Register for Digital Look

Company Announcements

Interim Management Statement

Related Companies

RNS Number : 5772O
Afren PLC
29 May 2015
 



Afren plc: Interim Management Statement

·      US$200 million interim funding provided by existing Noteholders by way of new private placement notes in April 2015;  proceeds to be used for general corporate purposes and capex;  wider recapitalisation programme to be completed by the end of July 2015

·      Nigeria projects progressing: Completion of top-side Ebok CFB extension; options for Okoro FFD with a low oil price under discussion; completion of first Okwok development well; fifth production well completed on OML 26

·      2015 capex guidance US$0.4 billion expected to focus on existing producing assets in Nigeria; average production guidance expected to be 23,000 - 32,000 bopd, reflecting lower share of production from Ebok following end of cost recovery

·      Q1 2015 net production at 36,035 bopd, above FY guidance range but in line with expectations; Q1 2015 Revenue of US$130 million; Operating cash flow before movements in working capital of US$59 million; Capex US$212 million; Net Debt US$1,196 million

London, 29 May 2015 - Afren plc ("Afren" or the "Group"), (LSE: AFR), announces its Interim Management Statement ("IMS") and financial results for the three months ended 31 March 2015 and an update on its operations year-to-date 2015.  Information contained within this release is unaudited and is subject to further review.

Operational Update

Afren delivered revenue of US$130.3 million (Q1 2014: US$269.0 million) and operating cash flows before movements in working capital of US$59.1 million (Q1 2014: US$169.1 million) in Q1 2015, driven by average net production at 36,035 bopd in line with expectations to meet our guidance range for 2015, averaging 23,000 - 32,000 bopd.  The fall in revenue was due to lower realised oil prices and production liftings from Ebok utilised to settle a net profit interest (NPI) liability. NPI represents a contractual profit share payable to previous owners of the Ebok field for which liftings made in settlement are offset against cost of sales (NPI liftings commenced in Q4 2014).

Our 2015 production guidance range reflects a lower share of production following end of all cost recovery at Ebok. At Ebok, following completion of the installation of the CFB extension wellhead jacket in late Q4 2014, the Partners completed the top-side installation of the bridge and decks in March 2015 and are targeting hook-up and commissioning of the facilities by Q4 2015.  Gross production at the Ebok field was 30,954 bopd.  As previously announced, Afren and Oriental have reached an agreement to end cost recovery.  Oriental will fund its share of expenditure from May 1 2015.  As a result of the agreement, Afren will receive a lower share of production to reflect its share of working interest in Ebok.

At Okoro, gross production at the field was circa 15,073 bopd in the period, incorporating planned downtime.  The Partners are currently in discussions on how to manage the Okoro Further Field Development Plan in line with the current low oil price environment with a view to re-engineering the forward work programme.  At Okwok, Afren and its JV Partners Oriental and Addax Petroleum, have completed and flow tested a first development well, which was completed in April 2015 from the Okwok jacket having been drilled to a total measured depth of 9,202 ft and flow tested successfully at a maximum rate of 5,400 bopd (24.5 deg API oil). 

At OML 26, following the receipt of Field Development Plan (FDP) approval by the Nigerian regulatory authorities in H1 2014, the Partners successfully drilled two producers in H2 2014.  A third producer was spudded in December 2014 and completed in February 2015, a fourth producer was completed in March 2015 and a fifth producer has just been completed in May 2015. All five new wells have been drilled with the same rig and from the same location cluster. Two of the wells tested at over 2,000 bopd and a third around 1,000 bopd during post completion well tests without any gaslift. The new wells will undergo the statutory well tests and gaslifted to realise their full production potential in the coming months.   Submission of the OML 26 FDP to the Nigerian authorities for Isoko is expected in Q2 2015.

At the Barda Rash field in Kurdistan, following a material reduction to previously published estimates of reserves and resources resulting from the reprocessing 3D seismic shot in 2012 and results from the Company's drilling campaign as well as the publication of an updated Competent Person's Report (CPR) on 12 January 2015, Afren is in discussions with the MNR regarding potential divestment opportunity options for the field.

