Interim / Quarterly Report • Nov 3, 2010
Interim / Quarterly Report
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3 November 2010
| 1 Jan 2010- 30 Sep 2010 9 months |
1 Jul 2010- 30 Sep 2010 3 months |
1 Jan 2009- 30 Sep 2009 9 months |
1 Jul 2009- 30 Sep 2009 3 months |
1 Jan 2009- 31 Dec 2009 12 months |
|
|---|---|---|---|---|---|
| Production in Mboepd, gross | 32.8 | 32.1 | 39.1 | 38.3 | 38.6 |
| Production in Mboepd, after minority |
32.8 | 32.1 | 38.6 | 37.7 | 38.2 |
| Operating income in MUSD | 623.1 | 202.4 | 583.8 | 238.2 | 805.9 |
| Net result in MUSD | 412.1 | 22.0 | 5.4 | -13.5 | -537.1 |
| Net result attributable to | 421.8 | 26.6 | 10.5 | -12.9 | -411.3 |
| shareholders of the parent company in MUSD |
|||||
| Earnings/share in USD1 | 1.35 | 0.09 | 0.03 | -0.04 | -1.31 |
| Diluted earnings/share in USD1 | 1.35 | 0.09 | 0.03 | -0.04 | -1.31 |
| EBITDA in MUSD | 458.0 | 167.3 | 362.1 | 145.2 | 486.2 |
| Operating cash flow in MUSD | 441.7 | 160.2 | 359.6 | 135.8 | 471.9 |
The numbers included in the table above are based on the total of continuing and discontinued operations. 1 Based on net result attributable to shareholders of the parent company.
The presentation and slides will be available on www.lundin-petroleum.com following the presentation. Please dial in to listen to the presentation on the following telephone number: + 44 (0) 203 043 24 36.
Lundin Petroleum is a Swedish independent oil and gas exploration and production company with a well balanced portfolio of world-class assets in Europe, Russia, South East Asia and Africa. The Company is listed at the Nasdaq OMX Nordic Exchange, Stockholm (ticker "LUPE"). Lundin Petroleum has existing proven and probable reserves of 177 million barrels of oil equivalent (MMboe).
For further information, please contact:
| C. Ashley Heppenstall, | Maria Hamilton, | |
|---|---|---|
| President and CEO | or | Head of Corporate Communications |
| Tel: +41 22 595 10 00 | Tel: +46 8 440 54 50 | |
| Tel: +41 79 63 53 641 |
Visit our website: www.lundin-petroleum.com
The highlight of the third quarter for Lundin Petroleum shareholders was the Avaldsnes oil discovery, offshore Norway. Our strategy is to create shareholder value through a proactive exploration drilling strategy and I am very pleased to report that we have a significant discovery at Avaldsnes with likely recoverable resource of between 100 and 400 million barrels of oil equivalent (MMboe) in PL501 where we operate with a 40 percent working interest. We encountered excellent reservoir quality at the well location, produced good quality oil on test and have now mapped a large fault controlled structure which also stretches into PL265 to the west. The structure is very large and as a result we need to confirm the lateral continuity of the reservoir. We have already secured additional drilling rig capacity next year and will likely drill a further two appraisal wells on Avaldsnes in PL501 in 2011.
We have successfully progressed development planning for the Luno field located in PL338. The recoverable reserves for the Luno field have increased by over 50 percent to 149 MMboe as a result of the successful appraisal well drilled earlier this year. The Luno field is commercial on a standalone basis and conceptual development studies have been substantially completed. We are also working closely with Det norske oljeselskap ASA, the operator of the nearby Draupne field, to determine whether a Luno/Draupne joint development makes sense, and early indications are that this is the case. The current plan is to submit a plan of development for the Luno field either on a joint or standalone basis during 2011.
In addition, the Avaldsnes discovery has increased the exploration prospectivity of the Greater Luno Area where Lundin Petroleum is the predominant holder of acreage. The discovery has proven the migration of hydrocarbons to the eastern side of the Utsira High and as a result we will now likely drill further exploration wells in 2011 on the Tellus prospect in PL338 and the Torvestad prospect in PL265/PL501, followed by additional wells in PL359 and PL410 in 2012.
I believe that with Luno, Avaldsnes and the additional exploration potential, the Greater Luno Area is likely to become a significant production hub on the Norwegian Continental Shelf.
The spin-off of our United Kingdom business into the new independent oil company EnQuest plc was successfully completed earlier this year. We are pleased that the positive development of EnQuest's market capitalisation has created additional value to our shareholders who have retained their investment in EnQuest. During November 2010 we plan to complete a further distribution to our shareholders involving shares in Etrion Corporation, an independent solar power development company, in which Lundin Petroleum currently owns approximately 40 percent of the outstanding shares. Etrion Corporation will, concurrent with the distribution, list its shares on the NASDAQ OMX Stockholm exchange and I believe Etrion will continue to grow and generate further value for its shareholders.
Lundin Petroleum produced a net result for the period of MUSD 412 which includes the gain of MUSD 358 reported on the spin-off of our UK business. Our remaining operations continue to produce strong operating cash flow, achieving MUSD 160 in the third quarter of 2010 to give a total operating cash flow for the period of MUSD 442. The generation of strong operating cash flow is driven by our Norwegian production where the cost of operations are below USD 4 per barrel.
During the third quarter of 2010, production averaged 32,100 boepd with continued strong contributions from both the Alvheim and Volund fields, offshore Norway. If we exclude the United Kingdom production included in the first quarter, then production has increased steadily during 2010 as a result of production build up from the Volund field. As a result of the strong third quarter production we have narrowed our previous production guidance range for 2010 to 32 - 34,000 boepd.
We are currently progressing five potential development projects in Norway which collectively will double our current corporate production to over 60,000 boepd within the next five years. I am confident that these projects can be financed through a combination of internally generated cash flow and bank borrowings without the requirement for further equity funding.
The Gaupe field received plan of development approval from the Norwegian government in 2010 and is now progressing through the construction phase. I expect plans of development for the Luno and Nemo projects to be submitted in 2011 with conceptual planning completed for Krabbe and Marihøne also in 2011.
In addition, exploration successes such as Avaldsnes are continuing to feed our pipeline of development projects and ensure that we maintain our excellent historical performance of reserve replacement ratios.
In Russia, we remain keen to progress the appraisal of the Morskaya oil discovery in the northern Caspian. We continue discussions with potential new partners to satisfy the requirements of the Russian Government which requires 'strategic' assets to have 50 percent ownership by state owned companies prior to development.
As I mentioned earlier, we are very excited about the Avaldsnes discovery and the potential for further discoveries in the Greater Luno Area. We are investing significant amounts of capital in Norway to continue our aggressive exploration drilling programme. We will continue to focus on the Greater Alvheim and Greater Luno areas where we feel our technical team have a competitive advantage. In 2011 we will also commence our exploration drilling programme in the Barents Sea where we have put together a large predominantly operated licence position. We plan to drill one or two wells per year in the Barents Sea for the next three years targeting large multi stacked prospects in this under explored area.
In 2011 we will also commence a five well exploration drilling programme in Malaysia. Our management has a proven track record in Malaysia having discovered significant hydrocarbons with Lundin Oil prior to its purchase by Talisman Energy in 2001. We returned to Malaysia with Lundin Petroleum a few years ago and have quietly built a licence portfolio where we have acquired new 3D seismic. Our objective is to replicate the Norwegian organic growth driven exploration success story in Malaysia.
We believe that the value creation within an independent oil company such as Lundin Petroleum is driven by our ability to increase our resource base. We have been successful with our recent exploration activity but I am convinced there is more to come and as such we can deliver further increases in value to our shareholders over the next few years.
Best Regards
C. Ashley Heppenstall President and CEO
The net production to Lundin Petroleum for the nine month period ended 30 September 2010 (reporting period) from the Alvheim field (Lundin Petroleum working interest (WI) 15%), offshore Norway, was 13,600 barrels of oil equivalent per day (boepd). The Alvheim field has been on production since June 2008 and continues to perform above expectations. This excellent reservoir performance has resulted in increased gross ultimate recoverable reserves during 2009 to 246 million of barrels of oil equivalent (MMboe). Phase 2 of Alvheim development drilling commenced in the second quarter of 2010 and now involves the drilling of four new multilateral wells to be completed mid 2011. The first Phase 2 well will come on production in late 2010. The cost of operations for the Alvheim field averaged below USD 4 per barrel for the period and is expected to remain at this level for 2010.
The net production to Lundin Petroleum from the Volund field (WI 35%) amounted to 3,800 boepd for the reporting period. The first two development wells (one producer and one water injector) on the Volund field were successfully completed in 2009 but due to limitations in production capacity on the Alvheim FPSO the first Volund production well did not commence production until April 2010. Phase 2 of Volund development drilling which involved a further two multilateral production wells was successfully completed in the third quarter of 2010. As a result current Volund field production has increased to a rate of above 8,700 boepd net to Lundin Petroleum which is the Volund field firm capacity on the Alvheim FPSO.
In October 2009, a new oil discovery on the Marihøne prospect in PL340 (WI 15%) was announced. The discovery is estimated to contain gross recoverable resources of 20 to 30 MMboe and will likely be developed as a subsea tieback to the Alvheim FPSO. A further exploration well targeting the Caterpillar prospect in PL340BS will commence drilling in late 2010.
The Luno field located in PL338 (WI 50%) was discovered in 2007 and has subsequently been appraised by two further wells. The results of these appraisal wells have been incorporated into the reservoir model being used for development planning and has resulted in an upgrade of gross proven and probable (2P) reserves from 95 MMboe to 149 MMboe for the Luno field. The reserves have been estimated by third party reserves auditors Gaffney Cline & Associates. Conceptual development studies for a Luno field standalone development are substantially complete. In parallel, studies are ongoing in relation to a joint development of the Luno field and the Draupne field located in nearby PL001B. A plan of development for the Luno field on a standalone or joint basis will be submitted in 2011.
Exploration well 16/1-14 in PL338 targeting the Apollo prospect is currently being drilled. Apollo is situated immediately to the south of the Draupne field in PL001B, and some 5 km northwest of, and down-dip from, the Luno field located in PL338. The main objective of the Apollo well is to test what is believed to be a possible extension of the Draupne field into PL338. Lundin Petroleum currently estimates unrisked gross prospective resources in the range of 20 to 130 MMboe for the Apollo prospect in PL338.
An exploration well in PL501(WI 40%) targeting the Avaldsnes prospect was successfully completed in the third quarter of 2010 as an oil discovery. Production tests confirmed excellent reservoir characteristics with the well flowing at a restricted production rate of approximately 5,000 bopd. It is estimated that the Avaldsnes discovery contains gross recoverable resources of 100 - 400 MMboe within licence PL501 and that the fault controlled
structure extends to the west into PL265 (WI 10%). Appraisal of the Avaldsnes discovery will commence in the first half of 2011 with the drilling of two appraisal wells in PL501. It is likely that the structure will be further appraised with the drilling of an additional well in PL265. The Avaldsnes discovery has successfully proven the migration of hydrocarbons to the eastern side of the Utsira High. This has a positive impact upon the exploration potential of the Greater Luno Area and as a result further exploration wells will likely be drilled in 2011 on the Tellus prospect in PL338 (WI 50%) and the Torvestad prospect in PL265/PL501 followed by wells in PL359 (WI 40%) and PL410 (WI 70%) in 2012.
The plan of development was approved in June 2010 for the Gaupe field in PL292 (WI 40%), where first production is expected in late 2011. The Gaupe field operated by BG group has estimated gross reserves of approximately 28 MMboe and is estimated to produce at a plateau production rate net to Lundin Petroleum of 5,000 boepd.
Development planning is ongoing on the Nemo field in PL148 (WI 50%) and the Krabbe field in PL301 (WI 40%). A concept selection has been completed for the Nemo field and subject to finalisation of commercial negotiations it is expected that a plan of development will be submitted in 2011.
In the first quarter of 2010, an exploration well on the Frusalen prospect in PL476 (WI 30%) was completed as a dry hole and a well on the Luno High prospect in PL359 (WI 40%) was completed as non-commercial.
