERM POWER ANNUAL REPORT | 2014 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (CONT.) (bb) Borrowing costs Borrowing costs incurred for the construction of any qualifying asset are capitalised during the period of time that is required to complete and prepare the asset for its intended use or sale. Other borrowing costs are expensed. The capitalisation rate used to determine the amount of borrowing costs to be capitalised to each project is the effective interest rate applicable to the specific borrowings at a project level during the year. (cc) Leases Finance leases, which transfer to the Group substantially all the risks and benefits incidental to ownership of the leased item, are capitalised at the inception of the lease at the fair value of the leased property or, if lower, at the present value of the minimum lease payments. Lease payments are apportioned between the finance charges and reduction of the lease liability so as to achieve a constant rate of interest on the remaining balance of the liability. Finance charges are charged directly against income. Capitalised leased assets are depreciated over the shorter of the estimated useful life of the asset or the lease term. Leases where the lessor retains substantially all the risks and benefits of ownership of the asset are classified as operating leases. Operating lease payments are recognised as an expense in the income statement on a straight-line basis over the lease term. (dd) Income tax Income tax expense or revenue for the period is the tax payable on the current period’s taxable income based on the prevailing income tax rate adjusted by changes in deferred tax assets and liabilities attributable to temporary differences and to unused tax losses. The current income tax charge is calculated on the basis of tax laws enacted or substantively enacted at the end of the reporting period in the countries where the Company’s subsidiaries and associates operate and generate taxable income. Management periodically evaluates positions taken in tax returns with respect to situations in which applicable tax regulation is subject to interpretation. It establishes provisions where appropriate on the basis of amounts expected to be paid to the tax authorities. Deferred income tax is provided in full, using the liability method, on temporary differences arising between the tax bases of assets and liabilities and their carrying amounts in the consolidated financial statements. However, deferred income tax is not accounted for if it arises from initial recognition of an asset or liability in a transaction other than a business combination that at the time of the transaction affects neither accounting nor taxable profit or loss. Deferred income tax is determined using tax rates (and laws) that have been enacted or substantially enacted by the balance date and are expected to apply when the related deferred income tax asset is realised or the deferred income tax liability is settled. Deferred tax assets are recognised for deductible temporary differences and unused tax losses only if it is probable that future taxable amounts will be available to utilise those temporary differences and losses. Deferred tax liabilities and assets are not recognised for temporary differences between the carrying amount and tax bases of investments in controlled entities where the entity is able to control the timing of the reversal of the temporary differences and it is probable that the differences will not reverse in the foreseeable future. Deferred tax assets and liabilities are offset when there is a legally enforceable right to offset current tax assets and liabilities and when the deferred tax balances relate to the same taxation authority. Current tax assets and tax liabilities are offset where the entity has a legally enforceable right to offset and intends either to settle on a net basis, or to realise the asset and settle the liability simultaneously. Current and deferred tax is recognised in profit or loss, except to the extent that it relates to items recognised in other comprehensive income or directly in equity. In this case, the tax is also recognised in other comprehensive income or directly in equity, respectively. (ee) Goods and services tax (GST) Revenues, expenses and assets are recognised net of the amount of associated GST, unless the GST incurred is not recoverable from the taxation authority. In this case it is recognised as part of the cost of acquisition of the asset or as part of the expense. Receivables and payables are stated inclusive of the amount of GST receivable or payable. The net amount of GST recoverable from, or payable to, the taxation authority is included with other receivables or payables at the balance date. Cash flows are presented on a gross basis. The GST components of cash flows arising from investing or financing activities which are recoverable from, or payable to the taxation authority, are presented as operating cash flows. PAGE 55 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (CONT.) (ff) Dividends Provision is made for the amount of any dividend declared, appropriately authorised, no longer at the discretion of the entity and not distributed during the reporting period. (gg) Rounding of amounts The Group is of a kind referred to in Class Order 98/100, issued by the Australian Securities and Investments Commission, relating to the “rounding off’’ of amounts in the financial statements. Amounts in the financial statements have been rounded off in accordance with that class order to the nearest thousand dollars, or in certain cases, the nearest dollar. (hh) New accounting standards and interpretations Certain new accounting standards and interpretations have been published that are not mandatory for the 30 June 2014 reporting period. Unless stated otherwise below, the Group is currently in the process of assessing the impact of these standards and amendments and is yet to decide whether to early adopt any of the new and amended standards. AASB 9 Financial Instruments (December 2013) (effective from 1 January 2017). AASB 9 addresses the classification, measurement and derecognition of financial assets and financial liabilities. Since December 2013, it also sets out new rules for hedge accounting and introduces expanded disclosure requirements and changes in presentation. AASB 9 Financial Instruments, AASB 2010-7 Amendments to Australian Accounting Standards arising from AASB 9 (December 2010) and AASB 2012-6 Amendments to Australian Accounting Standards – Mandatory Effective Date of AASB 9 and Transition Disclosures (effective from 1 January 2015). AASB 9 Financial Instruments addresses the classification, measurement and derecognition of financial assets and financial liabilities. The standard is not applicable until 1 January 2015 but is available for early adoption. AASB 2012-3 Amendments to Australian Accounting Standards – Offsetting Financial Assets and Financial Liabilities (effective from 1 January 2015). AASB 2012-3 adds application guidance to AASB 132 to address inconsistencies identified in applying some of the offsetting criteria of AASB 132, including clarifying the meaning of “currently has a legally enforceable right of set-off” and that some gross settlement systems may be considered equivalent to net settlement. AASB 2013-4 Amendments to Australian Accounting Standards – Novation of Derivatives and Continuation of Hedge Accounting (effective from 1 January 2014). AASB 2013-4 makes amendments to AASB 139 Financial Instruments: Recognition & Measurement to permit the continuation of hedge accounting in circumstances where a derivative, which has been designated as a hedging instrument, is novated from one counterparty to a central counterparty as a consequence of laws or regulations. AASB 2014-1 Amendments to Australian Accounting Standards (Part A: Annual Improvements 2010–2012 and 2011–2013 Cycles) (effective from 1 July 2014). Part A of AASB 2014-1 makes amendments to various Australian Accounting Standards arising from the issuance by the International Accounting Standards Board (IASB) of International Financial Reporting Standards Annual Improvements to IFRSs 2010-2012 Cycle and Annual Improvements to IFRSs 2011-2013 Cycle. AASB Interpretation 21 Levies (effective from 1 January 2014). Interpretation 21 addresses how an entity should account for liabilities to pay levies imposed by governments, other than income taxes, in its financial statements (in particular, when the entity should recognise a liability to pay a levy). There are no other standards that are not yet effective and that are expected to have a material impact on the entity in the current or future reporting periods and on foreseeable future transactions. PAGE 56 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014ERM POWER ANNUAL REPORT | 2014 1 3 9 , 3 2 ) 0 3 3 , 6 ( ) 0 3 9 , 1 ( 1 7 6 , 5 1 2 1 8 , 9 2 ) 4 4 9 , 8 ( 9 3 5 , 6 3 0 3 9 , 1 9 6 4 , 8 3 0 1 9 , 6 2 3 1 9 , 0 3 ) 2 2 8 ( 1 0 0 , 7 5 ) 8 6 5 , 5 1 1 ( 0 7 6 , 4 3 ) 7 9 8 , 3 2 ( 2 2 8 ) 5 7 0 , 3 2 ( l a t o T r e h t O s t e s s A n o i t a r e n e G l s e a S y t i c i r t c e E l 3 1 0 2 4 1 0 2 3 1 0 2 4 1 0 2 3 1 0 2 4 1 0 2 3 1 0 2 4 1 0 2 0 0 0 ’ $ 2 1 9 , 0 7 5 , 1 1 3 2 , 9 7 0 , 2 6 4 1 , 5 2 8 8 , 0 1 4 3 7 , 2 7 5 2 6 , 2 7 2 3 0 , 3 9 4 , 1 4 2 7 , 5 9 9 , 1 e u n e v e r y r o t u t a t s - n o N e u n e v e r y r o t u t a t s - n o N 8 4 2 9 8 9 3 4 2 ) 0 9 5 , 1 ( ) 3 8 6 , 3 ( ) 0 9 5 , 1 ( 0 7 5 , 9 6 5 , 1 7 3 5 , 6 7 0 , 2 9 9 7 , 3 4 3 1 ) 3 8 6 , 3 ( 3 3 3 , 7 5 – – 5 5 8 – – – – n o i t a n m e i l i s e a s l t n e m g e s r e t n I e m o c n i r e h t O 9 3 7 , 2 7 0 8 4 , 3 7 2 3 0 , 3 9 4 , 1 4 2 7 , 5 9 9 , 1 e u n e v e r t n e m g e s l a t o T ) 9 4 7 , 9 9 4 , 1 ( ) 9 9 2 , 2 0 0 , 2 ( ) 6 9 7 , 5 1 ( ) 6 9 6 , 6 2 ( ) 1 1 2 , 9 2 ( ) 7 8 6 , 1 2 ( ) 2 4 7 , 4 5 4 , 1 ( ) 6 1 9 , 3 5 9 , 1 ( s e s n e p x E s s e L T R O P E R T N E M G E S . 2 ) 7 3 0 , 4 1 ( ) 4 4 0 , 8 1 ( ) 3 5 8 , 1 3 ( ) 4 8 2 , 9 2 ( ) 1 2 1 , 1 ( ) 3 9 4 , 2 ( ) 7 6 ( ) 3 0 5 , 2 2 ( ) 1 2 7 , 0 2 ( ) 5 2 1 , 4 ( ) 0 8 9 , 1 1 ( ) 2 3 1 , 2 1 ( ) 6 3 9 ( 1 2 8 , 9 6 8 3 2 , 4 7 ) 7 9 9 , 1 1 ( ) 3 6 3 , 9 1 ( 8 2 5 , 3 4 3 9 7 , 1 5 0 9 2 , 8 3 ) 1 1 6 , 5 1 ( ) 5 5 5 , 3 2 ( 5 4 0 , 9 0 4 9 , 8 1 ) 7 5 8 , 6 ( 7 9 4 , 0 3 8 0 8 , 1 4 ) 7 8 7 , 1 ( ) 6 9 4 , 8 ( 5 2 5 , 1 3 x a t e m o c n i e r o f e b t i f o r p g n y l r e d n U i n o i t a s i t r o m a d n a i n o i t a c e r p e D s e s n e p x e e c n a n F i ) i ( I F A D T B E I t i f i o r p g n y l r e d n u o t d e t u b i r t t a e s n e p x e x a t e m o c n I t s e r e t n i g n i l l o r t n o c - n o N s s o l r o t i f o r p h g u o r h t e u a v l r i a f i s a d e t a n g s e d s t n e m u r t s n i l i a c n a n i f n o i n a g / ) s s o l ( e u a v l r i a f t e N i : t i f o r p g n y l r e d n u m o r f d e d u c x e l s m e t i f o t c a p m I t i f i o r p g n y l r e d n u m o r f d e d u c x e l s m e t i n o ) t i d e r c ( / t i f e n e b x a T y n a p m o C e h t l f o s r e d o h y t i u q e o t e b a t u b i r t t a x a t l r e t f a t i f o r p / ) s s o l ( y r o t u t a t S t s e r e t n i g n i l l o r t n o c - n o N x a t r e t f a t i f o r p / ) s s o l ( y r o t u t a t S y n a p m o C e h t l f o s r e d o h y t i u q e o t e b a t u b i r t t a x a t l r e t f a t i f o r p g n y l r e d n U i s e s s o l / s n a g d n a i s s o l d n a t i f o r p h g u o r h t e u a v l r i a f i t a d e t a n g s e d s t n e m u r t s n i l i a c n a n i f n o s e s s o l / s n a g e u a v l i r i a f t e n , t n e m r i a p m i , n o i t a s i t r o m a i , n o i t a c e r p e d , x a t , t s e r e t n i f e r o e b s g n n r a E i ) i ( . e m o c n i r e h t o d n a s e a s l e t a s n e d n o c d n a s a g , g n i t l u s n o c , t s e r e t n i s e s i r p m o c t n e m g e s r e h t O e h t n i e u n e v e R . s t c a r t n o c s u o r e n o n o PAGE 57 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014 6 8 0 , 8 6 4 6 5 7 9 8 , 5 9 6 9 6 2 , 9 3 7 1 1 8 , 7 2 6 5 0 7 , 8 3 7 3 0 2 , 3 1 2 9 2 , 3 1 2 4 0 , 2 8 2 9 0 1 , 9 3 2 6 6 5 , 2 3 3 4 0 3 , 6 8 4 s e i t i l i b a i l x a t d e r r e e d d n a f t n e r r u C s e i t i l i b a i l l a t o T s e i t i l i b a i l t n e m g e s l a t o T s e i t i l i b a L i i i r e k a m n o s c e d g n i t a r e p o f i e h c e h t s i o h w r o t c e r i i D g n g a n a M e h t y b d e w e v e r i s t r o p e r n o d e s a b s t n e m g e s g n i t a r e p o i e h t d e n m r e t e d s a h t n e m e g a n a M I I N O T P R C S E D T N E M G E S o t s a o s t n e m g e s g n i t a r e p o h c a e f o t i f i o r p g n y l r e d n u e h t n o n o i t a m r o n f i l i a c n a n i f i s e v e c e r l y l r a u g e r r o t c e r i i D g n g a n a M e h T . y t i t n e d e t a d i l o s n o c e h t r o f . t i f i o r p g n y l r e d n u t s a c e r o f d n a t e g d u b o t n o s i r a p m o c t n a v e e r l a l e b a n e o t d n a t n e m g e s h c a e f o e c n a m r o f r e p g n o g n o i e h t s s e s s a i : s e c v r e s d n a s t c u d o r P : s t n e m g e s s s e n s u B i s r e m o t s u c i s s e n s u b o t s e a s l y t i c i r t c e E l l s e a S y t i c i r t c e E l . d o i r e p e v i t a r a p m o c r o t n e r r u c e h t r e h t i e r o f e u n e v e r l a n r e t x e l a t o t s ’ y t i t n e d e t a d i l o s n o c e h t f o e r o m r o % 0 1 o t s t n u o m a r e m o t s u c l e g n s i o N s n o i t a r e p o d n a t n e m p o e v e d o t l h g u o r h t t p e c n o c l a i t i n i e h t m o r f , s n o i t u o s l n o i t a r e n e g r e w o p f o y r e v i l e d d n a s t e s s a n o i t a r e n e g r e w o p d e r i f - s a G s t e s s A n o i t a r e n e G e t a r o p r o C d n a g n i r e t e M , s a G r e h t O . n o i t a d i l o s n o c n o d e t a n m e i l i e r a d n a h t g n e l s ’ m r a t a t u o d e i r r a c e r a s t n e m g e s n e e w t e b s e a S l . a i l a r t s u A n i l e c a p s e k a t y t i v i t c a t n e m g e s l l A 5 9 8 , 1 6 9 5 8 6 , 6 0 0 , 1 6 4 3 , 4 3 1 6 0 3 , 5 9 3 4 4 , 7 6 4 9 2 0 , 9 5 4 6 0 1 , 0 6 3 0 5 3 , 2 5 4 s t e s s a t n e m g e s l a t o T 5 4 8 , 5 9 8 7 , 9 0 4 7 , 7 6 9 4 7 4 , 6 1 0 , 1 s t e s s a x a t d e r r e e d d n a f t n e r r u C s t e s s a l a t o T 3 1 0 2 4 1 0 2 3 1 0 2 4 1 0 2 3 1 0 2 4 1 0 2 3 1 0 2 4 1 0 2 l a t o T r e h t O s t e s s A n o i t a r e n e G l s e a S y t i c i r t c e E l ) . T N O C ( T R O P E R T N E M G E S . 