Quarterly Report • Jul 13, 2023
Quarterly Report
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OKEA ASA Q2 quarterly and half year report
2023
(Amounts in parentheses refer to previous quarter)
Production in the second quarter was in line with previous quarter despite the planned maintenance shutdown at Draugen. This was due to solid performance at key assets, production from the Talisker East well on Brage coming on stream in May, and improving performance at both Yme and Nova. We expect that production will further increase in the second half of the year as additional wells come on stream and the major maintenance work planned for the year already completed.
The solid production contributed to revenues increasing by 67% in the first half of 2023 compared to the same period last year, and OKEA generated more than NOK 1.4 billion cash in the same period.
Yme was again impacted by an impairment due to lowered expectations for realised prices going forward. We expensed NOK 300 million in the quarter which reduces net profit after tax by NOK 66 million. On a positive note, production reliability at Yme has steadily improved over the last year up to a reasonable level of 90% this quarter.
Closing of the Statfjord transaction is progressing towards completion in the fourth quarter. Despite some reductions in expected production for 2023, the transaction significantly enhances OKEA's production and reserves as well as further increasing diversification. The production forecast for 2024 and reserves estimates remain unchanged.
Market fundamentals for our industry remain strong and we remain committed to our growth strategy.
Svein J. Liknes, Chief Executive Officer
| Unit | Q2 2023 | Q1 2023 | Q2 2022 4) | Full year 2022 4) |
|
|---|---|---|---|---|---|
| Total operating income | MNOK | 1,707 | 2,954 | 1,332 | 6,653 |
| EBITDA 1) | MNOK | 1,167 | 1,592 | 928 | 4,758 |
| EBITDAX 1) | MNOK | 1,291 | 1,615 | 954 | 5,085 |
| Profit/loss (-) before income tax | MNOK | 391 | 1,121 | 532 | 3,215 |
| Net profit / loss (-) | MNOK | 69 | 226 | 28 | 670 |
| Net cash flow from operations | MNOK | 1,401 | 1,318 | 699 | 3,344 |
| Net cash flow used in investments | MNOK | -535 | -686 | -304 | -2,434 |
| Net cash flow used in financing activities | MNOK | -192 | -134 | -196 | -1,969 |
| Net interest-bearing debt (IBD) 1) | MNOK | -511 | 149 | -49 | 583 |
| Net IBD ex. other int. bearing liabilities1) | MNOK | -1,042 | -378 | -576 | 75 |
| Net production | Boepd 2) | 22,263 | 22,210 | 16,039 | 16,736 |
| Third-party volumes available for sale 3) | Boepd 2) | 332 | 448 | 849 | 596 |
| Over/underlift/inventory adjustments | Boepd 2) | 187 | 15,283 | -931 | -1,080 |
| Net sold volume | Boepd 2) | 22,782 | 37,941 | 15,957 | 16,252 |
| Production expense per boe 1) | NOK/boe | 223 | 241.8 | 234.7 | 236.8 |
| Realised liquids price | USD/boe | 70.1 | 77.7 | 100.3 | 98,4 |
| Realised gas price | USD/boe | 81.2 | 116.3 | 82.4 | 138.5 |
1) Definitions of alternative performance measures are available on page 36 of this report
2) Boepd is defined as barrels of oil equivalents per day
3) Sold volumes include net compensation volumes received from Duva and paid by Nova (tie-in to Gjøa)
4) In 2022, activities from assets acquired from Wintershall Dea were included in the statement of comprehensive income and key figures for November and December only; volumes (boepd) were divided by 365 days in the year
Total operating income in the second quarter was NOK 1,707 (2,954) million, whereof NOK 1,641 (2,929) million related to revenue from liquids and gas sales. The lower operating income compared to previous quarter follows from recovery of a significant underlift position in the previous quarter. The average realised crude price for the quarter was USD 76.4 (80.6) per boe. The NGL discount amounted to USD 6.3 (2.9) per boe which resulted in an average realised liquids price of USD 70.1 (77.7) per boe. Average realised price for gas was USD 84.2 (116.3) per boe, of which USD 23.3 per boe was attributable to realised gain on fixed price contracts.
Other operating income/loss (-) of NOK 66 (25) million consisted of tariff income at Gjøa of NOK 39 (32) million, change in fair value of the contingent consideration to Wintershall Dea of NOK 18 (-16) million, income from joint utilisation of logistic resources of NOK 8 (3) million, and a net gain from financial oil and gas hedging of NOK 5 (6) million.
Production expenses amounted to NOK 495 (518) million, corresponding to NOK 223 (242) per boe. The reduction in production expense per boe compared to previous quarter was due to reduced expenses from the asset portfolio.
Changes in over-/underlift positions and production inventory amounted to an income of NOK 126 (expense of 793) million. Sold volumes exceeded produced volumes by 518 (15,731) boepd in the quarter. The net income effect of the over-lift in the quarter is a result of differing unit production cost in the portfolio of assets. The high overlift expense in the previous quarter was mainly due to lifting of volumes held at fair value in the balance sheet following the purchase price allocation on Brage, as well as recovery of a significant underlift position during the quarter.
Net sold volumes from third-party compensation received from Duva and Nova (tie-ins to Gjøa) amounted to 332 (448) boepd.
Exploration and evaluation expenses amounted to NOK 124 (24) million. The high exploration expense in the quarter was mainly attributable to seismic purchases of NOK 80 million, as well as NOK 21 (4) million relating to work with maturing the Brasse discovery. Area fees and various field evaluation activities amounted to NOK 23 (20) million.
An impairment charge of NOK 300 (94) million was recognised on the Yme asset in the quarter. The impairment was driven by adverse developments in expected realised prices during the quarter. The related tax income amounted to NOK 234 (66) million, resulting in a net after tax impact of NOK 66 (21) million. Impairment in the previous quarter was mainly due to somewhat reduced recoverable reserves. As Yme is carried at fair value, any adjustments to asset performance and/or macro assumptions will result in impairments or reversal of previous impairments also going forward.
General and administrative expenses amounted to NOK 47 (28) million and represent OKEA's share of costs after allocation to licence activities. The high expense in the quarter was mainly due to advisor fees relating to business development activities.
Net financial items amounted to NOK -115 (-49) million. Interest income amounted to NOK 22 (10) million. Expensed interest amounted to NOK -30 (-37) million. Net foreign exchange gain/loss (-) amounted to NOK - 110 (-30) million following a weakened NOK compared to USD and GBP in the quarter. The foreign exchange loss was mainly attributable to FX-derivative contracts. For further details on financial items, reference is made to note 14.
Profit / loss (-) before tax amounted to NOK 391 (1,121) million.
Tax expenses (-) / tax income (+) amounted to NOK -322 (-894) million and represents an effective tax rate of 82% (80%). The deviation from the expected 78% was mainly due to financial expense being deductible at a lower tax rate, partly offset by the tax effect of uplift. In addition, the change in fair value of the contingent consideration to Wintershall Dea is not taxable.
Net profit / loss (-) for the quarter was NOK 69 (226) million. Earnings per share amounted to NOK 0.66 (2.18).
Goodwill amounted to NOK 1,292 (1,292) million consisting of NOK 1,129 (1,129) million in technical goodwill and NOK 163 (163) million in ordinary goodwill. Reference is made to note 27 for further information.
Oil and gas properties amounted to NOK 6,416 (6,496) million. The decrease mainly relates to impairment of the Yme asset of NOK 300 (94) million and depreciation of producing assets of NOK 351 (316) million. This effect was partly offset by investments of NOK 525 (405) million mainly relating to the Hasselmus development, Draugen power from shore, Draugen modifications and Brage production well drilling.
Right-of-use assets amounted to NOK 216 (225) million and mainly related to logistical resources on operated assets and lease of offices. The decrease in the quarter was due to IFRS 16 depreciation.
Non-current asset retirement reimbursement rights amounted to NOK 3,405 (3,760) million and related to Shell's and Wintershall Dea's obligations to cover decommissioning costs for Draugen/Gjøa and Brage respectively. The decrease was mainly due to an increase in the discount rate applied for estimating the net present value of OKEA's receivables.
Trade and other receivables amounted to NOK 1,362 (1,793) million and comprise accrued revenue, working capital from joint venture licences and underlift of petroleum products.
Cash and cash equivalents amounted to NOK 2,335 (1,634) million. The increase in cash balance was mainly due to high cash flows from operations exceeding cash flows used for investment and financing activities.
Spare parts, equipment and inventory amounted to NOK 714 (473) million, whereof NOK 424 (193) million related to oil inventory at Draugen, Brage and Yme. The increase was mainly due an increase in oil storage.
Equity amounted to NOK 2,165 (2,200) million, corresponding to an equity ratio of 13% (14%). The decrease was due to the dividend payment of NOK 104 million exceeding net profit after tax of NOK 69 million.
Non-current provision for asset retirement obligations amounted to NOK 5,613 (5,958) million. The decrease was due to an increase in the discount rate applied for the estimation. The obligations are largely offset by the asset retirement reimbursement rights outlined above.
Interest-bearing bond loans amounted to NOK 1,292 (1,255) million. The increase was due to an unrealised foreign exchange loss on the OKEA03 bond, which is nominated in USD.
Total other interest-bearing liabilities amounted to NOK 531 (528) million, whereof the non-current portion was NOK 479 (479) million and the current portion was NOK 51 (49) million. The amount represents OKEA's share of the net present value of the future obligations under the bareboat charter (BBC) agreement for Yme on the Inspirer rig. Reference is made to note 23 for further details.
The lease liability relating to IFRS 16 is split into a non-current liability of NOK 196 (204) million and a current liability of NOK 50 (50) million and represents the liability of the right-of-use assets as described above.
Trade and other payables amounted to NOK 1,960 (1,548) million and mainly related to payments received under payment quantity agreements, accrued expenses, and working capital from joint venture licences. In addition, liabilities for the FX forward contracts have increased as the NOK have weakened against GBP during the quarter.
Income tax payable was NOK 1,238 (1,429) million, mainly consisting of accrued tax payable for the first half of 2023.
Net cash flows from operating activities amounted to NOK 1,401 (1,318) million, accounting for taxes paid of NOK 333 (166) million. The increase in net cash flows from operating activities was mainly due to payments for two (one) Draugen cargos received in the quarter. The first estimate for tax payable for 2023 was submitted to the Oil Taxation Office in June and has been set to NOK 276 million per instalment. The first of a total of six instalments is due in August.
Net cash flows used in investment activities amounted to NOK -535 (-686) million. Investments in the quarter include oil and gas properties of NOK -505 (-390) million, mainly relating to the Hasselmus gas development, Draugen power from shore, Draugen modifications and production well drilling at Brage. In addition, NOK 21 (0) million was paid to Wintershall Dea in contingent consideration related to the acquisition of assets. In the previous quarter, a deposit of NOK 263 million was paid to Equinor for the acquisition of 28% in PL037 (Statfjord Area).
Net cash flows used in financing activities was NOK -192 (-135) million and mainly related to dividend payments of NOK -104 (-104) million and interest payments of NOK -68 (-11) million.
OKEA uses derivative financial instruments and forward sales to manage exposures to fluctuations in commodity prices and foreign exchange rates. In the second quarter, OKEA realised a total gain of NOK 121 million on hedging positions, comprising of gain on forward sale of gas recognised as operating income of NOK 137 million and a realised loss on financial hedging positions of NOK -16 million.
