Interim Results
Enterprise Oil PLC
6 September 2001
PART 1
2001 Interim Results
Enterprise Oil, one of the world's leading independent exploration and
production companies, today announced its results for the six months ended 30
June 2001. The main points are:
* Post tax profits of £204 million (£162 million in corresponding period
of 2000£);
* Earnings per share of 42.3 pence (first half 2000: 32.3 pence£);
* Interim dividend of 3.15 pence (first half 2000: 3.0 pence);
* Production of 255,116 barrels of oil equivalent per day (boepd)
including associated production (first half 2000: 277,056 boepd);
* Substantial progress on operated projects in Ireland and Brazil, and
non-operated ventures in the UK, Norway and US Gulf of Mexico;
* Start-up of new facilities at Val d'Agri oil centre in Italy;
* Drilling success in the UK, Norway and Brazil.
£ The results from the six months ended 30 June 2000 have been restated for
the effects of applying FRS19 'Deferred Tax'
Announcing the results, Sir Graham Hearne, Chairman, said: 'It is with much
pleasure that I can report that the first half of 2001 has seen Enterprise
continue its recent progress. Our post tax profit of £204 million demonstrates
the group's ability to deliver outstanding financial results and robust
returns, and we will not be complacent as we seek to continue our drive to
create value for our shareholders, which remains our prime objective.'
Chief Executive Pierre Jungels commented: 'We continue to focus on the
maintenance of capital discipline, and gearing has remained low. This, coupled
with continuing strong cash flows, enabled the group to initiate its stock
repurchase programme during the period. In addition, the group has seen some
success across all elements of its strategy: exploration and appraisal, new
field developments and asset trades. The rest of 2001 will be an important
time for Enterprise, as the group further progresses its operated developments
and maintains a busy exploration and appraisal programme.'
****
A copy of the Stock Exchange announcement is attached.
Copies of the Interim Statement are due to be posted to the Company's
shareholders on 10 September 2001. Copies will be available to the public at
the registered office at Grand Buildings, Trafalgar Square, London WC2N 5EJ.
For further information, please contact:
Pierre Jungels, Chief Executive +44 (0) 20 7925 4199
Andrew Shilston, Finance Director +44 (0) 20 7925 4476
Patrick d'Ancona, Head of Public Relations +44 (0) 20 7925 4160
Peter Reilly, Head of Investor Relations +44 (0) 20 7925 4476
Sucharita Sethi, Senior External Affairs Advisor +44 (0) 20 7925 4160
Enterprise Oil plc
Interim Results Announcement
Thursday, 6 September 2001
Highlights
Six months Six months
ended ended
30 June 2001 30 June 2000
(unaudited) (unaudited)
(Restated**)
£m £m
Turnover 804 835
Operating profit 465 477
Profit before tax 476 457
Profit after tax 204 162
Profit after tax excluding exceptional item* 204 205
Earnings per share 42.3p 32.3p
Dividends per share 3.15p 3.0p
Average production (barrels of oil equivalent
per
day) including associated production 255,116 277,056
Average realised oil price £18.54 ($26.79) £17.80 ($28.08)
Cost of sales per boe produced £5.94 £5.47
Operating expenditure per boe produced £2.63 £2.30
** The results for the six months ended 30 June 2000 have been restated for the
effects of applying FRS19 'Deferred Tax' (see note 1 to the accounts)
* The exceptional item related to the results for June 2000 (see note 3 to the
accounts)
Chairman's Statement
Enterprise has It is with much pleasure that I can report that the first
continued its half of 2001 has seen Enterprise continue its recent
recent progress, progress.
delivering
outstanding Our post tax profit of £204 million demonstrates the
financial results group's ability to deliver outstanding financial results
and robust returns. Crude oil prices maintained their
recent levels in the $23-26 per barrel range and we also
benefited from a favourable exchange rate.
Recent high oil prices should be seen in the context of a
cyclical business. Initially we used the cash surpluses to
increase our financial strength after the very low oil
price in 1998. Our attention is now focused on meeting our
production targets and enhancing the quality of our
portfolio, partly by making selective disposals of assets
no longer considered core in a relatively strong market, as
well as by making selective acquisitions both of assets and
acreage in our core areas as opportunities arise. The
disposal of our Danish interests is an example of the
former, and the acquisition of the Petrobras UK portfolio
an example of the latter. This policy will be pursued in
parallel with returning capital to shareholders as
circumstances permit.
