US AND CANADA ROADSHOW PRESENTATION
O C T O B E R / N O V E M B E R 2 0 1 9
US AND CANADA ROADSHOW PRESENTATION Compliance statements - - PowerPoint PPT Presentation
O C T O B E R / N O V E M B E R 2 0 1 9 US AND CANADA ROADSHOW PRESENTATION Compliance statements Disclaimer Financial Data Certain statements in this presentation may include, in addition to historical information, "forward-looking
O C T O B E R / N O V E M B E R 2 0 1 9
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Compliance statements
Disclaimer Certain statements in this presentation may include, in addition to historical information, "forward-looking statements" within the meaning of the "safe-harbor" provisions of the U.S. Private Securities Litigation Reform Act of 1995. Forward-looking statements are neither historical facts nor assurances of future performance. Instead, they are based
strategies, projections, anticipated events and trends, the economy and other future conditions. Because forward- looking statements relate to the future, they are subject to inherent uncertainties, risks and changes in circumstances that are difficult to predict and many of which are outside of our control. Our actual results and financial condition may differ materially from those indicated in the forward-looking statements. Therefore, you should not rely on any of these forward-looking statements. These forward looking statements are subject to risk factors associated with oil, gas and related businesses. It is believed that the expectations reflected in these statements are reasonable but they may be affected by a variety of variables and changes in underlying assumptions which could cause actual results or trends to differ materially, including, but not limited to: price fluctuations, actual demand, currency fluctuations, drilling and production results, reserve estimates, loss of market, industry competition, environmental risks, physical risks, legislative, fiscal and regulatory developments, economic and financial market conditions in various countries and regions, political risks, project delays or advancements, approvals and cost estimates. Although forward-looking statements contained in this presentation are based upon what management of Beach believes are reasonable assumptions, there can be no assurance that forward-looking statements will prove to be accurate, as actual results and future events could differ materially from those anticipated in such statements. Beach undertakes no obligation to update forward-looking statements if circumstances or management’s estimates or opinions should change except as required by applicable securities laws. The reader is cautioned not to place undue reliance on forward-looking statements. Reserves disclosure Beach prepares its petroleum reserves and contingent resources estimates in accordance with the Petroleum Resources Management System (PRMS) published by the Society of Petroleum Engineers. The reserves and contingent resources presented in this report were originally disclosed to the market in the FY19 annual report released 19 August 2019. Beach confirms that it is not aware of any new information or data that materially affects the information included in the aforesaid market announcement and that all the material assumptions and technical parameters underpinning the estimates in the aforesaid market announcement continue to apply and have not materially changed. The reserves and resources information in this report is based on, and fairly represents, information and supporting documentation prepared by, or under the supervision of, Mr David Capon (Manager Development Offshore Victoria, New Zealand and NT). Mr Capon is a full time employee of Beach Energy Limited and has a BSc (Hons) degree from the University of Adelaide and is a member of the Society of Petroleum Engineers. He has in excess of 25 years of relevant experience. The reserves and resources information in this presentation has been issued with the prior written consent of Mr Capon as to the form and context in which it appears. Conversion factors used to evaluate oil equivalent quantities are sales gas and ethane: 5.816 TJ per kboe, LPG: 1.398 bbl per boe, condensate: 1.069 bbl per boe and oil: 1 bbl per boe. The reference point for reserves determination is the custody transfer point for the products. Reserves are stated net of fuel, flare & vent and third party royalties. Financial Data Underlying EBITDAX (earnings before interest, tax, depreciation, amortisation, evaluation, exploration expenses and impairment adjustments), underlying EBITDA (earnings before interest, tax, depreciation, amortisation, evaluation