Posts

19 licences awarded in the Norwegian licensing round

APA 2020 licence awards

19 licences awarded in the Norwegian licensing round

19 January 2021

Lundin Energy AB announces that its wholly owned subsidiary Lundin Energy Norway AS (together Lundin Energy), has been awarded a total of 19 exploration licence interests in the 2020 Awards in Predefined Areas (APA) licensing round, in Norway.

The award includes 15 licences in the North Sea, two licences in the Norwegian Sea and two licences in the Southern Barents Sea, seven of the newly awarded licences will be operated by Lundin Energy Norway.

The awards from this licensing round continue to build on the Company’s seven core exploration areas and increases by 23 percent the number of licences held by the Company. Supporting the Company’s strategy to execute an exploration programme which targets a combination of high value, near field opportunities and high potential, frontier exploration.

 The licence interests are detailed below and maps of their location are provided in the link below.

 

LicencesBlockWorking InterestLicence Area
1089*1/5,650%North Sea
10872/2, 550%North Sea
1084*3/760%North Sea
10907/130%North Sea
1091*15/5,6,840%North Sea
1092*15/6,950%North Sea
109715/3, 24/11, 1230%North Sea
1095*16/2, 25/1150%North Sea
1094*17/2,3,5,6,8  18/760%North Sea
1045B125/415%North Sea
820SB125/840%North Sea
109925/3, 26/1, 30/12, 31/1030%North Sea
110430/340%North Sea
1102*30/3, 31/1,4,560%North Sea
110634/2,3,5,620%North Sea
11266609/5,6,7,8,9,10,11,12, 6610/2,4,5,6, 6611/4,530%Norwegian Sea
11296703/7,8,9,10,11,12, 6704/7,8,10,1130%Norwegian Sea
229G17122/8,950%Southern Barents Sea
11317122/8,9,10,11,12, 7123/7,8,920%Southern Barents Sea

*Operator Lundin Energy Norway

1 Geographical extension of the licence area.

 


 

Update on Q4 2020 financial results and webcast details for Capital Markets Day presentation on 28 January 2021

Update on Q4 2020 financial results and webcast details for Capital Markets Day presentation on 28 January 2021

Update on Q4 2020 financial results and webcast details for Capital Markets Day presentation on 28 January 2021

13 January 2021

Lundin Energy AB (Lundin Energy) will publish its financial report for the fourth quarter 2020 and host its annual Capital Markets Day presentation on Thursday, 28 January 2021. For the fourth quarter 2020, Lundin Energy will expense pre-tax exploration costs of approximately MUSD 58, and recognise a net foreign exchange gain of approximately MUSD 256.

Exploration costs
It is the Company’s policy to capitalize costs associated with its exploration activities and when it is determined that a commercial discovery has not been achieved, the associated exploration costs are charged to the income statement. For the fourth quarter of 2020, Lundin Energy will incur pre-tax exploration costs of approximately MUSD 58, which will be charged to the income statement and offset by a tax credit of approximately MUSD 45. The exploration costs are mainly related to the dry wells on the Polmak prospect (PL609/PL1027) and the Spissa prospect (PL960) and relinquished licenses.

Net debt and foreign exchange gain
The net debt position of Lundin Energy at 31 December 2020, amounted to USD 3.9 billion resulting in available liquidity of USD 1.1 billion, within its recently refinanced and cheaper, USD 5.0 billion credit facility. As a result of the refinancing, unamortized capitalized financing fees and loan modification gain were expensed during the fourth quarter.

Lundin Energy will recognise a net foreign exchange gain of approximately MUSD 256 for the fourth quarter of 2020. The Norwegian Krone strengthened against the US Dollar by approximately 10 percent and the Euro strengthened by approximately 5 percent during the fourth quarter of 2020. The foreign exchange gain is largely non-cash and mainly relates to the revaluation of loan balances at the prevailing exchange rates at the balance sheet date.

Change in inventory and under/overlift balances
Lundin Energy recognises income based on its sold volume (sales method). Consequently, changes in inventory and under/overlift balances are reported as an adjustment to cost valued at production cost, including depletion. During the fourth quarter of 2020, Lundin Energy was overlifted by 2.1 Mboepd.

Revenue from the crude oil sales from third parties
Lundin Energy markets its own crude oil production and at times markets crude oil from third parties. For the fourth quarter 2020, revenue from the sale of crude oil from third parties amounted to MUSD 24.9 offset by the purchase of crude oil from third parties of MUSD 24.5, resulting in a gross profit of MUSD 0.4 on third party activities for the fourth quarter 2020.

Fourth Quarter 2020 results and Capital Markets Day 2021
Lundin Energy’s financial report for the fourth quarter 2020, will be published on Thursday, 28 January 2021 at 07:30 CET.

Lundin Energy management team will present the financial results for the fourth quarter 2020 and Capital Markets Day presentation by webcast at 14.00 CET on the 28 January 2021. Please follow the event live at www.lundin-Energy.com or dial in using the following telephone numbers with the pin code shown below:

UK/International: +44 2071 928338
Sweden: +46 8 566 184 67
Norway: +47 21 56 30 15
USA: +1 646 741 3167

Access Pin : 6247379

Link : https://edge.media-server.com/mmc/p/oz7b59c2

 

Lundin Energy announces resource additions of 210 percent of 2020 production

Lundin Energy announces resource additions of 210 percent of 2020 production

Lundin Energy announces resource additions of 210 percent of 2020 production

12 January 2021

Lundin Energy AB (Lundin Energy) is pleased to announce that as at 31 December 2020, its proved plus probable net reserves (2P reserves) are 671 million barrels of oil equivalent (MMboe 1,2) and its proved plus probable plus possible net reserves (3P reserves) are 826 MMboe. 2P reserves plus best estimate net contingent resources (total resource) are 946 MMboe, with a total resource replacement ratio3 for 2020 of 210 percent.

