Premier Oil Issues Operational and Trading Update

Premier Oil plc said Wednesday that it plans to announce its interim results for the 6 months to June 30, 2006, on Sept. 21, 2006. In advance of these results, the company reported the following update on its recent operations and trading performance during the first half of 2006.


--100% exploration success record from three exploration wells in Indonesia
--Discovery on our first well in Vietnam, the Dua prospect
--Acquisition of 16.67% in the highly attractive North Sumatra Block A PSC in Indonesia
--On target to deliver four high-impact wells during 2006 at a planned spend of $50 million
--New rig contracts in Gabon, Guinea Bissau, India, Indonesia, and the U.K., successfully locking in 2006/7 drilling program
--Strong cash flow generation leading to a net cash position at June 30 of around $40 million

“Premier has continued to make excellent progress in realizing its strategic goals, with exploration success, progress in our development portfolio, and a promising acquisition in Indonesia,” said Simon Lockett, Premier’s chief executive. “We look forward to the second half of 2006, anticipating the results of high-impact exploration drilling from Vietnam, India, and the U.K.”


Working interest production for the first half of the year averaged 33,600 boepd (2005 FY - 33,300 boepd). Production from the Chinguetti field in Mauritania has now stabilized at around 35,000 boepd. At this level, Premier's total production for the year is likely to average at or around the current level of 33,000 boepd.

Cash flows for the first half benefited from strong oil and gas prices with oil production sold at an average of $66.37 per barrel for the first half, a premium to Brent. Indonesian gas prices were also extremely strong, benefiting from high-sulfur fuel oil pricing that drives the contracted price.

Development capex for the full year is expected to be around $120 million after inclusion of the $17 million purchase price for Premier’s acquisition in North Sumatra.

Exploration capex has been actively managed during the first half. This has included farm-outs on favorable terms in Vietnam, India, U.K., and Pakistan. Premier anticipates meeting its stated targets of drilling at least four-high impact wells for the year on exploration spend of no more than $50 million (pre-tax).

Premier’s cashflow continues to be very strong. Net debt of $26 million at Dec. 31, 2005, was transformed into a net cash position of approximately $40 million at June 30, 2006.


Current operations

Premier is currently drilling on the Dua prospect in Vietnam. Premier confirmed presence of oil and gas in the Northern fault block of this prospect. Sidetrack operations continue into the Southern fault block and a further release will be made upon completion of operations.

Premier's Al- Amir appraisal well was spudded on May 25, 2006. The well appraised an earlier 2005 discovery that flowed 750 boepd. The well has reached target depth, and oil was successfully encountered within several horizons in the South Gharib reservoir.

In addition to its previously announced successful wells at Macan Tutul and Lembu Peteng, Premier is pleased to report that the non-operated Lukah-1 exploration well in the Kakap block encountered gas. Gas was tested over two intervals and flowed at a combined rate of 19.7 mmscf/d with some additional flow of condensate. Premier holds 18.75% of this discovery, close to the existing infrastructure of the Kakap field.



On completion of the Dua well, Premier will drill the Blackbird prospect exploring a large tilted fault block updip of a pre-existing well that encountered very good oil shows. The Blackbird structure has the potential for up to 80 mmbbls of oil.

The Seadrill-5 rig is anticipated to spud an appraisal of Premier's significant Lembu Peteng discovery in December 2006. The Lembu-Peteng discovery, announced on March 23, 2006, tested an oil zone at a stabilized rate of 610 boepd. Two gas zones yielded 8.5 mmscf/d of gas plus 580 boepd of condensate.

Premier plans to spud the high-impact Masimpur-3 well, a 2-Tcf onshore gas prospect in Cachar in December 2006. Premier recently completed a farmout on this license and retains a 14% interest in Masimpur.

Premier recently signed an LOI to secure the Century 28 rig to drill the Masimpur prospect and a possible further two wells on the Cachar block. The farm-in agreement also contemplates joint bidding for selected licenses in the forthcoming NELP 6 exploration round.

North Sea

Premier plans to drill the Peveril prospect on license P802, commencing November 2006. Premier has completed a farm-out of its interest and is in final negotiations with a drilling contractor to manage and drill the well. Premier retains a 30% interest in this 40-mmbbl prospect, which is located close to existing Fife Area infrastructure (Premier, 15%). Premier also recently made two applications for new exploration acreage in the UKCS 24th Licencing Round.

Premier is continuing exploration activity on the 2005 APA blocks with a view to maturing prospects for drilling in 2007 and 2008. Premier has formed a number of AMI groups to progress applications in the forthcoming 2006 APA round.

West Africa

Woodside has reported that the Atwood Hunter is now on location for the Colin well. Colin is a 170-mmbbl Miocene prospect in which Premier holds a 4.63% share via its interest in PSC A. After a program of wells that may include phase 2 development drilling on the Chinguetti field, the Atwood Hunter is scheduled to drill the Kibaro exploration prospect late in 2006 or early in 2007. This is a 130-mbbl prospect in PSC A (Premier share 4.62%) with a Cretaceous objective.


West Africa

Guinea Bissau
Given the tight rig market in West Africa, Premier is pleased to announce that the Global SantaFe rig Baltic has been contracted to drill the Eirozes and Espinafre prospects (predrill estimates 250 mmbbls and 70 mmbbls gross, respectively) in early Q1 2007. Having previously reserved slots with the Bulford Dolphin Rig, operating delays and slippage in its program led Premier to seek an alternative rig to secure the timing of our wells on these prospects.

