Final Results - Part 2
Enterprise Oil PLC
8 March 2001
PART 2
Consolidated Profit and Loss Account
for the year ended 31 December 2000
2000 1999
Notes £m £m
Turnover 1,841.2 850.0
Cost of sales 2 (641.1) (427.5)
Gross profit 1,200.1 422.5
Exploration costs (68.0) (64.0)
Administrative and selling expenses (36.0) (35.9)
Group operating profit 1,096.1 322.6
Share of operating profit of associate 0.2 -
Total operating profit 1,096.3 322.6
Income from fixed asset investments 0.7 0.7
Gain on sales of oil and gas assets 3 0.7 1.5
Interest receivable and similar income 42.1 18.3
Interest payable and similar charges (80.5) (53.9)
Profit on ordinary activities before taxation 1,059.3 289.2
Tax on profit on ordinary activities 4 (570.5) (112.0)
Profit on ordinary activities after taxation 488.8 177.2
Dividends- preference shares (non-equity) (6.0) (6.9)
Dividends - ordinary shares (38.9) (35.8)
Preference share redemption costs (1.8) -
Retained profit for the financial year 442.1 134.5
Basic earnings per ordinary share 5 98.7p 34.8p
Diluted earnings per ordinary share 5 97.6p 34.6p
Adjusted earnings per ordinary share 5 106.9p 34.8p
Dividends per ordinary share 8.0p 7.3p
The results for 2000 include an exceptional charge in cost of sales,
relating to a ceiling test write-down of £40.2 million (note 2).
Consolidated Balance Sheet
as at 31 December 2000
2000 1999
Notes £m £m
Fixed assets
Intangible assets 6 206.5 209.8
Tangible assets 6 2,232.8 2,106.8
Investments:
Investment in associate 34.7 -
Other investments 51.3 52.6
Total investments 86.0 52.6
2,525.3 2,369.2
Current assets
Stocks 15.9 15.1
Debtors 252.9 208.2
Investments (liquid resources) 690.6 307.7
Cash at bank and in hand 142.7 68.5
1,102.1 599.5
Creditors: amounts falling due within one (720.1) (437.2)
year
Net current assets 382.0 162.3
Total assets less current liabilities 2,907.3 2,531.5
Creditors: amounts falling due after more (1,106.0) (1,104.7)
than one year
Provisions for liabilities and charges (348.5) (349.0)
Net assets 1,452.8 1,077.8
Capital and reserves
Called up share capital 124.7 198.9
Share premium account 103.0 100.5
Capital redemption reserve 191.7 103.8
Other reserves 179.7 179.7
Profit and loss account 853.7 494.9
Shareholders' funds 1,452.8 1,077.8
Analysis of shareholders' funds
Equity 1,452.8 1,003.5
Non-equity - 74.3
1,452.8 1,077.8
Consolidated Cash Flow Statement
for the year ended 31 December 2000
2000 1999
Notes £m £m
Cash flow from operating activities 7 (i) 1,445.3 514.4
Returns on investments and servicing of 7 (ii) (76.5) (84.0)
finance
Taxation 7 (ii) (318.0) (38.1)
Operating cash flow after tax and finance 1,050.8 392.3
costs
Capital expenditure and financial investment:
- capital expenditure (including 7 (ii) (409.9) (437.5)
asset acquisitions)
- financial investment (17.1) (14.0)
Acquisitions 7 (ii) (17.7) -
Equity dividends paid (37.1) (13.7)
Cash inflow (outflow) before management of 569.0 (72.9)
liquid resources and financing
Management of liquid resources 7 (ii) (383.9) 51.1
Financing - issue of shares 7 (ii) 2.6 2.0
- (decrease) increase in debt 7 (ii) (29.1) 63.4
- redemption of preference shares 7 (ii) (89.7) -
Increase in cash in the year 68.9 43.6
Reconciliation of net cash flow to movement 2000 1999
in net debt
Notes £m £m
Increase in cash in the year 7 (iii) 68.9 43.6
Cash outflow (inflow) from movement in debt 7 (iii) 29.1 (63.4)
and lease financing
Cash outflow (inflow) from movement in liquid 383.9 (51.1)
resources
Change in net debt resulting from cash flows 481.9 (70.9)
Translation differences (51.2) (19.2)
Other movements (1.2) (0.4)
Movement in net debt in the year 429.5 (90.5)
Net debt at 1 January 7 (iii) (860.7) (770.2)
Net debt at 31 December 7 (iii) (431.2) (860.7)
Consolidated Statement of Total Recognised Gains and Losses
for the year ended 31 December 2000
Notes 2000 1999
Profit on ordinary activities after taxation £m £m
Unrealised currency translation differences 488.8 177.2
Total recognised gains and losses relating to 4.6 1.5
the year
Prior year adjustment 493.4 178.7
Total recognised gains and losses since the - 58.8
last financial statements
493.4 237.5
The currency translation differences shown above are the net result of
retranslation to sterling of significant overseas investments and certain
foreign currency borrowings and preference shares which provide a partial
hedge against the impact of currency movements on those investments.