In the context of our organic investment programme, I can
report that the first half of 2001 has seen substantial
progress made on our operated developments in Ireland and
Brazil. In addition, non-operated projects in the UK, US
and most notably Italy are nearing completion. Our drilling
programme to date has achieved mixed results. Successes in
the UK, Norway and Brazil have been offset by
disappointments elsewhere, though several key wells in this
year's programme are still to be completed. We have also
enjoyed strong lease sale and licensing round performances,
not least in Brazil where we continue to establish
ourselves as a leading player in the industry.
Our policy on distribution of funds to shareholders now
embraces a dividend which is sustainable even at very low
oil prices and buy-backs when circumstances allow. The
Board has declared an interim dividend of 3.15 pence,
payable on 1 November 2001 to shareholders on the register
at close of business on 14 September 2001, and the stock
repurchase programme is active.
We remain committed to maintaining capital discipline and
planning the business through the oil price cycle. I can
assure you that we will not be complacent as we seek to
continue our drive to create value for our shareholders,
which remains our prime objective.
Sir Graham Hearne
Chairman
Chief Executive's Review
Enterprise has The first half of 2001 saw Enterprise deliver a strong
delivered a financial performance, with post tax profits of £204 million,
strong compared to £162 million* in the same period of last year. With
financial a realised oil price of £18.54 per barrel (first half 2000: £
performance 17.80) reflecting strong crude prices and a favourable exchange
rate, the group achieved a return on capital of 30.1 per cent
on an annualised basis.
We continue to focus on the maintenance of capital discipline,
and gearing remained low, at 34 per cent (full year 2000: 39
per cent*). This, coupled with continuing strong cash flows,
enabled the group to initiate its stock repurchase programme
during the period.
During the first half of the year, the group has seen some
success across all elements of its strategy: exploration and
appraisal, new field developments and asset trades.
There was exploration and appraisal success in the UK, Norway
and Brazil. The Howe discovery in the UK and the Svale and
Skarv discoveries in Norway were successfully appraised during
the period, and potential development options for these fields
are currently being evaluated. In addition, the group's first
well drilled in Brazil resulted in the Curio discovery on Block
BC-2 and the group recently secured adjacent exploration
acreage in the country's third licensing round. Despite these
successes, some of our high risk wells drilled so far this year
have been disappointing. However, the remainder of the year
will see the completion of the Llano and Deep Mensa wells in
the US and Rea-1 in Italy, as well as the drilling of several
wells in Norway and one in Greece.
Significant Work continues on the group's key operated projects, with
progress on significant progress made during the first half of the year on
operated both Corrib and Bijupira-Salema. Enterprise also became
projects in operator of Llano in May, and is now co-ordinating appraisal
Ireland and and field development study activities.
Brazil
2001 has also been a significant period for the group's
non-operated projects, and in particular the Val d'Agri
development in Italy. The new oil centre is now complete and by
August was already processing over 20,000 barrels of oil
equivalent per day (boepd), with work on the pipeline
connecting the oil centre to the Taranto refinery and export
facilities expected to be finished shortly. Output will also be
enhanced as the Skene field in the UK comes on stream by the
end of 2001 and Boomvang in the US achieves production in early
2002. In the UK, the Clair field owners are moving that project
forward, with it expected to see sanction in October, while in
August the plan for the Valhall Flank development project was
submitted to the Norwegian authorities.
The group has continued to manage its portfolio actively, with
the completion in August of the acquisition of the Petrobras UK
assets and the disposal of Enterprise's Danish interests due to
complete shortly. In addition, successful performances in
licensing rounds in Brazil and Norway and lease sales in the US
provide new opportunities for the group to create value from
its portfolio.
Production for the first half averaged 255,116 boepd, including
associated production from the group's interest in KMOC. As a
result of remedial work on Nelson's gas compressor, delayed
work-overs to two wells on Pierce and increased water-cut on
Jotun, it is anticipated that output for the year, including
associated production, will average just below the 250-260,000
boepd range published in March.