The net production to Lundin Petroleum in the Paris Basin (WI 100%) averaged 2,500 boepd and in the Aquitaine Basin (WI 50%) averaged 700 boepd for the reporting period. The drilling of a water injection well on the Mimosa licence (WI 50%) in the Aquitaine Basin has been successfully completed and has had a positive impact on production.
The net gas production to Lundin Petroleum from the Netherlands averaged 2,100 boepd for the reporting period which was ahead of forecast.
The exploration well De Hoeve-1 in the onshore Gorredijk concession (WI 7.75%) was successfully completed in the first quarter 2010 as a gas discovery.
A 3D seismic acquisition programme in the Slyne Basin licence 04/06 (WI 50%) was completed in the third quarter of 2010.
The net production to Lundin Petroleum from the United Kingdom averaged 3,000 boepd during the reporting period.
On 6 April 2010, Lundin Petroleum completed the spin-off of its operations in the United Kingdom into EnQuest plc, a newly formed company focusing on the UK North Sea. Production from the United Kingdom is included only for the three month period ended 31 March 2010.
Salawati Island and Basin (Papua)
The net production to Lundin Petroleum from Salawati (Salawati Island WI 14.5%, Salawati Basin WI 25.9%) was 2,000 boepd for the reporting period.
In September 2010, Lundin Petroleum signed a sale and purchase agreement with RH Petrogas (RHP) in relation to the sale of its Salawati interests. The consideration for the sale is MUSD 37.1 plus an additional MUSD 3.9 in the event of certain future field developments. The transaction is subject to certain conditions including RHP shareholder approval and is expected to complete before year end 2010.
The net production to Lundin Petroleum from the Singa gas field (WI 25.9%) during the reporting period amounted to 300 boepd. Production from the Singa field commenced during the second quarter of 2010. Current gross production from the first production well is 15- 20 million standard cubic feet per day (MMscfd) of sales gas and is restricted by surface facility limitations resulting from higher hydrocarbon liquid production than expected. Additional liquid removal facilities will be installed and until such time production will remain constrained. Production is expected to increase to a gross plateau rate of 50 MMscfd following further development drilling. The original Singa gas sales agreement with PT PLN (Persero), an Indonesian state owned electricity company, was amended in February 2010 incorporating an increased gas price and to allow PT PGN (Persero), an Indonesian state owned gas distributor, to buy initial production from the Singa field. The gas sales contract with PT PGN (Persero) was signed in April 2010. The average gas price for both contracts is in excess of USD 5 per million British thermal units (MMbtu).
A 474 km 2D seismic acquisition programme is currently ongoing on the Rangkas licence (WI 51%).
A 975 km2 3D seismic acquisition programme on the Baronang and Cakalang licences (WI 100%) was completed in April 2010 and interpretation is ongoing.
A total of 2,150 km2 of seismic acquisition on Blocks PM308A (WI 35%), PM308B (WI 75%) and SB303 (WI 75%) was completed in 2009. The seismic data processing and interpretation work has identified numerous drilling targets for the 2011/2012 drilling campaign. Five exploration wells will be drilled next year commencing in April 2011 and a jack up rig has been secured for this programme. In 2010 Lundin Petroleum signed a new Production Sharing Contract encompassing blocks SB307 & SB308 (WI 42.5%) offshore Sabah. A 330 km2 3D acquisition programme on blocks SB307 and SB308 was completed during the second quarter of 2010.
Exploration wells on the Hoa-Hong-X1 and Hoa Dao High prospects in Block 06/94 (WI 33.33%) were completed in 2010. Both wells were plugged and abandoned after either being dry or encountering uncommercial quantities of gas.
The net production to Lundin Petroleum from Russia for the period was 3,700 boepd.
In the Lagansky Block (WI 70%) in the northern Caspian a major oil discovery was made on the Morskaya field in 2008. The discovery due to its offshore location is deemed to be strategic by the Russian Government under the Foreign Strategic Investment Law. As a result a 50 percent ownership by a state owned company is required prior to development. Our work programme in 2010 on Lagansky is limited to the acquisition of 103 km2 of 3D seismic which has been substantially completed.
The net production to Lundin Petroleum from the Oudna field (WI 40%) was 1,100 boepd for the reporting period. The Oudna field production continues to outperform expectations.
An appraisal well on the Viodo discovery was completed in the fourth quarter of 2009 as an oil discovery. The results of the well are currently being reviewed with respect to the development potential of the Viodo field.
In Block Marine XIV (WI 21.55%) exploration drilling will commence during 2011 with the drilling of the Makouala prospect.
The net result including discontinued operations for the nine month period ended 30 September 2010 (reporting period) amounted to MUSD 412.1 (MUSD 5.4). The net result attributable to shareholders of the parent company including discontinued operations for the reporting period amounted to MUSD 421.8 (MUSD 10.5) representing earnings per share on a fully diluted basis of USD 1.35 (USD 0.03).
Lundin Petroleum reports a net result from continuing operations for the reporting period of MUSD 42.8 (MUSD 1.2). The net result attributable to shareholders of the parent company from continuing operations amounted to MUSD 52.5 (MUSD 6.3) representing earnings per share on a fully diluted basis of USD 0.17 (USD 0.02).
Operating cash flow including discontinued operations for the reporting period amounted to MUSD 441.7 (MUSD 359.6) representing operating cash flow per share on a fully diluted basis of USD 1.41 (USD 1.15). Earnings before interest, tax, depletion and amortisation (EBITDA) including discontinued operations for the reporting period amounted to MUSD 458.0 (MUSD 362.1) representing EBITDA per share on a fully diluted basis of USD 1.47 (USD 1.15).
During the first quarter of 2010, Lundin Petroleum announced its intention to spin-off the United Kingdom (UK) business. The spin-off was completed on 6 April 2010 with the sale of the UK business in exchange for shares in the newly incorporated company, EnQuest, and the subsequent distribution of the EnQuest shares received to Lundin Petroleum shareholders on 9 April 2010. The results of the UK business are included in the Lundin Petroleum accounts up until the end of the first quarter of 2010 and are shown as discontinued operations. For more detail refer to Note 8.
During the third quarter of 2010, Lundin Petroleum announced that it had signed a Sale and Purchase Agreement with RH Petrogas to sell its interests in the Salawati Basin and Salawati Island assets, Indonesia. The transaction was not completed as at 30 September 2010 and accordingly, the results from these assets are included for the reporting period. The assets and liabilities relating to Salawati Basin and Salawati Island have been classified as held for sale in the balance sheet as at 30 September 2010. For more detail refer to Note 11.
In October 2010, Lundin Petroleum announced its intention to distribute its shares in Etrion Corporation to the shareholders of Lundin Petroleum. The distribution is expected to be completed in November 2010. The results from Etrion are included for the reporting period and the assets and liabilities have been classified as held for distribution in the balance sheet as at 30 September 2010. For more detail refer to Note 11.
Production including discontinued operations for the reporting period amounted to 8,942.4 (10,524.8) thousand barrels of oil equivalent (Mboe) representing 32.8 Mboe per day (Mboepd) (38.6 Mboepd) and was comprised as follows:
| 1 Jan 2010- | 1 Jul 2010- | 1 Jan 2009- | 1 Jul 2009- | 1 Jan 2009- | |
|---|---|---|---|---|---|
| 30 Sep 2010 | 30 Sep 2010 | 30 Sep 2009 | 30 Sep 2009 | 31 Dec 2009 | |
| Production | 9 months | 3 months | 9 months | 3 months | 12 months |
| Norway | |||||
| - Quantity in Mboe | 4,755.7 | 1,838.2 | 3,749.4 | 1,316.0 | 5,060.9 |
| - Quantity in Mboepd | 17.4 | 20.0 | 13.7 | 14.3 | 13.9 |
| France | |||||
| - Quantity in Mboe | 864.2 | 296.1 | 942.5 | 314.6 | 1,249.2 |
| - Quantity in Mboepd | 3.2 | 3.2 | 3.5 | 3.4 | 3.4 |
| Netherlands | |||||
| - Quantity in Mboe | 565.3 | 176.2 | 580.6 | 175.2 | 759.3 |
| - Quantity in Mboepd | 2.1 | 1.9 | 2.1 | 1.9 | 2.1 |
| Indonesia | |||||
| - Quantity in Mboe | 636.9 | 234.1 | 678.3 | 211.9 | 896.3 |
| - Quantity in Mboepd | 2.3 | 2.5 | 2.5 | 2.3 | 2.4 |
| Russia | |||||
| - Quantity in Mboe | 1,019.2 | 319.1 | 1,484.1 | 494.7 | 1,890.0 |
| - Quantity in Mboepd | 3.7 | 3.5 | 5.4 | 5.4 | 5.2 |
| Tunisia | |||||
| - Quantity in Mboe | 288.9 | 90.6 | 389.4 | 126.0 | 494.9 |
| - Quantity in Mboepd | 1.1 | 1.0 | 1.4 | 1.4 | 1.4 |
| Total from continuing operations | |||||
| - Quantity in Mboe | 8,130.2 | 2,954.3 | 7,824.3 | 2,638.4 | 10,350.6 |
| - Quantity in Mboepd | 29.8 | 32.1 | 28.6 | 28.7 | 28.4 |
| Minority interest in Russia | |||||
| - Quantity in Mboe | - | - | 146.4 | 51.5 | 162.2 |
| - Quantity in Mboepd | - | - | 0.5 | 0.6 | 0.4 |
| Total from continuing operations | |||||
| excluding minority interest | |||||
| - Quantity in Mboe | 8,130.2 | 2,954.3 | 7,677.9 | 2,586.9 | 10,188.4 |
| - Quantity in Mboepd | 29.8 | 32.1 | 28.1 | 28.1 | 28.0 |
| Discontinued operations - United | |||||
| Kingdom | |||||
| - Quantity in Mboe | 812.2 | - | 2,846.9 | 887.4 | 3,743.3 |
| - Quantity in Mboepd | 3.0 | - | 10.5 | 9.6 | 10.2 |
| Total excluding minority interest | |||||
| - Quantity in Mboe | 8,942.4 | 2,954.3 | 10,524.8 | 3,474.3 | 13,931.7 |
| - Quantity in Mboepd | 32.8 | 32.1 | 38.6 | 37.7 | 38.2 |
In April 2010, the Volund field, offshore Norway commenced production and has contributed 3.8 Mboepd of the 17.4 Mboepd reported for Norway for the reporting period. Production from the Volund field averaged 7.1 Mboepd for the third quarter of 2010.
In 2009, Lundin Petroleum fully consolidated two subsidiaries in Russia over which it had control, with the portion not owned by Lundin Petroleum shown as a minority interest. The average production for Russia for the nine month period ended 30 September 2009 adjusted to Lundin Petroleum's share of ownership was 4.9 Mboepd. Lundin Petroleum sold the two controlled Russian subsidiaries during the second half of 2009.
Production quantities in a period can differ from sales quantities for a number of reasons. Timing differences can arise due to inventory, storage and pipeline balances effects. Other differences arise as a result of paying royalties in kind as well as the effects from production sharing agreements.
Net sales of oil and gas for the reporting period amounted to MUSD 549.0 (MUSD 414.8) and are detailed in Note 1. The average price achieved by Lundin Petroleum for a barrel of oil amounted to USD 70.19 (USD 53.93) and is detailed in the following table. The average Dated Brent price for the reporting period amounted to USD 77.14 (USD 57.32) per barrel.
