Woodside Petroleum Ltd. ASX Announcement ACN 004 898 962 Woodside Plaza 240 St Georges Terrace Perth WA 6000 Australia Thursday, 15 January 2015 ASX: WPL OTC: WOPEY www.woodside.com.au FOURTH QUARTER REPORT FOR PERIOD ENDED 31 DECEMBER 2014 Highlights Record annual production of 95.1 million barrels of oil equivalent (MMboe), up 9.3% on 2013. Record annual sales revenue of $7,076 million up 11% on previous record of $6,348 million, in 2012. A binding transaction was entered into to acquire Apache’s Wheatstone LNG, Balnaves oil and Kitimat LNG project interests, for an aggregate purchase price of US$2.75 billion. Completed basis of design for the Browse FLNG Development. Consistent with our strategy we have captured additional exploration acreage in the Atlantic Margins: Farm in to the Tilapia Production Sharing Contract, located off the coast of Cameroon. Farm in to offshore blocks in the Scotian Basin, located off the coast of Nova Scotia, Canada. The North West Shelf (NWS) project participants: Approved the Persephone Project off the north-west coast of Australia. Signed a non-binding Letter of Intent with Hess Exploration Australia to process resources from Hess’ permits in the Carnarvon Basin. With lower oil prices we are assessing the impact on near term profitability and future cash flows and revising investment expenditure accordingly. An update will be provided in February. Comparative performance at a glance Full Year comparison Production Sales Sales Revenue MMboe MMboe $ million Previous quarter 2014 2013 Change % 95.1 93.2 7,076 87.0 85.7 5,776 +9.3 +8.8 +22.5 Q4 2014 Q3 2014 Change % Production MMboe 23.4 25.2 - 7.1 Sales MMboe 24.1 24.5 -1.6 Sales Revenue $ million Corresponding quarter, prior year 1,762 1,959 -10.1 Q4 2014 Q4 2013 Change % Production MMboe 23.4 23.2 + 0.9 Sales Sales Revenue MMboe $ million 24.1 1,762 23.0 1,648 + 4.8 + 6.9 All dollar amounts are in US dollars unless otherwise stated Key production and sales points for the quarter: Relative to previous quarter (Q3 2014) Production volumes were 7.1% lower predominantly due to lower LNG and condensate volumes associated with the NWS Train 1 planned shutdown, partially offset by increased oil volumes reflecting our focus on reliability. Sales volumes were 1.6% lower due to lower production, partially offset by timing of shipments. Sales revenue for the quarter was 10.1% lower reflecting lower LNG sales volumes and lower oil prices, partially offset by higher oil sales volumes. The average Brent price for the quarter was US$77.07/bbl, 25.5% below the US$103.46/bbl average price in the previous quarter. Relative to corresponding period (Q4 2013) Production volumes were 0.9% higher and sales volumes were 4.8% higher predominantly due to higher oil volumes since the re-start of the Vincent FPSO in late 2013, partially offset by lower LNG volumes. Sales revenue for the quarter was 6.9% higher predominantly due to additional oil volumes sold primarily from Vincent. Production Summary Woodside’s share of production and sales for the quarter ended 31 December 2014 with appropriate comparatives: Q4 2013 Full Year 2014 Full Year 2013 Production(TJ) 19,857 21,485 20,410 81,537 85,318 Sales (TJ) 19,857 21,485 20,410 81,537 85,318 NWS LIQUEFIED NATURAL GAS (LNG) Production (t) 633,446 719,428 602,959 2,588,522 2,408,213 Sales Delivered (t) 618,169 711,833 598,144 2,527,516 2,386,241 63 72 61 256 244 NWS CONDENSATE Production (bbl) 1,466,683 1,601,004 1,581,155 6,103,036 6,886,404 Sales (bbl) 1,466,381 1,780,434 1,805,480 5,924,930 7,189,942 NWS OIL Production (bbl) 716,733 702,368 793,839 2,994,793 3,478,590 Sales (bbl) 869,843 661,222 840,920 3,032,249 3,396,489 NWS LIQUEFIED PETROLEUM GAS (LPG) Production (t) 23,487 25,272 21,589 98,158 109,335 Sales (t) 20,997 28,336 21,116 97,371 106,035 PLUTO LIQUEFIED NATURAL GAS (LNG) Production (t) 1,046,284 1,126,228 1,086,893 4,186,817 3,614,045 Sales Delivered (t) 1,010,488 1,120,246 1,089,513 4,016,604 3,504,123 Cargoes Delivered 16 19 18 65 58 PLUTO CONDENSATE Production (bbl) LAMINARIA–CORALLINA OIL ENFIELD OIL 718,770 761,929 744,310 2,886,904 2,601,153 1,232,802 538,423 360,311 3,404,410 2,335,974 Production (bbl) 260,254 260,458 199,528 994,136 1,042,664 Sales (bbl) 464,852 0 231,962 940,349 944,008 Production (bbl) 386,938 333,439 489,766 1,334,213 1,885,777 Sales (bbl) 433,159 447,465 447,315 1,403,713 1,757,872 STYBARROW OIL Production (bbl) 239,121 232,433 314,591 1,016,479 1,394,353 Sales (bbl) 287,699 0 557,485 837,494 1,672,016 VINCENT OIL Production (bbl) 1,232,359 1,160,706 365,495 5,036,515 365,495 Sales (bbl) 1,381,851 975,003 0 5,029,714 221,051 GULF OF MEXICO PIPELINE NATURAL GAS2 Production (MMBtu) 0 3,7783 142,840 131,032 823,619 Sales (MMBtu) 0 3 142,840 131,032 823,619 GULF OF MEXICO CONDENSATE2 Production (bbl) 0 41 386 324 1,493 Sales (bbl) 0 41 386 324 1,493 GULF OF MEXICO OIL2 Production (bbl) 0 0 148,830 223,986 716,026 Sales (bbl) 0 0 148,830 223,986 716,026 Total Production (boe) 4 23,420,601 25,211,381 23,227,342 95,093,890 86,998,393 24,061,112 24,465,769 22,958,711 93,235,109 85,659,708 Sales (bbl) Sales (boe) 2 3 4 Q3 2014 NWS PIPELINE NATURAL GAS1 Cargoes Delivered 1 Q4 2014 4 3,778 Woodside’s equity share is 50% of the first 414 TJ per day (contract flexibilities allow Woodside to receive 50% up to 517.5 TJ per day) and 16.67% for all gas produced above this amount. Gulf of Mexico production and sales volumes are reported net of royalties. Woodside completed a sale of its 20% interest in the Neptune asset on 20 May 2014. Production volumes are minor adjustments to reflect final sales to 20 May 2014. Conversion Factors are identified on page 9. Page 2 of 9 Sales Revenue and Expenditure Woodside’s share of sales revenue and exploration, evaluation and capital expenditure for the quarter ended 31 December 2014, with appropriate comparatives: Amounts in US$ million Q4 2014 Q3 2014 Q4 2013 Full Year 2014 Full Year 2013 Sales Revenue North West Shelf Pipeline Natural Gas LNG Condensate Oil LPG 79.6 375.3 110.1 70.9 14.8 95.2 460.9 172.1 71.3 22.8 95.5 410.6 195.3 93.7 16.8 376.0 1,653.5 568.4 308.0 80.0 366.4 1,645.3 754.4 376.5 88.3 Pluto LNG 805.5 935.2 641.2 2,908.6 1,701.4 Condensate 101.0 53.3 38.1 332.5 246.2 Laminaria-Corallina Oil 37.5 (2.2)1 25.1 85.5 99.1 Mutineer-Exeter2 Oil 0.0 0.0 0.0 0.0 0.2 Enfield Oil 37.9 47.5 52.2 146.1 199.7 Stybarrow Oil 22.5 (2.9)3 64.9 83.2 195.2 Vincent Oil 107.3 105.7 0.0 510.6 24.9 Gulf of Mexico4 Pipeline Natural Gas 0.0 0.0 0.0 0.0 0.0 (0.1) 0.9 0.1 13.9 0.9 0.0 22.1 4.6 0.2 73.5 1,762.4 1,958.8 1,648.3 7,075.4 5,775.9 54.9 46.7 48.5 199.0 149.8 1.8 60.1 0.0 160.9 0.0 1,819.1 2,065.6 1,696.8 7,435.3 5,925.7 125.1 2.2 2.1 29.1 1.9 0.4 31.9 22.9 2.8 274.4 21.4 11.3 244.4 44.8 26.6 129.4 31.4 57.6 307.1 315.8 (13.3) 8 30.7 159.2 6.6 48.8 35.2 110.9 1.6 13.5 39.2 77.5 13.2 131.9 128.9 410.4 14.3 21.2 145.2 388.6 31.5 183.2 196.5 143.4 685.5 586.5 Condensate Oil Total Sales Revenue LNG Processing Revenue Gross Trading Revenue5 Total Operating Revenue Exploration and Evaluation Expense Exploration Expensed Permit Amortisation Evaluation Expensed Total Capital Expenditure Exploration Capitalised6,7 Evaluation Capitalised7 Oil and Gas Properties7 Other Property, Plant and Equipment Total 1 2 3 4 5 6 7 8 The negative sales revenue represents an adjustment between the estimated price in June, and the final realised price in July. An 8.2% interest in the Mutineer-Exeter oil project sold, with effect from 1 July 2012. The negative revenue represents an adjustment to the expected realised price of product stock entitlements. Gulf of Mexico revenue is reported net of royalties. Woodside completed a sale of its 20% interest in the Neptune asset on 20 May 2014. Gross Trading Revenue equates to trading costs plus a margin. For example refer to pages 27 and 28 of 2014 half-year report. Exploration Capitalised represents expenditure on successful and pending wells, plus permit acquisition costs during the period and is net of well costs reclassified to expense on finalisation of well