Consolidated Half-Yearly Financial Results

RNS Number : 2232M
SEPLAT Petroleum Development Co PLC
27 July 2017
 
 

 

Seplat Petroleum Development Company Plc

Consolidated financial results for the period ended 30 June 2017

Lagos and London, 27 July 2017:  Seplat Petroleum Development Company Plc ("Seplat" or the "Company"), a leading Nigerian indigenous oil and gas company listed on both the Nigerian Stock Exchange and London Stock Exchange, today announces its consolidated half-yearly financial results for the period ended 30 June 2017 and provides an operational update.  Information contained within this release is un-audited and is subject to further review.   Details of the Webcast and conference call are set out on page 8 of this release.

 

Commenting on the results Austin Avuru, Seplat's Chief Executive Officer, said:

"Since the resumption of exports via the Forcados terminal our production has recovered strongly providing us with sufficient confidence to reinstate guidance, which we expect to be in the region of 43,000 to 50,000 boepd net to Seplat in the second half of the year.  After 18 difficult months, the Company is now well-placed to secure a long-term return to profitability and growth.  We have continued to cut costs, strengthen the balance sheet and establish alternative export routes to insure us against future disruption at Forcados.  I believe that we are now a fitter, stronger Company than at any time in our history and look to the future with renewed optimism. If the current operating environment continues, we expect to see a significant improvement in our performance."

Half-yearly results highlights

Return to Strong Production

·      Force majeure on exports from the Forcados terminal was subsequently lifted on 6 June.

·      After downtime, overall working interest production in H1 across all blocks stood at 9,507 bopd and 101.3 MMscfd, or 26,383 boepd. 

·      Guidance reinstated with working interest production in H2 after forecasted downtime expected to average 25,000 to 29,000 bopd and 110 to 130 MMscfd (43,000 to 50,000 boepd)

Multiple Export Routes

·      Upgrades and repairs now completed as planned on two jetties at the Warri refinery. The upgraded jetties will enable sustained exports of 30,000 bopd gross if required in the future

·      Completion of the 160,000 bopd Amukpe to Escravos pipeline prioritised by the Nigerian government and anticipated to be fully operational in Q1 2018.

Robust & Growing Gas Business

·      Gas revenues of US$54 million in H1 (41% of total H1 revenues and up 15% year-on-year)

·      Actively engaged with counterparties to finalise new GSA's - plan to take gross production towards 400 MMscfd

·      Proceeding towards FID at the large scale ANOH gas and condensate development at OML 53

Strengthen Balance Sheet

·      One year extension of revolving credit facility ("RCF"), 30% oversubscribed and successfully concluded in June

·      US$42 million debt principal repayments made in H1; gross debt at 30 June US$635 million and net debt US$433 million. Cash at bank at 30 June US$202 million and discretion maintained over spend (H1 capex US$11 million)

·      NPDC headline receivable at 30 June US$225 million (31 Dec 2016: US$239 million); net receivable US$215 million (31 Dec 2016: US$229 million) after adjusting for impairment.

Return to Operating Profit

·      27% year-on-year reduction in G&A helped drive return to operating profitability

·      Low cost production base (H1 production opex US$5.85/boe), diversification of oil export routes and growing contribution of the gas business positions Seplat on trajectory towards increased long term profitability

Financial overview

 

US$ million

 

billion

 

H1 2017

H1 2016

% change(1)

H1 2017

H1 2016

Revenue

132

153(4)

-14%

40

31

Gross Profit

54

69

-22%

16

15

Operating Profit/(Loss)

7

(42)

-116%

2

(10)

Profit / (loss) for the Period

(28)

(61)

-54%

(8)

(13)

Operating cash flow(2)

106

40

165%

32

8

Working interest production (boepd)

26,383

25,695

 3%

 

 

Average realised oil price (US$/bbl)(3)

45.0

45.8

-2%

 

 

Average realised gas price (US$/Mscf)

2.97

3.05

-3%

 

 

1) % change year-on-year calculated on US$ amounts; 2) Operating cash flow after movements in working capital; 3) Including sales in the period, stock in tank and hedging proceeds/costs (4) Net hedging fees reclassified to fair value movement

OPERATIONS REVIEW

Production for the first six months ended 30 June 2017

 

Gross

 

Working Interest

 

 

Liquids(1)

Gas

Oil equivalent

 

Liquids(1)

Gas

Oil equivalent

 

Seplat %

bopd

MMscfd

boepd

 

bopd

MMscfd

boepd

 

 

 

 

 

 

 

 

 

OMLs 4, 38 & 41

45.0%

16,748

225.0

54,250

 

7,536

101.3

24,413

OPL 283

40.0%

2,656

-

2,656

 

1,062

-

1,062

OML 53

40.0%

2,271

-

2,271

 

908

-

908

Total

 

21,675

225.0

59,177

 

9,507

101.3

26,383

(1)      Liquid production volumes as measured at the LACT unit for OMLs 4, 38 and 41 and OPL 283 flow station.  Volumes stated are subject to reconciliation and will differ from sales volumes within the period.

Average working interest production during the first six months was 26,383 boepd (compared to 25,695 boepd in 2016) and comprised 9,507 bopd liquids and 101.3 MMscfd gas.  These reported production figures reflect the longer than expected suspension of oil production after the terminal operator, Shell Nigeria, declared force majeure at the terminal from 21 February 2016 to 6 June 2017 following disruption in production and exports caused by a spill on the Forcados Terminal subsea crude export pipeline. Despite this, the Company achieved continuity of gas production to supply the domestic market, albeit at managed levels during the force majeure period owing to condensate handling constraints. The recommencement of oil and condensate injection into the Forcados system enabled Seplat to successfully reinstate gross production at OMLs 4, 38 and 41 to pre-Force Majeure working interest levels of around 56,000 boepd, being liquids of around 34,000 bopd and gas volumes of around 130 MMscfd.

In H1 2017, Seplat lifted and a monetised an equivalent of 0.5 MMbbls of oil from OML55, which resulted in a receipt of US$22.6 million.  The carrying value of the investment in the balance sheet was reduced from US$250.1 million to US$229 million and a profit of US$1.5 million was taken to the profit and loss in the period. 

Looking ahead, the Company is reinstating working interest production guidance (before reconciliation losses) for H2 2017 of 25,000 to 29,000 bopd and 110 to 130 MMscfd, which equates to 43,000 to 50,000 boepd.  On a full year 2017 basis, also taking into account H1 actual production, this translates to approximately 17,000 to 19,000 bopd and 105 to 115 MMscfd, or 35,000 to 38,000 boepd.  This guidance range is predicated on there being no further prolonged force majeure event and an overall assumed production uptime range of 75% to 85% during H2.

Proactive steps to secure alternative oil export routes

The Company's policy of creating multiple export routes for all of its assets, has resulted in actively pursuing alternative crude oil evacuation options for production at OMLs 4, 38 and 41 and potential strategies to further grow and diversify production in order to reduce any over-reliance on one particular third party operated export system.  In line with this objective, the Company has successfully completed repairs and upgrades on two jetties at the Warri refinery that will enable sustained exports of 30,000 bopd (gross) if required in the future.  Prior to the repair and upgrade work on the two jetties gross exports via the Warri refinery were around the 15,000 bopd level.  Exports via the Warri refinery jetty have incurred barging costs of around US$11/bbl but partially offsetting this, exports via this route are not subject to the reconciliation losses (typically in the order of 10% to 12%) or terminal crude handling and transport charges when exporting via the TFS. 

Longer term, the Amukpe to Escravos 160,000 bopd capacity pipeline is set to provide a third export option for liquids production at OMLs 4, 38 and 41.  Seplat has agreed with the pipeline owners, NAPIMS (a 100% subsidiary of NNPC) and Pan Ocean Corporation Limited, to a joint operating model.  An MOU was signed on 12 July 2017 with the pipeline operator Pan Ocean (and approved by NAPIMS) to work in partnership on completion of the pipeline, negotiation with the Escravos Terminal Operator - Chevron on crude handling and operation & maintenance of the pipeline going forward.

With line of sight on the availability of three independent export routes it is Seplat's ultimate intention to utilise all three to ensure there is adequate redundancy in evacuation routes, reducing downtime which has adversely affected the business over a number of years, significantly de-risking the distribution of production to market.  

Continued strong performance of the gas business with production and revenue upside in H2

Alongside its oil business, the Company has also prioritised the commercialisation and development of the substantial gas reserves and resources identified at its blocks and is today a leading supplier of gas to the domestic market in Nigeria.  The lifting of force majeure and resumption of full exports via the TFS has removed the condensate handling constraints and translated into an immediate uplift in gross gas production to around the 290 MMscfd level from a previously constrained level of 225 MMscfd.  Furthermore, having successfully completed and commissioned the Phase II expansion of the Oben gas processing plant earlier in the year, taking overall operated gas processing capacity to the 525 MMscfd level, the Company is actively engaged with counterparties to increase contracted gas sales with the intention of taking gross production towards the 400 MMscfd level.  Of the 525 MMscfd total processing capacity, 465 MMscfd is located at Oben with the remaining 60 MMscfd located at Sapele. The 375 MMscfd expansion at Oben (Phases I and II) was completed by Seplat as a 100% sole risk project.  The expansion of gas processing capacity is also designed to allow the Company to receive and tariff third party gas volumes in the future.  

The ANOH gas development at OML 53 (and adjacent OML 21 with which the upstream project is unitised) is expected to underpin the next phase of growth for the gas business and Seplat's involvement positions it at the heart of one of the largest greenfield gas and condensate developments onshore the Niger Delta to date. The Company is working with its partners to finalise a framework within which to progress the upstream and midstream elements of the project to FID in H2 2017.

Rig activity and other capital projects

Rig based activity year to date has been limited with just one rig deployed for a workover well in the Orogho field. The workover and re-completion of the Orogho-7 production well commenced in July and is expected to be completed in early August.  Upgrades to the liquid treatment infrastructure at OMLs 4,38 and 41 have also been made that will enable Seplat to inject export grade dry crude via alternative routes and at the same time eliminate crude handling charges that have historically been incurred on water in the wet crude injected into the TFS.  The Company continues to exercise discretion over spend and, having pulled back on expenditure during the extended period of force majeure, is selectively considering production drilling opportunities in the existing portfolio with a view to reinstating a work programme designed to capture the highest cash return production opportunities whilst diligently preserving a liquidity buffer.    

FINANCE REVIEW

Revenue

Gross revenue for H1 2017 was US$132 m illion ( 40 billion), a decrease of 14% compared to the same period in 2016 (H1 2016: US$153 million / 40 billion).  The suspension of exports at the Forcados terminal and consequently lower oil sales together with lower oil prices in the period have offset the year-on-year increase in gas production rates and step-up in gas revenues. 

Crude revenue (after stock movements) was US$77 million (N24 billion) for the first six months, a 27% decrease from the same period in 2016 (H1 2016: US$106 million / 22 billion).  Gas revenue for the period was US$54 million (17 billion), a 15% increase from the same period in 2016 (H1 2016: US$47 million / N10 billion).

During the first six months the Group realised an average oil price of US$45.0/bbl(1) (H1 2016: US$45.8/bbl), against an average price for Brent in the period of US$45.1/bbl (H1 2016: US$45.83/bbl), and an average gas price of US$2.97/Mscf (H1 2016: US$3.05/Mscf).  Working interest sales volume for the period increased slightly to 4.78 MMboe from 4.67 MMboe during the same period in 2016. Total gas volumes sold were 18.3 Bscf (H1 2016: 15.5 Bscf), while total liquid (crude and condensate) volumes lifted during the first six months were 1.72 MMbbls (H1 2016: 1.5 MMbbls).

Gross profit

Gross profit for the first six months was US$54 million (16 billion), a decrease of 22% compared to the same period in 2016 (H1 2016: US$69 million / 15 billion).  The movement is primarily driven by the reduction in oil revenues recorded in the period, partially offset by the higher gas revenues and lower cost of sales.

Direct operating costs decreased to US$28 million (9 billion) in the period (H1 2016: US$39 million / N8 billion), principally as a result of force majeure limiting production activities.  Rig related and other field expenses, which form part of direct operating costs decreased by 34% compared to the same period in 2016 at US$28 million (N6 billion) as a result of lower operation & maintenance costs.

Operating profit

Operating profit for the first six months was US$7 million (N2 billion), compared to an operating loss in the same period in 2016 (H1 2016: US$42 million / N10 billion). 

Partially offsetting the impact of lower gross revenues was a 27% year-on-year decrease in G&A expenses to US$36 million (N11 billion) during the first six months (H1 2016: US$50 million / N10 billion).

Tax

The Group did not recognise deferred income tax assets of US$235 million (2016: US$192 million) in respect of temporary differences amounting to US$357 million (2016: US$292 million). Out of this, deferred tax asset of US$71 million (2016: US$47 million) relates tax losses of US$109 million (2016: US$71 million). Taxation for the period was US$1.1 million (342 million).

Loss for the period

The Group loss after tax for the first six months was US$28 million (8 billion), compared to a loss in the same period in 2016 (H1 2016: US$61 million, 13 billion). Net finance charges stood at US$34 million ((10 billion) compared to US$16 million (3 billion) for the same period in 2016 principally as a result of interest accruable on NPDC and NGC receivables recognised as finance income in the prior period.

 

Cash flows from operating activities

Operating cash flow for the first six months was US$106 million (32 billion), up 165% compared to the same period in 2016 (H1 2016: US$40 million, 8 billion). 

The outstanding net NPDC receivable at period end, after offsetting NPDC's share of gas revenue, crude handling charges and adjusting for impairment stood at US$215 million (2016: US$229 million).  In accordance with the agreement signed in July 2015 with NPDC on terms for the payment of receivables due to Seplat, the Company has continued to withhold and offset gas revenues attributable to NPDC's 55% share of contracted gas sales. NPDC has agreed to pay current year US Dollar cash calls as they fall due and also make further payments for past receivables as well as continuing the arrangement whereby NPDC gas receipts are used to fund current year Naira cash calls as well as offsetting historical balances. 

Cash flows from investing activities

Net cash flows from investing activities were US$12 million (N3.6 billion), slightly up from US$9 million (N2.4 billion) during the same period in 2016.

Capital investments for the first six months amounted to US$11 million (N3 billion) and reflects the limited levels of operational activity owing to the extended shut-in of the Forcados terminal.  The vast majority of the Group's capital expenditures are discretionary and it has the flexibility to align spend with cash flow on a rolling basis. Committed capital expenditures for the rest of the year amount to US$20 million and relate to completion of the Oben booster compression project, construction activities at the Oben field logistics base and installation of a 20" Oben to NGC gas sales pipeline.  Also included is the drilling of the Anagba-1 appraisal well at OPL 283 and costs to progress the upstream and midstream elements of the ANOH project to FID.

Cash flows from financing activities

During the first six months loan repayments on the Company's seven year secured Term Loan amounted to US$16.5 million (5 billion) and repayments on its revolving credit facility ("RCF") amounted to US$25 million (8 billion).  Gross debt at period end was US$635 million (N194 billion).  Cash at bank at period end stood at US$202 million (62 billion) and net debt US$433 million (N132 billion).

Having re-profiled the seven-year Term Loan in Q3 2016 the Company announced on 3 July that it had successfully concluded an oversubscribed one year extension of the RCF.  The RCF, originally due to expire at the end of 2017, now expires on 31 December 2018 and has been successfully amended to amortise the remaining outstanding principal balance of US$150 million in equal instalments over five quarters commencing Q4 2017.  Overall, Seplat's aggregate indebtedness under its Term Loan and RCF has reduced by US$365 million from its peak in Q1 2015 of US$1 billion, which is a significant deleveraging of the balance sheet particularly in exceptionally difficult trading conditions over the past 18 months. 

Hedging

The Company had in place dated Brent puts covering a volume of 1.99 MMbbls over H1 2017 at a strike price of US$47.0/bbl resulting in a realised hedging loss of US$10 million in the period. Over H2 2017 the Company has in place dated Brent puts covering a volume of 1.70 MMbbls at a strike price of US$50.0/bbl. The board and management continue to closely monitor prevailing oil market dynamics, and will consider further measures to provide appropriate levels of cash flow assurance in times of oil price weakness and volatility. 