and impairment adjustments), underlying EBIT (earnings before interest, tax, and impairment adjustments) and underlying profit are non-IFRS financial information and also non-GAAP financial measures within the meaning of Regulation G under the US Securities Exchange Act of 1934. provided to assist readers to better understand the financial performance of the underlying operating business. They have not been subject to audit or review by Beach’s external auditors. The information has been extracted from the audited financial statements. The non-IFRS/non-GAAP financial information do not have a standardised meaning prescribed by Australian Accounting Standards and, therefore, may not be comparable to similarly titled measures presented by other entities, nor should they be construed as an alternative to other financial measures determined in accordance with Australian Accounting Standards. Recipients are cautioned, therefore, not to place undue reliance on any non-IFRS/non-GAAP financial information and ratios included in this presentation. Free cash flow in this presentation is defined as cash flows from operating activities plus cash flows from investing activities less cash flows from acquisitions and divestments. All references to dollars, cents or $ in this presentation are to Australian currency, unless otherwise stated. References to “Beach” may be references to Beach Energy Limited or its applicable subsidiaries. Unless otherwise noted, all references to reserves and resources figures are as at 30 June 2019 and represent Beach’s share. References to planned activities in FY20 and beyond FY20 may be subject to finalisation of work programs, government approvals, joint venture approvals and board approvals. Due to rounding, figures and ratios may not reconcile to totals throughout the presentation. Historical trading prices for securities of Beach cannot be relied upon as an indicator of (and provides no guidance as to) the future trading pride of securities of Beach. The historical information included in this presentation is, or is based on, information that has previously been released to the market, and is not represented as being indicative of the views of Beach on its future financial condition and/or performance. Assumptions The five year outlook set out in this presentation is not guidance. The outlook is uncertain and subject to change. The outlook has been estimated on the basis of the following assumptions: 1. a US$62.50/bbl Brent oil price in FY20 and a US$70/bbl Brent oil price from FY21; 2. 0.70 AUD/USD exchange rate in FY20 and 0.75 AUD/USD exchange rate from FY21; 3. various other economic and corporate assumptions; 4. assumptions regarding drilling results; and 5. expected future development, appraisal and exploration projects being delivered in accordance with their current expected project schedules. FY20 guidance is uncertain and subject to change. FY20 guidance has been estimated on the basis of the following assumptions: 1. a US$62.50/bbl Brent oil price;
and 5. expected future development, appraisal and exploration projects being delivered in accordance with their current expected project schedules. These future development, appraisal and exploration projects are subject to approvals such as government approvals, joint venture approvals and board approvals. Beach expresses no view as to whether all required approvals will be
Investment risk An investment in Beach securities is subject to known and unknown risks, a number of which are beyond the control of Beach. Beach does not guarantee any particular rate of return or the performance of Beach’s securities, nor does it guarantee the repayment of capital from Beach or any particular tax treatment. Recipients should make their own enquiries and investigations regarding all information in this presentation, including but not limited to the assumptions, uncertainties and contingencies which may affect future operations of Beach and the impact that different future outcomes may have on Beach.
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Beach Energy portfolio
29.4 MMboe 326 MMboe
FY19 2P reserves
Western Flank Cooper Basin Perth Basin Otway Basin Bass Basin Taranaki Basin
FY19 production
Western Flank Cooper Basin Perth Basin Otway Basin Bass Basin Taranaki Basin
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Asset summary
Asset Beach Interest Operator? FY19 production1 (MMboe) FY19 2P reserves2 (MMboe) FY20 capex3 range ($million) Key FY20 proposed activities
Western Flank Oil 40 – 100% Op/Non-op 5.2 42 200 – 225 Drill up to 77 wells Western Flank Gas 100% Op 1.9 16 40 – 60 Drill up to 7 wells Cooper Basin JV Various Non-op 8.3 84 200 – 220 Drill ~100 wells SA Otway 70 - 100% Op
