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Hurricane Energy PLC (HUR)

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Thursday 20 September, 2018

Hurricane Energy PLC

Half-year Results 2018

RNS Number : 3244B
Hurricane Energy PLC
20 September 2018
 

20 September 2018

Hurricane Energy plc

("Hurricane", the "Company", or the "Group")

Half-year Results 2018

 

Hurricane Energy plc, the UK based oil and gas company focused on hydrocarbon resources in naturally fractured basement reservoirs, is pleased to provide its 2018 interim report and half-year results for the period ended 30 June 2018.

 

 

Dr Robert Trice, Chief Executive of Hurricane, commented:

"During the first half of 2018, Hurricane has been focussed on the Lancaster Early Production System (EPS) development. I am delighted to report that operations have progressed to plan and within budget, allowing us to reiterate our first oil guidance of H1 2019.

The two production wells have been completed, the turret mooring system (TMS), subsea umbilical, risers and flowlines (SURF) have been installed at the field, and the upgrade and life extension of the Aoka Mizu FPSO is in its final stages in Dubai. Sea trials for the Aoka Mizu are due to commence by the end of September, with sailaway to follow shortly thereafter.

At 30 June 2018, the Company had $210.1 million in cash and liquid investments, of which $178.6 million was unrestricted. With the well completion, TMS installation and SURF installation phases complete, we remain confident in becoming cash generative based on existing funds. I'd like to acknowledge the outstanding contributions of all our staff and contractors, and our Tier 1 contractors: Bluewater Energy Services, TechnipFMC, Petrofac and Transocean, in delivering the operational progress that has allowed us to reach this position.

As we noted in our 2017 Annual Report, the task in front of us is to de-risk and monetise the substantial contingent and prospective resources across all of our assets. The recently announced farm-in by Spirit Energy (post period-end) to the Greater Warwick Area (GWA) is a first step on this path. The transaction accelerates the appraisal and initial development of the GWA and frees up cash flow from the Lancaster EPS to further appraise and develop the Greater Lancaster Area (GLA) and Whirlwind. We are delighted to have agreed a development strategy with a like-minded company which brings significant operating and financial capacity, together with experience in fractured basement reservoirs.

Following this transaction, Hurricane's outlook for 2019 now includes three GWA wells in addition to first oil in H1 from the Lancaster EPS. The next steps on the GLA remain subject to data obtained from the EPS. However, we believe that we will be able to undertake a drilling campaign on the GLA in 2020/21, ahead of planning for further development. We are entering a very exciting time for the Company and its shareholders. I look forward to first revenues and continued appraisal and development of our significant Rona Ridge resource base next year."

 

 

2018 Interim results summary

Financial results

·      The Group's loss after tax for the first half of 2018 was $75.1 million (H1 2017: $4.2 million), including a non-cash fair value loss on the embedded derivative element of the convertible bond of $70.2 million

·      Operating expenses for the period were $4.7 million (H1 2017: $6.0 million)

·      As at 30 June 2018, the Group had cash, cash equivalents and liquid investments of $210.1 million (31 December 2017: $360.1 million). This includes $39.0 million of liquid investments held in term deposits which mature within 12 months and $31.5 million held in escrow accounts

·      The net decrease in cash, cash equivalents and liquid investments in the period was $149.9 million (including the effects of foreign exchange rate changes), the majority of which was related to investment in the ongoing development of the Lancaster EPS, with net cash outflow from operating activities of $2.7 million

Operational and corporate developments/outlook

·      Lancaster EPS first oil guidance maintained at H1 2019

·      Significant Lancaster EPS development hurdles achieved, including:

Delivery of TMS and SURF

Completion of the two production wells

Conclusion of the offshore installation programme which included installation of TMS and SURF

Final stages of Aoka Mizu life extension and upgrade works reached in Dubai, with sea trials to commence by the end of September and sailaway anticipated shortly thereafter

·      Spirit Energy farm-in to GWA completed

Agreed five-phase work programme targeting development with 500 million barrels of reserves, significantly accelerating development of the GWA

Up to $387 million in carry

Hurricane fully carried on first phase of up to $180.6 million, including the drilling of three wells on the GWA in 2019

·      Transocean Leader rig contracted for the three 2019 GWA wells, to begin in Q1

 

Contacts: 

Hurricane Energy plc

Dr Robert Trice (Chief Executive Officer) / Alistair Stobie (Chief Financial Officer)

 

+44 (0)1483 862 820

Stifel Nicolaus Europe Limited

Nominated Adviser and Joint Corporate Broker

Callum Stewart / Nicholas Rhodes / Ashton Clanfield

 

+44 (0)20 7710 7600

Morgan Stanley & Co. International plc

Joint Corporate Broker

Andrew Foster / Tom Perry / Alex Smart

 

+44 (0)20 7425 8000

Vigo Communications

Public Relations

Patrick d'Ancona / Ben Simons

 

+44 (0)20 7390 0230

[email protected]

About Hurricane

 

Hurricane was established to discover, appraise and develop hydrocarbon resources associated with naturally fractured basement reservoirs. The Company's acreage is concentrated on the Rona Ridge, in the West of Shetland region of the UK Continental Shelf.

 

The Lancaster field (100%) is Hurricane's most appraised asset, with five wells drilled by the Company to date. It has 2P reserves and 2C contingent resources of 523 million stock tank barrels of oil. The Company is currently proceeding towards the first phase of development of Lancaster, an Early Production System which will be the UK's first basement field development. It involves a two well tie-back to the Aoka Mizu FPSO and is expected to initially produce 17,000 barrels of oil per day. First oil is targeted for 1H 2019.

 

Hurricane's other assets include Lincoln (50%), Warwick (50%), Halifax (100%), Whirlwind (100%), and Strathmore (100%). Together with Lancaster, these assets have total combined 2P reserves and 2C contingent resources of 2.6 billion barrels of oil equivalent (2.3 billion barrels of oil equivalent net to Hurricane).

 

In September 2018, Spirit Energy farmed-in to 50% of the Lincoln and Warwick assets, committing to a five-phase work programme targeting sanction of full field development in 2021.

Inside Information

 

This announcement contains inside information as stipulated under the market abuse regulation (EU no. 596/2014). Upon the publication of this announcement via regulatory information service this inside information is now considered to be in the public domain.

Competent Person

The technical information in this release has been reviewed by Dr Robert Trice, who is a qualified person for the purposes of the AIM Guidance Note for Mining, Oil and Gas Companies.  Dr Robert Trice, Chief Executive Officer of Hurricane Energy plc, is a geologist and geoscientist with a PhD in geology and has over 30 years' experience in the oil and gas industry. 

Standard

Resource estimates contained in this announcement have been prepared in accordance with the Petroleum Resource Management System guidelines endorsed by the Society of Petroleum Engineers, World Petroleum Congress, American Association of Petroleum Geologists and Society of Petroleum Evaluation Engineers.

 

 

Chief Executive Officer's Review

Lancaster EPS

The first half of the year was principally marked by significant construction and fabrication activities on the Aoka Mizu FPSO, and on the TMS and SURF for the Lancaster EPS development.

The offshore installation phase of the development was kicked-off with the successful installation of the Xmas trees by the Far Superior construction vessel in Q2. This was followed shortly thereafter by the completions of the Lancaster 6 and 7Z wells by Transocean's Paul B Loyd Jr semi-submersible rig.

