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EnQuest PLC (ENQ)

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Thursday 03 September, 2020

EnQuest PLC

EnQuest PLC Half Year Results 2020

RNS Number : 8834X
EnQuest PLC
03 September 2020
 

 

Results for the six months ended 30 June 2020

Strong production performance and targeted free cash flow breakeven on track

3 September 2020

Unless otherwise stated, all figures are on a Business performance basis and are in US Dollars.

Comparative figures for the income statement relate to the period ended 30 June 2019 and the Balance Sheet as at 31 December 2019.

Alternative performance measures are reconciled within the 'Glossary - Non-GAAP measures' at the end of the Financial Statements.

Good performance in a challenging environment

§ Group net production averaged 66,055 Boepd in the six months to end June 2020; full year production guidance range of 57,000 Boepd to 63,000 Boepd maintained, although currently expect to be towards the upper part of this range

§ Operations materially unaffected by COVID-19

§ Strong performance on Kraken with gross production of 38,967 Bopd (net 27,472 Bopd), c.19% higher than the same period in the prior year. Full year production is expected to be towards the upper part of the 30,000 Bopd to 35,000 Bopd (gross) guidance range

§ Revenue of $450.7 million (2019: $858.2 million) and EBITDA of $274.9 million (2019: $525.9 million), reflecting  strong production volumes and the benefit of the Group's hedging programme, partially offset by lower market prices

§ Operating expenditure decreased to $174.3 million (2019: $248.4 million) with unit operating costs reduced to $14.4/Boe (2019: $20.1/Boe), reflecting strong production and cost control

§ Robust cash generated from operations at $283.2 million (2019: $426.2 million); cash capital expenditure of $101.4 million (2019: $124.6 million), with full year guidance of c.$120 million unchanged

§ Free cash flow generation of $87.5 million (2019: $138.3 million) has enabled further debt reduction

§ Lower oil price assumptions resulted in non-cash post-tax impairments of $251.6 million, and non-cash de-recognition of undiscounted deferred tax assets of $432.6 million. EnQuest retains access to its tax losses and allowances

End June net debt reduced by $61.9 million from year end

§ At 30 June 2020, net debt was reduced to $1,351.1 million (end 2019: $1,413.0 million) with cash and available bank facilities amounting to $269.5 million (end 2019: $288.6 million)

§ Tanjong Baram Project Finance Facility of $31.7 million fully repaid in June; Sculptor Capital Facility reduced by $31.8 million in the period to end June

§ For full year 2020, the Group's hedge programme covers c.11.4 MMbbls. Approximately 10.3 MMbbls are hedged at an average floor price of $43/bbl, with a further 1.1 MMbbls hedged with an average floor price of c.$52/bbl in accordance with the Sculptor Capital facility agreement

Significant, low-cost 2C resource addition in the UK North Sea

§ Signed sale and purchase agreement for 40.81% equity interest in and operatorship of Bressay licences in July

§ Low-cost addition of up to 115 MMbbls (net) 2C resources; opportunity for long-term, low-risk, phased sub-sea tie-back project

EnQuest Chief Executive, Amjad Bseisu, said :

"The Group continues to perform well in challenging conditions, including COVID-19 and the early shutdown of a number of our assets. The safety of our people and our assets remains our priority. With our ongoing focus on operational excellence, we have continued to exceed our operational targets, including production of around 66,000 Boepd in the first half of 2020.

"Our difficult and early decisions to shut down our higher cost assets have resulted in a substantial cost reduction programme, which is on track. We remain confident that we will achieve our 2020 targets, with free cash flow breakeven for the full year at c.$33/Boe. We continue to target free cash flow breakeven of c.$27/Boe in 2021.

"Even with the most challenging macro and oil price environment since our genesis as a company, we have been able to generate around $87 million of free cash flow in the period and reduced our net debt. We remain focused on continuing to reduce our debt and strengthening our balance sheet.

"Looking further ahead, I am delighted we have agreed the acquisition of a material operating interest in the Bressay field. The addition of up to 115 MMbbls of net 2C resources materially increases our 2C resource base and provides EnQuest an opportunity to demonstrate further its proven capabilities in low-cost drilling and heavy oil."

 

Production and financial information

 

H1 2020

H1 2019

 

Change

%

Production (Boepd)

66,055

68,548

 

(3.6)

 

Revenue and other operating income ($m)1

450.7

858.2

 

(47.5)

Statutory reported revenue and other operating income ($m)2

439.4

815.4

 

(46.1)

Realised oil price ($/bbl)1

43.6

66.1

 

(34.0)

Average unit operating expenditure ($/Boe)

14.4

20.1

 

(28.3)

Gross profit ($m)

39.8

269.9

 

(85.3)

Statutory reported gross profit ($m)

19.3

223.0

 

(91.3)

Profit before tax & net finance costs ($m)

24.6

264.5

 

(90.6)

 

 

 

 

 

EBITDA ($m)

274.9

525.9

 

(47.7)

 

 

 

 

 

Statutory reported profit/(loss) after tax ($m)

(619.0)

44.3

 

-

Statutory reported basic earnings/(loss) per share (cents)

(37.4)

2.7

 

-

 

 

 

 

 

Cash generated from operations ($m)

283.2

426.2

 

(33.6)

Cash capex ($m)

101.4

124.6

 

(18.6)

 

End June 2020

End 2019

 

 

Net (debt)/cash ($m)

(1,351.1)

(1,413.0)

 

(4.4)

1 Including net realised gains of $35.2 million (2019: net realised gains of $7.6 million) associated with EnQuest's oil price hedges

2 Including net realised and unrealised gains of $23.9 million (2019: net realised and unrealised losses of $35.3 million) associated with EnQuest's oil price hedges

 

Summary financial review of H1 2020

Revenue was $450.7 million for the six months ended 30 June 2020 compared with $858.2 million for the same period in 2019. This decrease was primarily driven by the material reduction in the oil price and moving from a net overlift to a net underlift position at the end of 30 June 2020. Group revenue is predominantly derived from crude oil sales and for the six months ended 30 June 2020, crude oil sales totalled $375.5 million compared with $761.9 million for the comparative period in 2019. Revenue from the sale of gas and condensate in the period was $27.6 million (2019: $79.9 million), reflecting significantly lower market prices for gas.

The commodity hedge programme resulted in realised gains of $35.2 million in the first half of 2020 (2019: realised gains of $7.6 million). Consequently, the Group's average realised oil price was $43.6/bbl for the six months ended 30 June 2020, compared to $66.1/bbl received during the first half of 2019. Excluding the impact of hedging, the average realised oil price was $39.9/bbl in the first half of 2020, compared to $65.4/bbl received during the first half of 2019.

Cost of sales were $410.9 million for the six months ended 30 June 2020 compared with $588.3 million for the same period in 2019. Operating costs decreased by $74.1 million to $174.3 million, primarily reflecting the Group's focus on cost control, including the decision to cease production at Heather and Thistle. The Group's average unit operating cost has decreased by 28.3% to $14.4/Boe (2019: $20.1/Boe). Other cost of sales decreased by $103.3 million to $236.6 million (2019: $339.9 million), reflecting the change from a net overlift to a net underlift position, and the lower cost of Magnus-related third-party gas purchases following the reduction in the market price for gas, partially offset by a $19.0 million inventory write down recognised in the first half of the year, which primarily relates to inventory held at assets scheduled for decommissioning.

EBITDA for the six months ended 30 June 2020 reduced to $274.9 million compared with $525.9 million for the same period in 2019. This was driven by lower revenue partially offset by lower cost of sales.

The tax credit for the six months ended 30 June 2020 was $71.5 million (2019: $36.2 million tax charge).

Remeasurement and exceptional items were a net loss of $308.1 million before tax for the six months ended 30 June 2020 (2019: loss of $120.0 million). Revenue included unrealised losses of $11.3 million in respect of the mark-to-market movement on the Group's commodity contracts (2019: unrealised losses of $42.9 million). Pre-tax non-cash impairment charges of $409.8 million on the Group's tangible oil and gas assets were recognised, reflecting a reduction in oil price assumptions. Other remeasurement and exceptional items in the first half of 2020 also includes a $161.9 million gain in relation to the fair value recalculation of the Magnus contingent consideration reflecting the reduction in oil price assumptions and a $6.2 million provision in relation to the Group's transformation programme referred to below.

The Group's reported cash generated from operations for the six months ended 30 June 2020 was $283.2 million (2019:  $426.2 million) primarily as a result of lower revenue. Free cash flow for the six months ended 30 June 2020 was $87.5 million (2019: $138.3 million).

EnQuest's net debt decreased by $61.9 million from $1,413.0 million at the end of 2019 to $1,351.1 million at 30 June 2020. Net debt at 30 June 2020 includes $166.2 million of inception to date interest that has been capitalised to the principal of the senior credit facility and bonds ('PIK'), compared to $133.3 million at 31 December 2019.

In January 2020, EnQuest voluntarily repaid $35.0 million of the senior credit facility early, resulting in no further amortisations due in 2020. The next amortisation payment of $65.0 million is due by 1 April 2021.

In June 2020, EnQuest made an early voluntary repayment of the entire $31.7 million of the Tanjong Baram project finance facility having received the first of three instalments from PETRONAS for reimbursement of outstanding net capital expenditure of around $50 million relating to the Tanjong Baram project. The remaining two reimbursement instalments are due from PETRONAS in the second half of the year.

The strong production performance at Kraken has driven a $31.8 million reduction in the Sculptor Capital facility in the first six months of the year.

The Group continues to have access to its full UK corporate tax losses of $3,086.8 million at 30 June 2020 (2019: $2,903.4 million).

 

Operating review

Production details

 

Net daily average production on a working interest basis

 

1 Jan' 2020 to
30 Jun' 2020

1 Jan' 2019 to
30 Jun' 2019

 

 

(Boepd)

(Boepd)

Magnus

 

18,806

17,774

Kraken

 

27,472

23,107

Other North Sea

 

11,471

19,068

Total UKCS

 

57,749

59,949

Total Malaysia

 

8,306

8,599

Total EnQuest

 

66,055

68,548

 

Magnus

Average production in the six months to end June was 18,806 Boepd, 5.8% higher than the same period in 2019. This increase was driven by high production efficiency of 86% and also high water injection efficiency of 91%. Combined with two new wells coming onstream in March, which are performing in line with expectations, this has partially offset gas compressor performance issues experienced in the first quarter. Production optimisation activities are continuing and the Group expects to complete a one-week maintenance shutdown in the fourth quarter to carry out essential works,

Kraken

Gross production during the first six months of 2020 averaged 38,967 Bopd (net 27,472 Bopd), an increase of 18.9% and ahead of the top end of guidance. This was driven by a good performance from the floating, production, storage and offloading ('FPSO') vessel, with high production efficiency of 86%. Overall subsurface and well performance remains good and the Group continues to optimise production through improved injector-producer well management following the completion of well testing in May and June. Drilling at Worcester was completed during the first half of the year, with the new producer-injector pair coming onstream late in the second quarter.

In June 2020, Kraken reached three years since the delivery of first oil, with output significantly increasing from 7.7 MMbbls in the first 12 months of operation to over 14.2 MMbbls in its third year. Cargo pricing has improved over the same period and remains robust, with the Group continuing to optimise sales into the shipping market with Kraken oil being a key component of IMO 2020 compliant low-sulphur fuel oil.

In the third quarter, repairs were required to the DC1 riser, resulting in two producer wells shut in for approximately two weeks. In addition, a one-week planned shutdown of operations is planned in the third quarter to allow for essential maintenance work to be undertaken.

With the better than expected performance so far this year, production is currently expected to be towards the upper part of the 30,000 Bopd and 35,000 Bopd (gross) full year guidance range.

Other North Sea operations

Production in the six months to end June averaged 11,471 Boepd, 39.8% lower than the same period in 2019. This decrease was primarily driven by the decision not to restart production at the Heather/Broom and Thistle/Deveron fields, which contributed c.9,000 Boepd in the same period in 2019. Elsewhere, lower water injection and a lack of gas lift, along with gas compressor downtime and underlying natural declines, impacted production at the Dons. These reductions were partially offset by strong production efficiency at Alma/Galia, with production in line with expectations, while performance was significantly improved at Scolty/Crathes following the completion of the pipeline replacement project during the third quarter of 2019. Alba continues to perform in line with the Group's expectations, with the Group continuing to deliver stable operations and plant availability at the Sullom Voe Terminal.

In June, a cessation of production ('CoP') application for the Heather asset was accepted by the regulator, which allows preparations to begin for decommissioning and lowers EnQuest's share of costs to 37.5% (from 100.0%). The platform remains shutdown and is depressurised. The Group expects to recommence the well abandonment programme in 2021.

The Thistle/Deveron CoP application was lodged with the regulator in July and once accepted, the decommissioning phase will begin, resulting in EnQuest's share of post-tax costs reducing to 6.1% (from 99.0%). Project activities related to the removal of the redundant crude oil storage tanks at Thistle continued, with the successful removal of the tanks completed in July. The facility is expected to remain permanently unmanned for the remainder of 2020, with a well abandonment programme targeted for 2021.

