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Supplementary oil and gas information
 12 Months Ended
Jun. 30, 2020
Subclassifications of assets, liabilities and equities [abstract]  
Supplementary oil and gas information
5.7    Supplementary oil and gas information – unaudited
In accordance with the requirements of the Financial Accounting Standards Board (FASB) Accounting Standard Codification ‘Extractive
Activities-Oil
and Gas’ (Topic 932) and SEC requirements set out in Subpart 1200 of Regulation
S-K,
the Group is presenting certain disclosures about its oil and gas activities. These disclosures are presented below as supplementary oil and gas information, in addition to information disclosed in section 1.11.1 ‘Petroleum’ and section 6.4.1 ‘Petroleum reserves’.
The information set out in this section is referred to as unaudited as it is not included in the scope of the audit opinion of the independent auditor on the Financial Statements, refer to section 5.6 ‘Independent Auditors’ reports’.
On 28 September 2018, BHP completed the sale of 100 per cent of the issued share capital of BHP Billiton Petroleum (Arkansas) Inc. and 100 per cent of the membership interests in BHP Billiton Petroleum (Fayetteville) LLC, which held the Fayetteville assets. On 31 October 2018, BHP completed the sale of 100 per cent of the issued share capital of Petrohawk Energy Corporation, the BHP subsidiary which held the Eagle Ford (being Black Hawk and Hawkville), Haynesville and Permian assets. The financial and
non-financial
impact of the Onshore US assets is included in the supplementary oil and gas information presented below. The financial and
non-financial
impact of these assets has been footnoted beneath each applicable table. Refer to note 28 ‘Discontinued operations’ in Section 5.1 for further information.
Reserves and production
Proved oil and gas reserves and net crude oil and condensate, natural gas, LNG and NGL production information is included in section 6.3.2 ‘Production – Petroleum’ and section 6.4.1 ‘Petroleum reserves’.
Capitalised costs relating to oil and gas production activities
The following table shows the aggregate capitalised costs relating to oil and gas exploration and production activities and related accumulated depreciation, depletion, amortisation and valuation provisions.
 
   
Australia
  
United States
  (1)
  
Other
 (2)
  
Total
 
   
US$M
  
US$M
  
US$M
  
US$M
 
Capitalised cost
     
2020
     
Unproved properties
  
 
10
 
 
 
808
 
 
 
576
 
 
 
1,394
 
Proved properties
  
 
17,079
 
 
 
12,538
 
 
 
1,743
 
 
 
31,360
 
  
 
 
  
 
 
  
 
 
  
 
 
 
Total costs
  
 
17,089
 
 
 
13,346
 
 
 
2,319
 
 
 
32,75
4
 
Less: Accumulated depreciation, depletion, amortisation and valuation provisions
  
 
(11,423
)
 
 
 
(8,726
)
 
 
 
(1,370
)
 
 
 
(21,519
)
 
  
 
 
  
 
 
  
 
 
  
 
 
 
Net capitalised costs
  
 
5,666
 
 
 
4,620
 
 
 
949
 
 
 
11,235
 
  
 
 
  
 
 
  
 
 
  
 
 
 
2019
     
Unproved properties
   10   875   458   1,343 
Proved properties
   16,514   11,751   1,625   29,890 
  
 
 
  
 
 
  
 
 
  
 
 
 
Total costs
   16,524   12,626   2,083   31,233 
Less: Accumulated depreciation, depletion, amortisation and valuation provisions
   (10,867)   (8,339)   (1,302)   (20,508) 
  
 
 
  
 
 
  
 
 
  
 
 
 
Net capitalised costs
   5,657   4,287   781   10,725 
  
 
 
  
 
 
  
 
 
  
 
 
 
2018
     
Unproved properties
   10   4,528   202   4,740 
Proved properties
   16,258   43,885   2,424   62,567 
  
 
 
  
 
 
  
 
 
  
 
 
 
Total costs
   16,268   48,413   2,626   67,307 
Less: Accumulated depreciation, depletion, amortisation and valuation provisions
   (9,984)   (33,437)   (2,065)   (45,486) 
  
 
 
  
 
 
  
 
 
  
 
 
 
Net capitalised costs
   6,284   14,976   561   21,821 
  
 
 
  
 
 
  
 
 
  
 
 
 
 
(1)
 
Net capitalised costs includes Onshore US assets of US$ nil (2019: US$ nil; 2018: US$10,672 million).
 