Following the play-opening Ogo discovery, offshore Nigeria, Afren completed the fast track 2,716 km2 marine 3D seismic programme across OPL 310 and OML 113 to complement existing coverage on the two licences. Processing of 3D seismic data has been completed.  The fast track post-stack time migration was delivered in August 2014 and the final production pre-stack time migration was delivered in late Q4 2014.  The pre-stack depth migration was delivered in April 2015.  The interpretation of these data sets will be used to finalise a well location.  Afren has instructed NSAI to commence the preparation of a CPR for OPL 310 incorporating the new block wide seismic data.

Capex guidance for 2015 remains at US$0.4 billion, focussed on high margin Nigerian cash generating producing assets.

 

 

Commenting today, Alan Linn, Chief Executive Officer of Afren plc, said:

"Afren has delivered a solid first quarter result despite the continuing low oil price and additional NPI liftings from Ebok. We have already significantly curtailed immediate capital expenditure and are now working with our Partners to optimise forward investment in development projects in Nigeria. Business and process streamlining has commenced and we expect to begin seeing improved bottom line results from these efficiencies across the business as 2015 unfolds. Whilst interim funding is now in place, it will take time to work through historical issues and funding remains extremely tight. We will be working with shareholders in the coming weeks to explain the benefits of our proposed new funding structure and encourage them to support us in resolving our financing issues in order for Afren to deliver the long-term value and attractive future I see for the Company."

 

Production

Production Q1 2015 (bopd)

 

Working interest

Average gross production

Average net production

Okoro

50%

15,073

7,537

Ebok

 50%(1)

30,954

26,887

OML 26

45%

3,580

1,611

Total


49,607

36,035

(1 ) Afren's net production in 2015 includes its 50% working interest plus additional barrels to recover costs of capital investment funded by Afren. It includes any volumes provided to Partners to settle net profit interest liabilities.

 

Financial Position

Revenue for the three months ended 31 March 2015 was US$130.3 million (Q1 2014: US$269.0 million).  The 52% decrease in revenue is attributable to a significantly lower realised oil price of US$48.0/bbl (Q1 2014: US$ 106.5/bbl) and liftings of Ebok production being provided in settlement of the net profit interest liability (such amounts are therefore excluded from revenue and offset against cost of sales).

This fall in revenue, together with higher administrative costs incurred in relation to the Group's recapitalisation and the write-off of Q1 2015 expenditure on certain exploration and evaluation assets,  resulted in a loss before tax for the period of US$48.1 million (Q1 2014: profit before tax of US$55.8 million).  Although the Group continues to reflect the benefit of a five-year tax holiday at the Ebok field, a tax charge of US$5.0 million was recorded for Q1 2015 (Q1 2014: US$16.7 million credit).  The tax charge for Q1 2015 principally relates to the current tax charge at Okoro.  This resulted in a loss after tax of US$53.1 million (Q1 2014: US$72.5 million profit after tax).

Operating cash flow before movements in working capital for the three months to 31 March 2015 was US$59.1 million (Q1 2014: US$169.1 million).  This decrease was primarily attributable to lower revenue.  Net cash generated by operating activities was US$84.0 million (Q1 2014: US$114.2).  The narrowing of the decrease compared to operating cash flow before movements in working capital reflects a reduction in the inventory of crude oil compared to the respective year-ends.

During the three months to 31 March 2015 the Group spent US$212.0 million developing its assets (US$209.7 million investment in producing and development assets and US$2.3 million on exploration and evaluation projects).  The investment in producing and development assets included US$128.9 million in respect of various drilling and enhancement activities at Ebok.

Gross debt at 31 March 2015 was US$1,296.1 million, excluding finance leases.  Cash at bank at 31 March 2015 was US$100.5 million, resulting in net debt (excluding finance leases) of US$1,195.6 million (31 December 2014: gross debt of US$1,304.0 million; cash of US$236.5 million; and net debt of US$1,067.5 million).

 

On 30 April 2015, the Group announced that, as part of its recapitalisation plan, it will be provided with US$200 million of net interim funding.  For further details of this and the overall recapitalisation, please refer to our announcement on 30 April 2015 entitled "Completion of interim funding, appointment of new CEO and update of reserves".

There are no material changes to either the contingent liabilities or post balance sheet events, from those previously disclosed within the 2014 annual report and accounts.