2 PAGE 58 0 0 0 ’ $ s t e s s A ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014ERM POWER ANNUAL REPORT | 2014 3. FINANCIAL RISK MANAGEMENT Financial risk management objectives A. The Group’s activities are exposed to a variety of financial risks, including market risk (commodity price and interest rate), credit risk and liquidity risk. The Group’s overall risk management strategy focuses on the unpredictability of markets and seeks to minimise potential adverse effects on the financial performance of the Group. The Group uses a variety of derivative financial instruments such as electricity derivatives and interest rate swaps to hedge against certain risk exposures. The Group uses different methods to measure the different types of risk to which it is exposed. These methods include sensitivity analysis in the case of interest rate, foreign exchange and other price risks, and ageing analysis for credit risk. (a) Market risk Electricity pool price risk The Group is exposed to fluctuations in wholesale market electricity prices as a result of electricity generation and sales. Group policies prescribe active management of exposures arising from forecast electricity sales within prescribed limits. In doing so, various hedging contracts have been entered into with individual market participants. Any unhedged position has the potential for variation in net profit from fluctuations in electricity pool prices. ERM Power Retail Pty Ltd, one of the subsidiaries of the Group, routinely enters into forward sales contracts for the provision of electricity. The Group is exposed to a market risk of price fluctuations between the fixed price of these contracts and the relevant spot price of the electricity pool at the time of usage. The majority of this exposure to fluctuations in wholesale market electricity prices is managed through the use of various types of hedging contracts. The hedge portfolio consists predominantly of swaps, caps, futures and options. Electricity derivatives are either entered into in separate agreements or arise as embedded derivatives. Whilst the Group recognises the fair value of electricity derivative contracts for accounting purposes, the Group is not permitted to similarly recognise the fair value of the sales contracts that form the other side of the economic hedging relationship. The following tables summarise the impact of a 10% change in the relevant forward prices for wholesale market electricity prices for the Group at the balance date, while all other variables were held constant. Electricity sales sensitivity The impact disclosed below summarises the sensitivity on the unrealised mark to market of electricity derivatives contracts only and does not include any corresponding movement in the value of customer contracts, which would vary in the opposite direction to the underlying hedge. As electricity forward prices increase above the contracted rate of a derivative contract (buy side contract) the derivative contract becomes more valuable as it allows the Group to effectively purchase electricity at a cost lower than the prevailing forward market rate. Equally, the value of the corresponding customer contract (sell side contract) decreases as the Group has contracted to sell electricity to a customer at a rate lower than the prevailing forward market rate. Only the mark to market on the buy side contract has been recognised for accounting purposes regardless of whether there is an effective hedge in place. 2014 Net profit / (loss) – unrealised mark to market of electricity derivative contracts Other components of equity increase / (decrease) 2013 Net profit / (loss) – unrealised mark to market of electricity derivative contracts Other components of equity increase / (decrease) Increase by 10% $’000 Decrease by 10% $’000 40,132 (51,472) – – 75,915 (75,599) – – Sensitivity of 10% has been selected as this is considered reasonably possible based on industry standard benchmarks and historical volatilities. PAGE 59 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014 3. FINANCIAL RISK MANAGEMENT (CONT.) A. Financial risk management objectives (cont.) (a) Market risk (cont.) Electricity generation sensitivity The impact disclosed below summarises the sensitivity on the profit of generating assets held by the Group resulting from a change in spot prices. 2014 Net profit / (loss) Other components of equity increase / (decrease) 2013 Net profit / (loss) Other components of equity increase / (decrease) Increase by 10% $’000 Decrease by 10% $’000 161 – 117 – (161) – (117) – Sensitivity of 10% has been selected as this is considered reasonably possible based on industry standard benchmarks and historical volatilities Interest rate risk The Group is exposed to interest rate risk on the funds it borrows at floating interest rates and on cash deposits. The risk is managed by entering into interest rate swap contracts for project term debt. The sensitivity analysis to net profit (being profit before tax) and equity has been determined based on the exposure to interest rates at the balance date and assumes that there are concurrent movements in interest rates and parallel shifts in the yield curves. A sensitivity of 100 basis points has been selected as this is considered reasonable given the current level of short term and long term interest rates. At balance date, if interest rates had been 100 basis points higher / lower and all other variables were held constant, the impact on the Group would be: 2014 Net profit / (loss) Other components of equity increase / (decrease) 2013 Net profit / (loss) Other components of equity increase / (decrease) Increase by 100bps $’000 Decrease by 100bps $’000 173 – 589 – (173) – (589) – The impact on net profit is largely due to the Group’s exposure to interest rates on its non-hedged variable rate borrowings and cash assets. PAGE 60 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014ERM POWER ANNUAL REPORT | 2014 3. FINANCIAL RISK MANAGEMENT (CONT.) A. Financial risk management objectives (cont.) (b) Credit risk Credit risk refers to the loss that would occur if a debtor or other counterparty fails to perform under its contractual obligations. The carrying amounts of financial assets recognised at balance date best represents the Group’s maximum exposure to credit risk at balance date. The Group seeks to limit its exposure to credit risks as follows: • conducting appropriate due diligence on counterparties before entering into arrangements with them; • depending on the outcome of the credit assessment, obtaining collateral with a value in excess of the counterparties’ obligations to the Group – providing a ‘margin of safety’ against loss; and • for derivative counterparties, using primarily high credit quality counterparties, in addition to utilising ISDA master agreements with derivative counterparties in order to limit the exposure to credit risk. The Group has no significant concentrations of credit risk. The credit qualities of all financial assets are consistently monitored in order to identify any potential adverse changes in the credit quality. Concentrations of credit risk The Group minimises concentrations of credit risk in relation to debtors by undertaking transactions with a large number of customers from across a broad range of industries within the business segments in which the Group operates, such that there are no significant concentrations of credit risk within the Group at balance date. Credit risk to trade debtors is managed through setting normal payment terms of up to 30 days and through continual risk assessment of debtors with material balances. Credit risk to electricity debtors is managed through system driven credit management processes. The process commences after due date. For some debtors the Group may also obtain security in the form of guarantees, deeds of undertaking, or letters of credit which can be called upon if the counterparty is in default under the terms of the agreement. The ageing of receivables as at balance date was as follows: 2014 Consolidated Trade receivables Loan receivables Other receivables (iii) 2013 Consolidated Trade receivables Other receivables (iii) Total $’000 < 30 days $’000 31–60 days $’000 > 60 days $’000 Impaired (i) PDNI (ii) Impaired (i) PDNI (ii) 19,872 18,370 2,043 1,689 – 322 253 – – 535 1,043 – 23,604 18,692 253 1,578 15,746 14,356 2,338 23 18,084 14,379 44 – 44 1,210 – 1,210 617 – – 617 129 – 129 967 1,000 1,367 3,334 180 2,315 2,495 The majority of year-end debtors relate to electricity. (i) (ii) Impaired balance represents account balances deemed to be irrecoverable by the Group at balance date. A provision for doubtful debts has been provided for. Past due not impaired (PDNI) represents account balances outstanding for greater than 30 days but are still considered to be recoverable in the ordinary course of business. Included in the Group’s trade receivable balance are debtors with a carrying amount of $2,869,539 (2013: $1,383,056) which are past due at balance date for which the Group has not provided as there has not been a significant change in credit quality and the amounts are still considered recoverable. The Group does not have any collateral over these balances. (iii) Other receivables are neither past due or impaired and relate principally to employee shareholder loans, which are subject to loan deeds. PAGE 61 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014 3. FINANCIAL RISK MANAGEMENT (CONT.) A. Financial risk management objectives (cont.) Liquidity risk (c) Liquidity risk is the risk that the Group will not be able to meet its financial obligations as they fall due. Prudent liquidity risk management implies maintaining sufficient cash and marketable securities, the availability of funding through an adequate amount of committed credit facilities and the ability to close out market positions. The Group manages liquidity risk by continuously monitoring forecast and actual cash flows and matching the maturity profiles of financial assets and liabilities. Surplus funds are generally only invested in instruments that are tradeable in highly liquid markets. Information regarding undrawn finance facilities available as at 30 June 2014 is contained in Note 23. Maturities of financial liabilities The table below analyses the Group’s financial liabilities, including net and gross settled derivative financial instruments, into relevant maturity groupings based on the remaining period at balance date to the contractual maturity date. The amounts disclosed in the table are the contractual undiscounted cash flows. For interest rate swaps the cash flows have been estimated using forward interest rates applicable at balance date. For electricity derivatives the cash flows have been estimated using forward electricity prices at balance date. Financial liabilities Consolidated 2014 Trade payables Other payables Interest bearing liabilities ≤1 year $’000 1 to 5 years $’000 >5 years $’000 Discount $’000 Total $’000 186,321 63,081 129,949 – – – – – – – – – 186,321 63,081 129,949 Interest bearing liabilities – limited recourse (i) 8,079 23,411 184,853 (14,746) 201,597 Derivatives 2013 Trade payables Other payables Interest bearing liabilities Interest bearing liabilities – limited recourse (i) Derivatives 120,807 24,635 9,404 – 154,846 508,237 48,046 194,257 (14,746) 735,794 156,060 64,954 95,498 31,243 25,114 – – – – – – – – – 156,060 64,954 95,498 66,302 163,717 (17,909) 243,353 30,494 9,316 – 64,924 372,869 96,796 173,033 (17,909) 624,789 (i) Recourse limited to assets of the Neerabup Partnership and Oakey Power Holdings Pty Ltd. Refer note 23 for further details. No recourse relates to Oakey Power Station for the loan balance at 30 June 2014. PAGE 62 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014ERM POWER ANNUAL REPORT | 2014 3. FINANCIAL RISK MANAGEMENT (CONT.) B. Significant accounting policies Details of the significant accounting policies and methods adopted, including the criteria for recognition, the basis of measurement and the basis on which income and expenses are recognised in respect of each class of financial asset, financial liability and equity instrument are disclosed in note 1 to the financial statements. Fair value of financial assets and liabilities C. The Group holds the following financial instruments: Financial assets Derivative financial