At the Dons, given the impacts on gas supply for gas lift as a result of the shutdown at Thistle and the resulting lower production, the Group is working with its partners and the regulator to seek the necessary regulatory approvals in respect of CoP. Operations are expected to cease in the second quarter of 2021.

At Alma/Galia, CoP occurred on 30 June 2020 as planned. The EnQuest Producer FPSO will shortly move off station and sail to the oil terminal jetty at Nigg. The Group continues to explore a number of options regarding its future.

Following the decisions to pursue CoP at the Heather, Thistle/Deveron and the Dons assets, the Group has re-organised its UK North Sea business into three directorates that report to Bob Davenport, Managing Director - North Sea. These directorates are Upstream, Midstream and Decommissioning1. With the changing operational footprint of the Group, support functions have also been reviewed. Given the scale of change, with the number of employee and contractor roles in the UK reduced by approximately 40%, the UK workforce has undergone an open and transparent collective consultation process to ensure all employees were treated fairly and with respect. This consultation process, which included the appointment of employee representatives to work with management to ensure the proposed changes did not compromise safety and to minimise the impact on the Group's people and operations, gave all employees at EnQuest the opportunity to nominate themselves for relevant roles within the new organisation structure. Feedback received from the employee representatives was positive . This transformation enables the Group's directorates to focus on the most appropriate activities that deliver operational excellence and safe results at each of its assets.

1 Upstream includes: Magnus, Kraken, the Greater Kittiwake Area and Scolty/Crathes, and Alba. Midstream includes: the Sullom Voe Terminal and the Group's pipeline operations. Decommissioning includes Heather/Broom, Thistle/Deveron, the Dons and Alma/Galia

Malaysian operations

Average production in Malaysia in the six months to end June 2020 of 8,306 Boepd was broadly in line with the same period in 2019. Continued high production efficiency, which averaged c.96%, and the impact of idle well restoration activities, combined with higher gas sales, largely offset the loss of volumes from Tanjong Baram, which was shut-down ahead of the termination of the small field risk service contract.

In June, a short planned maintenance shutdown was successfully completed on PM8/Seligi, with a total production outage of around two days being achieved, well within the original planned five day outage.

 

 

Business development and growth opportunities

In July, the Group announced that it had signed a binding sale and purchase agreement with Equinor for an equity interest in the Bressay licenses. Under the agreement, EnQuest will assume operatorship of the licenses with a participating interest of 40.81% for an initial consideration of £2.2 million, payable as a carry against 50% of Equinor's net share of costs. It is expected that up to115 MMbbls, net to EnQuest, will be added to the Group's 2C resources. With no near-term capital commitments, Bressay offers the Group the opportunity for a long-term, low-risk, phased sub-sea tie-back project, potentially to the Kraken field, which could reduce emissions, costs and extend Kraken's field life.

Further to the addition of 2C resources potential at Bressay, EnQuest has a large volume of reserves and resources within its portfolio, providing opportunities for long term and low-cost drilling when conditions are supportive. Magnus offers 2C resources of c.38 MMbbls and around 250 million barrels of movable oil still to evaluate. Kraken continues to offer further near-field opportunities through the evaluation and development of the western area, which holds an estimated 70-130 MMbbls of STOIIP. In Malaysia, EnQuest has c.22 MMboe of 2P reserves and c.76 MMboe of 2C resources. Subsurface studies are ongoing on Block PM409, which is a proven hydrocarbon area containing several undeveloped discoveries contiguous to the Group's existing PM8/Seligi PSC.

Environmental, Social and Governance

The safety of its people will always be a top priority for EnQuest. The Group continues to monitor actively the impact on operations from COVID-19 and has implemented a number of mitigations to minimise the impact, adopting an approach based upon the principles of safety and welfare of people and security of supply. The Group has remained aligned and supportive of the government position and remained compliant with Dubai, Malaysia and UK government and industry policy. The Group has also been working with a variety of stakeholders, including industry and medical organisations, to ensure its operational response and advice to its workforce is appropriate and commensurate with the prevailing expert advice and level of risk. Appropriate restrictions on offshore travel have been implemented, such as self-declaration by, and isolation of, individuals who are symptomatic. Pre-mobilisation testing and temperature checks are also in operation for all operational staff prior to travelling to the Group's UK North Sea onshore and offshore operating facilities. EnQuest's normal communicable disease process has been updated specifically in respect of COVID-19, with additional offshore isolation capability and agreements in place to transport impacted individuals back onshore in dedicated helicopters. At the Sullom Voe Terminal, the same processes have also been implemented, with isolation capability at local accommodation. These measures have been robust, resulting in EnQuest having a strong record of minimising the impact of COVID-19 on our people, with only three cases of COVID-19 confirmed offshore, across all producing assets. Across the Group's onshore office locations, appropriate risk assessments have been undertaken with any necessary procedural and office layout alterations implemented to minimise the risk as the Group's workforce gradually returns to the office in line with relevant government guidelines. At the time of publication of EnQuest's half year results, the Group's day-to-day operations continue without being materially affected by COVID-19.

The Group expects its Scope 1 and 2 emissions to be around 15% lower in 2020 compared to 2019, reflecting the pursuit of several emission reduction projects and the Group's decisions to cease production at its Heather, Thistle/Deveron and Alma/Galia assets. Based on current estimates for the existing portfolio, the Group expects to deliver a reduction in emissions of c.10% over the next three years. EnQuest is also a participant in the Energy Hub, an initiative being developed by the Shetland Islands Council and the Oil and Gas Technology Centre aiming to deliver a clean, sustainable energy future for Shetland and the UK. In the meantime, the Group continues voluntarily to limit emissions in Malaysia below the regulatory limit and optimise sales of Kraken cargoes directly to the shipping market, avoiding emissions related to refining and helping reduce sulphur emissions in accordance with the IMO 2020 regulations. The Group Safety & Risk Committee has also concluded its assessment of whether 'climate change' should be categorised as a standalone risk area within the Group's risk management framework (in addition to the recognition already accorded to climate change related issues across the existing principal risk areas) and concluded that it should be categorised as such.

The Group remains committed to improving workforce diversity across the business. At present, around 20% of EnQuest's country leadership teams are female and the Group is committed to improving this further.

EnQuest has continued to provide support to the communities in which it works. In Malaysia, EnQuest is sponsoring one university student to study STEM-related subjects at University Malaya and has also signed a Memorandum of Agreement to sponsor the IChemE accreditation of the Chemical Engineering programme at The National University of Malaysia. This accreditation is expected to improve the employability of graduating students, anticipated to be some 80-100 individuals for each intake year.

In March, Howard Paver was appointed as the Senior Independent Director, replacing Helmut Langanger who retired from the Board, while in May, Howard replaced Laurie Fitch as Chair of the Remuneration Committee. Laurie remains a member of the Committee.

Liquidity and net debt

At the end of June 2020, net debt was $1,351.1 million, down $61.9 million from $1,413.0 million at 31 December 2019, reflecting strong operational performance and the impact of the Group's commodity hedge programme in the first quarter, partially offset by the settlement of the Group's high yield and retail bond interest as payment in kind through the issuance of additional notes. Total cash and available facilities were $269.5 million, including ring-fenced accounts associated with Magnus, the Sculptor Capital facility and other joint venture accounts totalling $89.3 million.

In June, the Group made an early voluntary repayment of the remaining $31.7 million of the Tanjong Baram project finance facility, having received the first of three instalments from PETRONAS for settlement of the outstanding net capital expenditure of around $50 million relating to the Tanjong Baram project. The remaining two reimbursement instalments are due from PETRONAS in the second half of the year.

As a result of the material decline in the oil price in the first quarter, the Group pre-emptively sought a waiver of the liquidity test for the remainder of 2020 from the lenders in the Senior Credit Facility which was granted in the second quarter.

By the end of June, c.5.9 MMbbls of oil hedges had been settled. Approximately 5.2 MMbbls had an average floor price of c.$49/bbl, while c. 0.7 MMbbls associated with the Sculptor Capital facility had an average floor price of c.$52/bbl. For the remaining six months of 2020, EnQuest has c. 5.5 MMbbls of oil hedges in place. Approximately 5.1 MMbbls are hedged at an average price of c.$36/bbl, with a further c.0.4 MMbbls hedged with an average floor price of c.$52/bbl in accordance with the Sculptor Capital facility agreement.

2020 outlook reaffirmed

Group production performance in the period was above the top end of guidance at 66,055 Boepd. Full year production guidance of 57,000 and 63,000 Boepd is maintained, although the Group currently expects to be towards the upper part of this range. During the second half of 2020, the strong production performance from the first half of the year is expected to be partially offset by planned maintenance shutdowns, the cessation of production at Alma/Galia in June, lower expected production from the Don's and natural field declines.

Implementation of the Group's 2020 cost savings and reduction in free cash flow breakeven remain on track, with operating expenditure expected to be around $335 million and cash capital expenditure around $120 million, in line with previous guidance.

While debt repayment remains the priority, the Group continues to assess its large and low-cost 2C resource base for future development when conditions are supportive.

- Ends -

 

For further information please contact:

 

EnQuest PLC

Tel: +44 (0)20 7925 4900

Amjad Bseisu (Chief Executive)

 

Jonathan Swinney (Chief Financial Officer)

 

Ian Wood (Head of Communications & Investor Relations)

 

Jonathan Edwards (Senior Investor Relations & Communications Manager)

 

 

 

Tulchan Communications

Tel: +44 (0)20 7353 4200

Martin Robinson

 

Martin Pengelley

 

Harry Cameron

 

Presentation to Analysts and Investors
A presentation to analysts and investors will be held at 09:00 today - London time. The presentation and Q&A will also be accessible via an audio webcast, available on the investor relations section of the EnQuest website at www.enquest.com. A conference call facility will also be available at 09:00 on the following numbers:

Conference call details:

UK: +44 (0) 800 376 7922

International: +44 (0) 207 192 8000

Confirmation Code: EnQuest

 

Notes to editors

This announcement has been determined to contain inside information.

Identity of the person making this notification: Stefan Ricketts, Company Secretary

 

ENQUEST

EnQuest is an independent production and development company with operations in the UK North Sea and Malaysia. The Group's strategic vision is to be the operator of choice for maturing and underdeveloped hydrocarbon assets by focusing on operational excellence, differential capability, value enhancement and financial discipline.

EnQuest PLC trades on both the London Stock Exchange and the NASDAQ OMX Stockholm. Its UK operated assets include Thistle/Deveron, Heather/Broom, the Dons area, Magnus, the Greater Kittiwake Area, Scolty/Crathes, Alma/Galia and Kraken; EnQuest also has an interest in the non-operated Alba producing oil field. At the end of June 2020, EnQuest had interests in 17 UK production licences and was the operator of 15 of these licences. EnQuest's interests in Malaysia include the PM8/Seligi and PM409 production sharing contracts, both of which the Group operates.

Forward-looking statements: This announcement may contain certain forward-looking statements with respect to EnQuest's expectations and plans, strategy, management's objectives, future performance, production, reserves, costs, revenues and other trend information. These statements and forecasts involve risk and uncertainty because they relate to events and depend upon circumstances that may occur in the future. There are a number of factors which could cause actual results or developments to differ materially from those expressed or implied by these forward-looking statements and forecasts. The statements have been made with reference to forecast price changes, economic conditions and the current regulatory environment. Nothing in this announcement should be construed as a profit forecast. Past share performance cannot be relied upon as a guide to future performance.

 

 

 

FINANCIAL REVIEW

Financial Overview

Unless otherwise stated, all figures are on a Business performance basis and are in US Dollars.

Comparative figures for the Statement of Comprehensive Income relate to the period ended 30 June 2019 and the Balance Sheet as at 31 December 2019.

Alternative performance measures are reconciled within the 'Glossary - Non-GAAP measures' at the end of the Financial Statements.

Production on a working interest basis decreased by 3.6% to 66,055 Boepd, compared to 68,548 Boepd in the first half of 2019.

Revenue for the six months ended 30 June 2020 was $450.7 million, 47.5% lower than the comparative 2019 six month period (2019: $858.2 million).

The Group's operating expenditures of $174.3 million were 29.8% lower than the comparative period (2019: $248.4 million). Unit operating costs decreased by 28.3% to $14.4/Boe (2019: $20.1/Boe).

EBITDA for the six months ended 30 June 2020 was $274.9 million, 47.7% lower than the comparative period (2019: $525.9 million).