(2)
 
Other is primarily comprised of Algeria, Mexico, Trinidad and Tobago and the United Kingdom (divested 30 November 2018).
 
Costs incurred relating to oil and gas property acquisition, exploration and development activities
The following table shows costs incurred relating to oil and gas property acquisition, exploration and development activities (whether charged to expense or capitalised). Amounts shown include interest capitalised.
 
   
Australia
   
United States
 
(3)
   
Other
 (4)
   
Total
 
   
US$M
   
US$M
   
US$M
   
US$M
 
2020
        
Acquisitions of proved property
  
 
–
 
  
 
–
 
  
 
–
 
  
 
–
 
Acquisitions of unproved property
  
 
–
 
  
 
38
 
  
 
6
 
  
 
44
 
Exploration
 (1)
  
 
38
 
  
 
278
 
  
 
370
 
  
 
686
 
Development
  
 
232
 
  
 
676
 
  
 
100
 
  
 
1,008
 
  
 
 
   
 
 
   
 
 
   
 
 
 
Total costs
 (2)
  
 
270
 
  
 
992
 
  
 
476
 
  
 
1,738
 
  
 
 
   
 
 
   
 
 
   
 
 
 
2019
        
Acquisitions of proved property
   –    –    –    – 
Acquisitions of unproved property
   –    5    –    5 
Exploration
 (1)
   44    190    492    726 
Development
   132    792    54    978 
  
 
 
   
 
 
   
 
 
   
 
 
 
Total costs
 (2)
   176    987    546    1,709 
  
 
 
   
 
 
   
 
 
   
 
 
 
2018
        
Acquisitions of proved property
   –    –    –    – 
Acquisitions of unproved property
   –    9    –    9 
Exploration
 (1)
   25    418    291    734 
Development
   195    1,548    34    1,777 
  
 
 
   
 
 
   
 
 
   
 
 
 
Total costs
 (2)
   220    1,975    325    2,520 
  
 
 
   
 
 
   
 
 
   
 
 
 
 
(1)
 
Represents gross exploration expenditure, including capitalised exploration expenditure, geological and geophysical expenditure and development evaluation costs charged to income as incurred.
 
(2)
 
Total costs include US$1,178 million (2019: US$1,275 million; 2018: US$1,970 million) capitalised during the year.
 
(3)
 
Total costs include Onshore US assets of US$
 
nil
 (2019: US$331 million; 2018: US$1,081 million).
 
(4)
 
Other is primarily comprised of Algeria, Canada, Mexico and Trinidad and Tobago.
 
Results of operations from oil and gas producing activities
The following information is similar to the disclosures in note 1 ‘Segment reporting’ in section 5.1, but differs in several respects as to the level of detail and geographic information. Amounts shown in the following table exclude financial income, financial expenses, and general corporate overheads. Further, the amounts shown below include Onshore US however the disclosures in note 1 ‘Segment reporting’ in Section 5.1 do not.
Income taxes were determined by applying the applicable statutory rates to
pre-tax
income with adjustments for permanent differences and tax credits.
 
   
Australia
  
United States
 (7)
  
Other
 (8)
  
Total
 
   
US$M
  
US$M
  
US$M
  
US$M
 
2020
     
Oil and gas revenue
 (1)
  
 
2,535
 
 
 
1,101
 
 
 
350
 
 
 
3,986
 
Production costs
  
 
(575
)
 
 
 
(161
)
 
 
 
(80
)
 
 
 
(816
)
 
Exploration expenses
  
 
(37
)
 
 
 
(271
)
 
 
 
(252
)
 
 
 
(560
)
 
Depreciation, depletion, amortisation and valuation provision
 (2)
  
 
(906
)
 
 
 
(476
)
 
 
 
(75
)
 
 
 
(1,457
)
 
Production taxes
 (3)
  
 
(177
)
 
 
 
(1
)
 
 
 
(13
)
 
 
 
(191
)
 
  
 
 
  
 
 
  
 
 
  
 
 
 
  
 
840
 
 
 
192
 
 
 
(70
)
 
 
 
962
 
Accretion expense
 (4)
  
 
(78
)
 
 
 
(24
)
 
 
 
(10
)
 
 
 
(112
)
 
Income taxes
  
 
(275
)
 
 
 
(35
)
 
 
 
(157
)
 
 
 
(467
)
 
Royalty-related taxes
 (5)
  