 

Unaudited condensed consolidated statement of comprehensive income

Three months ended 31 March 2015

 



3 months to


3 months to





31 March 2015


31 March 2014





Unaudited


Unaudited





US$m


US$m










Revenue


130.3


269.0



Cost of sales


(87.0)


(186.0)



Gross profit


43.3


83.0



Administrative expenses


(32.2)


(6.4)



Other operating expenses







- derivative financial instruments


(1.8)


(3.6)



- impairment of exploration and evaluation assets


(26.5)


(0.6)



Operating (loss)/profit


(17.2)


72.4



Finance income


0.2


0.6



Finance costs


(34.2)


(19.9)



Other gains







- foreign currency gains


3.1


2.3



- fair value gains on financial liabilities and financial assets

-


0.4



(Loss)/profit before tax


(48.1)


55.8



Income tax (charge)/credit


(5.0)


16.7



(Loss)/profit after tax


(53.1)


72.5



Attributable to:







Equity holders of Afren plc


(52.0)


74.3



Non-controlling interests


(1.1)


(1.8)





(53.1)


72.5










Other comprehensive income







Loss on revaluation of available-for-sale investment


 -  


(0.1)



Reclassification adjustment for gains recycled to profit and loss


(32.2)


-



Other comprehensive expense for the period


(32.2)


(0.1)



Total comprehensive (expense)/income for the period


(85.3)


72.4



Attributable to:







Equity holders of Afren plc


(84.2)


74.2



Non-controlling interests


(1.1)


(1.8)





(85.3)


72.4










(Loss)/earnings per share from all activities






Basic


(0.6)

c

6.8

c


Diluted


(0.6)

c

6.5

c


 

 

 

 

Unaudited condensed consolidated balance sheet

As at 31 March 2015

 









31 March 2015


31 December 2014




Unaudited


Audited




US$m


US$m


Assets






Non-current assets






Intangible oil and gas assets


221.0


219.6


Property, plant and equipment


1,580.1


1,379.9


Deferred tax assets


340.4


348.2




2,141.5


1,947.7


Current assets






Inventories


125.3


164.7


Trade and other receivables


195.6


221.8


Prepayments and advances to Partners


64.0


64.0


Cash and cash equivalents


100.5


236.5




485.4


687.0


Total assets


2,626.9


2,634.7


Liabilities






Current liabilities






Trade and other payables


(837.0)


(735.3)


Provisions


(13.6)


(21.0)


Borrowings


(574.8)


(268.4)


Current tax liabilities


(23.8)


(15.7)


Deferred consideration on acquisitions


(21.5)


(21.0)


Obligations under finance lease


(23.8)


(21.8)


Derivatives over own equity


(58.9)


(57.5)


Derivative financial instruments


-


(4.8)




(1,553.4)


(1,145.5)


Net current liabilities


(1,068.0)


(458.5)


Non-current liabilities






Deferred tax liabilities


(85.1)


(96.0)


Provision for decommissioning


(37.9)


(44.0)


Borrowings


(721.3)


(1,035.6)


Obligations under finance leases


(50.3)


(56.0)


Derivative financial instruments


(11.8)


(8.4)




(906.4)


(1,240.0)


Total liabilities


(2,459.8)


(2,385.5)


Net assets


167.1


249.2


Equity






Share capital


19.2


19.2


Share premium


929.3


929.3


Other reserves


89.0


118.0


Accumulated loss


(852.1)


(800.1)


Total equity attributable to parent company


185.4


266.4








Non-controlling interest


(18.3)


(17.2)


Total equity


167.1


249.2


 

 

 

Unaudited condensed consolidated cash flow statement

Three months ended 31 March 2015

 






3 months to


3 months to


31 March 2015


31 March 2014


Unaudited


Unaudited


US$m


US$m

Operating (loss)/profit for the period

(17.2)


72.4

Depreciation, depletion and amortisation

81.8


100.2

Unrealised gains on derivative financial instruments

(33.5)


(6.4)

Impairment charge on exploration and evaluation assets

26.5


0.6

Share-based payments charge

1.5


2.3

Operating cash-flows before movements in working capital

59.1


169.1

Decrease in trade and other operating receivables

30.7


26.1

Decrease in trade and other operating payables

(37.0)


(47.8)

Decrease/(increase) in inventory of crude oil

31.2


(29.8)