The Company had highlighted the construction and delivery of the TMS buoy as being a key gating item to delivery of first oil in H1 2019. The TMS was successfully installed in early August and the SURF installation completed in mid-September. The offshore installation programme has therefore now been completed and the system is ready for the arrival of the Aoka Mizu.

At the date of this report, the Aoka Mizu is expected to commence sea trials by the end of September with sailaway anticipated to follow shortly thereafter.

Spirit Energy farm-in

On 3 September 2018, Hurricane announced that Spirit Energy had farmed-in to the GWA. The farm-in has been structured to target significant reserve growth, with the partners agreeing a five-phase work programme which targets a development of 500 million barrels of reserves (gross) as the fifth phase. Following the drilling of three exploration and appraisal wells, one is planned to be tied-back to the Aoka Mizu. As with the Lancaster EPS, this will enable collection of long-term reservoir data to be used in planning for the initial stage of a full field development. One set of facilities will be used to de-risk two accumulations in parallel. The additional well will also be a source of reserves and cash flow - the Company intends to make the most of these benefits, subject to regulatory consents, by maximising production within the constraints of the vessel's capacity and prudent reservoir management.

The GWA farm-in significantly accelerates the development of the GWA, providing a clear path to its phased development and bringing forward a potential initial stage of a full field development final investment decision (FID) by a number of years. Notwithstanding the significant cash flow that the Lancaster EPS will deliver, Hurricane would not have otherwise been able to undertake such a development on a standalone basis, without impacting its ability to continue progressing its GLA licences. The GWA farm-in provides Hurricane with a new leg to its business, with a large portion of the up-front capital expenditure funded, whilst freeing up cash flow from the Lancaster EPS for appraisal and development of the rest of its portfolio.

Spirit Energy will fund 100% (up to a maximum of $180.6 million) of a three well 2019 drilling programme, together with certain engineering work and long lead items for future phases, in exchange for a 50% interest across the licences covering the GWA. Subsequently, one of these GWA wells is planned to be tied-back to the Aoka Mizu. Following FID, Spirit Energy will pay 75% (up to a maximum of $140.7 million) of the anticipated gross cost of the tie back and of the required modifications to the vessel, necessary to allow for this additional production.

Hurricane and Spirit Energy also target drilling three additional wells to further appraise the accumulation and to undertake front end engineering and design (FEED) prior to sanctioning the first phase of a standalone GWA full field development in 2021. Spirit Energy has undertaken to make a contingent contribution of a further $150 - $250 million in carry at this stage, dependent on the reserves included in the FID for the initial stage of full field development. Hurricane will remain field operator until commencement of the full field development workstreams (including FEED), at which point operatorship will transfer to Spirit Energy, subject to regulatory approval.

Other corporate developments

In 2017, Hurricane's board undertook to progress its board composition and governance towards compliance with the Financial Reporting Council's UK Corporate Governance Code (the Code), a standard not required of AIM-quoted companies. A significantly expanded annual report was published for the year ended 2017 and Steven McTiernan was appointed as Chairman of the board, effective from 1 May 2018.

The board continues to review its composition, noting the recent changes to corporate governance guidelines (including a new Code) which will be in force for accounting periods commencing from 1 January 2019. The board also continues to review the appropriateness of a listing on the premium segment of a recognised stock exchange (Premium Listing). In this regard, Morgan Stanley was appointed as co-Corporate Broker alongside Stifel and will be working with the Company as the board weighs up the costs, benefits and appropriate timing of a Premium Listing.

 

Dr Robert Trice

Chief Executive Officer

19 September 2018

 

 

Financial Review

During the first half of the year, the focus has remained on the Lancaster EPS development and the initial stages of offshore installation with capital expenditure continuing in line with forecasts and budget. Expenditure on the EPS in the first six months of 2018 was $136.4 million, all of which came from funds already held at the beginning of the year.

Use of funds

In H1 2018 the Group's primary use of funds were:

i)             Development expenditure on the EPS of $136.4 million

ii)            Intangible exploration expenditure of $2.0 million, including licence costs on the Group's exploration licences

iii)           Operating cash outflow of $2.7 million

iv)           Convertible bond coupon payments of $8.6 million

Income statement

The Group recorded a loss after tax for the first half of 2018 of $75.1 million (H1 2017: $4.2 million). This loss includes a non-cash fair value loss on the embedded derivative element of the convertible bond of $70.2 million. This is discussed in more detail below. Excluding the fair value loss, the loss for the period was $4.9 million. The majority of the loss relates to operating expenses of $4.7 million (H1 2017: $6.0 million); the foreign exchange losses in the period of $2.1 million were almost completely offset by the interest income received.

Whilst the movement in the foreign exchange rate between the US Dollar and Sterling resulted in the foreign exchange loss in the period, at the time of the July 2017 fund raise the Group matched the currency it held to its forecast currency expenditure. As such, whilst foreign exchange rates have fluctuated, the Group's ability to deliver planned operations has not been affected and the Group continues to hold sufficient cash in each currency that it forecasts using for the Lancaster EPS development.

Due to the nature of the Group's business, it has accumulated significant tax losses since incorporation. The Group has trading losses of $431.3 million at 30 June 2018, which have no expiry date and would be available for offset against future trading profits (though a deferred tax asset has not been recognised beyond offsetting existing deferred tax liabilities). A potential Ring Fence Expenditure Supplement claim could also be made which would result in additional trading losses of $111.7 million. The Group's tax loss position was not impacted by the GWA farm-in.

The Group had pre-trading expenditure of $84.3 million which was carried forward at 30 June 2018. Tax relief will be available on this amount as the Group's remaining licences reach the development stage.

Cash flow

As at 30 June 2018, the Group had an unrestricted cash position (including cash and cash equivalents and liquid investments, but excluding cash held in escrow accounts) of $178.6 million (31 December 2017: $326.6 million). The net decrease in cash, cash equivalents and liquid investments in the period was $149.9 million (including the effects of foreign exchange rate changes). The majority of the reduction in the period related to expenditure on the EPS. Net cash outflow from operating activities of $2.7 million was lower than the $4.7 million for the first half of 2017 (excluding H1 2017 tax receipts of $5.9 million). This was due to the decrease in the level of corporate activity as the Group focused on the EPS.

Convertible bond accounting

The accounting for the convertible bond (issued in July 2017) required the recognition of an embedded derivative liability related to the equity conversion option. The fair value of the embedded derivative is based on a simulation model which is impacted, in particular, by the volatility assumption applied and the Group's share price at the reporting date. The higher the assumed volatility and the higher the Group's share price, the more the fair value of the derivative liability increases. Any increase in the liability creates a corresponding non-cash charge in the income statement.

At 31 December 2017, the fair value of the embedded derivative liability was valued at $28.6 million. Between 31 December 2017 and 30 June 2018, Hurricane's share price rose from £0.32 to £0.475 per ordinary share, and the volatility assumption increased from 23.6% to 30.1%. The volatility assumption was calculated as a blended average of the trading history of the Group's own shares and shares in a relevant peer group, for a period of six months prior to the measurement date. It is assumed that this is an approximate forecast of the volatility in Hurricane's share price for the period to conversion. These movements have driven an increase in the derivative liability of $70.2 million, to a closing figure at 30 June 2018 of $98.8 million. Further share price rises would increase the liability and corresponding related losses, assuming other factors remain the same, as outlined further in note 14.