Principal risks and uncertainties

The Board of Directors is responsible for setting the overall risk management strategy of the Company and the determination of what level of risk is acceptable for Seplat to bear.  The principal risks and uncertainties facing Seplat at the year-end are detailed in the risk management section of the 2016 Annual Report and Accounts.  The board has identified the principal risks for the remainder of 2017 to be:

·      Third party infrastructure downtime and the corresponding impact on oil and gas production levels

·      Niger Delta stability and geo-political risk

·      Oil price volatility

·      Successful delivery of the planned work programme

 

 

Responsibility Statement

The Directors confirm that to the best of their knowledge:

a)       The condensed set of financial statements have been prepared in accordance with lAS 34 'Interim Financial Report';

b)       The interim management report  includes  a fair review  of  the information required  by UK DTR 4.2.7R indication  of  important  events during the first  six  months and  description  of  principal risks and uncertainties for the remaining six months of the year and 

c)       The interim management report includes a fair review of the information required by UK DTR 4.2.8R disclosure of related parties' transactions and changes therein.

 

The Directors of Seplat Plc are as listed in the Group's 2016 Annual Report and Accounts.  A list of current Directors is included on the company website: www.seplatpetroleum.com.

By order of the Board,

 

 

 

 

 

A. B. C. Orjiako

A. O. Avuru

R.T. Brown 

FRC/2013/IODN/00000003161

FRC/2013/IODN/00000003100

FRC/2014/IODN/00000007983

Chairman

Chief Executive Officer

Chief Financial Officer

27 July 2017

27 July 2017

27 July 2017

 

 

 

Important notice

The information contained within this announcement is deemed by the Company to constitute inside information as stipulated under the market Abuse Regulation. Upon the publication of this announcement via Regulatory Information Service, this inside information is now considered to be in the public domain.

Certain statements included in these results contain forward-looking information concerning Seplat's strategy, operations, financial performance or condition, outlook, growth opportunities or circumstances in the countries, sectors or markets in which Seplat operates. By their nature, forward-looking statements involve uncertainty because they depend on future circumstances, and relate to events, not all of which are within Seplat's control or can be predicted by Seplat. Although Seplat believes that the expectations and opinions reflected in such forward-looking statements are reasonable, no assurance can be given that such expectations and opinions will prove to have been correct. Actual results and market conditions could differ materially from those set out in the forward-looking statements. No part of these results constitutes, or shall be taken to constitute, an invitation or inducement to invest in Seplat or any other entity, and must not be relied upon in any way in connection with any investment decision. Seplat undertakes no obligation to update any forward-looking statements, whether as a result of new information, future events or otherwise, except to the extent legally required.

  

Ernst & Young

10th Floor, UBA House

57, Marina

Lagos, Nigeria 

Tel: +234 (01) 844 996 2/3

Fax: +234 (01) 463 0481

Email: services@ng.ey.com

www.ey.com

 

Report on review of interim condensed consolidated financial statements to the shareholders of Seplat Petroleum Development Company Plc

 

Introduction

We have reviewed the accompanying interim condensed consolidated financial statements of Seplat Petroleum Development Company Plc and its subsidiaries (the Group), which comprise the interim condensed consolidated statements of financial position at 30 June 2017 and profit or loss and other comprehensive income, changes in equity and cash flows for the half year then ended, and explanatory notes. The Company's directors are responsible for the preparation and fair presentation of these interim condensed consolidated financial statements in accordance with IAS 34 Interim Financial Reporting and in the manner required by the Companies and Allied Matters Act, CAP C20, Laws of the Federation of Nigeria 2004 and the Financial Reporting Council of Nigeria (FRCN) Act, No. 6, 2011. Our responsibility is to express a conclusion on these interim condensed consolidated financial statements based on our review.

Scope of Review

We conducted our review in accordance with International Standard on Review Engagements 2410, Review of Interim Financial Information Performed by the Independent Auditor of the Entity. 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 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 accompanying interim condensed consolidated financial statements are not prepared, in all material respects, in accordance with IAS 34.

 

 

Bernard Carrena, FCA

FRC/2013/ICAN/00000000670

For Ernst & Young

Lagos, Nigeria

 

27 July 2017

 

 

Webcast and conference call

At 10:00 am BST (London) / 10:00 am WAT (Lagos), Austin Avuru (CEO) and Roger Brown (CFO) will host a webcast and conference call to discuss the Company's results.

The webcast can be accessed via the Company's website http://seplatpetroleum.com/ or at the following address:

https://webconnect.webex.com/webconnect/onstage/g.php?MTID=e1dc4d6ca735b539340fecc960acf3f9b

To listen to the audio commentary only, participants can use the following telephone number:

Telephone Number (UK toll free): 0844 871 9434 or 0800 073 1340

Telephone number (international access): +44 (0) +44 (0) 1452 569393

Conference title: SEPLAT PETROLEUM DEVELOPMENT COMPANY - INTERIM RESULTS

Conference ID: 52989164

If you are listening to the audio commentary and viewing the webcast, you may notice a slight delay to the rate the slides change on the webcast.  If this is affecting you, please download the pdf slide pack from the Company's website http://seplatpetroleum.com/

Enquiries:

Seplat Petroleum Development Company Plc

 

Roger Brown, CFO

+44 203 725 6500

Andrew Dymond, Head of Investor Relations

 

Ayeesha Aliyu, Investor Relations

+234 1 277 0400

Chioma Nwachuku, GM - External Affairs and Communications

 

 

FTI Consulting

Ben Brewerton / Sara Powell

seplat@fticonsulting.com

+44 203 727 1000

Citigroup Global Markets Limited

Tom Reid / Luke Spells

 

+44 207 986 4000

Investec Bank plc

Chris Sim / George Price

 

+44 207 597 4000

 

Notes to editors

Seplat Petroleum Development Company Plc is a leading indigenous Nigerian oil and gas exploration and production company with a strategic focus on Nigeria, listed on the Main Market of the London Stock Exchange ("LSE") (LSE:SEPL) and Nigerian Stock Exchange ("NSE") (NSE:SEPLAT).

Seplat is pursuing a Nigeria focused growth strategy and is well-positioned to participate in future divestment programmes by the international oil companies, farm-in opportunities and future licensing rounds.  For further information please refer to the Company website, http://seplatpetroleum.com/

  
 

 

Interim condensed consolidated statement of profit or loss and other comprehensive income

for the half year ended 30 June 2017

 

 

Half year ended

30 June 2017

Half year ended

30 June 2016

3 months ended
30 June 2017

3 months ended

30 June 2016

 

 

Unaudited

Unaudited

Unaudited

Unaudited

 

Note

₦'m

₦'m

₦'m

₦'m

Revenue

7

 40,317

 31,576

            25,843

14,991

Cost of sales

8

 (23,914)

   (16,854)

           (15,290)

(6,162)

Gross profit

 

 16,403

 14,722

            10,553

 8,829

General and administrative expenses

9

 (11,108)

(10,333)

             (5,979)

 (6,069)

Loss on foreign exchange - net

10

(264)

(6,382)

(793)

 (5,897)

Fair value loss

11

 (2,817)

(7,573)

              (1,155)

 (7,414)

Operating profit/(loss)

 

 2,214

 (9,566)

2,626

(10,551)

Finance income

12

              270

5,694

                206

5,270

Finance costs                      

12

        (10,574)

 (8,321)

             (5,317)

(3,933)

Loss before taxation

 

(8,090)

(12,193)

(2,485)

(9,214)

Taxation

13

 (342)

(615)

                 (92)

886

Loss for the period

 

(8,432)

(12,808)

(2,577)

(8,328)

 

 

 

 

 

 

Loss attributable to equity holders of parent

 

(8,432)

(13,081)

(2,577)

(9,340)

Profit attributable to non-controlling interest

 

-

273

-

1,012

 

 

 

 

 

 

Other comprehensive income/(loss):

 

 

 

 

 

Items that may be reclassified to profit or loss:

 

 

 

 

 

Foreign currency translation difference

 

1,049

113,254

(1,403)

113,784

 

 

 

 

 

 

Total comprehensive (loss)/income for the period

 

(7,383)

100,446

(3,980)

105,456

 

 

 

 

 

 

(Loss)/profit attributable to equity holders of parent

 

(7,383)

98,436

(3,980)

102,707

Profit attributable to non-controlling interest

 

-

2,010

-

2,749

 

 

 

 

 

 

Loss per share ()

14

(14.97)

(23.33)

(4.57)

(16.66)

Diluted loss per share()

14

(14.83)

(23.24)

(4.53)

(16.60)

 

 

 

Interim condensed consolidated statement of financial position

As at 30 June 2017

 

 

As at 30 June 2017

As at 31 Dec 2016 

 

 

Unaudited

Audited

 

Note

₦'m

₦'m

Assets

 

 

 

Non-current assets

 

 

 

Oil and gas properties

 

        369,046

 373,442

Other property, plant and equipment

 

           1,809

 2,430

Other asset

17

          70,040

 76,277

Prepayments

 

 9,672

 10,253

Total non-current assets                          

 

450,567

 462,402

Current assets

 

 

 

Inventories

 

          31,229

 32,395

Trade and other receivables

18

132,520

 119,160

Prepayments

 

              983

 2,035

Cash & cash equivalents

 

          61,631

 48,684

Total current assets

 

226,363

 202,274

Total assets

 

676,930

 664,676

Equity and liabilities

 

 

 

Equity

 

 

 

Issued share capital

19

              283

 283

Share premium

 

          82,080

 82,080

Share based payment reserve

19

           3,415

 2,597

Capital contribution

 

           5,932

 5,932

Retained earnings

 

76,620

 85,052

Foreign currency translation reserve

 

        201,478

 200,429

Total equity

 

369,808

 376,373

Non-current liabilities

 

 

 

Interest bearing loans & borrowings

16

        133,163

 136,060

Deferred tax liabilities

 

                23

 -  

Contingent consideration

23

           3,957

 3,672

Provision for decommissioning obligation

 

              197

 182

Defined benefit plan                 

 

           1,905

 1,559

Total non-current liabilities

 

        139,245

 141,473

Current liabilities

 

 

 

Interest bearing loans and borrowings

16

          57,867

 66,489

Trade and other payables

20

        109,114

 79,766

Current taxation

 

896

 575

Total current liabilities

 

        167,877

 146,830

Total liabilities

 

        307,122

 288,303

Total shareholders' equity and liabilities

 

676,930

 664,676

 

                                                                                            

Interim condensed consolidated statement of financial position continued

As at 30 June 2017

The financial statements on pages 10 to 32 were approved and authorised for issue by the board of directors on 20 July 2017 and were signed on its behalf by

 

 

 

 

 

A. B. C. Orjiako

A. O. Avuru

R.T. Brown 

FRC/2013/IODN/00000003161

FRC/2013/IODN/00000003100

FRC/2014/IODN/00000007983

Chairman

Chief Executive Officer

Chief Financial Officer

27 July 2017

 

27 July 2017

 

27 July 2017

 

 

 

Interim condensed consolidated statement of changes in equity continued

for the half year ended 30 June 2017

for the half year ended 30 June 2016

 

 

 

 

 

 

 

Issued share

capital

Share premium

Capital contribution

Share based

payment reserve

Foreign currency translation reserve

Retained earnings

Total

Non-controlling interest

Total

equity   

 

₦'m

₦'m

₦'m

₦'m

₦'m

₦'m

₦'m

₦'m

₦'m

 

 

 

 

 

 

 

 

 

 

At 1 January 2016

282

82,080

5,932

1,729

56,182

134,919

281,124

(148)

280,976

(Loss)/Profit for the period

-

-

-

-

-

(13,081)

(13,081)

273

(12,808)

Other comprehensive income

-

-

-

 

111,517

-

111,517

1,737

113,254

Total comprehensive loss for the period

-

-

-

-

111,517

(13,081)

98,436

 2,010

100,446

Transactions with owners in their capacity as owners:

 

 

 

 

 

 

 

 

 

Share based payments

-

-

-

375

-

-

375

-

375

Dividends

-

-

-

-

-

(5,118)

(5,118)

 

(5,118)

Total

-

-

-

375

-

(5,118)

(4,743)

-

(4,743)

At 30 June 2016 (unaudited)

282

82,080

5,932

2,104

167,699

116,720

374,817

1,862

376,679

 

 

for the half year ended 30 June 2017

 

Issued share

capital

Share premium

Capital contribution

Share based

payment reserve

Foreign currency translation reserve

Retained earnings

Total

Non-controlling interest

Total

equity   

 

₦'m

₦'m

₦'m

₦'m

₦'m

₦'m

₦'m

₦'m

₦'m

At 1 January 2017

         283

        82,080

           5,932

      2,597

      200,429

     85,052

     376,373

              -  

     376,373

Loss for the period

 -  

 -  

 -  

 -  

 -  

(8,432)

(8,432)

              -  

(8,432)

Other comprehensive income

 -  

 -  

 -  

 -  

        1,049

-

     1,049

-

     1,049

Total comprehensive loss for the period

 -  

 -  

 -  

 -  

 1,049

(8,432)

(7,383)

 -  

(7,383)

Transactions with owners in their capacity as owners:

 -  

 -  

 -  

 -  

 -  

 -  

 -  

 -  

 -  

Share based payments

 -  

 -  

 -  

818

 -  

 -  

818

 -  

818

Dividends

 -  

 -  

 -  

 -  

 -  

 -  

 -  

 -  

 -  

Total

 -  

 -  

 -  

818  

 -  

 -  

818

 -  

818

At 30 June 2017 (unaudited)

 283

 82,080

 5,932

 3,415

 201,478

76,620

369,808

 -  

369,808

 

 

 

 

 

 

 

 

 

 

                     

 

 

 

Interim condensed consolidated statement of cash flow

for the half year ended 30 June 2017

 

Half year ended
30 June 2017

Half year ended
 30 June 2016

 

₦'m

₦'m

                                                                                                            Note

Unaudited

Unaudited

Cash flows from operating activities

 

 

Cash generated from operations                                                              21                                 

          32,492

             8,287

Net cash inflows from operating activities

          32,492

             8,287

Cash flows from investing activities

 

 

Acquisition of oil and gas properties

            (3,424)

            (3,091)

Acquisition of other property, plant and equipment

               (118)

              (246)

Receipts from other asset                                                                        17

6,914

-

Interest received

270

5,694

Net cash inflows from investing activities

            3,642

             2,357

Cash flows from financing activities

-

 

Repayments of bank financing

(12,693)

(24,201)

Dividends paid

-

(5,118)

Interest paid

          (10,560)

(8,298)

Net cash outflows from financing activities

          (23,253)

(37,617)

Net decrease in cash and cash equivalents

           12,881

(26,973)

Cash and cash equivalents at beginning of period

48,684

64,828

Effects of exchange rate changes on cash and cash equivalents

           66

(13,028)

Cash and cash equivalents at end of period

           61,631

24,827

 

 

 

 

 

 

 

 

 

 

 

Notes to the interim condensed consolidated financial statements

 

1.    Corporate structure and business

Seplat Petroleum Development Company Plc ('Seplat' or the 'Company'), the parent of the Group, was incorporated on 17 June 2009 as a private limited liability company and re-registered as a public company on 3 October 2014, under the Companies and Allied Matters Act, CAP C20, Laws of the Federation of Nigeria 2004. The Company commenced operations on 1 August 2010. The Company is principally engaged in oil and gas exploration and production.

 

The Company's registered address is: 25a Lugard Avenue, Ikoyi, Lagos, Nigeria.

 

The Company acquired, pursuant to an agreement for assignment dated 31 January 2010 between the Company, SPDC,

TOTAL and AGIP, a 45% participating interest in the following producing assets:

 

OML 4, OML 38 and OML 41 located in Nigeria. The total purchase price for these assets was US$340 million paid at the completion of the acquisition on 31 July 2010 and a contingent payment of US$33 million payable 30 days after the second anniversary, 31 July 2012, if the average price per barrel of Brent Crude oil over the period from acquisition up to 31 July 2012 exceeds US$80 per barrel. US$358.6 million was allocated to the producing assets including US$18.6 million as the fair value of the contingent consideration as calculated on acquisition date. The contingent consideration of US$33 million was paid on 22 October 2012.

 

In 2013, Newton Energy Limited (''Newton Energy''), an entity previously beneficially owned by the same shareholders as Seplat, became a subsidiary of the Company. On 1 June 2013, Newton Energy acquired from Pillar Oil Limited (''Pillar Oil'') a 40 percent Participant interest in producing assets: the Umuseti/Igbuku marginal field area located within OPL 283 (the ''Umuseti/Igbuku Fields'').

 

On 27 March 2013, Seplat Energy Limited ("Seplat Energy") was incorporated. The principal activities of the Company is the exploration, development and transportation of petroleum products and Seplat Gas Company Limited ("Seplat Gas") was incorporated on 9 December 2013 as a private limited liability company to engage in oil and gas exploration and production.