 

Business performance

 

H1 2020

H1 2019

 

$ million

$ million

 

 

 

Profit from operations before tax and finance income/(costs)

24.6

264.5

Depletion and depreciation

 252.3

 255.4

Inventory write-down

 19.0

 5.7

Net foreign exchange (gains)/losses

(21.0)

 0.3

EBITDA

274.9

 525.9

 

EnQuest's net debt decreased by $61.9 million from $1,413.0 million at the end of 2019 to $1,351.1 million at 30 June 2020. Net debt at 30 June 2020 includes $166.2 million of inception to date interest that has been capitalised to the principal of the facilities pursuant to the terms of the Group's November 2016 refinancing ('PIK'), compared to $133.3 million at 31 December 2019.

 

Net debt/(cash)

 

30 June

2020

31 December

2019

 

$ million

$ million

 

 

 

Bonds

991.4

 971.9

Multi-currency revolving credit facility('RCF')

440.8

 475.1

Sculptor Capital facility1

91.1

 122.9

Tanjong Baram Project Finance Facility

-

 31.7

SVT Working Capital Facility

11.2

 31.9

Cash and cash equivalents2

(183.4)

(220.5)

Net debt

1,351.1

 1,413.0

 

Notes:

1  Sculptor Capital facility was previously known as the Oz Management facility

2  Includes restricted cash of $1.6 million (see note 10)

In January 2020, EnQuest voluntarily repaid $35.0 million of the RCF early, resulting in the Group having repaid all the amortisations due in 2020. The next amortisation payment of $65.0 million is due 1 April 2021.

In June, EnQuest made an early voluntary repayment of the entire $31.7 million of the Tanjong Baram Project Finance facility having received the first of three instalments from PETRONAS for reimbursement of outstanding net capital expenditure of around $50 million relating to the Tanjong Baram project. The remaining two reimbursement instalments are due from PETRONAS in the second half of the year.

$32.2 million of bond interest was settled through the issue of additional notes ('PIK') and capitalised to the principal of the facilities in the period, reflecting an average oil price of less than $65/bbl over the relevant cash payment condition period in accordance with the terms of the bonds.

The strong production performance at Kraken has driven a $31.8 million reduction in the Sculptor Capital facility in the first six months of the year.

The Group continues to have full access to its UK corporate tax losses of $3,086.8 million at 30 June 2020 (31 December 2019: $2,903.4 million). In the current environment, no material corporation tax or supplementary corporation tax is expected to be paid on UK operational activities for the foreseeable future. The Group paid cash corporate income tax on the Malaysian assets, which will continue throughout the life of the production sharing contract.

 

Income Statement

Revenue

On average, market prices for crude oil in the first half of 2020 were lower than in the same period in 2019. The Group's average realised oil price excluding the impacts of hedging was $39.9/bbl for the six months ended 30 June 2020, 39.0% lower than the comparative period (2019: $65.4/bbl). Revenue is predominantly derived from crude oil sales, which for the six months ended 30 June 2020 totalled $375.5 million, 50.7% lower than the comparative period (2019: $761.9 million), primarily reflecting the significantly lower oil prices and moving from a net overlift to a net underlift position at the end of 30 June 2020. Crude oil sales for the period ended 30 June 2020 were 9.4 MMbbls (2019: 11.6 MMbbls). Revenue from the sale of condensate and gas in the period was $27.6 million (2019: $79.9 million), reflecting significantly lower market prices for gas. Tariff and other income generated $12.4 million (2019: $8.9 million). The Group's commodity hedges and other oil derivatives contributed $35.2 million of realised gains (2019: gains of $7.6 million), including a gain of $5.6 million of non-cash amortisation of option premiums (2019: gain of $4.7 million).

Cost of sales

 

Business performance

 

H1 2020

H1 2019

 

$ million

$ million

 

 

 

Production costs

 137.7

210.2

Tariff and transportation expenses

 36.1

39.2

Realised loss/(gain) on FX derivatives related to operating costs

 0.5

(1.0)

Operating costs

 174.3

248.4

 

 

 

Change in lifting position and inventory

(48.5)

29.4

Depletion of oil and gas assets

 248.4

250.4

Other cost of sales

 36.7

 60.1

Cost of sales

 410.9

 588.3

 

 

 

 

$/Boe

$/Boe

Operating cost per barrel

 

 

 - Production costs

 11.4

 16.9

 - Tariff and transportation expenses

 3.0

 3.2

Average unit operating cost

 14.4

 20.1

 

Cost of sales were $410.9 million for the six months ended 30 June 2020, 30.2% lower than the comparative period (2019: $588.3 million). Operating costs decreased by $74.1 million, primarily reflecting the Group's focus on cost control, including the decision to cease production at Heather and Thistle. The Group's average unit operating cost has decreased by 28.3% to $14.4/Boe.

The credit relating to the Group's lifting position and inventory was $48.5 million (2019: $29.4 million debit). This reflects a switch to a $23.5 million net underlift position at 30 June 2020 from a $28.6 million net overlift position at 31 December 2019.

Depletion expense of $248.4 million was 0.8% lower than the comparative period (2019: $250.4 million).

Other cost of sales of $36.7 million was lower than the comparative period (2019: $60.1 million). This primarily reflects the lower cost of Magnus-related third-party gas purchases following the reduction in the market price for gas partially offset by the $19.0 million inventory write down recognised in the first half of the year, which primarily relates to inventory held at assets scheduled for decommissioning.

Other income and expenses

Net other expense of $11.7 million (2019: net other expenses of $0.3 million) is primarily $45.9 million recognition of the increase in the decommissioning provision of the fully impaired assets offset by foreign exchange gains of $21.0 million and the $10.4 million gain on the termination of the Tanjong Baram risk service contract.

Finance costs and income

Finance costs of $90.9 million were 14.9% lower than the comparative period (2019: $106.8 million). The charges include $52.8 million of interest payable on loans and borrowings and bonds (2019: $69.7 million), $26.1 million of finance charges related to lease liabilities (2019: $26.8 million), $7.1 million unwinding of discount on provisions and liabilities (2019: $7.0 million), together with other facility fees such as commitment fees, and the amortisation of bond fees.

Finance income was a total of $1.1 million for the six months ended 30 June 2020 (2019: $1.1 million).

Taxation

The tax credit for the six months ended 30 June 2020 is $71.5 million (2019: $36.2 million tax charge).

 

 

Remeasurements and exceptional items

Remeasurements and exceptional items resulting in a net loss of $308.1 million before tax have been disclosed separately for the six months ended 30 June 2020 (2019: loss of $120.0 million).

Revenue included unrealised losses of $11.3 million in respect of the mark-to-market movement on the Group's commodity contracts (2019: unrealised losses of $42.9 million). Pre-tax non-cash impairment charges of $409.8 million on the Group's tangible oil and gas assets were recognised, reflecting a reduction in oil price assumptions. Other remeasurement and exceptional items in the first half of 2020 also includes a $161.9 million gain in relation to the fair value recalculation of the Magnus contingent consideration reflecting the reduction in oil price assumptions and a $6.2 million redundancy provision in relation to the Group's transformation programme (2019: increase in contingent consideration on the 75% acquisition of Magnus and associated infrastructure of $26.9 million, $28.1 million unwinding of discount on the end 2018 contingent consideration balance and the provision for settlement of the historical KUFPEC claim of $15.6 million).

A net tax charge of $317.1 million (2019: credit of $41.7 million) has been presented as exceptional, representing the non-cash de-recognition of undiscounted deferred tax assets of $432.6 milliongiven the Group's lower oil price assumptions, partially offset by the tax impact of the above items. The exceptional de-recognition of the undiscounted deferred tax asset balance is made up of de-recognition of previously recognised tax losses and allowances of $363.5 million and the immediate de-recognition of the notional tax-credit of $24.4 million arising on business performance in the six months to June 2020 and ring-fenced expenditure supplement uplift of $44.7 million recognised in the period to 30 June 2020. EnQuest continues to have access to its full UK corporate tax losses of $3,086.8 million at 30 June 2020.

Profit/(loss) for the period

Total pre-tax losses for the period to 30 June 2020 were $373.4 million (2019: profit of $38.7 million), primarily reflecting non-cash impairments. Total post-tax losses for the period to 30 June 2020 were $619.0 million (2019: profit of $44.3 million), and include the partial de-recognition of deferred tax assets.

Cash flow and liquidity

Net debt at 30 June 2020 amounted to $1,351.1 million, including PIK of $166.2 million, compared with net debt of $1,413.0 million, including PIK of $133.3 million, at 31 December 2019. The Group has remained in compliance with financial covenants under its debt facilities throughout the six month period. The movement in net debt was as follows:

 

 

 

$ million

Net debt 1 January 2020

(1,413.0)

Net cash flows from operating activities

275.1

Cash capital expenditure

(101.4)

Net cash received on termination of Tanjong Baram risk service contract

17.1

Lease payments

(56.1)

Magnus contingent consideration

(25.8)

Net interest and finance costs paid

(21.4)

Non-cash capitalisation of interest to principal of bond and debt facilities

(33.3)

Other movements, primarily net foreign exchange loss on cash and debt

7.7

Net debt 30 June 2020

(1,351.1)

 

The Group's reported net cash flows from operating activities for the six months ended 30 June 2020 were $275.1 million, 32.7% down compared to the comparative period (2019: $409.0 million). The main drivers for this decrease are the impact of a significantly lower oil price and lower sales volumes.

Cash outflow on capital expenditure is set out in the table below:

 

 

 

 

H1 2020

H1 2019

 

$ million

$ million

 

 

 

North Sea

 99.4

122.8

Malaysia

 1.9

1.7

Other

 0.1

0.1

 

101.4

124.6

 

Cash capital expenditure primarily relates to Kraken and Magnus drilling activities.

Balance Sheet

The Group's total asset value has decreased by $974.8 million to $3,801.8 million at 30 June 2020 (31 December 2019: $4,776.6 million), mainly due to impairment charge on the Group's tangible oil and gas assets, the non-cash partial de-recognition of the Group's undiscounted deferred tax assets and depletion of oil and gas assets. Net current liabilities have decreased by $69.1 million to $213.6 million as at 30 June 2020 (31 December 2019: $282.7 million). Included in the Group's net current liabilities are $88.6 million of estimated future obligations where settlement is ring-fenced to the financial performance at Kraken and Magnus (31 December 2019: $178.7 million).

Property, plant and equipment ('PP&E')

Property, plant and equipment has decreased to $2,809.1 million at 30 June 2020 from $3,450.9 million at 31 December 2019. This decrease is explained by impairment charges of $409.8 million, depletion and depreciation charges of $252.3 million, change in decommissioning provision of $10.6 million and the termination of the Tanjong Baram risk service contract ($41.6 million), offset by capital additions of $72.5 million. Capital additions are set out in the table below:

 

H1 2020

 

$ million

 

 

North Sea

71.8

Malaysia

0.7

 

72.5

Intangible oil and gas assets

Intangible oil and gas assets have remained consistent at $27.6 million at 30 June 2020 (31 December 2019: $27.6 million).

Trade and other receivables

Trade and other receivables have decreased by $17.7 million to $261.8 million at 30 June 2020 compared to $279.5 million at 31 December 2019. The decrease is driven by a reduction in joint venture debtors, due to timing, partially offset by an increase in the Groups underlift position.

Cash and net debt

The Group had $183.4 million of cash and cash equivalents and $1,351.1 million of net debt, including PIK and capitalised interest of $174.1 million, at 30 June 2020 (31 December 2019: $220.5 million cash and cash equivalents and $1,413.0 million of net debt, including PIK and capitalised interest of $140.7 million). Net debt comprises the following liabilities:

· $219.2 million principal outstanding on the £155 million retail bond, including interest capitalised as PIK of $28.2 million;

· $772.2 million principal outstanding on the high yield bond, including interest capitalised as PIK of $122.2 million;

· $440.8 million of the credit facility, comprising amounts drawn down of $425.0 million and interest capitalised as PIK of $15.8 million;

· $91.1 million on the Sculptor Capital facility, comprising amounts drawn down of $83.2 million and capitalised interest of $7.9 million; and

· $11.2 million relating to the SVT Working Capital Facility.

 

Provisions

The Group's decommissioning provision increased by $27.9 million to $739.8 million at 30 June 2020 (31 December 2019: $711.9 million). The movement is driven primarily by change in estimate $20.4 million, interest unwinding of $7.1 million and additions of $7.5 million offset by utilisation of $7.1 million.

 

Contingent consideration

The contingent consideration relating to the Magnus acquisition decreased by $152.3 million to $505.0 million at 30 June 2020 (30 December 2019: $657.3 million). In the six months ended 30 June 2020, EnQuest repaid $28.9 million to BP and recognised a change in fair value estimate charge of $161.9 million, offset by an unwinding of discount of $39.7 million. 

Income tax

The Group has a corporation tax liability at 30 June 2020 of $2.8 million, compared to $4.1 million at 31 December 2019. This primarily represents tax payable in relation to the activity in Malaysia.