results. Project Final Investment Decisions result in amounts of previously capitalised Exploration and Evaluation expenditure (from current and prior years) being transferred to Oil & Gas Properties. The table above does not reflect the impact of such transfers. The negative capitalised exploration amount primarily reflects a well previously capitalised during drilling which has subsequently been expensed. Page 3 of 9 Production Activities Field Woodside share Q4 2014 Q3 2014 Full field Q4 2014 Q3 2014 Remarks Australia NWS - Average daily production Pipeline gas (TJ) Production was lower driven by reduced customer demand for the quarter. 216 234 467 494 LNG (t) 6,885 7,820 43,992 49,823 Production was lower for the quarter due to a planned maintenance shutdown of approximately one month on LNG Train 1. Condensate (bbl) 15,942 17,402 77,769 85,316 Production was lower due to lower gas production resulting from the LNG Train 1 shutdown. Oil (bbl) 7,791 7,634 23,372 22,903 Production was higher primarily due to improved facility utilisation. LPG (t) 255 275 1,615 1,735 Production was lower due to lower gas production resulting from the LNG Train 1 shutdown. Australia Pluto - Average daily production LNG (t) 11,373 12,242 12,636 13,602 Production was lower as a result of unplanned outages in December. Condensate (bbl) 7,813 8,282 8,681 9,202 Production was lower in line with LNG production. Other Australia - Average daily production Laminaria-Corallina Oil (bbl) 2,829 2,831 4,470 4,469 Production was stable due to improved facility utilisation offsetting natural reservoir decline. Enfield Oil (bbl) 4,206 3,624 7,010 6,041 Production was higher due to improved facility utilisation and wells returning to production during the quarter. Stybarrow Oil (bbl) 2,599 2,526 5,198 5,053 Production was slightly higher due to a well returning to production during the quarter partially offset by planned maintenance activities. Vincent Oil (bbl) 13,395 12,616 22,325 21,027 Production was higher due to improved facility reliability. Page 4 of 9 Development Activities Australia Browse FLNG Woodside completed basis of design, as well as key pre front-end engineering and design (FEED) work during the quarter. Additional strategic activities continue ahead of FEED phase entry and include further progressing primary approvals, managing impacts of the maritime boundary change affecting the Browse retention leases and additional technical work to de-risk the development. We anticipate that the development will be in a position to enter the FEED phase in mid-2015 and we are targeting a final investment decision in mid-2016. The revised schedule provides an opportunity to seek significantly lower cost outcomes for the Browse FLNG Development. Greater Enfield Area Studies continue on aggregating undeveloped oil resources in the Exmouth sub-basin, including Laverda and Cimatti, focusing on maximising the use of existing infrastructure. The development is currently in the concept select phase. Pluto - Xena During the quarter, drilling of Xena Phase 1 was completed. Xena first gas is expected in 2H 2015. North West Shelf Persephone The Persephone Project was approved by the NWS Project participants in November 2014. The Project involves a two-well, 7km subsea tieback from the Persephone field to the existing North Rankin Complex. The total investment for the project is expected to be approximately A$1.2 billion (100% cost) and access approximately 140 MMboe (100% share), with start-up expected in early 2018. Greater Western Flank Phase 1 Project During the quarter, the A$2.5 billion (100% cost) Greater Western Flank Phase 1 Project completed the subsea installation program and continued topside modifications. The Project remains on budget and on schedule for start-up in early 2016. Greater Western Flank Phase 2 Project FEED commenced for the Greater Western Flank Phase 2 Project in September 2014. The Project continues to progress towards a final investment decision in 2H 2015. LNG Export Approval In November, the NWS