 

In 2015, the Group purchased a 40% participating interest in OML 53, onshore north eastern Niger Delta, from Chevron Nigeria Ltd for US$259.4 million.

 

In 2017, the Group incorporated a new subsidiary, ANOH Gas Processing Company Limited. The principal activities of the Company is the processing of gas from OML 53.

 

The Company together with its subsidiary, Newton Energy, and six wholly owned subsidiaries, namely, Seplat

Petroleum Development Company UK Limited ('Seplat UK'), which was incorporated on 21 August 2014, Seplat East

Onshore Limited ('Seplat East'), which was incorporated on 12 December 2014, Seplat East Swamp Company Limited

('Seplat Swamp'), which was incorporated on 12 December 2014, Seplat Gas Company Limited ('Seplat GAS'), which was incorporated on 12 December 2014, Seplat Energy Limited ('Seplat Energy'), which was incorporated on 27 March 2013 and ANOH Gas Processing Company Limited which was incorporated on 18 January 2017 are collectively referred to as the Group.

 

 

Subsidiary

Country of incorporation and place of business

Shareholding %

Principal activities

Newton Energy Limited

Nigeria

100%

Oil & gas exploration and production

Seplat Petroleum Development UK

United Kingdom

100%

Oil & gas exploration and production

Seplat East Onshore Limited

Nigeria

100%

Oil & gas exploration and production

Seplat East Swamp Company Limited

Nigeria

100%

Oil & gas exploration and production

Seplat Gas Company

Nigeria

100%

Oil & gas exploration and production

Seplat Energy Limited

Nigeria

100%

Oil & gas exploration and production

ANOH Gas Processing Company Limited

Nigeria

100%

Gas processing

 

 

 

Notes to the interim condensed consolidated financial statements continued

2.    Significant changes in the current reporting period

During the reporting period ended 30 June 2017, the Group renegotiated its lending arrangements resulting in a twelve month extension of its revolving credit facility till 31 December 2018. The Group also significantly increased its production volumes as a result of the lift in the force majeure which had in the previous financial year restricted exports from the Forcados terminal. The Group plans to open up other export lines to ensure sustained growth in production volumes.

 

Resumption of exports via the Forcados terminal, has strengthened the Group's financial performance and position during the period ended 30 June 2017.

 

3.    Summary of significant accounting policies

3.1   Introduction to summary of significant accounting policies

 

The accounting policies adopted are consistent with those of the previous financial year and corresponding interim reporting period, except for the adoption of new and amended standards which are set out below.

 

3.2   Basis of preparation

 

i)        Compliance with IFRS

 

The interim condensed consolidated financial statements of the Group for the half year reporting period ended 30 June 2017 have been prepared in accordance with accounting standard IAS 34 Interim financial reporting.

 

ii)       Historical cost convention

 

The financial information has been prepared under the going concern assumption and historical cost convention, except for contingent consideration, other asset and financial instruments on initial recognition measured at fair value. The historical financial information is presented in Nigerian Naira and all values are rounded to the nearest million ('m) except when otherwise indicated. The accounting policies are applicable to both the Company and Group.

 

iii)      Going concern

 

Nothing has come to the attention of the directors to indicate that the Company will not remain a going concern for at least twelve months from the date of these financial statements.

iv)      New and amended standards adopted by the Group

 

There were a number of new standards and amendments to standards that are effective for annual periods beginning after 1 January 2017; the Group has adopted these new or amended standards in preparing the interim condensed consolidated financial statements. The nature and impact of the new standards and amendments to the standards are described below.

 

Other than the changes described below, the accounting policies adopted are consistent with those of the previous financial year.

 

a)      Disclosure initiative - Amendments to IAS 7

 

The Group is now required to explain changes in their liabilities arising from financing activities. This includes changes arising from cash flows (e.g. drawdowns and repayments of borrowings) and non-cash changes such as acquisitions, disposals, accretion of interest and unrealised exchange differences.

 

Changes in financial assets are included in this disclosure if the cash flows were, or are, included in cash flows from financing activities. This is the case, for example, for assets that hedge liabilities arising from financing liabilities.

 

The Group may include changes in other items as part of this disclosure, for example by providing a 'net debt' reconciliation. However, in this case the changes in the other items are disclosed separately from the changes in liabilities arising from financing activities.

 

Notes to the interim condensed consolidated financial statements continued

 

The Group discloses this information in tabular format as a reconciliation from opening and closing balances, but may adopt a different format as the standard does not mandate a specific format.

 

The Group discloses this information in Note 16.

 

v)     New standards, amendments and interpretations not yet adopted

       

The Group has the following updates to information provided in the last annual financial statements about the standards issued but not yet effective that may have a significant impact on the Group's consolidated financial statements.

         

a.      Amendments to IFRS 2 Share-based payments

 

In June 2016, the IASB made amendments to IFRS 2 Share-based payments which clarified the effect of vesting conditions on the measurement of cash-settled share-based payment transactions, the classification of share-based payment transactions with net settlement features and the accounting for a modification of the terms and conditions that changes the classification of the transaction from cash-settled to equity-settled.

 

The amendments are effective for reporting periods beginning on or after 1 January 2018. The Group will adopt the amendments from 1 January 2018.

 

b.      IFRS 9 Financial Instruments

 

IFRS 9 Financial instruments addresses the classification, measurement and de-recognition of financial assets and financial liabilities, the standard introduces new rules for hedge accounting and a new impairment model for financial assets. The Group has decided not to adopt IFRS 9 until it becomes mandatory on 1 January 2018.

 

The Group is undergoing a detailed assessment of the impact of the new standard on the classification and measurement of its financial assets. From the preliminary results, the Group does not expect the new guidance to have a significant impact on the classification and measurement of its financial assets for the following reason:

 

·  All of the Group's financial assets are currently classified as loans and receivables and are measured at amortised cost and will satisfy the conditions for classification at amortised cost under IFRS 9.

 

There will be no impact on the Group's accounting for financial liabilities, as the new requirements only affect accounting for financial liabilities that are designated at fair value through profit or loss and the Group does not have such liabilities. The de-recognition rules have been transferred from IAS 39 Financial Instruments: Recognition and Measurement and have not been changed. The new hedge accounting rules will align the accounting for hedging instruments more closely with the Group's risk management practices. As a general rule, more hedge relationships might be eligible for hedge accounting, as the standard introduces a more principles-based approach. The Group does not expect a significant impact on the accounting for its hedging relationships as a result of the adoption of IFRS 9, as they have not formally elected to apply hedge accounting.

 

The new impairment model requires the recognition of impairment provisions based on expected credit losses (ECL) rather than only incurred credit losses as is the case under IAS 39. It applies to financial assets classified at amortised cost, debt instruments measured at fair value through OCI (FVOCI), contract assets under IFRS 15: Revenue from Contracts with Customers and lease receivables. Based on assessments undertaken on the Group's portfolio of NPDC receivables, it estimates that should the new rules had been adopted as at 1 January 2017, there would have been an increase to its loss allowance for NPDC receivables of approximately N1.2 billion (US$4 million) at that date and retained earnings would decrease by the same amount.

 

The new standard also introduces expanded disclosure requirements and changes in presentation. These are expected to change the nature and extent of the Group's disclosures about its financial instruments particularly in the year of the adoption of the new standard.

 

c.      IFRS 15 Revenue from contracts with customers

 

The IASB has issued a new standard for the recognition of revenue. This will replace IAS 18 which covers revenue arising from the sale of goods and the rendering of services and IAS 11 which covers construction contracts.

 

The new standard is based on the principle that revenue is recognised when control of a good or service transfers to a customer.

 

 

 

Notes to the interim condensed consolidated financial statements continued

 

The standard permits either a full retrospective or a modified retrospective approach for the adoption. The new standard is effective for first interim periods within annual reporting periods beginning on or after 1 January 2018. The Group will adopt the new standard from 1 January 2018.

 

Management identified the following areas that are likely to be affected:

 

·      Accounting for under lifts and over lifts: IFRS 15 is applicable only if the counterparty to the contract is a customer. The standard defines a customer as a party that has contracted with an entity to obtain goods or services that are an output of the entity's ordinary activities. IFRS 15 makes a distinction between customers and partners or collaborators who share in the risks and benefits that result from the activity or process. If the over-lifter does not meet the definition of a customer or the transaction is a non-monetary exchange, then over lifts and under lifts will not be recognised as revenue from contracts with customers. If the Group were to adopt the new rules as at 1 January 2017, it estimates that revenue would have reduced by N5 billion (US$16 million) and other operating income would have increased by the same amount.

 

·      Accounting for consideration payable to the customer: The standard requires that an entity accounts for consideration payable to a customer as a reduction of the transaction price and, therefore, net of revenue unless the payment to the customer is in exchange for a distinct good or service that the customer transfers to the entity. The Group incurs barging costs in the course of the satisfaction of its performance obligations i.e. delivery of crude oil and gas. These costs do not transfer any distinct good or service to Seplat and as such represent consideration payable to customer and will be accounted for as a direct deduction from revenue. If the Group had adopted the new rules as at 1 January 2017, revenue would have reduced by an additional N5.5 billion (US$18 million) as a result of barging costs.

 

·      Presentation of contract assets and contract liabilities in the balance sheet - IFRS 15 requires separate presentation of contract assets and contract liabilities in the balance sheet. This will result in some reclassifications as of 1 January 2018 in relation to advances for future oil sales which are currently included in deferred revenue.

 

·      Other likely areas of impact are in relation to advances for future oil sales that may have a significant financing component and variable consideration arising from gas pricing based on an index as well as optional pricing on crude oil sold to customers.

 

d.      IFRS 16 Leases

 

IFRS 16 was issued in January 2016. It will result in almost all leases being recognised on the balance sheet, as the distinction between operating and finance leases is removed. Under the new standard, an asset (the right to use the leased item) and a financial liability to pay rentals are recognised. The only exceptions are short-term and low-value leases. The accounting for lessors will not significantly change.

 

The standard will affect primarily the accounting for the Group's operating leases. As at the reporting date, the Group has non-cancellable operating lease commitments of N119 million (US$ 0.39 million). However, the Group has not yet determined to what extent these commitments will result in the recognition of an asset and a liability for future payments and how this will affect the Group's profit and classification of cash flows.

 

Some of the commitments may be covered by the exception for short-term leases, while none of the leases will be covered by the exception for low value leases. Some commitments may relate to arrangements that will not qualify as leases under IFRS 16, principally because they are service contracts.

 

The standard is mandatory for first interim periods within annual reporting periods beginning on or after 1 January 2019. At this stage, the Group does not intend to adopt the standard before its effective date.

 

3.3   Basis of consolidation

 

The consolidated financial statements comprise the financial statements of the Company and its subsidiaries as at 30 June 2017.

 

This basis is the same adopted for the last audited financial statements as at 31 December 2016.

3.4   Functional and presentation currency

The Group's financial statements are presented in United States Dollars, which is also the Company's functional currency. For each entity the Group determines the functional currency and items included in the financial statements of each entity are measured using that functional currency.

Notes to the interim condensed consolidated financial statements continued

 

i)      Transactions and balances

 

Foreign currency transactions are translated into the functional currency using the exchange rates prevailing at the dates of the transactions. Foreign exchange gains and losses resulting from the settlement of such transactions and from the translation of monetary assets and liabilities denominated in foreign currencies at year end exchange rates are generally recognised in profit or loss. Foreign exchange gains and losses that relate to borrowings are presented in the statement of profit or loss, within finance costs. All other foreign exchange gains and losses are presented in the statement of profit or loss on a net basis within other income or other expenses.

Non-monetary items that are measured at fair value in a foreign currency are translated using the exchange rates at the date when the fair value was determined. Translation differences on assets and liabilities carried at fair value are reported as part of the fair value gain or loss.

ii)      Group companies

 

The results and financial position of foreign operations that have a functional currency different from the presentation currency are translated into the presentation currency as follows:

·      assets and liabilities for each balance sheet presented are translated at the closing rate at the date of the balance sheet

·      income and expenses for each statement of profit or loss and statement of comprehensive income are translated at average exchange rates (unless this is not a reasonable approximation of the cumulative effect of the rates prevailing on the transaction dates, in which case income and expenses are translated at the dates of the transactions), and

·      all resulting exchange differences are recognised in other comprehensive income.

On disposal of a foreign operation, the component of other comprehensive income relating to that particular foreign operation is recognised in profit or loss.

4.    Segment reporting

 

Segment reporting has not been prepared as the Group operates one segment, being the exploration, development and production of oil and gas related products located in Nigeria. Operations in the different OMLs are integrated due to geographic proximity, the use of shared infrastructure and common operational management.

5.    Significant accounting judgements, estimates and assumptions

5.1    Judgements

 

Management's judgements at the end of the half year are consistent with those disclosed in the recent 2016 Annual financial statements. The following are some of the judgements which have the most significant effect on the amounts recognised in this consolidated financial statements.

 

i)        OMLs 4, 38 and 41

 

OMLs 4, 38, 41 are grouped together as a cash generating unit for the purpose of impairment testing. These three

OMLs are grouped together because they each do not independently generate cash flows. They currently operate as a single block sharing resources for the purpose of generating cash flows. Crude oil and gas sold to third parties from these OMLs are invoiced together.

 

ii)       Advances on investment (note 18)

 

The Group considers that the advances on investment of ₦20 million (2016: 20 million) in relation to the acquisition of additional assets is fully recoverable in accordance with the terms of the deposit.

 

 

Notes to the interim condensed consolidated financial statements continued

 

5.2   Estimates and assumptions

 

The key assumptions concerning the future and other key sources of estimation uncertainty that have a significant risk of causing a material adjustment to the carrying amount of assets and liabilities are disclosed in the most recent 2016 annual financial statements.

 

The following are some of the estimates and assumptions made.

 

i)        Impairment of financial assets

 

The Group assesses at each reporting date whether there is objective evidence that a financial asset or a group of financial assets is impaired. A financial asset or a group of financial assets is deemed to be impaired if there is objective evidence of impairment as a result of one or more events that has occurred since the initial recognition of the asset (an incurred loss event) and that loss event has an impact on the estimated future cash flows of the financial asset or the group of financial assets that can be reliably estimated. Evidence of impairment may include indications that the debtor or a group of debtors is experiencing significant financial difficulty, default or delinquency in interest or principal payments, the probability that they will enter bankruptcy or other financial reorganisation and observable data indicating that there is a measurable decrease in the estimated future cash flows, such as changes in arrears or economic conditions that correlate with defaults.

 

Management has made certain assumptions about the recoverability of financial assets exposed to credit risk from NPDC. These are based on management's past experiences with NPDC, current discussions with NPDC and financial capacity of NPDC. However, wherever these assumptions do not hold, it might have a significant impact on the Group's profit or loss in future.

 

ii)       Defined benefit plans

 

The cost of the defined benefit retirement plan and the present value of the retirement obligation are determined at the end of the financial year using actuarial valuations. An actuarial valuation involves making various assumptions that may differ from actual developments in the future. These include the determination of the discount rate, future salary increases, mortality rates and changes in inflation rates. Service and interest costs are recognised at each reporting period based on an estimate of the periodic benefit expense for the financial year.

 

The defined benefit obligation recognised in this period has been based on the same assumptions as in the previous financial year The subsequent financial year end balance was estimated as at 31 December 2016 and has been recognised in this half year period on a pro rata basis. Therefore, no actuarial gains or losses have been recognised given that last year's assumptions have been adopted.

 

iii)      Contingent consideration

 

The fair value of the contingent consideration arrangement of N4 billion (US$12.9 million) was estimated calculating the present value of the future expected cash flows. The estimates are based on a discount rate of 15.45%. Refer to note 23 for further details.

 

6.    Financial risk management

6.1    Financial risk factors

 

The Group's activities expose it to a variety of financial risks such as market risk (including foreign exchange risk, interest rate risk and commodity price risk), credit risk and liquidity risk. The Group's risk management programme focuses on the unpredictability of financial markets and seeks to minimise potential adverse effects on the Group's financial performance.

Risk management is carried out by the treasury department under policies approved by the Board of Directors. The Board provides written principles for overall risk management, as well as written policies covering specific areas, such as foreign exchange risk, interest rate risk, credit risk and investment of excess liquidity.

 

 

Notes to the interim condensed consolidated financial statements continued

 

Risk

Exposure arising from

Measurement

Management

Market risk - foreign exchange

Future commercial transactions

Recognised financial assets and liabilities not denominated in US dollars.

Cash flow forecasting

Sensitivity analysis

Match and settle foreign denominated cash inflows with foreign denominated cash outflows.