 
(85
)
 
 
 
–
 
 
 
–
 
 
 
(85
)
 
  
 
 
  
 
 
  
 
 
  
 
 
 
Results of oil and gas producing activities
 (6)
  
 
402
 
 
 
133
 
 
 
(237
)
 
 
 
298
 
  
 
 
  
 
 
  
 
 
  
 
 
 
2019
     
Oil and gas revenue
 (1)
   3,404   2,675   610   6,689 
Production costs
   (752)   (568)   (118)   (1,438) 
Exploration expenses
   (44)   (162)   (229)   (435) 
Depreciation, depletion, amortisation and valuation provision
 (2)
   (917)   (621)   (103)   (1,641) 
Production taxes
 (3)
   (198)   –   (25)   (223) 
  
 
 
  
 
 
  
 
 
  
 
 
 
   1,493   1,324   135   2,952 
Accretion expense
 (4)
   (80)   (34)   (13)   (127) 
Income taxes
   (530)   (193)   (267)   (990) 
Royalty-related taxes
 (5)
   (164)   –   –   (164) 
  
 
 
  
 
 
  
 
 
  
 
 
 
Results of oil and gas producing activities
 (6)
   719   1,097   (145)   1,671 
  
 
 
  
 
 
  
 
 
  
 
 
 
2018
     
Oil and gas revenue
 (1)
   3,229   3,747   421   7,397 
Production costs
   (701)   (1,312)   (121)   (2,134) 
Exploration expenses
   (25)   (270)   (254)   (549) 
Depreciation, depletion, amortisation and valuation provision
 (2)
   (1,045)   (2,842)   (81)   (3,968) 
Production taxes
 (3)
   (171)   –   (1)   (172) 
  
 
 
  
 
 
  
 
 
  
 
 
 
   1,287   (677)   (36)   574 
Accretion expense
 (4)
   (81)   (46)   (14)   (141) 
Income taxes
   (418)   (723)   (124)   (1,265) 
Royalty-related taxes
 (5)
   (103)   –   –   (103) 
  
 
 
  
 
 
  
 
 
  
 
 
 
Results of oil and gas producing activities
 (6)
   685   (1,446)   (174)   (935) 
 
(1)
 
Includes sales to affiliated companies of US$
62
million (2019: US$75 million; 2018: US$75 million).
 
(2)
 
Includes valuation provision of US$12 million (2019: US$21 million; 2018: US$596 million).
 
(3)
 
Includes royalties and excise duty.
 
(4)
 
Represents the unwinding of the discount on the closure and rehabilitation provision.
 
(5)
 
Includes petroleum resource rent tax and petroleum revenue tax where applicable.
 
(6)
 
Amounts shown exclude financial income, financial expenses and general corporate overheads and, accordingly, do not represent all of the operations attributable to the Petroleum segment presented in note 1 ‘Segment reporting’ in section 5.1.
 
(7)
 
Results of oil and gas producing activities includes Onshore US assets of US$
 
nil
(2019: US$431 million; 2018: US$(465) million).
 
(8)
 
Other is primarily comprised of Algeria, Canada, Mexico, Trinidad and Tobago
a
nd the United Kingdom (divested 30 November 2018).
 
Standardised measure of discounted future net cash flows relating to proved oil and gas reserves (Standardised measure)
The following tables set out the standardised measure of discounted future net cash flows, and changes therein, related to the Group’s estimated proved reserves as presented in section 6.
4
.1 ‘Petroleum reserves’, and should be read in conjunction with that disclosure.
The analysis is prepared in compliance with FASB Oil and Gas Disclosure requirements, applying certain prescribed assumptions under Topic 932 including the use of
 
unweighted average
first-day-of-the-month
market prices for the previous
12-months,
year-end
cost factors, currently enacted tax rates and an annual discount factor of 10 per cent to year end quantities of net proved reserves.
Certain key assumptions prescribed under Topic 932 are arbitrary in nature and may not prove to be accurate. The reserve estimates on which the Standard measure is based are subject to revision as further technical information becomes available or economic conditions change.
Discounted future net cash flows like those shown below are not intended to represent estimates of fair value. An estimate of fair value would also take into account, among other things, the expected recovery of reserves in excess of proved reserves, anticipated future changes in commodity prices, exchange rates, development and production costs as well as alternative discount factors representing the time value of money and adjustments for risk inherent in producing oil and gas.
 