The losses recognised do not have any impact on the Group's cash position, amounts payable in respect of the convertible bond, or on its tax position. On either the conversion of the bond or the repayment of the bond the recognised derivative liability will be released.

Principal risks

There are a number of potential risks and uncertainties which could have a material impact on the Group's performance over the remaining six months of 2018 and could cause actual results to differ materially from expected and historical results. The principal risks and uncertainties, along with the mitigation measures in place to reduce risks to acceptable levels, remain unchanged from those published on pages 18-21 of the 2017 Annual Report and Accounts (summarised below) except for one addition, discussed below.

Key risk factor

Risk summary

Substantial capital requirements

The Group's business plan to exploit and commercialise its assets requires significant capital expenditure. Future plans may be curtailed if the Group is unable to generate sufficient funds from operational cashflow and/or raise further funds.

Exploration, appraisal and development operational risks

There are a range of operational risks during offshore operations whether for exploration, appraisal or development. These include, but are not limited to, failure of offshore vessels/rigs or other crucial equipment, unforeseen problems occurring during drilling or completion works, and delays to offshore operations due to unfavourable weather.

Production operational risks

There are many production-related operational risks. These mainly relate to, but are not limited to, the risk of unplanned downtime of production facilities. This may be the result of mechanical issues, unfavourable weather leading to delays in operations, and/or other issues.

Geological and reservoir risk

The geology of the Group's licence areas and the behaviour of the associated reservoirs rely on various assumptions and interpretation techniques. There is a risk that the reservoirs do not behave as expected, such as earlier water production than predicted, reserves/resources being less than expected, or oil having different properties than expected.

Regulatory

There is a risk that the Group and/or its primary contractors are in breach of their regulatory obligations with one of their principal regulators in connection with the Group's activities. This could restrict the Group and/or its primary contractors' capacity to obtain permits and to carry out the Group's activities on the UK Continental Shelf. There is also a risk that a change in the regulatory environment affects the returns expected to be achieved from the Group's assets.

Oil price fluctuations

Declines in oil prices may adversely affect the cashflows generated from the EPS and may also affect market sentiment and consequently, the market price of the Company's Ordinary Shares and the ability of the Group to raise finance.

Third party infrastructure

Any field development, including gas export, is likely to be dependent upon the availability of third party infrastructure. If this fails, or is not available on reasonable commercial terms, it may result in delays to field development, production and cash generation. This would have a material adverse effect on the Group's business, prospects, financial condition and operations.

Development project delivery

Development projects are subject to various risks including availability of third party services and manufacturing slots, solvency of major contractors, correct fabrication of key components to specification, incident-free installation operations, installation windows, permits, consents and weather. Problems with any of the above can cause project delays that would impact both the timing for completion of the project, as well as the cost.

Health, Safety and Environmental (HSE)

In performing offshore exploration, development or production activities and onshore fabrication activities there is a risk of harm to the workforce, to the environment (e.g. from fabrication processes, hydrocarbon releases and/or oil spills, damage to seabed ecosystems or disturbance to marine mammal populations from noise pollution), to the assets during construction or in use, and to the Company's reputation as a result of some or all of the above.

Compliance

There is a risk of a major breach of the Group's business or ethical conduct standards due to unethical behaviour or breaches of anti-corruption laws by the Group or its contractors, resulting in investigations, fines, loss of reputation and loss of assets.

 

Further information on the above principal risks and uncertainties facing the Group is included in the Strategic Report of the 2017 Annual Report and Accounts. Also included in that report is the manner in which the Group seeks to mitigate each of these principal risks.

The only addition to these risks is, following the farm-out of 50% of the Lincoln and Warwick licences to Spirit Energy (discussed in more detail above), the inclusion of the following:

Key risk factor

Risk detail

How is it managed?

Joint venture partners

Operations in the oil and gas industry are often conducted in a joint venture environment. There is a risk that joint venture partners are not aligned in their objectives and drivers, which may lead to inefficiencies and delays.

Following farm-out transactions, the Group may not always act as operator on certain licence interests. The Group will generally have limited control over the day to day management of operations of those assets and will therefore be dependent upon a third-party operator.

Due diligence will be used to review and assess any third parties that the Group enters into a joint venture with in both operated and non-operated projects. The Group will have continuous and regular engagement with partners to ensure that all partners' interests are aligned, and the Group is not exposed to risks that it believes are unacceptable.

 

Related party transactions

There have been no new material related party transactions in the period and there have been no material changes to the related party transactions described in Note 27 to the Consolidated Financial Statements contained in the 2017 Annual Report and Accounts.

Going concern

At the time of preparation of these Interim Financial Statements, the directors have a reasonable expectation that the Group has adequate resources to continue to operate and meet its liabilities as they fall due for the foreseeable future, a period considered to be at least twelve months from the date of signing these Financial Statements. For this reason, they continue to adopt the Going Concern Basis for preparing the Interim Financial Statements. Further details are described in Note 3 in these financial statements.

Independent Review Report

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 2018 which comprises the condensed consolidated statement of comprehensive income, the condensed consolidated balance sheet, the condensed consolidated statement of changes in equity, the condensed consolidated cash flow statement and related notes 1 to 17. 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.

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.

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 AIM Rules of the London Stock Exchange.

As disclosed in note 1, 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 have 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 inquiries, 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 2018 is not prepared, in all material respects, in accordance with International Accounting Standard 34 "Interim Financial Reporting" as adopted by the European Union and the AIM Rules of the London Stock Exchange.

 

Deloitte LLP

Statutory Auditor

London, UK

19 September 2018

Condensed Consolidated Statement of Comprehensive Income

For the 6 months ended 30 June 2018

 

 

 

6 months ended

 

6 months ended

 

12 months ended

 

Notes

 

30 Jun 2018

 

30 Jun 2017

 

31 Dec 2017

 

 

 

 

 

 

 

 

 

 

 

(Unaudited)

 

(Unaudited)

 

(Audited)

 

 

 

$'000

 

$'000

 

$'000

 

 

 

 

 

 

 

 

Write off / impairment of intangible exploration and evaluation assets

 

 

-

 

-

 

(10,412)

Other operating expenses

 

 

(4,714)

 

(5,989)

 

(14,586)

Operating loss

 

 

(4,714)

 

(5,989)

 

(24,998)

Interest income

 

 

1,911

 

66

 

880

Foreign exchange (loss) / gain

4

 

(2,056)

 

1,734

 

8,020

Finance costs

 

 

(57)

 

(37)

 

(1,322)

Fair value (loss) / gain on derivative financial instruments

10

 

(70,167)

 

-

 

10,416

Loss before tax

 

 

(75,083)

 

(4,226)

 

(7,004)

Tax

5

 

-

 

-

 

-

Total comprehensive loss for the period

 

 

(75,083)

 

(4,226)

 

(7,004)

 

 

 

 

 

 

 

 

Loss per share, basic and diluted

6

 

(3.83 cents)

 

(0.35 cents)

 

(0.46 cents)

 

 

 

 

 

 

 

 

 

All of the Group's operations are classed as continuing.