Market risk - interest rate

Long term borrowings at variable rate

Sensitivity analysis

None

Market risk - commodity  prices

Future sales transactions

 

Sensitivity analysis

Oil price hedges

Credit risk

Cash and cash equivalents, trade receivables and derivative financial instruments.

Aging analysis

Credit ratings

Diversification of bank deposits.

Liquidity risk

Borrowings and other liabilities

Rolling cash flow forecasts

Availability of committed credit lines and borrowing facilities

 

6.1.1  Liquidity risk

 

Liquidity risk is the risk that the Group will not be able to meet its financial obligations as they fall due.

 

The Group manages liquidity risk by ensuring that sufficient funds are available to meet its commitments as they fall due.

The Group uses both long-term and short-term cash flow projections to monitor funding requirements for activities and to ensure there are sufficient cash resources to meet operational needs. Cash flow projections take into consideration the Group's debt financing plans and covenant compliance. Surplus cash held is transferred to the treasury department which invests in interest bearing current accounts, time deposits and money market deposits.

         The following table details the Group's remaining contractual maturity for its non-derivative financial liabilities with agreed maturity periods. The table has been drawn based on the undiscounted cash flows of the financial liabilities based on the earliest date on which the Group can be required to pay.

 

 

 

 

Notes to the interim condensed consolidated financial statements continued

 

 

Variable rate

  Less than 1 year

1 -2

years

2 - 3

years

 3 - 5

years

After
5 years

Total

 

%

₦'m

₦'m

₦'m

₦'m

₦'m

₦'m

30 June 2017

 

 

 

 

 

 

 

Non - derivatives

 

 

 

 

 

 

 

Variable interest rate borrowings (bank loans):

 

 

 

 

 

 

 

Allan Gray

8.5%+LIBOR

 1,324

 1,631

 1,500

 929

-

5,384

Zenith Bank Plc

8.5%+LIBOR

 18,141

 22,352

 20,554

 12,734

-

73,781

First Bank of Nigeria

8.5%+LIBOR

 10,015

 12,339

 11,346

 7,030

-

40,730

United Bank of Africa Plc

8.5%+LIBOR

 11,338

 13,970

 12,846

 7,959

-

46,113

Stanbic IBTC Bank Plc

8.5%+LIBOR

 1,699

 2,094

 1,925

 1,193

-

 6,911

The Standard Bank of South Africa Limited

8.5%+LIBOR

 1,699

 2,094

 1,925

 1,193

-

 6,911

Standard Chartered Bank

6.0%+LIBOR

 4,545

 2,826

-

-

-

 7,371

Natixis

6.0%+LIBOR

 4,545

 2,826

-

-

-

 7,371

Citibank Nigeria Limited and Citibank N.A.

6.0%+LIBOR

 3,535

 2,198

-

-

-

5,733

First Rand Bank (Merchant Bank Division)

6.0%+LIBOR

 3,030

 1,884

-

-

-

4,914

Nomura International Plc.

6.0%+LIBOR

 3,030

 1,884

-

-

-

4,914

Ned Bank Ltd London Branch

6.0%+LIBOR

 3,030

 1,884

-

-

-

4,914

The Mauritius Commercial Bank Plc

6.0%+LIBOR

 3,030

 1,884

-

-

-

4,914

Stanbic IBTC Bank Plc

6.0%+LIBOR

 2,272

 1,413

-

-

-

 3,685

The Standard Bank of South Africa Limited

6.0%+LIBOR

 3,283

 2,041

-

-

-

 5,324

Other non-derivatives

 

 

 

 

 

 

 

Trade and other payables

 

47,677

-

-

-

-

47,677

Contingent consideration

 

-

-

5,643

-

-

5,643

 

 

 122,193

 73,320

 55,739

 31,038

-

282,290

 

 

 

 

 

 

 

 

 

Notes to the interim condensed consolidated financial statements continued

 

 

 

 

Variable rate

Less than
1 year

1 - 2
year

2 - 3
years

3 - 5
years

After
5 years

Total

 

%

₦'m

₦'m

₦'m

₦'m

₦'m

₦'m

31 December 2016

 

 

 

 

 

 

 

Non - derivatives

 

 

 

 

 

 

 

Variable interest rate borrowings (bank loans):

 

 

 

 

 

 

 

Zenith Bank Plc

8.5% + LIBOR

 11,409

 23,182

 21,383

 22,715

 -  

 78,689

First Bank of Nigeria Limited

8.5% + LIBOR

 7,131

 14,489

 13,364

 14,197

 -  

 49,181

United Bank for Africa Plc

8.5% + LIBOR

 7,131

 14,489

 13,364

 14,197

 -  

 49,181

Stanbic IBTC Bank Plc

8.5% + LIBOR

 1,069

 2,171

 2,003

 2,128

 -  

 7,371

The Standard Bank of South Africa Limited

8.5% + LIBOR

 1,069

 2,171

 2,003

 2,128

 -  

 7,371

Standard Chartered Bank

8.5% + LIBOR

 8,452

 -  

 -  

 -  

 -  

 8,452

Natixis

6.00% + LIBOR

 8,452

 -  

 -  

 -  

 -  

 8,452

Citibank Nigeria Ltd and Citibank NA

6.00% + LIBOR

 8,452

 -  

 -  

 -  

 -  

 8,452

Bank of America Merrill Lynch Int'l Ltd

6.00% + LIBOR

 5,635

 -  

 -  

 -  

 -  

 5,635

FirstRand Bank Ltd (Rand Merchant Bank Division)

6.00% + LIBOR

 5,635

 -  

 -  

 -  

 -  

 5,635

JP Morgan Chase Bank NA, London Branch

6.00% + LIBOR

 5,635

 -  

 -  

 -  

 -  

 5,635

NedBank Ltd, London Branch

6.00% + LIBOR

 5,635

 -  

 -  

 -  

 -  

 5,635

Stanbic IBTC Bank Plc

6.00% + LIBOR

 4,225

 -  

 -  

 -  

 -  

 4,225

The Standard Bank of South Africa Ltd

6.00% + LIBOR

 4,225

 -  

 -  

 -  

 -  

 4,225

Other non - derivatives

 

 

 

 

 

 

 

Trade and other payables

 

 49,341

 -  

 -  

 -  

 -  

49,341

Contingent consideration

 

 -  

 -  

 -  

 5,643

 -  

 5,643

 

 

  133,496

 56,502

 52,117

 61,008

 -  

 303,123

6.2   Fair value measurements

Financial instruments measured at fair value were based on the same assumptions as determined in the 31 December 2016 financial statements. The judgements and estimates made by the Group in determining the fair values of the financial instruments have remained the same since the last annual financial report. There were no transfers of financial instruments between fair value hierarchy levels during this half year.  

7.    Revenue

 

Half year ended

30 June 2017

Half year ended

30 June 2016

3 months ended

30 June 2017

3 months ended

30 June 2016

           

₦'m

₦'m

₦'m

₦'m

Crude oil sales

 34,007

14,503

 24,793

 7,247

(Over lift)/under lift

 (10,317)

 7,481

 (7,909)

 3,585

 

 23,690

 21,984

 16,884

 10,832

Gas sales           

 16,627

 9,592

 8,959

 4,159

Revenue

 40,317

 31,576

 25,843

 14,991

 

The major off-taker for crude oil is Mercuria. The major off-taker for gas is the Nigerian Gas Company.

In the prior period to 30 June 2016, realised fair value losses on crude oil hedges of N2,271 million were included in Revenue. This is now classified under Fair Value Loss (note 11).

Notes to the interim condensed consolidated financial statements continued

 

8.    Cost of sales

 

Half year ended

30 June 2017

Half year ended

30 June 2016

3 months ended

30 June 2017

3 months ended

30 June 2016

 

₦'m

'm

₦'m

₦'m

Crude handling fees

              1,531

2,134

            1,363

209

Barging cost

              1,995

-

            1,340

-

Royalties

              5,736

2,693

            4,223

942

Depletion, depreciation and amortisation

              8,861

5,768

            5,387

2,003

Niger Delta Development Commission levy

                 729

591

              379

213

Rig related expenses

                 499

370

              193

162

Operations & maintenance expenses

4,563              

5,298

            2,405

2,633

Cost of sales

             23,914

16,854

          15,290

6,162

 

 

9.    General and administrative expenses

 

Half year ended

30 June 2017

Half year ended

30 June 2016

3 months ended

30 June 2017

3 months ended

30 June 2016

 

₦'m

₦'m

₦'m

₦'m

Depreciation

                 722

560

              380

299

Employee benefits

              3,296

2,154

            1,509

919

Professional and consulting fees

              3,449

2,279

            2,088

1,156

Auditor's remuneration

                   94

13

                48

-

Directors emoluments (executive)

                 423

328

              245

88

Directors emoluments (non-executive)

                 476

491

              246

309

Rentals

                 224

206

              151

89

Other general expenses

              2,424

4,302

            1,312

3,209

General and administrative expenses

             11,108

10,333

            5,979

6,069

 

Directors' emoluments have been split between executive and non-executive directors. There were no non-audit services rendered by the Group's auditors during the period. Other general expenses relate to costs such as office maintenance costs, telecommunication costs, logistics costs and others. Share based payment expenses are included in the employee benefits expense.

10.  Loss on foreign exchange - net

 

Half year ended

30 June 2017

Half year ended

30 June 2016

3 months ended

30 June 2017

3 months ended

30 June 2016

 

₦'m

₦'m

₦'m

₦'m

Exchange loss

(264)

 (6,382)

(793)

 (5,897)

This is principally as a result of translation of naira denominated monetary assets and liabilities.

 

 

 

Notes to the interim condensed consolidated financial statements continued

11.  Fair value loss

 

Half year ended

30 June 2017

Half year ended

30 June 2016

3 months ended

30 June 2017

3 months ended

30 June 2016

 

₦'m

₦'m

₦'m

₦'m

Realised fair value losses on crude oil hedges

             (3,006)

 (2,271)

 (1,478)

 (2,271)

Unrealised fair value losses on crude oil hedges

-

 (4,792)

-

 (4,792)

Fair value loss on contingent consideration

                (274)

(510)

         (140)

 (351)

Fair value gain on other assets

           463

-

       463

-

Fair value loss

 (2,817)

 (7,573)

 (1,155)

 (7,414)

Realised fair value losses on crude oil hedges represent the payments for crude oil price options, while unrealised fair value losses represent losses on crude oil price hedges charged to profit or loss. Fair value loss on contingent consideration arises in relation to remeasurement of contingent consideration on the Group's acquisition of participating interest in its OML 53. The contingency criteria are the achievement of certain production milestones. Fair value gain on other assets arises from the fair value remeasurement of the Group's rights to receive the discharge sum of N94 billion (US$308 million).

In the prior period to 30 June 2016, realised fair value loss on crude oil hedges of N2,271 million were included Revenue (note 7).  This is now classified under Fair Value Loss.

 

12.  Finance income/ (costs)

 

Half year ended

30 June 2017

Half year ended

30 June 2016

3 months ended

30 June 2017

3 months ended

30 June 2016

 

₦'m

₦'m

₦'m

₦'m

Finance income

 

 

 

 

Interest income

270

5,694

206

5,270

Finance costs

 

 

 

 

Interest on bank loan and other bank charges

             10,560

8,298

       5,310

                 3,933

Unwinding of discount on provision for decommissioning 

                   14

23

             7

 

 

             10,574

8,321

            5,317

3,933

Finance (cost)/ income - net

            (10,304)

(2,627)

           (5,111)

1,337

 

13.  Taxation

Income tax expense is recognised based on management's estimate of the weighted average effective annual income tax rate expected for the full financial year. The estimated average annual tax rate used for the period to 30 June 2017 is 65.75% for crude oil activities and 30% for gas activities. As at 31st December 2016, the tax rates were 65.75% and 30% for crude oil and gas activities respectively.

Deferred income tax assets are recognised for tax losses carried forward to the extent that the realisation of the related tax benefit through future taxable profits is probable. The Group did not recognise deferred income tax assets of N72 billion (2016: N58 billion) in respect of temporary differences amounting to N109 billion (2016: N89 billion). Out of this, deferred tax asset of N22 billion (2016: N14 billion) relates to tax losses of N33 billion (2016: N22 billion). There are no expiration dates for the tax losses.
 

Notes to the interim condensed consolidated financial statements continued

14.  Loss per share (LPS)

Basic
Basic LPS is calculated on the Group's loss after taxation attributable to the parent entity and on the basis of the weighted average of issued and fully paid ordinary shares at the end of the period.

Diluted
Diluted LPS is calculated by dividing the loss attributable to ordinary equity holders of the parent by the weighted average number of ordinary shares outstanding during the year plus the weighted average number of ordinary shares that would be issued on conversion of all the dilutive potential ordinary shares (arising from outstanding share awards in the share based payment scheme) into ordinary shares.

 

Half year ended

30 June 2017

Half year ended

30 June 2016

3 months ended

30 June 2017

3 months ended

30 June 2016

 

₦'m

₦'m

₦'m

₦'m

 

 

 

 

 

Loss for the period attributable to equity holders of the parent

(8,432)

 (13,081)

(2,577)

(9,340)

 

 Share

'000

Share
'000

Share
'000

Share
'000

Weighted average number of ordinary shares in issue

 563,445

560,576

 563,445

560,576

Share awards

 4,943

2,223

 4,943

2,223

Weighted average number of ordinary shares adjusted for the effect of dilution

 568,388

562,799

 568,388

562,799

 

N

N

N

N

Basic loss per share

 (14.97)

(23.33)

 (4.57)

(16.66)

Diluted loss per share

 (14.83)

(23.24)

 (4.53)

(16.60)

 

₦'m

'm

₦'m

₦'m

Loss attributable to equity holders of the parent

(8,432)

(13,081)

(2,577)

(9,340)

Loss used in determining diluted loss per share

(8,432)

(13,081)

(2,577)

(9,340)

 

15.  Dividend

 

Half year ended

30 June 2017

Half year ended

30 June 2016

 

₦'m

₦'m

Dividend paid during the period

-

5,118

 

Dividend per share ($)

-

9.13

 

16.  Interest bearing loans & borrowings

Below is the net debt reconciliation on interest bearing loans and borrowings.

 

Borrowings due within 1 year

Borrowings due above 1 year

 Total

 

₦'m

₦'m

₦'m

Balance as at 1 January 2017

 66,489

 136,060

 202,549

Effective interest

                      -  

             11,169

         11,169

Effect of loan restructuring

                (8,808)

              8,808

                -  

Repayment

                      -  

            (23,253)

        (23,253)

Exchange differences

                   186

                 379

              565

Balance as at 30 June 2017

               57,867

           133,163

       191,030

 

Notes to the interim condensed consolidated financial statements continued

17.  Other asset

 

As at 30 June 2017

 

'm

Initial fair value of investment in OML 55

76,277

Receipts from crude oil lifted

(6,914)

Fair value adjustment as at 30 June 2017

463

Exchange differences

214

Fair value as at 30 June 2017

70,040

Other asset represents the Group's rights to receive the discharge sum of N94 billion (2016: N100 billion) from the crude oil reserves of OML 55.The asset has been measured at fair value through profit or loss (FVTPL) and receipts from crude oil lifted reduce the value of the asset. At each reporting date, the fair value of the discharge sum is determined using the income approach in line with IFRS 13: Fair Value Measurement. As at 30 June 2017, the fair value of the discharge sum is N70 billion (2016: N76 billion)

18.  Trade and other receivables

 

As at 30 June 2017

As at 31 Dec 2016

 

₦'m

₦'m

Trade receivables

             41,100

 22,395

Nigerian Petroleum Development  Company (NPDC) receivables

68,790

 72,049

National Petroleum Investment Management Services

 1,835

 2,511

Advances on investment

             20,096

 20,040

Under lift

 748

 1,372

Advances to suppliers

 2,298

 2,720

Other receivables

791

 346

 

 -

 -  

Impairment loss on NPDC receivables

 (3,138)

 (2,273)

 

 

       

 

132,520

 119,160

         

 

18a. Trade receivables:

Included in trade receivables is an amount due from NGC of N27 billion (2016: N20 billion) with respect to the sale of gas.

18b. NPDC receivables: 

NPDC receivables represent the outstanding cash calls due to Seplat from its JV partner, Nigerian Petroleum Development Company. The receivables have been discounted to reflect the impact of time value of money, and an impairment loss has been recognized in the financial statements. As at 30 June 2017, the undiscounted value of this receivable is N69 billion (2016: N72 billion).