Sales for the reporting period were comprised as follows:
| Sales Average price per boe expressed in USD |
1 Jan 2010- 30 Sep 2010 9 months |
1 Jul 2010- 30 Sep 2010 3 months |
1 Jan 2009- 30 Sep 2009 9 months |
1 Jul 2009- 30 Sep 2009 3 months |
1 Jan 2009- 31 Dec 2009 12 months |
|---|---|---|---|---|---|
| Norway | |||||
| - Quantity in Mboe | 4,742.1 | 1,700.2 | 3,888.1 | 1,434.4 | 5,200.1 |
| - Average price per boe | 75.33 | 75.38 | 57.17 | 64.08 | 60.48 |
| France | |||||
| - Quantity in Mboe | 878.5 | 287.9 | 965.9 | 313.8 | 1,277.9 |
| - Average price per boe | 76.33 | 75.53 | 56.74 | 67.01 | 60.94 |
| Netherlands | |||||
| - Quantity in Mboe | 565.3 | 176.2 | 580.6 | 175.2 | 759.3 |
| - Average price per boe | 42.28 | 48.19 | 51.31 | 41.06 | 50.49 |
| Indonesia | |||||
| - Quantity in Mboe | 330.2 | 103.2 | 470.1 | 191.1 | 609.4 |
| - Average price per boe | 63.83 | 51.96 | 57.86 | 66.84 | 60.58 |
| Russia | |||||
| - Quantity in Mboe | 999.5 | 320.0 | 1,583.5 | 489.3 | 1,976.4 |
| - Average price per boe | 50.21 | 51.97 | 34.86 | 44.70 | 37.64 |
| Tunisia | |||||
| - Quantity in Mboe | 382.6 | 187.0 | 465.5 | 204.1 | 465.5 |
| - Average price per boe | 77.15 | 75.98 | 54.72 | 65.21 | 54.72 |
| Total from continuing | |||||
| operations | |||||
| - Quantity in Mboe | 7,898.2 | 2,774.5 | 7,953.7 | 2,807.9 | 10,288.6 |
| - Average price per boe | 69.51 | 70.14 | 52.15 | 59.87 | 55.16 |
| Discontinued operations - | |||||
| United Kingdom | |||||
| - Quantity in Mboe | 814.4 | - | 2,737.6 | 982.9 | 3,630.8 |
| - Average price per boe | 76.82 | - | 59.10 | 69.09 | 62.83 |
| Total | |||||
| - Quantity in Mboe | 8,712.6 | 2,774.5 | 10,691.3 | 3,790.8 | 13,919.4 |
| - Average price per boe | 70.19 | 70.14 | 53.93 | 62.26 | 57.16 |
The oil produced in Russia is sold on either the Russian domestic market or exported into the international market. 40 percent (38 percent) of Russian sales for the reporting period were on the international market at an average price of USD 74.16 per barrel (USD 53.91 per barrel) with the remaining 60 percent (62 percent) of Russian sales being sold on the domestic market at an average price of USD 33.94 per barrel (USD 23.06 per barrel).
Other operating income amounted to MUSD 9.5 (MUSD 3.0) for the reporting period and includes MUSD 7.0 (MUSD -) of income relating to Etrion's solar business. Also included in other operating income is tariff income from France and the Netherlands and income for maintaining strategic inventory levels in France.
Oil and gas production costs for the reporting period amounted to MUSD 108.3 (MUSD 116.8) and are detailed in Note 2. The production and depletion costs per barrel of oil equivalent produced from continuing operations are detailed in the table below.
| Production cost and depletion | 1 Jan 2010- | 1 Jul 2010- | 1 Jan 2009- | 1 Jul 2009- | 1 Jan 2009- |
|---|---|---|---|---|---|
| in USD per boe | 30 Sep 2010 | 30 Sep 2010 | 30 Sep 2009 | 30 Sep 2009 | 31 Dec 2009 |
| 9 months | 3 months | 9 months | 3 months | 12 months | |
| Cost of operations | 8.18 | 7.55 | 8.37 | 8.88 | 9.22 |
| Tariff and transportation expenses | 1.45 | 1.65 | 1.52 | 1.28 | 1.52 |
| Royalty and direct taxes | 3.87 | 3.44 | 3.77 | 4.68 | 3.96 |
| Changes in inventory/overlift | -0.45 | -5.26 | 0.99 | 3.03 | 0.01 |
| Other | 0.21 | 0.18 | 0.29 | 0.30 | 0.30 |
| Total production costs | 13.26 | 7.56 | 14.94 | 18.17 | 15.01 |
| Depletion | 12.87 | 13.22 | 11.11 | 10.87 | 11.41 |
| Total cost per boe | 26.13 | 20.78 | 26.05 | 29.04 | 26.42 |
The cost of operations for the third quarter of 2010 amounted to USD 7.55 per barrel. The cost of operations in total for the third quarter of 2010 was consistent with previous quarters, but when applied over the higher production achieved in the quarter, the cost per barrel has decreased. The cost of operations for the third quarter of 2010 is significantly below guidance. The forecast included activities such as well intervention and various oneoff activities, some of which were not incurred.
The forecast cost of operations for the final quarter of 2010 is expected to increase to approximately USD 9.00 per barrel due to the phasing of certain expenditures.
The total tariff and transportation expenses have increased in the third quarter of 2010 compared to the previous quarter due to the contribution of a full quarter's production from the Volund field. The operating cost of the Volund field consists of an operating expense share and a tariff element. The operating expense of the Alvheim production facilities is shared between the Alvheim (WI 15%), Volund (WI 35%) and Vilje (WI -%) fields based on volume throughput. Lundin Petroleum has a 15 percent working interest in the Alvheim field and a 35 percent interest in the Volund field and the self-to-self element is eliminated for accounting purposes leaving a net 20 percent cost in tariff and transportation expenses.
Royalty and direct taxes includes Russian Mineral Resource Extraction Tax ("MRET") and Russian Export Duties. The rate of MRET varies in relation to world oil prices and is levied on the volume of Russian production. MRET averaged USD 13.45 (USD 9.45) per barrel of Russian production for the reporting period. The rate of export duty on Russian oil is revised by the Russian Federation monthly and is dependant on the average price obtained for Urals Blend for the preceding one month period. The export duty is levied on the volume of oil exported from Russia and averaged USD 37.14 (USD 19.61) per barrel for the reporting period. The royalty and direct taxes have increased compared to the comparative period following the rise in crude prices impacting the cost of Russian MRET and export duty.
There are both permanent and timing differences that result in sales volumes not being equal to production volumes during a period. Changes to the hydrocarbon inventory and under or overlift positions result from these timing differences and an amount of MUSD 3.7 (MUSD -7.8) was credited to the income statement for the reporting period. The change to the hydrocarbon inventory and under or overlift position in the third quarter of 2010 was a credit to production costs of MUSD 15.5 (MUSD -8.0) and primarily relates to a Norwegian underlift position at the end of the third quarter.
Depletion costs amounted to MUSD 107.0 (MUSD 87.0) and are detailed in Note 3. Depletion per barrel is in line with forecast for the reporting period and also for the full year. Norway contributes approximately 70 percent of the total depletion charge for the nine month period at a rate of USD 15.55 per barrel. The depletion charge for the comparative period includes MUSD 9.1 in respect of the Oudna field, Tunisia, which was fully depleted by the end of 2009.
Exploration costs for the reporting period amounted to MUSD 66.8 (MUSD 84.8) and are detailed in Note 4. Exploration and appraisal costs are capitalised as they are incurred. When exploration drilling is unsuccessful the costs are immediately charged to the income statement as exploration costs. All capitalised exploration costs are reviewed on a regular basis and are expensed where there is uncertainty regarding their recoverability.
During the third quarter of 2010, an unsuccessful exploration well was drilled on the Hoa Dao High prospect in Block 06/94, Vietnam and a total of MUSD 17.1 was expensed including associated seismic, study and licence costs.
During the first six months of 2010, Lundin Petroleum expensed MUSD 46.2 being the costs of the unsuccessful HH-1X well and associated seismic, study and licence costs on Block 06/94, Vietnam, the costs of the unsuccessful wells on licences PL359 and PL476 in Norway and the costs of the relinquished licences PL486s and PL487s in Norway.
General, administrative and depreciation expenses for the reporting period amounted to MUSD 27.4 (MUSD 12.7) and includes an amount of MUSD 10.9 (MUSD -) relating to Etrion. The general, administrative and depreciation expenses for the third quarter amounted to MUSD 13.3 (MUSD 4.6) of which MUSD 5.4 (MUSD -) related to Etrion and MUSD 3.8 (MUSD 0.4) to non-cash charges in relation to the Group's Long term Incentive Plan (LTIP) scheme.
Awards to employees under the Group's LTIP scheme are valued using the Black & Scholes calculation method using the share price as at the balance sheet date. The cost is accrued over the vesting period of the awards in accordance with accounting rules. During the third quarter of 2010, the Lundin Petroleum share price increased by over 60 percent compared to the share price at the end of the second quarter of 2010 and accordingly, the cost associated with the LTIP was reflected in the third quarter of 2010. The value of the LTIP award as calculated using the Black & Scholes valuation is applied to the vested portion of all outstanding LTIP awards including that of prior years and therefore the charge to the income statement in the third quarter of 2010 reflects the change in the provision to date.
Financial income for the reporting period amounted to MUSD 13.8 (MUSD 56.8) and is detailed in Note 5.
Foreign exchange gains in the reporting period amounted to MUSD 8.4.(MUSD 42.5). The US dollar weakened by 10 percent against the Euro in the third quarter of 2010 generating exchange gains on the US dollar denominated external debt which is borrowed by a subsidiary using a functional currency of the Euro. The Norwegian Kroner was stable against the Euro during the third quarter of 2010 resulting in no significant foreign exchange fluctuation on the Norwegian Kroner intercompany loan.
Interest income for the reporting period amounted to MUSD 1.9 (MUSD 3.3) with the comparative period including accrued interest on the Norwegian tax refund in respect of the 2008 exploration expenditure.
Included in the comparative period in gain on sale of shares was an amount of MUSD 10.2 relating to the sale of the shareholding in a company owning an interest in Dutch gas processing and transportation infrastructure.
Other financial income for the reporting period amounted to MUSD 3.1 (MUSD 0.7) and includes a MUSD 2.1 (MUSD -) fee for supporting certain financial obligations for ShaMaran Petroleum.
Financial expenses for the reporting period amounted to MUSD 25.1 (MUSD 43.8) and are detailed in Note 6.
Interest expenses for the reporting period amounted to MUSD 6.3 (MUSD 5.6) and relates mainly to interest on the Group's bank loan facility and a charge of MUSD 2.2 (MUSD -) relating to Etrion's loan facilities.
In January 2008, the Group entered into an interest rate hedging contract to fix the LIBOR rate of interest at 3.75 percent p.a. on MUSD 200 of the Group's USD borrowings for the period from January 2008 until January 2012. An amount of MUSD 5.2 (MUSD 4.0) was charged to the income statement for the reporting period for settlements under the hedging contracts.
In November 2009, Etrion entered into an interest rate swap arrangement as part of an external loan agreement. A change in the market value of this swap arrangement amounted to an expense of MUSD 3.8 (MUSD -) for the reporting period.
A provision for the costs of site restoration is recorded in the balance sheet at the discounted value of the estimated future cost. The effect of the discount is unwound each year and charged to the income statement. An amount of MUSD 3.0 (MUSD 1.8) has been charged to the income statement for the reporting period. The increase versus the comparative period is due to increased liabilities following the inclusion of the Volund field, Norway and other cost revisions reflected at the end of 2009.
Included in other financial expenses in the comparative period is an amount of MUSD 29.8 relating to the write down of the investment in Etrion following Etrion's write down of its Venezuelan oil and gas assets.
The result from share in associated company for the comparative reporting period amounted to MUSD -24.9 and consisted of the 44.81 percent equity share of the result of Etrion owned by Lundin Petroleum. The results of Etrion have been fully consolidated into the Lundin Petroleum consolidated accounts from 30 September 2009 and as such, there is no amount recorded for 2010 in the result from share in associated company.
Included in the MUSD -24.9 for the comparative period is an amount of MUSD 22.8 relating to the write down of Etrion's Venezuelan oil and gas assets.
The tax charge for the reporting period amounted to MUSD 195.6 (MUSD 92.1) and is detailed in Note 7.
The current tax charge on continuing operations for the reporting period amounted to MUSD 33.7 (MUSD 9.1). The current tax charge comprises of tax charges in Norway, France, the Netherlands, Indonesia and Tunisia. There is a MUSD 14.6 (MUSD -9.5) accrued current tax payable in respect of Norway operations based on the forecast taxable income for the full year 2010 which shows that in respect of the 28 percent onshore tax regime, the losses brought forward have been utilised. The Norwegian current tax credit in 2009 of MUSD 9.5 arose from a combination of the low oil price achieved and the high exploration and capital expenditure incurred. These two factors created a situation whereby Lundin Petroleum was anticipating a cash tax refund under the Norwegian tax system at the end of the third quarter 2009, however by the year end as a result of the very good performance of the Alvheim field and higher oil prices achieved, no tax refund was due.