In 1999 a prior year adjustment arose from the implementation during the
year of the revised accounting policy for decommissioning costs (note 1).
1. Accounting policies
The financial statements have been prepared under the historic cost
convention and in accordance with applicable United Kingdom accounting
standards. During the year the group adopted FRS 15 Tangible Fixed Assets
and FRS 16 Current Tax. There was no effect on the group's net assets and
results for the period arising from the adoption of either of these
financial reporting standards. FRS 12 Provisions, Contingent Liabilities and
Contingent Assets, which affects the way the group accounts for
decommissioning costs, was adopted by the group in 1999 and the accounting
policy on decommissioning was changed accordingly. The adoption of the
policy, which was made by way of an adjustment to previously published
results as though the revised policy had always been applied by the group,
resulted in an increase in shareholders' funds, in 1999 of £58.8 million.
2000 1999
2. Cost of Sales £m £m
Depreciation of development costs 362.7 203.8
Operating costs 253.5 199.5
Research and development 1.5 1.8
Royalties 23.4 22.4
641.1 427.5
(i) An exceptional charge for depreciation of £40.2 million arose from a
reduction in the estimated reserves of the Garden Banks 161 field in the US
Gulf of Mexico. There was no related taxation.
(ii) Included in operating costs in 1999 is an amount of £9.0 million
relating to restructuring costs charged to the group by operators of joint
ventures. Also included in 1999 as a reduction in the depreciation charge is
an amount of £7.1 million reflecting the partial reversal of past ceiling
tests provisions.
3. Gains on Sale of Oil and Gas Assets
The gain on disposal of fixed assets in 1999 primarily reflects the gain of
£2.2 million on the sale of the group's entire interest in the Johnston
field in the Southern Gas Basin, together with certain appraisal acreage, to
Eastern Natural Gas Offshore.
2000 1999
4. Tax on Profit on Ordinary Activities £m £m
UK petroleum revenue tax charge (credit):
Current 115.0 57.1
Deferred (3.8) (5.7)
Norwegian petroleum tax:
Current 0.4 -
Deferred 40.0 -
UK corporation tax charge (credit):
current at 30% (1999: 30%) 162.4 42.8
deferred (9.4) 17.9
Overseas corporate tax charge (credit),
principally Norwegian taxes:
Current 313.4 0.1
Deferred (47.6) (0.2)
Share of associate's tax 0.1 -
570.5 112.0
The credit of £47.6 million in deferred overseas corporate tax in 2000
arises form revised expectations of future capital expenditure profiles.
The UK corporation tax charge before and after double taxation relief,
principally relating to Norwegian corporate taxes, is £339.2 million (1999:
£42.8 million) and £162.4 million (1999: £42.8 million) respectively.
5. Earnings per share
The calculation of basic earnings per share is based upon the profit
attributable to ordinary shareholders for 2000 of £481.0 million (1999: £
170.3 million) and the adjusted weighted average of 487.5 million ordinary
shares outstanding during the year (1999: 489.8 million ordinary shares).
Profit attributable to ordinary shareholders is arrived at by deducting
preference share dividends together with the premium attributable to the
redemption of the preference shares from profit on ordinary activities after
taxation. The weighted average number of ordinary shares outstanding
excludes 11.1 million shares (1999: 8.1 million) held by employee share
schemes on which the dividend has been waived by the trustees of the
employee share ownership plan.
Diluted earnings per share differs from basic earnings per share in that the
weighted average number of ordinary shares includes potential shares, being
any financial instrument or right that may entitle its holder to ordinary
shares, such as share options. The weighted average number of ordinary
shares used to calculate diluted earnings per share is 493.0 million in 2000
(1999: 491.9 million). The total number of dilutive potential shares is 5.5
million (1999: 2.1 million), comprising 1.9 million (1999: 0.2 million) in
respect of the Senior Executive Share Option Schemes, 3.1 million (1999: 1.5
million), in respect of the Long Term Performance Related Share Schemes and
0.5 million (1999: 0.4 million) in respect of the Savings Related Share
Option Schemes.