Project participants agreed to a new domestic gas commitment with the Government of Western Australia to enable additional LNG export commitments. This will take the form of a variation to the NWS State Agreement, which is subject to ratification by State Parliament. It will provide the NWS Project participants with State approval to export an additional 86 million tonnes of LNG. In addition the participants will market a quantity of domestic gas equal to 15% of the energy value of the LNG. North West Shelf third party gas processing In December, the NWS Project participants signed a non-binding Letter of Intent with Hess Exploration Australia which specifies proposed terms to toll resources from Hess’ permits in the Carnarvon Basin through the NWS Project’s Karratha Gas Plant. It is intended that, subject to the parties entering into binding agreements, Hess will deliver gas to the NWS Project’s offshore infrastructure for processing at the Karratha Gas Plant and will market and deliver its own volumes. A tie-in and operational integration front-end engineering and design studies agreement is expected to be executed in early 2015. International Sunrise During the quarter, the Timor-Leste and Australian Governments continued negotiations on an acceptable settlement following an adjournment on a dispute relating to the treaty on Certain Maritime Arrangements in the Timor Sea. Woodside has continued to engage with both governments to facilitate the timely progression of the development, including discussions on multiple development concepts, both on and offshore options. Page 5 of 9 Canada During the quarter, Woodside completed an initial geotechnical assessment of the Grassy Point site as part of its feasibility assessment of a potential LNG development. Woodside continues to consult with First Nations, government and community stakeholders and progress environmental and regulatory approval obligations under the Sole Proponent Agreement. Exploration and Appraisal Activities Cameroon During the quarter an agreement was finalised with Noble Energy and Glencore to farm in to the Tilapia Production Sharing Contract (PSC) off the coast of Cameroon. Under the agreement, Woodside will acquire a 30% non-operating interest. The Joint Venture plans to drill the Cheetah exploration well in 2015. The agreement is subject to required government and regulatory approvals. Nova Scotia Canada Woodside acquired a 20% participating interest in Exploration Licences 2431, 2432, 2433 and 2434 in the Scotian Basin off the coast of Nova Scotia, Canada. The future work program anticipates the drilling of exploration wells in 2017. The transaction remains subject to government and regulatory approvals. New Zealand During the quarter, environmental approvals for 3D seismic acquisition in the Taranaki Basin and Great South Basin were received from the Department of Conservation. Morocco During the quarter Woodside entered into a contract for an exclusive Reconnaissance Licence with the Office National Des Hydrocarbures et des Mines (the National Oil Company of the Kingdom of Morocco) to explore the Rabat Ultra Deep Offshore area. The licence is located west of the Rabat Deep Offshore I-VI blocks in which Woodside has a 25% interest. Republic of Korea Interpretation of data from the Muneo 3D seismic survey in the Ulleung Basin Block 8/6-1N continued during the quarter. Planning has commenced to drill an exploration well in the block in Q4 2015. Exploration or appraisal wells drilled during Q4 2014 Basin/ Area Target Woodside Interest (%) Spud Date Water 1 Depth (metres) Total Well 2 Depth (metres) Hannover South-1 Outer Canning Basin, WA-466-P Gas 43.90 18/07/2014 820 5,512 Exploration, dry hole Steel Dragon-1 Outer Canning Basin, WA-464-P Gas 55.00 03/11/2014 2,037 3,966 Exploration, dry hole Anhalt-1 Outer Canning Basin, WA-462-P Gas 43.90 08/11/20143 911 5,5594 Exploration, in progress Well Name Remarks AUSTRALIA Notes: 1 Water depth measured at lowest astronomical tide. 2 Well depths referenced to the rig rotary table. 