Current tax paid

-


(3.4)

Net cash generated by operating activities

84.0


114.2





Purchases of property, plant and equipment

(209.7)


(94.4)

Exploration and evaluation expenditure

(2.3)


(31.7)

Decrease/(increase) in inventories - drilling spare parts and materials

8.8


(13.4)

Investment inflow

-


0.2

Net cash used in investing activities

(203.2)


(139.3)





Issue of ordinary share capital - share-based plan exercises

-


1.4

Purchase of own shares

-


(3.1)

Proceeds from borrowings - net of issue costs

-


98.5

Repayment of borrowings and finance leases

(13.5)


(86.6)

Interest and financing fees paid

(3.3)


(16.9)

Net cash used in financing activities

(16.8)


(6.7)





Net decrease in cash and cash equivalents

(136.0)


(31.8)

Cash and cash equivalents at beginning of the period

236.5


389.9

Effect of foreign exchange rate changes

-


2.6

Cash and cash equivalents at end of period

100.5


360.7





 

 

 

 

 

Unaudited condensed consolidated statement of changes in equity

Three months ended 31 March 2015

 











Share capital

Share premium account

Merger reserve

Other reserves

Accumulated losses

Attributable to equity holders of parent

Non-controlling Interest

Total equity


US$m

US$m

US$m

US$m

US$m

US$m

US$m

US$m

At 1 January 2014

19.1

926.8

179.4

27.5

642.0

1,794.8

10.7

1,805.5

Issue of share capital

-

1.4

-

-

-

1.4

-

1.4

Share based payments for services

-

-

-

4.0

-

4.0

-

4.0

Exercise and lapse of warrants designated as financial liabilities

-

-

-

0.1

(0.1)

-

-

-

Purchase of own shares

-

-

-

(3.1)

-

(3.1)

-

(3.1)

Profit/(loss) after tax for the period

-

-

-

-

74.3

74.3

(1.8)

72.5

Other comprehensive loss for the period

-

-

-

(0.1)

-

(0.1)

-

(0.1)

Balance at 31 March 2014

19.1

928.2

179.4

28.4

716.2

1,871.3

8.9

1,880.2



















At 1 January 2015

19.2

929.3

-

118.0

(800.1)

266.4

(17.2)

249.2

Share based payments for services

-

-

-

3.2

-

3.2

-

3.2

Loss after tax for the period

-

-

-

-

(52.0)

(52.0)

(1.1)

(53.1)

Other comprehensive loss for the period

-

-

-

(32.2)

-

(32.2)

-

(32.2)

Balance at 31 March 2015

19.2

929.3

-

89.0

(852.1)

185.4

(18.3)

167.1

Notes to the condensed consolidated financial statements

Three months ended 31 March 2015

 

1. Basis of accounting and presentation of financial information

The condensed Group interim financial statements, comprised of Afren plc (''Afren'') and its subsidiaries (together, ''the Group''), have been prepared in accordance with the same accounting policies, presentation and methods of computation as applied in the audited financial statements for the year ended 31 December 2014, with the exception of taxes, which have been calculated using the estimated full year effective tax rate. The Group policies are in accordance with International Financial Reporting Standards ("IFRS") as adopted by the European Union. Certain information and note disclosures normally included in annual financial statements prepared in accordance with IFRS, as adopted by the EU, have been omitted or condensed as is normal practice for interim reporting periods. The condensed Group interim financial statements are unaudited, and do not constitute statutory accounts as defined in sections 435(1) and (2) of the Companies Act 2006. Statutory accounts for the year ended 31 December 2014 are published on the Group's website, www.afren.com. The report of the auditor on those accounts was unqualified, however it included an emphasis of matter regarding a material uncertainty in respect of going concern. The report of the auditor did not contain any statement under sections 498(2) or (3) of the Companies Act 2006.

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 Operations review of the Annual Report for the year ended 31 December 2014, which is available at www.afren.com. The financial position of the Group at the period end, its cash flows, liquidity position and net debt are described in the Financial review.

Events following the dismissal of the Group's former CEO and COO have placed significant pressure on the Group's liquidity position, resulting in the Group having net current liabilities of US$1,068 million as at 31 March 2015.