instruments Equity investments Loans and receivables Cash and cash equivalents Financial liabilities Derivative financial instruments Other financial liabilities at amortised cost Note 17 16 13 11 17 22/23 Financial assets by category Financial assets at fair value through profit or loss Amortised cost financial assets Financial assets at fair value through other comprehensive income Consolidated 2013 $’000 Carrying value 27,642 6,187 18,084 215,355 267,268 64,924 560,475 625,399 Consolidated 2013 $’000 Carrying value 27,642 233,439 6,187 2014 $’000 Carrying value 2,970 7,636 23,604 247,687 281,897 154,846 580,948 735,794 2014 $’000 Carrying value 2,970 271,291 7,636 281,897 267,268 PAGE 63 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014 3. FINANCIAL RISK MANAGEMENT (CONT.) C. Fair value of financial assets and liabilities (cont.) The financial assets and liabilities held by the group are outlined below: Derivative financial instruments The fair value of derivative instruments included in hedging assets and liabilities is calculated using quoted prices. The fair value of financial instruments that are not traded in an active market (for example, over-the-counter derivatives) is determined using valuation techniques. The Group uses a variety of methods, such as estimated discounted cash flows, and makes assumptions that are based on market conditions existing at each balance date. These amounts reflect the estimated amount which the Group would be required to pay or receive to terminate (or replace) the contracts at their current market rates at balance date. Equity investments The fair value of financial assets and financial liabilities with standard terms and conditions, and traded on active liquid markets, is determined with reference to quoted market prices. Other financial assets Due to their short-term nature, the carrying amounts of loans, receivables, and cash and cash equivalents approximate their fair value. Other financial liabilities at amortised cost The Group holds various trade payables and borrowings at period end. Due to the short-term nature of the trade payables the carrying value of these are assumed to approximate their fair value. The fair value of borrowings is not materially different then the carrying amounts as the interest rates are close to current market rates or are short-term in nature. The fair value of financial assets and financial liabilities must be estimated for recognition and measurement or for disclosure purposes. The following tables present the Group’s assets and liabilities measured and recognised at fair value at 30 June 2014 and 30 June 2013. As at 30 June 2014 Assets Electricity derivatives contracts Financial assets at fair value through other comprehensive income Total assets Liabilities Electricity derivatives contracts Derivatives used for hedging Total liabilities As at 30 June 2013 Assets Electricity derivatives contracts Financial assets at fair value through other comprehensive income Total assets Liabilities Electricity derivatives contracts Derivatives used for hedging Total liabilities PAGE 64 Level 1 $’000 Level 2 $’000 Level 3 $’000 Total $’000 – 2,970 7,636 7,636 32,624 – – 2,970 89,067 33,155 32,624 122,222 – – – – – – 2,970 7,636 10,606 121,691 33,155 154,846 Level 1 $’000 Level 2 $’000 Level 3 $’000 Total $’000 – 27,642 6,187 6,187 5,504 – 5,504 – 27,642 25,616 33,804 59,420 – – – – – – 27,642 6,187 33,829 31,120 33,804 64,924 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014ERM POWER ANNUAL REPORT | 2014 3. FINANCIAL RISK MANAGEMENT (CONT.) C. Fair value of financial assets and liabilities (cont.) Level 1 The fair value of financial instruments traded in active markets is based on quoted market prices at the end of the reporting period. The quoted market price used for financial assets held by the Group is the current bid price. Level 2 The fair values of financial instruments that are not traded in an active market are determined using valuation techniques. The Group uses a variety of methods and makes assumptions that are based on market conditions existing at the end of each reporting period. Quoted market prices or dealer quotes for similar instruments are used to estimate fair value for long-term debt for disclosure purposes. Other techniques, such as estimated discounted cash flows, are used to determine fair value for the remaining financial instruments. The fair value of interest rate swaps is calculated as the present value of the estimated future cash flows. Level 3 A valuation technique for these instruments is based on significant unobservable inputs. The Group’s policy is to recognise transfers into and transfers out of fair value hierarchy levels as at the end of the reporting period. For the years ending 30 June 2014 and 30 June 2013 there were no transfers between the fair value hierarchy levels. PAGE 65 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014 3. FINANCIAL RISK MANAGEMENT (CONT.) D. Offsetting of financial assets and financial liabilities Financial assets and liabilities are offset and the net amount reported in the balance sheet where the Group currently has a legally enforceable right to offset the recognised amounts, and there is an intention to settle on a net basis or realise the asset and settle the liability simultaneously. The Group has also entered into arrangements that do not meet the criteria for offsetting but still allow for the related amounts to be set off in certain circumstances, such as bankruptcy or the termination of a contract. The following table presents the recognised financial instruments that are offset, or subject to enforceable master netting arrangements and other similar agreements but not offset, as at 30 June 2014 and 30 June 2013. The column ‘net exposure’ shows the impact on the Group’s balance sheet if all set-off rights were exercised. The below table provides a reconciliation of the Group’s gross financial assets and liabilities offset to those presented on the consolidated statement of financial position as at 30 June 2014 and as at 30 June 2013. As at 30 June 2014 $’000 Financial assets Electricity derivatives contracts Total Financial liabilities Gross carrying amount (before offsetting) Gross amounts offset Net amount presented Related amounts not offset Net exposure Financial instruments(i) Cash collateral and futures margin deposits 37,675 37,675 (34,705) (34,705) 2,970 2,970 (1,548) (1,548) – – 1,422 1,422 Electricity derivatives contracts 156,396 (34,705) 33,155 – 189,551 (34,705) 121,691 33,155 154,846 (1,548) (39,685) 80,458 – – 33,155 (1,548) (39,685) 113,613 Interest rate swaps Total As at 30 June 2013 $’000 Financial assets Electricity derivatives contracts Total Financial liabilities Electricity derivatives contracts Interest rate swaps Total Gross carrying amount (before offsetting) Gross amounts offset Net amount presented Related amounts not offset Net exposure Financial instruments(i) Cash collateral and futures margin deposits 32,994 32,994 36,472 33,804 70,276 (5,352) (5,352) (5,352) – (5,352) 27,642 27,642 31,120 33,804 64,924 (5,152) (5,152) (5,152) – (5,152) – – 22,490 22,490 (8,039) – (8,039) 17,929 33,804 51,733 (i) Financial instruments that do not meet the criteria for offsetting but may be offset in certain circumstances. PAGE 66 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014ERM POWER ANNUAL REPORT | 2014 3. FINANCIAL RISK MANAGEMENT (CONT.) E. Capital risk management The Group manages its capital so that it will be able to continue as a going concern while maximising the return to stakeholders through an appropriate mix of debt and equity. This approach is consistent with prior years. The capital structure of the Group as at balance date consists of total corporate facilities, as listed in note 23, total limited recourse facilities as listed in note 23 and equity, comprising issued capital, reserves and retained earnings as listed in notes 25 and 26. In order to maintain or adjust the capital structure, the Group may adjust the amount of dividends paid to shareholders, return capital to shareholders, issue new shares or sell assets to reduce debt. The Group is required to provide prudential credit support to various parties which it does through the provision of bank guarantees or cash collateral. It also has a working capital facility in place which is settled each month. A large percentage of the Group debt is in the form of limited recourse project finance provided directly to power stations in which the Group has an interest. During the financial year ended 30 June 2014 the entity complied with all applicable debt covenants. The quantitative analysis of the Group’s gearing structure is illustrated below. To consider the risk of the company’s capital structure it is appropriate to segregate the projects from the rest of the Group. The table below illustrates the gearing and interest cover for the Group. When the Oakey and Neerabup assets and associated limited recourse debt are excluded the Group has no net debt. Current borrowings Non-current borrowings Total debt Cash and cash equivalents Net debt Total equity excluding reserves Total capital Gearing percentage(i) Gearing percentage(i) excluding Oakey and Neerabup EBITDA Interest cover ratio Consolidated 2013 $’000 122,288 216,563 338,851 2014 $’000 138,028 193,518 331,546 (247,687) (215,355) 83,859 323,488 407,347 21% 0% 2.54 123,496 306,619 430,115 29% 0% 2.19 (i) Gearing percentage is calculated as net debt divided by total capital. Net debt is calculated as total interest-bearing borrowings less cash and cash equivalents. Total capital is calculated as ‘equity’ as shown in the statement of financial position plus net debt less reserves attributable to fair value adjustments. PAGE 67 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014 4. CRITICAL ACCOUNTING ESTIMATES AND JUDGEMENTS Estimates and judgements are continually evaluated and are based on historical experience and other factors, including expectations of future events that may have a financial impact on the Group and that are believed to be reasonable under the circumstances. (a) Critical accounting estimates and assumptions The Group makes estimates and assumptions concerning variables. The estimates and assumptions that have a significant risk of causing a material adjustment to the carrying amounts of assets and liabilities within the next financial year are discussed below. Share-based payment transactions The Company measures the cost of shares and options issued to employees and third parties by reference to the fair value of the equity instruments at the date at which they are granted. Details regarding the terms and conditions upon which the instruments were granted and methodology for determining fair value at grant date are available in note 27. Deferred tax assets The Group has recognised deferred tax assets relating to carried forward tax losses to the extent there are sufficient taxable temporary differences (deferred tax liabilities) relating to the same taxation authority against which the unused tax losses can be utilised. However, utilisation of the tax losses also depends on the ability of the entity to satisfy certain tests at the time the losses are recouped. (b) Critical judgements in applying the entity’s accounting policies Recoverability of exploration costs All exploration, evaluation and development costs are capitalised to the extent that they are expected to be recouped through the successful development of the area or where activities in the area have not yet reached a stage which permits reasonable assessment of the existence of economically recoverable reserves and active or significant operations in relation to the area are continuing. The probability of expected future economic benefits is assessed using reasonable and supportable assumptions that represent management’s best estimate of the set of economic conditions that will exist over the useful life of the asset. In this assessment, greater weighting is given to available external evidence. Exploration and evaluation assets are reclassified as development assets at the point in which technical feasibility and commercial viability of extracting gas are demonstrated or a petroleum lease is granted. Exploration and evaluation assets are assessed for impairment and any impairment loss recognised before reclassification. Fair value of financial instruments The fair value of financial assets and financial liabilities are estimated for recognition and measurement and for disclosure purposes. Management uses its judgement in selecting appropriate valuation techniques for financial instruments not quoted in active markets. Valuation techniques commonly used by market practitioners are applied. For derivative financial instruments, assumptions are made based on quoted market rates adjusted for specific features of the instrument. Other financial instruments are valued using a discounted cash flow analysis based on assumptions supported, where possible, by observable market prices and rates. Refer to note 3 for further details of valuation methods used by the Group to determine fair value. Joint arrangements The Group has classified its investments in the NewGen Neerabup Partnership and various gas interests as joint operations. The partners of the Partnership are jointly and severally liable for the liabilities of the partnership and under the partnership agreement are entitled to a proportionate share of Partnership’s assets. The gas joint arrangements are not controlled through a separate vehicle and have accordingly been classified as joint operations. PAGE 68 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014ERM POWER ANNUAL REPORT | 2014 5. REVENUE Revenue from Continuing Operations Sale of electricity Electricity generation revenue Operations income and project fees Gas production and condensate income Interest income Consulting and other revenue Consolidated 2014 $’000 2013 $’000 1,992,410 1,490,147 63,703 6,533 3,624 6,292 2,986 65,228 6,112 – 5,842 1,993 2,075,548 1,569,322 Refer to note 2 for further information regarding transactions between entities within the Group that have been eliminated on consolidation. 