Condensed Consolidated Balance Sheet

As at June 2018

 

Notes

 

30 Jun 2018

 

30 Jun 2017

 

31 Dec 2017

 

 

 

(Unaudited)

 

(Unaudited)

 

(Audited)

 

 

 

$'000

 

$'000

 

$'000

Non-current assets

 

 

 

 

 

 

 

Property, plant and equipment

7

 

633,276

 

18

 

445,291

Intangible exploration and evaluation assets

8

 

127,720

 

373,493

 

126,365

Other receivables

 

 

198

 

170

 

202

Other non-current assets

 

 

7,397

 

3,034

 

16,089

 

 

 

768,591

 

376,715

 

587,947

Current assets

 

 

 

 

 

 

 

Inventory

 

 

1,434

 

1,434

 

1,434

Trade and other receivables

 

 

5,589

 

3,611

 

4,737

Liquid investments

 

 

39,040

 

-

 

201,973

Cash and cash equivalents

 

 

163,694

 

29,090

 

141,956

 

 

 

209,757

 

34,135

 

350,100

Total assets

 

 

978,348

 

410,850

 

938,047

Current liabilities

 

 

 

 

 

 

 

Trade and other payables

9

 

(51,484)

 

(10,202)

 

(28,833)

Derivative financial instruments

 

 

(27)

 

-

 

(11)

 

 

 

(51,511)

 

(10,202)

 

(28,844)

Non-current liabilities

 

 

 

 

 

 

 

Convertible loan liability

10

 

(194,517)

 

-

 

(191,102)

Derivative financial instruments

10

 

(98,772)

 

-

 

(28,622)

Decommissioning provisions

11

 

(23,693)

 

(6,975)

 

(7,023)

Total liabilities

 

 

(368,493)

 

(17,177)

 

(255,591)

Net assets

 

 

609,855

 

393,673

 

682,456

Equity

 

 

 

 

 

 

 

Share capital

12

 

2,843

 

1,892

 

2,843

Share premium

 

 

813,681

 

524,459

 

813,496

Share option reserve

 

 

21,840

 

17,932

 

19,477

Own shares held by SIP Trust

 

 

(389)

 

(351)

 

(323)

Foreign exchange reserve

 

 

(92,659)

 

(92,659)

 

(92,659)

Accumulated deficit

 

 

(135,461)

 

(57,600)

 

(60,378)

Total equity

 

 

609,855

 

393,673

 

682,456

 

Condensed Consolidated Statement of Changes in Equity

For the 6 months ended 30 June 2018

 

Share

capital

 

Share

premium

 

Share

option reserve

 

Own shares held

by SIP Trust

 

Foreign exchange reserve

 

Accumulated

deficit

 

Total

 

$'000

 

$'000

 

$'000

 

$'000

 

$'000

 

$'000

 

$'000

 

 

 

 

 

 

 

 

 

 

 

 

 

 

At 1 January 2017

(Audited)

1,860

 

508,510

 

15,648

 

(366)

 

(92,659)

 

(53,374)

 

379,619

Shares allotted

32

 

15,949

 

-

 

-

 

-

 

-

 

15,981

Share options charge

-

 

-

 

2,284

 

-

 

-

 

-

 

2,284

Own shares held by SIP Trust

-

 

-

 

-

 

15

 

-

 

-

 

15

Loss for the period

-

 

-

 

-

 

-

 

-

 

(4,226)

 

(4,226)

At 30 June 2017

(Unaudited)

1,892

 

524,459

 

17,932

 

(351)

 

(92,659)

 

(57,600)

 

393,673

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Shares allotted

951

 

303,924

 

-

 

-

 

-

 

-

 

304,875

Transaction costs

-

 

(14,887)

 

-

 

-

 

-

 

-

 

(14,887)

Share options charge

-

 

-

 

1,545

 

-

 

-

 

-

 

1,545

Own shares held by SIP Trust

-

 

-

 

-

 

28

 

-

 

-

 

28

Loss for the period

-

 

-

 

-

 

-

 

-

 

(2,778)

 

(2,778)

At 31 December 2017

(Audited)

2,843

 

813,496

 

19,477

 

(323)

 

(92,659)

 

(60,378)

 

682,456

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Shares allotted

-

 

185

 

-

 

-

 

-

 

-

 

185

Share option charge

-

 

-

 

2,363

 

-

 

-

 

-

 

2,363

Own shares held by SIP Trust

-

 

-

 

-

 

(66)

 

-

 

-

 

(66)

Loss for the period

-

 

-

 

-

 

-

 

-

 

(75,083)

 

(75,083)

At 30 June 2018 (Unaudited)

2,843

 

813,681

 

21,840

 

(389)

 

(92,659)

 

(135,461)

 

609,855

 

The share option reserve arises as a result of the expense recognised in the income statement to account for the cost of share-based employee compensation arrangements.

Condensed Consolidated Cash Flow Statement

For the 6 months ended 30 June 2018

 

 

 

6 months ended

 

6 months ended

 

12 months ended

 

Notes

 

 

30 Jun 2017

 

 

 

 

(Unaudited)

 

(Unaudited)

 

(Audited)

 

 

 

$'000

 

$'000

 

$'000

 

 

 

 

 

 

 

 

Net cash (outflow) / inflow from operating activities

13

 

(2,733)

 

1,124

 

(8,088)

Investing activities

 

 

 

 

 

 

 

Interest received

 

 

1,911

 

51

 

885

Decrease / (increase) in liquid investments1

 

 

162,933

 

-

 

(201,973)

Expenditure on property, plant and equipment

 

 

(136,382)

 

(8)

 

(85,062)

Expenditure on intangible exploration and evaluation assets

 

 

(2,043)

 

(87,196)

 

(180,612)

Expenditure on inventory

 

 

-

 

(991)

 

(991)

Net cash provided by (used in) investing activities

 

 

26,419

 

(88,144)

 

(467,753)

Financing activities

 

 

 

 

 

 

 

Bank charges

 

 

(8)

 

(3)

 

(15)

Net proceeds from borrowing2

 

 

-

 

-

 

223,095

Additional borrowing transaction costs2

 

 

-

 

-

 

(303)

Interest payments (Convertible Bonds)

 

 

(8,625)

 

-

 

(4,313)

Proceeds from issue of share capital and warrants

 

 

49

 

15,931

 

313,895

Additional equity issue transaction costs

 

 

-

 

-

 

(7,976)

Net cash (used in) / provided by financing activities

 

 

(8,584)

 

15,928

 

524,383

Net increase / (decrease) in cash and cash equivalents

 

 

15,102

 

(71,092)

 

48,542

Cash and cash equivalents at the beginning of the period4

 

 

158,045

 

101,482

 

101,482

Net increase /(decrease) in cash and cash equivalents

 

 

15,102

 

(71,092)

 

48,542

Effects of foreign exchange rate changes

 

 

(2,057)

 

1,734

 

8,021

Cash and cash equivalents at the end of the period4

 

 

171,091

 

32,124

 

158,045

 

1 Liquid investments comprise short-term liquid investments of between 3 and 12 months maturity while cash and cash equivalents comprise cash at bank and other short term highly liquid investments of less than three months maturity. The combined cash and cash equivalents and liquid investments balance at 30 June 2018 was $210,131,000 (30 June 2017: $32,124,000; 31 December 2017: $360,018,000).

 

2 Total transaction costs relating to borrowings were $nil (6 months ended 30 June 2017: $nil; 12 months ended 31 December 2017: $7,208,000 of which $6,905,000 were netted off against gross proceeds of $230,000,000).