3 The top-hole drilling of Anhalt-1 commenced during a period of rig availability during the Steel Dragon-1 operations. 4 Proposed total depth. Page 6 of 9 Permits and Licences Key changes to permit and licence holdings during the quarter are noted below (some transactions may be subject to government and regulatory approval). Region Change in Interest (%) Increase or (Decrease) Woodside‘s Current Interest % 65.00 65.00 Equity Acquisition1, 2 (90.00) 0.00 Permit Surrendered1 (90.00) 0.00 Permit Surrendered1 Rabat Ultra Deep Exclusive Reconnaissance Licence 75.00 75.00 Reconnaissance Licence Award Tilapia Licence 30.00 30.00 Equity acquisition1 EL 2431, 2432, 2433, 2434 20.00 20.00 Equity acquisition1 Permit or Licence Area Remarks AUSTRALIA WA-356-P Carnarvon Basin WA-347-P Exmouth Plateau WA-348-P Exmouth Plateau MOROCCO Offshore Rabat Ultra Deep Cameroon Douala Basin Canada Scotian Basin Notes: 1 Subject to government and regulatory approval. 2 Subject to conditions precedent under the Sale and Purchase Agreements as part of the acquisition of Apache assets announced during the quarter. Geophysical surveys conducted during Q4 2014 Location Survey name Progress INTERNATIONAL Block 108, Peru Block 108 2D 180 km of 550 km in Q4 (incomplete) Lake Tanganyika South Block, Tanzania Lake Tanganyika Geophysical Survey 2014 1,244 km in Q4 (complete) Lake Tanganyika South Block, Tanzania Tanganyika 2D TZ Seismic 2014 82 km of 111 km in Q4 (incomplete) Exploration or appraisal wells planned to commence in Q1 2015 Well Name Basin / Area Target Woodside Interest (%) Water Depth 1 (metres) Gas 90.00 961 Proposed Total Depth 2 (metres) Remarks AUSTRALIA Pyxis-1 Carnarvon Basin, WA-34-L Notes: 1 Water depth measured at lowest astronomical tide. 2 Reported depths referenced to the rig rotary table. Page 7 of 9 3,137 Exploration Corporate Activities Marketing In December Woodside signed a Heads of Agreement (HOA) with Singapore-based Pavilion Gas for the supply of up to 0.56 mtpa of LNG from our portfolio for a term of 13 years starting in 2020. The HOA includes several conditions precedent and is expected to be converted into a Sale and Purchase Agreement (SPA) in 2015. The SPA will be subject to Board approvals of both companies. Subsequent to the end of the quarter, on 14 January 2015, Woodside and Japan Australia LNG (MIMI Browse) Pty Ltd mutually agreed to terminate a Joint Marketing Agreement (JMA) executed on 30 April 2012. The JMA was for joint marketing to primarily Japanese customers of LNG to be produced from the Browse LNG development. Woodside continues to have ongoing discussions with various regional LNG customers regarding potential LNG sales from its growing global LNG portfolio, including Browse LNG. Business Development In December Woodside entered into a binding transaction with Apache Corporation to acquire Apache’s Australian Wheatstone LNG and Balnaves oil interests and Kitimat LNG project interests in Canada, for an aggregate purchase price of US$2.75 billion. Under the terms of the Sale and Purchase Agreements, Woodside will acquire: a 13% interest in the Wheatstone LNG Project and a 65% interest in the Julimar-Brunello upstream gas development, with near-term production; a 65% interest in the Balnaves oil project, with immediate production; and a 50% interest in the Kitimat LNG project, including approximately 320,000 acres in the Horn River and Liard Basins, adding a growth option in an emerging LNG province to Woodside’s development portfolio. The acquisition has an effective date of 1 July 2014 and is subject to regulatory approvals, pre-emption for both Balnaves oil and Kitimat LNG projects and joint venture participant consent for the Kitimat LNG project. Woodside and Apache have commenced the process of obtaining the necessary regulatory approvals and joint venture participant consents, and are targeting financial close by end Q1 2015. The transaction will have no material impact on Woodside’s 2014 financial accounts. Credit Rating Woodside’s credit