Deferred tax

The Group's net deferred tax asset has decreased from $555.1 million at 31 December 2019 to $311.8 million at 30 June 2020, primarily reflecting the non-cash partial de-recognition of undiscounted deferred tax assets given the Group's lower oil price assumptions. The exceptional de-recognition of the undiscounted deferred tax asset balance is made up of de-recognition of previously recognised tax losses and allowances of $363.5 million and the immediate de-recognition of the notional tax-credit of $24.4 million arising on business performance in the six months to June 2020 and ring-fenced expenditure supplement uplift of $44.7 million recognised in the period to 30 June 2020. EnQuest continues to have access to its full UK corporate tax losses carried forward at the half year amounting to $3,086.8 million (31 December 2019: $2,903.4 million).

Trade and other payables

Trade and other payables of $305.7 million at 30 June 2020 decreased from $419.9 million at 31 December 2019, reflecting settlement of previously deferred capital expenditures and a reduced cost base following the Group's transformation programme.

Lease obligations

As at 30 June 2020, the Group held a lease liability of $680.6 million (31 December 2019: $716.2 million).

Financial Risk Management

Oil price

The Group is exposed to the impact of changes in Brent crude oil prices on its revenue and profits. EnQuest's policy is to manage the impact of commodity prices to protect against volatility and allow availability of cash flow for reinvestment in capital programmes that are driving business growth.

During the six months ended 30 June 2020, commodity derivatives generated a total gain of $24.0 million, with revenue and other operating income including a realised gain of $35.2 million. The unrealised losses of $11.2 million relate mostly to open swaps.

Foreign exchange

EnQuest's functional and presentational currency is US Dollars. Foreign currency risk arises on purchases and the translation of assets and liabilities denominated in currencies other than US Dollars. To mitigate the risks of large fluctuations in the currency markets, the hedging policy agreed by the Board allows for up to 70% of the non-US Dollar portion of the Group's annual capital budget and operating expenditure to be hedged. For specific contracted capital expenditure projects, up to 100% can be hedged.

EnQuest continually reviews its currency exposures and, when appropriate, looks at opportunities to enter into foreign exchange hedging contracts. During the six months ended 30 June 2020, these contracts resulted in an unrealised loss of $3.0 million recognised in the income statement.

Surplus cash balances are deposited as cash collateral against in-place letters of credit as a way of reducing interest costs. Otherwise, cash balances can be invested in short-term bank deposits and AAA-rated liquidity funds, subject to Board-approved limits and with a view to minimising counterparty credit risks.

Going concern

The Group closely monitors and manages its funding position and liquidity risk throughout the year, including monitoring forecast covenant results, to ensure that it has access to sufficient funds to meet forecast cash requirements. Cash forecasts are regularly produced, and sensitivities considered for, but not limited to, changes in crude oil prices (adjusted for hedging undertaken by the Group), production rates and costs. These forecasts and sensitivity analyses are designed to allow management to mitigate liquidity or covenant compliance risks in a timely manner. Management has also repaid the term loan on or ahead of schedule, with no further scheduled payments due in 2020.

The Group continues to monitor actively the impact on operations from COVID-19 and has implemented a number of mitigations to minimise the impact, adopting an approach based upon the principles of safety and welfare of people and security of supply. The Group has remained aligned and supportive of the government position and remained compliant with Dubai, Malaysia and UK government and industry policy. The Group has also been working with a variety of stakeholders, including industry and medical organisations, to ensure its operational response and advice to its workforce is appropriate and commensurate with the prevailing expert advice and level of risk.  Appropriate restrictions on offshore travel have been implemented, such as self-declaration by, and isolation of, individuals who are symptomatic. Pre-mobilisation testing and temperature checks are also in place for all operational staff prior to travelling to the Group's UK North Sea onshore and offshore operating facilities. EnQuest's normal communicable disease process has been updated specifically in respect of COVID-19, with additional offshore isolation capability and agreements in place to transport impacted individuals back onshore in dedicated helicopters. At the Sullom Voe Terminal, the same processes have also been implemented, with isolation capability at local accommodation. 

At the time of publication of EnQuest's Half year Report and Accounts, the Group's day-to-day operations continue without being materially affected by COVID-19.

The Group reviewed each of its assets and related spending plans in response to the material decline in oil price in March 2020. The plan remains not to restart production at the Heather/Broom and Thistle/Deveron fields and CoP at the Dons field is planned in Q2 2021. At the same time, the Group continues to implement its operating cost and capital expenditure reduction programme and this is assumed in the Base case.

The Base case is in line with the Group's production guidance and uses an oil price assumption of $40/bbl for the remainder of 2020, $47/bbl for 2021, with a longer-term price assumption of $60/bbl and are broadly in line with current consensus.

The Base case has been subjected to stress testing by considering the impact of the following plausible downside risks (the 'Downside case'):

• 10.0% discount to Base Case prices;

• Corporate production risking of circa 2.0% for 2020 and circa 3.5% for 2021; and

• Potential restriction of cash associated with additional decommissioning security agreements.

The Base case and Downside case indicate that the Company is able to operate within its existing borrowing facilities for 12 months from the date of approval of the Half year Report and Accounts. The Directors have also performed reverse stress testing with the breakeven price for liquidity in the Going Concern period being c.$17/bbl.

The quarterly liquidity covenant in the facility (the 'Liquidity Test') requires that the Group shows it has sufficient funds available to meet all liabilities when due and payable for the period commencing on each quarter and ending on the date falling 12 months after the final maturity date which is 1 October 2021. The Liquidity Test assumptions include a price deck of the average forward curve oil price, minus a 10% discount, of 15 consecutive business days starting from approximately the middle of the previous quarter.

Under these prices the Group forecasts no breaches in the Base case for the Liquidity Test. The Group also obtained pre-emptive waivers for the remaining quarters in 2020 meaning the next applicable test date is 31 March 2021. By applying the 10% discount stipulated in the Liquidity Test and an additional reduction in excess of 9% on Base case prices, across all periods, the Group would breach this covenant, prior to any mitigations such as asset sales or other funding options. Under a lower oil price scenario, there is a risk of a potential covenant breach, which would therefore require a further covenant waiver to be obtained. The Directors are confident that obtaining further waivers from the facility providers would be forthcoming. Should circumstances arise that differ from the Group's projections, the Directors believe that a number of mitigating actions, including refinancing, asset sales or other funding options, can be executed successfully in the necessary timeframe to meet debt repayment obligations as they become due and in order to maintain liquidity. 

Outside of the going concern period, the RCF expires in October 2021 (see note 12). The Directors are confident the Group will be able to repay or refinance the RCF based on the Group's Base case cash flow projections.

After making appropriate enquiries and assessing the progress against the forecast, projections and the status of the mitigating actions referred to above, the Directors have a reasonable expectation that the Group will continue in operation and meet its commitments as they fall due over the going concern period. Accordingly, the Directors continue to adopt the going concern basis in preparing these financial statements.

The Group's risks and uncertainties were set out in the Annual Report and Accounts 2019. This was published in April 2020 and the below risks and uncertainties reflect the impacts of COVID-19 on the business, where relevant. Although the Group's risks and uncertainties are substantially unchanged from those disclosed in the Group's Annual Report and Accounts 2019, the Safety & Risk Committee has now concluded its assessment of whether 'climate change' should be categorised as a standalone risk area within the Group's risk management framework (in addition to the recognition already accorded to climate change related issues across the existing principal risk areas) and concluded that it should be categorised as such.

For the purposes of meeting the disclosure requirements of DTR 4.2.7(2) we believe that the Group's principal risks and uncertainties for the remaining six months are:

· Health, Safety and Environment ('HSE'):

Oil and gas development, production and exploration activities are by their nature complex, with HSE risks covering many areas, including major accident hazards, personal health and safety, compliance with regulatory requirements, asset integrity issues and potential environmental impact, including those associated with climate change.

 

· Oil and gas prices:

A material decline in oil and gas prices adversely affects the Group's operations and financial condition.

 

· Production:

The Group's production is critical to its success and is subject to a variety of risks including: subsurface uncertainties; operating in a mature field environment; potential for significant unexpected shutdowns; and unplanned expenditure (particularly where remediation may be dependent on suitable weather conditions offshore).

Lower than expected reservoir performance or insufficient addition of new resources may have a material impact on the Group's future growth.

The Group's delivery infrastructure in the UK North Sea is, to a significant extent, dependent on the Sullom Voe Terminal.

Longer-term production is threatened if low oil prices or prolonged field shutdowns requiring high-cost remediation bring forward decommissioning timelines.

 

· Project execution and delivery:  

The Group's success will be partially dependent upon the successful execution and delivery of development projects.

 

· Subsurface risk and reserves replacement:

Failure to develop its contingent and prospective resources or secure new licences and/or asset acquisitions and realise their expected value.

 

· Financial:  

Inability to fund financial commitments or maintain adequate cash flow and liquidity and/or reduce costs.

The Group's term loan and revolving credit facility contains certain financial covenants (based on the ratio of indebtedness incurred under the term loan and revolving facility to EBITDA, finance charges to EBITDA and a requirement for liquidity testing). Prolonged low oil prices, cost increases, including those related to an environmental incident, and production delays or outages, could threaten the Group's liquidity and/or ability to comply with relevant covenants.

Inability to provide appropriate security for decommissioning liabilities.

Further information is contained in the going concern paragraph in the Financial Review.

 

· Human resources:  

The Group's success continues to be dependent upon its ability to attract and retain key personnel and develop organisational capability to deliver strategic growth. Industrial action across the sector, or the availability of competent people given the potential impacts of COVID-19, could also impact the operations of the Group.

 

· Reputation:

The reputational and commercial exposures to a major offshore incident, including those related to an environmental incident, or non-compliance with applicable law and regulation, are significant.

 

· Fiscal risk and government take:  

Unanticipated changes in the regulatory or fiscal environment can affect the Group's ability to deliver its strategy/business plan and potentially impact revenue and future developments.

 

· Joint venture partners:  

Failure by joint venture parties to fund their obligations.

Dependence on other parties where the Group is not the operator.

 

· Competition:  

The Group operates in a competitive environment across many areas, including the acquisition of oil and gas assets, the marketing of oil and gas, the procurement of oil and gas services and access to human resources.

 

· Portfolio concentration:

The Group's assets are primarily concentrated in the UK North Sea around a limited number of infrastructure hubs and existing production (principally oil) is from mature fields. This amplifies exposure to key infrastructure (including ageing pipelines and terminals), political/fiscal changes and oil price movements.

 

· International business:

While the majority of the Group's activities and assets are in the UK, the international business is still material. The Group's international business is subject to the same risks as the UK business (e.g. HSEA, production and project execution); however, there are additional risks that the Group faces, including security of staff and assets, political, foreign exchange and currency control, taxation, legal and regulatory, cultural and language barriers and corruption.

 

· IT security and resilience:  

The Group is exposed to risks arising from interruption to, or failure of, IT infrastructure. The risks of disruption to normal operations range from loss in functionality of generic systems (such as email and internet access) to the compromising of more sophisticated systems that support the Group's operational activities. These risks could result from malicious interventions such as cyber-attacks.

 

For full details of these risks and uncertainties, please see the Group's Annual Report and Accounts 2019.

HALF YEAR GROUP STATEMENT OF COMPREHENSIVE INCOME

For the six months ended 30 June 2020

 

 

 

 

2020

 

 

 

2019

 

 

Notes

Business performance

 Remeasurements and exceptional items (note 4)

Reported

 in period

 

Business performance

Remeasurements and exceptional items (note 4)

Reported

 in period

 

 

$'000

$'000

$'000

 

$'000

$'000

$'000

 

 

Unaudited

Unaudited

Unaudited

 

Unaudited

Unaudited

Unaudited

Revenue and other operating income

5

 450,671

(11,278)

 439,393

 

 858,248

(42,859)

 815,389

Cost of sales

 

(410,870)

(9,201)

(420,071)

 

(588,317)

(4,098)

(592,415)

Gross profit/(loss)

 

 39,801

(20,479)

 19,322

 

 269,931

(46,957)

 222,974

 

 

 

 

 

 

 

 

 

Net impairment (charge)/ reversal to oil and gas assets

 

-

(409,800)

(409,800)

 

-

(3,186)

(3,186)

General and administration expenses

 

(3,538)

-

(3,538)

 

(5,137)

 -

(5,137)

Other income

6

 34,307

 161,908

 196,215

 

 490

1,256

1,746

Other expenses

6

(45,964)

-

(45,964)

 

(787)

(43,049)

(43,836)

Profit/(loss) from operations before tax and finance income/(costs)

 

 24,606

(268,371)

(243,765)

 

 264,497

(91,936)

172,561

 

 

 

 

 

 

 

 

 

Finance costs

 

(90,909)

(39,733)

(130,642)

 

(106,839)

(28,088)

(134,927)

Finance income

 

 1,050

-

 1,050

 

 1,115

-

 1,115

Profit/(loss) before tax

 

(65,253)

(308,104)

(373,357)

 

158,773

(120,024)

38,749

Income tax

 

 71,469

(317,120)

(245,651)

 

(36,203)

41,746

5,543

Profit/(loss) for the period attributable to owners of the parent

 

 6,216

(625,224)

(619,008)

 

122,570

(78,278)

44,292

 

 

Total comprehensive income/(expense) for the period, attributable to owners of the parent

 

(619,008)

 

 

 

44,292

 

 

 

 

 

 

 

 

 

Earnings per share

7

$

 

$

 

$

 

$

Basic

 

 0.004

 

(0.374)

 

 0.075

 

 0.027

Diluted

 

 0.004

 

(0.374)

 

 0.074

 

 0.027

 

 

There was no other comprehensive income/(expense) in the current or prior period.
 

