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Year End Report 2019

Year End Report 2019

Year End Report 2019

31 January 2020

·Strong financial performance with record free cash flow generation of MUSD 1,271.7, of which MUSD 312.7 relates to organic free cash flow and MUSD 959.0 relates to the sale of 2.6 percent working interest in Johan Sverdrup
·Board of Directors propose 2019 dividend of USD 1.80 per share corresponding to MUSD 511
·2019 production averaged 93.3 Mboepd above mid-point of upgraded guidance and, at year end production was over 150 Mboepd
·Operating cost of USD 4.03 per boe, below USD 4.25 per boe guidance for the year
·Johan Sverdrup producing around 350 Mbopd gross at year end 2019, 80 percent of Phase 1 plateau rate
·Completion of 2.6 percent sale of Johan Sverdrup and 16 percent share redemption with Equinor during 2019
·Launch of Decarbonisation Strategy targeting carbon neutrality in its exploration and production activities by 2030
·Board of Directors proposes to rename the Company to Lundin Energy

 

Financial summary1 Jan 2019-
31 Dec 2019
12 months
1 Oct 2019-
31 Dec 2019
3 months
1 Jan 2018-
31 Dec 2018
12 months
1 Oct 2018-
31 Dec 2018
3 months
Production in Mboepd93.3135.181.182.1
Revenue and other income in MUSD2,948.7749.72,640.7652.2
EBITDA in MUSD1
Per share in USD1
1,918.4
6.07
695.5
2.45
1,932.5
5.71
480.7
1.42
Free cash flow in MUSD
Per share in USD
1,271.7
4.03
153.8
0.54
663.0
1.96
173.3
0.51
Net result in MUSD
Per share in USD
824.9
2.61
155.3
0.56
225.7
0.67
-98.2
-0.29
Adjusted Net result in MUSD
Per share in USD
252.7
0.80
78.9
0.28
295.3
0.87
75.2
0.22
Net debt in MUSD4,006.74,006.73,398.23,398.2

1 Excludes the reported after tax accounting gain of MUSD 756.7 on the divestment of a 2.6 percent working interest in the Johan Sverdrup project.


Comments from Alex Schneiter, President and CEO of Lundin Petroleum:

“2019 has been one of the most transformational periods in the Company’s development, which ended with a record high exit production rate at over 150 Mboepd. Alongside this we have not only transformed what we are producing, we have also focused on how we produce oil and gas in the most sustainable and efficient manner. Such ambition has been formalised through our Decarbonisation Strategy, which targets carbon neutrality by 2030.

“The early startup of Johan Sverdrup Phase 1 in October 2019, was a significant milestone for our business and has firmly laid the foundations for a period of sustainable and efficient production growth well into the next decade. The field has since ramped up quickly and ahead of expectations and at year end was producing around 350 Mbopd gross, which is about 80 percent of the Phase 1 facilities capacity of 440 Mbopd. I would like to thank our teams, as well as the operator Equinor, for executing such a good project; to be achieving first oil on a development of this scale, two months early and significantly under budget, adds real value to our shareholders and is a testament to the hard work of everyone involved.

“Our key Edvard Grieg field continued to exceed expectations with operating efficiency ahead of guidance at 98 percent. This achievement is underpinned by continued reservoir outperformance and limited water production, which alongside the infill drilling programme scheduled for 2020, has enabled us to lift gross ultimate reserves to 300 MMboe. This field has consistently delivered above expectations for us and I am confident this performance will continue in the future, especially as we see more near-field resources being derisked through our ongoing drilling programme.

“Financially we have had another very strong period of free cash flow generation, driven by the sale of 2.6% of Johan Sverdrup, higher production and a cost base which we have continued to maintain at industry leading low levels of USD 4.03 per boe. This coupled with the share redemption from Equinor during the year, has driven our earnings per share and I am glad to note the Board is recommending a 22 percent increased dividend of USD 1.80 per share (in total MUSD 511), clearly demonstrating our focus on driving shareholder returns.