6. EXPENSES Cost of electricity sales Cost of electricity generation Employee benefits expense Other expenses Included in the above employee benefits and other expenses are: Rental expenses relating to operating leases Defined contribution superannuation expense Equity settled share based payment compensation Consolidated 2014 $’000 2013 $’000 1,931,696 1,438,257 7,909 32,793 29,901 9,371 30,524 21,597 2,002,299 1,499,749 3,684 2,431 1,890 3,250 2,092 753 PAGE 69 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014 7. NET FAIR VALUE (LOSS) / GAIN ON FINANCIAL INSTRUMENTS DESIGNATED AT FAIR VALUE THROUGH PROFIT AND LOSS Unrealised Electricity derivative contracts Consolidated 2014 $’000 2013 $’000 (115,568) (115,568) 29,812 29,812 In the absence of hedge accounting, the Group’s electricity derivatives are designated at fair value through profit or loss. The corresponding fair value movement in the value of customer contracts is not recognised for accounting purposes. 8. FINANCE EXPENSE Borrowing costs – bank loans Borrowing costs – receivables financing facility Borrowing costs – convertible notes Other borrowing costs Consolidated 2014 $’000 2013 $’000 16,619 18,131 5,308 4,039 3,318 5,510 4,196 4,016 29,284 31,853 PAGE 70 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014ERM POWER ANNUAL REPORT | 2014 9. INCOME TAX (a) Income tax (benefit) / expense Income tax comprises: Current tax expense Deferred tax (benefit) / expense Adjustment to current and deferred tax of prior periods Income tax (benefit) / expense Deferred income tax included in income tax expense comprises: (Increase) / decrease in deferred tax assets Increase / (decrease) in deferred tax liabilities Deferred income tax (benefit) / expense (b) Numerical reconciliation of prima facie tax benefit to prima facie tax (Loss) / profit from continuing operations Income tax (benefit) / expense calculated at 30% Effect of expenses that are not deductible in determining taxable profit Oakey acquisition(i) Other permanent differences Adjustment to deferred tax of prior periods Income tax (benefit) / expense (c) Amounts recognised directly in other comprehensive income (Increase) / decrease in equity due to current and deferred amounts charged directly to equity during the period: Net tax effect of amounts charged to cash flow hedge reserve Net tax effect of amounts charged to fair value reserve Net tax effect of amounts charged to share capital Consolidated 2014 $’000 2013 $’000 3,249 (69,419) 587 6,990 8,595 (311) (65,583) 15,274 (34,675) (34,157) (68,832) (88,658) (26,597) 286 (39,131) (728) 587 4,249 4,036 8,285 53,743 16,123 89 – (627) (311) (65,583) 15,274 (195) 1,179 720 1,704 (2,345) 1,916 543 114 (i) Tax effect of the non-controlling interest acquisition of the Oakey Power Station during the year ended 30 June 2014. Refer note 30(d) for further details. PAGE 71 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014 9. INCOME TAX (CONT.) (d) Tax losses Tax losses for which deferred tax asset is recognised in the current period Potential tax benefit at 30% (e) Current tax liabilities Current tax payables: Income tax payable (f) Recognised deferred tax assets and deferred tax liabilities Deferred tax assets Carried forward income tax losses Derivative financial instruments Employee provisions Financial assets at fair value through other comprehensive income Other items Set-off of deferred tax liabilities Net deferred tax assets Deferred tax liabilities Property, plant and equipment Capitalised gas exploration costs Gas assets Other items Set-off of deferred tax assets Net deferred tax liabilities Consolidated 2014 $’000 2013 $’000 – – 564 564 18,825 45,865 2,702 4,240 1,285 72,917 (63,128) 9,789 15,400 4,620 1,498 1,498 19,079 11,320 2,716 3,061 362 36,538 (30,693) 5,845 (55,831) (89,042) (4,594) (2,148) (555) (63,128) 63,128 – (3,734) (2,645) (1,860) (97,281) 30,693 (66,588) Tax consolidation The Company and its wholly-owned Australian controlled entities, has implemented the tax consolidation legislation. The entities in the tax consolidated group have entered into tax sharing agreements which, in the opinion of the directors, limits the joint and several liability of the wholly-owned entities in the case of a default by the head entity being ERM Power Limited. The entities in the tax consolidated group have also entered into tax funding agreements under which the wholly-owned entities fully compensate the head entity for any current tax payable assumed and are compensated by the head entity for any current tax receivable and deferred tax assets relating to unused tax losses or unused tax credits that are transferred to the head entity under the tax consolidation legislation. The funding amounts are determined by reference to the amounts recognised in the wholly-owned entities’ financial statements. The amounts receivable/payable under the tax funding agreement are due upon receipt of the funding advice from the head entity, which is issued as soon as practicable after the end of each financial year. The head entity may also require payment of interim funding amounts to assist with its obligations to pay tax instalments. The funding amounts are recognised as current intercompany receivables or payables. PAGE 72 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014ERM POWER ANNUAL REPORT | 2014 9. INCOME TAX (CONT.) Movements in temporary differences – consolidated 2014 Deferred tax assets Carried forward income tax losses Net derivative financial liabilities Employee provisions Financial assets at fair value through other comprehensive income Other items Deferred tax liabilities Capitalised gas exploration costs Gas assets Property, plant and equipment Other items 2013 Deferred tax assets Carried forward tax losses Net derivative financial liabilities Employee provisions Financial assets at fair value through other comprehensive income Other items Deferred tax liabilities Capitalised gas exploration costs Gas assets Property, plant and equipment Other items Opening balance $’000 Recognised in income statement $’000 Recognised in equity $’000 Closing balance $’000 19,079 11,320 2,716 3,061 362 36,538 (3,734) (2,645) (89,042) (1,860) (97,281) 14,459 22,467 1,799 1,145 803 40,673 (4,196) – (87,236) (1,813) (93,245) (254) 34,740 (14) – 203 34,675 (860) 497 33,211 1,305 34,153 4,620 (8,802) 917 – (984) (4,249) 462 (2,645) (1,806) (47) (4,036) – (195) – 1,179 720 1,704 – – – – – – (2,345) – 1,916 543 114 – – – – – 18,825 45,865 2,702 4,240 1,285 72,917 (4,594) (2,148) (55,831) (555) (63,128) 19,079 11,320 2,716 3,061 362 36,538 (3,734) (2,645) (89,042) (1,860) (97,281) PAGE 73 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014 10. DIVIDENDS PAID AND PROPOSED During the year ended 30 June 2014, the Company paid a fully franked final dividend for the year ended 30 June 2013 of 5.5 cents per share and an interim dividend for the year ended 30 June 2014 of 6.0 cents per share (2013: 5.0 cents). Franking credits available to shareholders in subsequent years The franking account balance is adjusted for: • franking credits that will arise from the payment of income tax; 2014 $’000 14,134 2013 $’000 17,770 • franking debits that will arise from the payment of dividends recognised as a liability at the reporting date; and • franking credits that will arise from the receipt of dividends recognised as receivables at the reporting date. After 30 June 2014 the following dividends were proposed by the directors. The dividends have not been provided for and there are no income tax consequences. Final proposed ordinary share dividend estimated based upon shares on issue at 30 June 2014 Cents per share Total amount $’000 Franked $’000 Date of payment 6.0 14,356 14,356 13/10/2014 The consolidated amounts include franking credits that would be available to the parent entity if distributable profits of subsidiaries not included within the tax consolidated group were paid as dividends. The impact on the franking account of the dividend recommended by the directors since the end of the reporting period, but not recognised as a liability at the reporting date, is forecast to be a reduction in the franking account of $6,152,650. 11. CASH AND CASH EQUIVALENTS Current Restricted cash Non-restricted cash at bank and cash on hand Total cash and cash equivalents Consolidated 2014 $’000 2013 $’000 160,525 87,162 247,687 120,486 94,869 215,355 The cash and cash equivalents are bearing interest at rates between nil and 3.96%. Restricted cash Cash that is reserved and its use specifically restricted for maintenance and / or debt servicing under the Group’s borrowing agreements is defined as restricted cash. Cash that is on deposit with counterparties as security deposits and cash that is on deposit with financial institutions as security for bank guarantees issued to various counterparties as credit support, is defined as restricted cash, with a corresponding disclosure in contingent liabilities in Note 29. The restricted cash deposits, held on term deposit, are bearing interest at rates between 3.00% and 3.96%. Term deposits Other restricted cash deposits PAGE 74 Consolidated 2013 $’000 93,971 26,515 120,486 2014 $’000 156,230 4,295 160,525 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014ERM POWER ANNUAL REPORT | 2014 12. RECONCILIATION OF CASH FLOWS FROM OPERATING ACTIVITIES Net (loss) / profit after tax Adjustments for: Depreciation and amortisation of non-current assets Share based payment expense Net unrealised fair value losses / (gains) on financial instruments and inventory Finance costs Transfers to / (from) provisions: Employee entitlements Changes in assets and liabilities: (Increase) / decrease in trade and other receivables (Increase) / decrease in other assets (Increase) / decrease in inventories (Increase) / decrease in deferred tax assets (Decrease) / increase / in deferred tax liabilities (Decrease) / increase in current tax liability Increase in trade and other payables Net cash provided by operating activities Disclosure of financing facilities Refer to note 23 for information regarding financing facilities. Consolidated 2013 $’000 38,469 14,037 753 (29,812) 31,853 2014 $’000 (23,075) 18,044 1,890 115,568 29,284 503 672 (42,789) (2,738) (29,089) (34,675) (34,157) (934) 27,647 25,479 (70,166) 823 19,049 4,135 4,036 219 90,674 104,742 PAGE 75 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014 13. TRADE AND OTHER RECEIVABLES AT AMORTISED COST Current Trade receivables Loan receivables Other receivables Amounts receivable from employee shareholders Accrued income Non-current Amounts receivable from employee shareholders Note (i) (ii) (iii) (iv) (iii) Consolidated 2014 $’000 2013 $’000 19,872 2,043 324 683 22,922 179,435 202,357 682 682 15,746 – 486 406 16,638 140,700 157,338 1,446 1,446 (i) Trade receivables are non-interest bearing and are generally on 30-day terms. An allowance for doubtful debts is made when there is objective evidence that a trade receivable is impaired. An allowance of $884,653 (2013: $173,069) has been recognised as an expense for the current year for specific debtors for which such evidence exists. The amount of the allowance / impairment loss is measured as the difference between the carrying amount of the trade receivables and the estimated future cash flows expected to be received from the relevant debtors. (ii) Credit Facility provided to Empire Oil & Gas NL at a fixed interest rate of 10.38% per annum. Termination of the loan is on 30 September 2014. (iii) Employee shareholder loans are subject to loan deeds and interest is charged at either the Division 7A or the FBT benchmark rates. (iv) Accrued income represents electricity amounts due to be invoiced after 30 June 2014. Details regarding the effective interest rate and credit risk of current receivables are disclosed in note 3. Impaired receivables and receivables past due None of the non-current receivables are impaired or past due. The carrying amounts of non-current receivables are equal to the fair values. PAGE 76 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014ERM POWER ANNUAL REPORT | 2014 14. INVENTORIES Renewable energy certificates(i) Renewable energy certificates recognised under sale and repurchase arrangement(ii) Gas in storage Diesel fuel(i) Consolidated 2013 $’000 24,979 36,383 142 1,949 63,453 2014 $’000 54,315 – 42 2,039 56,396 (i) Renewable energy certificates and diesel fuel are pledged as security against outstanding bank loan and receivables finance facilities at 30 June 2014. (ii) The Group has right of repurchase under sale and repurchase arrangement. The corresponding liability is included within borrowings at 30 June 2013. Refer to Note 23. The liability was repaid during the year ended 30 June 2014. 