GROUP BALANCE SHEET

At 30 June 2020

 

 

Notes

30 June 2020

31 December 2019

 

 

$'000

$'000

ASSETS

 

Unaudited

Audited

Non-current assets

 

 

 

Property, plant and equipment

8

 2,809,135

3,450,929

Goodwill

 

134,400

 134,400

Intangible oil and gas assets

9

 27,546

27,553

Deferred tax assets

 

 322,254  

576,038

Other financial assets

14

 2

 11

 

 

3,293,337

4,188,931

 

 

 

 

Current assets

 

 

 

Inventories

 

 56,371

78,644

Trade and other receivables

 

 261,823

279,502

Current tax receivable

 

-

-

Cash and cash equivalents

10

 183,374

 220,456

Other financial assets

14

 6,889

 9,083

 

 

 508,457

587,685

TOTAL ASSETS

 

 3,801,794

4,776,616

 

 

 

 

EQUITY AND LIABILITIES

 

 

 

Equity

 

 

 

Share capital and premium

15

 345,420

 345,420

Merger reserve

 

 662,855

 662,855

Share-based payment reserve

 

 1,531

(1,085)

Retained earnings

 

(1,067,137)

(448,129)

TOTAL EQUITY

 

(57,331)

 559,061

 

 

 

 

Non-current liabilities

 

 

 

Borrowings

12

 438,443

 493,424

Bonds

13

 987,025

 966,231

Leases liability

18

 568,165

 614,818

Contingent consideration

16

 442,541

545,550

Provisions

17

 690,397

 706,190

Deferred tax liabilities

 

10,498

20,919

 

 

3,137,069

3,347,132

 

 

 

 

Current liabilities

 

 

 

Borrowings

12

 102,374

165,589

Leases liability

18

 112,447

 101,348

Contingent consideration

16

62,472

 111,711

Provisions

17

 108,792

56,769

Trade and other payables

 

 305,687

 419,855

Other financial liabilities

14

 27,492

 11,073

Current tax payable

 

2,792

4,078

 

 

722,056

870,423

 

 

 

 

TOTAL LIABILITIES

 

3,859,125

4,217,555

 

 

 

 

TOTAL EQUITY AND LIABILITIES

 

3,801,794

4,776,616

 

GROUP STATEMENT OF CHANGES IN EQUITY

For the six months ended 30 June 2020

 

 

 

Share capital and share premium

Merger

reserve

Share-based payments reserve

Retained earnings

Total

 

$'000

$'000

$'000

$'000

$'000

 

Unaudited

Unaudited

Unaudited

Unaudited

Unaudited

 

 

 

 

 

 

Balance at 31 December 2018 (as previously reported)

345,331

662,855

(6,884)

(17,750)

983,552

Adjustment on adoption of IFRS 9/IFRS 16

-

-

-

18,922

18,922

Balance at 1 January 2019

 345,331

 662,855

(6,884)

1,172

 1,002,474

Profit/(loss) for the period

-

-

-

44,292

44,292

Total comprehensive income/(expense) for the period

-

-

-

44,292

44,292

Share-based payment

-

-

2,141

-

2,141

Balance at 30 June 2019

345,331

662,855

(4,743)

45,464

1,048,907

 

 

 

 

 

 

Balance at 1 January 2020

 345,420

 662,855

(1,085)

(448,129)

 559,061

Profit/(loss) for the period

-

-

-

(619,008)

(619,008)

Total comprehensive income/(expense) for the period

-

-

-

(619,008)

(619,008)

Share-based payment

-

-

 2,616

-

 2,616

Balance at 30 June 2020

 345,420

 662,855

 1,531

(1,067,137)

(57,331)

 

 

 

GROUP STATEMENT OF CASH FLOWS

For the six months ended 30 June 2020

 

 

 

2020

2019

 

Notes

$'000

$'000

 

 

Unaudited

Unaudited

CASH FLOW FROM OPERATING ACTIVITIES

 

 

 

Cash generated from operations

20

283,227

 426,170

Cash (paid)/received on sale/(purchase) of financial instruments

 

 4,417

 4,936

Decommissioning spend

 

(7,082)

(5,997)

Income taxes paid

 

(5,458)

(16,114)

Net cash flows from/(used) operating activities

 

275,104

 408,995

 

 

 

 

INVESTING ACTIVITIES

 

 

 

Purchase of property, plant and equipment

 

(101,385)

(122,904)

Purchase of intangible oil and gas assets

 

-

(1,661)

Net cash received on termination of Tanjong Baram risk service contract

6

17,086

-

Payment of Magnus contingent consideration - Profit share

16

(21,088)

-

Interest received

 

 696

 472

Net cash flows (used)/from in investing activities

 

(104,691)

(124,093)

 

 

 

 

FINANCING ACTIVITIES

 

 

 

Repayment of loan facilities

20

(118,906)

(200,675)

Repayment of Magnus contingent consideration - Vendor loan

16

(4,675)

(33,077)

Repayment of obligations under leases

18

(56,139)

(60,623)

Interest paid

 

(21,000)

(51,919)

Other finance costs paid

 

(1,118)

(944)

Net cash flows (used)/from financing activities

 

(201,838)

(347,238)

 

 

 

 

NET INCREASE/(DECREASE) IN CASH AND CASH EQUIVALENTS

 

(31,425)

(62,336)

Net foreign exchange on cash and cash equivalents

 

(4,974)

 2,616

Cash and cash equivalents at 1 January

 

 218,199

 237,200

CASH AND CASH EQUIVALENTS AT 30 JUNE

 

 181,800

 177,480

 

 

 

 

Reconciliation of cash and cash equivalents

 

 

 

Cash and cash equivalents per statement of cash flows

10

 181,800

 177,480

Restricted cash

10

 1,574

 2,645

Cash and cash equivalents per balance sheet

 

 183,374

 180,125

 

 

1.  Corporate information

EnQuest PLC ('EnQuest' or the 'Company') is a public limited company incorporated and domiciled in England and Wales, whose shares are publicly traded on the London Stock Exchange plc's main market for listed securities and on the Stockholm NASDAQ OMX.

The principal activities of the Company and its subsidiaries (together the 'Group') are to enhance hydrocarbon recovery and extend the useful lives of mature and underdeveloped assets and associated infrastructure in a profitable and responsible manner.

The Group's half year condensed financial statements for the six months ended 30 June 2020 were authorised for issue in accordance with a resolution of the Board of Directors on 2 September 2020.

2.  Summary of significant accounting policies

Basis of preparation

The interim condensed consolidated financial statements of the Group for the six months ended 30 June 2020 have been prepared in accordance with IAS 34 'Interim Financial Reporting' as adopted by the European Union. The presentation currency of the Group financial information is United States Dollars and all values in the Group financial information are rounded to the nearest thousand ($'000) except where otherwise stated.

The interim report does not include all the information and disclosures required in the annual financial statements and should be read in conjunction with the Group's annual financial statements as at 31 December 2019. The principal risks and uncertainties have not substantially changed since the date of the last annual report, which are detailed in the Group's annual financial statements as at 31 December 2019.

The financial information contained in this announcement does not constitute statutory financial statements within the meaning of section 435 of the Companies Act 2006.

Consolidated statutory accounts for the year ended 31 December 2019, on which the auditors gave an unqualified audit report, have been filed with the Registrar of Companies. The report contained a material uncertainty related to going concern.

The financial statements have been prepared on the going concern basis. Further information relating to the use of the going concern assumption is provided in the 'Going Concern' section of the Financial Review as set out on page 12. The interim financial statements have been reviewed by the auditor and its report to the Company is included within these interim financial statements.

Accounting policies

The accounting policies adopted in the preparation of the interim condensed financial statements for the six months ended 30 June 2020 are materially consistent with those followed in the preparation of the Group's financial statements for the year ended 31 December 2019, except for the adoption of new standards effective as of 1 January 2020. Any other standard, interpretation or amendment that was issued but not yet effective has not been adopted by the Group. Critical accounting judgements and key sources of estimation uncertainty remain consistent with those disclosed in the 2019 annual report and accounts.

New and amended standards adopted by the Group

The following new standards became applicable for the current reporting period, no material impact was recognised upon application:

· Amendments to References to Conceptual Framework in IFRS Standards

· Definition of a Business (Amendments to IFRS 3)

· Definition of Material (Amendments to IAS 1 and IAS 8)

 

 

3.  Segment information

Segment information for the six month period is as follows:

Period ended 30 June 2020

North Sea

Malaysia

All other segments

Total segments

Adjustments and eliminations(i)

Consolidated

$'000

 

 

 

 

 

 

Revenue:

 

 

 

 

 

 

Revenue from contracts with

customers

 377,808

 33,277

-

 411,085

-

 411,085

Other income

 4,147

-

 210

 4,357

 23,951

 28,308

Total Group revenue

 381,955

 33,277

 210

 415,442

 23,951

 439,393

Segment profit/(loss) (ii)

(291,439)

 10,847

 16,443

(264,149)

 20,384

(243,765)

 

Period ended 30 June 2019

North Sea

Malaysia

All other segments

Total segments

Adjustments and eliminations(i)

Consolidated

$'000

 

 

 

 

 

 

Revenue:

 

 

 

 

 

 

Revenue from contracts with

customers

 773,493

 71,643

-

 845,136

-

 845,136

Other income

 5,285

-

 262

 5,547

(35,294)

(29,747)

Total Group revenue

 778,778

 71,643

 262

 850,683

(35,294)

 815,389

Segment profit/(loss) (ii)

180,999

 28,484

1,482

210,965

(38,404)

172,561

 

The following table presents total assets for the Group's operating segments as at 30 June 2020 and 31 December 2019:

Period ended 30 June 2020

North Sea

Malaysia

All other segments

Total segments

Adjustments and eliminations(i)

Consolidated

$'000

 

 

 

 

 

 

Assets

 

 

 

 

 

 

30 June 2020

3,620,819

164,802

16,173

3,801,794

-

3,801,794

31 December 2019

4,593,665

173,175

9,776

4,776,616

-

4,776,616

(i) Finance income and costs and gains and losses on derivatives are not allocated to individual segments as the underlying instruments are managed on a Group basis

(ii) Inter-segment revenues are eliminated on consolidation. All other adjustments are part of the reconciliations presented further below

Reconciliation of profit/(loss):

 

Period ended

30 June

2020

Period ended

30 June

2019

 

$'000

$'000

 

 

 

Segment profit/(loss)

(264,149)

210,965

Finance costs

(130,642)

(134,927)

Finance income

1,050

1,115

Gains/(losses) on oil and foreign exchange derivatives

20,384

(38,404)

Profit/(loss) before tax

(373,357)

38,749

4.  Remeasurements and exceptional items

Period ended 30 June 2020

$'000

Fair value
remeasurement (i)

Impairments and write offs (ii)

Total

Revenue and other operating income

(11,278)

-

-

(11,278)

Cost of sales

(3,039)

-

(9,201)

Net impairment (charge)/reversal on oil and gas assets

-  

(409,800)

(409,800)

Other income

 161,908

-

 161,908

Finance costs

 -

-

(39,733)

(39,733)

 

 147,591

(409,800)

(308,104)

Tax on items above

(58,090)

158,188

115,470

De-recognition of undiscounted deferred tax asset(iv)

-

(432,590)

-

(432,590)

 

 89,501

(684,202)

(30,523)

(625,224)

 

Period ended 30 June 2019

$'000

Fair value
remeasurement (i)

Impairments and write offs (ii)

Total

 

 

 

 

Revenue and other operating income

(42,859)

-

-

(42,859)

Cost of sales

(4,074)

(24)

(4,098)

Net impairment (charge)/reversal on oil and gas assets

-

(3,186)

(3,186)

Other income

-

-

1,256

Other expenses

(26,900)

(519)

(43,049)

Finance costs

-

-

(28,088)

(28,088)

 

(73,833)

(3,729)

(120,024)

Tax on items above

29,510

1,492

41,746

 

(44,323)

(2,237)

(31,718)

(78,278)

(i)  Fair value remeasurements include unrealised mark-to-market movements on derivative contracts and other financial instruments and the impact of recycling realised gains and losses (including option premiums) out of 'Remeasurements and exceptional items' and into 'Business performance' profit or loss. Other income includes the fair value adjustment relating to the contingent consideration on the 75% acquisition of Magnus and associated infrastructure of $161.9 million (note 16) (2019: Other expenses include the fair value adjustment relating to the contingent consideration on the 75% acquisition of Magnus and associated infrastructure of $26.9 million (note 16))

(ii)  Impairments and write offs include an impairment of tangible oil and gas assets totalling $409.8 million (2019: $3.2 million) (note 8)

(iii)  Other expenses mainly relate to unwind of discounting on contingent consideration on the 75% acquisition of Magnus and associated infrastructure of $39.7 million (note 16) and the redundancy provision in relation to the Group's transformation programme of $6.1 million (2019: Other expenses mainly includes the unwind of discounting on contingent consideration on the 75% acquisition of Magnus and associated infrastructure of $28.1 million (note 16) and the provision for settlement of the historical KUFPEC claim of $15.6 million)

(iv)  Non-cash partial de-recognition of undiscounted deferred tax assets given the Group's lower oil price assumptions

 

 

 

5.  Revenue and other operating income

The Group generates revenue through the sale of crude oil, gas and condensate to third parties, and through the provision of infrastructure to its customers for tariff income. Further details are described in the last annual financial statements.
 

