2012 Half Year Results Media Presentation - Origin Energy
2012 Half Year Results Media Presentation - Origin Energy
2012 Half Year Results Media Presentation - Origin Energy
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<strong>2012</strong> <strong>Half</strong> <strong>Year</strong> <strong>Results</strong> <strong>Media</strong> <strong>Presentation</strong><br />
<strong>Half</strong> <strong>Year</strong> Ended 31 December 2011<br />
Grant King, Managing Director<br />
Karen Moses, Executive Director, Finance and Strategy<br />
23 February <strong>2012</strong>
Important Notice<br />
This presentation does not constitute investment advice, or an inducement or recommendation to acquire or dispose of any<br />
securities in <strong>Origin</strong>, in any jurisdiction (including the USA). This presentation is for information purposes only, is in a<br />
summary form, and does not purport to be complete. This presentation does not take into account the investment<br />
objectives, financial situation or particular needs of any investor, potential investor or any other person. No investment<br />
decision should be made in reliance on this presentation. Independent financial and taxation advice should be sought before<br />
making any investment decision.<br />
Certain statements in this presentation are in the nature of forward looking statements, including statements of current intention, statements<br />
of opinion and predictions as to possible future events. Such statements are not statements of fact and there can be no certainty of outcome<br />
in relation to the matters to which the statements relate. These forward looking statements involve known and unknown risks, uncertainties,<br />
assumptions and other important factors that could cause the actual outcomes to be materially different from the events or results expressed<br />
or implied by such statements. Those risks, uncertainties, assumptions and other important factors are not all within the control of <strong>Origin</strong> and<br />
cannot be predicted by <strong>Origin</strong> and include changes in circumstances or events that may cause objectives to change as well as risks,<br />
circumstances and events specific to the industry, countries and markets in which <strong>Origin</strong> and its related bodies corporate, joint ventures and<br />
associated undertakings operate. They also include general economic conditions, exchange rates, interest rates, the regulatory environment,<br />
competitive pressures, selling price, market demand and conditions in the financial markets which may cause objectives to change or may<br />
cause outcomes not to be realised. None of <strong>Origin</strong> or any of its respective subsidiaries, affiliates and associated companies (or any of their<br />
respective officers, employees or agents) (the "Relevant Persons") makes any representation, assurance or guarantee as to the accuracy or<br />
likelihood of fulfilment of any forward looking statement or any outcomes expressed or implied in any forward looking statements. The forward<br />
looking statements in this presentation reflect views held only at the date of this presentation. In addition, statements about past<br />
performance are not necessarily indicative of future performance. Subject to any continuing obligations under law or the ASX Listing Rules,<br />
<strong>Origin</strong> and the Relevant Persons disclaim any obligation or undertaking to disseminate after the date of this presentation any updates or<br />
revisions to any forward looking statements to reflect any change in expectations in relation to any forward looking statements or any change<br />
in events, conditions or circumstances on which such statements are based.<br />
No representation or warranty, express or implied, is or will be made in relation to the accuracy or completeness of the information in this<br />
presentation and no responsibility or liability is or will be accepted by <strong>Origin</strong> or any of the Relevant Persons in relation to it. In particular,<br />
<strong>Origin</strong> does not endorse, and is not responsible for, the accuracy or reliability of any information in this presentation relating to a third party.<br />
All references to "$" are references to Australian dollars unless otherwise specified.<br />
All references to debt refer to interest-bearing debt.<br />
A reference to Contact is a reference to Contact <strong>Energy</strong> of New Zealand, currently a 52.8% subsidiary of <strong>Origin</strong>.<br />
A reference to Australia Pacific LNG or APLNG is a reference to Australia Pacific LNG Pty Limited, an incorporated joint venture in which <strong>Origin</strong><br />
currently holds a 42.5% interest.<br />
A reference to the “NSW energy assets” or “NSW acquisition” is a reference to the Integral <strong>Energy</strong> and Country <strong>Energy</strong> retail businesses and the<br />
Eraring GenTrader arrangements.<br />
A reference to FID 1 is a reference to the Final Investment Decision on the first phase of APLNG‟s two train CSG to LNG project taken on 28<br />
July 2011. A reference to FID 2 is a reference to a Final Investment Decision on the second phase of APLNG‟s two train CSG to LNG project.<br />
A reference to NEM is a reference to Australia‟s National Electricity Market.<br />
All comparative data is in relation to the prior corresponding period, 1 July 2010 to 31 December 2010, unless otherwise stated. Certain<br />
comparative amounts have been reclassified to conform with the current year‟s presentation.<br />
2 |
Outline<br />
1. Performance Highlights Grant King<br />
2. Financial Review Grant King<br />
3. Operational Review Grant King<br />
4. Outlook Grant King<br />
3 |
1. Performance Highlights<br />
Grant King, Managing Director<br />
• <strong>Origin</strong>‟s Statutory Profit contains a number of items that do not portray the operational<br />
performance of the business. Underlying Profit excludes the impact of these items to<br />
better illustrate the business performance of the Company<br />
• Underlying measures are used internally by management to assess the performance of<br />
<strong>Origin</strong>‟s business, make decisions on allocation of resources and assess operational<br />
management<br />
• Underlying measures are non-IFRS measures, and are reconciled to statutory measures<br />
(where appropriate) in the Management Discussion & Analysis. Non-IFRS measures have<br />
not been subject to audit or review
During the half <strong>Origin</strong> has made substantial progress on its two<br />
major investments …<br />
Effective integration of the NSW<br />
acquisition with successful Retail<br />
Transformation setting up for retail<br />
systems integration, strengthening<br />
<strong>Origin</strong>‟s strong competitive position<br />