“With the sanction of the full electrification of Edvard Grieg, being developed together with the Johan Sverdrup Phase 2 project, our ambition to produce some of the lowest carbon intensity barrels in the world is closer to being realised. This will result in a significant reduction in CO2 emissions from the Edvard Grieg Area to below 1 kg per boe by the end of 2022. During the year and in line with the Decarbonisation Strategy, we also started to execute the plan to fully replace all Lundin Petroleum net power usage on both the Edvard Grieg and Johan Sverdrup fields by 2022, through direct investment in profitable renewable projects. These projects will also provide a natural hedge to the electricity price fluctuation, which will represent a significant element of field operating costs. Also announced in January 2020, the Board proposed to change the name of the Company to Lundin Energy in accordance with our Decarbonisation Strategy and our aim to continue to play an important part in the future energy mix.

“2020 is set to be another busy year for Lundin Petroleum across the full spectrum of our operations and we have another very active exploration and appraisal programme with ten wells across our portfolio in Norway, targeting over 650 MMboe of net unrisked resources. I would like to thank all stakeholders for their support during the year and I very much look forward to reporting our progress in 2020.”

2020 Capital Markets Day information
Lundin Petroleum will be hosting its 2020 Capital Markets Day on 31 January 2020 at 11.00 CET (10.00 GMT) at the London Stock Exchange. The Capital Markets Day will include presentations by the Company’s management team on its fourth quarter 2019 financial results, the business strategy, the 2020 budgeted development campaign and its exploration and appraisal programme.

Details for the live webcast:
Sweden +46 8 56642651
UK +44 3333000804
United States +1 6319131422
Norway +47 23500243

Access Pin : 58812582

Link : https://lundinpetroleum.videosync.fi/2020-01-31-q4_cmd

Lundin Petroleum announces its 2020 budget, production guidance and capital markets day information

Lundin Petroleum announces its 2020 budget, production guidance and capital markets day information

Lundin Petroleum announces its 2020 budget, production guidance and capital markets day information

31 January 2020

Lundin Petroleum AB (Lundin Petroleum) is pleased to announce its 2020 development, appraisal, exploration and abandonment budget which totals USD 1.27 billion and represents a 30 percent increase on 2019 capital expenditure. The production guidance for 2020 is between 145 to 165 thousand barrels of oil equivalent per day (Mboepd) and the long-term production guidance is increased to 160 – 170 Mboepd from 2021 with a target of over 200 Mboepd.

2020 guidance2019 results
Production145 to 165 Mboepd93.3 Mboepd
Operating costUSD 3.4 per boeUSD 4.03 per boe
Development expenditureMUSD 895MUSD 672
Exploration & Appraisal expenditureMUSD 225MUSD 298
Abandonment expenditureMUSD 50MUSD 4
Renewables InvestmentsMUSD 100
Long-term guidanceUpdated guidancePrevious guidance
Production160 to 170 Mboepd (2021 onwards)>150 Mboepd from Johan Sverdrup Phase 1 plateau (2020)
Target >200 Mboepd~170 Mboepd from Johan Sverdrup full field plateau (2023)
Operating costUSD 3.2 to 4.2 per boeUSD 3.4 to 4.4 per boe from 2020 onwards

2020 Production Guidance
The average production in 2019 was 93.3 Mboepd, which was above the mid-point of the upgraded 2019 production guidance of between 90 and 95 Mboepd, and 10 percent above the mid-point of the original guidance of 75 to 95 Mboepd. Lundin Petroleum’s production guidance for 2020 is between 145 to 165 Mboepd, reflecting the ramp-up of Johan Sverdrup Phase 1 to plateau levels by the summer of 2020 and a planned two-week maintenance shutdown at Edvard Grieg in the second quarter of 2020. The production contribution is split approximately 50 percent from the Johan Sverdrup field, 40 percent from the Edvard Grieg field and the remainder from the other assets.

The long-term production guidance for the Company has been increased to between 160 and 170 Mboepd from 2021 onwards, with a target of over 200 Mboepd from upsides from existing fields. The updated long-term guidance reflects the sale of a 2.6 percent interest in Johan Sverdrup during 2019, which is offset by an extension of the Edvard Grieg plateau period.