 

Period ended

30 June

Period ended

30 June

 

2020

2019

 

$'000

$'000

 

 

 

Revenue from contracts with customers

 

 

Revenue from crude oil sales

 375,518

 761,850

Revenue from gas and condensate sales

 27,574

 79,941

Tariff revenue

 7,993

 3,345

Total revenue from contracts with customers

 411,085

 845,136

 

 

 

Rental income

 3,532

3,524

Realised gains on oil derivative contracts (note 14)

 35,229

 7,565

Other operating revenue

 825

 2,023

Business performance revenue

 450,671

858,248

 

 

 

Unrealised losses on oil derivative contracts(i) (note 14)

(11,278)

(42,859)

Total revenue and other operating income

 439,393

 815,389

(i) Unrealised gains and losses on oil derivative contracts are disclosed as fair value remeasurement items in the income statement (see note 4)

 

6.  Other income/expense

(a)  Other income

 

Period ended

30 June

Period ended

30 June

 

2020

2019

 

$'000

$'000

 

 

 

Net foreign exchange gains

 20,971

-

Gain on termination of Tanjong Baram risk service contract

 10,412

Other

 2,924

 490

Business performance other income

 34,307

 490

Change in fair value of contingent consideration (note 16)

161,908

-

Write down of receivable

-

1,203

Other exceptional items

-

29

Total other income

 196,215

1,746

On 3 March 2020, the Group terminated the Tanjong Baram small field risk service contract with PETRONAS. Following the termination, the Group will receive three instalments from PETRONAS for the reimbursement of net outstanding capital expenditure of c.$50 million. The Group received $24.4 million from Petronas in June 2020, of which $7.3 million was received on behalf of the non-operating partner and immediately transferred. The amount has been presented net in the statement of cash flows to represent the substance of the transaction, with the remaining two instalments due from PETRONAS in the second half of the year and recognised net within receivables. On termination, the Tanjong Baram assets were carried at c.$40 million resulting in the $10.4 million gain (see note 8).

 

 

 

(b)  Other expense

 

Period ended

30 June

Period ended

30 June

 

2020

2019

 

$'000

$'000

 

 

 

Net foreign exchange losses

-

(308)

Change in provisions (note 17)

 (45,879)

-

Exploration and evaluation expenses: Pre-licence costs expenses

 (66)

 (30)

Other

 (19)

(449)

Business performance other income

 (45,964)

 (787)

Change in fair value of contingent consideration (note 16)

-

(26,900)

KUFPEC provision (note 17)

-

(15,630)

Exploration and evaluation expenses: Written off and impaired

-

(519)

Total other expense

 (45,964)

(43,836)

 

7.  Earnings per share

The calculation of earnings per share is based on the profit after tax and on the weighted average number of Ordinary shares in issue during the period.

Basic and diluted earnings per share are calculated as follows:

 

 

Profit /(loss) after tax

Weighted average number of Ordinary shares

 

Earnings per share

 

Period ended

30 June

Period ended

30 June

Period ended

30 June

 

2020

 2019

2020

 2019

2020

 2019

 

 $'000

 $'000

million

million

$

$

 

 

 

 

 

 

 

Basic

(619,008)

44,292

 1,654.8

 1,628.6

(0.374)

0.027

Dilutive potential of Ordinary shares granted under share-based incentive schemes

-

 6.9

 30.7

-

Diluted

(619,008)

44,292

 1,661.7

 1,659.3

(0.374)

0.027

Basic (Business performance)

 6,216

122,570

 1,654.8

 1,628.6

 0.004

0.075

Diluted (Business perfomance)

 6,216

122,570

 1,661.7

 1,659.3

 0.004

0.074

 

 

8.  Property, plant and equipment

 

Oil and gas assets

Office furniture, fixtures and fittings

Right-of-use assets

 Total

 

$'000

$'000

$'000

$'000

Cost:

 

 

 

 

At 1 January 2020

8,547,769

62,453

857,089

 9,467,311

Additions

 71,452

 1,016

-

 72,468

Disposals/termination of Tanjong Baram risk service contract

(83,312)

(143)

(936)

(84,391)

Change in decommissioning provision (note 17)

(10,591)

-

-

(10,591)

At 30 June 2020

 8,525,318

 63,326

 856,153

 9,444,797

 

 

 

 

 

Accumulated depletion and impairment:

 

 

 

 

At 1 January 2020

5,797,924

46,568

171,890

6,016,382

Charge for the period

204,461

2,148

45,716

252,325

Disposals/termination of Tanjong Baram risk service contract

 (42,501)

 (113)

 (231)

 (42,845)

Impairment charge for the period

301,640

-

108,160

409,800

At 30 June 2020

6,261,524

 48,603

325,535

 6,635,662

 

 

 

 

 

Net carrying amount:

 

 

 

 

At 30 June 2020

2,263,794

 14,723

530,618

2,809,135

At 31 December 2019

 2,749,845

 15,885

 685,199

 3,450,929

At 30 June 2019

 3,527,479

 17,006

737,582

4,282,067

 

Impairment testing of oil and gas assets

Impairments to the Group's producing oil and gas assets and reversals of impairments are set out in the table below:

 

Impairment

(charge)/reversal

Recoverable amount(i)

 

Period ended

30 June 2020

$'000

Year ended

31 December 2019

$'000

30 June

2020

$'000

31 December 2019

$'000

 

 

 

 

 

North Sea

409,800

(637,500)

628,090

46,462

Malaysia

-

-

-

Net impairment reversal/(charge)

(409,800)

(637,500)

 

 

 

(i)  Recoverable amount has been determined on a fair value less costs of disposal basis. The amounts disclosed above are in respect of assets where an impairment (or reversal) has been recorded. Assets which did not have any impairment or reversal are excluded from the amounts disclosed

The interim report does not include all the information and disclosures required in the annual financial statements and should be read in conjunction with the Group's annual financial statements as at 31 December 2019. The key sources of estimation uncertainty and the discount rate applied have not changed since the date of the last annual report. Future oil prices are a key driver of estimation and the oil price assumptions based on an internal view of forward curve prices at 30 June 2020 are $40.0/bbl (2020), $47.0/bbl (2021) and $60.0/bbl real thereafter, inflated at 2.0% per annum from 2023 (30 December 2019: $63.0/bbl (2020), $65.0/bbl (2021), $67.0/bbl (2022) and $70.0/bbl real thereafter, inflated at 2.0% per annum from 2024). The impairment in the period related to North Sea assets, mainly reflecting these changes in oil price assumptions.

The Group's recoverable value of assets is highly sensitive, inter alia, to oil price achieved and production volumes. Sensitivities have been run on the oil price assumption, with a 10% change being considered to be a reasonable possible change for the purposes of sensitivity analysis. A 10% reduction in oil price would increase the net pre-tax impairment by approximately $440.1 million, with the additional impairment attributable to the fields in the North Sea and goodwill.

       

9.  Intangible oil and gas assets

 

Cost

Accumulated impairment

Net carrying amount

 

$'000

$'000

$'000

At 1 January 2020

174,964

(147,411)

27,553

Additions

 175

-

 175

Change in decommissioning provision (note 17)

(182)

-

(182)

Write-off of relinquished licences previously impaired

(12,858)

 12,858

-

At 30 June 2020

 162,099

(134,553)

 27,546

 

10.  Cash and cash equivalents

 

Period ended

30 June 2020

Year ended

31 December 2019

 

$'000

$'000

Available cash

 

 

Cash at bank

91,323

137,365

Short-term deposits

2,753

6,849

Total available cash

94,076

144,214

Ring-fenced cash

 

 

Joint venture accounts

66,211

32,365

Operational accounts

21,513

41,620

Total ring-fenced cash

87,724

73,985

Cash at bank and in hand

181,800

218,199

Restricted cash - Cash subject to currency controls or other legal restrictions

 

 

Cash held in escrow

1,574

1,611

Cash collateral

-

646

Total restricted cash - Cash subject to currency controls or other legal restrictions

1,574

2,257

Total cash and cash equivalents

183,374

220,456

 

 

 

11.  Fair value measurement

The following table provides the fair value measurement hierarchy of the Group's assets and liabilities:

30 June 2020

Total

Quoted prices in active markets

Significant observable inputs

Significant unobservable inputs

 

 

(Level 1)

(Level 2)

(Level 3)

 

$'000

$'000

$'000

$'000

Financial assets measured at fair value:

 

 

 

 

Derivative financial assets at FVPL

 

 

 

 

Oil commodity derivative contracts(i)

 4,510

-

 4,510

-

Other financial assets at FVPL

 

 

 

 

Quoted equity shares

 2

 2

-

-

Liabilities measured at fair value:

 

 

 

 

Derivative financial liabilities at FVPL

 

 

 

 

Oil commodity derivative contracts(i)

 26,385

-

 26,385

-

Foreign currency derivative contracts(i)

 1,107

-

 1,107

-

Other financial liabilities measured at FVPL

 

 

 

 

Contingent consideration(ii)

505,012

-

-

505,012

Liabilities for which fair values are disclosed

 

 

 

 

Interest-bearing loans and borrowings

 543,092

-

-

 543,092

Obligations under leases

680,612

-

-

680,612

Retail bond

 174,900

 174,900

-

-

High yield bond

 467,316

 467,316

-

-

 

 

31 December 2019

Total

Quoted prices in active markets

Significant observable inputs

Significant unobservable inputs

 

 

(Level 1)

(Level 2)

(Level 3)

 

$'000

$'000

$'000

$'000

Financial assets measured at fair value:

 

 

 

 

Derivative financial assets at FVPL

 

 

 

 

Oil commodity derivative contracts(i)

 288

-

 288

-

Foreign currency derivative contracts(i)

 1,932

-

 1,932

-

Other financial assets at FVPL

 

 

 

-

Quoted equity shares

11

11

-

-

Liabilities measured at fair value:

 

 

 

 

Derivative financial liabilities at FVPL

 

 

 

 

Oil commodity derivative contracts(i)

11,073

-

11,073

-

Other financial liabilities measured at FVPL

 

 

 

 

Contingent consideration(ii)

657,261

-

-

657,261

Liabilities for which fair values are disclosed

 

 

 

 

Interest-bearing loans and borrowings

 661,638

-

-

 661,638

Obligations under leases

716,166

-

-

716,166

Retail bond

 195,948

 195,948

-

-

High yield bond

 655,462

 655,462

-

-

 

 

 

 

 

(i)  Valued by the counterparties, with the valuations reviewed internally and corroborated with readily available market data

(ii)  Contingent consideration is measured at fair value through profit/loss ('FVPL') using level 3 valuation process (see note 14)

There have been no transfers between Level 1 and Level 2 during the period (2019: no transfers).

 

 

 

12.  Loans and borrowings

The Group's loans are debt instruments carried at amortised cost as follows:

 

30 June 2020

 

31 December 2019

 

Principal

Fees

Total

 

Principal

Fees

Total

 

$'000

$'000

$'000

 

$'000

$'000

$'000

 

 

 

 

 

 

 

 

Credit facility(i)

 440,792

-

 440,792

 

 475,097

-

 475,097

Sculptor Capital facility

 91,055

(2,275)

 88,780

 

 122,912

(2,625)

 120,287

SVT Working Capital Facility

 11,245

-

 11,245

 

 31,899

-

 31,899

Tanjong Baram loan

-

-

-

 

 31,730

-

 31,730

Total loans

 543,092

(2,275)

 540,817

 

 661,638

(2,625)

 659,013

 

 

 

 

 

 

 

 

Due within one year

 

 

 102,374

 

 

 

 165,589

Due after more than one year

 

 

 438,443

 

 

 

 493,424

Total loans

 

 

 540,817

 

 

 

 659,013

 

(i)  At 30 June 2020, the total carrying amount of the credit facility on the balance sheet was $441.7 million, comprising the loan principal drawn down of $425.0 million, $15.8 million of interest capitalised to the PIK amount and $0.9 million accrued interest (2019: full carrying amount $477.4 million, comprising the loan principal drawn down of $460.0 million, $15.1 million of interest capitalised to the PIK amount and $2.3 million accrued interest). The maturity date of the credit facility is October 2021. Further details on the credit facility are included in the Group's Annual Report and Accounts 2019.