Longer term, we remain committed to growing the value of the
company, balancing short-term returns against longer term
capital growth. In this context, we are targeting production
growth of 5 per cent per annum from the company's record
production levels in 2000. This target, which is one of
management's key objectives, is viewed as challenging but
achievable over a five-year timeframe. More than half of this
production growth has already been identified in our existing
portfolio; the balance will be achieved through exploration
success, identifying further upside potential in our existing
producing fields and developments and portfolio management.
The rest of 2001 will be an important time for Enterprise, as
the group further progresses its operated developments and
maintains a busy exploration and appraisal programme, and I am
confident that I will be able to report further successes in
February.
Dr Pierre Jungels
Chief Executive
*As a result of the adoption of the new deferred tax accounting
standard published in December 2000, last year's accounts have
been restated.
Financial Review
First half First half 2000
2001
(Unaudited) (Unaudited)
(Restated - see
below)
£m £m
Turnover 804 835
Operating profit 465 477
Profit before tax 476 457
Profit after tax 204 162
Profit after tax excluding exceptional item* 204 205
Operating cash flow after tax and financing 364 503
costs
Average oil price £18.54 £17.80
*the exceptional item related to the results for June 2000 (see note 3 to the
accounts).
The group has maintained its strong financial performance, despite a decline
in production levels, reflecting the sustained high sterling oil price
realisations and continued cost and capital discipline.
Return on average capital employed (RoACE) was 30.1 per cent on an annualised
basis compared with 28.7 per cent for the first half of 2000.
Profit before tax of £476 million has increased by £19 million compared with
the first half 2000 result. The effective tax rate in the first half of 2001
was 57 per cent (2000 first half 59 per cent, excluding the exceptional item).
Profit after tax was £204 million (2000 first half £162 million).
Basic earnings per share were 42.3 pence compared with 32.3 pence in the first
half 2000.
In the first half 2001, the group generated operating cash flow after tax and
financing of £364 million compared with £503 million in the first half of
2000. Net debt was £433 million at the end of the first half 2001 compared
with £579 million at the end of the first half 2000. Gearing was 34 per cent
at the end of the first half 2001 compared with 60 per cent at the end of the
first half 2000 and 39 per cent at the end of the full year 2000, as restated
(see below).
Restatement of prior periods
In December 2000 the Accounting Standards Board issued Financial Reporting
Standard (FRS) 19 'Deferred Tax' which has been adopted by the group for the
first time in the first half 2001. The impact of this standard is a move from
partial to full provisioning for deferred tax. The standard allows the
optional use of discounting for the calculation of future provisions; the
group has not used this option. The implementation of the standard has
resulted in a prior year adjustment, which has decreased shareholders' funds
and increased provisions of the group by £260 million at 1 January 2000.
Comparatives have been restated and consequently reserves have decreased and
provisions increased by £47 million for the six months ended 30 June 2000 and
£95 million for the year ended 31 December 2000, decreasing shareholders'
funds and increasing provisions at those dates by £307 million and £355
million respectively. The tax charges for the six months ended 30 June 2000
and for the year ended 31 December 2000 have increased by £34 million and £81
million respectively (see note 1 to the accounts).
Turnover
Turnover for the first six months of 2001 was £804 million, which represents a
4 per cent decrease compared with the same period in 2000. This decrease was
due to lower production levels, partially offset by higher sterling oil price
realisations. The average realised oil price for the period was £18.54
($26.79) per barrel of oil equivalent compared with £17.80 ($28.08) for the
first half of 2000.
Direct production in the first half of 2001 of 251,632 barrels of oil
equivalent per day (boepd) was 9 per cent lower than the same period last
year. This reduction is mainly due to a planned but extended shut down on the
Nelson field in the UK in June 2001, which allowed maintenance and
modification work to be carried out, and operational problems on the Pierce
field, also in the UK.
Operating profit
Cost of sales in the first six months of 2001 was £271 million. Cost of sales
for the same period in 2000 was £319 million including an exceptional charge
of £43 million. Excluding the exceptional item, cost of sales for the first
half of 2001 has decreased by 2 per cent compared with 2000.
On a per barrel basis, cost of sales in the first six months of 2001 was £5.94
(first half 2000 £5.47). Operating costs per barrel have increased by 14 per
cent compared with 2000, mainly in the UK where well maintenance work on
several fields, including Nelson, Miller and Pierce, was incurred.