The deferred tax charge amounted to MUSD 161.9 (MUSD 82.9) for the reporting period with the increase versus the comparative period due to the higher profit achieved in 2010 driven by the higher oil prices and production from continuing operations.
The Group operates in various countries and fiscal regimes where corporate income tax rates are different from the regulations in Sweden. Corporate income tax rates for the Group vary between 20 percent and 78 percent. The effective tax rate for the Group for the reporting period amounts to 82 percent. This effective rate is the amount calculated from the face of the income statement and does not reflect the effective rate of tax paid within each country of operation. The main contributor to the tax charge is Norway with an effective tax rate of 74 percent. Reported losses in non-operating entities, with zero or low tax credits recorded, increase the effective rate. The effective rate of cash tax payable is 14 percent because tax loss carry forwards and exploration expenditure continue to provide a tax deduction in Norway.
The net result attributable to minority interest for the reporting period amounted to MUSD -9.6 (MUSD -5.1) and mainly relates to the minority interest's share in Etrion which is fully consolidated.
The net result from discontinued operations for the reporting period amounted to MUSD 369.3 (MUSD -) and relates to the net result of MUSD 10.9 (MUSD -) for the United Kingdom up to 6 April 2010, the date of the UK spin-off, and the subsequent gain on the sale of the UK assets of MUSD 358.4 (MUSD -). For more detail refer to Note 8.
During the third quarter of 2010, Lundin Petroleum signed a Sale and Purchase agreement to sell its interests in the Salawati Basin and Salawati Island assets, Indonesia. Furthermore in October 2010, Lundin Petroleum announced its intention to distribute its shares in Etrion Corporation to the shareholders of Lundin Petroleum. Consequently, related assets and liabilities relating to the Salawati assets and the Etrion group as at 30 September 2010 are classified as held for sale/distribution. None of these assets are considered to represent a major line of business to the Group and are therefore not considered to be discontinued operations. For more detail refer to Note 11.
Oil and gas properties amounted to MUSD 1,959.9 (MUSD 2,540.3) and are detailed in Note 9.
Development and exploration expenditure incurred for the reporting period was as follows:
| Development expenditure | 1 Jan 2010- 30 Sep 2010 |
1 Jul 2010- 30 Sep 2010 |
1 Jan 2009- 30 Sep 2009 |
1 Jul 2009- 30 Sep 2009 |
1 Jan 2009- 31 Dec 2009 |
|---|---|---|---|---|---|
| in MUSD | 9 months | 3 months | 9 months | 3 months | 12 months |
| Norway | 85.9 | 23.6 | 60.9 | 13.8 | 88.1 |
| France | 9.1 | 1.7 | 3.3 | 1.3 | 6.3 |
| Netherlands | 3.6 | 1.5 | 3.1 | 0.4 | 5.3 |
| Indonesia | 8.4 | 0.3 | 28.9 | 8.2 | 34.9 |
| Russia | 5.5 | 1.8 | 7.6 | 3.1 | 10.1 |
| Development expenditures | 112.5 | 28.9 | 103.8 | 26.8 | 144.7 |
| from continuing operations | |||||
| Discontinued operations - | |||||
| United Kingdom | 17.1 | - | 55.6 | 19.3 | 63.5 |
| Development expenditures | 129.6 | 28.9 | 159.4 | 46.1 | 208.2 |
| Exploration expenditure | 1 Jan 2010- | 1 Jul 2010- | 1 Jan 2009- | 1 Jul 2009- | 1 Jan 2009- |
|---|---|---|---|---|---|
| 30 Sep 2010 | 30 Sep 2010 | 30 Sep 2009 | 30 Sep 2009 | 31 Dec 2009 | |
| in MUSD | 9 months | 3 months | 9 months | 3 months | 12 months |
| Norway | 70.0 | 40.2 | 151.1 | 55.7 | 198.5 |
| France | 0.6 | 0.3 | 2.6 | 0.2 | 3.1 |
| Indonesia | 10.5 | 2.5 | 6.7 | 1.2 | 9.7 |
| Russia | 14.0 | 3.3 | 24.9 | 12.0 | 45.2 |
| Vietnam | 15.6 | 6.6 | 8.4 | 1.3 | 9.2 |
| Congo (Brazzaville) | 1.7 | 0.4 | 8.0 | 3.6 | 13.8 |
| Malaysia | 6.8 | 2.1 | 13.8 | 6.6 | 23.9 |
| Other | 3.9 | 3.6 | 2.5 | 0.4 | 4.7 |
| Exploration expenditures | 123.1 | 59.0 | 218.0 | 81.0 | |
| from continuing operations | 308.1 | ||||
| Discontinued operations - | |||||
| United Kingdom | 0.2 | - | 1.8 | 0.7 | 2.3 |
| Exploration expenditures | 123.3 | 59.0 | 219.8 | 81.7 | 310.4 |
Other tangible assets amounted to MUSD 14.2 (MUSD 15.3) and represents office fixed assets and real estate.
Financial assets amounted to MUSD 142.5 (MUSD 85.4) and are detailed in Note 10. Other shares and participations amounted to MUSD 29.5 (MUSD 32.4) and primarily relate to the shares held in ShaMaran Petroleum. Long-term receivables amounted to MUSD 90.4 (MUSD 24.2) and relates to the loan receivable from Etrion of MUSD 66.6 (MUSD -) and the convertible loan provided to Africa Oil Corporation for MUSD 23.8 (MUSD 23.8). Other financial assets amounted to MUSD 17.2 (MUSD 21.1) and mainly represents VAT paid on costs in Russia that is expected to be recovered amounting to MUSD 16.0 (MUSD 17.5).
The deferred tax asset amounted to MUSD 20.5 (MUSD 27.9) and mainly relates to unutilised tax losses in the Netherlands.
Assets held for sale/distribution amounted to MUSD 213.8 (MUSD -) and are detailed in Note 11. The amount relates to the assets of the Etrion group, Salawati Basin and Salawati Island.
Receivables and inventories amounted to MUSD 133.5 (MUSD 198.0) and are detailed in Note 12. Inventories include hydrocarbons and consumable well supplies and amounted to MUSD 15.0 (MUSD 27.4). The main reduction in value is due to the reclassification of Salawati Basin and Island inventories amounting to MUSD 8.1 to assets held for sale. Trade receivables amounted to MUSD 72.3 (MUSD 80.7) and include MUSD 49.3 (MUSD 21.4) of Norway trade receivables following the commencement of Volund field sales in the second quarter of 2010. The short-term loan receivable of MUSD 5.5 (MUSD 33.9) mainly relates to the deferred working capital to be paid by EnQuest following the UK spin-off amounting to MUSD 4.8 (MUSD -). The comparative period includes a MUSD 30.0 advance in relation to the acquisition of the 30 percent interest in the Lagansky Block to the minority partner. This transaction was successfully completed during the third quarter of 2010.
Cash and cash equivalents amounted to MUSD 53.5 (MUSD 77.3). Included in cash and cash equivalents at 31 December 2009 is an amount of MUSD 23.4 held by Etrion. Cash balances are held to meet operational and investment requirements.
Provisions amounted to MUSD 734.4 (MUSD 897.6) and are detailed in Note 13. This amount includes a provision for site restoration of MUSD 80.3 (MUSD 132.7). The decrease of the site restoration provision from the comparative period is mainly due to the UK business spin-off and consequent removal of the United Kingdom liability amount of MUSD 53.7.
The provision for deferred taxes amounted to MUSD 639.1 (MUSD 743.6) and is arising on the excess of book value over the tax value of oil and gas properties net of deferred tax assets which are netted off against deferred tax liabilities in accordance with IFRS where they relate to the same jurisdiction. The deferred tax provision has decreased from the comparative period mainly due to the UK business spin-off and consequent removal of the United Kingdom liability amount of MUSD 255.6, partly offset by the utilisation of tax losses in Norway.
The provision for derivative instruments amounted to MUSD 1.6 (MUSD 3.1) relates to the long term portion of the fair value of the interest rate swap entered into in January 2008 in relation to the Company's MUSD 850 credit facility.
Other provisions amounted to MUSD 12.1 (MUSD 16.8) and mainly relate to the LTIP scheme and termination indemnity provisions in Tunisia. The comparative period includes an exchange obligation of Etrion amounting to MUSD 5.7 which is now part of the liabilities held for distribution.
Long term interest bearing debt amounted to MUSD 535.0 (MUSD 545.7) and relates to the Group's financing facility consisting of a MUSD 850 revolving borrowing base and letter of credit facility with a seven year term expiring in 2014.
Liabilities held for sale/distribution amounted to MUSD 183.1 (MUSD -) and are detailed in Note 11. The amount relates to the liabilities of the Etrion group, Salawati Basin and Salawati Island.
Other current liabilities amounted to MUSD 130.6 (MUSD 257.5) and are detailed in Note 14. Joint venture creditors amounted to MUSD 83.3 (MUSD 140.0) and relate to ongoing operational costs. Short-term loans amounted to 0.7 (MUSD 32.4). The comparative relates mainly to the advance received in relation to the agreement with a subsidiary of Gunvor International BV to acquire a 30 percent interest in the Lagansky Block for an amount of MUSD 30.0. This transaction was successfully completed during the third quarter of 2010. Tax payables amounted to MUSD 13.9 (MUSD 20.9) with the movement in the period mainly due a payment of tax due in Tunisia in the third quarter of 2010. The short term portion of the fair value of the interest rate swap entered into in January 2008 is included in current liabilities and amounted to MUSD 6.9 (MUSD 7.1).
On 9 April 2010, Lundin Petroleum made a distribution of the EnQuest shares received in consideration for the sale of the UK business in a ratio of 1.3473 shares in EnQuest for each Lundin Petroleum share held. The distribution was valued at the market price of the shares at the time of the distribution and amounted to MUSD 656.3. The value of the distribution is charged against shareholders equity.
On 1 July 2010, Lundin Petroleum purchased 637,336 of its own shares, bringing the total amount of owned shares to 6,882,638.
The business of the parent company is investment in and management of oil and gas assets. The net result for the parent company amounted to MSEK 3,967.0 (MSEK -4.8) for the reporting period.
The result includes a dividend received from a subsidiary of MSEK 3,995.7 (MSEK -), financial income of MSEK 15.3 (MSEK -) for supporting certain financial obligations for ShaMaran Petroleum and accrued interest expense of MSEK 28.0 (MSEK -) on a MSEK 3,951.0 promissory note made to a subsidiary in relation to the UK business spinoff to EnQuest. The promissory note was cancelled on 1 July following the dividend distribution by a subsidiary. There is a tax credit of MSEK 7.3 resulting from an adjustment to the prior year tax accrual.
In October 2010, Lundin Petroleum announced its intention to distribute its shares in Etrion Corporation to its shareholders. The distribution is expected to be completed in November 2010.
Lundin Petroleum has a secured revolving borrowing base facility of MUSD 850, of which MUSD 535.0 has been drawn in cash as at 30 September 2010. The MUSD 850 facility is a revolving borrowing base facility secured against certain cash flows generated by the Group. The amount available under the facility is recalculated every six months based upon the calculated cash flow generated by certain producing fields at an oil price and economic assumptions agreed with the banking syndicate providing the facility. Following the disposal of the UK business, a new borrowing base redetermination was undertaken and an amount of approximately USD 850 million, effective 1 July 2010, was approved unanimously by the loan syndicate banks.
Lundin Petroleum has, through its subsidiary Lundin Malaysia BV, entered into four Production Sharing Contracts (PSC) with Petroliam Nasional Berhad, the oil and gas company of the Government of Malaysia ("Petronas"), in respect of the licenses PM308A, PM308B, SB307 and SB308, and SB303, in Malaysia. BNP Paribas, on behalf of Lundin Malaysia BV has issued bank guarantees in support of the work commitments in relation to these PSCs amounting to MUSD 87.7. In addition, BNP Paribas have issued additional bank guarantees to cover work commitments in Indonesia amounting to MUSD 15.0.
Lundin Petroleum AB's issued share capital as at 30 September 2010 amounted to SEK 3,179,106 represented by 317,910,580 shares with a quota value of SEK 0.01 each.