 

3 Total transaction costs relating to equity raises were $nil (6 months ended 30 June 2017: $715,000 all of which was netted off against gross proceeds of $15,931,000;12 months ended 31 December 2017: $14,887,000 of which $6,911,000 were netted off against gross proceeds of $320,806,000)

 

4 Cash and cash equivalents includes $7,397,000 (30 June 2017: $3,034,000; 31 December 2017: $16,089,000) of cash held in escrow which has been included in the balance sheet in other non-current assets, and $24,102,000 (30 June 2017: $nil; 31 December 2017: $17,327,000) of cash held in escrow which has been included in the balance sheet in cash and cash equivalents.

1.         General information

Hurricane Energy plc is a public company, limited by shares, incorporated in the United Kingdom and registered in England and Wales under the Companies Act 2006 (registered company number 05245689). The nature of the Group's operations and its principal activity is exploration for oil and gas reserves principally on the UK Continental Shelf. The address of Hurricane Energy plc's registered office is The Wharf, Abbey Mill Business Park, Lower Eashing, Godalming, Surrey, GU7 2QN. Hurricane Energy plc's shares are listed on the AIM market of the London Stock Exchange.

This Interim Report and Financial Statements was approved by the board of directors of Hurricane and authorised for issue on 19 September 2018.

This set of Interim Financial Statements for the 6 months ended 30 June 2018 is unaudited and does not constitute statutory accounts as defined by the Companies Act. The information for the year ended 31 December 2017 contained within these Interim Financial Statements does not constitute statutory accounts as defined in Section 435 of the Companies Act 2006. The Group Financial Statements for the year ended 31 December 2017 have been delivered to the Registrar of Companies. The auditor's report on those Financial Statements was unqualified, did not draw attention to any matters by way of emphasis and did not contain a statement made under Section 498 of the Companies Act 2006.

2.         Basis of preparation

The annual financial statements of the Group are prepared in accordance with International Financial Reporting Standards as adopted by the European Union (IFRS). The Interim Financial Statements have been prepared using accounting bases and policies consistent with those used in the preparation of the audited Financial Statements of the Group for the year ended 31 December 2017 with the exception of IFRS 9 'Financial Instruments' and IFRS 15 'Revenue from contracts with customers' (see note 2.1) and those to be used for the year ending 31 December 2018.

The Interim Financial Statements have been prepared under the historical cost convention, except for share based payments and certain financial instruments, which have been measured at fair value, and in accordance with the requirements of International Accounting Standard (IAS) 34 'Interim Financial Reporting' as adopted by the European Union and the AIM Rules.

2.1.     International Financial Reporting Standards adopted in the period

In the current period, the following accounting standards became effective and have been adopted:

2.1.1.  IFRS 9 'Financial Instruments'

IFRS 9 has superseded IAS 32 'Financial Instruments: Presentation' and IAS 39 'Financial Instruments: Recognition and Measurement' in its entirety for accounting periods commencing on or after 1 January 2018.

The core areas addressed within IFRS 9 are as follows:

·     Classification and measurement of financial instruments and liabilities

·     Impairment of financial assets

·     Hedge accounting

There have been no material changes in relation to the classification and measurement of financial assets and liabilities, impairment of financial assets or for hedge accounting other than additional annual report disclosure requirements.

2.1.2.  IFRS 15 'Revenue from contracts with customers'

IFRS 15 replaced IAS 18 'Revenue' and IAS 11 'Construction Contracts' for accounting periods commencing on or after 1 January 2018. The core principle of the standard is that an entity will recognise revenue at an amount that reflects the consideration to which the entity expects to be entitled in exchange for transferring promised goods or services to a customer.

The Group performed an impact assessment during the prior year regarding the accounting requirements of IFRS 15. As the Group has not previously had any revenue there has been no impact on adoption of the standard.

2.2.     New and revised standards: International Financial Reporting Standards

2.2.1.  IFRS 16 'Leases'

IFRS 16 'Leases' will replace IAS 17 'Leases' for accounting periods commencing on or after 1 January 2019. For Hurricane Energy plc the effective date is the year commencing 1 January 2019. The core principal of the standard is to provide a single lessee accounting model, requiring lessees to recognise a right-of-use asset and lease liability for all leases unless the term is less than 12 months, or the underlying asset has a low value. IFRS 16's approach to lessor accounting is mostly unchanged from IAS 17.

The transition to IFRS 16 will have a material impact on the balance sheet as all operating leases will need to be recognised on the balance sheet. Furthermore, operating lease expense in the income statement will be replaced with depreciation and interest expense. The Group has performed an initial impact assessment to determine which current leases and which anticipated future leases would be affected by this transition.

The primary objectives of this assessment are to: define accounting policies in compliance with the standard; identify all existing leases within the Group; identify anticipated future leases within the Group; capture the necessary data for each lease, including discount rates; determine a transition approach; and understand and implement necessary system and operational changes.

The Group is currently in the process of developing updated accounting policies and is assessing the information requirements for each lease. The Group currently plans to adopt the cumulative catch-up transition approach. As such, the value of the asset and liability recognised will be determined by the present value of the future lease payments on the existing leases at the date of transition (1 January 2019) and prior year comparatives will not be restated. The Group currently anticipates that the impact at the point of adoption of the standard is likely to be material as it will bring a Right of Use asset and liability for the Aoka Mizu FPSO and office properties onto the balance sheet. Further quantitative information cannot be provided at this time as the Group is continuing with its detailed assessment.

3.         Going concern

The Group's business activities, together with the factors likely to affect its future development, performance and position are set out in the Chief Executive's Report. The financial position of the Group, its cash flows and liquidity position are set out in the Interim Financial Statements.

The Group has no source of operating revenue prior to first oil from the Lancaster EPS (currently anticipated to occur in H1 2019) and currently obtains working capital primarily through equity and debt financing. During 2017, the Group raised gross funds of $547 million (before expenses), split between $317 million from the issue of Ordinary Shares and $230 million from the issue of Convertible Bonds.

The directors have performed a robust assessment, including a review of the budget for the year ending December 2019 and longer-term strategic forecasts and plans, including consideration of the principal risks faced by the Company. In particular, the directors considered a number of sensitivities which included the impact of a delay in first oil from the Lancaster EPS, cost and schedule overruns during the installation period and, following first oil, downside sensitivities in relation to production rates, operational uptime, oil price, opex and foreign exchange rates. Following this review, the directors are satisfied that, taking into consideration reasonably possible downside sensitivities, the Group has adequate resources to continue to operate and meet its liabilities as they fall due for the foreseeable future, a period considered to be at least twelve months from the date of signing these interim financial statements. For this reason, they continue to adopt the Going Concern Basis for preparing the Interim Financial Statements.

4.         Foreign exchange gains and losses

Foreign exchange losses of $2.1 million (6 months ended 30 June 2017: gain of $1.7 million; 12 months ended 31 December 2017: gain of $8.0 million) relate to fluctuations in the US Dollar to Pounds Sterling exchange rate. The Group's cash and cash equivalents are predominately held in US Dollars and Pounds Sterling.