Adjusted earnings per share differs from basic earnings per share in that
the profit attributable to ordinary shareholders for 2000 excludes an
exceptional item (see note 2). This measure, when compared with 1999, more
accurately reflects the ongoing group performance for 2000.
At At
31 31
December December
6. Fixed Assets 2000 1999
Capital expenditure comprises £m £m
Exploration and appraisal expenditure 102.9 100.0
Development expenditure:
Development 2447.4 320.0
Capitalised interest 35.4 49.5
Decommissioning 1.4 13.1
Acquisitions 85.3 7.0
472.4 389.6
Other fixed assets 7.0 2.1
479.4 491.7
i) Ceiling tests were conducted as at 31 December 2000. Tests were performed
on a field-by-field basis other than in the case of shared facilities where
groups of fields were considered.
The following assumptions were used in
performing the ceiling tests:
At At
31 31
December December
2000 1999
Oil price
2001 $20 $15
2002-2004 $18 $15
2005 Onwards $18 flat $15 flat
Foreign exchange rate 2001 $1.55:£1. $1.6: £1
Thereafter, $1.6:£1
Cost inflation per annum - -
Discount rate 10% 10%
In 2000 there was a deficiency totalling £40.2 million in the Garden Banks
161 field the US Gulf of Mexico and, accordingly, accelerated depreciation
was provided within cost of sales (see note 2(i)).
In 1999 an amount of £7.1 million was included in cost of sales, as a
reduction of the depreciation charge, reflecting the partial reversal of
past ceiling test provisions (see not 2(ii)).
7. Cash Flow Statement 2000 1999
(i) Reconciliation of operating profit to £m £m
operating cash flow
Operating profit 1,096.1 322.6
Depreciation charges 367.6 211.4
Exploration costs 68.0 64.0
Movements in stocks (0.8) 4.3
Movements in operating debtors (59.8) (84.0)
Movements in operating current liabilities (23.0) (8.8)
Other deferrals and accruals of operating 2.8 4.9
cash flows
Net cash inflow from operating activities 1,445.3 514.4
2000 1999
(ii) Analysis of cash flow captions £m £m
Returns on investments and servicing of
finance:
Interest received and similar income 38.1 17.5
Interest paid (108.3) (94.5)
Interest element of finance lease rentals (0.3) (0.1)
paid
Preference dividends paid (6.0) (6.9)
Net cash outflow for returns on investments (76.5) (84.0)
and servicing of finance
Taxation:
UK petroleum revenue tax (112.9) (31.6)
UK corporate taxes (64.8) (6.5)
Overseas tax (140.3) -
Net cash outflow for tax paid (318.0) (38.1)
2000 1999
Capital expenditure and financial investment: £m £m
Capital expenditure:
Development (237.7) (310.1)
Exploration and appraisal (82.2) (113.3)
Sale of licence interests 13.2 2.9
Purchase of licence interests (96.2) (14.9)
Purchase of other fixed assets (7.0) (2.1)
Net cash outflow for capital expenditure (409.9) (437.5)
Acquisition
Investment in associates (17.7) -
Net cash outflow from corporate acquisitions (17.7) -
2000 1999
Management of liquid resources: £m £m
Purchase of investments (2,406.8) (1,102.7)
Sales of investments 2,022.9 1,153.8
Net cash (outflow) inflow from management of (383.9) 51.1
liquid resources
Financing:
Issue of ordinary share capital 2.6 2.0
Debt repaid (13.3) (138.2)
Revolving credit facility repaid (45.0) (5.0)
Revolving credit facility drawdown 30.5 35.0
New debt issues - 188.2
Debt issue costs (1.0) (1.8)
Capital element of finance lease rental (0.3) (14.8)
payments
Redemption of preference shares (89.7) -
Net cash (outflow) inflow from financing (116.2) 65.3
At Other At
1 Exchange non-cash 31
January December
2000 Cash movement Changes 2000
flow
(iii) Analysis of net £m £m £m £m £m
debt
Cash at bank and in hand 68.5 68.1 6.1 - 142.7
Overdrafts (1.7) 0.8 - - (0.9)
66.8 68.9 6.1 - 141.8
Current asset investments 307.7 383.9 (1.0) - 690.6
(liquid resources)
Debt due within one year (132.7) 49.9 1.4 (76.3) (157.7)
Debt due after one year (1,097.6) (21.1) (57.7) 75.1 (1,101.3)
Finance leases (4.9) 0.3 - - (4.6)
(860.7) 481.9 (51.2) (1.2) (431.2)
8. Status of financial
Information
The information contained herein does not constitute the company's statutory
accounts for the years ended 31 December 2000 or 1999. Statutory accounts
for 1999 have been delivered to the Registrar of Companies and those for
2000 will be delivered following the company's annual general meeting. The
auditor has reported on both the 2000 and 1999 accounts; its reports were
unqualified and did not contain statements under section 237 (2) or (3) of
the Companies Act 1985.