Under the authorisation of the Board granted at the AGM held on 6 May 2010, Lundin Petroleum purchased 637,336 of its own shares during the third quarter of 2010. As at 30 September 2010, Lundin Petroleum held 6,882,638 of its own shares.
In 2008, Lundin Petroleum implemented a LTIP scheme consisting of a Unit Bonus Plan which provides for an annual grant of units that will lead to a cash payment at vesting. The LTIP will be payable over a period of three years from award. The cash payment will be determined at the end of each vesting period by multiplying the number of units then vested by the share price. The share price for determining the cash payment at the end of each vesting period will be the 5 trading day average closing Lundin Petroleum share price prior to and following the actual vesting date.
The AGM held on 13 May 2009 approved the 2009 LTIP and divided it into one plan for certain senior management (being the President and Chief Executive Officer, the Chief Operating Officer, the Chief Financial Officer and the Senior Vice President Operations) and one plan for certain other employees.
On 9 April 2010, Lundin Petroleum distributed the shares of EnQuest that it had received in consideration for the sale of the UK business. Under the rules of the various LTIPs the distribution triggered a recalculation of the number of units allocated and the strike price at which the options are exercisable.
The LTIP for senior executives includes 5,411,314 phantom options with an exercise price of SEK 53.79 (rebased from 4,000,000 phantom options and SEK 72.76 respectively following the distribution of the EnQuest shares). The phantom options will vest in May 2014 being the fifth anniversary of the date of grant. The recipients will be entitled to receive a cash payment equal to the average closing price of the Company's shares during the fifth year following grant, less the exercise price.
The number of units relating to the 2008 and 2009 LTIP schemes outstanding as at 30 September 2010 were 213,610 and 443,615 respectively.
The AGM held on 6 May 2010 awarded 722,450 units to employees under the 2010 LTIP scheme and this number of units remain outstanding as at 30 September 2010.
The financial statements of the Group have been prepared in accordance with International Accounting Standard (IAS) 34, Interim Reporting, and the Swedish Annual Accounts Act (1995:1554). The accounting policies adopted are consistent with those followed in the preparation of the Group's annual financial statements for the year ended 31 December 2009.
The financial statements of the parent company are prepared in accordance with accounting principles generally accepted in Sweden, applying RFR 2.3.
IAS 21 states that a company may present its financial statements in any currency. The generally accepted currency of the oil industry is United States dollars (USD) and as such the Board of Directors of Lundin Petroleum has resolved that Lundin Petroleum will present its financial statements in USD with effect from 1 January 2010. The Board believes that presenting the financial statements in this currency will further assist readers in understanding the underlying financial position of the company and its results. As a consequence the comparative figures are translated into USD whereby assets and liabilities are translated at the closing rate at the date of that balance sheet and income and expenses are translated at the exchange rates at the dates of the transactions. Equity is translated against historical rates.
For comparative purposes, historical income statements and balance sheets have been presented in USD on the Company's website www.lundin-petroleum.com.
Under Swedish company regulations it is not allowed to report the parent company results in any other currency than SEK and consequently the parent company financial statements are still reported in SEK and not in USD.
The major risk the Group faces is the nature of oil and gas exploration and production itself. Oil and gas exploration, development and production involve high operational and financial risks, which even a combination of experience, knowledge and careful evaluation may not be able to fully eliminate or which are beyond the Company's control. Lundin Petroleum's long-term commercial success depends on its ability to find, acquire, develop and commercially produce oil and natural gas reserves. A future increase in Lundin Petroleum's reserves will depend not only on its ability to explore and develop any properties that Lundin Petroleum may have from time to time, but also on its ability to select and acquire suitable producing properties or prospects. In addition, there is no assurance that commercial quantities of oil and gas will be discovered or acquired by Lundin Petroleum.
The Group faces a number of risks and uncertainties in the areas of operation which may have an adverse impact on its ability to successfully pursue its exploration, appraisal and development plans as well as on its production of oil and gas. A more detailed analysis of the operational risks faced by Lundin Petroleum is given in the Company's annual report for 2009.
Lundin Petroleum is, and will be, actively engaged in oil and gas operations in various countries. Lundin Petroleum's exploration, development and production activities may be subject to political and economic uncertainties, expropriation of property and cancellation or modification of contract rights, taxation, royalties, duties, foreign exchange restrictions and other risks arising out of foreign governmental sovereignty over the areas in which Lundin Petroleum's operations are conducted, as well as risks of loss in some countries due to civil strife, acts of war, guerrilla activities and insurrection. Further, certain aspects of Lundin Petroleum's exploration and production programmes require the consent or favourable decisions of governmental bodies.
As an international oil and gas exploration and production company operating globally, Lundin Petroleum is exposed to financial risks such as fluctuations in oil price, currency rates, interest rates as well as liquidity and credit risks. The Company shall seek to control these risks through sound management practice and the use of internationally accepted financial instruments, such as oil price, currency and interest rate hedges. Lundin Petroleum uses financial instruments solely for the purpose of minimising risks in the Company's business. A more detailed analysis of the financial risks faced by Lundin Petroleum and how it addresses these risks is given in the Company's annual report for 2009.
The Group entered into an interest hedging contract on 8 January 2008, fixing the LIBOR rate of interest at 3.75 percent p.a. on MUSD 200 of the Group's USD borrowings for the period January 2008 to January 2012. The interest rate contract relates to the current credit facility. Under IAS 39, the interest rate contract is effective and qualifies for hedge accounting. Changes in fair value of this contract are charged directly to equity. As at 30 September 2010, a provision has been recognised in the balance sheet amounting to MUSD 1.6 (MUSD 3.1), representing the long-term portion of the fair value of the outstanding part of the interest rate contract and a current liability in the balance sheet amounting to MUSD 6.9 (MUSD 6.4) representing the short-term portion of the fair value of the outstanding part of the interest rate contract.
For the preparation of the financial statements for the reporting period, the following currency exchange rates have been used.
| Average | Period end | ||
|---|---|---|---|
| 1 USD equals NOK | 6.0724 | 5.8382 | |
| 1 USD equals Euro | 0.7599 | 0.7327 | |
| 1 USD equals Rouble | 30.2364 | 30.5483 | |
| 1 USD equals SEK | 7.3381 | 6.6985 |
| 1 Jan 2010- | 1 Jul 2010- | 1 Jan 2009- | 1 Jul 2009- | 1 Jan 2009- | ||
|---|---|---|---|---|---|---|
| 30 Sep 2010 | 30 Sep 2010 | 30 Sep 2009 | 30 Sep 2009 | 31 Dec 2009 | ||
| Expressed in TUSD | Note | 9 months | 3 months | 9 months | 3 months | 12 months |
| Continuing operations | ||||||
| Operating income | ||||||
| Net sales of oil and gas | 1 | 548,965 | 194,590 | 414,775 | 168,103 | 567,488 |