FID 1 taken, with binding sales<br />
agreements clearing the way for<br />
FID 2<br />
Construction commenced;<br />
on schedule and budget<br />
… and is delivering on the value proposition central to the<br />
ongoing growth of the company<br />
5 |
A strong increase in earnings in the half year reflecting the<br />
NSW acquisition …<br />
Statutory Profit / (Loss) $794 m up from ($136) m<br />
Statutory Earnings per Share 73.8 cps up from (15.0) cps 1<br />
Underlying Profit $489 m up 61% from $304 m<br />
Underlying Earnings per Share 45.5 cps up 36% from 33.5 cps 2<br />
Interim Dividend per Share 25.0 cps steady<br />
Group OCAT (incl. share of APLNG) 3 $736 m down 7% from $794 m<br />
Capital and APLNG Expenditure 4 $1,036 m up 13% from $915 m<br />
Total Recordable Injury Frequency Rate 6.3 up from 6.1<br />
… with ongoing investment in the business to drive continued growth<br />
6 |<br />
(1) Dec 10 Statutory EPS of (15.4) cps restated to (15.0) cps for the bonus element of the rights issue completed in April 2011<br />
(2) Dec 10 Underlying EPS of 34.4 cps restated to 33.5 cps for the bonus element of the rights issue completed in April 2011<br />
(3) Group OCAT means operating cash flow after tax of the Consolidated Group, including <strong>Origin</strong>’s share of APLNG<br />
(4) Capital expenditure is based on cash flow amounts rather than accrual accounting amounts; Includes growth and stay-in-business capital<br />
expenditure, capitalised interest and <strong>Origin</strong>’s cash contributions to APLNG; Dec 10 capital expenditure is restated to conform to this half<br />
year’s classification
A$ million<br />
FY<strong>2012</strong><br />
FY2013<br />
FY2014<br />
FY2015<br />
FY2016<br />
FY2017<br />
FY2018<br />
FY2019<br />
FY2020<br />
FY2021<br />
FY2022<br />
FY2023+<br />
<strong>Origin</strong> has undertaken a number of funding activities during<br />
the half year …<br />
<strong>Origin</strong> Debt & Bank Guarantee Maturity Profile as at 31 December 2011<br />
2,500<br />
2,000<br />
1,500<br />
1,000<br />
500<br />
0<br />
Loans & Bank Guarantees - Undrawn<br />
Loans & Bank Guarantees - Drawn<br />
USPP, Retail Notes & Euro Hybrid<br />
• Underwritten DRP - $266m<br />
• Unsecured Notes issuance in US<br />
144A market – US$500m ($492m)<br />
• Subordinated Notes in Australian<br />
retail bond market - $900m<br />
• Additional debt facilities - $800m<br />
(and repaid $500m of matured<br />
facilities)<br />
• Work on Project Finance for<br />
APLNG progressing well<br />
Short term<br />
refinancing<br />
requirements are<br />
not significant<br />
Post FY2023,<br />
approximately $1.5<br />
billion 2 of instruments<br />
with staggered maturities<br />
… which have increased committed undrawn debt facilities and cash<br />
from $3.9 billion at June 2011 to $5.5 billion 1 at December 2011<br />
7 |<br />
(1) Excludes Contact<br />
(2) Includes $900m Retail Subordinated Notes (first call right December 2016) and Euro500m Hybrid (first call right June 2018)
2. Financial Review<br />
Grant King, Managing Director
<strong>2012</strong> <strong>Half</strong> <strong>Year</strong> Financial Highlights<br />
($ million) Dec 11 Dec 10 Change<br />
Statutory Profit / (Loss) 794 (136) na<br />
EPS – Statutory 73.8 cps (15.0) cps na<br />
Revenue 6,499 4,590 42%<br />
Underlying EBITDA 1,157 818 41%<br />
Underlying EBIT 832 536 55%<br />
Underlying Profit 489 304 61%<br />
EPS – Underlying 45.5 cps 33.5 cps 36%<br />
Group OCAT (incl. share of APLNG) 736 794 (7%)<br />
Free cash flow per share 51.7 cps 78.2 cps (34%)<br />
Capital and APLNG Expenditure 1,036 915 13%<br />
<strong>Origin</strong> Undrawn Committed Debt Facilities<br />
and cash 1 5,477 2,865 91%<br />
9 | (1) Excluding Contact and bank guarantees. Dec 10 number also excludes NSW acquisition funding
$ million<br />
Statutory Profit of $794 million, up $930 million from a loss of<br />
$136 million<br />
1,000<br />
800<br />
600<br />
400<br />
200<br />
-<br />
-200<br />
(136)<br />
Dec 10<br />
Statutory<br />
Loss<br />
440<br />
Items<br />
excluded<br />
from<br />
Underlying<br />
Profit<br />
<strong>Origin</strong> Underlying Profit Movement - Dec 10 to Dec 2011<br />
304<br />
Dec 10<br />
Underlying<br />
Profit<br />
41% 15% 91%<br />
339<br />
Underlying<br />
EBITDA<br />
(43)<br />
D&A<br />
and<br />
1<br />
ITDA<br />
(40)<br />
Net<br />
financing<br />
costs<br />
47%<br />
(73)<br />
Tax<br />
Expense<br />
6%<br />
2<br />
Noncontrolling<br />
interests<br />
61%<br />
489<br />
Dec 11<br />
Underlying<br />
Profit<br />
na<br />
305<br />
Items<br />
excluded<br />
from<br />
Underlying<br />
Profit<br />
na<br />
794<br />
Dec 11<br />
Statutory<br />
Profit<br />
Underlying Profit increased 61%, reflecting higher Underlying EBITDA due to contributions from the NSW<br />
energy assets and lower exploration expense in the Exploration & Production segment, offset by:<br />
• Higher depreciation and amortisation charges (up $45m to $305m) primarily due to NSW acquisition<br />
and Contact‟s Stratford Peaker and Ahuroa developments. ITDA 1 lower by $2m<br />
• Higher net financing costs (up $40m to $84m) reflecting debt financing for NSW acquisition and<br />
capital expenditure<br />
• Higher Underlying Tax Expense (up $73m to $227m) in line with increased profits<br />
Underlying Profit of $489 million, up by $185 million or 61%<br />
10 |<br />
(1) Share of interest, tax, depreciation and amortisation of equity accounted investees
OCAT decreased, with the increase in Underlying EBITDA offset<br />
primarily by changes in working capital, acquisition liabilities<br />
and capex<br />
($ million) Dec 11 Dec 10 Change<br />
Underlying EBITDA 1,157 818 339<br />
Change in working capital (192) (62) (130)<br />
Stay-in-business capex (99) (69) (30)<br />
Share of APLNG OCAT net of EBITDA 14 10 4<br />
Exploration expense 11 97 (86)<br />
NSW acquisition related liabilities (139) - (139)<br />
Other 1 (3) 8 (11)<br />
Tax (13) (8) (5)<br />
Group OCAT (incl. share of APLNG) 736 794 (58)<br />
Net interest paid (174) (102) (72)<br />
Free cash flow 562 692 (130)<br />
Productive Capital (calendar year) 13,638 9,631 4,007<br />
Group OCAT Ratio 2 (calendar year) 10.5% 13.2% (2.7%)<br />
Higher working capital<br />
requirements primarily<br />
due to additional SRES<br />
requirements and<br />
reduced creditors<br />
Decrease in exploration<br />
expense which is added back<br />
in calculating OCAT and<br />
treated as investing activities<br />
Unwind of non-cash TSA<br />
and PPA provisions relating<br />
to the NSW acquisition<br />
Higher productive capital<br />
primarily due to the<br />
inclusion of NSW energy<br />
assets<br />
11 |<br />
(1) The add-back of non–cash equity accounted profits excluding APLNG and movements in other provision balances are included within the<br />