Proven and Probable Oil and Gas Reserves
Crude oil Gas Total
(mmbbls) (mmboe) (mmboe)
Net proven and probable oil and gas
reserves at 1 January 2000 1,022.1 245.1 1,267.2
Changes during year:
Revisions of previous estimates (5.5) (0.0) (5.5)
Purchase, exchange of reserves 92.5 17.5 110.0
Discoveries, extensions and other additions 27.6 117.1 144.7
Disposals, exchange of reserves - (1.3) (1.3)
Production (90.8) (11.9) (102.7)
Net proven and probable reserves at 31 December 2000 1,045.7 366.5 1,412.2
Of which:
Fields in production 598.2 135.0 733.1
Fields under development 213.9 56.1 270.0
Fields awaiting development 233.7 175.4 409.1
1,045.7 366.5 1,412.2
Notes: Crude oil includes natural gas liquids and condensate; 'mmbbls' means
million barrels; 'mmboe' means million barrels of oil equivalent. Gas reserves
are converted to barrels of oil equivalent at the rate of 5,800 cubic feet of
gas per barrel.
Totals may differ from the sum of the components due to rounding effects.
Group share of associate reserves
Undiluted Fully dilute
equity equity
(mmbbls) (mmbbls)
Proven and probable reserves at 31 December 2000 248.7 170.1
Proved oil reserves at 31 December 2000 114.2 78.1
Note: Proved oil reserves for the associate are from the independent
consultant, Ryder Scott volumetric reserve report as of 30 June 2000, adjusted
for movements for the second half of 2000.
Additional Information Under US Accounting Principles
The production figures, reserves and results reported in this statement are
prepared in accordance with the group's established reporting and accounting
policies which comply with UK accounting principles. The following
supplementary information is presented under US accounting principles:
(in millions, except per ADS amounts) ------2000------ ------1999------
Approximate net income (after tax) $556.5 £372.6 $125.4 £77.8
Approximate shareholders' equity at 31 $1,559.8 £1,044.2 $1,313.1 £814.7
December
Approximate earnings/loss per ADS (2)
Basic $3.228 £2.161 $0.700 £0.434
Diluted $3.192 £2.137 $0.696 £0.432
Dividends per ADS (2) $0.359 £0.240 $0.353 £0.219
1. US dollar amounts are shown translated for convenience at the exchange rate
on 31 December 2000 of $1.4938: £1 (1999: $1.6117: £1).
2. On the basis of one ADS for every three ordinary shares.
The principal recurring differences between UK and US generally accepted
accounting principles ('GAAP') as applicable to the group relate to business
combinations and deferred taxation. Certain business combinations completed
prior to 1990 were accounted for based on historical costs under UK GAAP. US
GAAP requires these combinations to be dealt with under purchase accounting,
based on fair valuations, with consequent adjustments to depreciation charges,
interest capitalised and deferred taxation. Also, US GAAP requires full
provision in respect of deferred tax temporary differences between the tax
basis of assets and liabilities and their carrying values for accounting
purposes, whereas UK GAAP requires provision for deferred tax timing
differences only to the extent it is expected that assets or liabilities will
crystallise in the foreseeable future.
Production in accordance with US principles (i.e. excluding volumes
attributable to royalties payable in cash or in kind) averaged 277.0 thousand
barrels of oil equivalent ('boe') per day for 2000, compared with 208.4
thousand boe per day in 1999.
Oil and gas reserve quantities recorded in accordance with US GAAP comprise
proved developed and undeveloped reserves, rather than the definition of
proven and probable reserves used by the group. The group's total proved
developed and undeveloped reserves at 31 December 2000 were 915.7 million
barrels of oil equivalent compared with 900.7 million barrels of oil
equivalent at 31 December 1999.