Exploration and appraisal spend for the period was £71 million (£33 million
for the first half of 2000). Exploration and appraisal costs written off, as a
percentage of expenditure, were 65 per cent compared with 63 per cent in the
first half last year. First half 2001 administrative and selling expenses of £
25 million have increased by £6 million compared with 2000. The half year 2000
charge benefited from a £2 million release of a restructuring provision. The
remaining rise in administration costs reflects the increase in portfolio
management and other corporate activities across the group.
Operating profit for the first half of 2001 was £465 million compared with a
profit of £477 million in the first half of 2000.
Profit before tax
Profit before tax in the first half of 2001 was £476 million, an increase of £
19 million over the same period last year.
Net interest and similar income in the first six months of 2001 was £10
million compared with a charge of £22 million in the first half of 2000. This
includes foreign exchange gains of £15 million arising from the revaluing of
the Norwegian krone tax liabilities and other dollar denominated working
capital. Excluding foreign exchange gains, capitalised interest and unwinding
of discounts on long term provisions, the net interest charge for the first
half of 2001 was £29 million (first half 2000: £37 million). This decrease is
due to significantly lower net debt levels. Interest capitalisation has
increased by £12 million compared with the first half 2000, mainly due to the
inclusion in 2001 of the Boomvang development in the US Gulf of Mexico and the
Skarv gas development in Norway, together with higher spend in Italy on the
Monte Alpi and Cerro Falcone developments.
Taxation
The tax charge for the first six months of 2001 was £272 million (first half
2000: £295 million). The UK petroleum revenue tax ('PRT') charge was £36
million (2000: £52 million). The provision for PRT is calculated for each
discrete period based on average oil prices for those periods and the number
of barrels produced for each PRT paying field. In the first half of 2001
production from these fields, in particular the Nelson field, was lower than
in 2000, resulting in a lower tax charge. UK corporation tax was £71 million
in the first half of 2001 (first half 2000: £75 million).
The overseas tax charge for the first half 2001 is £164 million (first half
2000: £168 million).
The effective tax rate for the period was 57 per cent (first half 2000: 59 per
cent, excluding the exceptional item).
Profit after tax
The profit after tax in the first six months of 2001 was £204 million (first
half 2000: £162 million).
RoACE was 30.1 per cent on an annualised basis (first half 2000: 28.7 per
cent).
First half First half
2001 2000
(Unaudited) (Unaudited)
(Restated)
Return on average capital employed (RoACE) £m £m
calculation
Profit after taxation 203.9 161.7
Add back:
Interest (10.1) 22.4
Depreciation of capitalised interest 12.6 14.4
206.4 198.5
Average capital employed: shareholders' funds, plus
net debt
And excluding capitalised interest 1,369.7 1,384.5
RoACE calculation on an annualised basis 30.1% 28.7%
Capital expenditure
Capital expenditure, including capitalised interest and acquisitions, was £280
million in the first half of 2001 (first half 2000: £256 million). Production
and development expenditure, including capitalised interest but excluding
acquisitions, was £206 million (first half 2000: £133 million). This increase
is mainly due to the development since the first half 2000 of the Skarv field
in Norway and the Boomvang field in the US Gulf of Mexico. Exploration and
appraisal expenditure was £71 million for the first half 2001 (first half
2000: £33 million). Drilling activity in the US Gulf of Mexico, Ireland and
Brazil in the first half of 2001 has resulted in higher expenditure compared
with the first half of 2000, which saw a relatively low level of drilling
activity compared with the second half of that year and the first half of
2001.
Second half exploration and appraisal expenditure in 2001 is expected to be
higher than the first half at approximately £84 million, with planned drilling
activities in the US Gulf of Mexico, the UK, Greece, Norway and Italy.
Production and development expenditure for the full year, including
capitalised interest but excluding acquisitions, is expected to be slightly
over £500 million.