“Other” line item<br />
(2) Group OCAT Ratio = (OCAT – interest tax shield)/Productive Capital
<strong>Origin</strong> has revised its operating segments<br />
• Final Investment Decision on the first phase of APLNG‟s CSG to LNG project<br />
• Deepening integration within <strong>Origin</strong>‟s <strong>Energy</strong> Markets business<br />
• Increased development opportunities outside of existing operations<br />
Segment<br />
<strong>Energy</strong> Markets<br />
Exploration &<br />
Production<br />
Australia Pacific LNG<br />
Contact <strong>Energy</strong><br />
Corporate<br />
Business Description<br />
Australian energy retailing, associated products and services; power<br />
generation in Australia; and LPG operations in Australia, the Pacific,<br />
Papua New Guinea and Vietnam<br />
Gas and oil exploration and production in Australia, New Zealand and<br />
international areas of interest<br />
<strong>Origin</strong>‟s investment in Australia Pacific LNG including current domestic<br />
operations and the Australia Pacific LNG CSG to LNG project<br />
<strong>Origin</strong>‟s investment in its 52.8% owned New Zealand subsidiary Contact<br />
<strong>Energy</strong> Ltd<br />
Corporate activities that are not allocated to other operating segments<br />
and business development activities outside of <strong>Origin</strong>‟s existing<br />
operations<br />
12 |<br />
This reflects management‟s view of the operational performance<br />
of the business
$ million<br />
Underlying EBITDA up 41% to $1,157 million<br />
1,400<br />
1,200<br />
1,000<br />
800<br />
600<br />
400<br />
200<br />
818<br />
<strong>Origin</strong> Underlying EBITDA Movement - Dec 10 to Dec 11<br />
83% 50%<br />
1% 33%<br />
41%<br />
52%<br />
(16) 217 2 (10) 1,157<br />
81<br />
282<br />
145<br />
75<br />
-<br />
Dec 10<br />
Underlying<br />
EBITDA<br />
<strong>Energy</strong><br />
Markets<br />
Expl. & Prod.<br />
Australia<br />
Pacific LNG<br />
Contact Corporate Dec 11<br />
Underlying<br />
EBITDA<br />
Underlying EBITDA increased by 41%, largely reflecting:<br />
• Full 6 months‟ contribution from the acquired NSW energy assets<br />
• Significantly reduced exploration expense in Exploration & Production segment<br />
13 |
$ million<br />
During the half year <strong>Origin</strong> spent $764 million on growth capital,<br />
and contributed $173 million to APLNG<br />
Growth Capital and APLNG Expenditure by<br />
Segment (includes capitalised interest)<br />
1,000<br />
900<br />
800<br />
700<br />
600<br />
500<br />
400<br />
300<br />
200<br />
100<br />
0<br />
937<br />
846<br />
Dec 10 Dec 11<br />
<strong>Energy</strong> Markets<br />
Exploration & Production<br />
Contact<br />
Corporate<br />
APLNG<br />
• Growth capital expenditure 1 , excluding APLNG<br />
contribution, down 10% on prior half year<br />
• Key areas of capital expenditure include:<br />
- Mortlake Power Station ($96m)<br />
- Eraring Power Station ($92m)<br />
- Retail Transformation ($46m)<br />
- Ironbark ($52m)<br />
- BassGas ($37m)<br />
- Otway ($35m)<br />
- Contact‟s Te Mihi geothermal<br />
development ($93m)<br />
• Total capital expenditure within APLNG $2.5b<br />
- <strong>Origin</strong>‟s cash contribution $173m<br />
14 | (1) Including capitalised interest of $89 million (Dec 10: $74 million)
<strong>Origin</strong> has raised additional capital to further strengthen its<br />
balance sheet, improve liquidity and diversify its funding sources<br />
Funding Diversity at 31 December 2011<br />
Funding Diversity at 30<br />
Jun June 2010 1 2010 ($5.6b)<br />
Dec 2011 2 ($9.5b)<br />
Funding Diversity at 31 December<br />
5% 7%<br />
2011<br />
4% 15%<br />
26%<br />
10% 5% 7% 26%<br />
55%<br />
Bank Facilities - Domestic<br />
Bank Facilities European - Domestic Hybrid Issue<br />
European Hybrid Issue<br />
US Private Placement<br />
Senior Unsecured Notes - US Issue<br />
US Private Placement<br />
Senior Unsecured Notes - US Issue<br />
7%<br />
10%<br />
7%<br />
45%<br />
45%<br />
26%<br />
Bank Facilities - International<br />
Bank Australian Facilities Retail -Notes<br />
International<br />
Australian Medium Term Retail Notes Notes<br />
Medium Term Notes<br />
• Given facilities <strong>Origin</strong> has in place, there<br />
is no intention to raise additional equity<br />
for APLNG Train 1 and other committed<br />
projects<br />
• Future funding choices, including<br />
additional equity, will be dependent on:<br />
• Timing of APLNG Train 2 decision<br />
• Final equity share in APLNG<br />
• The quantum and cost of project<br />
finance for APLNG<br />
• Consideration of credit metrics<br />
• Other business activity<br />
Given the success of recent funding initiatives and current committed<br />
obligations, the underwritten DRP will not be exercised and the DRP<br />
discount will be zero for the December 2011 half year dividend<br />
15 |<br />
(1) As at 30 June 2010; excludes Contact<br />
(2) As at 31 December 2011; excludes Contact
$ million<br />
Without additional future commitments, the majority of<br />
expenditure over the next three years will be APLNG related<br />
5,000<br />
Growth Capital and APLNG Expenditure by Segment<br />
4,500<br />
4,000<br />
3,500<br />
3,000<br />
2,500<br />
2,000<br />
1,500<br />
1,000<br />
500<br />
0<br />
NSW<br />
Acquisition<br />
FY2011 FY<strong>2012</strong> FY2013 FY2014<br />
<strong>Energy</strong> Markets<br />
Exploration & Production<br />
Contact<br />
Corporate<br />
2<br />
APLNG - <strong>Origin</strong> cash contribution based on FID 1<br />
estimates and <strong>Origin</strong> equity at 42.5%<br />
• With $5.5 billion of<br />
committed undrawn facilities<br />
and cash, <strong>Origin</strong> is well<br />
placed to fund future<br />
commitments<br />
• APLNG funding currently<br />
assumes no allowance for<br />
project finance<br />
16 |<br />
(1) Historical numbers include capitalised interest, forward looking estimates do not include capitalised interest<br />
(2) APLNG numbers represent <strong>Origin</strong>’s cash injection requirements rather than <strong>Origin</strong>’s share of total APLNG capital expenditure
cents per share<br />
FY2001<br />
FY2002<br />
FY2003<br />
FY2004<br />
FY2005<br />
FY2006<br />
FY2007<br />
FY2008<br />
FY2009<br />
FY2010<br />
FY2011<br />
FY<strong>2012</strong><br />
A fully franked interim dividend of 25 cps has been declared,<br />
which represents a 55% payout ratio<br />
60<br />
50<br />
40<br />
30<br />
20<br />
10<br />
0<br />
4<br />
3<br />
2<br />
Dec <strong>Half</strong><br />
Jun <strong>Half</strong><br />
Additional<br />
<strong>Origin</strong> Dividend History<br />
25 25 25 25<br />
11 13 9<br />
25 25 25 25<br />
7<br />
8<br />
5<br />
5 6 7 9 10 12<br />