15. OTHER ASSETS Current Prepayments Security and other deposits (i) Consolidated 2013 $’000 2,027 6,447 8,474 2014 $’000 2,235 8,486 10,721 (i) Refer to Note 29 for further details regarding security deposits. 16. FINANCIAL ASSETS AT FAIR VALUE THROUGH OTHER COMPREHENSIVE INCOME Non-current Shares held in listed entities Consolidated 2013 $’000 6,187 6,187 2014 $’000 7,636 7,636 All shares held in listed entities as at 30 June 2014 have been classified as fair value through other comprehensive income because they are investments that the group intends to hold for the long-term. No dividends have been received in respect of these investments during the current or prior year. Refer note 1(b) for further details. PAGE 77 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014 17. DERIVATIVE FINANCIAL INSTRUMENTS Current assets Electricity derivatives Non-current assets Electricity derivatives Current liabilities Electricity derivatives Non-current liabilities Electricity derivatives Interest rate swaps Consolidated 2013 $’000 27,622 27,622 20 20 17,757 17,757 13,363 33,804 47,167 2014 $’000 2,133 2,133 837 837 114,367 114,367 7,324 33,155 40,479 Derivative financial instruments used by the Group The Group is party to derivative financial instruments in the normal course of business acquired in order to hedge exposure to fluctuations in electricity prices and interest and foreign exchange rates in accordance with the Group’s financial risk management policies. All electricity derivatives are measured at fair value through profit and loss. Interest rate swap contracts – cash flow hedges The Neerabup partnership has limited recourse, variable interest rate project finance in place. This variable interest has been swapped into fixed. Swaps currently in place for the Neerabup partnership cover approximately 98% (2013: 97%) of the variable loan principal outstanding and are timed to expire as each loan repayment falls due. The fixed interest rate is 7.189% (2013: 7.189%) and the variable rate is 1.1% above the BBSY rate which at the end of the reporting period was 2.72% (2013: 2.87%). Swaps in place for Oakey Power Holdings Pty Ltd were terminated in December 2013. For the year ended 30 June 2013 these swaps covered 100% of the variable loan principal outstanding. In 2013, the fixed interest rate was 4.16% and the variable rate was 2.75% above the BBSY rate which at the end of the reporting period was 2.87%. The contracts require settlement of net interest receivable or payable each 90 days. The settlement dates coincide with the dates on which interest is payable on the underlying debt. The contracts are settled on a net basis. The gain or loss from re-measurement of hedging instruments at fair value is recognised in other comprehensive income and deferred in equity in the hedging reserve, to the extent that the hedge is effective. It is reclassified into profit or loss when the hedged interest expense is recognised. There was no hedge ineffectiveness in the current or prior year. Electricity derivative contracts held for trading The maximum exposure to credit risk at the end of the reporting period is the carrying amount of each class of derivative financial asset. PAGE 78 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014ERM POWER ANNUAL REPORT | 2014 17. DERIVATIVE FINANCIAL INSTRUMENTS (CONT.) Derivative financial instruments designated as cash flow hedges The following table indicates the periods in which the cash flows associated with cash flow hedges are expected to impact profit or loss and the fair value of the related hedging instruments. Liabilities Interest rate swaps 12 months or less 1-2 years 2-5 years More than 5 years Consolidated 2014 $’000 2013 $’000 6,440 5,711 11,600 9,404 33,155 7,359 5,994 11,135 9,316 33,804 PAGE 79 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014 18. PROPERTY, PLANT AND EQUIPMENT Consolidated 2014 Cost Land $’000 Capital work in progress $’000 Plant and equipment $’000 Furniture, fittings and improvements $’000 Total $’000 2,914 – (27) (13,588) 435,691 Total $’000 Accumulated depreciation and impairment – – (102,483) Net carrying amount at 30 June 2014 23,109 26,735 380,052 23,109 26,735 482,535 10,530 (4,735) 5,795 542,909 (107,218) 435,691 Opening net carrying amount at 1 July 2013 22,835 26,851 390,599 6,107 446,392 Additions Transfers Disposals Depreciation 268 6 – – 1,518 (1,634) – – Closing net carrying amount at 30 June 2014 23,109 26,735 473 1,065 (27) (12,058) 380,052 655 563 – (1,530) 5,795 Land $’000 Capital work in progress $’000 Plant and equipment $’000 Furniture, fittings and improvements $’000 Consolidated 2013 Cost 22,835 26,851 481,056 9,307 540,049 Accumulated depreciation and impairment – – (90,457) (3,200) (93,657) Net carrying amount at 30 June 2013 22,835 26,851 390,599 6,107 446,392 Opening net carrying amount at 1 July 2012 21,091 21,581 401,971 Additions Disposals Depreciation 1,744 5,270 – – – – 577 (32) 1,137 5,945 (6) 445,780 13,536 (38) (11,917) (969) (12,886) Closing net carrying amount at 30 June 2013 22,835 26,851 390,599 6,107 446,392 Capital work in progress relates to capitalised costs for power station projects. One of the Group’s current generation assets, the Neerabup power station, is project financed by limited recourse debt, meaning the security of project lenders does not extend beyond the particular generation asset. The Group also raised funds for its equity investment in the Neerabup power station by issuing notes in 2008. Those notes are limited-recourse to the Group’s interest in the Neerabup power station. Refer note 23 for details regarding recourse and limited recourse borrowings of the Group. PAGE 80 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014ERM POWER ANNUAL REPORT | 2014 19. EXPLORATION AND EVALUATION COSTS Cost (gross carrying amount) Accumulated amortisation and impairment Net carrying amount Reconciliations Net of accumulated amortisation and impairment at start of year Additions Transfers to gas assets Net of accumulated amortisation and impairment at end of year 20. GAS ASSETS Assets in production Cost (gross carrying amount) Accumulated amortisation and impairment Net carrying amount Reconciliations Net of accumulated amortisation and impairment at start of year Transfer from exploration and evaluation costs Additions Amortisation Net of accumulated amortisation and impairment at end of year Consolidated 2014 $’000 2013 $’000 15,313 12,448 – – 15,313 12,448 12,448 2,865 – 15,313 13,985 7,425 (8,962) 12,448 Consolidated 2014 $’000 2013 $’000 18,652 (2,344) 16,308 17,309 – 1,343 (2,344) 16,308 17,309 – 17,309 – 8,962 8,347 – 17,309 PAGE 81 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014 21. INTANGIBLE ASSETS Consolidated 2014 Cost Accumulated depreciation and impairment Net carrying amount at 30 June 2014 Opening net carrying amount at 1 July 2013 Additions Transfer Amortisation Closing net carrying amount at 30 June 2014 Consolidated 2013 Cost Accumulated depreciation and impairment Net carrying amount at 30 June 2013 Opening net carrying amount at 1 July 2012 Additions Amortisation Closing net carrying amount at 30 June 2013 22. TRADE AND OTHER PAYABLES Current Trade creditors and accruals Other creditors PAGE 82 Capital work in progress $’000 Software internally generated $’000 Software and other $’000 Customer acquisition costs $’000 4 – 4 1,130 4 (1,130) – 4 7,560 (1,845) 5,715 1,052 4,171 1,130 (638) 5,715 3,817 (2,033) 1,784 1,673 461 – (350) 1,784 4,930 (1,509) 3,421 1,996 2,549 – (1,124) 3,421 Capital work in progress $’000 Software internally generated $’000 Software and other $’000 Customer acquisition costs $’000 1,130 – 1,130 – 1,130 – 1,130 2,259 (1,207) 1,052 367 1,020 (335) 1,052 3,356 (1,683) 1,673 2,001 103 (431) 1,673 2,381 (385) 1,996 – 2,381 (385) 1,996 Total $’000 16,311 (5,387) 10,924 5,851 7,185 – (2,112) 10,924 Total $’000 9,126 (3,275) 5,851 2,368 4,634 (1,151) 5,851 Consolidated 2014 $’000 2013 $’000 186,321 156,670 63,081 64,954 249,402 221,624 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014ERM POWER ANNUAL REPORT | 2014 23. BORROWINGS Current Secured Bank loan – Receivables financing facility Bank loan – Inventory repurchase Secured – limited recourse Bank loan – Neerabup working capital facility Bank loan – Neerabup term facility (current portion) Bank loan – Oakey term facility (current portion) Total current borrowings Non-current Secured – limited recourse Bank loan – Neerabup term facility Bank loan – Oakey term facility Convertible notes Total non-current borrowings Total borrowings Note (i) (ii) (iii) (iv) (v) (iv) (v) (vi) Consolidated 2014 $’000 2013 $’000 129,949 – 129,949 3,000 5,079 – 8,079 138,028 59,115 36,383 95,498 3,000 4,453 19,337 26,790 122,288 146,977 151,818 – 46,541 193,518 193,518 19,561 45,184 216,563 216,563 331,546 338,851 Information on credit risk, fair value and interest rate risk exposure of the Group is provided at note 3. (i) (ii) (iii) (iv) (v) (vi) Amounts drawn down on receivables financing facility secured against billed and unbilled electricity sales customer revenue receivables. Sale and repurchase agreement in respect of renewable energy certificates. The equivalent renewable energy certificate assets, over which ERM has the right of repurchase, are included within inventory at 30 June 2014. Amounts drawn down on a limited recourse bank working capital facility by Neerabup Partnership. This debt has recourse to the assets of Neerabup Partnership only. Amounts drawn down on a limited recourse term debt facility in respect of the Neerabup Partnership. This debt has recourse to the assets of Neerabup Partnership only. Amounts drawn down on a limited recourse term debt facility in respect of the Oakey Power Station. This debt had recourse to the assets of Oakey Power Holdings Pty Ltd only. The debt was repaid in December 2013. Convertible notes are redeemable by the issuer from 30 September 2010 until maturity in February 2023. Notes have a coupon rate that is variable based on BBSY plus 4%. The notes are accounted for using the effective interest method at 8.79% (2013: 8.84%). The notes can only be converted to shares in the issuing subsidiary upon failure to redeem them at maturity or other named event of default. The notes have recourse to the Group’s 50% interest in the Neerabup partnership only. PAGE 83 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014 23. BORROWINGS (CONT.) Financing facilities available The Group’s financing facilities predominantly relate to limited recourse power station development activities. Funding is drawn down progressively according to project time lines. At balance date, the following financing facilities had been negotiated and were available: Total facilities – bank loans Facilities used at balance date – bank loans Facilities unused at balance date – bank loans 24. PROVISIONS Current Employee benefits – annual leave Non-current Employee benefits – long service leave Movements in provisions Carrying amount at start of the year Additional provision recognised and charged to profit and loss Amounts used during the year Consolidated 2013 $’000 377,645 336,760 40,885 2014 $’000 356,343 326,292 30,051 Consolidated 2014 $’000 2,014 2,014 897 897 2,412 2,256 (1,757) 2,911 2013 $’000 1,818 1,818 594 594 1,732 1,871 (1,191) 2,412 The entire amount of the annual leave provision is presented as current since the Group does not have an unconditional right to defer settlement for any of these obligations. In addition, based on past experience, the Group expects all employees to take the full amount of accrued leave or require payment within the next 12 months. PAGE 84 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014ERM POWER ANNUAL REPORT | 2014 25. CONTRIBUTED EQUITY Issued ordinary shares – fully paid Treasury shares (a) Movement in ordinary share capital At the beginning of the period Issue of shares – employee incentive scheme Issue of shares – dividend reinvestment plan Vesting and exercise of options Vesting of shares – employee incentive scheme Transfer from / (to) treasury shares Issue of shares – capital raising Consolidated Consolidated 2014 Number of shares 2013 Number of shares 2014 $’000 2013 $’000 239,269,727 203,332,935 328,762 237,837 (2,916,707) (2,642,681) (6,425) (4,546) 236,353,020 200,690,254 322,337 233,291 Note 25(a) 25(b) 203,332,935 168,295,039 237,837 169,263 1,404,304 991,885 840,130 416,590 – – – 8,629,421 – – 3,566 2,040 286 2,212 (199) 33,692,358 25,000,000 84,700 2,024 1,104 6,935 – – 60,000 (1,489) Transaction costs arising on share issue (net of tax) – – (1,680) At the end of the period 239,269,727 203,332,935 328,762 237,837 (b) Terms and conditions of contributed equity Ordinary shares During the year ended 30 June 2014, the Company conducted a capital raising issuing 29.5m ordinary fully paid shares at $2.53 per share, raising a total of $74.7m. The Company also issued an additional 4.2m shares through a share purchase plan at $2.40 per share, raising $10m. Transaction costs of $1.7m after tax were incurred in raising these funds. Ordinary shares have the right to receive dividends as declared and, in the event of winding up the Company, to participate in the proceeds from the sale of all surplus assets in proportion to the number of shares held. Ordinary shares entitle their holder to one vote, either in