On 30 June, OKEA had sold forward ~14% of the estimated net after tax exposure for natural gas for the third quarter of 2023 at an average price of 89 GBp/th, ~16% for the fourth quarter of 2023 at an average price of 127 GBp/th, and ~10% for the first three quarters of 2024 at an average price 124 GBp/th. In addition, OKEA had entered into financial hedging agreements for approximately 37% of the estimated net after tax exposure for oil for the third quarter of 2023 consisting of collars with price floors around 72-75 USD/bbl and ceilings around 90-105 USD/bbl. The company had also hedged 22% of the estimated net after tax exposure for the fourth quarter of 2023 with collars with price floors at 72 USD/bbl and ceilings around 81-105 USD/bbl.
OKEA's net production in the quarter was 22,263 (22,210) boepd. Production was in line with previous quarter despite the planned turnaround at Draugen due to start of production from the new Talisker East well at Brage in May and improved production performance at Yme and Nova.
| Unit | Q2 2023 | Q1 2023 | Q2 2022 4) | Full year 2022 4) |
|
|---|---|---|---|---|---|
| Draugen – production reliability1)1 | % | 94 | 96 | 99 | 96 |
| Draugen – production availability2)2 | % | 60 | 96 | 98 | 94 |
| Brage – production reliability3 | % | 94 | 92 | N/A | N/A |
| Brage – production availability4 | % | 90 | 91 | N/A | N/A |
| Gjøa – production reliability | % | 99 | 100 | 97 | 90 |
| Gjøa – production availability | % | 97 | 99 | 89 | 92 |
| Yme – production reliability | % | 90 | 64 | 23 | 28 |
| Yme – production availability | % | 84 | 55 | N/A | 21 |
| Ivar Aasen – production availability | % | 94 | 90 | 99 | 82 |
| Nova – production availability | % | 96 | 99 | N/A | 81 |
| Draugen – production | Boepd | 4,793 | 6,584 | 7,060 | 6,767 |
| Brage – Production | Boepd | 3,456 | 2,162 | N/A | 383 |
| Gjøa – production | Boepd | 6,240 | 6,812 | 7,107 | 6,932 |
| Yme – production | Boepd | 2,854 | 2,442 | 1,322 | 1,429 |
| Ivar Aasen – production | Boepd | 3,218 | 3,110 | 550 | 1,086 |
| Nova – production | Boepd | 1,702 | 1,100 | N/A | 139 |
| Total net production | Boepd | 22,263 | 22,210 | 16,039 | 16,736 |
| Draugen – sold volume | Boepd | 6,789 | 13,774 | 6,949 | 6,740 |
| Brage – sold volume | Boepd | 605 | 7,078 | N/A | 27 |
| Gjøa – sold volume | Boepd | 7,881 | 7,572 | 6,611 | 7,381 |
| Yme – sold volume | Boepd | 2,542 | 3,628 | 1,448 | 1,157 |
| Ivar Aasen – sold volume | Boepd | 4,632 | 4,508 | 100 | 351 |
| Nova – sold volume | Boepd | 0 | 933 | N/A | 0 |
| Third-party volumes available for sale3) | Boepd | 332 | 448 | 849 | 596 |
| Total net sold volume | Boepd | 22,782 | 37,941 | 15,957 | 16,252 |
| Total over/underlift/inventory adj. | Boepd | 187 | 15,283 | -931 | -1,080 |
1) Production reliability = Actual production / (Actual production + Unscheduled deferment)
2) Production availability = Actual production / (Actual production + Scheduled deferment + Unscheduled deferment)
Deferment is the reduction in production caused by a reduction in available production capacity due to an activity, an unscheduled event, poor equipment performance or sub-optimum settings
3) Net compensation volumes from Duva and Nova received and sold (tie-in to Gjøa)
4) In 2022, activities from assets acquired from Wintershall Dea were included in the statement of comprehensive income and key figures for November and December only; volumes (boepd) were divided by 365 days in the year
Net production to OKEA from Draugen was 4,793 (6,584) boepd in the quarter. Production availability was 66% (96%) and production reliability was 94% (96%).
The reduction in availability and produced volumes was mainly due to downtime during the planned maintenance turnaround which was completed in May. Pull-in of the Hasselmus gas pipeline and other activities were executed in parallel.
A scale squeeze campaign on platform and subsea wells was successfully executed in the quarter and will contribute to safeguarding long-term production from the wells.
Topside installation to prepare for the Hasselmus tie-back is progressing according to schedule and production start is expected in the fourth quarter of 2023. Installation of the Xmas tree subsea is planned for end of July. Topside modifications and installation of early scope for the power from shore project have also commenced.
Seven days of shut in of the subsea wells is planned in July for installation of new upgraded subsea pumps. Production from Draugen is expected to be reduced by ~50% during the shut in period.
The observation well drilling campaign on the Springmus East prospect and Garn West South area started in early July from the Transocean Endurance rig.
Net production to OKEA from Brage was 3,456 (2,162) boepd in the quarter. Production availability was 90% (91%) and production reliability was 94% (92%). Production from the Talisker East well commenced in May which increased production by 60% compared to previous quarter. Planning for drilling of a water injector and a second producer in Talisker East is ongoing.
Production drilling on the Brage platform is expected to continue in the coming years, targeting infill wells and the development of new resources. The Sognefjord gas producer was completed during the quarter, and is currently being prepared for production start-up during the third quarter. Drilling of a well to Fensfjord south commenced in the quarter with production start-up scheduled for the fourth quarter. The pilot well to the Kim prospect confirmed new oil resources that will be evaluated for a potential development well from the Brage platform.
A plan for development and operation (PDO) for Cook was submitted in the quarter with government approval expected in the third quarter. The associated Cook oil production well is planned drilled in the third quarter with production start-up expected in the fourth quarter. With the additional production from wells to come on stream later this year, Brage is expected to reach a plateau of approximately 6,000 boepd net to OKEA in the fourth quarter.
Concept studies for a Brasse tie-in to Brage were completed during the quarter and work towards a concept decision (DG2) is progressing.
Net production to OKEA from Gjøa was 6,240 (6,812) boepd in the quarter. Production reliability was 99% (100%). The reduced production was mainly a result of natural decline. Net delivered and sold compensation volumes from Duva and Nova was 332 (448) boepd in the quarter. 4-6 days maintenance shut-down of the platform is planned for late August.
Further maturation of potential development scenarios of the Hamlet discovery is ongoing. Other IOR (Increased Oil Recovery) targets are also evaluated within the PL153/153 C license utilising new reprocessed seismic data. The earliest start of production for these targets are 2028/2029. Evaluations to identify potential synergies with other potential developments to further reduce costs continues.
Options to appraise the Aurora discovery and drill the Selene prospect in PL195 west of Gjøa are still under review.
Net production to OKEA from Yme was 2,854 (2,442) boepd in the quarter. Production reliability is improving with an average of 90% (64%) for the quarter.
One producer well has been drilled in the Yme Gamma campaign and is expected to come on stream during July 2023. The well is expected to contribute to lifting the plateau production to approximately 5,000 boepd net to OKEA. Two more producers and one injector are on track for drilling by end of 2023.
Net production to OKEA from Ivar Aasen was 3,218 (3,110) boepd with a production availability of 94% (90%).
Two wells (D-8 and D-9) from the IOR 2022 campaign are planned converted to water injectors for pressure support. This is scheduled for the fourth quarter for D-8. Timing for D-9 is still under assessment. Plans for an IOR 2024 campaign are progressing towards a concept decision (DG2).
Net production to OKEA from Nova was 1,702 (1,100) boepd in the quarter. Technical production reliability was 96% (99%) in the quarter.
Production from Nova has improved during the quarter, but is still limited by reduced effectiveness of the water injectors. A side-track drilling operation to improve the location of one of the injector wells has been completed with expected injection start in the third quarter. A rig has been secured to drill a fourth water injector well in the first half of 2024.
On 20 March, OKEA entered into an agreement with Equinor Energy AS to acquire 28% working interest (WI) in PL037 (Statfjord Area) with effective date 1 January 2023.
The acquired portfolio comprises 23.93123% WI in Statfjord Unit, 28% WI in Statfjord Nord, 14% WI in Statfjord Øst Unit and 15.4% WI in Sygna Unit and adds net 2P reserves of 41 mmboe and net 2C resources of 8 mmboe. Additional upside volume potential estimated to net 14 mmboe, has been identified by OKEA, based on drilling beyond 2028 and cost reduction initiatives.
The acquisition includes an initial fixed consideration of USD 220 million, of which USD 25 million were paid in March. In addition, the agreement contains a contingent consideration structure based on profit sharing on crude oil volumes sold as well as on dry gas volumes sold during the period 2023 – 2025.
Following the announcement of the transaction, expected additional production to OKEA for 2023 has been adjusted from 13,000 – 15,000 boepd to 11,000 – 13,000 boepd. The adjustment mainly relates to reduced production efficiency and unforeseen events such as prolonged turn-around at Statfjord C and unplanned shutdown at Statfjord A. The operator has strengthened focus and procedures to reduce wells shut-in periods, improving production efficiency and reduce time to get new wells onstream. The forecast for 2024 remains unchanged to 16,000 – 20,000 boepd net to OKEA. Reserves estimates remain unchanged.
As operator of Draugen, OKEA is currently developing the Hasselmus field as a single subsea gas well with direct tie-back to the Draugen platform for further processing and export. Production start is expected in the fourth quarter of 2023 with a gross plateau gas production at 4,400 barrels boepd.
The project is progressing according to plan and budget. A key project milestone was achieved when the 8 km flowline from Hasselmus to Draugen was successfully installed in May. The compressor train was also upgraded during the turnaround. Remaining subsea equipment and topside construction scope is planned completed in July and August, with the final rock overlay scheduled for end of the third quarter.
OKEA and Equinor in collaboration with the license partners have established a joint project to electrify the Draugen and Njord A platforms.
OKEA is responsible for developing the power infrastructure from shore to Draugen including modifications on Draugen. Equinor is responsible for the cable from Draugen to Njord including modifications on Njord A. Draugen and Njord will be connected to the power grid at Tensio's transformer station at Straum in Åfjord municipality, where Statnett assesses the connection as operationally sound without a need for reinforcement of the power grid.
The PDO and plan for construction and operation was submitted to the Ministry of Petroleum and Energy in the fourth quarter of 2022. Approval is expected in 2023. Following the Ministry of Petroleum and Energy approval of pre-commitments, the project entered into an EPCIC contract with Aker Solutions and a contract with NKT for engineering, production, installation and protection of the power cable from shore to Draugen.
The project will result in annual reductions of CO2 emissions of 200,000 tonnes from Draugen and 130,000 tonnes from Njord. In addition, the project will result in lower cost of operations and extend the economic lifetime of the Draugen field.
OKEA has been informed that a factory fire occurred in one of the project's planned equipment suppliers. The project is currently developing a recovery plan in close cooperation with the supplier to mitigate potential cost and schedule impact. Expected completion of the Draugen project is in 2027.