30 – 35 Drill 2 wells. Gas facility construction Vic Otway 60% Op 8.4 62 205 – 225 Commence 10 well drilling campaign BassGas 53.75%4 Op 1.7 20 10 – 25 Trefoil concept select Kupe (New Zealand) 50% Op 3.2 27 15 – 20 Compression project FID Perth Basin 50%5 Op/Non-op 0.7 73 30 – 35 Drill 1 well. Waitsia Stage 2 FID Frontier Exploration Various Op/Non-op
Preparation for FY21 drilling TOTAL 29.4 326 750 – 850
1. Refer to Q4 FY19 quarterly report ref: #020/19 dated 24th July 2019 for further details 2. Refer to FY19 annual report for further details 3. Based on data contained within slide 13 4. Beach interest in producing permits. 50.25% interest in retention licenses. 5. Note that Perth Basin, Beharra Springs interest of 50% is subject to completion of sale of 17% interest to Mitsui E&P Australia
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Executive Summary
1. Market capitalization as at 22 October 2019 2. EnergyQuest September 2019 quarterly report 3. Based on Beach actual FY19 production divided by estimated FY19 east coast domestic gas demand from the 2018 AEMO Gas Statement of Opportunities 4. Refer to Compliance Statements slide for reserves disclosures 5. Internal rates of return are calculated based on internal assumptions. Refer to slide 2 for further detail regarding assumptions and disclaimer
Company overview
✓ Listed on the Australian securities exchange (code: BPT.AX) ✓ Market capitalization ~A$5.3 billion (~US$3.7 billion)1 ✓ Diversified portfolio of producing assets in 5 basins in Australia and New Zealand ✓ Oil and gas infrastructure ownership, operating 70% of group production in FY19
Footprint High margin investment Five year outlook Financial discipline
✓ Investment prioritized towards conventional oil, Australian east coast gas market ✓ Over 90% of growth investment commencing in FY20 generating IRRs > 50%5 ✓ Production: 34 – 40 MMboe in FY24 ✓ Cumulative free cash flow: A$2.7 billion over next 5 years ✓ Strong balance sheet position. Debt-free with net cash of A$214 million at 30 Sep 2019 ✓ Target ~A$4 billion investment FY20 – FY24 to grow production and free cash flow
Australian oil and gas producer
✓ Largest Australian oil producer in FY192 ✓ Supplied an estimated 15% of Australian east coast domestic gas market in FY193
Reserves position and outlook
✓ 326 MMboe 2P reserves at 30 June 2019, 2P reserves life 12.4 years4 ✓ Targeting > 100% 2P reserves replacement average over next 5 years
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Delivering on our promises
Beach said…. In FY19 Beach delivered…
FY19 production1 26 – 28 MMboe
✓
29.4 MMboe FY19 capital expenditure1 $460 – 540 million
✓
$447 million FY19 free cash flow2 ~$290 million
✓
$559 million FY19 underlying EBITDA2 $1.1 – 1.2 billion
✓
$1.375 billion Return on capital employed (ROCE) 17 – 20%
✓
27% Five year average 2P reserves replacement ratio >100%
✓
204% Lattice synergies Target of $60m p.a. by end of FY19
✓
Synergy target met Direct controllable operating costs $30m p.a. reduction by end of FY20
✓
$21 million p.a. reduction by end of FY19
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200 400 600 800 1,000 1,200 FY20E FY21E FY22E FY23E FY24E
20 25 30 35 40
FY19A FY20E FY21E FY22E FY23E FY24E
Investing to accelerate production and free cash flow growth
Beach is now targeting 34–40MMboe annual production in the medium term… …and cumulative free cash flow3
the next 5 years… Production outlook1
(MMboe)
Free cash flow outlook1
($ million)
Outlook presented October 2018 Updated 5 year outlook
…by accelerating investment in
Capital expenditure outlook1
($ million)
200 400 600 800 1,000 Range
750 - 850 650 - 800 FY20 guidance range FY21 – 24 Outlook
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HSE Performance
Lattice acquisition safely integrated
Safety performance
15.6 3.8 7.9 3.5 3.4 4 8 12 16 TRIFR1
Focus on HSE delivering best performance to date
Process Safety - Loss of containment3
51.9 9.6 0.2 0.1 0.07
FY15 FY16 FY17 FY18 FY19
99.9%
Crude Spill Volumes (kl)
Environmental performance2
2017 2018 FY19 FY18 FY16 FY17 FY15 2019 2 4 6 8 10 Dec Feb Apr Jun Aug Oct Dec Feb Apr Jun Aug Oct Dec Feb Apr June
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FY20 guidance
FY19 Reported1 FY19 Pro Forma1 FY20 Guidance Production 29.4 MMboe 26.2 MMboe 27 – 29 MMboe Capital Expenditure2 $447 million $435 million $750 – 850 million Underlying EBITDA $1.375 billion $1.22 billion $1.25 – 1.40 billion DD&A3 $523 million ($17.8/boe) $443 million ($16.9/boe) $17-18 / boe