Development Budget
The 2020 development expenditure is budgeted at USD 895 million, which is an increase of one-third over 2019 levels. The Edvard Grieg tie-back projects, Solveig and Rolvsnes EWT will see increased activity compared to last year, and drilling will start on the Edvard Grieg infill campaign.

Approximately 40 percent of the 2020 budgeted development expenditure relates to the non-operated Johan Sverdrup field (WI 20%). The remaining spend for the Phase 1 project relates mainly to the drilling of additional development wells, while the Phase 2 project will see another active year of construction ahead of scheduled start-up in Q4 2022.

Approximately 35 percent of the budgeted development expenditure relates to the operated Solveig project (WI 65%) and the Rolvsnes Extended Well Test (WI 80%). Both projects will be subsea tie-backs to Edvard Grieg and are being implemented together. In 2020, offshore construction activities will take place, which include the installation of the subsea equipment and pipelines. On Solveig, drilling will start on the first development wells during the year and the project remains on track for first oil in Q1 2021.

The Edvard Grieg field (WI 65%) 2020 programme, includes drilling of the first of the three infill wells sanctioned in 2019, as well as contribution to the Utsira High Area power from shore system.

Budgeted expenditure at the non-operated Alvheim area involves the drilling of two infill wells.

Exploration and Appraisal Budget
The exploration and appraisal budget for 2020 is USD 225 million and involves the drilling of 10 wells, of which five are operated, and is targeting over 650 MMboe of net unrisked resources.

Four exploration wells are planned in the Southern Barents Sea. Two wells will be drilled on the Loppa high area close to the Alta/Gohta discoveries, targeting the Polmak prospect in PL609 (WI 40%) and the Bask prospect in PL533B (WI 40%). The other wells to be drilled are Schenzhou in PL722 (WI 20%) close to the Wisting oil discovery, and Spissa in PL960 (WI 20%).

In the Norwegian Sea two wells are planned, an appraisal well on the Balderbrå gas discovery made in 2018 in PL894 (WI 10%) estimated to contain between 50 and 140 MMboe of gross resources and an exploration well on the Melstein prospect in PL886 (WI 60%).

Four exploration wells are planned to be drilled in the Norwegian North Sea, Iving in PL820S (WI 40%) and Hasselbaink in PL917 (WI 20%) both located east of the Alvheim area, Merckx in PL981 (WI 60%) in the greater Utsira High area within tie-back distance to Edvard Grieg, and the Dovregubben prospect in PL976 (WI 50%) on the Sele High southeast of the Utsira High.

Abandonment Expenditure
The 2020 abandonment expenditure budget is USD 50 million for abandonment of the Brynhild development wells, representing the bulk of the field abandonment costs, and with the subsea facilities scheduled to be decommissioned in 2021.

Renewables Power Investments
Investments in the Leikanger hydropower and Metsälamminkangas windfarm renewables power projects in 2020 is USD 100 million, representing approximately eight percent of the Company’s total capital spend, which also reflects the intention to farm-down 50% of the 100% acquired interest in the Metsälamminkangas project.

2020 Capital Markets Day information
Lundin Petroleum will be hosting its 2020 Capital Markets Day on 31 January 2020 at 11.00 CET (10.00 GMT) at the London Stock Exchange. The Capital Markets Day will include presentations by the Company’s management team on its fourth quarter 2019 financial results, the business strategy, the 2020 budgeted development campaign and its exploration and appraisal programme.

Details for the live webcast:
Sweden +46 8 56642651
UK +44 3333000804
United States +1 6319131422
Norway +47 23500243

Access Pin : 58812582

Link : https://lundinpetroleum.videosync.fi/2020-01-31-q4_cmd

 

Proposed 2019 dividend of USD 1.80 per share corresponding to USD 511 million

Proposed 2019 dividend of USD 1.80 per share corresponding to USD 511 million

Proposed 2019 dividend of USD 1.80 per share corresponding to USD 511 million

31 January 2020

The Board of Directors of Lundin Petroleum AB (Lundin Petroleum) proposes a 2019 dividend of USD 1.80 per share, corresponding to USD 511 million.