Cash flow and financing
Operating cash flow after tax and financing costs was £364 million compared
with £503 million in the first half of 2000. This anticipated decrease
reflects the significantly higher cash taxes paid in the first half 2001,
mainly in Norway. The second installment of the Norwegian tax liability for
2000 was paid in the first half of 2001, representing the balance of the 2000
liability, based on high oil prices in the second half of 2000. The second
installment of the 1999 liability, paid in the first half of 2000, was based
on much lower 1999 earnings in Norway. The UK corporation tax payment dates
are currently in a transition period. The first half 2001 payment represents
the major part of the 2000 tax liability.
Interest cover for finance costs was 13 times, compared with 17 times for the
first half 2000. This decrease also reflects the high level of tax payments in
the first half 2001 compared with the first half 2000.
Net cash payments on capital items of £237 million increased by £100 million
compared with the first half of 2000 due to the increase in the number of
exploration and development projects. Net debt at the end of June 2001 was £
433 million compared with £579 million at the end of June 2000. Gearing was 34
per cent compared with 60 per cent at the end of June 2000, as restated. The
impact of the application of FRS19 as a prior year adjustment, referred to
above, was to increase gearing at the end of June 2000 by 15 percentage
points.
The group had available funds, including committed facilities, of £1.2 billion
at 30 June 2001. The group's credit ratings from Standard and Poor's and
Moody's are unchanged at BBB+ and Baa1 respectively.
At the March 2001 Board meeting the directors approved a share repurchase
programme pursuant to the authority granted by shareholders at the 2000 AGM.
During the three and a half months to 30 June 2001, 6.7 million ordinary
shares of 25p each were purchased and then cancelled. The nominal value of the
shares that were cancelled was £1.7 million. The repurchase prices ranged from
548.8p to 618.76p, resulting in £38.4 million being returned to shareholders
at 30 June 2001. To date a total of £47.9 million has been repaid to
shareholders at 5 September 2001.
Operational Review
A solid performance During the first half of the year total production
positioning the including associated output averaged 255,116 boepd (2000:
group for long term 277,056 boepd).
growth
Enterprise has performed solidly in all its key
geographical areas and has seen operational success
throughout its core businesses laying the foundation for
future growth.
The first six months of 2001 have seen the following
operational highlights:
UK
The group is The first half of the year saw the announcement of the
accessing new group's acquisition of Petrobras UK Limited which was
opportunities to completed in August 2001. This acquisition provides the
build for the group with assets including fields in production, potential
future in the North developments and exploration acreage. In particular the
Sea assets include eight potential developments of which four
are operated. This acquisition has strengthened the group's
ability to unlock value from undeveloped discoveries.
Production from the 21 fields in the UK North Sea averaged
139,500 boepd in the first half of the year. The group's
operated UK fields, Nelson, Pierce and Cook, produced 43
per cent of the group's UK production in this period.
The Nelson field is now producing at rates of 80,000 boepd
following an extensive planned production shutdown, which
was extended by the need to rework an incorrectly assembled
compressor.
In late August, an infill drilling programme of up to six
wells commenced on the Nelson field, and it is expected
that this will give a significant boost to the field's
production rates in 2002.
Pierce is currently producing at rates of 38,000 boepd.
Production is expected to increase further following
completion of the work-over programme on the field.
The Cook field continues to produce steadily, at rates of
up to 24,000 boepd, and has now produced in excess of seven
million boe. The Conoco-operated Banff field re-commenced
production in March 2001 and is producing consistently at
rates of up to 28,000 boepd following the upgrades to the
Floating Production Storage and Offtake vessel (FPSO) and
the installation of a storage tanker.
Activity on the Skene development has progressed with the
project moving towards first gas by the end of 2001. The
field is being developed as a sub-sea tieback to the Beryl
Alpha platform. At peak the Skene field is expected to
produce approximately 180 million cubic feet of gas and
25,000 barrels of associated liquids per day. The Maclure
development is expected to receive project sanction in
September 2001. First production is anticipated in the
second half of 2002.
The Clair field in the West of Shetlands area was
discovered in 1977 and is the largest undeveloped field in
the UK. The field is heading towards project sanction
expected by the end of the year. The export route for oil
will be through a pipeline to the Sullom Voe terminal and
work is nearing completion on the front-end engineering and
design phase of the project.
Exploration and appraisal activity in the UK during the
first half of the year included the drilling of four wells.