ratings have been affirmed by Standard & Poor’s (BBB+) and Moody’s (Baa1) following the announcement of the transaction to acquire Apache’s interests in key assets. Finance Facilities During the quarter, Woodside entered into $2 billion of short term bilateral facility agreements for general corporate purposes. Preliminary 2014 income statement, line item guidance The following numbers are provided as an indicative guide and are subject to the external audit processes and the Woodside Board approval of the 2014 Financial Statements. Petroleum Resource Rent Tax (PRRT) PRRT for 2014 is anticipated to be in the range of $0 million to $90 million benefit. This reflects underlying business performance and the offsetting impact of augmentation on carry forward deductible expenditure. Impairments of oil and gas properties Impairments for full-year 2014 are anticipated to be in the range of $250 million to $400 million pre-tax ($100 million to $170 million after income tax and PRRT). For the purpose of calculating the final dividend, it is intended that the net value of all 2014 impairments after income tax and PRRT, will be added back to Reported Profit. The final dividend is subject to Board approval. Page 8 of 9 2015 Production Outlook Woodside’s production target range for 2015 is 84 - 91 MMboe, comprising a product split of approximately 38% Pluto LNG, 26% NWS LNG, 15% NWS Domestic gas and 21% condensate, oil and LPG. This range does not include production from the Balnaves oil project. An updated production target range will be issued after the transaction has closed. Relative to 2014, the main production differences expected in 2015 are: MMboe Pluto – planned shutdown in the order of one month duration ~(3.4) NWS pipeline natural gas – variance due to lower customer demand ~(0.5) System utilisation, including allowance for cyclone impacts ~(1.2) Field decline across all oil assets ~(2.2) Asset sales – Gulf of Mexico ~(0.3) 2015 Investment Expenditure Outlook In light of the current challenging market conditions which has seen crude oil pricing decrease from over $100 per barrel in September 2014, to around $55 per barrel at the beginning of January, Woodside is assessing the impact on near term profitability and cash flows, and revising investment expenditure accordingly. We expect to provide a 2015 Investment expenditure outlook concurrent with the 2014 Full Year results. 2014 Full Year Results Webcast The 2014 annual results, 2014 Annual Report and the associated investor briefing presentation will be available on Woodside’s website at www.woodside.com.au on Wednesday, 18 February 2015. A media specific briefing will take place at 6.30am (AWST) on 18 February 2015 and a separate investor/analyst briefing will take place at 7.30am (AWST) on 18 February 2015. The briefings will be streamed live to Woodside’s website. Annual General Meeting In accordance with ASX Listing Rule 3.13.1, Woodside advises that its Annual General Meeting will be held in Perth, Western Australia on Thursday, 16 April 2015. Investor Briefing Day Woodside advises that its 2015 Investor Briefing Day will be held in Melbourne, Victoria on Thursday, 21 May 2015. CONVERSION FACTORS (boe) = barrel of oil equivalent (TJ) = terajoules (MMcfg) = million cubic feet of gas (t) = tonne (bbl) = barrel (MMBtu) = million British thermal units (Bcf) = billion cubic feet of gas (kt) = thousand tonnes Product Factor Australian Pipeline Natural Gas Liquefied Natural Gas (LNG) Condensate Oil Liquefied Petroleum Gas (LPG) Gulf of Mexico Pipeline Natural Gas 1TJ 1 tonne 1 bbl 1 bbl 1 tonne 1 MMBtu Conversion Factors* = = = = = = * minor changes to some conversion factors can occur over time due to gradual changes in the process stream Contacts: MEDIA INVESTORS Michelle Grady W: +61 8 9348 5995 M: +61 418 938 660 E: [email protected] Craig Ashton W: +61 8 9348 6214 M: +61 417 180 640 E: [email protected] Page 9 of 9 163.6 boe 8.9055 boe 1.000 boe 1.000 boe 8.1876 boe 0.1724 boe
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