In accordance with the dividend policy as announced on 30 January 2019, the Board of Directors will propose to the 2020 Annual General Meeting a dividend for 2019 of USD 1.80 per share, corresponding to USD 511 million (rounded off), to be paid in quarterly instalments of USD 0.45 per share, corresponding to USD 128 million (rounded off). Before payment, each quarterly dividend of USD 0.45 per share shall be converted into a SEK amount, and paid out in SEK, based on the USD to SEK exchange rate published by Sweden’s central bank (Riksbanken) four business days prior to each record date (rounded off to the nearest whole SEK 0.01 per share). The final USD equivalent amount received by the shareholders may therefore slightly differ depending on what the USD to SEK exchange rate is on the date of the dividend payment. The SEK amount per share to be distributed each quarter will be announced in a press release four business days prior to each record date.

Information about the proposed dividend to be paid out as follows:

Expected Ex-dividend dateExpected Record dateExpected payment date
1 April 20202 April 20207 April 2020
2 July 20203 July 20208 July 2020
1 October 20202 October 20207 October 2020
30 December 20204 January 20218 January 2021

In order to comply with Swedish company law, a maximum total SEK amount shall be pre-determined to ensure that the dividend distributed does not exceed the available distributable reserves of the Company and such maximum amount for the dividend has been set to a cap of SEK 9.203 billion (i.e. SEK 2.301 billion per quarter). If the total dividend would exceed the cap of SEK 9.203 billion, the dividend will be automatically adjusted downwards so that the total dividend corresponds to the cap of SEK 9.203 billion.

 

Launch of the Decarbonisation Strategy targeting carbon neutrality by 2030 and proposed name change to Lundin Energy AB

Decarbonisation Strategy and proposed name change to Lundin Energy AB

Launch of the Decarbonisation Strategy targeting carbon neutrality by 2030 and proposed name change to Lundin Energy AB

27 January 2020

Lundin Petroleum AB (Lundin Petroleum) is pleased to announce the launch of its Decarbonisation Strategy, which targets carbon neutrality by 2030. In relation to this, and to better reflect the business today and the clear actions and targets towards a lower carbon future, the Board is proposing to change the name of the Company to Lundin Energy AB.

Decarbonisation Strategy
Lundin Petroleum recognise the challenges of climate change combined with the increasing energy needs linked to growing global population, the international community’s commitment to reduce global carbon emissions and the role that forward-thinking companies can play in this. With the Decarbonisation Strategy, the Company has formalised its ongoing commitment to reduce its carbon footprint to the lowest possible levels, through an effective combination of emissions reductions, energy efficiency, targeted research and development and carbon capture mechanisms. Also, as previously announced investment in renewable energy projects will be undertaken to replace net electricity consumption, providing these generate a good return to shareholders on a leveraged basis.

Roadmap to carbon neutrality by 2030:
• From 2020 limit average operated and non-operated portfolio carbon intensity to below 4kg CO2 per boe and from 2023 to below 2kg CO2 per boe
• In 2022 fully electrify Edvard Grieg and Johan Sverdrup Phase 2, to achieve carbon intensity for these assets of less than 1kg CO2 per boe
• From 2022 replace all net electricity usage from power from shore, through investments in renewable power generation
• To offset all business and operationally related air travel emissions through natural carbon capture, effective from 2018
• By 2030 achieve carbon neutrality across our operations as an oil and gas producer

Proposed name change to Lundin Energy AB
The Board of Lundin Petroleum is proposing to change the name of the Company to Lundin Energy AB. The proposed name change remains subject to shareholder approval at the Company’s Annual General Meeting on 31 March 2020.