   
Australia
  
United States
 (1)
  
Other
 (2)
  
Total
 
   
US$M
  
US$M
  
US$M
  
US$M
 
Standardised measure
     
2020
     
Future cash inflows
  
 
11,526
 
 
 
12,997
 
 
 
1,660
 
 
 
26,183
 
Future production costs
  
 
(4,027
)
 
 
 
(4,943
)
 
 
 
(494
)
 
 
 
(9,464
)
 
Future development costs
  
 
(4,124
)
 
 
 
(3,242
)
 
 
 
(433
)
 
 
 
(7,799
)
 
Future income taxes 
(3)
  
 
(187
)
 
 
 
(880
)
 
 
 
(473
)
 
 
 
(1,540
)
 
  
 
 
  
 
 
  
 
 
  
 
 
 
Future net cash flows
  
 
3,188
 
 
 
3,932
 
 
 
260
 
 
 
7,380
 
Discount at 10 per cent per annum
  
 
(642
)
 
 
 
(1,586
)
 
 
 
(94
)
 
 
 
(2,322
)
 
  
 
 
  
 
 
  
 
 
  
 
 
 
Standardised measure
  
 
2,546
 
 
 
2,346
 
 
 
166
 
 
 
5,058
 
  
 
 
  
 
 
  
 
 
  
 
 
 
2019
     
Future cash inflows
   18,292   18,076   1,807   38,175 
Future production costs
   (4,710)   (4,917)   (459)   (10,086) 
Future development costs
   (3,860)   (4,516)   (226)   (8,602) 
Future income taxes 
(3)
   (2,551)   (1,657)   (711)   (4,919) 
  
 
 
  
 
 
  
 
 
  
 
 
 
Future net cash flows
   7,171   6,986   411   14,568 
Discount at 10 per cent per annum
   (1,926)   (3,396)   (94)   (5,416) 
  
 
 
  
 
 
  
 
 
  
 
 
 
Standardised measure
   5,245   3,590   317   9,152 
  
 
 
  
 
 
  
 
 
  
 
 
 
2018
     
Future cash inflows
   17,398   28,012   2,124   47,534 
Future production costs
   (5,345)   (11,182)   (501)   (17,028) 
Future development costs
   (3,842)   (6,554)   (189)   (10,585) 
Future income taxes 
(3)
   (1,919)   (1,236)   (901)   (4,056) 
  
 
 
  
 
 
  
 
 
  
 
 
 
Future net cash flows
   6,292   9,040   533   15,865 
Discount at 10 per cent per annum
   (1,713)   (3,783)   (129)   (5,625) 
  
 
 
  
 
 
  
 
 
  
 
 
 
Standardised measure
   4,579   5,257   404   10,240 
  
 
 
  
 
 
  
 
 
  
 
 
 
 
(1)
 
Standardised measure includes Onshore US assets of US$ nil (2019: US$ nil; 2018: US$1,932 million).
 
(2)
 
Other is primarily comprised of Algeria and Trinidad and Tobago.
 
(3)
 
Future income taxes include credits to be received as a result of Petroleum operations and the utilisation of future tax losses by the Group.
 
Changes in the Standardised measure are presented in the following table.
 
   
2020
   2019  2018 
   
US$M
   US$M  US$M 
Changes in the Standardised measure
     
Standardised measure at the beginning of the year
  
 
9,152
 
   10,240   8,242 
Revisions:
     
Prices, net of production costs
  
 
(5,633
)
 
   3,821   5,540 
Changes in future development costs
  
 
330
 
   (228)   (358) 
Revisions of reserves quantity estimates
 (1)
  
 
(229
)
 
   1,268   (166) 
Accretion of discount
  
 
1,313
 
   1,178   1,016 
Changes in production timing and other
  
 
(310
)
 
   (618)   946 
  
 
 
   
 
 
  
 
 
 
  
 
4,623
 
   15,661   15,220 
Sales of oil and gas, net of production costs
  
 
(2,980
)
 
   (5,029)   (5,091) 
Acquisitions of
reserves-in-place
  
 
–
 
   –   – 
Sales of
reserves-in-place
 
(2)
  
 
–
 
   (1,489)   (26) 
Previously estimated development costs incurred
  
 
1,005
 
   545   1,068 
Extensions, discoveries, and improved recoveries, net of future costs
  
 
145
 
   (33)   502 
Changes in future income taxes
  
 
2,265
 
   (503)   (1,433) 
  
 
 
   
 
 
  
 
 
 
Standardised measure at the end of the year
 
(3)
  
 
5,058
 
   9,152   10,240 
  
 
 
   
 
 
  
 
 
 
 
(1)
 
Changes in reserves quantities are shown in the Petroleum reserves tables in section 6.
4
.1.
 