 

18c. Advances on investment:

 

This comprises an advance of N13.8 billion (2016: N13.8 billion) on a potential investment in OML 25 and N6 billion (2016: N6 billion) currently held in an escrow account. Proceedings commenced against Newton Energy Limited, a wholly owned subsidiary of Seplat Plc by Crestar Natural Resources relating to the N6 billion (2016: N6 billion) currently held in an escrow account. The escrow monies relate to the potential acquisition of OML 25 by Crestar which Newton Energy has an option to invest into. These monies were placed in escrow in July 2015 pursuant to an agreement reached with Crestar and the vendor on final terms of the transaction.

 

 

Notes to the interim condensed consolidated financial statements continued

19.  Share capital

19a.  Authorised and issued share capital

 

 

As at 30 June 2017

As at 31 Dec 2016

 

₦'m

₦'m

Authorised ordinary share capital

 

 

 

 

 

1,000,000,000 ordinary shares denominated in  Naira of 50 kobo per share

500

500

 

 

 

Issued and fully paid

 

 

 

 

 

563,444,561 (2016: 563,444,561) issued shares denominated in Naira of 50 kobo per share

283

283

 

 

19b.  Employee share based payment scheme

 

As at 30 June 2017, the Group had awarded shares of 25,726,262 (2016: 25,448,071 shares) to certain employees and senior executives in line with its share based incentive scheme. During the half year ended 30 June 2017 no shares were vested (31 December 2016: 2,868,460 shares had vested, resulting in an increase in number of issued and fully paid ordinary shares of 50k each from 561 million to 563 million).

 

20.  Trade and other payables

 

 

As at 30 June 2017

As at 31 Dec 2016

 

₦'m

₦'m

Trade payables

 32,073

 32,983

 

Accruals and other payables

 27,136

 25,574

 

NDDC levy

 1,574

 6

 

Deferred revenue

 37,213

10,727

 

Royalties

 11,118

 10,476

 

 

            109,114 

 79,766

 

 

Included in accruals and other payables are field-related accruals N11 billion (2016: N10.7 billion) and other vendor payables of N16.2 billion (2016: N14.6 billion). Deferred revenue includes advance payments for crude oil sales of N37 billion (2016: N10 billion) and royalties include accruals in respect of gas sales for which payment is outstanding at the end of the period.
 

Notes to the interim condensed consolidated financial statements continued

21.  Computation of cash generated from operations

 

Half year ended

30 June 2017

Half year ended

30 June 2016

 

'm

₦'m

Loss before tax

(8,090)

 (12,193)

Adjusted for:

 

 

Depletion, depreciation and amortisation

              9,583

6,328

Interest on bank loan and other bank charges

             10,560

8,298

Unwinding of discount on provision for decommissioning

                   14

23 

Interest income

                (270)

(5,694)

Fair value loss on contingent consideration

                         274

510

Unrealised fair value loss on crude oil hedges

                           -

4,792

Fair value gain on other asset

                   (463)

                        -

Unrealised foreign exchange loss

                264

            6,382

Share based payments expenses

                 818

375

Defined benefit expenses

                 341

(185)

Loss on disposal of other property, plant and equipment

25

-

Changes in working capital (excluding the effects of exchange differences):

 

 

Trade and other receivables, including prepayments

(8,133)

 14,820

Trade and other payables

26,313

(10,423)

Inventories

 1,256

(4,746)

Net cash from operating activities                                                                            

32,492

8,287

22.  Related party relationships and transactions

The Group is controlled by Seplat Petroleum Development Company Plc (the 'parent Company'). As at 30 June 2017, the parent Company is owned 8.39% either directly or by entities controlled by A.B.C. Orjiako ('SPDCL BVI') and members of his family and 13.15% either directly or by entities controlled by Austin Avuru ('Professional Support Limited' and 'Platform Petroleum Limited'). The remaining shares in the parent company are widely held.

22a.  Related party relationships

The services provided by the related parties:

Abbeycourt Trading Company Limited: The Chairman of Seplat is a director and shareholder. The company provides diesel supplies to Seplat in respect of Seplat's rig operations.

Berwick Nigeria Limited: The Chairman of Seplat is a shareholder and director. The company provides construction services to Seplat in relation to a field base station in Sapele.

Cardinal Drilling Services Limited (formerly Caroil Drilling Nigeria Limited): Is owned by common shareholders with the parent Company. The company provides drilling rigs and drilling services to Seplat.

Charismond Nigeria Limited: The sister to the CEO works as a General Manager. The company provides administrative services including stationary and other general supplies to the field locations.

 Helko Nigeria Limited: The Chairman of Seplat is shareholder and director. The company owns the lease to Seplat's main office at 25A Lugard Avenue, Lagos, Nigeria.

Keco Nigeria Enterprises: The Chief Executive Officer's sister is shareholder and director. The company provides diesel supplies to Seplat in respect of its rig operations.

Montego Upstream Services Limited: The Chairman's nephew is shareholder and director. The company provides drilling and engineering services to Seplat.

Nabila Resources & Investment Ltd: The Chairman's in-law is a shareholder and director. The company provides lubricant to Seplat.
 

Ndosumili Ventures Limited: Is a subsidiary of Platform Petroleum Limited. The company provides transportation services to Seplat.

Nerine Support Services Limited: Is owned by common shareholders with the parent Company. Seplat leases a warehouse from Nerine and the company provides agency and contract workers to Seplat.

Oriental Catering Services Limited: The Chief Executive Officer of Seplat's spouse is shareholder and director. The company provides catering services to Seplat at the staff canteen.

ResourcePro Inter Solutions Limited: The Chief Executive Officer of Seplat's in-law is its UK representative. The company supplies furniture to Seplat.

Shebah Petroleum Development Company Limited (BVI): The Chairman of Seplat is a director and shareholder of SPDCL (BVI). SPDCL (BVI) provided consulting services to Seplat.

The following transactions were carried by Seplat with related parties:

22b.  Related party relationships

 

i)      Purchases of goods and services

Half year ended

30 June 2017

Half year ended

30 June 2016

 

'm

₦'m

Shareholders of the parent company

 

 

M&P (MPI SA)

            -

           8  

SPDCL (BVI)

            172

        115

 

 172

123

Entities controlled by key management personnel:

 

 

Contracts > $1million in 2017

 

 

Nerine Support Services Limited

          826

1,238

 

826

1,238

 

 

 

Contracts < $1million in 2017

 

 

Abbey Court trading Company Limited

 107

36

Charismond Nigeria Limited

10

4

Cardinal Drilling Services Limited

190

1,122

Keco Nigeria Enterprises

 22

5

Ndosumili Ventures Limited

170

206

Oriental Catering Services Limited

65

57

ResourcePro Inter Solutions Limited

-

15

Berwick Nigeria Limited

-

6

Montego Upstream Services Limited

-

2,331

Nabila Resources & Investment Limited

-

1

Helko Nigeria Limited

 

82

 

 564

3,865

Total

 1,390

5,103

       

 

* Nerine charges an average mark-up of 7.5% on agency and contract workers assigned to Seplat. The amounts shown above are gross i.e. it includes salaries and Nerine's mark-up. Total costs for agency and contracts during the half year ended 30 June 2017 is N795 million.

 

 

 

Notes to the interim condensed consolidated financial statements continued

 

22c. Balances

The following balances were receivable from or payable to related parties as at 30 June 2017:

 

i)   Prepayments / receivables

As at 30 June 2017

As at 31 Dec 2016

 

₦'m

₦'m

Entities controlled by key management personnel

 

 

Cardinal Drilling Services Limited

1,896

1,894

 

1,896

1,894

 

ii)  Payables

As at 30 June 2017

As at 31 Dec 2016

 

₦'m

₦'m

Entities controlled by key management personnel

 

 

Cardinal Drilling Services Limited

                 190

              308

Abbey Court Petroleum Company Limited

                   89

-

Charismond Nigeria Limited

                     6

-

Ndosumili Ventures Limited

                 140

-

ResourcePro Inter Solutions Limited

                   -  

-

Nerine Support Services Limited

                 800

3,480

Montego Upstream Services Limited

-

3,520

 

1,225

7,308

 

23.  Commitments and contingencies

23a. Operating lease commitments - Group as lessee

The Group leases drilling rigs, buildings, land, boats and storage facilities. The lease terms are between 1 and 5 years. The operating lease commitments of the Group as at 30 June 2017 are:

 

Operating lease commitments

As at 30 June 2017

As at 31 Dec 2016

 

₦'m

₦'m

Not later than one year

36

36

Later than one year and not later than five years

83

83

 

119

119

 

23b. Contingent consideration

     

As part of the purchase agreement of OML 53, a portion of the consideration is contingent on the performance of the producing asset. There will be additional cash payments to the previous owners should the oil price rise above US$90/bbl in the three year period following the acquisition date.

 

Significant unobservable valuation inputs are shown below:

Discount rate        15.45%

 

A significant increase or decrease in the discount rate would result in a lower/ (higher) fair value of the liability.

 

The fair value of the contingent consideration determined at 31 December 2016 reflects the current and projected crude oil prices, amongst other factors and a fair value adjustment has been recognised in profit or loss.

 

A reconciliation of the fair value of the contingent consideration liability is provided below:

 

 

As at 30 June 2017

 

'm

Initial fair value of the contingent consideration at acquisition date

2,073

Unrealised fair value changes recognised in profit or loss during year ended 31 December 2016

411

Exchange difference

1,188

Financial liability for the contingent consideration as at 31 December 2016

3,672

Fair value adjustment as at 30 June 2017

274

Exchange difference

11

Contingent consideration as at 30 June 2017

3,957

 

23c. Contingent liabilities

 

The Group is involved in a number of legal suits as defendant. The estimated value of the contingent liabilities for the period ended 30 June 2017 is N53 billion (2016: N4.7 billion). No provision has been made for this potential liability in these financial statements. Management and the Group's solicitors are of the opinion that the Group will suffer no loss from these claims.

24.  Events after the reporting period

There was no significant event after the reporting date which could have a material effect on the state of affairs of the Group as at 30 June 2017 and on the profit or loss for the half year ended on that date, which have not been adequately provided for or disclosed in these financial statements.

25.  Compliance with FRC Rule 1

In compliance with the regulatory requirement in Nigeria that the CFO, who signs the Annual Report and Accounts, must be a member of a professional accountancy body recognised by an Act of the National Assembly in Nigeria, the CFO of Seplat, Roger Brown, has been granted a waiver by the Financial Reporting Council of Nigeria to sign the accounts of the Group.

26.  Reclassification

Certain comparative figures have been reclassified in line with the current year's presentation.

27.  Exchange rates used in translating the accounts to Naira

The table below shows the exchange rates used in translating the accounts into Naira.

 

Basis

30 June 2017 ₦/$

30 June 2016 ₦/$

31 December 2016 ₦/$

Fixed assets - opening balances

Historical rate

Historical

Historical

Historical

 

Fixed assets - additions

Average rate

305.86

199

308

 

Fixed assets - closing balances

Closing rate

305.85

283

305

 

Current assets

Closing rate

305.85

283

305

 

Current liabilities

Closing rate

305.85

283

305

 

Equity

Historical rate

Historical

Historical

Historical

 

Income and Expenses:

Overall Average rate

305.86

213

255

 

                   

 

 

 

 

 

 

 

 

Interim condensed consolidated statement of profit or loss and other comprehensive income

for the half year ended 30 June 2017

 

 

Half year ended

30 June 2017

Half year ended

30 June 2016

3 months ended
30 June 2017

3 months ended

30 June 2016

 

 

Unaudited

Unaudited

Unaudited

Unaudited

 

Note

$'000

$'000

$'000

$'000

Revenue

7

 131,814

            153,022

 84,515

69,606

Cost of sales

8

 (78,187)

(83,742)

 (50,003)

(29,962)

Gross profit

 

 53,627

69,280

 34,512

39,644

General and administrative expenses

9

 (36,315)

 (49,592)

 (19,556)

(28,143)

Loss on foreign exchange - net

10

(866)

(28,330)

(2,596)

(25,889)

Fair value loss

11

 (9,210)

(33,345)

 (3,777)

(32,544)

Operating profit/(loss)

 

7,236

(41,987)

8,583

(46,932)

Finance income

12

 883

25,886

 673

23,655

Finance costs                      

12

 (34,573)

(41,432)

 (17,392)

(19,262)

Loss before taxation

 

(26,454)

(57,533)

(8,136)

(42,539)

Taxation

13

 (1,119)

(3,632)

 (300)

3,918

Loss for the period

 

(27,573)

(61,165)

(8,436)

(38,621)

 

 

 

 

 

-

Loss attributable to equity holders of parent

 

(27,573)

(62,506)

(8,436)

(43,677)

Profit attributable to non-controlling interest

 

-

1,341

 -  

5,056

 

 

 

 

 

-

Other comprehensive income/(loss):

 

 

 

 

 

Items that may be reclassified to profit or loss:

 

-

-

 

-

Foreign currency translation difference

 

-

-

-

-

 

 

 

 

 

 

Total comprehensive loss for the period

 

(27,573)

(61,165)

(8,436)

(38,621)

 

 

-

 

 

-

Loss attributable to equity holders of parent

 

(27,573)

(62,506)

(8,436)

(43,677)

Profit attributable to non-controlling interest

 

-

1,341

-

5,056

 

 

 

 

 

 

Loss per share ($)

14

(0.05)

(0.11)

(0.01)

(0.08)

Diluted loss per share($)

14

(0.05)

(0.11)

(0.01)

(0.08)

 

 

 

Interim condensed consolidated statement of financial position

As at 30 June 2017

 

As at 30 June 2017

As at 31 Dec 2016 

 

Unaudited

Audited

 

Note

$'000

$'000

Assets

 

 

 

Non-current assets

 

 

 

Oil and gas properties

 

 1,206,623

1,224,400

Other property, plant and equipment

 

 5,914

7,967

Other asset

17

 229,000

250,090

Prepayments

 

 31,624

33,616

Total non-current assets                          

 

1,473,161

 1,516,073

Current assets

 

 

 

Inventories

 

 102,106

 106,213

Trade and other receivables

18

433,282

 390,694

Prepayments

 

 3,215

 6,672

Cash & cash equivalents

 

 201,506

159,621

Total current assets

 

740,109

 663,200

Total assets

 

2,213,270

 2,179,273

Equity and liabilities

 

 

 

Equity

 

 

 

Issued share capital

19

 1,826

 1,826

Share premium

 

 497,457

 497,457

Share based payment reserve

19

 14,808

 12,135

Capital contribution

 

 40,000

 40,000

Retained earnings

 

651,349

 678,922

Foreign currency translation reserve

 

 3,675

 3,675

Total equity

 

1,209,115

 1,234,015

Non-current liabilities

 

 

 

Interest bearing loans & borrowings

16

 435,386

 446,098

Deferred tax liabilities

 

 76

-

Contingent consideration

23

 12,937

 12,040

Provision for decommissioning obligation

 

 644

 597

Defined benefit plan                 

 

 6,228

 5,112

Total non-current liabilities

 

455,271

 463,847

Current liabilities

 

 

 

Interest bearing loans and borrowings

16

 189,200

217,998

Trade and other payables

20

 356,756

 261,528

Current taxation

 

2,928

1,885

Total current liabilities

 

548,884

 481,411

Total liabilities

 

1,004,155

 945,258

Total shareholders' equity and liabilities

 

2,213,270

 2,179,273

 

                                                             

                                                             

Interim condensed consolidated statement of financial position continued

As at 30 June 2017

The financial statements on pages 34 to 56 were approved and authorised for issue by the board of directors on 20 July 2017 and were signed on its behalf by

 

 

 

 

 

A. B. C. Orjiako

A. O. Avuru

R.T. Brown 

FRC/2013/IODN/00000003161

FRC/2013/IODN/00000003100

FRC/2014/IODN/00000007983

Chairman

Chief Executive Officer

Chief Financial Officer

27 July 2017

 

27 July 2017

 

27 July 2017

 

 

 

Interim condensed consolidated statement of changes in equity continued

for the half year ended 30 June 2017

for the half year ended 30 June 2016

 

 

 

 

 

 

 

 

Issued share

capital

Share premium

Capital contribution

Share based

payment reserve

Foreign currency translation reserve

Retained earnings

Total

Non-controlling interest

Total

equity   

 

 

$'000

$'000

$'000

$'000

$'000

$'000

$'000

$'000

$'000

 

At 1 January 2016

1,821

497,457

40,000

8,734

325

865,485

1,413,822

(745)

1,413,077

 

(Loss)/Profit for the period

-

-

-

-

-

(62,506)

(62,506)

1,341

(61,165)

 