The Board believes that with the production growth pathway set towards the target of 200 Mboepd, coupled with sustainable, industry leading low operating costs and a carbon intensity which will be below 2 kg CO2 per boe in 2023 versus the world average of 18 kg CO2 per boe, it is clear that the Company is transforming what it delivers as well as how it is delivered. Lundin Energy better reflects what the Company is doing as an explorer and producer today and its role in supplying the energy transition with the most sustainable oil and gas production possible as an essential part of the future energy mix.

Alex Schneiter, President and CEO of Lundin Petroleum commented:
“I am personally very proud to announce the launch of our Decarbonisation Strategy, through which we are seeking to formalise our commitment to reducing emissions and our carbon footprint, in order to supply the growing demand for all types of energy with the most sustainably produced product we can. We have a target of 2030 to reach carbon neutrality across our operations and we have set out a realistic and deliverable pathway towards this, which clearly differentiates us as an independent oil and gas producer in our industry.

“I am also pleased to announce that the Board is proposing to change the name of the Company to Lundin Energy. It represents our ambition to become carbon neutral, our position as a leading provider of oil and gas in the future and recognition of our role in the changing energy mix.”

 

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Decarbonisation Strategy
27.01.2020, 159.92 KB

Update on Q4 2019 financial results and webcast details for 31 January 2020

Q4 financial update

Update on fourth quarter 2019 financial results and
webcast details for 31 January 2020

15 January 2020

Lundin Petroleum AB (Lundin Petroleum) will publish its financial report for the fourth quarter 2019, on Friday 31 January 2020. For the fourth quarter 2019, Lundin Petroleum will expense pre-tax exploration costs of approximately MUSD 41, expense pre-tax decommissioning costs of approximately MUSD 19 and recognise a largely non-cash net foreign exchange gain of approximately MUSD 106.

Exploration costs
For the fourth quarter of 2019, Lundin Petroleum will incur pre-tax exploration costs of approximately MUSD 41 which will be charged to the income statement and offset by a tax credit of approximately MUSD 32. The exploration costs are mainly related to the dry or non-commercial wells on the Toutatis prospect (PL896), the Gladsheim prospect (PL921) and the Enniberg prospect (PL917).

Decommissioning costs
For the fourth quarter of 2019, Lundin Petroleum will incur pre-tax decommissioning costs of approximately MUSD 19, which will be charged to the income statement and offset by a tax credit of approximately MUSD 15. The decommissioning costs are related to expected increases in site restoration costs for the Brynhild and Gaupe fields.

Net debt and foreign exchange gain
The net debt position of Lundin Petroleum at 31 December 2019 amounted to USD 4.0 billion resulting in available liquidity of USD 1.0 billion within its USD 5.0 billion reserve-based lending facility.

Lundin Petroleum will recognise a net foreign exchange gain of approximately MUSD 106 for the fourth quarter of 2019. Both the Norwegian Krone and Euro strengthened against the US Dollar by approximately 3 percent during the fourth quarter of 2019. 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 under/overlift balances
Lundin Petroleum 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 2019, Lundin Petroleum was overlifted by 0.1 Mboepd offset by an increase in inventory balances, related to the filling of the Johan Sverdrup pipeline, of 2.7 Mboepd.

Fourth Quarter 2019 results and Capital Markets Day 2020
Lundin Petroleum’s financial report for the fourth quarter 2019, will be published on Friday 31 January at 07:30 CET.

Lundin Petroleum management team will present its financial results for the fourth quarter 2019 and capital markets day presentation by webcast at 11:00 CET (10:00 GMT) on the 31 January. Please follow the event live at www.lundin-petroleum.com or dial in using the following telephone numbers with the pin code shown below:

Sweden +46 8 56642651
UK +44 3333000804
United States +1 6319131422
Norway +47 23500243

Access Pin : 58812582

Link : https://lundinpetroleum.videosync.fi/2020-01-31-q4_cmd

 

Lundin Petroleum announces increased reserves for sixth consecutive year

Lundin Petroleum announces increased reserves for sixth consecutive year

Lundin Petroleum announces increased reserves and contingent resources

13 January 2020

Lundin Petroleum AB (Lundin Petroleum) is pleased to announce that as at 31 December 2019, its proved plus probable net reserves (2P reserves) are 693 million barrels of oil equivalent (MMboe), its proved plus probable plus possible net reserves (3P reserves) are 858 MMboe and its best estimate net contingent resources (contingent resources) are 185 MMboe. The 2P reserves replacement ratio for 2019 is 150 percent and this is the sixth consecutive year that Lundin Petroleum has more than replaced production.1