 

13.  Bonds

The Group's bonds are debt instruments carried at amortised cost as follows:

 

30 June 2020

 

31 December 2019

 

Principal

Fees

Total

 

Principal

Fees

Total

 

$'000

$'000

$'000

 

$'000

$'000

$'000

 

 

 

 

 

 

 

 

High yield bond(i)

 772,168

(3,487)

 768,681

 

 746,056

(4,483)

 741,573

Retail bond(ii)

 219,191

(847)

 218,344

 

 225,747

(1,089)

 224,658

Total bonds due after more than one year

 991,359

(4,334)

 987,025

 

 971,803

(5,572)

 966,231

(i)  The total carrying value of the bond as at 30 June 2020 is $782.4 million. This includes bond principal of $772.2 million, bond interest accrual of $11.3 million and liability for the IFRS 9 Financial Instruments loss on modification of $2.4 million less unamortised fees of $3.5 million (2019: $754.8 million. This includes bond principal of $746.1 million, bond interest accrual of $11.0 million and liability for the IFRS 9 Financial Instruments loss on modification of $2.2 million less unamortised fees of $4.5 million)

(ii)  The total carrying value of the bond as at 30 June 2020 is $233.9 million. This includes bond principal of $219.2 million, bond interest accrual of $5.7 million and liability for the IFRS 9 Financial Instruments loss on modification of $9.8 million less unamortised fees of $0.8 million (2019: $241.1 million. This includes bond principal of $225.7 million, bond interest accrual of $6.0 million and liability for the IFRS 9 Financial Instruments loss on modification of $10.5 million less unamortised fees of $1.1 million)

14.  Other financial assets and financial liabilities

(a)  Summary

 

30 June 2020

 

31 December 2019

 

Assets

Liabilities

 

Assets

Liabilities

 

$'000

$'000

 

$'000

$'000

Fair value through profit or loss:

 

 

 

 

 

Derivative commodity contracts

 4,510

 26,385

 

 288

 11,073

Derivative foreign exchange contracts

-

 1,107

 

 1,932

-

Amortised cost:

 

 

 

 

 

Other receivables

 2,379

-

 

6,863

-

Total current

 6,889

 27,492

 

 9,083

 11,073

 

 

 

 

 

 

Fair value through profit or loss:

 

 

 

 

 

Quoted equity shares

 2

-

 

11

-

Total non-current

 2

-

 

11

-

 

(b)  Commodity contracts

The Group uses derivative financial instruments to manage its exposure to the oil price, including put and call options, swap contracts and futures.

During the six months ended 30 June 2020, gains totalling $24.0 million (2019: losses of $34.2 million) were recognised in respect of commodity contracts designated as FVPL. This included realised gains totalling $35.2 million (2019: gains of $8.7 million) on contracts that matured during the period, and mark-to-market losses totalling $11.2 million (2019: losses of $42.9 million). Of the realised amounts recognised during the period in Business performance revenue, $5.6 million (2019: $4.7 million) was in respect of the amortisation of premiums on these options. The premiums received and paid are amortised into Business performance revenue over the life of the option.

(c)  Foreign currency contracts

The Group enters into a variety of foreign currency contracts, primarily in relation to Sterling. During the six months ended 30 June 2020, these contracts resulted in an unrealised loss of $3.0 million recognised in the income statement (2019: loss of $2.0 million).

(d)  Income statement impact

The income/(expense) recognised for commodity, currency and interest rate derivatives are as follows:

 

 

Revenue and other operating income

 

Cost of sales

Period ended

Realised

Unrealised

Realised

Unrealised

30 June 2020

$'000

$'000

$'000

$'000

 

 

 

 

 

Commodity options

 20,711

 4,972

-

-

Commodity swaps

 9,556

(16,223)

-

-

Commodity futures

 4,962

(27)

-

-

Foreign exchange swaps

-

-

(528)

(3,039)

 

 35,229

(11,278)

(528)

(3,039)

 

 

 

Revenue and other operating income

 

Cost of sales

Period ended

Realised

Unrealised

Realised

Unrealised

30 June 2019

$'000

$'000

$'000

$'000

 

 

 

 

 

Commodity options

 8,053

(47,649)

-

-

Commodity swaps

 2,604

 4,848

-

-

Commodity futures

(1,985)

(58)

-

-

Commodity collar on prepayment transaction

(1,107)

-

-

-

Foreign exchange swaps

-

-

(42)

(2,012)

Carbon forward contracts

-

-

 1,006

(2,062)

 

 7,565

(42,859)

 964

(4,074)

 

(e)  Other receivables

 

Other receivables

 

$'000

 

 

At 1 January 2020

6,874

Change in fair value

(8)

Utilised/(collected) during the period

(4,760)

Unwinding of discount

275

At 30 June 2020

2,381

 

 

Comprised of:

 

BUMI receivable

 2,379

Other

 2

Total

 2,381

 

 

Classified as:

 

Current

 2,379

Non-current

 2

 

 2,381

 

Other receivables

In August 2016, EnQuest agreed with Armada Kraken PTE Ltd ('BUMI') that BUMI would refund $65 million (EnQuest's share being $45.8 million) of a $100.0 million lease prepayment made in 2014 for the FPSO for the Kraken field.
This refund was receivable during 2018 and onwards. Included within other receivables at 30 June 2020 is an amount of $2.4 million representing the discounted value of EnQuest's share of these repayments (31 December 2019: $6.9 million).
  A total of $4.8 million was collected during the period.

 

15.  Share capital and premium

The share capital of the Company as at 30 June 2020 was $118.3 million (31 December 2019: $118.3 million) comprising 1,695,801,955 Ordinary shares of £0.05 each (31 December 2019: 1,695,801,955) and share premium of $227.1 million (31 December 2019: $227.1 million).

 

16.  Contingent consideration

 

Magnus 75%

Magnus decommissioning-linked liability

 

Total

 

$'000

$'000

$'000

 

 

 

 

At 1 January 2020

641,400

15,861

657,261

Change in fair value

(159,527)

 (2,380)

(161,907)

Unwinding of discount

38,940

793

39,733

Paid

 (28,900)

(1,174)

(30,074)

At 30 June 2020

491,913

13,100

505,013

 

 

 

 

Classified as

 

 

 

Current

61,643

829

62,472

Non-current

430,270

12,271

442,541

 

491,913

13,100

505,013

 

75% Magnus acquisition contingent consideration

On 1 December 2018, EnQuest completed the acquisition of the additional 75% interest in the Magnus oil field ('Magnus') and associated interests (collectively the 'Transaction assets') which was part funded through a vendor loan and profit share arrangement with BP. This acquisition followed from the acquisition of initial interests completed in December 2017.

 

The consideration for the acquisition was $300 million, consisting of $100 million cash contribution, paid from the funds received through the rights issue undertaken in October 2018, and $200 million deferred consideration financed by BP. The deferred consideration, which is repayable solely out of cash flows which are in excess of operating cash outflows, including capital expenditure, from Magnus, is secured over the interests in the Transaction assets and accrues interest at a rate of 7.5% per annum on the deferred consideration. The consideration also included a contingent profit sharing arrangement whereby EnQuest and BP share the net cash flow generated by the 75% interest on a 50:50 basis, subject to a cap of $1 billion received by BP. Together, the deferred consideration and contingent profit sharing arrangement are known as contingent consideration.

 

The contingent consideration was fair valued at 30 June 2020, which resulted in a decrease in fair value of $159.5 million and unwinding of discount of $38.9 million was charged to finance costs during the period, both recognised through remeasurements and exceptional items in the consolidated income statement. The contingent profit sharing arrangement cap of $1 billion is not forecast to be reached in the latest life of field present value calculations. A total of $28.9 million was repaid during the first half of 2020. At 30 June 2020, the fair value of the contingent consideration was $491.9 million (31 December 2019: $641.4 million).

 

Magnus decommissioning-linked contingent consideration

As part of the Magnus and associated interests acquisition, EnQuest agreed to pay additional consideration in relation to the management of the physical decommissioning costs of Magnus. At 30 June 2020, the amount due to BP by reference to 30% of BP's decommissioning costs on Magnus on an after-tax basis was $13.1 million (31 December 2019: $15.9 million).

 

17.  Provisions

 

Decommissioning provision

Other provisions

 

Total

 

$'000

$'000

$'000

 

 

 

 

At 1 January 2020

711,898

51,061

762,959

Additions

 7,462

6,162

13,624

Changes in estimates

 20,377

-

20,377

Changes in fair value

-

7,267

7,267

Unwinding of discount

 7,116

398

 7,514

Utilisation

(7,082)

(5,625)

(12,707)

Foreign exchange

-

 155

 155

At 30 June 2020

  739,771

59,418

 799,189

 

 

 

Classified as

 

 

 

Current

 77,908

 30,884

 108,792

Non-current

 661,863

 28,534

 690,397

 

 739,771

 59,418

 799,189

Decommissioning provision

An additional provision of $20.4 million was recognised mainly in relation to the accelerated decommissioning profile of Heather offset by the impact of exchange rates on the Group's underlying Sterling and Malaysian Ringgit cost estimates. At 30 June 2020, an estimated $77.9 million is expected to be utilised within the next year, $223.5 million between one and five years, $161.0 million between six and ten years, and the remainder in later periods.

 

Other provisions

At 30 June 2020, the amount due to BP by reference to 7.5% of BP's decommissioning costs on Thistle and Deveron on an after-tax basis was $47.6 million (31 December 2019: $39.8 million). The increase was primarily driven by the earlier than expected cessation of production at Thistle/Deveron.

 

During 2019, the Group finalised and settled the historical breach of warranty claims with KUFPEC , the Group's field partner in respect of Alma/Galia. The settlement completed all outstanding claims and a provision of $22.5 million was recognised, in 2019, for the payments to be made to KUFPEC. A total of $5.6 million was paid by June 2020, with $5.6 million disclosed within current provision as scheduled for repayment (31 December 2019: $11.3 million).

 

At 30 June 2020 the Group recognised a redundancy provision of $6.2 million in relation to its transformation programme. The Group expects to settle this liability by year end.

 

 

18.  Leases

Right-of-use assets and lease liabilities

Set out below are the carrying amounts of the Group's right-of-use assets and lease liabilities and the movements during the period:

 

 

Right-of-use
assets
$'000

Lease

liabilities

$'000

As at 31 December 2019

685,199

716,166

Depreciation expense

(45,716)

 

Impairment

(108,160)

-

Disposal/de-recognition

(705)

(726)

Interest expense

-

26,093

Payments

-

(56,139)

Foreign exchange movements

-

(4,782)

As at 30 June 2020

530,618

680,612

Current

-

112,447

Non-current

-

568,165

 

-

680,612

 

Amounts recognised in profit or loss

 

Period ended

30 June

2020

$'000

Depreciation expense of right-of-use assets

 45,716

Impairment of right-of-use assets

(108,160)

Interest expense on lease liabilities

 26,093

Rent expense - short-term leases

 1,988

Rent expense - leases of low-value assets

 21

Total amounts recognised in profit or loss

(34,342)

 

 

19.  Contingencies

Contingencies

The Group becomes involved from time to time in various claims and lawsuits arising in the ordinary course of its business. The Company is not, nor has been during the past 12 months, involved in any governmental, legal or arbitration proceedings which, either individually or in the aggregate, have had, or are expected to have, a material adverse effect on the Company's and/or the Group's financial position or profitability, nor, so far as the Company is aware, are any such proceedings pending or threatened.

