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*
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* 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