Lundin Petroleum’s 2P reserves as at 31 December 2019 are 693.3 MMboe and reflect a positive revision of 52.1 MMboe, excluding asset transactions. The 3P reserves as at 31 December 2019 are 857.5 MMboe and reflect a positive revision of 73.4 MMboe, excluding asset transactions 2,3

 

2P Reserves3P Reserves
End 2018 745.4900.9
– Disposal of 2.6% interest in Johan Sverdrup-69.6-82.0
End 2018 adjusted 675.9818.8
  – Produced4-34.7-34.7
  + Revisions+52.1+73.4
End 2019693.3857.5
Reserves replacement ratio5150%212%

 

The increase in reserves relates to project sanctions for Solveig Phase 1, the Rolvsnes Extended Well Test and the Edvard Grieg infill well programme, with the contingent resources associated with these projects being promoted to reserves. Oil accounts for 93 percent of Lundin Petroleum’s 2P reserves and the majority of the reserves are associated with fields in production.

Edvard Grieg production performance continues to exceed expectations with significantly slower build-up of water production than anticipated. With the sanction of the Edvard Grieg infill well programme, the best estimate gross ultimate recovery from Edvard Grieg as at 31 December 2019, which is cumulative production plus 2P reserves, is increased to 300 MMboe, representing a 60 percent increase from the original PDO. With the increased reserves at Edvard Grieg, combined with Solveig Phase 1 and the Rolvsnes Extended Well Test, which will be produced through the Edvard Grieg facilities, the production plateau will be maintained at the contractually available facilities capacity until at least the end of 2022, representing a four-year extension compared to the original Edvard Grieg PDO.

First oil from the Johan Sverdrup field occurred in October 2019 and production has ramped up quickly from the eight pre-drilled production wells, to reach around 350 Mbopd gross, which is about 80 percent of Phase 1 facilities capacity of 440 Mbopd. The drilling of two new production wells will be required to achieve Phase 1 plateau, which is expected in the summer of 2020. Initial Johan Sverdrup reservoir performance is excellent and well productivities are above expectations. Further production experience is needed to justify an update to the reserves estimate.

Lundin Petroleum’s contingent resources as at 31 December 2019 are 185 MMboe, a reduction of 40 MMboe from year end 2018, primarily due to the projects which were promoted to reserves. New discoveries on Jorvik and Tellus East, the addition of an improved recovery project at Edvard Greig involving water alternating gas injection (WAG), as well as the acquisition of an additional 30 percent interest in the Rolvsnes discovery have contributed to increases.

The contingent resource estimate for the Alta discovery has been adjusted downwards based on evaluation of the high specification 3D seismic survey (Topseis) acquired over the area, combined with the extensive data and analysis from the well drilled for the extended well test conducted in 2018. A standalone development of the Alta and nearby Gohta discoveries is no longer considered to be commercial, and a subsea tie-back development to either Johan Castberg or another future host development in the area is considered the most viable option. Lundin Petroleum is drilling several large prospects in the Loppa High area in 2020, which if successful could change the dynamic of commercial options for this area.

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 to 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, COO of Lundin Petroleum commented:
“This has been the sixth consecutive year in which we have more than replaced our produced barrels, whilst in the same period production has increased by four times; which is a testament to the quality of the asset base and organic growth model. In 2019, we increased reserves by moving three new projects in the Edvard Grieg area from the appraisal phase into development, adding high value barrels that significantly extend the Edvard Grieg production plateau. I am confident we will see further reserves and resources growth as we continue to mature the portfolio and kick off another busy year with the drill bit in 2020.”