The Howe appraisal well, close to our Nelson field, was
suspended as a potential producing well in February 2001
and possible development options for the field are being
evaluated. Enterprise has also participated in the first
well to be drilled on the Faroese continental shelf which
whilst not a discovery has yielded valuable information on
the potential of the area.
Ireland
A major gas project The Corrib development continues to gather momentum with
on course for significant progress made in the first six months of the
Enterprise, and for year. The development is expected to ensure an indigenous
Ireland gas supply in Ireland for at least 15 years.
In February, Enterprise and its co-venturers announced
project sanction for the development, which will comprise
the construction of an offshore pipeline connecting subsea
facilities to an onshore terminal in the West of Ireland.
In June another step in the project was taken with the
award of three major contracts for both the on and offshore
elements of the development. The contracts cover the subsea
equipment and installation, and the construction of the
onshore terminal. The value of these contracts covers a
significant part of the total project costs, and the award
is a milestone in the project's schedule.
The group has engaged in extensive consultation with local
communities and stakeholders in the region. Following this
process, planning permission for the terminal (subject to
an appeal to be heard later this year) was granted in
August 2001 by Mayo County Council. In addition, agreement
is in place for the sale of 60 per cent of the group's
Corrib gas to Bord Gas Eireann, and the group is discussing
the sale of the rest of its share of the gas with other
potential customers.
Norway and Denmark
Developing new The group's operations in Norway have been boosted by
relationships and appraisal success and licence round awards.
alliances to
strengthen a In the first six months of the year Norwegian and Danish
dynamic business production averaged 105,600 boepd from 10 fields. The Jotun
field, which produced significantly higher rates than
planned during 2000, has come off plateau and is now
producing more water than forecast as it matures, resulting
in declining oil production levels.
The Skarv discovery was successfully appraised confirming
additional reserves. The Svale discovery was appraised in
May and development options for both fields are being
considered.
The fabrication of the Valhall Water Injection Platform
began in April 2001 and was 25 per cent complete by the
middle of the year. Work is on schedule for first water
injection early in 2003. The Valhall Flank development
project has received the approval of the field owners, and
the group has submitted plans for government approval. This
project will enable the group to access further reserves
and accelerate production from the Valhall field.
In April the group celebrated its most successful
performance in a Norwegian licensing round to date, when it
gained three awards including its first operatorship in
Norway. As a part of the preparation for future licensing
rounds, Enterprise has entered into area of mutual interest
(AMI) agreements with major companies active in the
Norwegian Continental Shelf, and in particular those active
in natural gas production such as Shell and Statoil. Under
these agreements Enterprise and the other parties will
consider joint participation in future licensing rounds and
other opportunities to acquire interests offshore Norway.
In August the group disposed of its non-core Danish
interests through the sale of its subsidiary Enterprise Oil
Denmark Ltd for $35 million to Paladin Resources. The sale
is expected to be completed in September.
Italy
Time and patience 2001 is an exciting year for the group's Italian operations
in Italy have paid with the start of phase one production from the Val d'Agri
dividends project. Gross production from this phase of the project
doubled in August to 20,000 boepd following commissioning
of the new facilities at the oil centre. The group's
Italian production during the first half averaged 4,100
boepd.
The first half of the year has seen the conclusion of
construction of the Val d'Agri oil centre, with production
expected to increase significantly in late 2001. The
group's target is that the oil centre will eventually
process 120,000 boepd at full capacity. The Tempa Rossa
field in which the group has a 25 per cent interest may
achieve project sanction later in 2001, and has the
potential to increase the production flowing through the
pipeline to around 150,000 boepd in 2005.
Work on the pipeline connecting the oil centre at Viggiano
to the refinery at Taranto is nearing completion. It is
anticipated that the pipeline will be commissioned in
October 2001. The oil from the Val d'Agri fields will be
delivered to the oil centre for separation and processing
and then through the pipeline onwards to the refinery and
the export facilities. Drilling of the development wells on
Monte Alpi and Cerro Falcone and an exploration well in the
Po Valley continues.
US Gulf of Mexico
Building a core The US Gulf of Mexico is developing towards core area
area with diversity status within Enterprise's portfolio, with the group's
regional assets now including producing fields, development
projects and exploration acreage, providing exposure to all
aspects of the business cycle. The first half of 2001 has
been important for business activities in the US.