Lundin Energy’s 2P reserves as at 31 December 2020 are 670.9 MMboe and reflect a positive revision of 39.3 MMboe. The 3P reserves as at 31 December 2020 are 826.0 MMboe and reflect a positive revision of 30.0 MMboe. The best estimate net contingent resources (2C resources) as at 31 December 2020 are 275.5 MMboe, which is an increase of 90.2 MMboe from year end 2019. The total resource as at 31 December 2020 are 946.4 MMboe, which reflects additions of 129.4 MMboe from year end 2019, including asset acquisitions.

 

2P Reserves3P ReservesTotal Resources
2P + 2C
End 2019693.3857.5878.6
  – Produced 4-61.6-61.6-61.6
  – Sales/+Acquisitions+78.4
  + Revisions/Discoveries+39.3+30.0+51.0
End 2020670.9826.0946.4
Reserves replacement ratio 3,564%49%210%

 

The increase in 2P reserves relates primarily to the Edvard Grieg field, along with minor reserves additions at other assets. The increase in 2C contingent resources relates to the acquisition of interests in the Wisting and Alta discoveries in the southern Barents Sea, as well as exploration success at the Iving prospect in the Norwegian North Sea. Oil accounts for approximately 90 percent of Lundin Energy’s total resource.

As announced in September 2020, gross 2P reserves at Edvard Grieg have been increased by 51 MMboe from year end 2019 (33 MMboe net to Lundin Energy), which lifts the gross 2P ultimate recovery for the field to 350 MMboe6, representing an increase of 90 percent from the original PDO estimate. Gross 2P ultimate recovery for the Greater Edvard Grieg Area has therefore grown to 410 MMboe, which includes the Solveig Phase 1 and Rolvsnes Extended Well Test (EWT) tie-back developments. These additional reserves extend the plateau production period for the Greater Edvard Grieg Area by one year to late 2023, representing a five-year extension from the original PDO. Activity in the Greater Edvard Grieg Area will continue in 2021, with the drilling of three infill wells at Edvard Grieg, first oil from the two tie-back developments and further exploration drilling.

The Johan Sverdrup field continues to exceed expectations, with excellent reservoir performance and well productivities. The Phase 1 facility capacity has been increased to 500 thousand barrels of oil per day (Mbopd), with potential for a further increase, post modifications to the water injection system, which is planned in mid-2021. When Phase 2 comes on stream, scheduled for the fourth quarter of 2022, it is expected that the production capacity will be lifted to 720 Mbopd. More production experience is required to further understand the reservoir performance prior to any potential revisions to the reserves estimate.

In March 2020, Lundin Energy announced discoveries at the Iving and Evra prospects in in the Norwegian North Sea, close to the Balder and Ringhorne fields. The discoveries are estimated to contain between 12 and 71 MMboe of gross resources and will be further appraised in 2021.

In October 2020, Lundin Energy announced the acquisition of a 10 percent working interest in the Wisting oil discovery and a further 15 percent working interest in the operated Alta discovery, both located in the Southern Barents Sea. Equinor, the operator of Wisting in the development phase, is targeting a PDO by end 2022, to benefit from the temporary tax incentives established by the Norwegian Government in June 2020. The transaction adds 2C resources of 78 MMboe.

The reserves estimates have been audited by ERCE, a third-party independent reserves auditor, and have been calculated using the 2018 Petroleum Resource Management System (SPE PRMS) Guidelines of the Society of Petroleum Engineers (SPE), World Petroleum Congress (WPC), American Association of Petroleum Geologists (AAPG) and Society of Petroleum Evaluation Engineers (SPEE). The contingent resource estimates associated with the Edvard Grieg, Alvheim area, Johan Sverdrup, Solveig and Rolvsnes assets have been audited by ERCE. For the other assets, the contingent resource volumes are based on management estimates.

Nick Walker, President and CEO of Lundin Energy, commented:
“Growth and value creation are the key drivers for our business, and I am pleased that in a year when our production almost doubled, we were still able to deliver total resource additions of over two times our produced barrels. Our strong track record of growing the business continues, as we have now achieved a total resource replacement of 150 percent of our production over the last five years.

“Our growth strategy is underpinned by our world class producing assets which continue to outperform, a pipeline of potential new projects that we are prioritising for development within the new tax environment and an exciting exploration portfolio. With our 2021 programme already underway, I am confident that we will deliver another year of resource growth.”

1 BOE’s may be misleading, particularly if used in isolation. A BOE conversion ratio of 6 Mcf : 1 Bbl is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent the value equivalency at the wellhead.
2 The reserves were calculated using a nominal Brent oil price of USD 50 per barrel in 2021, 54 in 2022, 58 in 2023, 60 in 2024, and increasing by 2 percent per year thereafter.
3 Total resource replacement ratio is the sum of 2P reserves revisions and 2C Contingent resources revisions including assets transactions divided by the yearly production.
4Reserves are measured in salable quantities (saleable oil, natural gas liquids and dry gas converted to oil equivalents), which may differ from production volumes provided in corporate reports which are given in wellhead production quantities (oil and rich gas converted to oil equivalents).
5 As per industry standards the reserves replacement ratio is defined as the ratio of reserves additions to production during the year, excluding the effect of acquisitions and dispositions.
6 2P ultimate recovery is cumulative production to date plus remaining proved plus probable (2P) reserves.

Downloads

Finansiell uppdatering för det fjärde kvartalet 2020 och detaljer för webbsändning av kapitalmarknadsdagen den 28 januari 2021 (regulatorisk)

Update on Q4 2020 financial results and webcast details for Capital Markets Day presentation on 28 January 2021 (regulatory)