1 Relates to Lundin Petroleum’s portfolio in Norway.
2 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.
3 The reserves were calculated using ERCE’s forecasted nominal Brent oil price of USD 66 per barrel in 2020, 68 in 2021, 70 in 2022, 72 in 2023, 74 in 2024, 75 in 2025, 77 in 2026, 78 in 2027, 80 in 2028, 81 in 2029 and increasing by 2 percent per year thereafter.
4 Reserves 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.

The fourth quarterly instalment of the dividend for 2018

The fourth quarterly instalment of the dividend for 2018

The fourth quarterly instalment of the dividend for 2018 of USD 0.37 per share will amount to SEK 3.47 per share

27 December 2019

Lundin Petroleum AB (Lundin Petroleum) announces that the fourth quarterly instalment of the dividend for 2018 of USD 0.37 per share will amount to SEK 3.47 per share, with a total amount of SEK 986 million, corresponding to approximately USD 105 million. The expected payment date for the fourth quarterly instalment is 9 January 2020.

Information about the fourth quarterly instalment of the dividend:

Amount per share
(SEK)
Total dividend amount
(SEK)
Ex-dividend dateRecord dateExpected payment date
3.47986 million2 January 20203 January 20209 January 2020

In accordance with the updated dividend policy announced by Lundin Petroleum on 30 January 2019, the Annual General Meeting held on 29 March 2019 resolved on a dividend for 2018 of USD 1.48 per share, to be paid in quarterly instalments of USD 0.37 per share.

According to the dividend resolution, before payment, each quarterly dividend of USD 0.37 per share shall be converted into a SEK amount based on the USD to SEK exchange rate published by Sweden’s central bank (Riksbanken) four business days prior to each record date (rounded off to the nearest whole SEK 0.01 per share) and the exchange rate used for the conversion is 9.3808.

Information about the approved dividend is available on www.lundin-petroleum.com.

1 The estimated total amount of the dividend as previously communicated has been reduced as a result of Lundin Petroleum completing the redemption of 16 percent of its shares in issue in August 2019.

 

Lundin Petroleum audiocast – Q3 report 2019 presentation

Lundin Petroleum audiocast - Q3 report 2019 presentation

Lundin Petroleum audiocast – Q3 report 2019 presentation

31 October 2019

Listen to Alex Schneiter, President and CEO, and Teitur Poulsen, CFO, commenting on the report at an audiocast held on Thursday 31 October 2019 at 09.00 CET.

Follow the presentation live on www.lundin-petroleum.com or dial in using the following telephone numbers:
Sweden: +46 8 519 993 55
Norway: +47 23 500 211
UK: +44 203 194 05 50
International Toll Free: +1 855 269 26 05

Audiocast link

 


Report for the nine months ended 30 September 2019

Report for the nine months ended 30 September 2019

Report for the nine months ended 30 September 2019

31 October 2019

· Production above mid-point guidance for the nine months at 79.2 Mboepd and Q3 at 82.7 Mboepd
· Production ramp up from Johan Sverdrup Phase 1 above 200 Mboepd gross as at end of October 2019, following first oil on 5 October 2019, ahead of schedule and under budget
· 2019 production guidance raised to 90 to 95 Mboepd from 75 to 95 Mboepd, following early start up from Johan Sverdrup and continued outperformance from Edvard Grieg
· Strong financial performance for the reporting period and third quarter
· Completion of 2.6 percent sale of Johan Sverdrup and 16 percent shares redemption with Equinor in August 2019
· Plan to fully electrify Edvard Grieg as part of the Utsira High Area power grid finalised, increasing uptime efficiency further and continuing our emissions trajectory to below 1kg CO2 per boe from the Johan Sverdrup and Edvard Grieg fields

 