• Ex-dividend date: 28 February <strong>2012</strong><br />
• Record Date: 5 March <strong>2012</strong><br />
• Payment Date: 30 March <strong>2012</strong><br />
• Dividend Reinvestment plan will apply<br />
to this dividend with zero discount<br />
• <strong>Origin</strong> intends to maintain a minimum<br />
annual payout ratio of 60% of annual<br />
Underlying Profit<br />
Franking<br />
100% 100% 40% 100% 100% 100% 100% 100% 100% 100% 100% 100%<br />
17 |<br />
<strong>Origin</strong>‟s DRP underwrite agreement will not be exercised for the<br />
December half year dividend
3. Operational Review<br />
Grant King, Managing Director
<strong>Energy</strong> Markets<br />
‣ Underlying EBITDA up 52% to $820 million<br />
‣ Strong earnings growth from NSW acquisition<br />
‣ Lower average wholesale energy costs due to deepening integration, supporting margins<br />
‣ NSW market churn increased, as expected<br />
‣ Successful migration of pre-NSW acquisition customer base to SAP<br />
‣ Continued integration activities for acquired NSW retail businesses<br />
($m)<br />
900<br />
Underlying<br />
EBITDA<br />
Total Assets<br />
less Segment<br />
Liabilities<br />
($b)<br />
12<br />
600<br />
820<br />
820<br />
12.5<br />
10.0<br />
8<br />
300<br />
538<br />
538<br />
5.9<br />
4<br />
Six months‟ contribution from NSW acquisition<br />
Lower average cost of energy<br />
Lower energy consumption<br />
0<br />
Dec 10 Dec 11<br />
Dec 10 Dec 11<br />
0<br />
19 |
<strong>Origin</strong>‟s <strong>Energy</strong> Markets business is an integrated provider of<br />
energy products<br />
• Diverse and flexible legacy<br />
fuel portfolio<br />
• 5,310 MW generation portfolio<br />
• Operationally diverse<br />
• Geographically diverse<br />
• 3,075,000 electricity<br />
customer accounts<br />
• 950,000 gas customer<br />
accounts<br />
• 355,000 LPG customer<br />
accounts<br />
• Solar PV installations<br />
• Solar hot water<br />
• Heating and Cooling<br />
• Electric Vehicle Charging<br />
• Trigeneration<br />
20 |
Capacity (MW)<br />
Capacity (MW)<br />
Capacity (MW)<br />
<strong>Origin</strong>‟s large, diverse fuel portfolio, and flexible gas transport<br />
arrangements, are central to its integrated business model …<br />
400<br />
300<br />
200<br />
100<br />
Fuel/Generation - Gas<br />
Fuel/Generation - Coal<br />
Retail - Gas<br />
Retail - Electricity<br />
10,000<br />
9,000 10,000 10,000<br />
9,000 9,000<br />
8,000<br />
8,000 8,000<br />
7,000<br />
7,000 7,000<br />
6,000<br />
6,000 6,000<br />
5,000<br />
5,000 5,000<br />
4,000<br />
4,000 4,000<br />
3,000 3,000 3,000<br />
2,000 2,000<br />
Peak<br />
Electricity<br />
Peak Peak<br />
Electricity<br />
Retail<br />
Retail<br />
Retail<br />
Demand<br />
Contract or or<br />
or<br />
Spot Spot<br />
Spot<br />
Market Market<br />
Market<br />
Long Long Term Term<br />
Contracts<br />
Movement of gas<br />
0<br />
Optionality to:<br />
• Send gas to generation portfolio<br />
• Send gas to retail portfolio<br />
• Send gas to wholesale market<br />
1,000 1,000<br />
-<br />
--<br />
Peak Peak Demand<br />
Peak Demand<br />
Optionality to:<br />
Supply Supply<br />
Supply<br />
• Run coal-fired generation<br />
• Run gas-fired generation<br />
• Run peaking liquids generation<br />
• Run pumped-storage hydro generation<br />
• Purchase from market (contract or pool)<br />
21 |<br />
… which together with a flexible and diverse generation portfolio,<br />
enables a competitive cost of energy
<strong>Energy</strong> Markets delivered strong earnings growth from the NSW<br />
acquisition<br />
Performance Metrics, $m<br />
(% change from Dec 10)<br />
Natural Gas<br />
Electricity<br />
Noncommodity<br />
Revenue 1 624 (+2%) 3,827 (+78%) 136 (-36%) 350 (+5%)<br />
Gross Profit 126 (+20%) 930 (+68%) 18 (-42%) 94 (+5%)<br />
Underlying EBITDA 820 (+52%)<br />
Underlying EBIT 697 (+53%)<br />
Underlying EBIT/Sales % 14.1% (13.8% in Dec 10)<br />
Volumes (sold) 68 PJ (-7%) 22 TWh (+57%)<br />
245 kt (-1%)<br />
n.a.<br />
Customer accounts („000) 2 950 (+3%) 3,075 (-4%) 355 (-3%)<br />
Gross Profit per customer ($) 267 (+1%) 265 (+5%)<br />
Cost to Serve 3 per customer ($) (70) (-1%)<br />
LPG<br />
Earnings uplift from<br />
NSW acquisition<br />
Cost to Serve maintained<br />
Underlying EBITDA per customer ($) 197 (+2%) 80 (-15%)<br />
Underlying EBIT per customer ($) 169 (+1%) 43 (-28%)<br />
22 |<br />
Effective portfolio management led to steady margins broadly in<br />
line with the prior half year‟s strong performance<br />
(1) <strong>Energy</strong> Markets earns pool revenue and revenue from the sale of gas swaps. These revenues are netted off with the associated costs<br />
within the wholesale energy costs line of Electricity COGS and the associated cost in Natural Gas COGS respectively<br />
(2) Customer account movement since 30 June 2011<br />
(3) Cost to serve includes the benefit associated with the unwind of the Transitional Service Agreements entered into as part of the NSW<br />
Acquisition ($49m)
Base<br />
Load/<br />
Interm.<br />
Externally<br />
A diverse generation portfolio and high reliability levels<br />
delivered a competitive cost of energy<br />
Contracted Wind Peaking<br />
Eraring<br />
Darling Downs<br />
Ladbroke Grove<br />
Quarantine<br />
Roma<br />
Uranquinty<br />
Shoalhaven<br />
Mt Stuart<br />
Cullerin Range<br />
Worsley<br />
Osborne<br />
Bulwer Island<br />
0% 20% 40% 60% 80% 100%<br />
Equivalent Reliability Factor (ERF) Capacity Factor<br />
• Eraring Power Station ERF was 86%<br />
due to fire in transformer of Unit 2<br />
• First of two Mortlake units available<br />
for dispatch in January <strong>2012</strong><br />
- Completion of second unit<br />
expected in second half of<br />
FY<strong>2012</strong><br />
• <strong>Origin</strong> has a portfolio of gas fired<br />
and wind developments providing<br />
future optionality<br />
Option to run generation harder<br />
23 |
<strong>Energy</strong> Markets has successfully migrated 2.6 million customers<br />
to a new industry-leading billing and customer relationship<br />
management system<br />
• Four large-scale migrations of <strong>Origin</strong>‟s 2.6<br />
million pre-NSW customers onto new integrated<br />
SAP billing platform successfully completed<br />
• New online functionality in final stages of being<br />
launched<br />
• SAP solution provides robust platform to support<br />
implementation of Clean <strong>Energy</strong> Package,<br />
commencing 1 July <strong>2012</strong><br />
• Successful Retail Transformation setting up for<br />
the integration of retail systems from the NSW<br />
acquisition<br />
25 |
<strong>Origin</strong> continues to develop its new retail products and<br />
business lines to deliver innovative solutions to customers<br />