In December 2022, OKEA entered into an SPA with DNO Norge AS to enter into the Brasse licence (PL740) with 50% WI and effective date 1 January 2023. The transaction and extension of the license was approved by the Ministry of Petroleum and Energy in the first quarter of 2023. The target of the new partnership is to undertake a fast-track, low-cost review to assess whether a value accretive development concept can be found for the estimated 30 mmboe recoverable volumes at Brasse, which is located only 13 km from the OKEAoperated Brage field. The transaction itself was at zero cost to OKEA.
Concept studies for a Brasse tie-in to Brage were completed during the quarter and work towards a concept decision (DG2) is progressing.
A drilling campaign on Draugen commenced in July. Two observation wells will be drilled to assess remaining resources for an Increased Oil Recovery (IOR) opportunity in the Garn West South area and potential undiscovered resources in the Springmus prospect.
Work programmes have been initiated on the four new exploration licences awarded in the APA 2022 round.
There were no actual serious HSE incidents and no serious acute discharges or emissions in OKEA's operations in the second quarter.
As part of the company's strategy, OKEA targets to maintain a clear, credible, and consistent approach to ESG. ESG concerns are embedded in all business and operational activities, as a key element of the licence to operate. Comprehensive ESG reporting is key to realising and communicating our ESG ambitions, activities, and performance. In the second quarter, OKEA was recognised with an A+ classification for the 2022 ESG report from the rating company Position Green.
| Unit | H1 2023 | H1 2022 | |
|---|---|---|---|
| Total operating income | MNOK | 4,661 | 2,845 |
| EBITDA | MNOK | 2,759 | 2,071 |
| Net profit / loss (-) | MNOK | 295 | 241 |
| Cash flow from operations | MNOK | 2,720 | 1,771 |
| Cash flow from investments | MNOK | -1,221 | -590 |
| Cash flow from financing activities | MNOK | -327 | -531 |
(Amounts in parentheses refer to first half of 2022)
Total operating income for the period amounted to NOK 4,661 (2,845) million. The increase was mainly due to more producing assets in portfolio, as Brage and Nova and 6.46% increase in WI in Ivar Aasen was added in the fourth quarter of 2022. Total sold volumes was 22,782 (15,957) boepd.
Production expenses amounted to NOK 1,013 (668) million, equivalent to NOK 232 (214) per boe. The increase in production expense in absolute terms was mainly due to a larger portfolio of producing assets. The increase in production expense per boe was mainly due to new portfolio of assets and turnaround at Draugen in 2023.
EBITDA amounted to NOK 2,759 (2,070) million. The increase in EBITDA was mainly due to the higher operating income following the increased asset base more than offsetting the higher absolute production expense. Changes in over/underlift position resulted in an expense of NOK 667 (income of 94) million. The expense was significantly impacted by lifting of volumes at Brage in February which was recognised at fair value in the purchase price allocation (PPA) following the Wintershall Dea transaction in November 2022.
Impairment (-)/reversal of impairment amounted to NOK -394 (363) million related to the Yme asset, with the corresponding loss(-)/gain after-tax of NOK -87 (80) million.
Net financial items were NOK -164 (-292) million, whereof net foreign exchange rate loss amounted to NOK - 140 (-177) million.
Net profit after tax was NOK 295 (241) million.
Cash flow from operations was NOK 2,720 (1,771) million including taxes paid of NOK 499 (580) million. The increase compared to the previous year was mainly due to the higher EBITDA resulting from higher volumes sold.
Cash flow used in investment activities amounted to NOK -1,221 (-590) million for the period, which mainly related to investments of NOK 894 (450) million in the Hasselmus development, Draugen power from shore and the Talisker East production well at Brage. In addition, a deposit amounting to NOK 296 (137) million was paid to Equinor (Wintershall Dea) for the acquisition of 28% WI in PL037/Statfjord Area (Brage, Nova and Ivar Aasen assets). Investments in the first half of 2022 mainly related to Yme, Hasselmus and drilling of the Ginny and Hamlet exploration wells.
Cash flow used in financing activities amounted to NOK -327 (-531) million and include dividend payments of NOK -208 (-93) million, interest payments on bond loans and other interest-bearing liabilities of NOK -79 (-105) million, repayments on other interest-bearing liabilities of NOK -23 (-19) million and lease payments of NOK - 17 (-14) million. In the first half of previous year, OKEA also used NOK 299 million to repurchase OKEA02 bonds in the market.
On 20 March, OKEA announced a transaction with Equinor Energy AS, where OKEA will acquire 28% WI in the Statfjord Area with effective date 1 January 2023. The transaction is conditional upon Norwegian government approval and is expected to be completed in the fourth quarter of 2023.
For Draugen, the production performance was good with high reliability throughout the period. A planned shutdown was successfully completed in May. Most of the shutdown scope related to tie-in activities for Hasselmus and topside maintenance. The Hasselmus gas project is progressing according to schedule with expected start of production in the fourth quarter of 2023.
For Brage, the production performance in the first half of the year was good. Production from the Talisker East well commenced in May and increases production from Brage.
Production performance at Gjøa was good with high reliability throughout the period.
Production availability at Yme has improved during the period. In addition, start-up of the Beta Nord wells in January has increased production from Yme.
Production performance at Ivar Aasen has been good throughout the period.
Production from Nova has improved during the period. A side-track drilling operation was completed in the second quarter to compensate for reduced water injection.
Investment in OKEA involves risks and uncertainties as described in the company's annual report for 2022. The company's revenues, cash flow, reserve and resource estimates, profitability and rate of growth depend on international and regional prices of oil and gas which may fluctuate significantly based on factors beyond the company's control.
The company is also exposed to other financial risks including, but not limited to, fluctuations in exchange rates, increased interest rates and capital requirements. Reference is made to note 31 in OKEA's annual report for 2022 for further details on financial risks.
On 13 July OKEA announced a dividend payment of NOK 103.9 million (NOK 1 per share) to be paid on or about 15 September. The board also reaffirmed its intention to distribute NOK 1 per share in the fourth quarter of 2023. Future dividend payments may be revised due to changes in the market environment, company situation and/or value accretive opportunities available.
The invasion of Ukraine has impacted petroleum prices with significant volatility at relatively high price levels and unprecedented price differentials in the European gas market. This critical situation has resulted in high revenues for OKEA but also a significant and heightened focus on security measures.
In March, OKEA entered into an SPA with Equinor to acquire 28% WI in PL037 (Statfjord Area) with effective date 1 January 2023 and expected completion in the fourth quarter of 2023. This transformational deal represents another step change in production as well as diversification and fits very well into OKEA's growth strategy. Following the execution of the SPA, lower production in the licence has resulted in an adjustment of expected additional production to OKEA for 2023 from 13,000 – 15,000 boepd to 11,000 – 13,000 boepd. Expected production in 2024 remains unchanged at 16,000 – 20,000 boepd net to OKEA. Reserves estimates also remain unchanged.
To manage the increased exposure to commodity prices that follows from the acquisition, the company has implemented a more conservative hedging policy including forward sales of gas and options collars for oil.
In addition to pursuing inorganic growth opportunities, OKEA is also working to execute its portfolio of development projects. The Hasselmus gas project is progressing according to schedule with planned production start in the fourth quarter of 2023. Approval of the PDO for the electrification project at Draugen is expected in 2023.
OKEA's production guiding for 2023 remains unchanged at 22,000-25,000 boepd. Capex guiding, for 2023 remains at NOK 1,700-2,100 million. The capex guiding comprises completion of the Hasselmus project, Draugen power from shore, Brage infill drilling and other investments, and does not include capitalised interest or exploration capex.
Liftings of 46,000 bbl from Yme and 485,000 bbl from Brage were completed in July. In August 325,000 bbl from Ivar Aasen and two liftings of 67,000 bbl each from Yme are expected. One lifting of 645,000 bbl from Draugen and two liftings of 67,000 bbl each from Yme are scheduled for September. Timing of future lifting from Yme may deviate somewhat subject to the nominated allocation between licence partners. All volumes in this paragraph are net to OKEA.
OKEA continues to deliver according to the dividend plan. In each of March and June, OKEA distributed cash dividends of NOK 103.9 million (NOK 1.00 per share) to its shareholders. On 13 July, OKEA announced a dividend distribution of NOK 1.00 per share to be paid on or about 15 September and the board also reaffirmed its intention to distribute dividends of NOK 1.00 per share in the fourth quarter of 2023.
In light of the upcoming maturity for the USD 120 million OKEA03 bond in December 2024 as well as the company's increased production and reserves following from the Statfjord acquisition, the company has initiated a process to evaluate options to refinance OKEA03 and optimise its debt capital structure, including a potential bank facility (revolving credit facility) in combination with a bond issue.
OKEA has a clear ambition to deliver competitive shareholder returns driven by solid growth, value creation and capital discipline and the strategy continues to focus on three growth levers:
actively pursuing further value creation in current portfolio,
pursuing mergers and acquisitions to add new legs to the portfolio, and
considering organic projects either adjacent to existing hubs or pursuing new hubs, dependent on financial headroom and attractive risk-reward.
The outlook remains good and the board considers that the company is well positioned to continue to execute on its growth strategy.