1. FY19 Reported data accounts for Victoria Otway assets at 100% for 11 months to 31 May 2019 and 60% for June 2019. FY19 Pro Forma adjusts to reflect Victorian Otway assets at 60% for the entire FY19. 2. Excludes corporate capital expenditure 3. Excludes DD&A associated with corporate assets
All guidance is unchanged following the release of Q1 FY20 quarterly report
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FY20 capital expenditure guidance splits
Investment focus remains on Cooper Basin and Victoria
26% 33% 27% 4% 4% 5%
Cooper Basin JV Western Flank Vic Otway SA Otway WA Other
29% 57% 14%
Exploration/Appraisal Development Fixed
Capital expenditure by type …by asset group
62% 30% 8% East Coast Gas Oil Other
…by target Increase in FY20 vs FY19 driven by
FY20 (~$50 million)
East Coast and Cooper Basin focus
supplies for the east coast gas market
“Fixed” refers to stay-in-business capital expenditure. Growth projects defined as Exploration/appraisal and Development projects Other represents New Zealand, Western Australia and Frontier
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East coast gas market
Southeastern Australia gas demand vs production1
Market dynamics support Beach’s investment strategy
100 200 300 400 500 600 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028 2029 2030 2031 2032 2033 2034 2035 2036 2037 2038
PJ
Southern production from anticipated projects Southern production from existing and committed projects Southern demand
Supply gap expected to be met by LNG diversions and/or LNG imports in the absence of material new indigenous supply sources LNG exports from QCLNG, APLNG and GLNG Location of proposed LNG import terminals
Conventional supply CSG supply
ranging from $8.87 – 10.83/GJ for gas supply in 2020
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Attractive medium-long term pricing outlook
step-ups and CPI adjustments ahead of repricing events
Beach’s east coast gas sales is expected to be re-priced or re- contracted
supported by market dynamics
Higher gas sales and repricing of legacy volumes to deliver higher gas revenues
Re-contracted / re-priced volumes
Almost 80% of Beach’s estimated FY24 east coast gas sales is expected to be sold at prevailing market prices Beach average realised price: FY19 $6.81/GJ
East coast gas supply
0% 10% 20% 30% 40% 50% 60% 70% 80% 90% 100% FY20 FY21 FY22 FY23 FY24 Legacy Pricing New Market Pricing
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Delivering as a low cost operator
value through safe, reliable and efficient operations
improve to >97% across our six operated facilities in FY19
reduction in direct controllable operating costs
costs by the end of FY20 remains on track
99% across our six operated facilities - focus now on maintaining reliability above 98% for FY20
Beach operating costs/boe1
1. Operating costs exclude royalties, tolls, tariffs and 3rd party purchases. Operating costs per boe is for the entire group and includes both operated and non-operated assets 2. Relative to FY18 baseline direct controllable operating costs of $160 million
$/boe 9.1 9.7 9.3 9.9 9.4 9.2 8 9 10
FY17 (pre-Lattice) FY18 (blend of pre- and post- Lattice) FY19 H2 FY18 H1 FY19 H2 FY19
Full year data Half year data
U S A N D C A N A D A R O A D S H O W P R E S E N TAT I O N
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Cooper Basin Overview
Key assets include Western Flank (operated and non-operated) and CBJV (non-operated)
years
large acreage relinquishment in 1999. Its potential has only been recently unlocked following a change in appraisal strategy
and Moomba gas plant) provides secure access to markets
targeting a 10-23% increase in output from 2018 to 2025
Beach’s Cooper Basin interests span more than 8 million acres with surface infrastructure
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Western Flank Oil
Record year of investment and drilling activity planned in FY20
FY19 2P reserves
Western Flank Oil Rest of Beach
FY19 production
29.4 MMboe
Western Flank Oil Rest of Beach
326 MMboe
5.2 MMboe 42 MMbbl,
FY20 proposed activities
horizontal wells)
infrastructure expansion and debottlenecking to unlock Western Flank potential
strategy across fields as well as follow-up appraisal drilling at Bauer, Hanson and Kalladeina-Congony complex
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Western Flank Oil
Bauer (Beach 100% interest) – keeps on getting bigger
Success of the Bauer appraisal strategy
defining field extent
easterly extension to the field
structure, remaining oil potential and full field development
and 15 development wells, including 7 horizontal wells
Bauer North-2, coming in 6 metres and 8 metres high to prognosis respectively.