<strong>Origin</strong>’s portfolio of non-commodity products include solar electricity, solar hot water, heating,<br />
cooling, electric vehicle charging, trigeneration systems and smart meters<br />
• Revenue for non-commodity business reduced by 36% reflecting fewer solar PV installations<br />
• Significant impact on demand due to policy changes<br />
• <strong>Origin</strong>‟s other non-commodity product offerings performing well and continue to complement<br />
core commodity business<br />
• E-Mobility business recently announced Australia‟s first 100% electric vehicle car share scheme in<br />
partnership with GoGet and is currently negotiating charging partnerships with electric vehicle<br />
manufacturers for Australian market<br />
• Cogent signed several major deals including Victoria‟s City of Dandenong co-generation plant<br />
• Tendril Energize TM home energy manager trial operational; preparing for mass market roll out<br />
26 |
Exploration & Production<br />
‣ Underlying EBITDA up 83% to $179 million<br />
‣ Steady operational performance<br />
‣ Completed major planned maintenance shutdowns at Kupe and Otway<br />
‣ Commenced BassGas Mid Life Enhancement Project<br />
‣ Lower exploration activity<br />
($m)<br />
200<br />
Underlying<br />
EBITDA<br />
Total Assets<br />
less Segment<br />
Liabilities<br />
($b)<br />
4<br />
150<br />
179<br />
179<br />
3.5<br />
3.1<br />
2.8<br />
3<br />
Lower exploration expense (down $86m)<br />
100<br />
50<br />
0<br />
98<br />
98<br />
Dec 10 Dec 11<br />
Dec 10 Dec 11<br />
2<br />
1<br />
0<br />
Higher commodity prices (+10%)<br />
Lower production (-2%) and sales (-4%) volumes<br />
Higher operating costs (+27%) associated with<br />
planned shutdowns and flood recovery<br />
27 |
Notwithstanding planned shutdowns at Otway, BassGas and<br />
Kupe …<br />
PJe<br />
50<br />
mmboe<br />
8.6<br />
mmboe<strong>Origin</strong> Gas Production <strong>Origin</strong> PJe Gas by Production <strong>Half</strong> <strong>Year</strong>by <strong>Half</strong> <strong>Year</strong><br />
8.6<br />
10<br />
mmboe<br />
1.7<br />
7.7<br />
40<br />
6.9<br />
6.9<br />
8<br />
1.4<br />
30<br />
6.0<br />
5.1<br />
5.1<br />
6<br />
1.0<br />
20<br />
4.3<br />
3.4<br />
3.4<br />
4<br />
0.7<br />
10<br />
2.6<br />
1.7<br />
1.7<br />
2<br />
0.3<br />
0<br />
0.9<br />
0.0<br />
0<br />
0.0<br />
Dec Jun Dec Jun Dec Jun Dec Jun Dec<br />
Dec Jun Dec Jun Dec Jun Dec Jun Dec<br />
0.0<br />
Total Liquids SA Cooper & SWQ<br />
FY 08 FY09 FY10 FY11 FY12<br />
Dec Jun Dec Jun Dec Jun Dec<br />
Otway - Onshore FY 08 FY09 Perth FY10 FY11 FY12<br />
Surat<br />
Bass<br />
Total Liquids SA Cooper & SWQ SA Otway Cooper - Onshore & SWQ Otway - Onshore Perth<br />
FY09 FY10 FY11 FY12<br />
Taranaki - Onshore Otway - Offshore<br />
Bass Taranaki - Onshore Otway - Of<br />
Perth Surat Bass<br />
Taranaki - Onshore Otway - Offshore Kupe<br />
28 |<br />
… <strong>Origin</strong> delivered steady operational performance
Major planned maintenance shutdowns have been undertaken on<br />
<strong>Origin</strong>‟s key offshore producing assets …<br />
Australian Offshore - Otway<br />
• Lower production (-9%) resulting from planned maintenance shutdown in November 2011<br />
• Inlet compression project being commissioned, planned to be operational in March <strong>2012</strong><br />
• The offshore Thistle-1 exploration prospect will be drilled in April <strong>2012</strong><br />
• Geographe Field Development underway; drilling planned to commence in May <strong>2012</strong><br />
Australian Offshore - BassGas<br />
• Lower production (-10%) due to commencement of Phase 1 of BassGas Mid Life<br />
Enhancement project in December 2011<br />
• Phase 2 of the project (drilling of additional wells) planned to take place over summer<br />
<strong>2012</strong>/2013<br />
Australian Onshore – Cooper, Surat and Perth Basins<br />
• Production up on prior half year (+4%) with increases across all basins<br />
• Marginally higher production in Cooper Basin despite lower gas volumes and wet weather<br />
during the December Quarter causing delays in operational and drilling activities<br />
Australian Onshore – Queensland CSG (Ironbark)<br />
• Community consultation continued<br />
• Construction on pilot ponds and gathering network commenced; a third multi-well pilot is<br />
planned for drilling in the Ironbark area in the March Quarter <strong>2012</strong><br />
New Zealand Offshore - Kupe<br />
• Production increased (+5%) reflecting reduced planned maintenance days<br />
• Kupe joint venture parties entered into 2-year agreement with BP Singapore for sale and<br />
marketing of Kupe light crude<br />
29 |<br />
… underpinning asset reliability and increased production capability<br />
into an expanding gas market
Asset reliability is currently being optimised in anticipation of<br />
industry gas demand tripling over the next 5 years<br />
2,500<br />
2,000<br />
1,500<br />
1,000<br />
500<br />
0<br />
PJ<br />
East coast gas production 2000-2017 (PJ)<br />
LNG<br />
Ramp Gas<br />
East Coast<br />
Source: <strong>Energy</strong>Quest Feb <strong>2012</strong><br />
Gas demand<br />
expected to triple<br />
2008 2009 2010 2011 <strong>2012</strong> 2013 2014 2015 2016 2017<br />
Calendar <strong>Year</strong>s<br />
• <strong>Origin</strong> currently supplies around 15% of<br />
eastern Australia‟s gas<br />
• Maintenance & enhancement of offshore assets<br />
creates flexibility to address opportunities as<br />
LNG projects ramp-up gas production through<br />
to 2017<br />
• In addition upside potential exists in all major<br />
regions in which <strong>Origin</strong> is involved<br />
• Cooper Basin – contingent resources,<br />
deep gas and shale gas<br />
• Surat / Bowen – Ironbark CSG, deep gas<br />
potential in Surat and Bowen<br />
• Otway Basin - spare plant capacity,<br />
Geographe development, Halladale &<br />
Black Watch fields, Thistle exploration<br />
Source: <strong>Energy</strong>Quest February <strong>2012</strong><br />
LNG well assumptions: FY<strong>2012</strong>, gas production new permits<br />
estimates for LNG<br />
projects that have reached FID. Based on company<br />
announcements for contracted offtake from two trains,<br />
• Bass Basin – BassGas MLE and upside in<br />
with start-up staggered over two years for each project.<br />
Fuel Trefoil, gas assumed Rockhopper to be 10%. and further<br />
exploration<br />
<strong>Origin</strong> has a diverse equity gas position in eastern Australia, with upside<br />
potential identified in all regions<br />
30 |<br />
LNG assumptions (source: <strong>Energy</strong>Quest): gas production estimates for LNG projects that have reached FID. Based on company announcements for contracted<br />
offtake from two trains, with start-up staggered over two years for each project. Fuel gas assumed to be 10%.