| 01.01-30.06 | 01.01-31.12 | ||||||
|---|---|---|---|---|---|---|---|
| Q2 2023 | Q1 2023 | Q2 2022 | 2023 | 2022 | 2022 | ||
| Amounts in NOK `000 | Note | (unaudited) | (unaudited) | (unaudited) | (unaudited) | (unaudited) | (audited) |
| Revenues from crude oil and gas sales | 6 | 1 641 477 | 2 929 405 | 1 253 704 | 4 570 882 | 2 769 331 | 6 398 654 |
| Other operating income / loss (-) | 6, 25 | 65 809 | 24 701 | 78 021 | 90 510 | 75 387 | 253 975 |
| Total operating income | 1 707 286 | 2 954 106 | 1 331 726 | 4 661 392 | 2 844 718 | 6 652 629 | |
| Production expenses | 7 | -494 902 | -517 868 | -380 990 | -1 012 770 | -668 285 | -1 616 020 |
| Changes in over/underlift positions and production inventory | 7 | 126 061 | -793 349 | 61 063 | -667 288 | 93 656 | 296 523 |
| Exploration and evaluation expenses | 8 | -123 756 | -23 561 | -26 009 | -147 316 | -118 685 | -327 506 |
| Depreciation, depletion and amortisation | 10 | -361 953 | -327 174 | -165 151 | -689 128 | -322 931 | -769 359 |
| Impairment (-) / reversal of impairment | 10, 11, 12 | -299 795 | -94 417 | - | -394 212 | 362 597 | -497 584 |
| General and administrative expenses | 13 | -47 304 | -27 726 | -58 065 | -75 031 | -80 646 | -212 602 |
| Total operating expenses | -1 201 649 | -1 784 095 | -569 153 | -2 985 744 | -734 293 | -3 126 549 | |
| Profit / loss (-) from operating activities | 505 637 | 1 170 011 | 762 572 | 1 675 648 | 2 110 425 | 3 526 080 | |
| Finance income | 14 | 63 892 | 52 065 | 26 423 | 115 957 | 48 295 | 126 041 |
| Finance costs | 14 | -68 036 | -71 646 | -80 332 | -139 682 | -163 047 | -334 055 |
| Net exchange rate gain/loss (-) | 14 | -110 454 | -29 818 | -177 047 | -140 271 | -177 012 | -103 101 |
| Net financial items | -114 597 | -49 398 | -230 956 | -163 995 | -291 764 | -311 115 | |
| Profit / loss (-) before income tax | 391 039 | 1 120 613 | 531 616 | 1 511 653 | 1 818 661 | 3 214 965 | |
| Taxes (-) / tax income (+) | 9 | -322 166 | -894 483 | -503 836 | -1 216 648 | -1 577 628 | -2 545 357 |
| Net profit / loss (-) | 68 874 | 226 130 | 27 780 | 295 004 | 241 033 | 669 608 |
Items that will not be reclassified to profit or loss in subsequent periods:
| Remeasurements pensions, actuarial gain/loss (-) | - | - | - | - | - | 110 |
|---|---|---|---|---|---|---|
| Total other comprehensive income, net of tax | - | - | - | - | - | 110 |
| Total comprehensive income / loss (-) | 68 874 | 226 130 | 27 780 | 295 004 | 241 033 | 669 718 |
| Weighted average no. of shares outstanding basic | 103 910 350 | 103 910 350 | 103 870 350 | 103 910 350 | 103 870 350 | 103 873 090 |
| Weighted average no. of shares outstanding diluted | 103 910 350 | 103 910 350 | 103 950 350 | 103 910 350 | 103 950 350 | 103 947 610 |
| Earnings per share (NOK per share) - Basic | 0.66 | 2.18 | 0.27 | 2.84 | 2.32 | 6.45 |
| Earnings per share (NOK per share) - Diluted | 0.66 | 2.18 | 0.27 | 2.84 | 2.32 | 6.44 |
| 30.06.2023 | 31.03.2023 | 31.12.2022 | 30.06.2022 | ||
|---|---|---|---|---|---|
| Amounts in NOK `000 | Note | (unaudited) | (unaudited) | (audited) | (unaudited) |
| ASSETS | |||||
| Non-current assets | |||||
| Goodwill | 11, 12 | 1 292 206 | 1 292 206 | 1 296 591 | 801 011 |
| Exploration and evaluation assets | 11 | 186 153 | 192 304 | 184 317 | 78 654 |
| Oil and gas properties | 10 | 6 415 615 | 6 496 242 | 6 556 314 | 5 129 040 |
| Furniture, fixtures and office equipment | 10 | 54 578 | 45 699 | 40 622 | 10 986 |
| Right-of-use assets | 10 | 216 276 | 224 588 | 232 901 | 224 136 |
| Asset retirement reimbursement right | 15 | 3 404 526 | 3 760 131 | 3 662 122 | 2 558 574 |
| Total non-current assets | 11 569 354 | 12 011 171 | 11 972 868 | 8 802 401 | |
| Current assets | |||||
| Trade and other receivables | 17, 25 | 1 361 721 | 1 793 034 | 1 743 901 | 1 060 052 |
| Financial investments | 26 | - | - | - | 210 126 |
| Spare parts, equipment and inventory | 20 | 714 193 | 472 786 | 800 333 | 253 220 |
| Asset retirement reimbursement right, current | 15 | 81 539 | - | - | 13 682 |
| Cash and cash equivalents | 18 | 2 334 876 | 1 633 594 | 1 104 026 | 2 758 124 |
| Total current assets | 4 492 329 | 3 899 415 | 3 648 261 | 4 295 204 | |
| TOTAL ASSETS | 16 061 683 | 15 910 586 | 15 621 128 | 13 097 605 | |
| EQUITY AND LIABILITIES | |||||
| Equity | |||||
| Share capital | 16 | 10 391 | 10 391 | 10 391 | 10 387 |
| Share premium | 1 419 486 | 1 523 397 | 1 627 307 | 1 834 376 | |
| Other paid in capital | 19 140 | 19 140 | 19 140 | 19 110 | |
| Retained earnings/loss (-) | 716 195 | 647 322 | 421 191 | -7 494 | |
| Total equity | 2 165 213 | 2 200 250 | 2 078 030 | 1 856 379 | |
| Non-current liabilities | |||||
| Asset retirement obligations | 19 | 5 613 372 | 5 958 198 | 5 915 084 | 3 644 780 |
| Pension liabilities | 49 129 | 46 192 | 43 255 | 41 104 | |
| Lease liability | 23 | 195 747 | 204 078 | 212 409 | 209 156 |
| Deferred tax liabilities | 9 | 2 774 193 | 2 594 237 | 2 835 089 | 2 288 515 |
| Other provisions | 27, 28 | 18 574 | 51 864 | 39 107 | - |
| Interest bearing bond loans | 22 | 1 292 803 | 1 255 250 | 1 178 610 | 1 187 330 |
| Other interest bearing liabilities | 23 | 479 429 | 478 502 | 462 078 | 482 150 |
| Total non-current liabilities | 10 423 247 | 10 588 321 | 10 685 633 | 7 853 034 | |
| Current liabilities | |||||
| Trade and other payables | 21, 25 | 1 960 912 | 1 547 509 | 2 219 658 | 942 644 |
| Interest bearing bond loans, current | 22 | - | - | - | 994 835 |
| Other interest bearing liabilities, current | 23 | 51 577 | 49 482 | 45 874 | 44 380 |
| Income tax payable | 9 | 1 238 334 | 1 429 114 | 476 850 | 1 297 547 |
| Lease liability, current | 24 | 49 643 | 49 643 | 49 643 | 44 106 |
| Asset retirement obligations, current | 19 | 101 923 | - | - | 17 103 |
| Public dues payable | 70 834 | 46 267 | 65 440 | 47 578 | |
| Total current liabilities | 3 473 223 | 3 122 015 | 2 857 465 | 3 388 192 | |
| Total liabilities | 13 896 470 | 13 710 336 | 13 543 099 | 11 241 226 | |
| TOTAL EQUITY AND LIABILITIES | 16 061 683 | 15 910 586 | 15 621 128 | 13 097 605 |
| Other paid in | Retained | ||||
|---|---|---|---|---|---|
| Amounts in NOK `000 | Share capital Share premium | capital | earnings/loss (-) | Total equity | |
| Equity at 1 January 2022 | 10 387 | 1 927 859 | 19 064 | -248 527 | 1 708 783 |
| Total comprehensive income/loss (-) for the period | - | - | - | 241 033 | 241 033 |
| Dividend paid | - | -93 483 | - | - | -93 483 |
| Share based payment | - | - | 47 | - | 47 |
| Equity at 30 June 2022 | 10 387 | 1 834 376 | 19 110 | -7 494 | 1 856 379 |
| Equity at 1 July 2022 | 10 387 | 1 834 376 | 19 110 | -7 494 | 1 856 379 |
| Total comprehensive income/loss (-) for the period | - | - | - | 428 685 | 428 685 |
| Dividend paid | - | -207 781 | - | - | -207 781 |
| Share issues, cash | 4 | 712 | - | - | 716 |
| Share based payment | - | - | 30 | - | 30 |
| Equity at 31 December 2022 | 10 391 | 1 627 307 | 19 140 | 421 191 | 2 078 030 |
| Equity at 1 January 2023 | 10 391 | 1 627 307 | 19 140 | 421 191 | 2 078 030 |
| Total comprehensive income/loss (-) for the period | - | - | - | 295 004 | 295 004 |
| Dividend paid | - | -207 821 | - | - | -207 821 |
| Equity at 30 June 2023 | 10 391 | 1 419 486 | 19 140 | 716 195 | 2 165 213 |
| 01.01-30.06 | 01.01-31.12 | ||||||
|---|---|---|---|---|---|---|---|
| Q2 2023 | Q1 2023 | Q2 2022 | 2023 | 2022 | 2022 | ||
| Amounts in NOK `000 | Note | (unaudited) | (unaudited) | (unaudited) | (unaudited) | (unaudited) | (audited) |
| Cash flow from operating activities | |||||||
| Profit / loss (-) before income tax | 391 039 | 1 120 613 | 531 616 | 1 511 653 | 1 818 661 | 3 214 965 | |
| Income tax paid/received | 9 | -332 991 | -166 496 | -386 058 | -499 487 | -579 839 | -2 289 373 |
| Depreciation, depletion and amortization | 10 | 361 953 | 327 174 | 165 151 | 689 128 | 322 931 | 769 359 |
| Impairment / reversal of impairment | 10, 11, 12 | 299 795 | 94 417 | 0 | 394 212 | -362 597 | 497 584 |
| Expensed exploration expenditures temporary capitalised | 8, 11 | 171 | 4 512 | -1 462 | 4 683 | 63 402 | 141 892 |
| Accretion asset retirement obligations/reimbursement right - net | 14, 15, 19 | 3 738 | 3 191 | 2 174 | 6 929 | 3 113 | 11 768 |
| Asset retirement costs from billing (net after reimbursement) | 15, 19 | -18 010 | -106 | -12 849 | -18 116 | -17 432 | -22 525 |
| Interest expense | 14 | 18 341 | 21 200 | 48 287 | 39 540 | 98 785 | 172 369 |
| Gain / loss on financial investments | 14 | - | - | -800 | - | -165 | 64 |
| Change in fair value contingent consideration | 6, 28 | -17 927 | 15 631 | - | -2 296 | - | -12 376 |
| Change in trade and other receivables, and inventory | 189 906 | 536 603 | 38 661 | 726 509 | 87 284 | -799 208 | |
| Change in trade and other payables | 471 687 | -722 026 | 56 338 | -250 339 | 64 345 | 1 425 986 | |
| Change in foreign exchange interest bearing debt and other non-current items | 33 760 | 83 412 | 258 197 | 117 173 | 272 752 | 233 567 | |
| Net cash flow from / used in (-) operating activities | 1 401 462 | 1 318 126 | 699 256 | 2 719 588 | 1 771 239 | 3 344 073 | |
| Cash flow from investment activities | |||||||
| Investment in exploration and evaluation assets | 11 | 5 980 | -12 499 | -25 086 | -6 519 | -131 297 | -315 833 |
| Business combinations, cash paid | 27, 28, 17 | -21 731 | -274 869 | -90 697 | -296 600 | -136 612 | -1 239 721 |
| Investment in oil and gas properties | 10, 14 | -504 870 | -389 618 | -186 357 | -894 489 | -318 915 | -1 052 354 |
| Investment in furniture, fixtures and office machines | 10 | -14 235 | -9 459 | -2 114 | -23 693 | -2 914 | -36 422 |
| Cash used on (-)/received from financial investments | 26 | - | - | - | - | - | 209 896 |
| Net cash flow from / used in (-) investment activities | -534 855 | -686 446 | -304 255 | -1 221 301 | -589 738 | -2 434 433 | |
| Cash flow from financing activities | |||||||
| Repayment/buy-back of bond loans | 22 | - | - | -10 057 | - | -299 136 | -1 401 531 |
| Repayment of other interest bearing liabilities | 23 | -11 968 | -11 165 | -8 934 | -23 132 | -19 193 | -42 730 |
| Interest paid | -67 630 | -11 276 | -76 170 | -78 906 | -105 163 | -193 729 | |
| Payments of lease debt | 24 | -8 331 | -8 331 | -7 243 | -16 663 | -14 479 | -30 544 |
| Dividend payments | 16 | -103 910 | -103 910 | -93 483 | -207 821 | -93 483 | -301 264 |
| Net proceeds from share issues | - | - | 0 | - | - | 716 | |
| Net cash flow from / used in (-) financing activities | -191 840 | -134 682 | -195 887 | -326 522 | -531 454 | -1 969 082 | |
| Net increase/ decrease (-) in cash and cash equivalents | 674 766 | 496 998 | 199 113 | 1 171 765 | 650 047 | -1 059 442 | |
| Cash and cash equivalents at the beginning of the period | 1 633 594 | 1 104 026 | 2 469 576 | 1 104 026 | 2 038 745 | 2 038 745 | |
| Effect of exchange rate fluctuation on cash held | 26 515 | 32 570 | 89 434 | 59 085 | 69 332 | 124 723 | |
| Cash and cash equivalents at the end of the period | 2 334 876 | 1 633 594 | 2 758 124 | 2 334 876 | 2 758 124 | 1 104 026 |
These financial statements are the unaudited interim condensed financial statements of OKEA ASA for the second quarter and first half of 2023. OKEA ASA ("OKEA" or the "company") is a public limited liability company incorporated and domiciled in Norway, with its main office located in Trondheim. The company's shares are listed on the Oslo Stock Exchange under the ticker OKEA.