Middle East and Pakistan

The high-impact Anne well is now scheduled to spud in Q2 2007. The timing of this well has been moved to avoid the significant costs that would have been associated with drilling through the monsoon season. Anne is only the third well to be drilled on the offshore Indus Delta, and success on this high-risk well would open up a new oil frontier. Premier holds a 12.5% share in this 250- mmbbl prospect.


Premier has extended the current 2006 rig contract with the Seadrill-5 for the 2007 program. The company anticipates his will comprise a Premier-operated five-well program with two exploration wells, likely on Block A, and further appraisal wells on the Lembu Trend and on Gajah Puteri. Premier has options on two further rig slots.

After completion of operations on Masimpur-3, which is planned to be drilling during December 2006, Premier is planning to spud a further two wells on the large Chargola and Kancipir gas prospects. Premier will hold a 14% share.

Premier operates Service Contract 43 in the Ragay Gulf with a 42.5% working interest. Having identified a trend of carbonate build-ups, Premier is planning for a well to test the trend in the second half of 2007.


Premier has continued to make strong progress in the commercialization of its project development portfolio.


Natuna Sea Block A
The West Lobe Wellhead Platform was installed in April and achieved mechanical completion in June 2006. The wellhead platform will be used to drill up to a maximum of 12 wells over the productive life of the field, will tie-in to the existing pipeline facilities, and will be controlled remotely from the existing Anoa production complex. A four-well development drilling program will commence in July using the Seadrill-5 drilling rig.

Negotiations continue over the sale of further gas from Block A with prospective buyers in Singapore. Premier currently assesses Singapore to be the optimal market for new gas sales where new gas-fired power stations, as well as new petrochemical plants, are planned; but, the company maintain a watching brief over alternative markets--particularly domestic Indonesia.

North Sumatra Block A
Premier, together with its partners Medco and Japex, acquired a subsidiary of ExxonMobil that holds a 50% working interest in the North Sumatra Block A PSC, onshore Indonesia in March. The partners paid $51 million in aggregate, with Premier paying $16.7 million for a 16.67% interest in the block. The operator of the block is ConocoPhillips (50%).

The block contains three undeveloped discoveries, which in total are certified as holding more than 650 bcf gross of proved and probable reserves (110 bcf net to Premier). The gas reserves will be developed to supply PT Pupuk Iskandar Muda (PIM), which operates two fertilizer plants located close to the Arun LNG facility. Premier plans for first gas in 2010. Premier anticipates that development costs for the three areas will be approximately $400 million gross.

North Sumatra Block A offers substantial potential upside. Around 20 prospects have been identified with total prognosed unrisked reserves of 1.5 tcf gross. The giant Kuala Langsa field is located at the eastern edge of the block and contains 10 tcf with high CO2 content.

The PSC for the Ratna field development project, offshore Mumbai, received preliminary government approval earlier this year. Discussions continue with the partners and MoPNG regarding offtake arrangements under the contract. Under the draft PSC Premier is the operator with a carried 10% stake in the project. Post-redevelopment, Premier expects that production from the field will be in excess of 20,000 boepd.

Middle East and Pakistan

Premier said that all four of its existing producing fields are performing extremely well, again generating record production levels in response to strong local demand for gas. Good progress is being made in pursuing field and plant capacity expansions on the following projects:

--Zamzama Phase 2 expansion: expected onstream July 2007
--Qadirpur plant capacity enhancement: expected onstream January 2008
--Bhit Phase 2: expected onstream January 2008

These initiatives are projected to increase the company’s net production in Pakistan from the current level of around 12,000 boepd to more than 16,000 boepd during 2008.

A Qadirpur development well is currently being deepened to evaluate a lower prospect (“Qadirpur deep”) targeting gross mean reserves of 400 bcf. Results from this well are expected in September.

A 3D seismic study on Kadanwari has been completed and has identified new prospects for drilling.

West Africa

Production from the Chinguetti field (Premier, 8.12%) has currently stabilized in the 35-40 kboepd range (gross). A significant increase in production is not expected until additional development wells are onstream. It is too early to fully assess the impact of recent reservoir performance in reserve estimates. Options for the next phase of development drilling are currently being finalized.

Evaluation of the potential development of the Tiof and Tevet discoveries in PSC B (Premier, 8.12%) is advanced and expected to lead to initial development decisions in early 2007. Both fields present considerable technical and commercial challenges that are being actively addressed by the joint venture.

North Sea

Production on Wytch Farm in the first half of 2006 was lower than expected; however, Premier is looking forward to a strong second half as two new wells are brought onstream and further interventions are completed to maintain production levels. The Operator is considering options for the development of the 98/2 offshore discovery now named Beacon.

Kyle oil production has been better than expected during the first half of 2006. In August the K15 well will be re-perforated to maintain oil production rates. Approvals have been given for the purchase of long lead items required for the Palaeocene well that is currently scheduled for the end of the second quarter 2007.

Premier is working toward declaring the commerciality on the Froy field (Premier 50%) by the end of 2006, prior to submitting the plan of development during the first half of 2007.

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