<strong>Origin</strong> is exploring for resources in regions that offer high<br />
prospectivity and access to growing markets…<br />
New Zealand<br />
• Anadarko, as operator, continued preparations to drill Caravel-1 in the<br />
offshore Canterbury Basin in late <strong>2012</strong> targeting significant gas and liquids<br />
• Manutahi oil project delivering encouraging early results onshore Taranaki<br />
South East Asia<br />
• Dao Ruang-3 appraisal drilling in the Khorat Plateau onshore Thailand<br />
concluded; results indicated limited potential; plugged and abandoned<br />
• Continued evaluation of opportunities throughout South East Asia<br />
• Preparations continue for drilling in Block 121 in the Song Hong Basin,<br />
offshore Vietnam, during FY2013<br />
Kenya<br />
• Completed farmout of 5% interest in Block L8 to Tullow Oil<br />
• Preparations continue for drilling of Mbawa-1 well in the Lamu Basin in late <strong>2012</strong>.<br />
Acreage comprises over 5,000 km 2 with attractive exploration opportunities in the<br />
emerging plays offshore East Africa<br />
Botswana<br />
• Established Kubu <strong>Energy</strong> Resources, a 50:50 JV with Sasol, to explore for CSG in Botswana<br />
• Consistent with <strong>Origin</strong>'s strategy to target resources close to markets at low entry prices<br />
• Exploration operations expected to commence in the Karoo Basin later in <strong>2012</strong><br />
… working with experienced joint venture partners<br />
31 |
Australia Pacific LNG<br />
‣ Underlying EBITDA down 50% to $16 million<br />
‣ FID on LNG Train 1 and infrastructure to support Train 2 taken in July 2011<br />
‣ <strong>Origin</strong> equity share in APLNG JV reduced from 50% to 42.5%<br />
‣ Binding agreements signed with Kansai and Sinopec for Train 2 LNG sales<br />
‣ Sinopec to take additional 10% interest in APLNG 1 ; <strong>Origin</strong>‟s share will reduce to 37.5%<br />
‣ Project remains on track with FID 2 expected by mid <strong>2012</strong><br />
($m)<br />
40<br />
Underlying<br />
EBITDA<br />
Total Assets<br />
less Segment<br />
Liabilities<br />
($b)<br />
8<br />
30<br />
32<br />
32<br />
32<br />
5.7 6<br />
5.2<br />
5.7<br />
20<br />
4<br />
16<br />
16<br />
16<br />
10<br />
2<br />
0<br />
0<br />
Dec 10 Dec 11 Dec 10 Dec 11<br />
Lower sales revenue<br />
Higher operating costs<br />
Dilution of <strong>Origin</strong>‟s interest from 50% to 42.5%<br />
32 | (1) Binding and conditional on Australian and Chinese Government approvals and a Final Investment Decision on Train 2
<strong>Origin</strong>, as part of the APLNG joint venture, is developing one<br />
of Australia‟s largest CSG to LNG projects<br />
Compelling Project<br />
• Leverages strong growth in Asia<br />
• Oil-linked revenues<br />
• Strong and aligned joint venture<br />
• Large, quality reserves base<br />
• Successful history of working sustainably with communities<br />
• Extensive experience in CSG and LNG development<br />
Robust First Phase Economics, with Additional Train 2 Benefits<br />
• Train 1 economics underpinned by high quality, low cost CSG reserves base<br />
• Attractive returns in its own right<br />
• Train 2 benefits from economies of scale<br />
33 |
APLNG‟s CSG to LNG project is underpinned by a long history of<br />
production growth and a large, high quality reserves base<br />
PJ<br />
120<br />
30,000<br />
100<br />
80<br />
25,000<br />
60<br />
20,000 40<br />
30,000<br />
20<br />
25,000<br />
0<br />
20,000<br />
15,000<br />
10,000<br />
15,000<br />
10,000<br />
5,000<br />
5,000<br />
-<br />
-<br />
Jan-Jun<br />
Jul-Dec<br />
<strong>Origin</strong> Share<br />
• APLNG production up 4% on the<br />
prior half year to 52 PJ<br />
• Production capacity from both<br />
operated and non-operated<br />
assets increased to 323 TJ/day<br />
• APLNG currently operates 335<br />
producing wells; a further 48<br />
development wells drilled but<br />
not producing<br />
Estimated<br />
Requirements<br />
estic Gas <strong>Origin</strong> Contract 3C 2C 3P 2P<br />
Ramp and Tail Gas Train 2 Train 1 QCLNG GSA Domestic Gas <strong>Origin</strong> Contract 3C 2C 3P 2P<br />
34 |<br />
Ramp and Tail Gas Train 2 Train 1<br />
QCLNG GSA Domestic Gas <strong>Origin</strong> Contract<br />
3C<br />
2C<br />
3P<br />
2P<br />
APLNG increased 2P reserves by 1,035 PJ to 12,810 PJ and 3P reserves<br />
have increased to 16,022 PJ<br />
Note: Some of APLNG’s CSG reserves and resources are subject to reversionary right.<br />
Refer to <strong>Origin</strong>’s Management Discussion & Analysis for the half year ended 31 December 2011 for further information
APLNG continues to make good progress against project<br />
milestones<br />
• FID 1 in July 2011<br />
• Marketing agreements in place to underpin two<br />
trains<br />
– Train 1 - Sinopec (4.3 mtpa) 1<br />
– Train 2 - Kansai (1.0 mtpa) 2<br />
– Train 2 – Sinopec (3.3 mtpa) 2<br />
• Sinopec to increase holding to 25% 3<br />
• Major contracts awarded<br />
• Costs confirmed for key Train 2 contracts,<br />
including Bechtel EPC contract<br />
• Overall construction approximately 12% complete<br />
• On schedule and budget for Train 1 LNG mid-2015<br />
(Train 2 early 2016)<br />
35 |<br />
(1) Binding and unconditional<br />
(2) Binding and conditional on a Final Investment Decision on Train 2<br />
(3) Binding and conditional on Australian and Chinese Government approvals and a Final Investment Decision on Train 2
Upstream activities are ramping up with land access, drilling and<br />
gas processing facilities tracking within plan<br />
• Participated in over 200 wells during the half<br />
• Two hybrid coil tubing drilling rigs now in operation; capability to<br />
drill wells in less than 4 days per rig; more rigs to be added<br />
progressively over the coming months<br />
• On track to drill 30 wells per month by mid <strong>2012</strong>, with up to 1,100<br />
new production wells expected to be drilled by the end of 2015 to<br />
support initial ramp requirements for two trains<br />
• Land access on schedule; 428 well locations scouted; land access<br />
plan ensures rigs minimise down-time<br />
• First Siemens electric drive compressor completed factory<br />
acceptance testing in January, on schedule<br />
• Plant module construction awarded to BJC Thailand – first module<br />