20.  Cash flow information

Cash generated from operations

 

 

Period ended

30 June

Period ended

30 June

 

 

2020

2019

 

 

$'000

$'000

 

 

 

 

Profit/(loss) before tax

 

(373,357)

38,749

Depreciation

 

 3,941

 5,077

Depletion

 

 248,384

 250,366

Exploration costs impaired/(reversed) and written off

 

-

 519

Net impairment charge/(reversal) to oil and gas assets

 

409,800

 3,186

Write down of inventory

 

18,959

 5,679

Write down/(back) of asset

 

-

(1,203)

Impairment (reversal)/charge to investments

 

 8

-

Share-based payment charge

 

 2,616

2,141

Gain on termination of Tanjong Baram risk service contract

 

(10,412)

-

Change in deferred consideration

 

(122,175)

54,988

Unwind of decommissioning provision

 

7,116

 6,713

Change in other provisions

 

6,560

 15,936

Amortisation of option premiums

 

(5,587)

(4,654)

Unrealised (gain)/loss on commodity financial instruments

 

 11,278

 42,859

Unrealised loss/(gain) on other financial instruments

 

 3,039

 4,074

Unrealised exchange (gain)/loss

 

(18,371)

 (412)

Net finance (income)/expense

 

82,345

98,675

Operating profit before working capital changes

 

264,144

522,693

(Increase)/decrease in trade and other receivables

 

 52,639

(42,353)

(Increase)/decrease in inventories

 

 3,129

 5,786

Increase/(decrease) in trade and other payables

 

(36,685)

(59,956)

Cash generated from operations

 

 283,227

 426,170

 

Changes in liabilities arising from financing activities

Period ended 30 June 2020

Loans and borrowings

Bonds

Lease

liabilities

Total

 

$'000

$'000

$'000

$'000

 

 

 

 

 

At 1 January 2020

(661,282)

(995,983)

(716,166)

(2,373,431)

Cash movements:

 

 

 

 

Repayments of loans and borrowings

118,906

-

-

118,906

Repayment of lease liabilities

-

-

56,139

56,139

Cash interest paid in year

17,863

-

-

17,863

Non-cash movements:

 

 

 

 

Unwinding of finance discount

(18,711)

(34,117)

(26,093)

(78,921)

Fee amortisation

(350)

(1,241)

-

(1,591)

Foreign exchange adjustments

809

15,176

4,782

20,767

Disposal/de-recognition of leases

-

-

726

726

Other non-cash movements

1,074

3

-

1,077

At 30 June 2020

(541,691)

(1,016,162)

(680,612)

(2,238,465)

 

Reconciliation of carrying value

 

Loans and borrowings

Bonds

Lease

liabilities

Total

 

$'000

$'000

$'000

$'000

 

 

 

 

 

Principal

(543,092)

(991,359)

(680,612)

(2,215,063)

Unamortised fees

2,275

4,334

-

6,609

Accrued interest

(874)

(29,137)

-

(30,011)

At 30 June 2020

(541,691)

(1,016,162)

(680,612)

(2,238,465)

The Directors confirm that, to the best of their knowledge, the condensed set of financial statements for the six months ended 30 June 2019 has been prepared in accordance with IAS 34 'Interim Financial Reporting' as adopted by the European Union, and that the half year management report includes a fair review of the information required by
DTR 4.2.7R and a true and fair review of the information required by DTR 4.2.8R of the Disclosure and Transparency Rules.

 

A list of current Directors is maintained on the EnQuest PLC website which can be found at www.enquest.com .

 

 

 

By the order of the Board

 

 

 

 

 

Amjad Bseisu

Chief Executive

 

2 September 2020

 

 

We have been engaged by the Company to review the condensed set of financial statements in the half-yearly financial report for the six months ended 30 June 2020 which comprises the Group statement of comprehensive income, the Group balance sheet, the Group statement of changes in equity, the Group statement of cash flows and related notes 1 to 20. We have read the other information contained in the half yearly financial report and considered whether it contains any apparent misstatements or material inconsistencies with the information in the condensed set of financial statements.

Directors' Responsibilities

The half-yearly financial report is the responsibility of, and has been approved by, the Directors. The Directors are responsible for preparing the half-yearly financial report in accordance with the Disclosure Guidance and Transparency Rules of the United Kingdom's Financial Conduct Authority.

As disclosed in note 2, the annual financial statements of the Group are prepared in accordance with IFRSs as adopted by the European Union. The condensed set of financial statements included in this half-yearly financial report has been prepared in accordance with International Accounting Standard 34, "Interim Financial Reporting", as adopted by the European Union.

Our Responsibility

Our responsibility is to express to the Company a conclusion on the condensed set of financial statements in the
half-yearly financial report based on our review.

Scope of Review

We conducted our review in accordance with International Standard on Review Engagements (UK and Ireland) 2410 "Review of Interim Financial Information Performed by the Independent Auditor of the Entity" issued by the Financial Reporting Council for use in the United Kingdom. A review of interim financial information consists of making enquiries, primarily of persons responsible for financial and accounting matters, and applying analytical and other review procedures. A review is substantially less in scope than an audit conducted in accordance with International Standards on Auditing (UK) and consequently does not enable us to obtain assurance that we would become aware of all significant matters that might be identified in an audit. Accordingly, we do not express an audit opinion.

Conclusion

Based on our review, nothing has come to our attention that causes us to believe that the condensed set of financial statements in the half-yearly financial report for the six months ended 30 June 2020 is not prepared, in all material respects, in accordance with International Accounting Standard 34 as adopted by the European Union and the Disclosure Guidance and Transparency Rules of the United Kingdom's Financial Conduct Authority.

Use of Report

This report is made solely to the company in accordance with International Standard on Review Engagements (UK and Ireland) 2410 "Review of Interim Financial Information Performed by the Independent Auditor of the Entity" issued by the Financial Reporting Council. Our work has been undertaken so that we might state to the company those matters we are required to state to it in an independent review report and for no other purpose. To the fullest extent permitted by law, we do not accept or assume responsibility to anyone other than the company, for our review work, for this report, or for the conclusions we have formed.

Deloitte LLP

London, United Kingdom

2 September 2020

Glossary - Non-GAAP measures

The Group uses Alternative Performance Measures ('APMs') when assessing and discussing the Group's financial performance, financial position and cash flows that are not defined or specified under IFRS. The Group uses these APMs, which are not considered to be a substitute for, or superior to, IFRS measures, to provide stakeholders with a clear and consistent presentation of the underlying operating performance of the Group's ongoing business. The Group believes these APMs provide additional useful information by adjusting for exceptional items and certain remeasurements which impact upon IFRS measures or, by defining new measures, to aid the understanding of the Group's financial performance, financial position and cash flows.

Business performance net profit attributable to EnQuest PLC shareholders

Period ended

30 June

2020

$'000

Period ended

30 June

2019

$'000

Reported net profit/(loss) (A)

(619,008)

44,292

Adjustments - remeasurements and exceptional items (note 4):

 

 

Unrealised gains/(losses) on oil derivative contracts (note 5)

(11,278)

(42,859)

Unrealised (gains)/losses on foreign exchange derivative contracts

(3,039)

(2,012)

Unrealised (gains)/losses on carbon derivative contracts

-

(2,062)

Net impairment (charge)/reversal to oil and gas assets (note 8)

(409,800)

(3,186)

Redundancy provision (note 17)

(6,162)

-

Unwind of contingent consideration (note 16)

(39,733)

(28,088)

Change in contingent consideration (note 16)

161,908

(26,900)

KUFPEC provision (note 17)

-

(15,630)

Write down of receivable

-

1,203

Exploration and evaluation expenses: Written off and impaired

-

(519)

Other exceptional items

-

29

Pre-tax remeasurements and exceptional items (B)

(308,104)

(120,024)

Tax on remeasurements and exceptional items (C)

(317,120)

41,746

Post-tax remeasurements and exceptional items (D = B + C)

(625,224)

(78,278)

Business performance net profit attributable to EnQuest PLC shareholders (A - D)

6,216

122,570

 

 

EBITDA

Period ended

30 June

2020

$'000

Period ended

30 June

2019

$'000

Reported profit/(loss) from operations before tax and finance income/(costs)

(243,765)

172,561

Adjustments:

 

 

Pre-tax remeasurements and exceptional items

268,371

91,936

Depletion and depreciation (note 8)

252,325

255,443

Inventory revaluation

18,959

5,679

Net foreign exchange (gain)/loss

(20,971)

308

Business performance EBITDA (E)

274,919

525,927

 

 

EBITDA is calculated on a 'Business performance' basis, and is calculated by taking profit/(loss) from operations before tax and finance income/(costs) and adding back depletion, depreciation, foreign exchange movements, inventory revaluation and the realised gain/(loss) on foreign currency and derivatives related to capital expenditure.

 

 

Glossary - Non-GAAP measures (continued)

 

Total cash and available facilities

Period ended

30 June

2020

$'000

Year ended

31 December

2019

$'000

Available cash

94,076

144,214

Ring-fenced cash

87,724

73,985

Restricted cash

1,574

2,257

Total cash and cash equivalents (F)

183,374

220,456

 

 

 

Available credit facilities

513,900

535,000

a.  RCF- Tranche A

425,000

460,000

b.  RCF- Tranche B

75,000

75,000

c.  Trade creditor facility

13,900

-

Credit facility - Drawn down (appendix)

(425,000)

(460,000)

Letter of credit

(2,754)

(6,849)

Available undrawn facility (G)

 86,146

68,151

Total cash and available facilities (F + G)

269,520

288,607

 

 

Net debt

Period ended

30 June

2020

$'000

Year ended

31 December

2019

$'000

Borrowings (note 12):

 

 

Credit facility - Drawn down

425,000

460,000

Credit facility - PIK

15,792

15,097

Sculptor Capital facility

88,780

120,287

SVT working capital facility

11,245

31,899

Tanjong Baram project financing facility

-

31,730

Borrowings (H)

540,817

659,013

Bonds (note 13):

 

 

High yield bond

 768,681

741,573

Retail bond

 218,344

224,658

Bonds (I)

 987,025

966,231

Non-cash accounting adjustments:

 

 

Unamortised fees on loans and borrowings

2,275

2,625

Unamortised fees on bonds

4,334

5,572

Non-cash accounting adjustments (J)

6,609

8,197

Debt (H + I + J) (K)

1,534,451

1,633,441

Less: Cash and cash equivalents (F)

183,374

220,456

Net debt/(cash) (K - F) (L)

1,351,077

1,412,985

 

 

 

Glossary - Non-GAAP measures (continued)

Net debt/EBITDA

Period ended

30 June

2020

$'000

Year ended

31 December

2019

$'000

Net debt (L)

1,351,077

1,412,985

12-month Business performance EBITDA (E)

739,472

1,006,535

Net debt/EBITDA (L/E)

1.8

1.4

 

 

Cash capex

Period ended

30 June

2020

$'000

Period ended

30 June

2019

$'000

Reported net cash flows from/(used in) investing activities

(104,691)

(124,093)

Adjustments:

 

 

Net cash received on termination of Tanjong Baram risk service contract

(17,086)

-

Payment of Magnus contingent consideration - Profit share

21,088

-

Interest received

(696)

(472)

Cash Capex

(101,385)

(124,565)

 

 

Free cash flow

Period ended

30 June

2020

$'000

Period ended

30 June

2019

$'000

Net cash flows from/(used in) operating activities

275,104

 408,995

Net cash flows from/(used in) investing activities

(104,691)

(124,093)

Net cash flows from/(used in) financing activities

(201,838)

(347,238)

Adjustments:

 

 

Repayment of loans and borrowings

118,906

200,675

Free cash flow

87,481

 138,339

 

Free cash flow is the net change in cash and cash equivalents less net (repayments)/proceeds from loan facilities

 

 

 

Revenue sales

Period ended

30 June

2020

$'000

Period ended

30 June

2019

$'000

Revenue from crude oil sales (note 5) (M)

375,518

 761,850

Revenue from gas and condensate sales (note 5) (N)

27,574

 79,941

Realised (losses)/gains on oil derivative contracts (note 5) (P)

35,229

3,345

Total revenue

438,321

845,136

 

 

 

 

Glossary - Non-GAAP measures (continued)

Barrels equivalent sales

Period ended

30 June

2020

kboe

Period ended

30 June

2019

kboe

Sales of crude oil (Q)

9,417

11,645

Sales of gas and condensate

1,923

2,302

Total sales (R)

11,340

13,947

 

Average realised prices

Period ended

30 June

2020

$/Boe

Period ended

30 June

2019

$/Boe

Average realised oil price, excluding hedging (M/Q)

 39.9

65.4

Average realised oil price, including hedging ((M + P)/Q)

 43.6

66.1

Average realised blended price, excluding hedging ((M + N)/R)

 35.5

 60.4

Average realised blended price, including hedging ((M + N + P)/R)

 38.7

 60.9

 

 

Operating costs

Period ended

30 June

2020

$'000

Period ended

30 June

2019

$'000

Reported cost of sales

420,071

592,415

Adjustments:

 

 

Pre-tax remeasurements and exceptional items

(9,201)

(4,098)

Depletion of oil and gas assets

(248,384)

(250,366)

(Credit)/charge relating to the Group's lifting position and inventory

48,535

(29,438)

Other cost of sales

(36,755)

(60,077)

Operating costs

174,266

248,436

Realised (gain)/loss on derivative contracts

(528)

964

Operating costs directly attributable to production

173,738

249,400

Comprising of:

 

 

Production costs (S)

137,650

 210,200

Tariff and transportation expenses (T)

36,088

 39,200

Operating costs directly attributable to production

173,738

249,400

 

 

 

Barrels equivalent produced

Period ended

30 June

2020

kboe

Period ended

30 June

2019

kboe

Total produced (working interest) (U)

12,022

12,407

 

Unit opex

Period ended

30 June

2020

$/Boe

Period ended

30 June

2019

$/Boe

Production costs (S/U)

 11.4

 16.9

Tariff and transportation expenses (T/U)

 3.0

 3.2

Total unit opex ((S + T)/U)

 14.4

 20.1

 

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