The Company's inability to execute the planned refinancing in the middle of 2014, followed by the sharp decline in market oil prices, led the Directors to initiate an urgent review of the Group's capital structure, liquidity and funding requirements as announced on 20 January 2015. On 30 January 2015, the Group announced it had obtained from the lenders of the US$300 million Ebok debt facility a deferral of the US$50 million amortisation payment due on 31 January 2015. On 4 March 2015, the Group announced that the Board had decided at the expiration of a 30 day grace period not to pay US$15 million of interest which was due on 1 February 2015 under its 2016 Senior Notes.

On 13 March 2015, the Group announced a preliminary agreement for the receipt of Interim Funding and the Recapitalisation of the business. The agreement entered into by Afren together with certain noteholders under its 2016 Notes, 2019 Notes and 2020 Notes (Noteholders) and a majority of the lenders under the Group's existing US$300 million Ebok credit facility, wasintended to result in the provision of US$255-US$305 million of net total funding before the end of July 2015. On 30 April 2015, the Company entered into definitive agreements with certain Noteholders and issued US$212 million of private placement notes (PPN), providing US$200 million in net cash to the Group. In conjunction with such agreement, the lenders under the Group's existing US$300 million Ebok credit facility agreed to the deferral of the US$50 million amortisation payments due on 31 January 2015 and 30 April 2015 until the completion of the implementation of the Recapitalisation (at which point it is expected that the amortisation payments will be further deferred until after the repayment of the New High Yield Notes - see below).

In connection with the Recapitalisation, on 30 April 2015 the Group also entered into a conditional agreement to raise US$55 million in additional net proceeds (after the repayment of the PPN) from the issuance of new High Yield Notes due in 2017 (New HY Notes). On 29 May 2015 the Group announced that the Noteholders have agreed to subscribe for further New HY Notes up to the maximum level permitted of US$369 million increasing the additional net cash proceeds by a further $93 million. In addition, as part of the Recapitalisation (i) 25% of the 2016 Notes, 2019 Notes and 2020 Notes (Existing Notes) will be converted to new equity in the Company; (ii) the remaining 75% of the Existing Notes will be extended to mature as to US$350 million in each of December 2019 and December 2020; (iii) the existing Ebok credit facility will be extended to 2019; (iv) new shares will be issued to subscribers to the New HY Notes and the PPN; and (v) the Company will undertake an equity offering of up to US$75 million to shareholders. The Group has also reached agreement with the lender of its Okwok/OML 113 facility to restructure and defer this facility until 2018. 

The US$200 million net cash proceeds from the issuance of the PPN has been deposited in escrow, to be drawn down by the Group over the coming months. Withdrawals from escrow are required to be applied broadly in accordance with agreed financial forecasts, and are subject to an agreed drawdown schedule and the Group's continuing compliance with certain default conditions. The PPN would be repayable by April 2016 if not refinanced through the Recapitalisation.

In order for the Recapitalisation to be implemented there are other conditions that need to be fulfilled, including obtaining (i) the approval of requisite majorities of holders of the Existing Notes in connection with a scheme of arrangement of such Existing Notes; (ii) approval from the relevant courts in the UK and the US as to such scheme of arrangement; and (iii) agreement from the Group's remaining lenders. The Company will also seek the approval of shareholders in general meeting to the terms of the Recapitalisation, which is required in order to issue the new ordinary shares in connection with the Recapitalisation. If shareholder approval is not received, the Recapitalisation will still proceed, but on amended terms for the New HY Notes (see below).

As at 29 May 2015 Afren is in default under the terms of its 2016 Notes due to the non-payment of interest. The Company has received assurances from the ad hoc committee of Noteholders (which members hold in aggregate approximately 63% of the principal face amount of the 2016 Notes and approximately 50% of the total principal face amount of the Existing Notes) (Ad Hoc Committee) that the Ad Hoc Committee has no current intention to take enforcement action with respect to the 2016 Notes held by its members as a result of the failure to make payment of interest due under the 2016 Notes, on the basis that agreement has been reached with the Company and its key stakeholders on the terms of a consensual (but conditional) restructuring.

As at 29 May 2015 Afren is in default under the terms of its 2019 Notes due to the non-payment of interest. The Company has received assurances from the Ad Hoc Committee (which members hold in aggregate approximately 35% of the principal face amount of the 2019 Notes) that it has no current intention to take enforcement action with respect to the 2019 Notes held by its members as a result of the failure to make payment of interest due under the 2019 Notes.