| Other operating income | 9,541 | 7,737 | 3,021 | 1,016 | 4,347 | |
| 558,506 | 202,327 | 417,796 | 169,119 | 571,835 | ||
| Cost of sales | ||||||
| Production costs | 2 | -108,330 | -22,860 | -116,845 | -47,942 | -155,311 |
| Depletion costs Exploration costs |
3 4 |
-106,964 -66,847 |
-41,342 -20,674 |
-86,951 -84,819 |
-28,666 -43,603 |
-118,128 -134,792 |
| Impairment costs for oil and gas | ||||||
| properties | - | - | - | - | -525,719 | |
| Impairment costs for Goodwill | - | - | - | - | -119,047 | |
| Gross profit | 276,365 | 117,451 | 129,181 | 48,908 | -481,162 | |
| Gain on sale of assets | - | - | -11,899 | -11,899 | 4,589 | |
| Other income | 747 | 319 | 638 | 103 | 1,222 | |
| General, administration and | ||||||
| depreciation expenses | -27,437 | -13,260 | -12,726 | -4,601 | -28,841 | |
| Operating profit | 249,675 | 104,510 | 105,194 | 32,511 | -504,192 | |
| Result from financial | ||||||
| investments | ||||||
| Financial income Financial expenses |
5 6 |
13,839 -25,073 |
9,848 -8,953 |
56,756 -43,753 |
38,546 -34,200 |
82,031 -52,472 |
| -11,234 | 895 | 13,003 | 4,346 | 29,559 | ||
| Result from share in associated company |
- | - | -24,920 | -23,351 | -25,504 | |
| Profit before tax | 238,441 | 105,405 | 93,277 | 13,506 | -500,137 | |
| Tax | 7 | -195,594 | -83,368 | -92,052 | -30,143 | -45,669 |
| Net result from continuing operations |
42,847 | 22,037 | 1,225 | -16,637 | -545,806 | |
| Discontinued operations | ||||||
| Net result from discontinued operations |
8 | 369,275 | - | 4,223 | 3,174 | 8,737 |
| Net result | 412,122 | 22,037 | 5,448 | -13,463 | -537,069 | |
| Net result attributable to the shareholders of the parent |
||||||
| company: | ||||||
| From continuing operations | 52,487 | 26,569 | 6,302 | -16,078 | -420,005 | |
| From discontinued operations | 369,275 | - | 4,223 | 3,174 | 8,737 | |
| 421,762 | 26,569 | 10,525 | -12,904 | -411,268 | ||
| Net result attributable to | ||||||
| Minority interest: | ||||||
| From continuing operations | -9,640 | -4,532 | -5,077 | -559 | -125,801 | |
| From discontinued operations | - | - | - | - | - | |
| -9,640 | -4,532 | -5,077 | -559 | -125,801 | ||
| Net result | 412,122 | 22,037 | 5,448 | -13,463 | -537,069 | |
| Earnings per share – USD 1 | ||||||
| From continuing operations | 0.17 | 0.09 | 0.02 | -0.05 | -1.34 | |
| From discontinued operations | 1.18 | - | 0.01 | 0.01 | 0.03 | |
| 1.35 | 0.09 | 0.03 | -0.04 | -1.31 | ||
| Diluted earnings per share – | ||||||
| USD 1 | ||||||
| From continuing operations | 0.17 | 0.09 | 0.02 | -0.05 | -1.34 | |
| From discontinued operations | 1.18 | - | 0.01 | 0.01 | 0.03 | |
| 1.35 | 0.09 | 0.03 | -0.04 | -1.31 |
1 Based on net result attributable to shareholders of the parent company.
| Expressed in TUSD | 1 Jan 2010- 30 Sep 2010 9 months |
1 Jul 2010- 30 Sep 2010 3 months |
1 Jan 2009- 30 Sep 2009 9 months |
1 Jul 2009- 30 Sep 2009 3 months |
1 Jan 2009- 31 Dec 2009 12 months |
|---|---|---|---|---|---|
| Net result | 412,122 | 22,037 | 5,448 | -13,463 | -537,069 |
| Other comprehensive income | |||||
| Exchange differences foreign operations | -42,771 | 61,106 | 65,772 | 42,727 | 74,763 |
| Cash flow hedges | -1,595 | -591 | 40,833 | 2,006 | 47,583 |
| Available-for-sale financial assets | 13,437 | 7,254 | -11,378 | -10,632 | -19,158 |
| Income tax relating to other | |||||
| comprehensive income | -1,942 | -1,699 | -18,570 | -1,045 | -19,064 |
| Other comprehensive income, net of tax | -32,871 | 66,070 | 76,657 | 33,056 | 84,124 |
| Total comprehensive income | 379,251 | 88,107 | 82,105 | 19,593 | -452,945 |
| Total comprehensive income attributable to: |
|||||
| Shareholders of the parent company | 389,654 | 91,708 | 96,900 | 19,577 | -317,291 |
| Minority interest | -10,403 | -3,601 | -14,795 | 16 | -135,654 |
| 379,251 | 88,107 | 82,105 | 19,593 | -452,945 |
| 30 September | 31 December | ||
|---|---|---|---|
| Expressed in TUSD | Note | 2010 | 2009 |
| ASSETS | |||
| Non-current assets | |||
| Oil and gas properties | 9 | 1,959,916 | 2,540,348 |
| Solar power properties | - | 644 | |
| Other tangible assets | 14,185 | 15,283 | |
| Goodwill | - | 674 | |
| Other intangible assets | - | 5,132 | |
| Financial assets | 10 | 142,532 | 85,437 |
| Deferred tax | 20,546 | 27,850 | |
| Total non-current assets | 2,137,179 | 2,675,368 | |
| Current assets | |||
| Assets held for sale / distribution | 11 | 213,838 | - |
| Receivables and inventories | 12 | 133,531 | 197,952 |
| Cash and cash equivalents | 53,545 | 77,338 | |
| Total current assets | 400,914 | 275,290 | |
| TOTAL ASSETS | 2,538,093 | 2,950,658 | |
| EQUITY AND LIABILITIES | |||
| Equity | |||
| Shareholders´ equity | 858,096 | 1,141,658 | |
| Minority interest | 80,706 | 95,555 | |
| Total equity | 938,802 | 1,237,213 | |
| Non-current liabilities | |||
| Provisions | 13 | 734,440 | 897,622 |
| Bank loans | 534,970 | 545,729 | |
| Other non-current liabilities | 16,215 | 12,598 | |
| Total non-current liabilities | 1,285,625 | 1,455,949 | |
| Current liabilities | |||
| Liabilities held for sale / distribution | 11 | 183,092 | - |
| Other current liabilities | 14 | 130,574 | 257,496 |
| Total current liabilities | 313,666 | 257,496 | |
| TOTAL EQUITY AND LIABILITIES | 2,538,093 | 2,950,658 | |
| Pledged assets | 450,966 | 699,506 | |
| Contingent liabilities | - | - |
| Expressed in TUSD | 1 Jan 2010- 30 Sep 2010 9 months |
1 Jul 2010- 30 Sep 2010 3 months |
1 Jan 2009- 30 Sep 2009 9 months |
1 Jul 2009- 30 Sep 2009 3 months |
1 Jan 2009- 31 Dec 2009 12 months |
|---|---|---|---|---|---|
| Cash flow from operations | |||||
| Net result | 412,122 | 22,037 | 5,448 | -13,463 | -537,069 |
| Gain on sale of discontinued operations | -358,353 | - | - | - | - |
| Adjustments for non-cash related items | 408,339 | 153,309 | 353,717 | 156,161 | 1,005,388 |
| Interest received | 362 | 68 | 2,500 | 774 | 3,381 |
| Interest paid | -3,295 | -2,828 | -7,110 | -2,012 | -6,309 |
| Income taxes paid | -20,788 | -10,405 | -13,678 | 1,927 | -26,305 |
| Changes in working capital | -52,351 | 3,486 | -27,133 | 50,053 | 50,512 |
| Total cash flow from operations | 386,036 | 165,667 | 313,744 | 193,440 | 489,598 |
| Cash flow used for investments | |||||
| Investment in subsidiary assets | -8,183 | 450 | - | - | 26,489 |
| Investment in associated companies | 225 | - | - | - | - |
| Sale of other shares and participations | 446 | -32 | 12,285 | 12,285 | 12,285 |
| Change in other financial fixed assets | -4 | -251 | -139 | -80 | -194 |
| Other payments | -1,521 | -243 | -2,023 | -102 | -2,050 |
| Divestment | -25,003 | - | -888 | - | - |
| Investment in intangible fixed assets | -205 | -21 | - | - | -2,161 |
| Investment in oil and gas properties | -253,608 | -87,887 | -375,115 | -123,588 | -514,313 |
| Investment in solar power properties | -19,397 | -10,087 | - | - | -644 |
| Investment in office equipment and other assets | -3,132 | -673 | -1,721 | -528 | -2,391 |
| Total cash flow used for investments | -310,382 | -98,744 | -367,601 | -112,013 | -482,979 |
| Cash flow used for/from for financing | |||||
| Changes in long-term receivables | -66,637 | -66,637 | - | - | - |
| Changes in long-term liabilities | 13,986 | 2,968 | 41,112 | -105,112 | 4,750 |
| Paid financing fees | -51 | - | -79 | - | -97 |
| Purchase of own shares | -10,712 | -2,823 | - | - | - |
| Proceeds from share issuance subsidiary company | 15,191 | 15,191 | - | - | - |
| Dividend paid to minority | - | - | -46 | - | -46 |
| Total cash flow used for/from financing | -48,223 | -51,301 | 40,987 | -105,112 | 4,607 |
| Change in cash and cash equivalents Cash and cash equivalents at the beginning of the |
27,431 | 15,622 | -12,870 | -23,685 | 11,226 |
| period | 77,338 | 89,874 | 57,445 | 74,214 | 57,445 |
| Acquired on consolidation | - | - | 26,970 | 26,970 | - |
| Cash held for sale / distribution Currency exchange difference in cash and cash |
-50,074 | -50,074 | - | - | - |
| equivalents | -1,150 | -1,877 | 8,288 | 2,334 | 8,667 |
| Cash and cash equivalents at the end of the period |
53,545 | 53,545 | 79,833 | 79,833 | 77,338 |
| Total cash flow from operations | |||||
| From continuing operations | 709,029 | 165,667 | 259,714 | 116,750 | 433,227 |
| Used for/from discontinued operations | -322,993 | - | 54,030 | 76,690 | 56,371 |
| 386,036 | 165,667 | 313,744 | 193,440 | 489,598 | |
| Total cash flow used for investments | |||||
| Used for continuing operations | -267,996 | -98,744 | -310,088 | -92,003 | -416,853 |
| Used for discontinued operations | -42,386 | - | -57,513 | -20,010 | -66,126 |
| -310,382 | -98,744 | -367,601 | -112,013 | -482,979 | |
| Total cash flow used for/from investments | |||||
| From/used for continuing operations | -48,223 | -51,301 | 55,987 | -85,112 | 19,607 |
| From/used for discontinued operations | - | - | -15,000 | -20,000 | -15,000 |
| -48,223 | -51,301 | 40,987 | -105,112 | 4,607 |
| Additional | ||||||
|---|---|---|---|---|---|---|
| paid-in | ||||||
| Expressed in TUSD | Share | capital/ Other | Retained | Minority | ||
| capital | reserves | earnings | Net result | interest | Total equity | |
| Balance at 1 January 2009 | 463 | 754,104 | 613,917 | 93,958 | 179,793 | 1,642,235 |
| Transfer of prior year net result | - | - | 93,958 | -93,958 | - | - |
| Total comprehensive income | - | 85,471 | 903 | 10,526 | -14,795 | 82,105 |
| Acquired on consolidation | - | 14,970 | 6,225 | - | 18,547 | 39,742 |
| Divestments | - | -12,910 | - | - | 17,966 | 5,056 |
| Transfer of share based payments | - | 4,421 | -4,421 | - | - | - |
| Share based payments | - | - | 23 | - | - | 23 |
| Minority share in dividend paid | - | - | - | - | -46 | -46 |
| Balance at 30 September 2009 | 463 | 846,056 | 710,605 | 10,526 | 201,465 | 1,769,115 |
| Total comprehensive income | - | 7,758 | -155 | -421,794 | -120,859 | -535,050 |
| Acquired on consolidation | - | -71 | - | - | 223 | 152 |
| Divestments | - | -13,285 | - | - | 14,726 | 1,441 |
| Transfer of share based payments | - | -80 | 80 | - | - | - |
| Share based payments | - | - | 1,555 | - | - | 1,555 |
| Balance at 31 December 2009 | 463 | 840,378 | 712,085 | -411,268 | 95,555 | 1,237,213 |
| Transfer of prior year net result | - | - | -411,268 | 411,268 | - | - |
| Total comprehensive income | - | -32,365 | 256 | 421,763 | -10,403 | 379,251 |
| Acquired on consolidation | - | - | - | - | 97 | 97 |
| Distributions | - | -358,049 | -298,288 | - | - | -656,337 |
| Purchase of own shares | - | -10,714 | - | - | - | -10,714 |
| Held for sale / distribution | - | 1,587 | -10,195 | - | -4,543 | -13,151 |
| Transfer of share based payments | - | 4,386 | -4,386 | - | - | - |
| Share based payments | - | - | 2,443 | - | - | 2,443 |
| Balance at 30 September 2010 | 463 | 445,223 | -9,353 | 421,763 | 80,706 | 938,802 |
| NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS | ||||
|---|---|---|---|---|
| -- | -- | ------------------------------------------------ | -- | -- |