OKEA is a leading mid to late-life operator on the Norwegian continental shelf (NCS). OKEA finds value where others divest and has an ambitious growth strategy built on accretive M&A activities, value creation and capital discipline.
The interim accounts have been prepared in accordance with IAS 34 Interim Financial Reporting. The interim accounts do not include all the information required in the annual accounts and should therefore be read in conjunction with the annual accounts for 2022. The annual accounts for 2022 were prepared in accordance with EU`s approved International Financial Reporting Standards (IFRS).
The interim financial statements were authorised for issue by the company's board of directors on 12 July 2023.
The accounting policies adopted in the preparation of the interim accounts are consistent with those followed in the preparation of the annual accounts for 2022. New standards, amendments and interpretations to existing standards effective from 1 January 2023 did not have any significant impact on the financial statements.
The preparation of the interim accounts entails the use of judgements, estimates and assumptions that affect the application of accounting policies and the amounts recognised as assets and liabilities, income and expenses. The estimates, and associated assumptions, are based on historical experience and other factors that are considered as reasonable under the circumstances. The actual results may deviate from these estimates. The material assessments underlying the application of the company's accounting policies, and the main sources of uncertainty, are the same for the interim accounts as for the annual accounts for 2022.
The company's only business segment is development and production of oil and gas on the Norwegian continental shelf.
| 01.01-30.06 | 01.01-31.12 | |||||
|---|---|---|---|---|---|---|
| Amounts in NOK `000 | Q2 2023 | Q1 2023 | Q2 2022 | 2023 | 2022 | 2022 |
| Sale of liquids | 1 153 095 | 2 305 721 | 849 703 | 3 458 816 | 1 546 431 | 3 621 472 |
| Sale of gas | 488 381 | 623 684 | 404 001 | 1 112 065 | 1 222 900 | 2 777 182 |
| Total petroleum revenues | 1 641 477 | 2 929 405 | 1 253 704 | 4 570 882 | 2 769 331 | 6 398 654 |
| Sale of liquids (boe*) | 1 521 324 | 2 892 527 | 902 412 | 4 413 851 | 1 772 199 | 3 841 817 |
| Sale of gas (boe*) | 551 815 | 522 167 | 549 656 | 1 073 981 | 1 069 853 | 2 090 128 |
| Total sale of petroleum in boe* | 2 073 138 | 3 414 693 | 1 452 068 | 5 487 832 | 2 842 052 | 5 931 945 |
*Barrels of oil equivalents
| 01.01-30.06 | 01.01-31.12 | |||||
|---|---|---|---|---|---|---|
| Amounts in NOK `000 | Q2 2023 | Q1 2023 | Q2 2022 | 2023 | 2022 | 2022 |
| Gain / loss (-) from put/call options, oil | 4 699 | 212 | - | 4 911 | - | - |
| Gain / loss (-) from forward contracts, gas | 126 | 5 523 | 39 773 | 5 648 | 7 049 | 72 492 |
| Change in fair value contingent consideration (see note 28) | 17 927 | -15 631 | - | 2 296 | - | 12 376 |
| Tariff income Gjøa | 35 442 | 32 061 | 26 216 | 67 503 | 50 361 | 131 596 |
| Joint utilisation of logistics resources | 7 614 | 2 537 | 12 032 | 10 152 | 17 976 | 37 512 |
| Total other operating income/loss (-) | 65 809 | 24 701 | 78 021 | 90 510 | 75 387 | 253 975 |
| Production expenses | ||||||
|---|---|---|---|---|---|---|
| 01.01-30.06 | 01.01-31.12 | |||||
| Amounts in NOK `000 | Q2 2023 | Q1 2023 | Q2 2022 | 2023 | 2022 | 2022 |
| From licence billings - producing assets | 420 892 | 436 467 | 339 058 | 857 359 | 588 547 | 1 420 803 |
| Other production expenses (insurance, transport) | 64 705 | 74 041 | 38 983 | 138 745 | 73 443 | 179 295 |
| G&A expenses allocated to production expenses | 9 305 | 7 361 | 2 950 | 16 666 | 6 294 | 15 922 |
| Total production expenses | 494 902 | 517 868 | 380 990 | 1 012 770 | 668 285 | 1 616 020 |
| Changes in over/underlift positions and production inventory | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| 01.01-30.06 | 01.01-31.12 | ||||||||
| Amounts in NOK `000 | Q2 2023 | Q1 2023 | Q2 2022 | 2023 | 2022 | 2022 | |||
| Changes in over/underlift positions | -104 972 | -474 992 | 66 629 | -579 963 | 96 160 | 196 372 | |||
| Changes in production inventory | 231 032 | -318 357 | -5 567 | -87 325 | -2 504 | 100 151 | |||
| Total changes income/loss (-) | 126 061 | -793 349 | 61 063 | -667 288 | 93 656 | 296 523 |
| 01.01-30.06 | 01.01-31.12 | ||||||
|---|---|---|---|---|---|---|---|
| Amounts in NOK `000 | Q2 2023 | Q1 2023 | Q2 2022 | 2023 | 2022 | 2022 | |
| Share of exploration and evaluation expenses from participation in licences excluding dry well impairment, from billing |
34 929 | 19 582 | 19 413 | 54 511 | 40 223 | 75 304 | |
| Share of exploration expenses from participation in licences, dry well write off, from billing |
171 | 4 512 | -1 462 | 4 683 | 63 402 | 141 892 | |
| Seismic and other exploration and evaluation expenses, outside billing |
87 435 | -1 449 | 7 878 | 85 986 | 14 514 | 108 525 | |
| G&A expenses allocated to exploration expenses | 1 221 | 916 | 181 | 2 136 | 546 | 1 786 | |
| Total exploration and evaluation expenses | 123 756 | 23 561 | 26 009 | 147 316 | 118 685 | 327 506 |
| 01.01-30.06 | 01.01-31.12 | |||||
|---|---|---|---|---|---|---|
| Amounts in NOK `000 | Q2 2023 | Q1 2023 | Q2 2022 | 2023 | 2022 | 2022 |
| Change in deferred taxes current year | -179 955 | 240 852 | -189 382 | 60 896 | -523 326 | -436 027 |
| Taxes payable current year | -180 411 | -1 135 334 | -310 284 | -1 315 745 | -1 050 133 | -2 105 157 |
| Tax payable adjustment previous year | 38 201 | - | -4 170 | 38 201 | -4 170 | -4 173 |
| Total taxes (-) / tax income (+) recognised in the income | ||||||
| statement | -322 166 | -894 483 | -503 836 | -1 216 648 | -1 577 628 | -2 545 357 |
| 01.01-30.06 | 01.01-31.12 | ||||||
|---|---|---|---|---|---|---|---|
| Amounts in NOK `000 | Q2 2023 | Q1 2023 | Q2 2022 | 2023 | 2022 | 2022 | |
| Profit / loss (-) before income taxes | 391 039 | 1 120 613 | 531 616 | 1 511 653 | 1 818 661 | 3 214 965 | |
| Expected income tax at tax rate 78.004% | -305 026 | -874 123 | -414 661 | -1 179 149 | -1 418 555 | -2 507 802 | |
| Permanent differences, including impairment of goodwill | -11 185 | -22 632 | -13 990 | -33 817 | -50 376 | -25 612 | |
| Effect of uplift | 15 784 | 22 704 | 23 619 | 38 488 | 41 593 | 102 044 | |
| Financial and onshore items | -66 991 | -20 431 | -90 502 | -87 422 | -141 988 | -105 620 | |
| Effect of new tax rates | - | - | - | - | - | -104 | |
| Adjustments previous year and other | 45 253 | - | -8 302 | 45 253 | -8 302 | -8 264 | |
| Total income taxes recognised in the income statement | -322 166 | -894 483 | -503 836 | -1 216 648 | -1 577 628 | -2 545 357 | |
| Effective income tax rate | 82 % | 80 % | 95 % | 80 % | 87 % | 79 % | |
| Amounts in NOK `000 | 30.06.2023 | 31.03.2023 | 31.12.2022 | 30.06.2022 |
|---|---|---|---|---|
| Tangible and intangible non-current assets | -4 407 660 | -4 406 969 | -4 372 336 | -3 426 655 |
| Provisions (net ARO), lease liability, pensions and gain/loss account | 2 061 462 | 2 061 117 | 2 102 801 | 1 272 106 |
| Interest bearing loans | -1 237 | -1 397 | -1 466 | -2 481 |
| Current items (spareparts and inventory) | -426 759 | -246 989 | -564 088 | -131 485 |
| Tax losses carried forward, onshore 22% | 4 887 | 4 887 | 4 887 | 4 887 |
| Valuation allowance (uncapitalised deferred tax asset) | -4 887 | -4 887 | -4 887 | -4 887 |
| Total deferred tax assets / liabilities (-) recognised | -2 774 193 | -2 594 237 | -2 835 089 | -2 288 515 |
| Amounts in NOK `000 | Total |
|---|---|
| Tax payable at 1 January 2023 | 476 850 |
| Tax paid | -499 487 |
| Tax payable adjustment previous year | -38 201 |
| Tax payable current year recognised in the income statement | 1 315 745 |
| Tax payable recognised in business combination (see note 27) | -16 574 |
| Tax payable at 30 June 2023 | 1 238 334 |
| Furniture, | ||||
|---|---|---|---|---|
| fixtures and | ||||
| Amounts in NOK `000 | Oil and gas properties |
office machines |
Right-of-use assets |
Total |
| Cost at 1 January 2023 | 10 276 046 | 52 650 | 358 702 | 10 687 398 |
| Additions | 404 814 | 9 459 | - | 414 273 |
| Reclassification from inventory | 4 492 | - | - | 4 492 |
| Removal and decommissioning asset | -57 980 | - | - | -57 980 |
| Disposals | - | -2 464 | - | -2 464 |
| Cost at 31 March 2023 | 10 627 373 | 59 644 | 358 702 | 11 045 719 |
| Accumulated depreciation and impairment | ||||
| at 1 January 2023 | -3 719 732 | -12 027 | -125 802 | -3 857 561 |
| Depreciation | -316 981 | -4 382 | -5 811 | -327 174 |
| Impairment (-) / reversal of impairment | -94 417 | - | - | -94 417 |
| Disposals | - | 2 464 | - | 2 464 |
| Additional depreciation of IFRS 16 Right-of | ||||
| use assets presented gross related to leasing contracts entered into as licence |
||||
| operator | - | - | -2 501 | -2 501 |
| Accumulated depreciation and | ||||
| impairment at | ||||
| 31 March 2023 | -4 131 130 | -13 945 | -134 114 | -4 279 189 |
| Carrying amount at 31 March 2023 | 6 496 242 | 45 699 | 224 588 | 6 766 530 |
| Cost at 1 April 2023 | 10 627 373 | 59 644 | 358 702 | 11 045 719 |
| Additions | 524 516 | 14 235 | - | 538 751 |
| Reclassification from inventory | - | - | - | - |
| Removal and decommissioning asset | ||||
| Disposals | 45 437 | - | - | 45 437 |
| Cost at 30 June 2023 | - | - | - | - |
| 11 197 326 | 73 879 | 358 702 | 11 629 907 | |