(2)
 
Onshore US assets disposal
 in 2019
.
 
(3)
 
Standardised measure at the end of the year includes Onshore US assets of US$ nil (2019: US$ nil; 2018: US$1,932 million).
Accounting for suspended exploratory well costs
Refer to note 11 ‘Property, plant and equipment’ in section 5.1 for a discussion of the accounting policy applied to the cost of exploratory wells. Suspended wells are also reviewed in this context.
The following table provides the changes to capitalised exploratory well costs that were pending the determination of proved reserves for the three years ended 30 June 2020, 30 June 2019 and 30 June 2018.
 
   
2020
   2019  2018 
   
US$M
   US$M  US$M 
Movement in capitalised exploratory well costs
     
At the beginning of the year
  
 
1,040
 
   794   668 
Additions to capitalised exploratory well costs pending the determination of proved reserves
  
 
120
 
   297   186 
Capitalised exploratory well costs charged to expense
  
 
–
 
   (9)   (62) 
Capitalised exploratory well costs reclassified to wells, equipment, and facilities based on the determination of proved reserves
  
 
(6
)
 
   (42)   2 
Sale of suspended wells
  
 
(65
)
 
   –   – 
  
 
 
   
 
 
  
 
 
 
At the end of the year
  
 
1,089
 
   1,040   794 
  
 
 
   
 
 
  
 
 
 
 
The following table provides an ageing of capitalised exploratory well costs, based on the date the drilling was completed, and the number of projects for which exploratory well costs has been capitalised for a period greater than one year since the completion of drilling.
Exploration activity typically involves drilling multiple wells, over a number of years, to fully evaluate and appraise a project. The term “project” as used in this disclosure refers primarily to individual wells and associated exploratory activities.
 
   
2020
   2019   2018 
   
US$M
   US$M   US$M 
Ageing of capitalised exploratory well costs
      
Exploratory well costs capitalised for a period of one year or less
  
 
120
 
   210    124 
Exploratory well costs capitalised for a period greater than one year
  
 
969
 
   830    670 
  
 
 
   
 
 
   
 
 
 
At the end of the year
  
 
1,089
 
   1,040    794 
  
 
 
   
 
 
   
 
 
 
   
2020
   2019   2018 
Number of projects that have been capitalised for a period greater than one year
  
 
14
 
   13    17 
  
 
 
   
 
 
   
 
 
 
Drilling and other exploratory and development activities
The number of crude oil and natural gas wells drilled and completed for each of the last three years was as follows:
 
   
Net exploratory wells
   
Net development wells
     
 
  
Productive
   
Dry
   
Total
   
Productive
   
Dry
   
Total
   
Total
 
Year ended 30 June 2020
              
Australia
  
 
–
 
  
 
–
 
  
 
–
 
  
 
–
 
  
 
–
 
  
 
–
 
  
 
–
 
United States
 (1)
  
 
–
 
  
 
–
 
  
 
–
 
  
 
–
 
  
 
1
 
  
 
1
 
  
 
1
 
Other
 (2)
  
 
1
 
  
 
1
 
  
 
2
 
  
 
1
 
  
 
–
 
  
 
1
 
  
 
3
 
  
 
 
   
 
 
   
 
 
   
 
 
   
 
 
   
 
 
   
 
 
 
Total
  
 
1
 
  
 
1
 
  
 
2
 
  
 
1
 
  
 
1
 
  
 
2
 
  
 
4
 
  
 
 
   
 
 
   
 
 
   
 
 
   
 
 
   
 
 
   
 
 
 
Year ended 30 June 2019
              
Australia
   –    –    –    1    –    1    1 
United States
 (1)
   1    –    1    33    –    33    34 
Other
 (2)
   4    2    6    –    –    –    6 
  
 
 
   
 
 
   
 
 
   
 
 
   
 
 
   
 
 
   
 
 
 
Total
   5    2    7    34    –    34    41 
  
 
 
   
 
 
   
 
 
   
 
 
   
 
 
   
 
 
   
 
 