campaign and reserves updated at the end of FY20
Top reservoir map (pre-2018 appraisal campaign) Top reservoir map (pre-2019 appraisal campaign)
Bauer NW-2 Bauer N-2
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Western Flank Gas
ex PEL 106, ex PEL 107 and ex PEL 91, Beach 100% and operator
FY20 Focus:
and Middleton
3D seismic survey to extend proven stratigraphic play and test new exploration plays
plateau at Middleton and/or expand capacity
FY19 2P reserves
Western Flank Gas Rest of Beach
FY19 production
29.4 MMboe
Western Flank Gas Rest of Beach
326 MMboe
1.9 MMboe 16 MMboe
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Cooper Basin JV
Beach various interests (20.76 - 52.2% range), Santos operator
FY19 2P reserves
Cooper Basin JV Rest of Beach
FY19 production
29.4 MMboe
Cooper Basin JV Rest of Beach
326 MMboe
FY20 Focus:
South coming out of the successful FY19 appraisal campaign
Permian reservoirs with follow-up potential in success case
8.1 MMboe 84 MMboe
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Victorian Otway Basin
Beach 60% and operator
FY19 2P reserves
Vic Otway Basin Rest of Beach
FY19 production
29.4 MMboe
Vic Otway Basin Rest of Beach
326 MMboe
8.4 MMboe 62 MMboe
FY20 Focus:
Reach Directional (ERD) wells to be drilled from mid-FY20
deliverability from H2 FY20
currently expected in March quarter 2020
Plant scheduled for March 2020
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Increasing exposure to market pricing
Otway Gas Plant gas production outlook (100% interest)1
Legacy contract pricing to end in FY21/22, exploration and La Bella adds flexibility
10 20 30 40 50 60 70 FY20E FY21E FY22E FY23E FY24E FY25E FY26E
Market prices (La Bella and one exploration success) Re-priced contracts Current contract prices
planned in the next 3 years to keep the Otway Gas Plant (OGP) full
fill OGP capacity by FY23
and leads. Two year rig contract provides flexibility in drilling schedule
debottlenecking OGP
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Bass Basin
Beach 53.75% producing assets, 50.25% non-producing, Beach operated
FY19 2P reserves
Bass Basin Rest of Beach
FY19 production
29.4 MMboe
Bass Basin Rest of Beach
326 MMboe
FY20 Focus:
field
to contract the remaining Yolla 2P reserves beyond expiration of current contract
1.7 MMboe 20 MMboe
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New Zealand – Kupe Gas Project
Beach 50% and operator
FY20 Focus:
project in Q1 FY20, expected to be completed by late FY21. Supports production plateau extension to FY24
November 2019
drilling potential (Kupe and NFE)
FY19 2P reserves
New Zealand Rest of Beach
FY19 production
29.4 MMboe
New Zealand Rest of Beach
326 MMboe
3.2 MMboe 27 MMboe
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Perth Basin
Waitsia (Beach 50%), Beharra Springs (Beach 50%1 and operator)
FY19 2P reserves
Perth Basin Rest of Beach
FY19 production
29.4 MMboe
Perth Basin Rest of Beach
326 MMboe
FY20 Focus:
expansion
100 – 250 TJ/day output
targeting the Kingia and High Cliff formations also intersected at Waitsia and West Erregulla-2, announced as a new gas discovery on 28 October
0.7 MMboe 73 MMboe
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Beharra Springs Deep gas discovery
Kingia Sandstone well Log comparison: Waitsia-4 to Beharra Springs Deep-1
well Beharra Springs Deep-1 (Beach 50% and
Kingia Sandstone
Waitisa-4
porosities up to 21%
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South Australian Otway Basin
Beach interests 70 – 100% and operator
FY20 Focus:
in the Pretty Hill Formation subsequent to quarter end
Ensign 931 rig at Haselgrove-4 drill site in the SA Otway Basin
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Frontier Exploration
Wherry – Canterbury Basin (Beach 37.5% interest)
High Impact Exploration Targets in Portfolio