Gross production from the Gyrfalcon and Garden Banks 161
fields averaged 2,500 boepd during the first half of 2001.
In May Enterprise took over operatorship of the Llano field
from EEX and the group is now focusing on the forward work
programme for the field. This includes the drilling of a
third appraisal well which is currently underway. The
results of this well together with data acquired from
previous wells will help determine the best development
option for the field. A Llano project team has been formed
in Houston.
The Boomvang development is on course to achieve first
production in early 2002. The first half of the year has
already seen the construction of the SPAR platform hull in
Finland. The hull will be delivered to the US Gulf towards
the end of the year, with topsides scheduled for delivery
in late 2001. During the first half of the year six
development wells were drilled on the field, three of which
will be completed ahead of the installation and hook-up of
the SPAR platform in early 2002. Gross production from this
field is anticipated to reach a peak of 25,000 barrels of
oil and 150 million standard cubic feet of gas per day in
2003.
The group has gained access to several high quality
exploration opportunities in the first half 2001. This
follows a strategy of pursuing selective exploration
prospects where Enterprise can identify significant
potential. The Shell operated Deep Mensa well, which
Enterprise has farmed into and is currently drilling, is an
example of such an opportunity. The group intends to
continue to build up its acreage in areas in which it
maintains a strategic position such as the Boomvang area
where it recently added 10 blocks in the August lease
sales.
Brazil
On fast forward to The group's growth in Brazil is an illustration of the
a strong new dynamism of Enterprise's business culture. In the first
business half of 2001 the group has strengthened its position as a
leading player in the recently deregulated oil and gas
industry.
Enterprise farmed into the Bijupira-Salema field
development in March 2000 as operator and has since then
driven the project on a rapid development schedule. In the
first six months of 2001 contracts for the provision of the
FPSO and subsea equipment were awarded to FMC Modec.
The development was sanctioned by the Brazilian licensing
authority, the ANP, in June 2001 and development drilling
is expected to begin in September. A total of 16 wells are
planned to be drilled over the next two years. The fields
are expected to begin producing in the second half 2003 at
rates of up to 70,000 boepd.
In the first half of the year the group also secured its
first operated block and three non-operated blocks in
Brazil's third oil and gas licensing round. The awards
provide access to future exploration opportunities in two
new deep-water basins offshore Brazil. The first well
drilled by the group in Brazil resulted in the Curio
discovery in Block BC-2 in January.
New Ventures
Doing business in Enterprise is broadening its international presence with
different ways interests in a number of new venture areas in which the
group seeks to find new ways of creating value for its
shareholders.
KMOC
The group's involvement with the Khanty Mansisyk Oil
Corporation (KMOC) has continued during 2001. KMOC's
operations programme for 2001 has progressed well with 18
new wells completed in the first half. Gross production for
this period averaged over 12,800 boepd of which over 11,100
boepd came from KMOC's operated fields, an increase of
approximately 60 per cent from the first half of 2000.
Following the completion of a new direct tie-in from the
Potanay field to the Transneft export pipeline, operated
production in June averaged over 14,600 boepd. As a result
of its 27 per cent (18.6 per cent fully diluted)
shareholding in KMOC, Enterprise has reported 3,484 boepd
as associated production for the first half of 2001.
Iran
The group continued to evaluate investment in Phases 6, 7
and 8 of the South Pars gas development in Iran. An
appraisal well, managed by Enterprise,was spudded in late
July. The basic facilities design work is nearing
completion and detailed discussions about commercial,
financing and project management arrangements are
progressing. The final investment decision will depend upon
satisfactory resolution of these discussions.
Morocco
Enterprise has been pursuing opportunities in Morocco
during 2001 and has acquired interests in two additional
onshore reconnaissance licences in the Azila Ouezzane and
Tissa areas. The group also holds an offshore exploration
licence over the Cap Draa Haute Mer area. The first half of
2001 saw the acquisition of 1,800 square kilometres of 3D
seismic in this permit with a further 2,000 square
kilometres due to be acquired in 2002.
Greece
During the first half of the year the North West
Peloponnesos licence was relinquished following the two
wells drilled in 2000. Drilling in the Ioannina area will
commence in September with the Demetra 1 well. This deep
onshore well is expected to take three to four months to
complete.
MORE TO FOLLOW