 
Year ended 30 June 2018
              
Australia
   –    –    –    1    –    1    1 
United States
 (1)
   1    1    2    84    1    85    87 
Other
 (2)
   –    –    –    –    –    –    – 
  
 
 
   
 
 
   
 
 
   
 
 
   
 
 
   
 
 
   
 
 
 
Total
   1    1    2    85    1    86    88 
  
 
 
   
 
 
   
 
 
   
 
 
   
 
 
   
 
 
   
 
 
 
 
(1)
 
Includes Onshore US assets net productive development wells of
nil
 (2019: 33; 2018: 84) and net dry development wells of nil (2019: nil; 2018: 1). Onshore US assets had nil net exploratory wells in 2020, 2019 and 2018.
 
(2)
 
Other is primarily comprised of Algeria, Mexico and Trinidad and Tobago.
The number of wells drilled refers to the number of wells completed at any time during the respective year, regardless of when drilling was initiated. Completion refers to the installation of permanent equipment for production of oil or gas, or, in the case of a dry well, to reporting to the appropriate authority that the well has been abandoned.
An exploratory well is a well drilled to find oil or gas in a new field or to find a new reservoir in a field previously found to be productive of oil or gas in another reservoir. A development well is a well drilled within the limits of a known oil or gas reservoir to the depth of a stratigraphic horizon known to be productive.
A productive well is an exploratory, development or extension well that is not a dry well. Productive wells include wells in which hydrocarbons were encountered and the drilling or completion of which, in the case of exploratory wells, has been suspended pending further drilling or evaluation. A dry well (hole) is an exploratory, development, or extension well that proves to be incapable of producing either oil or gas in sufficient quantities to justify completion as an oil or gas well.
 
Oil and gas properties, wells, operations, and acreage
The following tables show the number of gross and net productive crude oil and natural gas wells and total gross and net developed and undeveloped oil and natural gas acreage as at 30 June 2020. A gross well or acre is one in which a working interest is owned, while a net well or acre exists when the sum of fractional working interests owned in gross wells or acres equals one. Productive wells are producing wells and wells mechanically capable of production. Developed acreage is comprised of leased acres that are within an area by or assignable to a productive well. Undeveloped acreage is comprised of leased acres on which wells have not been drilled or completed to a point that would permit the production of economic quantities of oil and gas, regardless of whether such acres contain proved reserves.
The number of productive crude oil and natural gas wells in which the Group held an interest at 30 June 2020 was as follows:
 
   
Crude oil wells
   
Natural gas wells
   
Total
 
   
Gross
   
Net
   
Gross
   
Net
   
Gross
   
Net
 
Australia
   353    176    162    54    515    230 
United States
   61    24    –    –    61    24 
Other
 (1)
   59    22    8    4    67    26 
  
 
 
   
 
 
   
 
 
   
 
 
   
 
 
   
 
 
 
Total
  
 
473
 
  
 
222
 
  
 
170
 
  
 
58
 
  
 
643
 
  
 
280
 
  
 
 
   
 
 
   
 
 
   
 
 
   
 
 
   
 
 
 
 
(1)
 
Other is primarily comprised of Algeria and Trinidad and Tobago.
Of the productive crude oil and natural gas wells,
133
(net:
62
) operated wells had multiple completions.
Developed and undeveloped acreage (including both leases and concessions) held at 30 June 2020 was as follows:
 
   
Developed acreage
   
Undeveloped acreage
 
Thousands of acres
  
Gross
   
Net
   
Gross
   
Net
 
Australia
   2,152    823    766    279 
United States
   98    36    844    800 
Other
 (1)(2)
   146    57    3,926    3,445 
  
 
 
   
 
 
   
 
 
   
 
 
 
Total
  
 
2,396
 
  
 
916
 
  
 
5,536
 
  
 
4,524
 
  
 
 
   
 
 
   
 
 
   
 
 
 
 
(1)
 
Developed acreage in Other primarily consists of Algeria and Trinidad and Tobago.
 
(2)
 
Undeveloped acreage in Other primarily consists of
Barb
a
dos
,
Canada, Mexico and Trinidad and Tobago.
Approximately 833 thousand gross acres (411 thousand net acres), 1,089 thousand gross acres (655 thousand net acres) and 264 thousand gross acres (256 thousand net acres) of undeveloped acreage will expire in the years ending 30 June 2021, 2022 and 2023 respectively, if the Group does not establish production or take any other action to extend the terms of the licences and concessions.