shipment due mid <strong>2012</strong>, on schedule<br />
• Gas processing and water treatment facilities construction on track<br />
to commence mid-<strong>2012</strong><br />
Milestones<br />
Date<br />
36 |<br />
First two Savanna rigs introduced mid 2011<br />
Initial drilling for Train 1 complete mid 2013<br />
Mechanical completion of first gas processing plant mid 2013<br />
Train 1 - gas processing plants complete late 2014<br />
First gas to LNG Train 1 early 2015
Preparations for the major pipeline construction activities and gas<br />
field electrification project are on track<br />
• EPC pipeline contract awarded to McConnell Dowell,<br />
Consolidated Contracting Co. joint venture in July 2011<br />
• Line pipe awarded to MetalOne in Japan; first delivery<br />
made in January <strong>2012</strong><br />
• APLNG and QCLNG collaborating on Narrows crossing;<br />
execution by QCLNG delayed however significant float<br />
remains for APLNG<br />
• Pipeline land access arrangements progressing at rate<br />
which maintains pipeline construction productivity;<br />
agreements reached with one third of properties<br />
• Engineering on schedule and welding on track to<br />
commence in June <strong>2012</strong><br />
• Train 1 electrification contracts awarded to Powerlink<br />
and on schedule<br />
Milestones<br />
Date<br />
Line pipe manufacture 2011 and <strong>2012</strong><br />
Welding commences mid <strong>2012</strong><br />
Pipeline completion early 2014<br />
Train 1 electrification complete mid 2014<br />
37 |
Curtis Island site preparations are progressing well, and<br />
major downstream contracts have been awarded<br />
January <strong>2012</strong><br />
• Bechtel responsible for all activity on Curtis Island under a<br />
fixed price contract<br />
• Costs confirmed for key Train 2 contracts, including Bechtel<br />
EPC contract; long lead items awarded<br />
• Engineering, procurement and construction of Curtis Island<br />
and Mainland facilities approximately 12% complete<br />
• On budget and schedule for Train 1 start-up mid-2015<br />
• Roll-on roll-off facility complete, including required<br />
dredging works<br />
• LNG tank area site preparations on track; tank contractor<br />
mobilisation in March <strong>2012</strong><br />
• Curtis Island site camp on schedule for June <strong>2012</strong> operations<br />
Milestones<br />
Date<br />
38 |<br />
Complete 2015<br />
Commenced Curtis Island works mid 2011<br />
Awarded EPC contract to Bechtel mid 2011<br />
1st occupancy of Curtis Island camp mid <strong>2012</strong><br />
Heavy mechanical erection start late <strong>2012</strong><br />
First LNG module delivery early 2013<br />
Pre-commissioning late 2014<br />
Train 1 ready for start-up mid 2015
The APLNG Project is committed to community engagement,<br />
education and minimising environmental impacts …<br />
Example Programs include<br />
• Independently chaired community consultative<br />
committees operating in regional centres<br />
• Skills Queensland program to enable farmers to<br />
support CSG infrastructure on their land<br />
• Program to address housing affordability in<br />
regional communities commenced<br />
• Development drilling using minimal disturbance<br />
lease construction<br />
• Community information sessions run<br />
- For example, over 1,000 people attended<br />
sessions in Roma, Miles, Chinchilla, Brisbane<br />
and Canberra to view a 1,500 metre rock core<br />
section showing Surat Basin geology to explain<br />
facts regarding groundwater, fraccing,<br />
drilling, well integrity and the environment<br />
• Assurance and reporting of environment and<br />
social regulatory compliance managed using<br />
common information and data register<br />
39 |<br />
… with many programs implemented and EIS assurance reporting<br />
centralised to ensure compliance with State and Federal requirements
APLNG 100% capital expenditure for the half year was<br />
$2.5 billion …<br />
APLNG Capital Expenditure for the half year to Dec 11<br />
A$m Upstream Downstream Total<br />
Development expenditure 852 1,550 2,402<br />
Exploration & appraisal 91 - 91<br />
Total 943 1,550 2,493<br />
<strong>Origin</strong> cash contribution 173<br />
• APLNG capital expenditure in the table above includes:<br />
- CSG to LNG export project (total US$14 billion based on forward<br />
exchange rates assumed at the time of APLNG FID 1)<br />
- domestic operations<br />
- capitalised pre-LNG operating and maintenance costs<br />
- development of gas to supply third party LNG projects<br />
- exploration and appraisal activities<br />
• Over 2/3 of costs based in AUD, with balance primarily in USD.<br />
• Due to movements in foreign exchange rates total project cost have<br />
increased when expressed in USD and decreased if expressed in AUD<br />
APLNG FID 1 LNG project costs by currency<br />
AUD USD EUR<br />
40 |<br />
… with expected capital expenditure in line with currency splits at<br />
the time of FID for the first phase of the project
Contact <strong>Energy</strong><br />
‣ Underlying EBITDA up 1% to $182 million<br />
‣ Flexibility delivering savings benefits<br />
‣ Low hydro volumes and high retail competition<br />
‣ Te Mihi and Enterprise Transformation projects on track<br />
‣ Balance Sheet strengthened<br />
($m)<br />
200<br />
160<br />
Underlying<br />
EBITDA<br />
180 182<br />
Total Assets<br />
less Segment<br />
Liabilities<br />
4.1<br />
4.7<br />
4.4<br />
($b)<br />
5<br />
4<br />
120<br />
3<br />
Higher wholesale electricity prices<br />
80<br />
40<br />
2<br />
1<br />
Gas take-or-pay savings<br />
Low hydro generation<br />
Higher operational costs<br />
0<br />
Dec 10 Dec 11<br />
Dec 10 Dec 11<br />
0<br />
41 |
Contact is one of New Zealand‟s leading energy companies,<br />
supplying gas, electricity and LPG products across the country<br />
Generation Portfolio<br />
• 290 MW geothermal generation<br />
• 752 MW hydro generation<br />
• 1,176 MW gas generation<br />
• Over 2,000 MW in generation<br />
development opportunities<br />
<strong>Energy</strong> Retailer<br />
• 443,000 electricity customers<br />
• 60,000 gas customers<br />
• 60,200 LPG customers 1<br />
42 |<br />
(1) Including franchises
Increased portfolio flexibility and improved wholesale prices<br />