| Note 1. Segment information, | 1 Jan 2010- 30 Sep 2010 |
1 Jul 2010- 30 Sep 2010 |
1 Jan 2009- 30 Sep 2009 |
1 Jul 2009- 30 Sep 2009 |
1 Jan 2009- 31 Dec 2009 |
|---|---|---|---|---|---|
| TUSD | 9 months | 3 months | 9 months | 3 months | 12 months |
| Operating income | |||||
| Net sales of: | |||||
| Crude oil | |||||
| - Norway | 335,977 | 119,167 | 208,989 | 88,461 | 296,231 |
| - Netherlands | 76 | 39 | 77 | 12 | 139 |
| - France | 67,053 | 21,747 | 54,811 | 21,027 | 77,871 |
| - Indonesia | 18,699 | 3,590 | 26,968 | 12,711 | 36,617 |
| - Russia | 50,179 | 16,631 | 55,195 | 21,872 | 74,398 |
| - Tunisia | 29,517 | 14,209 | 25,469 | 13,308 | 25,469 |
| 501,501 | 175,383 | 371,509 | 157,391 | 510,725 | |
| Condensate | |||||
| - Netherlands | 735 | 253 | 523 | 202 | 848 |
| - Indonesia | 64 | 19 | 103 | 18 | 124 |
| 799 | 272 | 626 | 220 | 972 | |
| Gas | |||||
| - Norway | 21,260 | 8,984 | 13,314 | 3,464 | 18,257 |
| - Netherlands | 23,091 | 8,199 | 29,194 | 6,980 | 37,354 |
| - Indonesia | 2,314 | 1,752 | 132 | 48 | 180 |
| 46,665 | 18,935 | 42,640 | 10,492 | 55,791 | |
| Net sales from continuing operations | 548,965 | 194,590 | 414,775 | 168,103 | 567,488 |
| Net sales from discontinued operations | 62,567 | - | 161,806 | 67,911 | 228,111 |
| Total net sales | 611,532 | 194,590 | 576,581 | 236,014 | 795,599 |
| Operating profit contribution | |||||
| - Norway | 241,475 | 105,145 | 89,043 | 29,756 | 153,045 |
| - France | 37,927 | 11,806 | 24,192 | 11,749 | 36,230 |
| - Netherlands | 4,687 | 1,814 | 12,944 | 2,007 | 15,125 |
| - Russia | 3,779 | 2,144 | -7,832 | -9,815 | -700,677 |
| - Indonesia | 4,336 | 1,108 | 3,479 | 2,756 | 3,638 |
| - Tunisia | 11,705 | 8,548 | 3,157 | 2,737 | 3,159 |
| - Sudan | - | - | 1,550 | 40 | 1,582 |
| - Vietnam | -32,164 | -17,129 | -7,204 | 175 | -7,203 |
| - Congo (Brazzaville) | - | - | - | - | -2,525 |
| - Other | -22,070 | -8,926 | -14,135 | -6,894 | -6,566 |
| Operating profit contribution from | |||||
| continuing operations | 249,675 | 104,510 | 105,194 | 32,511 | -504,192 |
| Operating profit contribution from | |||||
| discontinued operations – United Kingdom | 20,774 | - | 25,495 | 9,418 | 35,919 |
| Total operating profit contribution | 270,449 | 104,510 | 130,689 | 41,929 | -468,273 |
| 1 Jan 2010- | 1 Jul 2010- | 1 Jan 2009- | 1 Jul 2009- | 1 Jan 2009- |
|---|---|---|---|---|
| 30 Sep 2010 | 30 Sep 2010 | 30 Sep 2009 | 30 Sep 2009 | 31 Dec 2009 |
| 9 months | 3 months | 9 months | 3 months | 12 months |
| 67,008 | 22,846 | 72,130 | 28,640 | 95,415 |
| 11,800 | 4,884 | 7,486 | -1,044 | 15,738 |
| 31,488 | 10,160 | 29,466 | 12,356 | 40,987 |
| -3,684 | -15,549 | 7,763 | 7,990 | 89 |
| 1,718 | 519 | - | - | 3,082 |
| 108,330 | 22,860 | 116,845 | 47,942 | 155,311 |
| 32,030 | - | 95,325 | 41,609 | 140,036 |
| 140,360 | 22,860 | 212,170 | 89,551 | 295,347 |
| Note 3. Depletion costs, | 1 Jan 2010- | 1 Jul 2010- | 1 Jan 2009- | 1 Jul 2009- | 1 Jan 2009- |
|---|---|---|---|---|---|
| 30 Sep 2010 | 30 Sep 2010 | 30 Sep 2009 | 30 Sep 2009 | 31 Dec 2009 | |
| TUSD | 9 months | 3 months | 9 months | 3 months | 12 months |
| Norway | 73,381 | 28,025 | 48,309 | 16,823 | 65,301 |
| France | 10,654 | 3,859 | 9,784 | 3,020 | 12,821 |
| Netherlands | 12,775 | 4,371 | 9,720 | 2,909 | 12,727 |
| Indonesia | 3,201 | 1,343 | 3,467 | 1,271 | 7,334 |
| Russia | 4,632 | 1,452 | 6,608 | 2,174 | 8,627 |
| Tunisia | 6 | 6 | 9,063 | 2,469 | 11,318 |
| Depletion of oil and gas properties | 104,649 | 39,056 | 86,951 | 28,666 | 118,128 |
| Italy | 2,315 | 2,286 | - | - | - |
| Depletion of solar properties | 2,315 | 2,286 | - | - | - |
| Depletion from continuing operations | 106,964 | 41,342 | 86,951 | 28,666 | 118,128 |
| Depletion from discontinued operations – | |||||
| United Kingdom | 11,362 | - | 39,477 | 12,277 | 51,778 |
| Total depletion costs | 118,326 | 41,342 | 126,428 | 40,943 | 169,906 |
| Note 4. Exploration costs, | 1 Jan 2010- | 1 Jul 2010- | 1 Jan 2009- | 1 Jul 2009- | 1 Jan 2009- |
|---|---|---|---|---|---|
| 30 Sep 2010 | 30 Sep 2010 | 30 Sep 2009 | 30 Sep 2009 | 31 Dec 2009 | |
| TUSD | 9 months | 3 months | 9 months | 3 months | 12 months |
| Norway | 33,473 | 2,891 | 66,422 | 38,168 | 69,544 |
| France | 214 | 214 | 2,741 | 70 | 3,128 |
| Russia | - | - | - | - | 35,000 |
| Sudan | - | - | -1,548 | -37 | -1,580 |
| Congo (Brazzaville) | - | - | 3,253 | 3,253 | 2,522 |
| Vietnam | 32,164 | 17,129 | 7,203 | -176 | 7,203 |
| Indonesia | -186 | 10 | 3,609 | 35 | 3,712 |
| Cambodia | 23 | 5 | - | - | 10,989 |
| Other | 1,159 | 425 | 3,139 | 2,290 | 4,274 |
| Exploration costs from continuing | |||||
| operations | 66,847 | 20,674 | 84,819 | 43,603 | 134,792 |
| Exploration costs from discontinued | |||||
| operations - United Kingdom | 61 | - | 6,017 | 5,990 | 6,149 |
| Total exploration costs | 66,908 | 20,674 | 90,836 | 49,593 | 140,941 |
| Note 5. Financial income, | 1 Jan 2010- | 1 Jul 2010- | 1 Jan 2009- | 1 Jul 2009- | 1 Jan 2009- |
|---|---|---|---|---|---|
| 30 Sep 2010 | 30 Sep 2010 | 30 Sep 2009 | 30 Sep 2009 | 31 Dec 2009 | |
| TUSD | 9 months | 3 months | 9 months | 3 months | 12 months |
| Interest income | 1,887 | 591 | 3,332 | 1,148 | 4,595 |
| Foreign exchange gains, net | 8,437 | 8,437 | 42,462 | 27,224 | 66,019 |
| Insurance proceeds | 377 | - | - | - | - |
| Gain on sale of shares | - | - | 10,244 | 10,244 | 10,244 |
| Other financial income | 3,138 | 820 | 718 | -70 | 1,173 |
| Financial income from continuing | |||||
| operations | 13,839 | 9,848 | 56,756 | 38,546 | 82,031 |
| Financial income from discontinued | |||||
| operations – United Kingdom | 360 | - | 26 | 26 | 32 |
| Total financial income | 14,199 | 9,848 | 56,782 | 38,572 | 82,063 |
| Note 6. Financial expenses, | 1 Jan 2010- 30 Sep 2010 |
1 Jul 2010- 30 Sep 2010 |
1 Jan 2009- 30 Sep 2009 |
1 Jul 2009- 30 Sep 2009 |
1 Jan 2009- 31 Dec 2009 |
|---|---|---|---|---|---|
| TUSD | 9 months | 3 months | 9 months | 3 months | 12 months |
| Interest expenses | 6,270 | 3,697 | 5,588 | 1,882 | 8,895 |
| Result on interest rate hedge settlement | 5,189 | 1,673 | 3,957 | 1,650 | 5,669 |
| Change in market value interest rate | |||||
| hedge | 3,840 | 2,037 | - | - | 452 |
| Unwinding of site restoration discount | 2,974 | 978 | 1,845 | 634 | 2,490 |
| Amortisation of deferred financing fees | 1,757 | 985 | 1,749 | 602 | 2,539 |
| Foreign exchange losses, net | - | -626 | - | - | - |
| Loss on sale of shares | 3,884 | - | - | - | - |
| Other financial expenses | 1,159 | 209 | 30,614 | 29,432 | 32,427 |
| Financial expenses from continuing | |||||
| operations | 25,073 | 8,953 | 43,753 | 34,200 | 52,472 |
| Financial expenses from discontinued | |||||
| operations – United Kingdom | 1,224 | - | 20,011 | 4,048 | 24,398 |
| Total financial expenses | 26,297 | 8,953 | 63,764 | 38,248 | 76,870 |
| Note 7. Tax, | 1 Jan 2010- 30 Sep 2010 |
1 Jul 2010- 30 Sep 2010 |
1 Jan 2009- 30 Sep 2009 |
1 Jul 2009- 30 Sep 2009 |
1 Jan 2009- 31 Dec 2009 |
|---|---|---|---|---|---|
| TUSD | 9 months | 3 months | 9 months | 3 months | 12 months |
| Continuing operations | |||||
| Current tax | 33,724 | 19,353 | 9,127 | 11,079 | 32,014 |
| Deferred tax | 161,870 | 64,015 | 82,925 | 19,064 | 13,655 |
| Tax from continuing operations | 195,594 | 83,368 | 92,052 | 30,143 | 45,669 |
| Current tax | 7,315 | - | 2,900 | 1,772 | 6,546 |
| Deferred tax | 1,673 | - | -1,613 | 450 | -3,730 |
| Tax from discontinued operations – United | |||||
| Kingdom | 8,988 | - | 1,287 | 2,222 | 2,816 |
| Total tax | 204,582 | 83,368 | 93,339 | 32,365 | 48,485 |
| Note 8. Discontinued operations, | 1 Jan 2010- | 1 Jul 2010- | 1 Jan 2009- | 1 Jul 2009- | 1 Jan 2009- |
|---|---|---|---|---|---|
| 30 Sep 2010 | 30 Sep 2010 | 30 Sep 2009 | 30 Sep 2009 | 31 Dec 2009 | |
| TUSD | 9 months | 3 months | 9 months | 3 months | 12 months |
| Net sales | 62,567 | - | 161,806 | 67,911 | 228,111 |
| Other operating income | 1,983 | - | 4,246 | 1,197 | 5,906 |
| Operating income | 64,550 | - | 166,052 | 69,108 | 234,017 |
| Production costs | -32,030 | - | -95,325 | -41,609 | -140,036 |
| Depletion of oil and gas properties | -11,362 | - | -39,477 | -12,277 | -51,778 |
| Exploration costs | -61 | - | -6,017 | -5,990 | -6,149 |
| General, administration and depreciation | |||||
| expenses | -323 | - | 262 | 186 | -135 |
| Operating profit | 20,774 | - | 25,495 | 9,418 | 35,919 |
| Financial income | 360 | - | 26 | 26 | 32 |
| Financial expenses | -1,224 | - | -20,011 | -4,048 | -24,398 |
| Profit before tax | 19,910 | - | 5,510 | 5,396 | 11,553 |
| Tax | -8,988 | - | -1,287 | -2,222 | -2,816 |
| Net result from discontinued | |||||
| operations | 10,922 | - | 4,223 | 3,174 | 8,737 |
| Gain on sale of assets | 358,353 | - | - | - | - |
| Net result from discontinued | |||||
| operations | 369,275 | - | 4,223 | 3,174 | 8,737 |
| Note 9. Oil and gas properties, TUSD |
30 Sep 2010 | 31 Dec 2009 |
|---|---|---|
| Norway | 991,001 | 951,793 |
| United Kingdom | - | 588,885 |
| France | 158,758 | 168,907 |
| Netherlands | 49,574 | 61,670 |
| Indonesia | 75,879 | 90,528 |
| Russia | 610,808 | 598,719 |
| Tunisia | - | 210 |
| Congo (Brazzaville) | 31,475 | 29,800 |
| Vietnam | - | 16,563 |
| Malaysia | 38,236 | 31,473 |
| Others | 4,185 | 1,800 |
| 1,959,916 | 2,540,348 |
| Note 10. Financial assets, TUSD |
30 Sep 2010 | 31 Dec 2009 |
|---|---|---|
| Other shares and participations | 29,512 | 32,369 |
| Capitalised financing fees | 5,372 | 7,514 |
| Long-term receivable | 90,426 | 24,239 |
| Derivative instruments | - | 231 |
| Other financial assets | 17,222 | 21,084 |
| 142,532 | 85,437 |
| Note 11. Assets and liabilities held for sale / distribution, TUSD |
30 Sep 2010 | 31 Dec 2009 |
|---|---|---|
| Assets held for sale / distribution | ||
| Oil and gas properties | 29,889 | - |
| Solar power properties | 270,557 | - |
| Other tangible assets | 316 | - |
| Goodwill | 1,080 | - |
| Other intangible assets | 3,416 | - |
| Financial assets | 19,197 | - |
| Deferred tax | 9,878 | - |
| Total non-current assets | 334,333 | - |
| Receivables and inventories | 54,095 | - |
| Cash and cash equivalents | 50,074 | - |
| Total current assets | 104,169 | - |
| Minority interest | -224,664 | - |
| Total assets held for sale / distribution | 213,838 | - |
| Liabilities held for sale / distribution | ||
| Provision for site restoration | 164 | - |
| Other provisions | 63,997 | - |
| Long term liabilities | 273,158 | - |
| Total non-current liabilities | 337,319 | - |
| Tax payables | 3,021 | - |
| Other current liabilities | 53,001 | - |
| Total current liabilities | 56,022 | - |
| Minority interest | -210,249 | - |
| Net liabilities held for sale / distribution | 183,092 | - |
| Net assets held for sale / distribution | 30,746 | - |
| Note 12. Receivables and inventories, TUSD |
30 Sep 2010 | 31 Dec 2009 |
|---|---|---|
| Inventories | 15,046 | 27,373 |
| Trade receivables | 72,288 | 80,721 |