| Accumulated depreciation and impairment | ||||
| at 1 April 2023 | -4 131 130 | -13 945 | -134 114 | -4 279 189 |
| Depreciation | -350 785 | -5 356 | -5 811 | -361 953 |
| Impairment (-) / reversal of impairment | -299 795 | - | - | -299 795 |
| Disposals | - | - | - | - |
| Additional depreciation of IFRS 16 Right-of | ||||
| use assets presented gross related to | ||||
| leasing contracts entered into as licence | ||||
| operator | - | - | -2 501 | -2 501 |
| Accumulated depreciation and | ||||
| impairment at | ||||
| 30 June 2023 | -4 781 711 | -19 301 | -142 426 | -4 943 438 |
| Carrying amount at 30 June 2023 | 6 415 615 | 54 578 | 216 276 | 6 686 469 |
| Exploration | ||||
|---|---|---|---|---|
| and evaluation | Technical | Ordinary | ||
| Amounts in NOK `000 | assets | goodwill | goodwill | Total goodwill |
| Cost at 1 January 2023 | 184 317 | 1 642 191 | 416 415 | 2 058 607 |
| Additions | 12 499 | - | - | - |
| Additions through business combination (see note 27) | - | -4 385 | - | -4 385 |
| Expensed exploration expenditures temporarily capitalised | -4 512 | - | - | - |
| Cost at 31 March 2023 | 192 304 | 1 637 806 | 416 415 | 2 054 221 |
| Accumulated impairment at 1 January 2023 | - | -508 818 | -253 198 | -762 016 |
| Impairment | - | - | - | - |
| Accumulated impairment at 31 March 2023 | - | -508 818 | -253 198 | -762 016 |
| Carrying amount at 31 March 2023 | 192 304 | 1 128 988 | 163 217 | 1 292 206 |
| Cost at 1 April 2023 | 192 304 | 1 637 806 | 416 415 | 2 054 221 |
| Additions Additions through business combination (see note 27) |
-5 980 - |
- - |
- - |
- - |
| Expensed exploration expenditures temporarily capitalised | -171 | - | - | - |
| Cost at 30 June 2023 | 186 153 | 1 637 806 | 416 415 | 2 054 221 |
| Accumulated impairment at 1 April 2023 | - | -508 818 | -253 198 | -762 016 |
| Impairment | - | - | - | - |
| Accumulated impairment at 30 June 2023 | - | -508 818 | -253 198 | -762 016 |
| Carrying amount at 30 June 2023 | 186 153 | 1 128 988 | 163 217 | 1 292 206 |
Tangible and intangible assets are tested for impairment / reversal of impairment whenever indicators are identified and at least on an annual basis. Impairment is recognised when the book value of an asset or cash generating unit exceeds the recoverable amount. The recoverable amount is the higher of the asset's fair value less costs to sell and value in use. The recoverable amount is estimated based on discounted future after tax cash flows. The expected future cash flows are discounted to net present value by applying a discount rate after tax that reflects the weighted average cost of capital (WACC).
Technical goodwill arises as an offsetting account to the deferred tax recognised in business combinations and is allocated to each Cash Generating Unit (CGU). When deferred tax from the initial recognition decreases, more goodwill is as such exposed for impairments.
Fair value assessment of the company's right-of-use (ROU) assets portfolio are included in the impairment test.
Below is an overview of the key assumptions applied in the impairment test as of 30 June 2023:
| Year | Oil USD/BOE* |
Gas GBP/therm* |
Currency rates USD/NOK |
|---|---|---|---|
| 2023 | 71.9 | 1.08 | 10.7 |
| 2024 | 68.7 | 1.32 | 10.6 |
| 2025 | 67.2 | 1.07 | 10.6 |
| 2026 | 70.8 | 0.84 | 9.8 |
| From 2027 | 72.1 | 0.75 | 9.0 |
* Prices in real terms
For oil and gas reserves future cash flows are calculated on the basis of expected production profiles and estimated proven and probable remaining reserves.
Future capex, opex and abandonment cost are calculated based on the expected production profiles and the best estimate of related cost. For fair value testing the discount rate applied is 10.0% post tax unchanged from the Q1 test.
The long-term inflation rate is assumed to be 2.0%.
The valuation of oil and gas properties and goodwill are inherently uncertain due to the judgemental nature of the underlying estimates. This risk has increased due to the current market conditions with rapid fluctuation in supply and demand of oil and gas causing more volatility in prices.
Total cost for CO2 comprises Norwegian CO2 tax and cost of the EU Emission Trading System and is estimated to gradually increase from NOK 1 523 per tonne in 2022 towards a long term price of NOK 2 000 (real 2020) per tonne from 2030 in line with price estimates presented by the Norwegian authorities in late 2021. NOx prices are estimated to increase from approximately NOK 17 per kg in 2022 to a level of approximately 28 NOK per kg from 2030. A future change in how the world will react in light of the goals set in the Paris Agreement could have adverse effects on the value of OKEA's oil and gas assets. Sensitivities on changes to environmental cost is reflected in the table below.
Based on the company's impairment assessments NOK 300 millinon in impairment of the Yme asset was recognised in the second quarter. The impairment was mainly driven by lower expected realised prices of oil from Yme.
No impairment of technical and ordinary goodwill or ROU assets was required in the three month period ending on 30 June 2023.
The table below shows what the impairment pre-tax would have been in the second quarter under various alternative assumptions, assuming all other assumptions remaining constant. The total figures shown are combined impairment for CGUs Gjøa, Draugen, Ivar Aasen, Yme, Brage and Nova.
| Alternative calculations of pre tax impairment/reversal (-) Q2 2023 (NOK '000) |
Increase / decrease (-) of pre tax impairment Q2 2023 (NOK '000) |
||||
|---|---|---|---|---|---|
| Assumptions | Change | Increase in assumption |
Decrease in assumption |
Increase in assumption |
Decrease in assumption |
| Oil and gas price | +/- 10% | -103 573 | 796 931 | -403 368 | 497 136 |
| Currency rate USD/NOK | +/- 1.0 NOK | -100 235 | 762 546 | -400 030 | 462 751 |
| Discount rate | +/- 1% point | 323 819 | 275 379 | 24 024 | -24 416 |
| Environmental cost (CO2 and NOx) | +/- 20% | 369 801 | 240 198 | 70 006 | -59 597 |
| 01.01-30.06 | 01.01-31.12 | ||||||
|---|---|---|---|---|---|---|---|
| Amounts in NOK `000 | Q2 2023 | Q1 2023 | Q2 2022 | 2023 | 2022 | 2022 | |
| Salary and other employee benefits expenses | 243 336 | 230 156 | 143 375 | 473 492 | 271 272 | 620 072 | |
| Consultants and other operating expenses | 160 962 | 142 657 | 75 268 | 303 620 | 129 265 | 336 209 | |
| Allocated to operated licences | -346 468 | -336 811 | -157 140 | -683 279 | -312 455 | -725 343 | |
| Allocated to exploration and production expenses | -10 526 | -8 276 | -3 438 | -18 802 | -7 436 | -18 336 | |
| Total general and administrative expenses | 47 304 | 27 726 | 58 065 | 75 031 | 80 646 | 212 602 |
| 01.01-30.06 | 01.01-31.12 | ||||||
|---|---|---|---|---|---|---|---|
| Amounts in NOK `000 | Q2 2023 | Q1 2023 | Q2 2022 | 2023 | 2022 | 2022 | |
| Interest income | 22 496 | 10 122 | 3 244 | 32 618 | 4 914 | 22 165 | |
| Unwinding of discount asset retirement reimbursement right | |||||||
| (indemnification asset) | 41 396 | 41 943 | 23 014 | 83 339 | 43 216 | 103 876 | |
| Gain on financial investments | - | - | 165 | - | 165 | - | |
| Finance income | 63 892 | 52 065 | 26 423 | 115 957 | 48 295 | 126 041 | |
| Interest expense and fees from loans and borrowings | -37 987 | -36 396 | -53 824 | -74 382 | -107 259 | -200 371 | |
| Capitalised borrowing cost, development projects | 19 646 | 15 196 | 5 537 | 34 842 | 8 474 | 28 059 | |
| Interest expense shareholder loan | - | - | - | - | - | -57 | |
| Other interest expense | -15 | -45 | -2 339 | -60 | -3 979 | -5 268 | |
| Unwinding of discount asset retirement obligations | -45 134 | -45 134 | -25 188 | -90 268 | -46 329 | -115 645 | |
| Loss on buy-back/early redemption bond loan | - | - | -2 046 | - | -6 407 | -23 535 | |
| Loss on financial investments | - | - | 634 | - | - | -64 | |
| Other financial expense | -4 546 | -5 268 | -3 107 | -9 813 | -7 547 | -17 174 | |
| Finance costs | -68 036 | -71 646 | -80 332 | -139 682 | -163 047 | -334 055 | |
| Exchange rate gain/loss (-), interest-bearing loans and | |||||||
| borrowings | -50 622 | -106 329 | -338 302 | -156 951 | -319 352 | -296 881 | |
| Net exchange rate gain/loss (-), other | -59 832 | 76 511 | 161 255 | 16 680 | 142 339 | 193 780 | |
| Net exchange rate gain/loss (-) | -110 454 | -29 818 | -177 047 | -140 271 | -177 012 | -103 101 | |
| Net financial items | -114 597 | -49 398 | -230 956 | -163 995 | -291 764 | -311 115 |
| Amounts in NOK `000 | |
|---|---|
| Asset retirement reimbursement right at 1 January 2023 (indemnification asset) | 3 662 122 |
| Additions through business combination (see note 27) | |
| Changes in estimates | 41 280 |
| Effect of change in the discount rate | -225 483 |
| Asset retirement costs from billing, reimbursement from Shell and Wintershall Dea | -75 195 |
| Unwinding of discount | 83 339 |
| Asset retirement reimbursement right at 30 June 2023 (indemnification asset) | 3 486 064 |
| Of this: | |
| Asset retirement reimbursement right, non-current | 3 404 526 |
| Asset retirement reimbursement right, current | 81 539 |
| Asset retirement reimbursement right at 30 June 2023 (indemnification asset) | 3 486 064 |
Asset retirement reimbursement right consists of a receivable from the seller Shell from OKEA's acquisition of Draugen and Gjøa assets in 2018, and a receivable from the seller Wintershall Dea from OKEA's acquisition of the Brage asset in 2022.