were offset by an unfavourable fuel mix and retail competition<br />
Balance sheet gearing level remains strong<br />
• Successful NZ$200m capital bond issue<br />
• Issue tapped NZ retail market demand for<br />
higher yield securities<br />
• Export credit financing (NZ$105m) provides<br />
15 year amortising funding at competitive<br />
rates, further diversifying funding mix<br />
Solid operational progress under challenging<br />
market conditions<br />
• Wholesale market prices responded to belowaverage<br />
hydro storage levels<br />
• Ahuroa Gas Storage and lower contract volumes<br />
eliminated direct gas take-or-pay costs<br />
• Low hydro inflows delivered unfavourable fuel<br />
cost mix<br />
• Operating costs increased with particular<br />
increases in SAP licence and support costs and<br />
insurance<br />
• Pricing offers positively impacted customer<br />
numbers; mass market margins consequently<br />
compressed. Time-of-Use sales continues to<br />
gain<br />
• Increase in mass market tariffs absorbed by<br />
“OLOT” (Online On Time) discount, and<br />
increases in network and operating costs<br />
43 |
Increased portfolio diversity and flexibility, along with strategic<br />
development opportunities provide a positive outlook<br />
Lower Average Cost of Generation<br />
and increased portfolio flexibility<br />
• 166 MW Te Mihi geothermal power<br />
station, under development<br />
• Peaking power stations<br />
• Diverse generation fuel mix<br />
• Gas storage<br />
• Flexible gas recontracting<br />
structure<br />
• CCGT operating regime<br />
Positioned for Growth<br />
• Tauhara – New Zealand‟s lowest<br />
cost generation development<br />
• Diverse range of development<br />
options across all fuels<br />
• Will only be developed when<br />
market signals dictate<br />
44 |
Corporate<br />
‣ Underlying EBITDA down 33% to ($40) million<br />
‣ Commenced geothermal exploration in Chile, and acquired additional<br />
concessions<br />
‣ Technical feasibility of PNG hydroelectric development confirmed<br />
($m)<br />
50<br />
Underlying<br />
EBITDA<br />
Total Assets<br />
less Segment<br />
Liabilities<br />
($b)<br />
1.2<br />
25<br />
0.9 1.0<br />
0.6<br />
0<br />
0.0<br />
-25<br />
(30)<br />
(40)<br />
-0.6<br />
Increased expenditure on international growth<br />
-50<br />
Dec 10 Dec 11<br />
Dec 10 Dec 11<br />
-1.2<br />
45 |
Building on its domestic success, <strong>Origin</strong> is exploring for<br />
resources in markets that offer high prospectivity and access to<br />
growing demand<br />
• Low cost resources<br />
• Fuel source of the future<br />
• Leverage existing experience<br />
• Low cost market entry<br />
• Growing demand for energy<br />
• Low regulatory environment<br />
• Feasibility studies for PNG hydro have begun; FID expected by 2015<br />
• Exploration continued in Chile; JV acquired additional geothermal concessions<br />
• Exploration activities continue in Indonesia in second half FY<strong>2012</strong><br />
• Habanero 4 exploration well scheduled to spud in coming weeks<br />
• Transform Solar completed commissioning 20 MW p.a. production line<br />
• Exploring range of alternative pathways to scale SLIVER technology<br />
46 |
4. Outlook<br />
Grant King, Managing Director
Based on prevailing market conditions, <strong>Origin</strong> confirms its<br />
FY<strong>2012</strong> guidance provided in August 2011<br />
• <strong>Origin</strong> provided FY<strong>2012</strong> guidance based on prevailing business conditions and following<br />
assumptions:<br />
- Full year contribution from NSW acquisition<br />
- Initial contribution from Mortlake Power Station<br />
- Lower levels of planned exploration expense versus prior year<br />
- Improved profitability due to increased flexibility of Contact‟s energy supply portfolio<br />
• Performance largely in line with expectations, with variations including:<br />
- Lower volumes in Australian energy markets from mild weather offset by strong<br />
performance of generation portfolio<br />
- Mortlake Power Station previously expected during first half; both units now expected to<br />
be fully operational by end of second half<br />
- Increased portfolio flexibility for Contact and improved New Zealand wholesale prices<br />
largely offset by low hydro generation volumes and high levels of retail competition<br />
Based on <strong>Origin</strong>’s current assessment of operations and prevailing market<br />
conditions, <strong>Origin</strong> anticipates Underlying EBITDA and Underlying Profit to<br />
increase by around 35 and 30 per cent respectively when compared with FY2011<br />
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<strong>Origin</strong> continues to deepen the integration of its business …<br />
… which is delivering strong growth in earnings and a robust business<br />
in challenging markets …<br />
• Extensive fuel position<br />
• Large, flexible and diverse generation portfolio<br />
• Australia‟s leading energy retailer<br />
• Integration across the energy chain supports stability of margins<br />
… as well as an expectation for strong growth in the medium term …<br />
• Margin growth through <strong>Origin</strong>‟s legacy gas, coal and renewables positions due to<br />
imminent tightening of market supply/demand balances<br />
• Gas supply to third party CSG to LNG projects at export prices<br />
• Commencement of APLNG‟s project, offering exposure to rapidly growing Asian<br />
energy markets<br />
… and low-cost options for growth in the longer term<br />
• Gas development options on Australian east coast such as Ironbark and Halladale/Blackwatch<br />
• Unconventional reserves growth in Australia (Cooper, Surat/Bowen, Perth basins)<br />
• Exploration and development of geothermal resources in Chile and Indonesia<br />
• Assessment and development of hydro resources in PNG<br />
• Exploration for gas in New Zealand, Otway/Bass basins, South East Asia, Botswana and Kenya<br />
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Thank you<br />
Further Information<br />
Lina Melero<br />
General Manager, Corporate Communication<br />
Email: lina.melero@originenergy.com.au<br />
Office: +61 2 8345 5217<br />
Mobile: + 61 427 017 798<br />
Website<br />
www.originenergy.com.au<br />
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