| Underlift | 15,355 | 8,649 |
| Short-term loan receivable | 5,500 | 33,907 |
| Corporation tax | - | 2,241 |
| Joint venture debtors | 15,103 | 28,930 |
| Other assets | 10,239 | 16,131 |
| 133,531 | 197,952 |
| Note 13. Provisions, TUSD |
30 Sep 2010 | 31 Dec 2009 |
|---|---|---|
| Site restoration | 80,319 | 132,698 |
| Pension | 1,401 | 1,354 |
| Deferred taxes | 639,081 | 743,646 |
| Derivative instruments | 1,575 | 3,122 |
| Other provisions | 12,064 | 16,802 |
| 734,440 | 897,622 |
| Note 14. Other current liabilities, TUSD |
30 Sep 2010 | 31 Dec 2009 |
|---|---|---|
| Trade payables | 10,285 | 20,487 |
| Overlift | 3,886 | 1,287 |
| Tax payables | 13,942 | 20,870 |
| Accrued expenses | 1,259 | 16,472 |
| Acquisition liabilities | 5,613 | 7,238 |
| Joint venture creditors | 83,319 | 140,046 |
| Short-term loans | 675 | 32,400 |
| Derivative instruments | 6,947 | 7,074 |
| Other liabilities | 4,648 | 11,622 |
| 130,574 | 257,496 |
| 1 Jan 2010- | 1 Jul 2010- | 1 Jan 2009- | 1 Jul 2009- | 1 Jan 2009- | |
|---|---|---|---|---|---|
| 30 Sep 2010 | 30 Sep 2010 | 30 Sep 2009 | 30 Sep 2009 | 31 Dec 2009 | |
| Expressed in TSEK | 9 months | 3 months | 9 months | 3 months | 12 months |
| Operating income | |||||
| Other operating income | 15,227 | 4,088 | 24,124 | 8,449 | 33,154 |
| Gross profit | 15,227 | 4,088 | 24,124 | 8,449 | 33,154 |
| General and administration expenses | -38,314 | -10,295 | -33,726 | -6,822 | -49,281 |
| Operating loss | -23,087 | -6,207 | -9,602 | 1,627 | -16,127 |
| Result from financial investments | |||||
| Financial income | 4,011,134 | 3,997,716 | 4,837 | 931 | 8,589 |
| Financial expenses | -28,382 | -265 | -44 | -15 | -7,133 |
| 3,982,752 | 3,997,451 | 4,793 | 916 | 1,456 | |
| Result before tax | 3,959,665 | 3,991,244 | -4,809 | 2,543 | -14,671 |
| Tax | 7,328 | - | - | - | -17,600 |
| Net result | 3,966,993 | 3,991,244 | -4,809 | 2,543 | -32,271 |
| Expressed in TSEK | 1 Jan 2010- 30 Sep 2010 9 months |
1 Jul 2010- 30 Sep 2010 3 months |
1 Jan 2009- 30 Sep 2009 9 months |
1 Jul 2009- 30 Sep 2009 3 months |
1 Jan 2009- 31 Dec 2009 12 months |
|---|---|---|---|---|---|
| Net result | 3,966,993 | 3,991,244 | -4,809 | 2,543 | -32,271 |
| Other comprehensive income | - | - | - | - | - |
| Total comprehensive income Total comprehensive income |
3,966,993 | 3,991,244 | -4,809 | 2,543 | -32,271 |
| attributable to: Shareholders of the parent company Minority interest |
3,966,993 - |
3,991,244 - |
-4,809 - |
2,543 - |
-32,271 - |
| 3,966,993 | 3,991,244 | -4,809 | 2,543 | -32,271 |
| Expressed in TSEK | 30 September 2010 | 31 December 2009 |
|---|---|---|
| ASSETS | ||
| Non-current assets | ||
| Financial assets | 7,871,947 | 7,891,762 |
| Total non-current assets | 7,871,947 | 7,891,762 |
| Current assets | ||
| Receivables | 7,760 | 5,365 |
| Cash and cash equivalents | 1,656 | 532 |
| Total current assets | 9,416 | 5,897 |
| TOTAL ASSETS | 7,881,363 | 7,897,659 |
| SHAREHOLDERS´EQUITY AND LIABILITIES Shareholders´ equity including net result for the period |
7,774,994 | 7,840,752 |
| Non current liabilities | ||
| Provisions | 36,403 | 36,403 |
| Total non current liabilites | 36,403 | 36,403 |
| Current liabilities | ||
| Current liabilities | 69,966 | 20,504 |
| Total current liabilities | 69,966 | 20,504 |
| TOTAL EQUITY AND LIABILITIES | 7,881,363 | 7,897,659 |
| Pledged assets | 3,500,808 | 4,978,037 |
| Contingent liabilities | - | - |
| 1 Jan 2010- | 1 Jul 2010- | 1 Jan 2009- | 1 Jul 2009- | 1 Jan 2009- | |
|---|---|---|---|---|---|
| 30 Sep 2010 | 30 Sep 2010 | 30 Sep 2009 | 30 Sep 2009 | 31 Dec 2009 | |
| Expressed in TSEK | 9 months | 3 months | 9 months | 3 months | 12 months |
| Cash flow from/used for | |||||
| operations | |||||
| Net result | 3,966,993 | 3,991,244 | -4,809 | 2,543 | -32,271 |
| Adjustment for non-cash related items | -3,947,996 | -3,988,488 | 1,514 | 1,271 | 18,958 |
| Changes in working capital | -2,739 | -14,048 | 4,392 | 1,235 | 11,744 |
| Total cash flow from/used for | |||||
| operations | 16,258 | -11,292 | 1,097 | 5,049 | -1,569 |
| Cash flow from investments | |||||
| Change in other financial fixed assets | 68,318 | 29,770 | -884 | -5,404 | 738 |
| Total cash flow from investments | 68,318 | 29,770 | -884 | -5,404 | 738 |
| Cash flow used for financing | |||||
| Purchase of own shares | -83,157 | -21,915 | - | - | - |
| Total cash flow used for financing | -83,157 | -21,915 | - | - | - |
| Change in cash and cash | |||||
| equivalents | 1,419 | -3,437 | 213 | -355 | -831 |
| Cash and cash equivalents at the | |||||
| beginning of the period | 532 | 5,474 | 1,184 | 1,323 | 1,184 |
| Currency exchange difference in cash | |||||
| and cash equivalents | -295 | -381 | 217 | 646 | 179 |
| Cash and bank at the end of the | |||||
| period | 1,656 | 1,656 | 1,614 | 1,614 | 532 |
| Restricted equity | Unrestricted equity | |||||
|---|---|---|---|---|---|---|
| Share | Statutory | Other | Retained | Total | ||
| Expressed in TSEK | capital | reserve | reserves | earnings | Net result | equity |
| Balance at 1 January 2009 | 3,179 | 861,306 | 5,089,856 | 1,855,683 | 62,778 | 7,872,802 |
| Transfer of prior year net result | - | - | - | 62,778 | -62,778 | - |
| Total comprehensive income | - | - | - | - | -4,809 | -4,809 |
| Transfer of share based payments | - | - | 30,894 | -30,894 | - | - |
| Share based payments | - | - | - | 163 | - | 163 |
| Balance at 30 September 2009 | 3,179 | 861,306 | 5,120,750 | 1,887,730 | -4,809 | 7,868,156 |
| Total comprehensive income | - | - | - | - | -27,462 | -27,462 |
| Transfer of share based payments | - | - | - | - | - | - |
| Share based payments | - | - | - | 58 | - | 58 |
| Balance at 31 December 2009 | 3,179 | 861,306 | 5,120,750 | 1,887,788 | -32,271 | 7,840,752 |
| Transfer of prior year net result | - | - | - | -32,271 | 32,271 | - |
| Total comprehensive income | - | - | - | - | 3,966,993 | 3,966,993 |
| Dividend | - | - | -2,123,457 | -1,826,272 | - | -3,949,729 |
| Purchase of own shares | - | - | -83,157 | - | - | -83,157 |
| Transfer of share based payments | - | - | 29,380 | -29,380 | - | - |
| Share based payments | - | - | - | 135 | - | 135 |
| Balance at 30 September 2010 | 3,179 | 861,306 | 2,943,516 | - | 3,966,993 | 7,774,994 |
| Data per share | 1 Jan 2010- 30 Sep 2010 |
1 Jul 2010- 30 Sep 2010 |
1 Jan 2009- 30 Sep 2009 |
1 Jul 2009- 30 Sep 2009 |
1 Jan 2009- 31 Dec 2009 |
|---|---|---|---|---|---|
| 9 months | 3 months | 9 months | 3 months | 12 months | |
| Shareholders' equity USD per share1 | 2.76 | 2.76 | 5.00 | 5.00 | 3.64 |
| Operating cash flow USD per share 2 | 1.41 | 0.51 | 1.15 | 0.44 | 1.51 |
| Cash flow from operations USD per share3 | 1.24 | 0.53 | 1.01 | 0.63 | 1.56 |
| Earnings USD per share4 | 1.35 | 0.09 | 0.03 | -0.04 | -1.31 |
| Earnings USD per share fully diluted5 | 1.35 | 0.09 | 0.03 | -0.04 | -1.31 |
| EBITDA USD per share fully diluted6 | 1.47 | 0.54 | 1.15 | 0.46 | 1.54 |
| Dividend per share | 2.10 | - | - | - | - |
| Quoted price at the end of the financial | |||||
| period (regards the parent company), USD7 | 8.47 | 8.47 | 8.54 | 8.54 | 7.95 |
| Number of shares issued at period end | 317,910,580 | 317,910,580 | 317,910,580 | 317,910,580 | 317,910,580 |
| Number of shares in circulation at period end | 311,027,942 | 311,027,942 | 313,420,280 | 313,420,280 | 313,420,280 |
| Weighted average number of shares for the | |||||
| period8 | 312,457,256 | 311,027,942 | 313,420,280 | 313,420,280 | 313,420,280 |
| Weighted average number of shares for the | |||||
| period (fully diluted)8 | 312,457,256 | 311,027,942 | 313,420,280 | 313,420,280 | 313,420,280 |
The data per share and the key data are based on the total of the continuing and discontinued operations.
1 the Group's shareholders' equity divided by the average number of shares at period end.
2 the Group's operating income less production costs and less current taxes divided by the weighted average number of shares for the period.
3 cash flow from operations in accordance with the consolidated statement of cash flow divided by the weighted average number of shares for the period.
4 the Group's net result attributable to shareholders of the parent company divided by the weighted average number of shares for the period.
5 the Group's net result attributable to shareholders of the parent company divided by the weighted average number of shares for the period after considering the dilution effect of outstanding warrants.
6 the Group's EBITDA divided by the weighted average number of shares for the period after considering the dilution effect of outstanding warrants. EBITDA is defined as operating profit before depletion of oil and gas properties, exploration costs, impairment costs and gain on sale of assets.
7 the quoted price in USD is based on the quoted price in SEK converted in USD against the closing rate of the period.
8 the number of shares at the beginning of the period with new issue of shares weighted for the proportion of the period they are in issue.
| Key data group | 1 Jan 2010- 30 Sep 2010 9 months |
1 Jul 2010- 30 Sep 2010 3 months |
1 Jan 2009- 30 Sep 2009 9 months |
1 Jul 2009- 30 Sep 2009 3 months |
1 Jan 2009- 31 Dec 2009 12 months |
|---|---|---|---|---|---|
| Return on equity, %9 | 38 | 2 | - | -1 | -37 |
| Return on capital employed, %10 | 37 | 7 | 4 | - | -29 |
| Net debt/equity ratio, %11 | 62 | 62 | 31 | 31 | 40 |
| Equity ratio, %12 | 37 | 37 | 49 | 49 | 42 |
| Share of risk capital, %13 | 62 | 62 | 71 | 71 | 66 |
| Interest coverage ratio, %14 | 3,960 | 1,401 | 688 | -143 | -2,865 |
| Operating cash flow/interest ratio, %15 | 2,804 | 2,161 | 2,986 | 3,472 | 2,605 |
| Yield, %16 | 25 | - | - | - | - |
9 the Group's net result divided by the Group's average total equity.
10 the Group's income before tax plus interest expenses plus/less exchange differences on financial loans divided by the average capital employed (the average balance sheet total less non-interest bearing liabilities).
11 the Group's net interest bearing liabilities in relation to shareholders' equity.
12 the Group's total equity in relation to balance sheet total.
13 the sum of the total equity and the deferred tax provision divided by the balance sheet total.
14 the Group's result after financial items plus interest expenses plus/less exchange differences on financial loans divided by interest expenses.
15 the Group's operating income less production costs and less current taxes divided by the interest charge for the period.
16 dividend per share in relation to quoted share price at the end of the financial period.
The Company will publish the following reports:
The AGM will be held on 5 May 2011 in Stockholm, Sweden.
Stockholm, 3 November 2010
C. Ashley Heppenstall President & CEO
The financial information relating to the nine month period ended 30 September 2010 has not been subject to review by the auditors of the company.
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