5.         Tax on loss on ordinary activities

 

6 months ended

 

6 months ended

 

12 months ended

 

30 Jun 2018

 

30 Jun 2017

 

31 Dec 2017

 

(Unaudited)

 

(Unaudited)

 

(Audited)

 

$'000

 

$'000

 

$'000

UK corporation tax

 

 

 

 

 

Current tax - current year

-

 

-

 

-

Total current tax

-

 

-

 

-

 

 

 

 

 

 

Deferred tax - current year

-

 

-

 

-

Total deferred tax

-

 

-

 

-

Tax credit per income statement

-

 

-

 

-

 

 

 

 

 

 

Loss on ordinary activities before tax

(75,083)

 

(4,226)

 

(7,004)

Loss on ordinary activities multiplied by standard rate of corporation tax in the UK applicable to oil and gas companies of 40%

(30,033)

 

(1,690)

 

(2,802)

Effects of:

 

 

 

 

 

Expenses not deductible for tax purposes

973

 

940

 

1,576

Effect of changes in tax rates

-

 

-

 

(2,395)

Losses and other temporary differences not recognised

29,060

 

750

 

3,621

Total tax credit for the year

-

 

-

 

-

 

In 2016 the Company made a claim under the SME Research & Development tax relief scheme and has surrendered the resulting losses for a payable tax credit. $0.9 million of the research and development tax credit was received in cash during that year, relating to the 2013 claim. The remaining $5.9 million relating to the 2014 claim was received in February 2017.

5.1.     Factors which may affect future tax charges

The Group has trading losses of $431.3 million at 30 June 2018 (31 December 2017: $393.6 million), which have no expiry date and would be available for offset against future trading profits. A potential Ring Fence Expenditure Supplement claim could also be made which would result in additional trading losses of $111.7 million.

The Group has pre-trading expenditure of $84.3m which is carried forward at 30 June 2018 and tax relief will be available when FDP approval is obtained on the remaining licences.

5.2.     Deferred tax asset / liability

 

6 months ended

 

6 months ended

 

12 months ended

 

30 Jun 2018

 

30 Jun 2017

 

31 Dec 2017

 

(Unaudited)

 

(Unaudited)

 

(Audited)

 

$'000

 

$'000

 

$'000

 

 

 

 

 

 

Accelerated capital allowances

153,149

 

-

 

139,520

Other timing differences

4

 

-

 

4

Fair value movement on derivative

-

 

-

 

1,771

Tax losses carried forward

(153,153)

 

-

 

(141,295)

Deferred tax liability

-

 

-

 

-

 

No asset has been recognised in these Financial Statements for a potential deferred tax asset of $29.5 million (31 December 2017: $16.1 million). The Group's practice is generally not to recognise potential deferred tax assets until such time as it has been demonstrated that the Group will generate taxable profits. No deferred tax asset has yet been recognised due to the inherent uncertainty of success at this stage. The potential deferred tax asset is calculated at a rate of 40% (30 June 2017 and 31 December 2017: 40%).

6.         Loss per share

The basic and diluted loss per share has been calculated using the loss for the period and a weighted average number of Ordinary Shares in issue less treasury shares.

 

 

6 months ended

 

6 months ended

 

12 months ended

 

 

30 Jun 2018

 

30 Jun 2017

 

31 Dec 2017

 

 

(Unaudited)

 

(Unaudited)

 

(Audited)

 

 

$'000

 

$'000

 

$'000

 

 

 

 

 

 

 

Loss after tax

 

(75,083)

 

(4,226)

 

(7,004)

 

 

 

 

 

 

 

 

 

Number of shares

 

Number of shares

 

Number of shares

Weighted average shares in issue (basic and diluted)

 

1,958,438,402

 

1,207,828,832

 

1,583,803,716

 

 

 

 

 

 

 

 

 

Cents

 

Cents

 

Cents

Loss per share (basic and diluted)

 

(3.83)

 

(0.35)

 

(0.46)

The effect of the warrants, options and Convertible Bonds outstanding at the end of each period was anti-dilutive as the Group incurred a loss and all the interest on the Convertible Bond was capitalised.

7.         Property, plant and equipment

 

 

Oil and gas properties

6 months ended

 30 Jun 18

(Unaudited)

$'000

Other fixed assets

6 months ended

30 Jun 18

(Unaudited)

$'000

Total

 

6 months ended

30 Jun 18

(Unaudited)

$'000

 

Oil and gas properties

6 months ended

30 Jun 17

(Unaudited)

$'000

Other fixed assets

6 months ended

30 Jun 17

(Unaudited)

$'000

Total

 

6 months ended

30 Jun 17

(Unaudited)

$'000

 

Oil and gas properties

12 months ended

31 Dec 17

(Audited)

$'000

Other fixed assets

12 months ended

31 Dec 17

(Audited)

$'000

Total

 

12 months ended

31 Dec 17

(Audited)

$'000

Cost

 

 

 

 

 

 

 

 

 

 

 

At 1 January

445,237

1,053

446,290

 

-

995

995

 

-

995

995

Additions

188,004

-

188,004

 

-

8

8

 

109,381

58

109,439

Transfer from intangible assets

-

-

-

 

-

-

-

 

335,856

-

335,856

At 30 June / 31 December

633,241

1,053

634,294

 

-

1,003

1,003

 

445,237

1,053

446,290

 

 

 

 

 

 

 

 

 

 

 

 

Depreciation

 

 

 

 

 

 

 

 

 

 

 

At 1 January

-

(999)

(999)

 

-

(977)

(977)

 

-

(977)

(977)

Charge for the period

-

(19)

(19)

 

-

(8)

(8)

 

-

(22)

(22)

At 30 June / 31 December

-

(1,018)

(1,018)

 

-

(985)

(985)

 

-

(999)

(999)

 

 

 

 

 

 

 

 

 

 

 

 

Carrying amount at 30 June / 31 December

633,241

35

633,276

 

-

18

18

 

445,237

54

445,291

 

 

 

 

 

 

 

 

 

 

 

 

 

Included within additions is $12,041,000 of borrowing costs that have been capitalised in the period (30 June 2017: $nil; 31 December 2017: $10,448,000).

Also included in additions are $16,620,000 (30 June 2017: $nil; 31 December 2017: $nil) relating to the changes in decommissioning estimates on the Lancaster field (note 11).

On 24 September 2017 approval was granted for the Lancaster EPS field development. As a result, $335,856,000 of intangible exploration and evaluation assets were reclassified as oil and gas properties within property, plant and equipment. The oil and gas property balance at 30 June 2018 solely relates to the Lancaster development.

Depreciation of the oil and gas properties will commence once production begins and will be on a unit of production (UOP) basis.

Property, plant and equipment (other fixed assets) comprises the Group's investment in leasehold improvements, fixtures, office equipment and computer hardware.

8.         Intangible exploration and evaluation assets

 

6 months ended

 

6 months ended

 

12 months ended

 

30 Jun 2018

 

30 Jun 2017

 

31 Dec 2017

 

(Unaudited)

 

(Unaudited)

 

(Audited)

 

$'000

 

$'000

 

$'000

 

 

 

 

 

 

At start of period

126,365

 

302,539

 

302,539

Additions

851

 

981

 

169,113

Effects of additions / changes to decommissioning estimates (note 11)

504

 

69,973

 

981

Impairment of intangible exploration and evaluation assets

-

 

-

 

(1,971)

Write off of intangible and evaluation assets

-

 

-

 

(8,441)

Transfer to property, plant and equipment

-

 

-

 

(335,856)

At end of period

127,720

 

373,493

 

126,365

Intangible exploration and evaluation expenditure comprises the book cost of licence interests and exploration and evaluation expenditure within the Group's licensed acreage in the West of Shetlands.