Receivable from the seller Shell from OKEA's acquisition of Draugen and Gjøa assets in 2018:
The parties agreed that the seller Shell will cover 80% of the actual abandonment expenses for the Draugen and Gjøa fields up to a predefined after-tax cap amount of NOK 757 million (2022 value) subject to Consumer Price Index (CPI) adjustment. The present value of the expected payments is recognised as a pre-tax receivable from the seller.
In addition, the seller has agreed to pay OKEA an amount of NOK 441 million (2022 value) subject to a CPI adjustment according to a schedule based on the percentage of completion of the decommissioning of the Draugen and Gjøa fields.
The net present value of the receivable is calculated using a discount rate of 4.6% (year end 2022: 3.9%).
Receivable from the seller Wintershall Dea from OKEA's acquisition of the Brage asset in 2022: The parties have agreed that Wintershall Dea will retain responsibility for 80% of OKEA's share of total decommissioning costs related to the Brage Unit, limited to an agreed pre-tax cap of NOK 1520.6 million subject to index regulation.
The net present value of the receivable is calculated using a discount rate of 6.4% (year end 2022: 6.4%).
| Number of shares | Ordinary shares |
|---|---|
| Outstanding shares at 1 January 2023 | 103 910 350 |
| New shares issued during 2023 | - |
| Number of outstanding shares at 30 June 2023 | 103 910 350 |
| Nominal value NOK per share at 30 June 2023 Share capital NOK at 30 June 2023 |
0.1 10 391 035 |
Dividend paid in Q1 2023 is NOK 103.9 million and dividend paid in Q2 2023 is NOK 103.9 million.
| Amounts in NOK `000 | 30.06.2023 | 31.03.2023 | 31.12.2022 | 30.06.2022 |
|---|---|---|---|---|
| Accounts receivable and receivables from operated licences* | 277 434 | 666 723 | 234 811 | 55 674 |
| Accrued revenue | 302 883 | 335 981 | 422 885 | 347 228 |
| Prepayments | 372 701 | 342 721 | 79 009 | 129 488 |
| Working capital and overcall, joint operations/licences | 273 079 | 268 722 | 386 637 | 197 581 |
| Underlift of petroleum products | 107 211 | 163 041 | 588 934 | 301 621 |
| VAT receivable | 20 852 | 15 342 | 21 049 | 5 928 |
| Accrued interest income | - | - | - | 1 518 |
| Other receivables | - | - | - | 21 014 |
| Fair value forward contracts, gas | - | - | 10 578 | - |
| Fair value put/call options, oil | 7 562 | 505 | - | - |
| Total trade and other receivables | 1 361 721 | 1 793 034 | 1 743 901 | 1 060 052 |
* There is no provision for bad debt on receivables.
** Prepayments at 30.06.2023 include a prepayment of USD 25 million to Equinor Energy AS in connection with an agreement with Equinor to acquire an 28% working interest in PL037 (Statfjord Area) with effective date 1 January 2023. The transaction is conditional upon Norwegian governmental approval and is expected to be completed in Q4 2023.
| Amounts in NOK `000 | 30.06.2023 | 31.03.2023 | 31.12.2022 | 30.06.2022 |
|---|---|---|---|---|
| Bank deposits, unrestricted | 2 233 326 | 1 547 485 | 1 010 492 | 1 641 192 |
| Bank deposit, time deposit | - | - | - | 1 047 960 |
| Bank deposit, restricted, employee taxes | 33 500 | 18 468 | 31 224 | 25 135 |
| Bank deposit, restricted, deposit office leases | 14 824 | 14 824 | 14 824 | 14 810 |
| Bank deposit, restricted, other | 53 226 | 52 817 | 47 486 | 29 028 |
| Total cash and cash equivalents | 2 334 876 | 1 633 594 | 1 104 026 | 2 758 124 |
| Amounts in NOK `000 | |
|---|---|
| Provision at 1 January 2023 | 5 915 084 |
| Additions | 110 197 |
| Additions through business combination (see note 27) | |
| Changes in estimates | 23 940 |
| Effects of change in the discount rate | -330 882 |
| Asset retirement costs from billing | -93 311 |
| Unwinding of discount | 90 268 |
| Asset retirement obligations at 30 June 2023 | 5 715 296 |
| Of this: | |
| Asset retirement obligations, non-current | 5 613 372 |
| Asset retirement obligations, current | 101 923 |
| Asset retirement obligations at 30 June 2023 | 5 715 296 |
Provisions for asset retirement obligations represent the future expected costs for close-down and removal of oil equipment and production facilities. The provision is based on the company's best estimate. The net present value of the estimated obligation is calculated using a discount rate of 3.5% (year end 2022: 3.1%). The assumptions are based on the economic environment at balance sheet date. Actual asset retirement costs will ultimately depend upon future market prices for the necessary works which will reflect market conditions at the relevant time. Furthermore, the timing of the close-down is likely to depend on when the field ceases to produce at economically viable rates. This in turn will depend upon future oil and gas prices, which are inherently uncertain.
For recovery of costs of decommissioning related to assets acquired from Shell and Wintershall Dea, reference is made to note 15.
| Amounts in NOK `000 | 30.06.2023 31.03.2023 |
31.12.2022 | 30.06.2022 | |
|---|---|---|---|---|
| Inventory of petroleum products | 424 184 | 193 152 | 511 509 | 121 754 |
| Spare parts and equipment | 290 008 | 279 634 | 288 824 | 131 466 |
| Total spare parts, equipment and inventory | 714 193 | 472 786 | 800 333 | 253 220 |
| Amounts in NOK `000 | 30.06.2023 | 31.03.2023 | 30.06.2022 | |
|---|---|---|---|---|
| Trade creditors | 114 024 | 48 428 | 126 044 | 28 537 |
| Accrued holiday pay and other employee benefits | 123 841 | 110 086 | 146 858 | 71 849 |
| Working capital, joint operations/licences | 946 018 | 779 796 | 1 061 014 | 565 618 |
| Overlift of petroleum products | 146 192 | 97 050 | 47 952 | 11 435 |
| Accrued interest bond loans | 5 655 | 33 003 | 5 175 | 5 231 |
| Other provisions, current (see note 28) | 26 317 | 32 685 | 29 810 | - |
| Prepayments from customers | 336 272 | 277 748 | 506 637 | 23 093 |
| Fair value forward contracts, gas | - | - | - | 4 170 |
| Fair value forward contracts, foreign exchange* | 74 665 | 9 245 | - | - |
| Loan from shareholder OKEA Holdings Ltd | 1 428 | 1 428 | 1 428 | 1 371 |
| Other accrued expenses | 186 500 | 158 040 | 294 740 | 231 340 |
| Total trade and other payables | 1 960 912 | 1 547 509 | 2 219 658 | 942 644 |
* Outstanding contracts at 30 June 2023: OKEA has sold a total of GBP 105 million against NOK forward at NOK/GBP rates in the range of 12.81-12.85 with expiry dates in Q3-Q4 2023.
| Amounts in NOK `000 | Bond loan OKEA03 |
Total |
|---|---|---|
| Interest bearing bond loans at 1 January 2023 | 1 178 610 | 1 178 610 |
| Amortisation of transaction costs | 3 428 | 3 428 |
| Foreign exchange movement | 110 765 | 110 765 |
| Interest bearing bond loans at 30 June 2023 | 1 292 803 | 1 292 803 |
| Of this: | ||
| Interest bearing bond loans, non-current | 1 292 803 | 1 292 803 |
| Interest bearing bond loans, current | - | - |
| Interest bearing bond loans at 30 June 2023 | 1 292 803 | 1 292 803 |
| Amounts in NOK `000 | Bond loan OKEA03 |
Total |
| Interest bearing bond loans at 1 January 2023 | 1 178 610 | 1 178 610 |
| Cash flows: | ||
| Gross proceeds from borrowings | - | - |
| Transaction costs | - | - |
| Repayment/buy-back of borrowings | - | - |
| Total cash flows: | - | - |
| Non-cash changes: |
| Amortisation of transaction costs | 3 428 | 3 428 |
|---|---|---|
| Foreign exchange movement | 110 765 | 110 765 |
| Interest bearing bond loans at 30 June 2023 | 1 292 803 | 1 292 803 |
During 2023 the company has been in full compliance with the covenants under the bond agreements.
From 01.01.2022 the covenants comprise of: (i) Leverage ratio shall not exceed 2:1 (ii) Capital employment ratio above 35%
(iii) Minimum free liquidity of USD 10 million
Maturity date of OKEA03 is 11 December 2024.
In October 2021 the Yme licence completed acquisition of the Inspirer jack-up rig through a bareboat charter (BBC) agreement with Havila Sirius AS (Havila). The part of the lease payments to Havila corresponding to the purchase price paid by Havila to Maersk is considered as an investment in a rig with a corresponding liability, while the remaining amount of the total payments is treated as interest expenses. This treatment is based on the underlying assessment that the reality of the transaction is that it is an investment in a rig financed with a interest bearing liability, rather than a lease. OKEA's proportionate share of the investment and corresponding liability is USD 55.95 million.
The Yme licence has the right and the obligation to purchase the rig at the end of the lease period for NOK 1. In addition the Yme licence has the unconditional obligation to purchase the rig from Havila in case of any termination event during the lease period. The purchase price will then be the remaining amount paid by Havila to Maersk plus interest and other costs. The Yme licence also has the option to purchase the rig at any time during the lease period for the same price.
The liability carries a implicit interest rate of 5.21% p.a., and will be repaid with the lease payments to Havila with the last lease payment in October 2031. Repsol S.A. (RSA) is the parent company of the Yme licence operator Repsol Norge AS. On behalf of Yme, RSA has issued a parent company guarantee for the future lease payments to Havila.
| Liability | ||
|---|---|---|
| Amounts in NOK `000 | Yme rig | Total |
| Other interest bearing liabilities at 1 January 2023 | 507 952 | 507 952 |
| Repayments | -23 132 | -23 132 |
| Foreign exchange movement | 46 186 | 46 186 |
| Other interest bearing liabilities at 30 June 2023 | 531 006 | 531 006 |
| Of this: | ||
| Other interest bearing liabilities, non-current | 479 429 | 479 429 |
| Other interest bearing liabilities, current | 51 577 | 51 577 |
| Other interest bearing liabilities at 30 June 2023 | 531 006 | 531 006 |
| Liability | ||
| Amounts in NOK `000 | Yme rig | Total |
| Other interest bearing liabilities at 1 January 2023 | 507 952 | 507 952 |
| Cash flows: | ||
| Gross proceeds from borrowings | - | - |
| Repayment of borrowings | -23 132 | -23 132 |
| Total cash flows: | -23 132 | -23 132 |
| Non-cash changes: | ||
| Foreign exchange movement | 46 186 | 46 186 |
| Other interest bearing liabilities at 30 June 2023 | 531 006 |
The company has entered into operating leases for office facilities. In addition, as operator of the Draugen field, the company has on behalf of the licence entered into operating leases for logistic resources such as supply vessel with associated remote operated vehicle (ROV), base and warehouse for spare parts and hence gross basis of these lease debts are recognised.
| Amounts in NOK `000 | |
|---|---|
| Lease liability 1 January 2023 | 262 052 |
| Additions lease contracts | - |
| Accretion lease liability | 8 432 |
| Payments of lease debt and interest | -25 095 |
| Total lease debt at 30 June 2023 | 245 389 |
| Break down of lease liability | |
|---|---|
| Short-term (within 1 year) | 49 643 |
| Long-term | 195 747 |
| Total lease liability | 245 389 |
| Amounts in NOK `000 | 30.06.2023 |
|---|---|
| Within 1 year | 50 190 |
| 1 to 5 years | 160 074 |
| After 5 years | 149 450 |
| Total | 359 714 |
Future lease payments related to leasing contracts entered into as an operator of the Draugen field are presented on a gross basis.
| Amounts in NOK `000 | 30.06.2023 | 31.03.2023 | 31.12.2022 | 30.06.2022 |
|---|---|---|---|---|
| Premium commodity contracts | - | 631 | - | - |
| Accumulated unrealised gain/loss (-) commodity contracts included in other operating income / loss(-) |
7 562 | -126 | 10 578 | -4 170 |
| Short-term derivatives included in assets/liabilities (-) | 7 562 | 505 | 10 578 | -4 170 |
The company uses derivative financial instruments (put and call options) to manage exposures to fluctuations in commodity prices. Put options are purchased to establish a price floor for a portion of future production of petroleum products. In addition a price ceiling is established by selling call options, which reduces the net premium paid for hedging.