Other comprehensive income

-

-

-

-

-

-

-

-

-

 

Total comprehensive loss for the period

-

-

-

-

-

(62,506)

(62,506)

1,341

(61,165) 

 

Transactions with owners in their capacity as owners:

 

 

 

 

 

 

 

 

 

 

Share based payments

-

-

-

1,650

-

-

1,650

-

1,650

 

Dividends

-

-

-

-

-

(22,534)

(22,534)

-

(22,534)

 

Total

-

-

-

1,650

-

(22,534)

(20,884)

-

(20,884)

 

At 30 June 2016 (unaudited)

1,821

497,457

40,000

10,384

325

780,445

1,330,432

596

1,331,028

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

for the half year ended 30 June 2017

 

 

Issued share

capital

Share premium

Capital contribution

Share based

payment reserve

Foreign currency translation reserve

Retained earnings

Total

Non-controlling interest

Total

equity   

 

 

$'000

$'000

$'000

$'000

$'000

$'000

$'000

$'000

$'000

 

At 1 January 2017

1,826

497,457

40,000

12,135

3,675

678,922

1,234,015

-

1,234,015

 

Loss for the period

 -  

 -  

 -  

 -  

 -  

(27,573)

(27,573)

 -  

(27,573)

 

Other comprehensive income

-

-

-

-

-

-

-

-

-

 

Total comprehensive loss for the period

 -  

 -  

 -  

 -  

 -  

(27,573)

(27,573)

 -  

(27,573)

 

Transactions with owners in their capacity as owners:

 

 

 

 

 

 

 

 

 

 

Share based payments

-

-

-

2,673

-

-

2,673

-

2,673

 

Dividends

-

-

-

-

-

-

-

-

-

 

Total

-

-

-

2,673

-

 -

 2,673

-

2,673

 

At 30 June 2017 (unaudited)

 1,826

 497,457

 40,000

 14,808

 3,675

651,349

1,209,115

 -  

1,209,115

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Interim condensed consolidated statement of cash flow

for the half year ended 30 June 2017

 

Half year ended
30 June 2017

Half year ended
30 June 2016

 

$'000

$'000

                                                                                                                          Note

Unaudited

Unaudited

Cash flows from operating activities

 

 

Cash generated from operations                                                              21         

106,241

39,907

Net cash inflows from operating activities

106,241

            39,907

Cash flows from investing activities

-

 

Acquisition of oil and gas properties

(11,202)

(15,519)

Acquisition of other property, plant and equipment

(386)

(1,236)

Receipts from other asset                                                                        17

22,604

-

Interest received

883

25,886

Net cash inflows from investing activities

11,899

9,131

Cash flows from financing activities

 

 

Repayments of bank financing

 (41,500)

(121,509)

Dividends paid

-

(22,534)

Interest paid

(34,526)

(41,216)

Net cash outflows from financing activities

(76,026)

(185,259)

Net decrease in cash and cash equivalents

42,114

(136,221)

Cash and cash equivalents at beginning of period

159,621

326,029

Effects of exchange rate changes on cash and cash equivalents

(229)

(10,008)

Cash and cash equivalents at end of period

201,506

179,800

 

 

 

 

 

 

 

 

Notes to the interim condensed consolidated financial statements

 

1.    Corporate structure and business

Seplat Petroleum Development Company Plc ('Seplat' or the 'Company'), the parent of the Group, was incorporated on 17 June 2009 as a private limited liability company and re-registered as a public company on 3 October 2014, under the Companies and Allied Matters Act, CAP C20, Laws of the Federation of Nigeria 2004. The Company commenced operations on 1 August 2010. The Company is principally engaged in oil and gas exploration and production.

 

The Company's registered address is: 25a Lugard Avenue, Ikoyi, Lagos, Nigeria.

 

The Company acquired, pursuant to an agreement for assignment dated 31 January 2010 between the Company, SPDC,

TOTAL and AGIP, a 45% participating interest in the following producing assets:

 

OML 4, OML 38 and OML 41 located in Nigeria. The total purchase price for these assets was US$340 million paid at the completion of the acquisition on 31 July 2010 and a contingent payment of US$33 million payable 30 days after the second anniversary, 31 July 2012, if the average price per barrel of Brent Crude oil over the period from acquisition up to 31 July 2012 exceeds US$80 per barrel. US$358.6 million was allocated to the producing assets including US$18.6 million as the fair value of the contingent consideration as calculated on acquisition date. The contingent consideration of US$33 million was paid on 22 October 2012.

 

In 2013, Newton Energy Limited (''Newton Energy''), an entity previously beneficially owned by the same shareholders as Seplat, became a subsidiary of the Company. On 1 June 2013, Newton Energy acquired from Pillar Oil Limited (''Pillar Oil'') a 40 percent Participant interest in producing assets: the Umuseti/Igbuku marginal field area located within OPL 283 (the ''Umuseti/Igbuku Fields'').

 

On 27 March 2013, Seplat Energy Limited ("Seplat Energy") was incorporated. The principal activities of the Company is the exploration, development and transportation of petroleum products and Seplat Gas Company Limited ("Seplat Gas") was incorporated on 9 December 2013 as a private limited liability company to engage in oil and gas exploration and production.

 

In 2015, the Group purchased a 40% participating interest in OML 53, onshore north eastern Niger Delta, from Chevron Nigeria Ltd for $ 259.4 million.

 

In 2017, the Group incorporated a new subsidiary, ANOH Gas Processing Company Limited. The principal activities of the Company is the processing of gas from OML 53.

 

The Company together with its subsidiary, Newton Energy, and six wholly owned subsidiaries, namely, Seplat

Petroleum Development Company UK Limited ('Seplat UK'), which was incorporated on 21 August 2014, Seplat East

Onshore Limited ('Seplat East'), which was incorporated on 12 December 2014, Seplat East Swamp Company Limited

('Seplat Swamp'), which was incorporated on 12 December 2014, Seplat Gas Company Limited ('Seplat GAS'), which was incorporated on 12 December 2014, Seplat Energy Limited ('Seplat Energy'), which was incorporated on 27 March 2013 and ANOH Gas Processing Company Limited which was incorporated on 18 January 2017 are collectively referred to as the Group.

 

 

 

Subsidiary

Country of incorporation and place of business

Shareholding %

Principal activities

Newton Energy Limited

Nigeria

100%

Oil & gas exploration and production

Seplat Petroleum Development UK

United Kingdom

100%

Oil & gas exploration and production

Seplat East Onshore Limited

Nigeria

100%

Oil & gas exploration and production

Seplat East Swamp Company Limited

Nigeria

100%

Oil & gas exploration and production

Seplat Gas Company

Nigeria

100%

Oil & gas exploration and production

Seplat Energy Limited

Nigeria

100%

Oil & gas exploration and production

ANOH Gas Processing Company Limited

Nigeria

100%

Gas processing

 

 

 

Notes to the interim condensed consolidated financial statements continued

2.    Significant changes in the current reporting period

During the reporting period ended 30 June 2017, the Group renegotiated its lending arrangements resulting in a twelve month extension of its revolving credit facility till 31 December 2018. The Group also significantly increased its production volumes as a result of the lift in the force majeure which had in the previous financial year restricted exports from the Forcados terminal. The Group plans to open up other export lines to ensure sustained growth in production volumes.

 

Resumption of exports via the Forcados terminal, has strengthened the Group's financial performance and position during the period ended 30 June 2017.

 

3.    Summary of significant accounting policies

3.1   Introduction to summary of significant accounting policies

 

The accounting policies adopted are consistent with those of the previous financial year and corresponding interim reporting period, except for the adoption of new and amended standards which are set out below.

 

3.2   Basis of preparation

 

i)        Compliance with IFRS

 

The interim condensed consolidated financial statements of the Group for the half year reporting period ended 30 June 2017 have been prepared in accordance with accounting standard IAS 34 Interim financial reporting.

 

ii)       Historical cost convention

 

The financial information has been prepared under the going concern assumption and historical cost convention, except for contingent consideration, other asset and financial instruments on initial recognition measured at fair value. The historical financial information is presented in US Dollars and all values are rounded to the nearest thousand ($000) except when otherwise indicated. The accounting policies are applicable to both the Company and Group.

 

iii)      Going concern

 

Nothing has come to the attention of the directors to indicate that the Company will not remain a going concern for at least twelve months from the date of these financial statements.

iv)      New and amended standards adopted by the Group

 

There were a number of new standards and amendments to standards that are effective for annual periods beginning after 1 January 2017; the Group has adopted these new or amended standards in preparing the interim condensed consolidated financial statements. The nature and impact of the new standards and amendments to the standards are described below.

 

Other than the changes described below, the accounting policies adopted are consistent with those of the previous financial year.

 

a)       Disclosure initiative - Amendments to IAS 7

 

The Group is now required to explain changes in their liabilities arising from financing activities. This includes changes arising from cash flows (e.g. drawdowns and repayments of borrowings) and non-cash changes such as acquisitions, disposals, accretion of interest and unrealised exchange differences.

 

Changes in financial assets are included in this disclosure if the cash flows were, or are, included in cash flows from financing activities. This is the case, for example, for assets that hedge liabilities arising from financing liabilities.

 

The Group may include changes in other items as part of this disclosure, for example by providing a 'net debt' reconciliation. However, in this case the changes in the other items are disclosed separately from the changes in liabilities arising from financing activities.

 

Notes to the interim condensed consolidated financial statements continued

 

The Group discloses this information in tabular format as a reconciliation from opening and closing balances, but may adopt a different format as the standard does not mandate a specific format.

 

The Group discloses this information in Note 16.

 

v)     New standards, amendments and interpretations not yet adopted

       

The Group has the following updates to information provided in the last annual financial statements about the standards issued but not yet effective that may have a significant impact on the Group's consolidated financial statements.

         

a.      Amendments to IFRS 2 Share-based payments

 

In June 2016, the IASB made amendments to IFRS 2 Share-based payments which clarified the effect of vesting conditions on the measurement of cash-settled share-based payment transactions, the classification of share-based payment transactions with net settlement features and the accounting for a modification of the terms and conditions that changes the classification of the transaction from cash-settled to equity-settled.

 

The amendments are effective for reporting periods beginning on or after 1 January 2018. The Group will adopt the amendments from 1 January 2018.

 

b.      IFRS 9 Financial Instruments

 

IFRS 9 Financial instruments addresses the classification, measurement and de-recognition of financial assets and financial liabilities, the standard introduces new rules for hedge accounting and a new impairment model for financial assets. The Group has decided not to adopt IFRS 9 until it becomes mandatory on 1 January 2018.

 

The Group is undergoing a detailed assessment of the impact of the new standard on the classification and measurement of its financial assets. From the preliminary results, the Group does not expect the new guidance to have a significant impact on the classification and measurement of its financial assets for the following reason:

 

·  All of the Group's financial assets are currently classified as loans and receivables and are measured at amortised cost and will satisfy the conditions for classification at amortised cost under IFRS 9.

 

There will be no impact on the Group's accounting for financial liabilities, as the new requirements only affect accounting for financial liabilities that are designated at fair value through profit or loss and the Group does not have such liabilities. The de-recognition rules have been transferred from IAS 39 Financial Instruments: Recognition and Measurement and have not been changed. The new hedge accounting rules will align the accounting for hedging instruments more closely with the Group's risk management practices. As a general rule, more hedge relationships might be eligible for hedge accounting, as the standard introduces a more principles-based approach. The Group does not expect a significant impact on the accounting for its hedging relationships as a result of the adoption of IFRS 9, as they have not formally elected to apply hedge accounting.

 

The new impairment model requires the recognition of impairment provisions based on expected credit losses (ECL) rather than only incurred credit losses as is the case under IAS 39. It applies to financial assets classified at amortised cost, debt instruments measured at fair value through OCI (FVOCI), contract assets under IFRS 15: Revenue from Contracts with Customers and lease receivables. Based on assessments undertaken on the Group's portfolio of NPDC receivables, it estimates that should the new rules had been adopted as at 1 January 2017, there would have been an

increase to its loss allowance for NPDC receivables of approximately $4 million at that date and retained earnings would decrease by the same amount.

 

The new standard also introduces expanded disclosure requirements and changes in presentation. These are expected to change the nature and extent of the Group's disclosures about its financial instruments particularly in the year of the adoption of the new standard.

 

c.      IFRS 15 Revenue from contracts with customers

 

The IASB has issued a new standard for the recognition of revenue. This will replace IAS 18 which covers revenue arising from the sale of goods and the rendering of services and IAS 11 which covers construction contracts.

 

The new standard is based on the principle that revenue is recognised when control of a good or service transfers to a customer.

 

 

 

Notes to the interim condensed consolidated financial statements continued

 

The standard permits either a full retrospective or a modified retrospective approach for the adoption. The new standard is effective for first interim periods within annual reporting periods beginning on or after 1 January 2018. The Group will adopt the new standard from 1 January 2018.

 

Management identified the following areas that are likely to be affected:

 

·      Accounting for under lifts and over lifts: IFRS 15 is applicable only if the counterparty to the contract is a customer. The standard defines a customer as a party that has contracted with an entity to obtain goods or services that are an output of the entity's ordinary activities. IFRS 15 makes a distinction between customers and partners or collaborators who share in the risks and benefits that result from the activity or process. If the over-lifter does not meet the definition of a customer or the transaction is a non-monetary exchange, then over lifts and under lifts will not be recognised as revenue from contracts with customers. If the Group were to adopt the new rules as at 1 January 2017, it estimates that revenue would have reduced by $16 million and other operating income would have increased by the same amount.

 

·      Accounting for consideration payable to the customer: The standard requires that an entity accounts for consideration payable to a customer as a reduction of the transaction price and, therefore, net of revenue unless the payment to the customer is in exchange for a distinct good or service that the customer transfers to the entity. The Group incurs barging costs in the course of the satisfaction of its performance obligations i.e. delivery of crude oil and gas. These costs do not transfer any distinct good or service to Seplat and as such represent consideration payable to customer and will be accounted for as a direct deduction from revenue. If the Group had adopted the new rules as at 1 January 2017, revenue would have reduced by an additional $18 million as a result of barging costs.

 

·      Presentation of contract assets and contract liabilities in the balance sheet - IFRS 15 requires separate presentation of contract assets and contract liabilities in the balance sheet. This will result in some reclassifications as of 1 January 2018 in relation to advances for future oil sales which are currently included in deferred revenue.

 

·      Other likely areas of impact are in relation to advances for future oil sales that may have a significant financing component and variable consideration arising from gas pricing based on an index as well as optional pricing on crude oil sold to customers.

 

d.      IFRS 16 Leases

 

IFRS 16 was issued in January 2016. It will result in almost all leases being recognised on the balance sheet, as the distinction between operating and finance leases is removed. Under the new standard, an asset (the right to use the leased item) and a financial liability to pay rentals are recognised. The only exceptions are short-term and low-value leases. The accounting for lessors will not significantly change.

 

The standard will affect primarily the accounting for the Group's operating leases. As at the reporting date, the Group has non-cancellable operating lease commitments of $0.39 million. However, the Group has not yet determined to what extent these commitments will result in the recognition of an asset and a liability for future payments and how this will affect the Group's profit and classification of cash flows.

 

Some of the commitments may be covered by the exception for short-term leases, while none of the leases will be covered by the exception for low value leases. Some commitments may relate to arrangements that will not qualify as leases under IFRS 16, principally because they are service contracts.

 

The standard is mandatory for first interim periods within annual reporting periods beginning on or after 1 January 2019. At this stage, the Group does not intend to adopt the standard before its effective date.

 

3.3   Basis of consolidation

 

The consolidated financial statements comprise the financial statements of the Company and its subsidiaries as at 30 June 2017.

 

This basis is the same adopted for the last audited financial statements as at 31 December 2016.

3.4   Functional and presentation currency

The Group's financial statements are presented in United States Dollars, which is also the Company's functional currency. For each entity the Group determines the functional currency and items included in the financial statements of each entity are measured using that functional currency.

Notes to the interim condensed consolidated financial statements continued

 

i)        Transactions and balances

 

Foreign currency transactions are translated into the functional currency using the exchange rates prevailing at the dates of the transactions. Foreign exchange gains and losses resulting from the settlement of such transactions and from the translation of monetary assets and liabilities denominated in foreign currencies at year end exchange rates are generally recognised in profit or loss. Foreign exchange gains and losses that relate to borrowings are presented in the statement of profit or loss, within finance costs. All other foreign exchange gains and losses are presented in the statement of profit or loss on a net basis within other income or other expenses.