There is a risk that one or more of these Recapitalisation steps outlined above, may not be completed or satisfied and the Recapitalisation may not occur. If additional funds are not available to be drawn under the New HY Notes, and the Recapitalisation does not proceed, the Directors are of the opinion that the Group would become insolvent, absent an alternative proposal being received by the Company that is capable of being implemented.

If shareholder approval of the Recapitalisation is not received, the Ad Hoc Committee and the lenders under the Group's existing US$300 million Ebok credit facility have agreed to an alternative restructuring plan, whereby the economic terms of the New HY Notes will be amended, and the amendment and restatement of the Existing Notes will be revised (so that no new shares are issued). In addition, the New HY Notes will include a requirement for the Company to initiate a sale of the Group's business by the end of 2016, which together will mean that existing shareholders would be unlikely to see any return of their current investment.

On the basis that the Recapitalisation is successfully achieved as outlined above, the Group's financial footing and ability to continue in operation would be significantly strengthened. The Group's financial forecasts and projections for the next twelve months indicate that the Group would then be able to meet its obligations as they fall due, however, this assessment is sensitive to a number of downside risks such as any further significant deterioration in the outlook for oil prices, any significant disruption to the Group's production revenue stream due to operational or other factors, and the crystallisation of other risks such as those described in notes 10 and 13 to the financial statements for the year ended 31 December 2014 (which are available at www.afren.com), particularly if such downside risks were to materialise in combination. Therefore, the Group expects that it will still need to seek industry partnerships, strategic divestments and other fundraising transactions as necessary to build resilience against, or respond to, downside risks, capture the opportunity in the Group's portfolio and secure the Group's future.

The Directors recognise that the combination of the circumstances described above represents a material uncertainty that may cast significant doubt as to the Group's ability to continue as a going concern and that it may be unable to realise its assets in the normal course of business. Nevertheless, the Directors expect that the Recapitalisation will obtain all of the necessary approvals and consents as set out above and the Directors therefore have a reasonable expectation that the Group will be able to successfully navigate the present uncertainties and continue in operation. Accordingly the condensed interim financial statements have been prepared on a going concern basis and no break up adjustments have been made. 

2. Operating segments

The Group currently operates in three geographical markets which form the basis of the information evaluated by the Group: Nigeria and other West Africa, East Africa and Kurdistan region of Iraq. Unallocated operating expenses, assets and liabilities relate to the general management, financing and administration of the Group.

 


Nigeria and other West Africa

East Africa

Kurdistan region of Iraq

Unallocated

Consolidated


US$m

US$m

US$m

US$m

US$m

Three months to 31 March 2015






Revenue by origin

130.3

-

-

-

130.3

Operating gain/(loss) before derivative financial instruments

19.1

(5.5)

(4.3)

(24.7)

(15.4)

Derivative financial instruments losses

 -  

 -  

 -  

(1.8)

(1.8)

Segment result

19.1

(5.5)

(4.3)

(26.5)

(17.2)

Finance costs





(34.2)

Other gains and losses - forex and finance income





3.3

Loss before tax


(48.1)

Income tax charge





(5.0)

Loss after tax


(53.1)

Loss for the period





(53.1)







Segment assets - non-current

2,139.4

0.5

0.2

1.4

2,141.5

Segment assets - current

422.3

 -  

-

63.1

485.4

Segment liabilities

(1,370.7)

(9.5)

(36.0)

(1,043.6)

(2,459.8)

Capital additions - oil and gas assets

290.7

-

3.1

-

293.8

Capital additions - exploration and evaluation

19.7

4.9

4.1

0.1

28.8

Capital additions - other

0.2

-

(0.6)

0.1

(0.3)

Depletion, depreciation and amortisation

(80.8)

-

(0.2)

(0.8)

(81.8)

Impairment of exploration and evaluation assets

(17.5)

(4.9)

(4.0)

(0.1)

(26.5)

 

2. Operating segments continued

 


Nigeria and other West Africa

East Africa

Kurdistan region of Iraq

Unallocated

Consolidated


US$m

US$m

US$m

US$m

US$m

Year to 31 December 2014






Revenue by origin

945.8

-

-

-

945.8

Operating gain/(loss) before derivative financial instruments

(329.5)