person or by proxy, at a meeting of the Company. Ordinary shares have no par value and the Company does not have a limited amount of authorised capital. Treasury shares Treasury shares are shares that are held in trust for the purpose of issuing shares under employee share incentive schemes. For details of shares and options issued under employee share schemes (see note 27). PAGE 85 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014 Note 26. RESERVES Cash flow hedge reserve Fair value reserve Transactions with non-controlling interests Share based payment reserve Movements Cash flow hedge reserve Balance at the beginning of the year Revaluation – gross Revaluation – deferred tax Transfer to profit and loss (net of tax) Transactions with non-controlling interests Balance at the end of the year Fair value reserve Balance at the beginning of the year Revaluation – gross Revaluation – deferred tax Balance at the end of the year Share based payment reserve Balance at the beginning of the year Share based payments vested Share based payment expense Balance at the end of the year Transactions with non-controlling interests reserve Balance at the beginning of the year Transfer of non-controlling interest from cash flow hedge reserve Acquisition of additional ownership in Oakey Power Holdings Pty Ltd 30(d) Balance at the end of the year PAGE 86 Consolidated 2013 $’000 (23,595) (7,143) (5,868) 1,830 2014 $’000 (23,208) (9,893) (14,404) 1,222 (46,283) (34,776) (23,595) 153 (46) 348 (68) (29,026) 7,758 (2,327) – – (23,208) (23,595) (7,143) (3,929) 1,179 (9,893) 1,830 (2,498) 1,890 1,222 (2,671) (6,388) 1,916 (7,143) 1,252 (175) 753 1,830 (5,868) (5,868) 68 (8,604) – – (14,404) (5,868) ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014ERM POWER ANNUAL REPORT | 2014 26. RESERVES (CONT.) (a) Cash flow hedge reserve The cash flow hedge reserve comprises the effective portion of the cumulative net change in the fair value of cash flow hedging instruments related to hedged transactions that have not yet occurred. Fair value reserve (b) Changes in the fair value and exchange differences arising on translation of investments, such as equities classified as fair value through other comprehensive income, are recognised in other comprehensive income, as described in note 1(i) and accumulated in a separate reserve within equity. Transactions with non-controlling interests (c) This reserve is used to record the differences described in note 1(b) which may arise as a result of transactions with non-controlling interests that do not result in a loss of control. (d) Share based payment reserve The share-based payments reserve is used to recognise: • the grant date fair value of options issued to employees but not exercised • the grant date fair value of shares issued to employees • the issue of shares held by the LTIST and LTIOT Employee Share Trusts to employees. Refer to note 27 for details of the employee share and option incentive schemes. PAGE 87 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014 27. SHARE BASED PAYMENTS Long term incentives (a) The objective of the Long Term Incentive Scheme is to provide incentives to focus on long term shareholder returns. Participation in the scheme is open to selected employees (including the Managing Director) who are invited by the board. These incentive awards have been granted by way of offers to participate in both the Long Term Incentive Share Trust (LTIST) and the Long Term Incentive Option Trust (LTIOT). LTIST i. Shares are acquired by a trustee who holds those shares on behalf of participants. The shares are acquired by the trustee either subscribing for new shares or purchasing shares on market. Vesting conditions may be a combination of service and performance hurdles, as determined by the directors. Participants hold their interest in the LTIST through units, where one unit represents one share. Participants are issued units at the prevailing market value of the shares. A participant may instruct the trustee how to exercise their vote in the case of a poll at a meeting of the Company. If the participant’s employment ceases prior to the shares vesting, the board will determine if the participant’s units in the LTIST are forfeit or, for redundancy, death or permanent disability, or in circumstances that the board determines appropriate, continue to be held to the end of the performance period at which time the proportion to vest will be re-assessed. Early vesting may occur on a change of control of the Company, being a material change in the composition of the board initiated as a result of a change of ownership of shares and the purchaser of the shares requiring (or agreeing with other shareholders to require) that change in board composition, or in other circumstances that the board determines appropriate. The fair value is independently determined using a Monte Carlo simulation (using a Black-Scholes framework). The model inputs for restricted shares granted are shown in the table below. Assessed fair value per share at grant date Number of units allocated under the plan during the financial year Share price at grant date Exercise price Expected price volatility of the Company’s shares based on historic volatility Risk free interest rate Expected vesting date Dividend yield Proportion subject to vesting on satisfaction of total security holder return (TSR) performance 2014 financial year grant 2013 financial year grant $1.99 787,098 $2.64 Nil 34.8% 2.84% $1.51 991,885 $2.01 Nil 33.8% 2.65% 3 years after issue 3 years after issue 5.53% 100% 5.72% 100% LTIOT and other option grants ii. Options were granted during the 2008 and 2011 financial years. No options have been granted subsequent to the 2011 financial year. 2011 financial year grant – LTIOT Participants were issued units at the prevailing market value of the options. The assessed fair value at grant date of options granted during the year ended 30 June 2011 was 10.43 cents. The fair value at grant date is determined using a Black-Scholes option pricing model that takes into account the exercise price, the term of the option, the share price at grant date and expected price volatility of the underlying share, the expected dividend yield and the risk free interest rate for the term of the option. Early vesting and the consequences of cessation of employment prior to vesting are identical to the LTIST as described above. PAGE 88 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014ERM POWER ANNUAL REPORT | 2014 27. SHARE BASED PAYMENTS (CONT.) Details of movements in each option plan are set out below. Financial year Grant Date Expiry date Exercise price Balance at start of the year Granted during the year Forfeited during the year Options exercised during the year Balance at end of the year Vested and exercisable at end of the year Number Number Number Number Number Number 2011 2011 Total 1/11/2010 1/11/2017 $2.75 1,235,088 8/11/2010 8/11/2017 $2.75 242,706 1,477,794 – – – – – – – – – 1,235,088 1,235,088 242,706 242,706 1,477,794 1,477,794 The weighted average remaining contractual life of options outstanding at the end of the period is 3.4 years. 2008 financial year grant In June 2008, the Company granted options with a five year exercise period and an exercise price of $0.806. There were no performance conditions attached to the options. The assessed fair value at grant date of options granted during the year ended 30 June 2008 was 8.97 cents. The fair value at grant date is determined using a Black-Scholes option pricing model that takes into account the exercise price, the term of the option, the share price at grant date and expected price volatility of the underlying share, the expected dividend yield and the risk free interest rate for the term of the option. The balance at the start and end of the financial year was nil. (b) Other awards The Company may offer awards outside of the standard incentive plans. In August 2013, 92,285 Performance Rights were granted as part of an employee retention strategy. The Performance Rights are subject to a 5 year vesting period and will be satisfied, at the board’s discretion, in cash or shares, subject to continuous full-time employment with the Company. The notional share price at grant date was $2.709 per share. The vesting value will be the number of Performance Rights held, multiplied by the higher of either the notional issue price, or the 10 day VWAP at the vesting date. (c) Amounts expensed in respect of share-based payment transactions Expenses recognised in respect of share-based payment transactions during the period as part of employee benefit expense: Shares issued under long term employee share scheme Consolidated 2013 $’000 753 753 2014 $’000 1,890 1,890 PAGE 89 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014 2014 $’000 2013 $’000 203,766 365,684 9,259 9,259 84,418 242,589 7,921 7,921 356,425 234,668 328,762 237,837 (6,425) (9,894) 1,222 42,760 (4,546) (7,143) 1,830 6,690 356,425 234,668 61,839 (2,750) 59,089 (2,431) (4,472) (6,903) 28. PARENT ENTITY FINANCIAL INFORMATION Summary financial information (a) The individual financial statements for the parent entity show the following aggregate amounts Statement of financial position Current Assets Total Assets Current Liabilities Total liabilities Net assets Shareholders’ equity Contributed equity Treasury shares Fair value reserves Share option reserve Retained earnings Total equity Profit / (loss) for the year Other comprehensive loss Total comprehensive profit / (loss) (b) Guarantees entered into by the parent entity The Company does not have any guarantees entered into by the parent entity at 30 June 2014. (c) Contingent liabilities of the parent entity The Company does not have any contingent liabilities at 30 June 2014. (d) Contractual commitments for acquisition of property, plant and equipment There are no contractual commitments for the acquisition of property, plant and equipment at 30 June 2014. PAGE 90 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014ERM POWER ANNUAL REPORT | 2014 29. COMMITMENTS AND CONTINGENCIES (a) Capital expenditure commitments Estimated capital expenditure contracted for at balance date, not provided for but payable (including share of associates and joint ventures): – not later than one year – later than one year and not later than five years – later than five years (b) Lease expenditure commitments Operating leases (non-cancellable): Minimum lease payments – not later than one year – later than one year and not later than five years – later than five years Aggregrate lease expenditure contracted for at balance date Consolidated 2014 $’000 2013 $’000 3,492 1,418 – – – – 3,492 1,418 2,787 17,573 16,935 37,295 1,556 15,892 21,403 38,851 The Group leases office premises in Brisbane, Sydney, Melbourne and Perth. Operating lease commitments shown above are net of any cash incentives under the respective lease agreements. PAGE 91 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014 29. COMMITMENTS AND CONTINGENCIES (CONT.) (c) Contingent liabilities Details of contingent liabilities are set out below. The directors are of the opinion that provisions are not required in respect of these items as it is not probable that a future sacrifice of economic benefits will be required or the amount is not capable of reliable measurement. Bank guarantees – Australian Energy Market Operator and other counterparties Bank guarantees – Lease arrangements Futures margin deposits Security deposits Bank guarantees – Western Power Bank guarantees – Powerlink Bank guarantees – Neerabup / Contractor dispute Bank guarantees – AGL Hydro Partnership Bank guarantees – NSW exploration licence Note (i) (ii) (iii) (iv) (v) (vi) (vii) (viii) (ix) Consolidated 2014 $’000 2013 $’000 153,592 112,164 2,945 59,660 8,019 300 – 1,750 4,227 60 3,320 26,209 5,971 300 2,200 1,750 4,227 60 230,553 156,201 The Group has provided bank guarantees in favour of the Australian Energy Market Operator to support its obligations to settle electricity purchases from the National Electricity Market. Bank guarantees have also been provided to various counterparties in relation to electricity derivatives. A portion of the guarantees are supported by term deposits. (vii) The Group has provided bank guarantees in relation to lease arrangements for premises in Brisbane, Sydney and Melbourne. These guarantees are supported by term deposits. Futures margin deposits represent interest bearing cash lodged with the Group’s futures clearing brokers. The deposits are in relation to various futures contracts on the Australian Stock Exchange and may be retained by the clearing brokers in the event that the Group does not meet its contractual obligations. Security deposits represent interest bearing cash lodged as eligible credit support with various counterparties to the Group’s electricity derivative contracts and may be retained by those counterparties in the event that the Group does not meet its contractual obligations. The Group has provided a bank guarantee in favour of Western Power. This can be called upon if the Neerabup partnership fails to pay its monthly transmission invoices. (i) (ii) (iii) (iv) (v) (vi) The Group has provided a bank guarantee in favour of its partner in the NewGen Neerabup Partnership under an indemnity agreement for a contractor dispute. Lend Lease Services Pty Limited (formerly Conneq Infrastructure Services (Australia) Pty Limited (Lend Lease)) served a notice of dispute on the NewGen Neerabup Partnership on 27 August 2010 in relation to a liquidated damages claim made by the NewGen Neerabup Partnership and also alleging several breaches of the balance of plant contract. The notice of dispute claims that Lend Lease is not liable to pay a sum of approximately $12.0m levied against it by the NewGen Neerabup Partnership as liquidated damages for certain delays under the balance of plant contract. The notice also alleges that the NewGen Neerabup Partnership has failed to pay Lend Lease a sum of approximately $770,000 and also claims the sum of approximately $8.0m for delay costs. The dispute is currently being progressed through arbitration in line with the dispute resolution provisions contained within the contract. Should the dispute settle in favour of the Partnership the Group expects to recognise the settlement proceeds as revenue. (viii) The Group has provided a bank guarantee in favour of the AGL Hydro Partnership in the event that there are damages resulting from the Oakey power station failing an annual capacity test. This guarantee is supported by a term deposit. The Group provided a bank guarantee in favour of Powerlink for $2.2m under a Connection Agreement. This guarantee was supported by a term deposit. (ix) The Group has provided bank guarantees in favour of the NSW Government in connection with its gas exploration licences in NSW. These guarantees are supported by term deposits. PAGE 92 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014ERM POWER ANNUAL REPORT | 2014 30. INTERESTS IN OTHER ENTITIES (a) Subsidiary companies The Consolidated Entity consists of a number of wholly or majority owned subsidiaries as well as interests in joint operations for power station projects and gas interests. Place of incorporation Percentage of equity interest held by the Company 2014 % 2013 % Percentage of equity interest held by the non-controlling interests 2014 % 2013 % Name Material operating subsidiaries ERM Financial Services Pty Ltd ERM Gas Pty Ltd ERM Holdings Pty Ltd ERM Neerabup Power Pty Ltd ERM Power Developments Pty Ltd Powermetric Metering Pty Ltd ERM Power Generation Pty Ltd ERM Power Retail Pty Ltd ERM Land Holdings Pty Ltd ERM Neerabup Pty Ltd SAGE Utility Systems Pty Ltd Oakey Power Holdings Pty Ltd1 Other non-material subsidiaries MetroWest Pty Ltd2 ERM Wellington 1 Holdings Pty Ltd Braemar 3 Holdings Pty Ltd ERM Braemar 3 Pty Ltd ERM Gas WA01 Pty Ltd ERM Power Utility Systems Pty Ltd ACN 162 696 335 Pty Ltd3 ERM Finance Pty Ltd ERM Braemar 3 Power Pty Ltd ERM Oakey Power Holdings Pty Ltd Richmond Valley Solar Thermal Pty Ltd ERM Power Services Pty Ltd Oakey Power Pty Ltd 1,4 Oakey Power Finance Pty Ltd 1,4 Oakey Power Operations Pty Ltd 1,4 Oakey Power Constructions Pty Ltd 1,4 Private Power Investors Pty Ltd 1,4 Elrex Pty Ltd 1,4 QLD QLD QLD VIC VIC NSW VIC VIC QLD VIC VIC ACT QLD QLD QLD QLD VIC QLD QLD QLD QLD NSW QLD VIC ACT ACT ACT ACT ACT NSW 100 100 100 100 100 100 100 100 100 100 100 100 – 100 100 100 100 100 – 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 83.3 100 100 100 100 100 100 100 – 100 100 100 100 83.3 83.3 83.3 83.3 83.3 83.3 – – – – – – – – – – – – – – – – – – – – – – – – – – – – – – 1 Non-controlling interest purchased during the year ended 30 June 2014. Refer note 30(d) for further details. 2 Deregistered in December 2013. 3 Sold to Trevor St Baker in August 2013. 4 Deregistered in July 2014. The consolidated financial statements incorporate the assets, liabilities and results of the above subsidiaries in accordance with the accounting policy described in note 1(b). The equity interest is equal to the proportion of voting power held. – – – – – – – – – – – 16.7 – – – – – – – – – – – – 16.7 16.7 16.7 16.7 16.7 16.7 PAGE 93 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014 30. INTERESTS IN OTHER ENTITIES (CONT.) (b) Significant joint operations – power station projects As at 30 June 2014 and 30 June 2013, the Group has the following interests in power station projects with other external parties: Neerabup Power Station: NewGen Power Neerabup Pty Ltd NewGen Neerabup Pty Ltd NewGen Neerabup Partnership Oakey Power Station: ERM Power Trust ERM Oakey Power Pty Ltd Queensland Electricity Investors Pty Ltd Principle place of business 2014 % 2013 % Interest Held QLD QLD WA QLD QLD QLD 50 50 50 100 100 100 50 50 50 50 50 50 The consolidated entity’s proportionate share of assets employed and liabilities incurred in power station projects classified as joint operations is summarised below. CURRENT ASSETS Cash and cash equivalents Trade and other receivables Inventories Other assets TOTAL CURRENT ASSETS NON-CURRENT ASSETS Property, plant and equipment Intangible assets TOTAL NON-CURRENT ASSETS TOTAL ASSETS CURRENT LIABILITIES Trade and other payables Borrowings Provisions TOTAL CURRENT LIABILITIES NON-CURRENT LIABILITIES Borrowings Derivative financial instruments TOTAL NON-CURRENT LIABILITIES TOTAL LIABILITIES NET ASSETS PAGE 94 Consolidated 2014 $’000 2013 $’000 10,488 4,579 42 587 10,458 3,379 142 195 15,696 14,174 183,662 188,425 23 183,685 199,381 1,779 8,079 51 9,909 146,976 33,155 180,131 190,040 9,341 – 188,425 202,599 587 7,453 69 8,109 151,817 33,220 185,037 193,146 9,453 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014ERM POWER ANNUAL REPORT | 2014 30. INTERESTS IN OTHER ENTITIES (CONT.) Capital expenditure commitments Estimated capital expenditure contracted for at balance date, not provided for but payable – not later than one year – later than one year and not later than five years – later than five years Consolidated 2014 $’000 2013 $’000 73 – – 73 – – – – (c) Other joint operations The consolidated entity also holds interests in a number of unincorporated gas joint ventures. The principal activities of these joint operations are gas exploration, development and production. (d) Transactions with non-controlling interests In December 2013, a wholly owned subsidiary of ERM Power Limited acquired an additional interest in Queensland Electricity Investors Pty Ltd “QEI”. The effect of the transaction was such that the non-controlling interest in Oakey Power Holdings Pty Ltd (“OPH”) was reduced from 16.7% to Nil at a total cash cost of $30m. The carrying amount of the non-controlling interest in OPH on the date of the acquisition of the QEI shares was $23.3m. The Group has recognised a decrease in the non-controlling interest of $8.6m and an increase in equity attributable to ERM Power Limited of $8.6m. Adjustment to non-controlling interest Consideration paid inclusive of transaction costs and acquired liabilities net of tax Excess of consideration paid recognised in the transactions with non-controlling interests reserve within equity Consolidated 2014 $’000 (23,330) 31,934 8,604 PAGE 95 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014 31. RELATED PARTY DISCLOSURES Parent Company ERM Power Limited is the parent entity of the consolidated entity. Balances and transactions between the Parent entity and its wholly owned subsidiaries (which are related parties) have been eliminated on consolidation and are not disclosed in this note. Details of transactions between the consolidated entity and other related parties are disclosed below. Equity interests in subsidiaries and jointly controlled entities Details of interests in subsidiaries are set out in note 30. Details of interests in jointly controlled entities are set out in note 30. Key management personnel Disclosures relating to key management personnel are set out in the Directors’ Report. Transactions with related parties Transaction type Loans from directors Loan repayments Interest and facility fees paid on director loans Director related entity transactions Consulting fees Consolidated 2014 $’000 2013 $’000 – – 5,200,000 630,838 150,000 245,000 Note (i) (ii) (iii) (i) (ii) (iii) Loans of $5.2m from a director related entity bearing interest at 12% per annum were repaid during the year ended 30 June 2013. Loan of $5.2m ($0.8m advanced on 4 July 2011) from a related entity of Trevor St Baker in relation to funding of additional 50% interest in Oakey acquisition. The loan was interest bearing at 12% per annum. Facility fees of $228,800 were paid during the year ended 30 June 2012. The Company had a consulting agreement with Sunset Power Pty Ltd (a related party of Trevor St Baker) which was extended to June 2014. Under this agreement the Company paid $150,000 to Sunset Power Pty Ltd (“Sunset”) for services provided for the current financial year (2013:$245,000). Sunset is also entitled to be reimbursed for all reasonable expenses incurred in providing these services. Transactions with Empire Oil & Gas NL During the year, senior members of the ERM Power Limited’s executive management team were appointed to the roles of acting CEO and Director of Empire Oil & Gas NL (“Empire”) respectively for a period of three to seven months during the current financial year. The appointments were to assist during the transition period whilst this company searched for a new CEO and independent director. In March 2014, Empire successfully appointed a new CEO and the ERM Power Limited senior member formerly acting CEO was assigned to Company Secretary. Other ERM Power Limited employees were also used on an adhoc basis to assist in this transition period. Empire has paid ERM Power various daily arms-length rates for these services consistent with each individuals skill set as well as any reasonable expenses incurred in providing these services. Charges in respect of the services provided for the year ended 30 June 2014 were $641,169. In December 2013 ERM Power Limited extended a $2m working capital credit facility to Empire. The key terms of the facility currently are: • Repayable at 30 September 2014. • Interest rate based on the highest of the big-four banks’ benchmark overdraft rate plus 1 per cent, secured. The interest rate is fixed for the period of the facility at the time of first draw-down. As at 30 June 2014, the facility is drawn down at $2m and aggregated with any outstanding interest payable. PAGE 96 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014ERM POWER ANNUAL REPORT | 2014 31. RELATED PARTY DISCLOSURES (CONT.) Other related party transactions In the normal course of business the Company enters into the following transactions with related parties: • Project management and operations management fees are charged to jointly controlled entities; • Interest is paid on shareholder loans; and • Directors personal travel insurance is provided under standard terms of a directors and officers business travel insurance policy taken out by the Company. Cover under this policy for directors personal travel is provided by the insurer at no additional cost to the Company. During the year ended 30 June 2014, Andrew St Baker was employed by the Company on terms and conditions no more favourable than those that would have been adopted if dealing at arm’s length with an unrelated person. Total payments for the year ended 30 June 2014 were $301,579 in cash salary and superannuation (2013: $234,588). During the year ended 30 June 2014, the Company provided administrative support to the St Baker Wilkes Indigenous Educational Foundation Limited (SWIEF), of which Trevor St Baker is the co-founder and Chairman and Tony Iannello is a Director. SWIEF is the corporate trustee for two charitable funds which provide grants to indigenous students for ongoing tertiary education. The value of the support provided was $20,406. During the year ended 30 June 2014, the Company sold a dormant subsidiary ACN 162 696 335 Pty Ltd, to Trevor St Baker for the arm’s length consideration of $1. There is no allowance account for impaired receivables in relation to any outstanding balances, and no expense has been recognised in respect of impaired receivables due from related parties. Transactions with jointly controlled entities: Movements in net loans advanced / (repaid) Current trade receivables balance Current trade payables balance Project fees and operations management fees Consolidated 2014 $’000 2013 $’000 13,084 112,893 (89,119) 121,244 184,661 (344,799) 2,606,032 2,639,924 PAGE 97 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014 32. KEY MANAGEMENT PERSONNEL Key management personnel compensation Short-term and long-term employee benefits Post-employment benefits Termination benefits Share-based payments Detailed remuneration disclosures are provided in the remuneration report. 