Non-monetary items that are measured at fair value in a foreign currency are translated using the exchange rates at the date when the fair value was determined. Translation differences on assets and liabilities carried at fair value are reported as part of the fair value gain or loss.

ii)           Group companies

 

The results and financial position of foreign operations that have a functional currency different from the presentation currency are translated into the presentation currency as follows:

·      assets and liabilities for each balance sheet presented are translated at the closing rate at the date of the balance sheet

·      income and expenses for each statement of profit or loss and statement of comprehensive income are translated at average exchange rates (unless this is not a reasonable approximation of the cumulative effect of the rates prevailing on the transaction dates, in which case income and expenses are translated at the dates of the transactions), and

·      all resulting exchange differences are recognised in other comprehensive income.

On disposal of a foreign operation, the component of other comprehensive income relating to that particular foreign operation is recognised in profit or loss.

4.    Segment reporting

 

Segment reporting has not been prepared as the Group operates one segment, being the exploration, development and production of oil and gas related products located in Nigeria. Operations in the different OMLs are integrated due to geographic proximity, the use of shared infrastructure and common operational management.

5.    Significant accounting judgements, estimates and assumptions

5.1    Judgements

 

Management's judgements at the end of the half year are consistent with those disclosed in the recent 2016 Annual financial statements. The following are some of the judgements which have the most significant effect on the amounts recognised in this consolidated financial statements.

 

i)        OMLs 4, 38 and 41

 

OMLs 4, 38, 41 are grouped together as a cash generating unit for the purpose of impairment testing. These three

OMLs are grouped together because they each do not independently generate cash flows. They currently operate as a single block sharing resources for the purpose of generating cash flows. Crude oil and gas sold to third parties from these OMLs are invoiced together.

 

ii)       Advances on investment (note 18)

 

The Group considers that the advances on investment of US$65.7 million (2016: US$65.7 million) in relation to the acquisition of additional assets is fully recoverable in accordance with the terms of the deposit.

 

 

 

 

Notes to the interim condensed consolidated financial statements continued

 

5.2   Estimates and assumptions

 

The key assumptions concerning the future and other key sources of estimation uncertainty that have a significant risk of causing a material adjustment to the carrying amount of assets and liabilities are disclosed in the most recent 2016 annual financial statements.

 

The following are some of the estimates and assumptions made.

 

i)        Impairment of financial assets

 

The Group assesses at each reporting date whether there is objective evidence that a financial asset or a group of financial assets is impaired. A financial asset or a group of financial assets is deemed to be impaired if there is objective evidence of impairment as a result of one or more events that has occurred since the initial recognition of the asset (an incurred loss event) and that loss event has an impact on the estimated future cash flows of the financial asset or the group of financial assets that can be reliably estimated. Evidence of impairment may include indications that the debtor or a group of debtors is experiencing significant financial difficulty, default or delinquency in interest or principal payments, the probability that they will enter bankruptcy or other financial reorganisation and observable data indicating that there is a measurable decrease in the estimated future cash flows, such as changes in arrears or economic conditions that correlate with defaults.

 

Management has made certain assumptions about the recoverability of financial assets exposed to credit risk from NPDC. These are based on management's past experiences with NPDC, current discussions with NPDC and financial capacity of NPDC. However, wherever these assumptions do not hold, it might have a significant impact on the Group's profit or loss in future.

 

ii)       Defined benefit plans

 

The cost of the defined benefit retirement plan and the present value of the retirement obligation are determined at the end of the financial year using actuarial valuations. An actuarial valuation involves making various assumptions that may differ from actual developments in the future. These include the determination of the discount rate, future salary increases, mortality rates and changes in inflation rates. Service and interest costs are recognised at each reporting period based on an estimate of the periodic benefit expense for the financial year.

 

The defined benefit obligation recognised in this period has been based on the same assumptions as in the previous financial year The subsequent financial year end balance was estimated as at 31 December 2016 and has been recognised in this half year period on a pro rata basis. Therefore, no actuarial gains or losses have been recognised given that last year's assumptions have been adopted.

 

iii)      Contingent consideration

 

The fair value of the contingent consideration arrangement of US$12.9 million was estimated calculating the present value of the future expected cash flows. The estimates are based on a discount rate of 15.45%. Refer to note 23 for further details.

 

6.    Financial risk management

6.1    Financial risk factors

 

The Group's activities expose it to a variety of financial risks such as market risk (including foreign exchange risk, interest rate risk and commodity price risk), credit risk and liquidity risk. The Group's risk management programme focuses on the unpredictability of financial markets and seeks to minimise potential adverse effects on the Group's financial performance.

Risk management is carried out by the treasury department under policies approved by the Board of Directors. The Board provides written principles for overall risk management, as well as written policies covering specific areas, such as foreign exchange risk, interest rate risk, credit risk and investment of excess liquidity.

 

 

Notes to the interim condensed consolidated financial statements continued

 

Risk

Exposure arising from

Measurement

Management

Market risk - foreign exchange

Future commercial transactions

Recognised financial assets and liabilities not denominated in US dollars.

Cash flow forecasting

Sensitivity analysis

Match and settle foreign denominated cash inflows with foreign denominated cash outflows.

Market risk - interest rate

Long term borrowings at variable rate

Sensitivity analysis

None

Market risk - commodity  prices

Future sales transactions

 

Sensitivity analysis

Oil price hedges

Credit risk

Cash and cash equivalents, trade receivables and derivative financial instruments.

Aging analysis

Credit ratings

Diversification of bank deposits.

Liquidity risk

Borrowings and other liabilities

Rolling cash flow forecasts

Availability of committed credit lines and borrowing facilities

 

 

6.1.1  Liquidity risk

 

Liquidity risk is the risk that the Group will not be able to meet its financial obligations as they fall due.

 

The Group manages liquidity risk by ensuring that sufficient funds are available to meet its commitments as they fall due.

The Group uses both long-term and short-term cash flow projections to monitor funding requirements for activities and to ensure there are sufficient cash resources to meet operational needs. Cash flow projections take into consideration the Group's debt financing plans and covenant compliance. Surplus cash held is transferred to the treasury department which invests in interest bearing current accounts, time deposits and money market deposits.

         The following table details the Group's remaining contractual maturity for its non-derivative financial liabilities with agreed maturity periods. The table has been drawn based on the undiscounted cash flows of the financial liabilities based on the earliest date on which the Group can be required to pay.

 

 

 

 

 

 

 

 

Notes to the interim condensed consolidated financial statements continued

 

 

 

Variable rate

  Less than

     1 year

        1 -2

years

         2 - 3

years

         3 - 5

years

After
5 years

      Total

 

 

%

$ '000

$ '000

$ '000

$ '000

$ '000

$ '000

30 June 2017

 

 

 

 

 

 

 

Non - derivatives

 

 

 

 

 

 

 

Variable interest rate borrowings (bank loans):

 

 

 

 

 

 

 

Allan Gray

8.5%+LIBOR

4,328

5,333

4,904

3,038

-

17,603

Zenith Bank Plc

8.5%+LIBOR

59,315

73,081

67,203

41,636

-

241,235

First Bank of Nigeria

8.5%+LIBOR

32,743

40,343

37,098

22,984

-

133,168

United Bank of Africa Plc

8.5%+LIBOR

37,072

45,676

42,002

26,022

-

150,772

Stanbic IBTC Bank Plc

8.5%+LIBOR

5,556

6,845

6,294

3,900

-

22,595

The Standard Bank of South Africa Limited

8.5%+LIBOR

5,556

6,845

6,294

3,900

-

22,595

Standard Chartered Bank

6.0%+LIBOR

14,859

9,240

-

-

-

24,099

Natixis

6.0%+LIBOR

14,859

9,240

-

-

-

24,099

Citibank Nigeria Limited and Citibank N.A.

6.0%+LIBOR

11,557

7,186

-

-

-

18,743

First Rand Bank (Merchant Bank Division)

6.0%+LIBOR

9,906

6,160

-

-

-

16,066

Nomura International Plc.

6.0%+LIBOR

9,906

6,160

-

-

-

16,066

Ned Bank Ltd London Branch

6.0%+LIBOR

9,906

6,160

-

-

-

16,066

The Mauritius Commercial Bank Plc

6.0%+LIBOR

9,906

6,160

-

-

-

16,066

Stanbic IBTC Bank Plc

6.0%+LIBOR

7,429

4,620

 

-

-

12,049

The Standard Bank of South Africa Limited

6.0%+LIBOR

10,733

6,674

-

-

-

17,407

Other non-derivatives

 

 

 

 

 

 

 

Trade and other payables

-

155,304

-

-

-

-

155,304

Contingent consideration

-

-

-

18,500

-

-

18,500

 

 

398,935

239,723

182,295

101,480

 

922,433

 

 

 

 

 

 

Notes to the interim condensed consolidated financial statements continued

 

 

 

Variable rate

Less than
1 year

1 - 2
year

2 - 3
years

3 - 5
years

After
5 years

Total

 

%

$ '000

$ '000

$ '000

$ '000

$ '000

$ '000

31 December 2016

 

 

 

 

 

 

 

Non - derivatives

 

 

 

 

 

 

 

Variable interest rate borrowings (bank loans):

 

 

 

 

 

 

 

Zenith Bank Plc

8.5% + LIBOR

 37,406

 76,006

 70,109

 74,477

 -  

 257,998

First Bank of Nigeria Limited

8.5% + LIBOR

 23,379

 47,504

 43,818

 46,548

 -  

 161,249

United Bank for Africa Plc

8.5% + LIBOR

 23,379

 47,504

 43,818

 46,548

 -  

 161,249

Stanbic IBTC Bank Plc

8.5% + LIBOR

 3,504

 7,119

 6,567

 6,976

 -  

 24,166

The Standard Bank of South Africa Limited

8.5% + LIBOR

 3,504

 7,119

 6,567

 6,976

 -  

 24,166

Standard Chartered Bank

6.0% + LIBOR

 27,711

 -  

 -  

 -  

 -  

 27,711

Natixis

6.0% + LIBOR

 27,711

 -  

 -  

 -  

 -  

 27,711

Citibank Nigeria Ltd and Citibank NA

6.0% + LIBOR

 27,711

 -  

 -  

 -  

 -  

 27,711

Bank of America Merrill Lynch Int'l Ltd

6.0% + LIBOR

 18,474

 -  

 -  

 -  

 -  

 18,474

FirstRand Bank Ltd (Rand Merchant Bank Division)

6.0% + LIBOR

 18,474

 -  

 -  

 -  

 -  

 18,474

JP Morgan Chase Bank NA, London Branch

6.0% + LIBOR

 18,474

 -  

 -  

 -  

 -  

 18,474

NedBank Ltd, London Branch

6.0% + LIBOR

 18,474

 -  

 -  

 -  

 -  

 18,474

Stanbic IBTC Bank Plc

6.0% + LIBOR

 13,856

 -  

 -  

 -  

 -  

 13,856

The Standard Bank of South Africa Ltd

6.0% + LIBOR

 13,856

 -  

 -  

 -  

 -  

 13,856

Other non - derivatives

 

 

 

 

 

 

 

Trade and other payables

-

161,773

 -  

 -  

 -  

 -  

161,773

Contingent consideration

-

 -  

 -  

 -  

 18,500

 -  

 18,500

 

 

437,686 

 185,252

 170,879

 200,025

 -  

  993,842

 

6.2   Fair value measurements

Financial instruments measured at fair value were based on the same assumptions as determined in the 31 December 2016 financial statements. The judgements and estimates made by the Group in determining the fair values of the financial instruments have remained the same since the last annual financial report. There were no transfers of financial instruments between fair value hierarchy levels during this half year.

 

 

Notes to the interim condensed consolidated financial statements continued

7.    Revenue

 

Half year ended

30 June 2017

Half year ended

30 June 2016

3 months ended

30 June 2017

3 months ended

30 June 2016

           

$'000

$'000

$'000

$'000

Crude oil sales

 111,183

 69,952

 81,073

33,457

(Over lift)/under lift

 (33,732)

 35,930

 (25,863)

16,334

 

 77,451

 105,882

 55,210

49,791

Gas sales           

 54,363

 47,140

 29,305

19,815

Revenue

 131,814

 153,022

 84,515

69,606

 

The major off-taker for crude oil is Mercuria. The major off-taker for gas is the Nigerian Gas Company.

In the prior period to 30 June 2016, realised fair value losses on crude oil hedges of US$9,999 ('000) were included in Revenue.  This is now classified under Fair Value Loss (note 11).

 

8.    Cost of sales

 

Half year ended

30 June 2017

Half year ended

30 June 2016

3 months ended

30 June 2017

3 months ended

30 June 2016

 

$'000

$'000

$'000

$'000

Crude handling fees

5,006

10,833

4,458

1,151

Barging cost

 6,524

-

 4,384

-

Royalties

 18,753

13,376

 13,809

4,568

Depletion, depreciation and amortisation

 28,974

28,509

 17,619

9,573

Niger Delta Development Commission levy

 2,381

2,961

 1,240

1,060

Rig related expenses

 1,630

1,813

 630

765

Operations & maintenance expenses

 14,919

26,250

7,863

12,845

Cost of sales

 78,187

83,742

 50,003

29,962

 

 

9.    General and administrative expenses

 

Half year ended

30 June 2017

Half year ended

30 June 2016

3 months ended

30 June 2017

3 months ended

30 June 2016

 

$'000

$'000

$'000

$'000

Depreciation

 2,362

2,744

 1,244

1,431

Employee benefits

 10,776

10,465

 4,939

4,252

Professional and consulting fees

 11,276

11,174

 6,831

5,525

Auditor's remuneration

 306

56

 156

-

Directors emoluments (executive)

 1,382

1,613

 800

404

Directors emoluments (non-executive)

 1,555

2,395

 802

1,480

Rentals

 732

1,008

 494

418

Other general expenses

7,926

20,137

 4,290

14,633

General and administrative expenses

 36,315

49,592

 19,556

28,143

 

Directors' emoluments have been split between executive and non-executive directors. There were no non-audit services rendered by the Group's auditors during the period. Other general expenses relate to costs such as office maintenance costs, telecommunication costs, logistics costs and others. Share based payment expenses are included in the employee benefits expense.

Notes to the interim condensed consolidated financial statements continued

10.  Loss on foreign exchange - net

 

Half year ended

30 June 2017

Half year ended

30 June 2016

3 months ended

30 June 2017

3 months ended

30 June 2016

 

$'000

$'000

$'000

$'000

Exchange loss

(866)

(28,330)

(2,596)

(25,889)

This is principally as a result of translation of naira denominated monetary assets and liabilities.

11.  Fair value loss

 

Half year ended

30 June 2017

Half year ended

30 June 2016

3 months ended

30 June 2017

3 months ended

30 June 2016

 

$'000

$'000

$'000

$'000

Realised fair value losses on crude oil hedges

 (9,827)

(9,999)

 (4,834)

(9,999)

Unrealised fair value losses on crude oil hedges

-

(20,787)

-

(20,787)

Fair value loss on contingent consideration

 (897)

(2,559)

 (457)

(1,758)

Fair value gain on other assets

 1,514

-

1,514

-

Fair value loss

(9,210)

(33,345)

 (3,777)

(32,544)

Realised fair value losses on crude oil hedges represent the payments for crude oil price options, while unrealised fair value losses represent losses on crude oil price hedges charged to profit or loss. Fair value loss on contingent consideration arises in relation to remeasurement of contingent consideration on the Group's acquisition of participating interest in its OML 53. The contingency criteria are the achievement of certain production milestones. Fair value gain on other assets arises from the fair value remeasurement of the Group's rights to receive the discharge sum of US$308 million.

In the prior period to 30 June 2016, realised fair value losses on crude oil hedges of US$9,999 ('000) were included in Revenue (note 7).  This is now classified under Fair Value Loss.

12.  Finance income/ (costs)

 

Half year ended

30 June 2017

Half year ended

30 June 2016

3 months ended

30 June 2017

3 months ended

30 June 2016

 

$'000

$'000

$'000

$'000

Finance income

 

 

 

 

Interest income

883

25,886

 673

23,655

Finance costs

 

 

 -

 -

Interest on bank loan and other bank charges

 34,526

41,216

 17,368

19,262

Unwinding of discount on provision for decommissioning 

 47

216

 24

-

 

 34,573

41,432

 17,392

19,262

Finance (cost)/ income - net

(33,690)

(15,546)

(16,719)

4,393

 

13.  Taxation

Income tax expense is recognised based on management's estimate of the weighted average effective annual income tax rate expected for the full financial year. The estimated average annual tax rate used for the period to 30 June 2017 is 65.75% for crude oil activities and 30% for gas activities. As at 31st December 2016, the tax rates were 65.75% and 30% for crude oil and gas activities respectively.