(327.0)

(1,218.0)

(14.7)

(1,889.2)

Derivative financial instruments gains/(losses)

1.9

 -  

 -  

(10.8)

(8.9)

Segment result

(327.6)

(327.0)

(1,218.0)

(25.5)

(1,898.1)

Finance costs





(66.9)

Other gains and losses:






 - fair value of financial assets and liabilities





0.7

 - share of joint venture loss

(1.7)




(1.7)

 - forex and finance income





11.0

Loss before tax


(1,955.0)

Income tax credit





303.9

Loss after tax


(1,651.1)

Loss for the year





(1,651.1)







Segment assets - non-current

1,944.5

0.7

0.5

2.0

1,947.7

Segment assets - current

529.0

0.3

6.1

151.6

687.0

Segment liabilities

(1,365.6)

(8.2)

(45.8)

(965.9)

(2,385.5)

Capital additions - oil and gas assets

547.8

-

145.9

-

693.7

Capital additions - exploration and evaluation

83.4

32.1

27.9

-

143.4

Capital additions - other

2.1

-

-

2.8

4.9

Depletion, depreciation and amortisation

(365.4)

(0.2)

(0.6)

(4.2)

(370.4)

Impairment of property, plant and equipment

(273.0)

-

(932.6)

-

(1,205.6)

Impairment of exploration and evaluation assets

(198.9)

(360.7)

(265.2)

(14.3)

(839.1)

Impairment of goodwill

(115.2)

-

-

-

(115.2)

Share of joint venture loss

(1.7)

-

-

-

(1.7)

 

2. Operating segments continued

 


Nigeria and other West Africa

East Africa

Kurdistan region of Iraq

Unallocated

Consolidated


US$m

US$m

US$m

US$m

US$m

Three months to 31 March 2014






Revenue by origin

269.0

-

-

-

269.0







Operating gain/(loss) before derivative financial instruments

81.7

(0.1)

(2.5)

(3.1)

76.0

Derivative financial instruments losses

(2.9)

-

-

(0.7)

(3.6)

Segment result

78.8

(0.1)

(2.5)

(3.8)

72.4

Finance costs





(19.9)

Other gains and losses:






 - fair value of financial assets & liabilities





0.4

 - forex and finance income





2.9

Profit before tax


55.8

Income tax credit





16.7

Profit after tax


72.5

Profit for the period





72.5







Segment assets - non-current

2,023.6

304.6

1,052.8

21.0

3,402.0

Segment assets - current

615.2

3.4

15.8

133.5

767.9

Segment liabilities

(1,254.7)

(38.2)

(24.2)

(972.6)

(2,289.7)

Capital additions - oil and gas assets

52.8

-

42.6

-

95.4

Capital additions - exploration and evaluation

8.7

8.7

6.5

(0.5)

23.4

Capital additions - other

0.6

0.1

0.1

1.9

2.7

Depletion, depreciation and amortisation

(99.4)

(0.1)

(0.1)

(0.6)

(100.2)

Impairment of exploration and evaluation assets

(0.3)

(0.3)

-

-

(0.6)

 

 

 

 

Advisers and Company Secretary

 

 

Company Secretary and Registered Office

Elekwachi Ukwu

Afren plc

Kinnaird House

1 Pall Mall East

London SW1Y 5AU

 


Broker

Morgan Stanley

20 Bank Street

London E14 4AD

www.morganstanley.com

 


Auditor

Deloitte LLP

Chartered Accountants and Registered Auditor

2 New Street Square

London EC4A 3BZ

www.deloitte.com

 


Financial PR Advisers

Bell Pottinger

5th Floor

Holborn Gate

330 High Holborn

London

WC1V 7QD

www.bell-pottinger.co.uk

 


Registrars

Computershare Investor Services PLC

PO Box 82, The Pavilions

Bridgwater Road

Bristol BS99 7NH

www-uk.computershare.com


 

Legal Advisers

White & Case LLP

5 Old Broad Street

London EC2N 1DW

www.whitecase.com

 

 

 

 


This information is provided by RNS
The company news service from the London Stock Exchange
 
END
 
 
IMSDMGZKZRFGKZZ

Top of Page