33. AUDITORS’ REMUNERATION Amounts received or due and receivable by PricewaterhouseCoopers Australia for: An audit or review of the financial report of the entity and any other entity in the Group Amounts received or due and receivable by PricewaterhouseCoopers Australia for non-audit services: Other agreed-upon procedures in relation to the entity and any other entity in the consolidated Group(i) Consolidated 2014 $ 2013 $ 3,819,844 3,748,920 259,891 235,999 – – 840,437 630,988 4,920,172 4,615,907 Consolidated 2014 $ 2013 $ 582,910 582,910 513,834 513,834 1,196,808 1,196,808 199,930 199,930 (i) For the year ended 30 June 2014 these services include due diligence services in relation to the Company’s bid to acquire the Macquarie Generation assets PAGE 98 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014ERM POWER ANNUAL REPORT | 2014 34. EARNINGS PER SHARE Basic (loss) / earnings per share Diluted (loss) / earnings per share Consolidated Consolidated 2014 Number of shares ‘000 226,328 226,328 2013 Number of shares ‘000 175,666 175,666 2014 Cents (10.56) (10.56) 2013 Cents 20.80 20.80 Reconciliation of weighted average number of ordinary shares Weighted average number used in calculating basic earnings per share 226,328 175,666 Effect of share options on issue – – Weighted average number used in calculating diluted earnings per share 226,328 175,666 Information concerning earnings per share Options Options granted are considered to be potential ordinary shares and taken into account in the determination of diluted earnings per share. They are not included in the determination of basic earnings per share. Reconciliation of earnings used in calculating earnings per share Basic earnings per share (Loss) / profit attributable to the ordinary equity holders of the Company used in calculating basic earnings per share From continuing operations Diluted earnings per share (Loss) / profit attributable to the ordinary equity holders of the Company used in calculating diluted earnings per share Consolidated 2014 $’000 2013 $’000 (23,897) 36,539 From continuing operations (23,897) 36,539 35. EVENTS AFTER THE REPORTING PERIOD Since 30 June 2014 there have been no other matters or circumstances not otherwise dealt with in the financial report that have significantly or may significantly affect the Group. PAGE 99 ERM POWER LIMITEDNOTES TO THE CONSOLIDATED FINANCIAL STATEMENTSFOR THE YEAR ENDED 30 JUNE 2014 ERM POWER LIMITED DIRECTORS’ DECLARATION In the opinion of the directors of ERM Power Limited (“Company”): (a) the financial statements and notes set out on pages 38 to 99 are in accordance with the Corporations Act 2001, including: i. ii. giving a true and fair view of the financial position of the consolidated entity as at 30 June 2014 and of its performance for the year then ended, and complying with Australian Accounting Standards (including the Australian Accounting Interpretations), the Corporations Regulations 2001 and other mandatory professional reporting requirements. (b) the financial report complies with International Financial Reporting Standards as disclosed in note 1; (c) there are reasonable grounds to believe that the Company will be able to pay its debts as and when they become due and payable; Note 1(a) confirms that the financial statements also comply with International Financial Reporting Standards as issued by the International Accounting Standards Board. The directors have been given the declarations by the chief executive officer and chief financial officer required by section 295A of the Corporations Act 2001. Signed in accordance with a resolution of the directors: Tony Bellas Chairman 21 August 2014 PAGE 100 ERM POWER ANNUAL REPORT | 2014 INDEPENDENT AUDITOR’S REPORT TO THE MEMBERS OF ERM POWER LIMITED Independent auditor’s report to the members of ERM Power Limited Report on the financial report We have audited the accompanying financial report of ERM Power Limited (the company), which comprises the statement of financial position as at 30 June 2014, the income statement, statement of comprehensive income, statement of changes in equity and statement of cash flows for the year ended 30 June 2014, a summary of significant accounting policies, other explanatory notes and the directors’ declaration for ERM Power Limited (the consolidated entity). The consolidated entity comprises the company and the entities it controlled at the period’s end or from time to time during the financial period. Directors’ responsibility for the financial report The directors of the company are responsible for the preparation of the financial report that gives a true and fair view in accordance with Australian Accounting Standards and the Corporations Act 2001 and for such internal control as the directors determine is necessary to enable the preparation of the financial report that is free from material misstatement, whether due to fraud or error. In Note 1(a), the directors also state, in accordance with Accounting Standard AASB 101 Presentation of Financial Statements, that the financial statements comply with International Financial Reporting Standards. Auditor’s responsibility Our responsibility is to express an opinion on the financial report based on our audit. We conducted our audit in accordance with Australian Auditing Standards. Those standards require that we comply with relevant ethical requirements relating to audit engagements and plan and perform the audit to obtain reasonable assurance whether the financial report is free from material misstatement. An audit involves performing procedures to obtain audit evidence about the amounts and disclosures in the financial report. The procedures selected depend on the auditor’s judgement, including the assessment of the risks of material misstatement of the financial report, whether due to fraud or error. In making those risk assessments, the auditor considers internal control relevant to the consolidated entity’s preparation and fair presentation of the financial report in order to design audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the entity’s internal control. An audit also includes evaluating the appropriateness of accounting policies used and the reasonableness of accounting estimates made by the directors, as well as evaluating the overall presentation of the financial report. We believe that the audit evidence we have obtained is sufficient and appropriate to provide a basis for our audit opinion. Independence In conducting our audit, we have complied with the independence requirements of the Corporations Act 2001. PricewaterhouseCoopers, ABN 52 780 433 757 Riverside Centre, 123 Eagle Street, BRISBANE QLD 4000, GPO Box 150, BRISBANE QLD 4001 T: +61 7 3257 5000, F: +61 7 3257 5999, www.pwc.com.au Liability limited by a scheme approved under Professional Standards Legislation. PAGE 101 INDEPENDENT AUDITOR’S REPORT TO THE MEMBERS OF ERM POWER LIMITED Auditor’s opinion In our opinion: (a) the financial report of ERM Power Limited is in accordance with the Corporations Act 2001, including: (i) (ii) giving a true and fair view of the consolidated entity's financial position as at 30 June 2014 and of its performance for the year ended on that date; and complying with Australian Accounting Standards (including the Australian Accounting Interpretations) and the Corporations Regulations 2001. (b) the financial report and notes also comply with International Financial Reporting Standards as disclosed in Note 1(a). Report on the Remuneration Report We have audited the remuneration report included in pages 28 to 39 of the directors’ report for the year ended 30 June 2014. The directors of the company are responsible for the preparation and presentation of the remuneration report in accordance with section 300A of the Corporations Act 2001. Our responsibility is to express an opinion on the remuneration report, based on our audit conducted in accordance with Australian Auditing Standards. Auditor’s opinion In our opinion, the remuneration report of ERM Power Limited for the year ended 30 June 2014 complies with section 300A of the Corporations Act 2001. Matters relating to the electronic presentation of the audited financial report This auditor’s report relates to the financial report and remuneration report of ERM Power Limited (the company) for the year ended 30 June 2014 included on ERM Power Limited’s web site. The company’s directors are responsible for the integrity of ERM Power Limited’s web site. We have not been engaged to report on the integrity of this web site. The auditor’s report refers only to the financial report and remuneration report named above. It does not provide an opinion on any other information which may have been hyperlinked to/from the financial report or the remuneration report. If users of this report are concerned with the inherent risks arising from electronic data communications they are advised to refer to the hard copy of the audited financial report and remuneration report to confirm the information included in the audited financial report and remuneration report presented on this web site. PricewaterhouseCoopers Tim Allman Partner PAGE 102 Brisbane 21 August 2014 ERM POWER ANNUAL REPORT | 2014 ERM POWER LIMITED SHARE AND SHAREHOLDER INFORMATION TWENTY LARGEST SHAREHOLDERS The following table sets out the 20 largest shareholders in ERM Power Limited (“the Company”) (when multiple holdings are grouped together) and the percentage each holds of the 239,269,727 shares on issue as at 20 August 2014: Shareholders Number of shares % of issued shares Energy Resource Managers Holdings Pty Ltd UBS Wealth Management Australia Nominees Pty Ltd J P Morgan Nominees Australia Limited Gaffwick Pty Limited National Nominees Limited Ilwella Pty Limited Citicorp Nominees Pty Limited HSBC Custody Nominees (Australia) Limited RBC Investor Services Australia Nominees Pty Ltd Trinity Management Pty Ltd Sunset Power C Pty Ltd Sunset Power D Pty Ltd Philip St Baker & Peta St Baker UBS Nominees Pty Ltd BNP Paribas Noms Pty Ltd WH & LL St Baker Pty Ltd Argo Investments Limited St Baker-Childs Investments Pty Ltd Trevor and Judith St Baker Family Philanthropic Pty Ltd Mr Matthew David John Forrest 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 Total DISTRIBUTION OF SHARES The following table summarises the distribution of shares as at 20 August 2014: Ordinary Shares 1 – 1,000 1,001 – 5,000 5,001 – 10,000 10,000 – 100,000 100,001 – and over Total 43,549,489 32,954,644 17,213,577 11,895,238 11,555,370 11,209,001 11,087,746 6,892,633 5,732,400 5,290,923 5,160,934 5,160,934 4,109,187 3,507,412 1,795,628 1,442,100 1,224,266 1,199,532 1,025,242 1,008,516 18.20 13.77 7.19 4.97 4.83 4.68 4.63 2.88 2.40 2.21 2.16 2.16 1.72 1.47 0.75 0.60 0.51 0.50 0.43 0.42 183,014,772 76.48 Number of shareholders % of issued shares 568 1,417 983 1,163 120 4,251 The number of investors holding less than a marketable parcel of 248 shares was 191, holding 11,817 shares. 0.11 1.89 3.23 11.42 83.35 100.00 PAGE 103 ERM POWER LIMITED SHARE AND SHAREHOLDER INFORMATION SUBSTANTIAL SHAREHOLDERS The following table shows holdings of five per cent or more of voting rights as notified to the Company under the Corporations Act 2001, Section 671B. Class of Securities Identity of person or group Date of notice received Relevant interest in number of securities Percentage of total voting rights Ordinary Shares Trevor Charles St Baker1 25/11/2013 85,610,647 35.86% 1 Trevor Charles St Baker controls each registered shareholder of Energy Resource Managers Holdings Pty Ltd as trustee for the Energy Resource Managers Trust, Sunset Power Pty Ltd as trustee for the St Baker Family Trust, Sunset Power A Pty Ltd as trustee for Sunset Power Trust A, Sunset Power B Pty Ltd as trustee for Sunset Power Trust B, Sunset Power C Pty Ltd as trustee for Sunset Power Trust C, Sunset Power D Pty Ltd as trustee for the Sunset Power Trust D, Baygrove Pty Ltd as trustee for ERM Consultants STF S/F, Sunset Power Holdings Pty Ltd and Trevor & Judith St Baker Family Philanthropic Pty Ltd as trustee for the Trevor & Judith St Baker Family Foundation. Trevor is also a joint registered holder of TC & JK St Baker as trustee for family members VOTING RIGHTS As a meeting of members, each member who is entitled to attend and vote may attend and vote in person or by proxy, attorney or representative. On a show of hands, every person present who is a member, proxy, attorney or representative, shall have one vote and on a poll, every member who is present in person or by proxy, attorney or representative shall have one vote for each share held. SECURITIES EXCHANGE LISTING The Company’s shares are traded on the Australian Securities Exchange under the symbol “EPW”. UNQUOTED SECURITIES As at 20 August 2014, there were 1,477,794 options to acquire fully paid ordinary shares. The options do not carry any entitlement to participate in any share issue. All options expire on their expiry date or as otherwise determined by the board. Expiry Date 1 November 2017 8 November 2017 Issue price of shares (cents) 275.0 275.0 Number under option 1,235,088 242,706 Number of holders 22 1 PAGE 104 ERM POWER ANNUAL REPORT | 2014 CORPORATE DIRECTORY MELBOURNE Level 3 90 Collins Street Melbourne VIC 3000 Tel: (03) 9214 9333 Fax: (03) 9663 2201 PERTH OFFICE Level 4, St Georges Square 225 St Georges Terrace Perth WA 6000 Tel: (08) 6318 6411 Fax: (08) 9322 6154 BANKERS National Australia Bank Limited Macquarie Bank Limited AUDITORS PricewaterhouseCoopers LAWYERS McCullough Robertson SHARE REGISTRY Link Market Services Level 12, 680 George Street Sydney NSW 2000 Tel: 1300 554 474 Fax: (02) 9287 0303 WEBSITE www.ermpower.com.au COMPANY ERM Power Limited (ACN: 122 259 223) DIRECTORS Tony Bellas (Non-Executive Chairman) Trevor St Baker (Non-Executive Deputy Chairman and Founder) Martin Greenberg Tony Iannello CHIEF EXECUTIVE OFFICER Philip St Baker COMPANY SECRETARIES Peter Jans Graeme Walker HEAD OFFICE Level 52, One One One 111 Eagle Street Brisbane QLD 4000 GPO Box 7152 Brisbane QLD 4001 Australia Tel: (07) 3020 5100 Fax: (07) 3220 6110 SYDNEY OFFICE Level 26 25 Bligh Street Sydney NSW 2000 Tel: (02) 8243 9100 Fax: (02) 9235 3898 ERM Power Limited ABN 28 122 259 223 Level 52, 111 Eagle Street Brisbane Queensland 4000 www.ermpower.com.au E R M P o w e r L i m i t e d A n n u a l R e p o r t 2 0 1 4