The directors have fully considered and reviewed the potential value of licence interests at 30 June 2018, including carried forward exploration and evaluation expenditure. The directors have considered the Group's tenure to its licence interests, its plans for further exploration and evaluation activities in relation to these and the likely opportunities for realising the value of the Group's licences, either by farm-out or by development of the assets. The directors have concluded that no impairment is necessary at this time.

On 24 September 2017 approval was granted for the Lancaster EPS field development. As a result, $335,856,000 of intangible assets were reclassified as Oil and Gas properties within property, plant and equipment.

In December 2017, the directors fully impaired the intangible exploration and evaluation assets relating to Strathmore, being $1,971,000. On 8 December 2017 the Group relinquished its P1485 and P1834 licences (Typhoon and Tempest). As such, the intangible exploration and evaluation assets relating to those licences of $8,441,000 were fully written off.

9.         Trade and other payables

 

 

 

30 Jun 2018

 

30 Jun 2017

 

31 Dec 2017

 

 

 

(Unaudited)

 

(Unaudited)

 

(Audited)

 

 

 

$'000

 

$'000

 

$'000

 

 

 

 

 

 

 

 

Trade payables

 

 

2,263

 

1,593

 

1,030

Other payables

 

 

166

 

114

 

159

Accruals

 

 

49,055

 

8,495

 

27,644

 

 

 

51,484

 

10,202

 

28,833

 

The accruals at 30 June 2018 includes significant expenditure in relation to the EPS that has not yet been invoiced.

10.       Borrowings

In July 2017 the Group raised $230 million (gross) from the successful placement of Convertible Bonds ("the Bonds"). The Bonds were issued at par and carry a coupon of 7.5% payable quarterly in arrears. The Bonds are convertible into fully paid Ordinary Shares of the Company with the initial conversion price set at $0.52, representing a 25% premium above the placing price of the Concurrent Equity Placement, being £0.32 (converted into US dollars at USD/GBP 1.30). Unless previously converted, redeemed or purchased and cancelled, the Bonds will be redeemed at par on 24 July 2022.

The conversion feature of the Bonds is classified as an embedded derivative liability as it can be settled by the Group in cash and hence does not meet the 'fixed for fixed' criteria for a compound instrument outlined in IFRS 9 (see note 14). It has therefore been measured at fair value through profit and loss. The amount recognised at inception in respect of the host debt contract was determined by deducting the fair value of the conversion option at inception (the embedded derivative) from the fair value of the consideration received for the convertible loan notes. The debt component is then recognised at amortised cost, using the effective interest method until extinguished upon conversion or at the instrument's maturity date.

 

6 months ended

 

6 months ended

 

12 months ended

 

30 Jun 2018

 

30 Jun 2017

 

31 Dec 2017

 

$'000

 

$'000

 

$'000

 

 

 

 

 

 

Proceeds of issue of convertible bonds

-

 

-

 

230,000

Transaction costs

-

 

-

 

(7,208)

Net proceeds on issue of convertible loan notes

-

 

-

 

222,792

 

 

 

 

 

 

Transaction costs relating to liability component

-

 

-

 

5,984

Transaction costs relating to derivative liability

-

 

-

 

1,224

Total transaction costs

-

 

-

 

7,208

 

 

 

 

 

 

Liability component at start of period (net of transaction costs)

(191,102)

 

-

 

-

Liability component issued in period (net of transaction costs)

-

 

 

 

(184,967)

Interest charged

(12,041)

 

-

 

(10,448)

Interest paid

8,625

 

-

 

4,313

Liability at end of period

(194,518)

 

-

 

(191,102)

 

 

 

 

 

 

Derivative liability at start of period

(28,622)

 

-

 

-

Derivative liability issued in the period

-

 

 

 

(39,049)

Change in fair value recognised in the income statement (note 14)

(70,150)

 

-

 

10,427

Derivative liability at end of period

(98,772)

 

-

 

(28,622)

 

The interest expensed in the period is calculated by applying an effective interest rate of 13.5% to the liability component for the period. The liability component is measured at amortised cost. The difference between the carrying amount of the liability component at the date of issue and the amount reported in the balance sheet at 30 June 2018 represents the interest charged at the effective interest rate less interest paid to that date. All of the interest charge has been capitalised within property, plant and equipment as it is considered to relate to the development of the Lancaster Field, a qualifying asset.

 

11.       Decommissioning provisions

 

6 months ended

 

6 months ended

 

12 months ended

 

30 Jun 2018

 

30 Jun 2017

 

31 Dec 2017

 

(Unaudited)

 

(Unaudited)

 

(Audited)

 

$'000

 

$'000

 

$'000

 

 

 

 

 

 

At start of period

7,023

 

5,959

 

5,959

Unwinding of discount rate

50

 

35

 

83

Additions

15,984

 

981

 

981

Changes to decommissioning estimate

636

 

-

 

-

At end of period

23,693

 

6,975

 

7,023

The provision for decommissioning relates to the costs required to decommission the suspended wells previously drilled on the Lancaster, Whirlwind and Halifax exploration assets, and the costs required to decommission the Lancaster EPS installations at 30 June 2018. The expected decommissioning cost for these assets is based on the directors' best estimate of the cost of decommissioning the assets at the end of 2025 discounted at 1.09% per annum (2017: 1.31%). The addition in 2018 was due to the work completed in 2018 in relation to the EPS installation on the Lancaster asset. This work comprised the completion of the 6 and 7Z wells and installation of the Xmas trees.

12.       Called up share capital

 

 

6 months ended

 

6 months ended

 

12 months ended

 

 

30 Jun 2018

 

30 Jun 2017

 

31 Dec 2017

 

 

(Unaudited)

 

(Unaudited)

 

(Audited)

 

 

$'000

 

$'000

 

$'000

Allotted, called up and fully paid

 

 

 

 

 

 

30 June 2018: 1,959,551,637; (30 June 2017: 1,227,988,123; 31 December 2017: 1,959,210,336) Ordinary Shares of £0.001 each

 

2,843

 

1,892

 

2,843

The Company does not have an authorised share capital.

On 24 January 2018 341,301 new Ordinary Shares were issued to the Hurricane Energy plc Share Incentive Plan (SIP) at a subscription price of £0.39 per share.

13.       Reconciliation of operating loss to net cash (outflow) / inflow from operating activities

 

30 Jun 2018

 

30 Jun 2017

 

31 Dec 2017

 

 

 

 

 

 

Operating loss

(4,714)

 

(5,989)

 

(24,998)

Adjustments for:

 

 

 

 

 

Depreciation of property, plant and equipment

19

 

8

 

22

Impairment / write off of intangible exploration and evaluation assets

-

 

-

 

10,412

Share based payment charge

2,433

 

2,349

 

3,922

Operating cash outflow before working capital movements

(2,263)

 

(3,632)

 

(10,642)

 

 

 

 

 

 

Increase in receivables

(848)

 

(2,192)

 

(3,370)

Increase in payables

378

 

1,088

 

64

Cash used in operating activities

(2,733)

 

(4,736)

 

(13,948)

 

 

 

 

 

 

Corporation tax received

-

 

5,860

 

5,860

Net cash (outflow) / inflow from operating activities

(2,733)

 

1,124

 

(8,088)

14.       Financial Instruments

The derivative financial instruments held by the Group are the embedded derivative associated with the issue of the convertible bonds, and the forward foreign exchange contracts the Group entered into during 2017.