Financial summary1 Jan 2019-
30 Sep 2019
9 months
1 Jul 2019-
30 Sep 2019
3 months
1 Jan 2018-
30 Sep 2018
9 months
1  Jul 2018-
30 Sep 2018
3 months
1 Jan 2018-
31 Dec 2018
12 months
Production in Mboepd79.282.780.878.281.1
Revenue and other income in MUSD2,199.01,215.01988.5604.62,640.7
Operating cash flow in MUSD11,158.9380.01,412.8434.41,864.1
EBITDA in MUSD11,222.9411.31,451.8476.81,932.5
Free cash flow in MUSD1,117.9950.5489.7228.7663.0
Net result in MUSD669.6519.9323.956.7225.7
Adjusted net result in MUSD173.845.4220.175.1295.3
Earnings/share in USD2.051.720.960.170.67
Adjusted earnings/share in USD0.530.150.650.220.87
Net debt in MUSD4,054.94,054.93,569.93,569.93,398.2
1 Excludes the reported after tax accounting gain of MUSD 756.7 on the divestment of a 2.6 percent working interest in the Johan Sverdrup project.


Comments from Alex Schneiter, President and CEO of Lundin Petroleum:

“I am pleased to announce another very good quarter of operational and financial performance. The Company’s production currently stands at over 120 Mboepd and as a result of continued outperformance from Edvard Grieg and an earlier startup and quicker ramp up of the pre-drilled wells at Johan Sverdrup, we are raising the production guidance for the year to between 90 and 95 Mboepd.

“A stand out moment for us was first oil from the world class Johan Sverdrup Phase 1 project, which was achieved on 5 October 2019, ahead of schedule and significantly below budget. Since then production has been ramping up ahead of expectations, as the eight pre-drilled wells are progressively commissioned and as at the end of October 2019, the field was producing above 200 Mboepd gross from five wells. It is now anticipated that all of the eight pre-drilled wells will be on production during November 2019. We will then drill the remaining two to four new wells required to achieve Phase 1 plateau production of 440 Mbopd, which is expected by summer 2020.

“Our other production assets continue to perform well, with operating costs at industry leading levels and in line with our guidance for the year. Edvard Grieg continues to exceed expectations with uptime and production above forecast. With the approval of the new infill drilling programme in 2020, we are now anticipating the gross ultimate proved plus probable reserves will be over 300 MMboe as compared to the original PDO of 186 MMboe. This is a fantastic indictment to the quality of this field.

“As an important development we’ve now sanctioned the full electrification of the Edvard Grieg facility as part of the Utsira High Area power grid, which is being developed together with Johan Sverdrup Phase 2. This project will result in a significant reduction in CO2 emissions from the field, taking Edvard Grieg Area CO2 emissions below 1 kg per barrel. This will mean that our two key assets, Edvard Grieg and Johan Sverdrup, will have emissions of below 1kg CO2 per boe, about twenty times lower than the world average and one of the lowest for any offshore operator. This is in line with the Board endorsed Sustainable Energy Strategy, which will provide the Company with the roadmap to continue to be one of the most efficient offshore oil and gas producers in terms of low emissions per barrel produced, as well as increased operating efficiency. Our aim is to continue to further reduce our carbon footprint and increase overall efficiency through new investments and innovative approaches. In this regard, the investment in a hydro power project in Norway to offset the Company’s net non-renewable electricity usage for power from shore, is in line with this strategy.

“Looking ahead to the rest of the year; we remain in the intensive ramp up period at Johan Sverdrup and development operations at Solveig and Phase 2 of Johan Sverdrup are progressing on schedule. It will also be another busy period for us with the exploration drill bit, focussed north of the Utsira High and in the North Norwegian Sea, targeting net unrisked resources of 130 MMboe for the remainder of the year and a significant exploration drilling programme is taking shape for 2020 as we continue to drive our organic growth strategy. This is the 17th quarter of production delivery on or above expectations and I look forward to updating shareholders in January 2020 on the full year 2019 progress.”

Audiocast presentation
Listen to Alex Schneiter, President and CEO, and Teitur Poulsen, CFO, commenting on the report at an audiocast held on Thursday 31 October 2019 at 09.00 CET.

Follow the presentation live on www.lundin-petroleum.com or dial in using the following telephone numbers:
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UK: +44 203 194 05 50
International Toll Free: +1 855 269 26 05

Audiocast link

 

Downloads

Letter to shareholders – 18 August 2020

Operations and financial update – Q2 2020