Ironbark – Carnarvon Basin (Beach 21% interest)
Ironbark top reservoir structure Wherry top reservoir structure
NWS project
primary reservoirs at Gorgon
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Beach to employ 10 rigs in FY20, up from 5 in at the start FY19
Beach illustrative rig schedule1
Ocean Onyx (Offshore Vic) Non-operated rig (Santos operator) Operated rig (oil development) Operated rig (oil exploration & appraisal + gas) Operated/non-operated rig (oil appraisal) Haselgrove-4 Dombey-1 Black Watch-1 Enterprise-1 H1 FY20 H2 FY20 H1 FY21 Cooper Basin JV Western Flank
Beharra Springs Deep-1
Easternwell 106 Perth Basin Offshore program to commence with the Artisan-1 exploration well Ensign 931 (onshore SA and Vic extended reach drilling) Otway Basin
Beach has significantly expanded its drilling capabilities over the past 18 months to operate 6 rigs in FY20
Non-operated rig (Santos operator) Non-operated rig (Santos operator) Non-operated rig (Santos operator)
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Indicative FY20 drilling program
Record drilling activity in the Western Flank, offshore Otway drilling to commence
FY20 expected number of wells
Subject to change.
Gas Oil Total
Western Flank 7 77 84 Cooper Basin JV 83 20 103 Total Cooper Basin 90 97 187 SA Otway Basin 2 2 Victorian Otway Basin 4 4 Perth Basin 1 1 Total Beach 97 97 194
Highlights
planned) set to materially increase oil production
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Reserves and contingent resources
Highlights
✓ 2P reserves increased by 4% from 313 MMboe to 326 MMboe ✓ 204% organic 2P reserves replacement ✓ 2P reserves life increased from 11.0 years to 12.4 years ✓ Western Flank oil and gas had 2P Total Revisions of 22 MMboe
Key factors influencing 2P reserves
✓ Sale of 40% interest in Victorian Otway assets ✓ Victorian Otway Basin: Rigorous reassessment of existing fields ✓ Western Flank: Positive reservoir performance and appraisal success ✓ Cooper Basin JV: Moomba South appraisal and oil appraisal results ✓ New 2P reserves booking at Trefoil, Haselgrove, La Bella
204% organic 2P reserves replacement, well ahead of 100% five year average target
Summary of reserves at 30 June 2019 (developed plus undeveloped, net to Beach)
(MMboe ) FY18 FY19 1P reserves 190 201 +6% 2P reserves 313 326 +4% 3P reserves 491 514 +5% 2C contingent resources 207 185 (11%)
Western Flank CBJV Perth Basin Otway Basin Bass Basin Taranaki Basin
326 MMboe
Refer to Compliance Statement slides for reserves disclosures.
2P reserves
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Financial highlights
Underlying NPAT recognises
Operating cash flow
Net cash position
dividend announced
1. Excludes the impact of hedging 2. Underlying results in this presentation are categorised as non-IFRS financial information provided to assist readers to better understand the financial performance of the underlying operating business. They have not been subject to audit or review by Beach’s external auditors. The information has been extracted from the audited financial statements. For a reconciliation of FY19 net profit after tax to underlying net profit after tax, refer to Appendix.
$ million (unless otherwise indicated) FY18 FY19 Change Production (MMboe) 19.0 29.4 55% Sales volumes (MMboe) 20.1 31.2 55%
93.4 101.8 9%
6.57 6.81 4% Sales revenue 1,251 1,925 54% Underlying EBITDA 766 1,375 80% Net profit after tax 199 577 190% Underlying NPAT2 302 560 86% Operating cash flow 663 1,038 57% Net assets 1,838 2,374 29% Net (debt) / cash (639) 172
Beach Energy Limited
Level 8, 80 Flinders Street Adelaide SA 5000 Australia T: +61 8 8338 2833 F: +61 8 8338 2336 beachenergy.com.au
Investor Relations
Nik Burns, Investor Relations Manager Mark Hollis, Investor Relations Advisor T: +61 8 8338 2833