Deferred income tax assets are recognised for tax losses carried forward to the extent that the realisation of the related tax benefit through future taxable profits is probable. The Group did not recognise deferred income tax assets of US$235

Notes to the interim condensed consolidated financial statements continued

million (2016: US$192 million) in respect of temporary differences amounting to US$357 million (2016: US$292 million). Out of this, deferred tax asset of $71 million (2016: US$47 million) relates tax losses of US$109 million (2016: US$71 million). There are no expiration dates for the tax losses.

14.  Loss per share (LPS)

Basic

Basic LPS is calculated on the Group's loss after taxation attributable to the parent entity and on the basis of the weighted average of issued and fully paid ordinary shares at the end of the period.

Diluted

Diluted LPS is calculated by dividing the loss attributable to ordinary equity holders of the parent by the weighted average number of ordinary shares outstanding during the year plus the weighted average number of ordinary shares that would be issued on conversion of all the dilutive potential ordinary shares (arising from outstanding share awards in the share based payment scheme) into ordinary shares.

 

Half year ended

30 June 2017

Half year ended

30 June 2016

3 months ended

30 June 2017

3 months ended

30 June 2016

 

$'000

$'000

$'000

$'000

 

 

 

 

 

Loss for the period attributable to equity holders of the parent

(27,573)

 (62,506)

(8,436)

(43,677)

 

 -

Share
'000

Share
'000

Share
'000

Weighted average number of ordinary shares in issue

563,445

560,576

563,445

560,576

Share awards

4,943

2,223

4,943

2,223

Weighted average number of ordinary shares adjusted for the effect of dilution

568,388

562,799

568,388

562,799

 

$

$

$

$

Basic loss per share

 (0.05)

(0.11)

(0.01)

(0.08)

Diluted loss per share

 (0.05)

(0.11)

(0.08)

 

 

 

 

 

 

$'000

$'000

$'000

$'000

Loss attributable to equity holders of the parent

(27,573)

 (62,506)

(8,436)

(43,677)

Loss used in determining diluted loss per share

(27,573)

 (62,506)

(8,436)

(43,677)

 

15.  Dividend

 

Half year ended

30 June 2017

Half year ended

30 June 2016

 

$'000

$'000

Dividend paid during the period

-

22,534

 

$

$

Dividend per share ($)

-

0.04

 

 

 

Notes to the interim condensed consolidated financial statements continued

16.  Interest bearing loans & borrowings

Below is the net debt reconciliation on interest bearing loans and borrowings.

 

Borrowings due within 1 year

Borrowings due above 1 year

 Total

 

US$'000

US$'000

US$'000

Balance as at 1 January 2017

 217,998

 446,098

 664,096

Effective interest

-

36,515

36,515

Effect of loan restructuring

 (28,798)

 28,798

 -  

Repayment

 -  

 (76,025)

 (76,025)

Balance as at 30 June 2017

 189,200

 435,386

 624,586

 

17.  Other asset

 

As at 30 June 2017

 

$'000

Initial fair value of investment in OML 55

250,090

Receipts from crude oil lifted

 (22,604)

Fair value adjustment as at 30 June 2017

1,514

Fair value as at 30 June 2017

229,000

 

Other asset represents the Group's rights to receive the discharge sum of US$308 million (2016: US$330 million) from the crude oil reserves of OML 55.The asset is measured at fair value through profit or loss (FVTPL) and receipts from crude oil lifted reduce the value of the asset. At each reporting date, the fair value of the discharge sum is determined using the income approach in line with IFRS 13: Fair Value Measurement. As at 30 June 2017, the fair value of the discharge sum is US$229 million (2016: US$250 million).

18.  Trade and other receivables 

 

As at 30 June 2017

As at 31 Dec 2016

 

$'000

$'000

Trade receivables

 134,378

 73,427

Nigerian Petroleum Development  Company (NPDC) receivables

224,915

 239,034

National Petroleum Investment Management Services

 6,001

 8,233

Advances on investment

65,705

 65,705

Under lift

 2,445

 4,498

Advances to suppliers

 7,513

 8,921

Other receivables

2,585

1,136

 

 -

 

Impairment loss on NPDC receivables

(10,260)

(10,260)

 

 

 

 

433,282

 390,694

 

 

18a.  Trade receivables:

Included in trade receivables is an amount due from NGC of US$87 million (2016: US$67 million) with respect to the sale of gas.

Notes to the interim condensed consolidated financial statements continued

18b.  NPDC receivables: 

NPDC receivables represent the outstanding cash calls due to Seplat from its JV partner, Nigerian Petroleum Development Company. The receivables have been discounted to reflect the impact of time value of money, and an impairment loss has been recognized in the financial statements. As at 30 June 2017, the undiscounted value of this receivable is US$225 million (2016: US$239 million).

 

18c.  Advances on investment:

 

This comprises an advance of US$45million on a potential investment in OML 25 and US$20.5 million currently held in an escrow account. Proceedings commenced against Newton Energy Limited, a wholly owned subsidiary of Seplat Plc by Crestar Natural Resources relating to the US$20.5 million currently held in an escrow account. The escrow monies relate to the potential acquisition of OML 25 by Crestar which Newton Energy has an option to invest into. These monies were placed in escrow in July 2015 pursuant to an agreement reached with Crestar and the vendor on final terms of the transaction.

19.  Share capital

19a.  Authorised and issued share capital

 

As at 30 June 2017

As at 31 Dec 2016

 

$'000

$'000

Authorised ordinary share capital

 

 

 

 

 

1,000,000,000 ordinary shares denominated in  Naira of 50 kobo per share

3,335

3,335

 

 

 

Issued and fully paid

 

 

 

 

 

563,444,561 (2016: 563,444,561) issued shares denominated in Naira of 50 kobo per share

1,826

1,826

 

 

19b.  Employee share based payment scheme

 

As at 30 June 2017, the Group had awarded shares of 25,726,262 (2016: 25,448,071 shares) to certain employees and senior executives in line with its share based incentive scheme. During the half year ended 30 June 2017, no shares were vested (31 December 2016: 2,868,460 shares had vested, resulting in an increase in number of issued and fully paid ordinary shares of 50k each from 561 million to 563 million).

 

20.  Trade and other payables

 

 

As at 30 June 2017

As at 31 Dec 2016

 

$'000

$'000

Trade payables

 104,866

 108,140

Accruals and other payables

 88,724

 83,850

NDDC levy

 5,145

 19

Deferred revenue

 121,671

 35,170

Royalties

 36,350

 34,349

 

356,756

 261,528

       

Included in accruals and other payables are field-related accruals US$36 million (2016: US$35m) and other vendor payables of US$53m (2016: US$48m). Deferred revenue includes advance payments for crude oil sales of US$120m (2016: US$34m) and royalties include accruals in respect of gas sales for which payment is outstanding at the end of the period.

Notes to the interim condensed consolidated financial statements continued

21.  Computation of cash generated from operations

 

Half year ended

30 June 2017

Half year ended

30 June 2016

 

$'000

$'000

Loss before tax

(26,454)

 (57,533)

Adjusted for:

 

 

Depletion, depreciation and amortisation

 31,336

 31,253

Interest on bank loan and other bank charges

 34,526

 41,216

Unwinding of discount on provision for decommissioning

 47

216

Interest income

 (883)

 (25,886)

Fair value loss on contingent consideration

 897

2,559

Unrealised fair value loss on crude oil hedges

-

20,787

Fair value gain on other asset

 (1,514)

-

Unrealised foreign exchange loss

866

 28,330

Share based payments expenses

 2,673

 1,650

Defined benefit expenses

 1,116

(930)  

Loss on disposal of other property, plant and equipment

82

 -

Changes in working capital (excluding the effects of exchange differences):

 

 

Trade and other receivables, including prepayments

(26,589)

 74,407

Trade and other payables

86,031

 (52,333)

Inventories

 4,107

 (23,829)

Net cash from operating activities                                                                            

106,241

 39,907

 

22.  Related party relationships and transactions

The Group is controlled by Seplat Petroleum Development Company Plc (the 'parent Company'). As at 30 June 2017, the parent Company is owned 8.39% either directly or by entities controlled by A.B.C. Orjiako ('SPDCL BVI') and members of his family and 13.15% either directly or by entities controlled by Austin Avuru ('Professional Support Limited' and 'Platform Petroleum Limited'). The remaining shares in the parent company are widely held.

22a.  Related party relationships

 

The services provided by the related parties:

Abbeycourt Trading Company Limited: The Chairman of Seplat is a director and shareholder. The company provides diesel supplies to Seplat in respect of Seplat's rig operations.

Berwick Nigeria Limited: The Chairman of Seplat is a shareholder and director. The company provides construction services to Seplat in relation to a field base station in Sapele.

Cardinal Drilling Services Limited (formerly Caroil Drilling Nigeria Limited): Is owned by common shareholders with the parent Company. The company provides drilling rigs and drilling services to Seplat.

Charismond Nigeria Limited: The sister to the CEO works as a General Manager. The company provides administrative services including stationary and other general supplies to the field locations.

Helko Nigeria Limited: The Chairman of Seplat is shareholder and director. The company owns the lease to Seplat's main office at 25A Lugard Avenue, Lagos, Nigeria.

Keco Nigeria Enterprises: The Chief Executive Officer's sister is shareholder and director. The company provides diesel supplies to Seplat in respect of its rig operations.

Montego Upstream Services Limited: The Chairman's nephew is shareholder and director. The company provides drilling and engineering services to Seplat.

Nabila Resources & Investment Ltd: The Chairman's in-law is a shareholder and director. The company provides lubricant to Seplat.

Ndosumili Ventures Limited: Is a subsidiary of Platform Petroleum Limited. The company provides transportation services to Seplat.

Nerine Support Services Limited: Is owned by common shareholders with the parent Company. Seplat leases a warehouse from Nerine and the company provides agency and contract workers to Seplat.

Oriental Catering Services Limited: The Chief Executive Officer of Seplat's spouse is shareholder and director. The company provides catering services to Seplat at the staff canteen.

ResourcePro Inter Solutions Limited: The Chief Executive Officer of Seplat's in-law is its UK representative. The company supplies furniture to Seplat.

Shebah Petroleum Development Company Limited (BVI): The Chairman of Seplat is a director and shareholder of SPDCL (BVI). SPDCL (BVI) provided consulting services to Seplat.

The following transactions were carried by Seplat with related parties:

 

22b.  Related party relationships

 

ii)    Purchases of goods and services

Half year ended

30 June 2017

Half year ended

30 June 2016

 

$'000

$'000

Shareholders of the parent company

 

 

M&P (MPI SA)

            -

           38  

SPDCL (BVI)

564

        576

 

564

614

Entities controlled by key management personnel:

 

 

Contracts > $1million in 2017

 

 

Nerine Support Services Limited

2,700 

6,215

 

2,700

6,215

 

 

 

Contracts < $1million in 2017

 

 

Abbey Court trading Company Limited

349

183

Charismond Nigeria Limited

31

20

Cardinal Drilling Services Limited

621

5,632

Keco Nigeria Enterprises

73

27

Ndosumili Ventures Limited

554

1,036

Oriental Catering Services Limited

211

284

ResourcePro Inter Solutions Limited

1

77

Berwick Nigeria Limited

 -  

28

Montego Upstream Services Limited

 -  

11,704

Nabila Resources & Investment Limited

-

5

Helko Nigeria Limited

-

411

 

1,840

19,407

Total

4,540

25,622

 

* Nerine charges an average mark-up of 7.5% on agency and contract workers assigned to Seplat. The amounts shown above are gross i.e. it includes salaries and Nerine's mark-up. Total costs for agency and contracts during the half year ended 30 June 2017 is US$2.6 million.

 

 

 

 

Notes to the interim condensed consolidated financial statements continued

 

22c.  Balances

 

The following balances were receivable from or payable to related parties as at 30 June 2017:

 

Prepayments / receivables

As at 30 June 2017

As at 31 Dec 2016

 

$'000

$'000

Entities controlled by key management personnel

 

 

Cardinal Drilling Services Limited

 6,200

6,211

 

 6,200

6,211

 

Payables

As at 30 June 2017

As at 31 Dec 2016

 

$'000

$'000

Entities controlled by key management personnel

 

 

Cardinal Drilling Services Limited

621

1,009

Abbey Court Petroleum Company Limited

291

-

Charismond Nigeria Limited

21

-

Ndosumili Ventures Limited

457

-

ResourcePro Inter Solutions Limited

1

-

Nerine Support Services Limited

2,616

11,411

Montego Upstream Services Limited

-

11,540

 

4,007

23,960

 

23.  Commitments and contingencies

23a. Operating lease commitments - Group as lessee

 

The Group leases drilling rigs, buildings, land, boats and storage facilities. The lease terms are between 1 and 5 years. The operating lease commitments of the Group as at 30 June 2017 are:

 

Operating lease commitments

As at 30 June 2017

As at 31 Dec 2016

 

$'000

$'000

Not later than one year

119

119

Later than one year and not later than five years

271

271

 

390

390

23b. Contingent consideration

     

As part of the purchase agreement of OML 53, a portion of the consideration is contingent on the performance of the producing asset. There will be additional cash payments to the previous owners should the oil price rise above US$90/bbl in the three year period following the acquisition date.

 

Significant unobservable valuation inputs are shown below:

Discount rate        15.45%

 

A significant increase or decrease in the discount rate would result in a lower/ (higher) fair value of the liability.

 

The fair value of the contingent consideration determined at 31 December 2016 reflects the current and projected crude oil prices, amongst other factors and a fair value adjustment has been recognised in profit or loss.

 

A reconciliation of the fair value of the contingent consideration liability is provided below:

 

 

 

As at 30 June 2017

 

$'000

Initial fair value of the contingent consideration at acquisition date

10,427

Unrealised fair value changes recognised in profit or loss during year ended 31 December 2016

1,613

Financial liability for the contingent consideration as at 31 December 2016

12,040

Fair value adjustment as at 30 June 2017

897

Contingent consideration as at 30 June 2017

12,937

 

23c. Contingent liabilities

 

The Group is involved in a number of legal suits as defendant. The estimated value of the contingent liabilities for the period ended 30 June 2017 is US$ 174 million (2016: US$15.5 million). No provision has been made for this potential liability in these financial statements. Management and the Group's solicitors are of the opinion that the Group will suffer no loss from these claims.

24.  Events after the reporting period

There was no significant event after the reporting date which could have a material effect on the state of affairs of the Group as at 30 June 2017 and on the profit or loss for the half year ended on that date, which have not been adequately provided for or disclosed in these financial statements.

25.  Compliance with FRC Rule 1

In compliance with the regulatory requirement in Nigeria that the CFO, who signs the Annual Report and Accounts, must be a member of a professional accountancy body recognised by an Act of the National Assembly in Nigeria, the CFO of Seplat, Roger Brown, has been granted a waiver by the Financial Reporting Council of Nigeria to sign the accounts of the Group.

26.  Reclassification

Certain comparative figures have been reclassified in line with the current year's presentation.

 

 

 

 

 

General information

 

Company secretary

Mirian Kachikwu

 

Registered office and business

 

 

Address of directors

25a Lugard Avenue

Ikoyi

Lagos

Nigeria

 

Registered number

RC No. 824838

 

FRC number

FRC/2015/NBA/00000010739

 

Auditors

Ernst & Young

10th & 13th Floor, UBA House

57 Marina Lagos.

 

Registrars

DataMax Registrars Limited

7 Anthony Village Road

Anthony

P.M.B 10014

Shomolu

Lagos, Nigeria

 

Solicitors

Abraham Uhunmwagho & Co

Adepetun Caxton-Martins Agbor & Segun ('ACAS-Law')

Austin and Berns Solicitors

Chief J.A. Ororho & Co.

Consolex LP

Freshfields Bruckhaus Deringer LLP

G.C. Arubayi & Co.

Herbert Smith Freehills LLP

J.E. Okodaso & Company

Norton Rose Fulbright LLP

Ogaga Ovrawah & Co.

Olaniwun Ajayi LP

O. Obrik. Uloho and Co.

Streamsowers & Kohn

Thompson Okpoko & Partners

V.E. Akpoguma & Co.

Winston & Strawn London LLP

 

Bankers

Citibank Nigeria Limited

First Bank of Nigeria Limited

HSBC Bank

Skye Bank Plc

Stanbic IBTC Bank Plc

Standard Chartered Bank

United Bank for Africa Plc

Zenith Bank Plc

 

 

 

 

 


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