At 30 June 2023 there are no outstanding financial forward contracts gas (without physical delivery of gas). All outstanding contracts at 31 December 2022 expired in Q1 2023.
In addition OKEA has entered into non-financial contracts with physical delivery of gas in 2023-2024 at fixed price. At 30 June 2023 the outstanding contracts are 38 940 000 therms of gas with delivery in Q3 2023 - Q3 2024 at fixed prices in the range of 87 - 144.5 GBp/therm. Revenue from these contracts will be recognised at delivery of the gas.
| Amounts in NOK `000 | 30.06.2023 | 31.03.2023 | 31.12.2022 | 30.06.2022 |
|---|---|---|---|---|
| Investments in money-market funds and combination funds | - | - | - | 210 126 |
| Total financial investments | - | - | - | 210 126 |
On 1 November 2022 OKEA completed the acquisition of a 35.2% working interest in the Brage field, a 6.4615% working interest in the Ivar Aasen field and a 6% working interest in the Nova field from Wintershall Dea Norge AS.
The purchase price allocation (PPA) presented below is based on a updated completion statement from Q1 2023 compared to the PPA presented in Q4 2022. At this stage, the purchase price allocation is preliminary. As a result, the final PPA and the impact on the financial statements from the transaction may differ. The final PPA will be completed within 12 months of the acquisition at the latest.
| Amounts in NOK `000 | PPA Q4 2022 |
Changes Q1 2023 |
Updated PPA |
|---|---|---|---|
| Assets | |||
| Oil and gas properties | 1 791 614 | - | 1 791 614 |
| Receivables on seller* | 947 255 | - | 947 255 |
| Net working capital | 441 429 | - | 441 429 |
| Income tax receivable (reduced tax payable) | 165 808 | 16 574 | 182 382 |
| Right-of-use assets | 17 315 | - | 17 315 |
| Total assets | 3 363 421 | 16 574 | 3 379 996 |
| Liabilities | |||
| Deferred tax liabilities | 633 483 | - | 633 483 |
| Asset retirement obligations | 1 926 780 | - | 1 926 780 |
| Contingent consideration | 116 041 | - | 116 041 |
| Lease liability | 17 315 | - | 17 315 |
| Total liabilities | 2 693 618 | - | 2 693 618 |
| Total identifiable net assets at fair value | 669 803 | 16 574 | 686 377 |
| Total consideration | 1 165 383 | 12 189 | 1 177 572 |
| Goodwill | 495 580 | -4 385 | 491 194 |
| Goodwill consist of: | |||
| Negative ordinary goodwill | -500 811 | - | -500 811 |
| Technical goodwill | 996 390 | -4 385 | 992 005 |
| Total goodwill | 495 580 | -4 385 | 491 194 |
* No changes to the PPA was made in Q2 2023.
| Amounts in NOK `000 | |
|---|---|
| Provision at 1 January 2023 | 68 917 |
| Settlements/payments to Wintershall Dea | -21 731 |
| Changes in fair value | -2 296 |
| Other provisions at 30 June 2023 | 44 891 |
| Of this: | |
| Other provisions, non-current | 18 574 |
| Other provisions, current (classified within trade and other payables) | 26 317 |
| Other provisions at 30 June 2023 | 44 891 |
OKEA shall pay to Wintershall Dea an additional contingent consideration based on an upside sharing arrangement subject to oil price level during the period 2022- 2024. The provision for the contingent consideration is measured at fair value with changes in fair value recognised in the income statement. The fair value is estimated using an option pricing methodology, where the expected option payoff is calculated at each future payment date and discounted back to the balance date.
It is assessed that the carrying amounts of financial assets and liabilities, except for interest bearing bond loans, is approximately equal to its fair values.
For interest bearing bond loan OKEA03, the fair value is estimated to be NOK 1,317 million at 30 June 2023. The OKEA03 bond loan is listed on the Oslo Stock Exchange and the fair value is based on the latest quoted market price (level 2 in the fair value hierarchy according to IFRS 13) as per balance sheet date.
Fair values of put/call options oil and forward contracts foreign exchange are based on quoted market prices at the balance sheet date (level 2 in the fair value hierarchy). The put/call options oil and the forward contracts foreign exchange are carried in the statement of financial position at fair value.
There are no subsequent events with significant impacts that have occured between the end of the reporting period and the date of this report that are not already reflected or discloused in these financial statements.
| EBITDA | Q2 2023 | Q1 2023 | Q2 2022 | 2023 | 2022 | 2022 |
|---|---|---|---|---|---|---|
| Amounts in NOK `000 | 3 months | 3 months | 3 months | 6 months | 6 months | 12 months |
| Profit / loss (-) from operating activities | 505 637 | 1 170 011 | 762 572 | 1 675 648 | 2 110 425 | 3 526 080 |
| Add: depreciation, depletion and amortisation | 361 953 | 327 174 | 165 151 | 689 128 | 322 931 | 769 359 |
| Add: impairment | 299 795 | 94 417 | - | 394 212 | -362 597 | 497 584 |
| EBITDA | 1 167 385 | 1 591 602 | 927 723 | 2 758 987 | 2 070 759 | 4 793 024 |
| EBITDAX | Q2 2023 | Q1 2023 | Q2 2022 | 2023 | 2022 | 2022 |
| Amounts in NOK `000 | 3 months | 3 months | 3 months | 6 months | 6 months | 12 months |
| Profit / loss (-) from operating activities | 505 637 | 1 170 011 | 762 572 | 1 675 648 | 2 110 425 | 3 526 080 |
| Add: depreciation, depletion and amortisation | 361 953 | 327 174 | 165 151 | 689 128 | 322 931 | 769 359 |
| Add: impairment / reversal of impairment | 299 795 | 94 417 | - | 394 212 | -362 597 | 497 584 |
| Add: exploration and evaluation expenses | 123 756 | 23 561 | 26 009 | 147 316 | 118 685 | 327 506 |
| Production expense per boe | Q2 2023 | Q1 2023 | Q2 2022 | 2023 | 2022 | 2022 |
|---|---|---|---|---|---|---|
| Amounts in NOK `000 | 3 months | 3 months | 3 months | 6 months | 6 months | 12 months |
| Productions expense | 494 902 | 517 868 | 380 990 | 1 012 770 | 668 285 | 1 616 020 |
| Less: processing tariff income | -35 442 | -32 061 | -26 216 | -67 503 | -50 361 | -131 596 |
| Less: joint utilisation of resources | -7 614 | -2 537 | -12 032 | -10 152 | -17 976 | -37 512 |
| Divided by: produced volumes (boe) | 2 025 961 | 1 998 902 | 1 459 581 | 4 024 863 | 2 801 254 | 6 108 800 |
| Production expense NOK per boe | 223.0 | 241.8 | 234.7 | 232.3 | 214.2 | 236.8 |
EBITDAX 1 615 163 1 291 141 953 733 2 906 304 2 189 444 5 120 530
| Net interest-bearing debt | ||||
|---|---|---|---|---|
| Amounts in NOK `000 | 30.06.2023 | 31.03.2023 | 31.12.2022 | 30.06.2022 |
| Interest bearing bond loans | 1 292 803 | 1 255 250 | 1 178 610 | 1 187 330 |
| Other interest bearing liabilities | 479 429 | 478 502 | 462 078 | 482 150 |
| Interest bearing bond loans, current | - | - | - | 994 835 |
| Other interest bearing liabilities, current | 51 577 | 49 482 | 45 874 | 44 380 |
| Less: Cash and cash equivalents | -2 334 876 | -1 633 594 | -1 104 026 | -2 758 124 |
| Net interest-bearing debt | -511 067 | 149 640 | 582 537 | -49 429 |
| Net interest-bearing debt excl. other interest bearing liabilities | ||||
|---|---|---|---|---|
| Amounts in NOK `000 | 30.06.2023 | 31.03.2023 | 31.12.2022 | 30.06.2022 |
| Interest bearing bond loans | 1 292 803 | 1 255 250 | 1 178 610 | 1 187 330 |
| Interest bearing bond loans, current | - | - | - | 994 835 |
| Less: Cash and cash equivalents | -2 334 876 | -1 633 594 | -1 104 026 | -2 758 124 |
| Net interest-bearing debt excl. other interest bearing liabilities | -1 042 073 | -378 345 | 74 584 | -575 959 |
EBITDA is defined as earnings before interest and other financial items, taxes, depreciation, depletion, amortisation and impairments.
EBITDAX is defined as earnings before interest and other financial items, taxes, depreciation, depletion, amortisation, impairments and exploration and evaluation expenses.
Net interest-bearing debt is book value of current and non-current interest-bearing loans, bonds and other interest-bearing liabilities excluding lease liability (IFRS 16) less cash and cash equivalents.
Net interest-bearing debt excl. other interest bearing liabilities is book value of interest-bearing bond loans less cash and cash equivalents.
Production expense per boe is defined as production expense less processing tariff income and joint utilisation of resources income for assets in production divided by produced volumes. Expenses classified as production expenses related to various preparation for operations on assets under development are excluded.
We hereby confirm, to the best of our knowledge, that the unaudited interim financial statement for the period 1 January to 30 June 2023 of OKEA ASA have been prepared in accordance with IAS 34 Interim Financial Reporting and that the information presented gives a true and fair view of the company's assets, liabilities, financial position and results for the period viewed in their entirety and that the half year report gives a fair view of the information as described in the Securities Trading Act §5-6 fourth paragraph.
The board of directors of OKEA ASA Trondheim, 12 July 2023
Chaiwat Kovavisarach Jon Arnt Jacobsen Chairman of the board Board member
Per Magne Bjellvåg Sverre Nes Board member Board member
Phatpuree Chinkulkitnivat Rune Olav Pedersen Board member Board member
Michael William Fischer Elizabeth Williamson Board member Board member
Nicola Carol Gordon Ragnhild Aas Board member Board member
Board member CEO
Finn Haugan Svein Jakob Liknes
OKEA ASA is a leading mid- to late-life operator on the Norwegian continental shelf (NCS).
OKEA finds value where others divest and has an ambitious strategy built on growth, value creation and capital discipline.
OKEA ASA Kongens gate 8 7011 Trondheim
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