IFRS 7 'Financial Instruments: Disclosures' requires entities to disclose the fair value of each class of financial assets and financial liabilities in a way that permits it to be compared with its carrying value. IFRS 7 also requires financial instruments to be classified into a fair value hierarchy based on the lowest level input that is significant to the fair value measurement.

The fair value hierarchy is defined in IFRS 13 'Fair Value Measurement' and has the following levels:

Level 1 - quoted prices (unadjusted) in active markets for identical assets or liabilities.

Level 2 - inputs other than quoted prices included within Level 1 that are observable for the asset or liability, either directly or indirectly.

Level 3 - inputs for the asset or liability that are not based on observable market data (unobservable inputs).

 

Embedded Derivative

At inception and at the Balance Sheet date, the fair value of the embedded derivative contained within the Convertible Bonds was calculated based on the conversion option contained within. In determining the fair value of the embedded derivative, the likelihood of the early redemption option being exercised and the likelihood of a change of control of the Group within the life of the bonds were considered. The likelihood of each was considered to be nil for the purposes of the valuation.

 

6 months ended

 

6 months ended

 

12 months ended

 

30 June 2018

 

30 June 2017

 

31 Dec 2017

 

(Unaudited)

 

(Unaudited)

 

(Audited)

 

$'000

 

$'000

 

$'000

Derivative liability at start of period

(28,622)

 

-

 

-

Derivative liability issued in the period

-

 

 

 

(39,049)

Change in fair value recognised in the income statement

(70,150)

 

-

 

10,427

Derivative liability at end of period

(98,772)

 

-

 

(28,622)

 

The derivatives that are a part of the Convertible Bond issue have been assessed to be a Level 3 financial liability. This is because the derivatives themselves are not traded on an active market and their fair values are determined by a valuation technique that uses one key input that is not based on observable market data, being share price volatility.

Volatility is a key input in the valuation of the Convertible Bond embedded derivative. Volatility is a measure of the variability or uncertainty in return for a given underlying derivative. It represents an estimate of how much a particular instrument, parameter or index (in this case share price) will change in value over time. The valuation technique was based on a simulation model and the volatility was calculated as a blended average of the trading history of the Group's own shares and shares in a relevant peer group, for a period of six months prior to the measurement date.

The fair value at 30 June 2018 was calculated using the Hurricane share price on that date of £0.475 (31 December 2017: £0.310) and a share price volatility assumption of 30.1% (31 December 2017: 23.6%). The effect on the fair value of the derivative liability due to changes to the share price and share price volatility have been considered below.

 

 

Base share price
(£0.475)

 

Base share price
-£0.10 (£0.375)

 

Base share price
+£0.10 (£0.575)

 

$,000

 

$,000

 

$,000

Fair value of derivative liability

98,772

 

57,275

 

146,200

 

 

 

 

 

 

 

Base volatility
(30.1%)

 

Base volatility
-5% (25.1%)

 

Base volatility
+5% (35.1%)

 

$,000

 

$,000

 

$,000

Fair value of derivative liability

98,772

 

90,856

 

106,955

 

As movements in the fair value are recognised directly in the income statement these changes would directly affect the loss after tax by the same amount.

Foreign exchange swaps

During 2017 the Group entered into several foreign exchange swaps to cover specific foreign currency payments in the Group's future. At the reporting date the Group had one remaining foreign exchange swap for the purposes of settling a known Euro payment to occur in October 2018.

These foreign exchange swaps were accounted for using the spot rate on the date the swap was entered into, and subsequently revalued at each reporting date for movements in the foreign exchange rate. Any change in the forward spot rate at period-end is accounted for by taking the fair value changes to the income statement and recognising either a derivative asset or derivative liability in the statement of financial position.

During the period, two of the foreign exchange swaps were settled.

The following table details the foreign currency swaps outstanding at 30 June 2018:

EUR

Forward Rate (inception)

Forward Rate (30 Jun 18)

Foreign Currency

€'000

Notional Value

$'000

Trade Value

$'000

Derivative Liability

$'000

3 - 6 months

0.8988

0.8867

1,700

1,998

1,971

(27)

 

 

 

 

 

 

(27)

 

 

6 months ended

 

6 months ended

 

12 months ended

 

30 Jun 2018

 

30 Jun 2017

 

31 Dec 2017

 

(Unaudited)

 

(Unaudited)

 

(Audited)

 

$'000

 

$'000

 

$'000

Derivative liability at start of period

(11)

 

-

 

-

Termination of derivative liability on FX swap

4

 

-

 

-

Change in fair value recognised in the income statement

(20)

 

-

 

(11)

Derivative liability at end of period

(27)

 

-

 

(11)

 

The derivatives that are a part of the foreign exchange swaps have been assessed to be a Level 2 financial liability. This is because the foreign currency swaps themselves are not traded on an active market. However, their fair values are determined by valuation techniques that use observable market data, e.g. foreign exchange rates.

15.       Capital commitments

As at 30 June 2018 the Group had capital commitments of $70.3 million (30 June 2017: $69.0 million; 31 December 2017: $199.7 million).

16.       Related parties

During the 6 months ended 30 June 2018, the only related party transactions are those with the directors who are considered the Group's key management personnel.

17.       Subsequent events

On 3 July 2018, the Group transferred $22.1 million to the Law Debenture Trust by way of security for the decommissioning of the Lancaster EPS which will be classified as non-current restricted cash.

On 3 September 2018, the Group announced that Spirit Energy Limited has farmed-in to 50% of Hurricane's Lincoln (P1368 South) and Warwick (P2294) licences together covering the Greater Warwick Area . Further details are provided in the Chief Executive Officer's Review in the front half of this report.

 

Glossary

 

2P reserves

Proved plus probable reserves under the Society of Petroleum Engineers' Petroleum Resources Management System

2C contingent resources

Best case contingent resources under the Society of Petroleum Engineers' Petroleum Resources Management System

AIM

The AIM market of the London Stock Exchange

Aoka Mizu

The Aoka Mizu FPSO

the Code

The Financial Reporting Council's UK Corporate Governance Code

Company

Hurricane Energy plc and/or its subsidiaries

EPS

Early production system

FEED

Front end engineering and design

FID

Final investment decision

FPSO

Floating production storage and offloading vessel

GLA

Greater Lancaster Area, comprising the Lancaster and Halifax fields located on UKCS licences P.1368 Central and P.2308

the Group

Hurricane Energy plc and its subsidiaries

GWA

Greater Warwick Area, comprising the Lincoln and Warwick fields located on UKCS licences P.1368 South and P.2294

HSE

Health, Safety and Environmental

Hurricane

Hurricane Energy plc and its subsidiaries

IFRS

International Financial Reporting Standards as adopted by the European Union

Ordinary Shares

Ordinary shares in the Company of £0.001 each

Premium Listing

Listing on the premium segment of a recognised stock exchange

SIP

Share incentive plan

Spirit Energy

Spirit Energy Limited

SURF

Subsea umbilical, risers and flowlines

TMS

Turret mooring system

UKCS

United Kingdom Continental Shelf

UOP

Unit of Production

Xmas trees

An assembly of valves, spools and fittings used at the head of an oil and gas well

 

 


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