Final Results
Final Results for the Year Ended 30 June 2010
Pantheon Resources plc ("Pantheon", the "Company" or the "Group"), the AIM-quoted oil and gas exploration company active in Louisiana and Texas, today announces its final results for the period ended 30 June 2010.
HIGHLIGHTS
· Financial year under review commenced on a positive note as an extension of the Brookeland field (Austin Chalk) into Pantheon's Tyler County acreage was confirmed.
· Operator, Vision Gas Resources LLC ("Vision"), now considers the Tyler County project proven as a development play.
· Plans to drill a second well, Kara Farms #1, ("KF#1H"), have been impacted by the shortage of large horizontal rigs and the resulting rising cost leading to a series of unavoidable delays.
· Vision's current expectation is for drilling to commence in December 2010 or January 2011.
· The KF#1H well is scheduled to test both the main Austin Chalk target and secondary Woodbine objective which are two independent and totally separate targets.
· Drilling delays should not distract from the positive developments that have occurred at Tyler County.
· Extensive geological analyses on both the Austin Chalk and Woodbine objectives have led to further confidence in the entire Tyler County play and enhanced expectations.
· Projected economics for the Tyler County project remain positive at current natural gas price. Leverage from either a modest natural gas price increase or reduction in service costs is high.
· Through the Joint Venture Pantheon continues to build its acreage position in this exciting play.
· Pantheon raised a total of £7.8 million after expenses in difficult stock market conditions though two separate share placings.
· Loss for the year of £2.54m versus £3.05m last year. Results include impairment charges of £1.4m which included the final costs incurred in connection with the plug and abandonment of the Vision Rice University #1 well in September 2009.
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In accordance with the AIM Rules, the information in this announcement has been reviewed and signed off by Jay Cheatham, who has over 30 years’ relevant experience within the sector.
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For further information on Pantheon Resources plc, see the website at: www.pantheonresources.com
Further information:
Pantheon Resources plc
|
Jay Cheatham, CEO Justin Hondris, Director, Finance and Corporate Development |
+44 20 7484 5359
|
Oriel Securities Limited (Nominated Adviser)
|
Michael Shaw |
+44 20 7710 7600 |
CHAIRMAN'S STATEMENT FOR THE YEAR ENDED 30 JUNE 2010
For Pantheon the financial year under review commenced on a strong note for its key strategic Tyler County, East Texas project. Confirmation was received that the adjacent Brookeland field in the Austin Chalk extended into Pantheon's acreage with all the encouraging ramifications this had for the rest of the acreage. The Group's optimism for its Tyler County project appeared well founded and shared as Pantheon was able to raise a total of £7.8 million in difficult stock market conditions through two separate share placings completed in August and December 2009 respectively. The December 2009 placing was particularly important for the Group as it secured Pantheon's participation in its crucial Tyler County venture, which remains a high leverage project for the Group.
Pantheon and its shareholders have endured a frustrating twelve months since then. Plans to drill a second well, Kara Farms #1, ("KF#1H"), have been subject to a series of unwelcome but unavoidable delays caused essentially by a shortage of suitable specialised drilling rigs and rising costs. The operator of the Joint Venture ("JV"), Vision Gas Resources LLC ("Vision"), had also been hampered by the requirement to drill only a single well at this stage rather than embark on a large multi-well programme. This left it, and the JV, at a competitive disadvantage and subject to rigs only becoming available when released by other operators. Rather than enter a "bidding war" Vision opted to wait until a rig became available. It is hoped that the current decline in rig utilisation rates continues as this would provide support that availability will occur relatively soon.
Once a rig becomes available then drilling operations should proceed quickly. This reflects the progress made at the selected drilling location for KF#1H. Vision's revised schedule is for the KF#1H well to spud in December 2010 or January 2011. However the timing of rig availability to Vision remains subject to their release by current operators.
The delays to drilling should not distract from the positive developments that have occurred at Tyler County. The operator has not been idle and has undertaken further and extensive geological analyses on both the main Austin Chalk target and at the secondary Woodbine. This work has enhanced the JV's expectations and led to further confidence in the entire Tyler County play. More encouragement may also occur should Krescent Energy Company's ("Krescent") nearby well yield positive results. Located on offset acreage to the east of the JV's proposed well, Krescent's well is in a structurally similar position to Pantheon's Tyler County acreage. Initial results announced recently have provided some encouragement.
Moreover the JV continues to be active in building its acreage portfolio in the region, which remains an on-going process. This has led to the addition of material acreage which Pantheon considers to be of strategic importance.
Pantheon retains an overlooked asset in its Bullseye acreage which has been identified by recent work. The main prospect is now considered to lie in the Camerina formation where potential gross reserve estimates in excess of five million barrels of oil equivalent ("mmboe") have been made by the operator.
The main issue at Bullseye has been how to constrain drilling and completion costs for further wells. Two well locations for the Miogyp have been identified, each with potential gross reserves of over 500 thousand barrels of oil ("mbo") according to the operator. At present a well has been scheduled for 2011, although this will not occur without confidence that drilling and completion costs will be reduced substantially. Achieving a reduction in costs is the subject of a study now underway.
The next few months should witness not only the start of drilling on the long-awaited second well on Pantheon's Tyler County acreage but also the fifth anniversary of the Group's debut on the AIM. In this short period, Pantheon has undergone a series of changes both to its asset base and its management. However the prospect for a potential corporate transformation has never been greater than it is at present. This exciting outlook should not be lost in the understandable frustration and disappointment at the seemingly incessant delays to drilling; sentiments which are shared by all the members of the Board. As drilling of KF#1H gets underway the focus should shift to exploiting the enormous potential that Pantheon has at Tyler County. The Board looks forward to an exciting and busy year ahead when technical success should be converted into commercial achievement.
Susan Graham
17 November 2010
CHIEF EXECUTIVE OFFICER'S STATEMENT FOR THE YEAR ENDED 30 JUNE 2010
Pantheon's plans to spud a second well on Tyler County play have been impacted by the shortage of large horizontal rigs and the resulting rising cost. Vision Gas Resources LLC, ("Vision"), the operator, has been reluctant to try and outbid operators with larger drilling programmes than the Joint Venture's ("JV") single well contract. Although the expected economics for the Tyler County project remain positive at current natural gas prices, the leverage from either a modest natural gas price increase or reduction in service prices is high. The JV would expect to produce natural gas to the sales pipeline five or six months after a commitment to drill. A well spudding in December 2010 or January 2011 would result in production during the summer cooling season.
At the time of last year's CEO statement US natural gas prices were about US$5 per million BTU ("mmBTU") and the number of horizontal gas rigs in service in the US was slightly above 400. Currently natural gas prices have fallen to just above US$3 per mmBTU while more than 600 horizontal gas rigs are in service. This increase in horizontal gas rig activity is a direct result of drilling in the unconventional Barnett and Haynesville gas shale plays of Texas and Louisiana and the Marcellus in Pennsylvania. Additionally, many horizontal rigs are drilling in the Eagleford shale in South Texas which is primarily an oil play. These factors have led to drilling rig numbers and service costs being at an all time high. Last year I wrote that many shale gas plays had become uneconomic. While at the current rig rates and natural gas prices this remains the case, many producers continue to drill to hold acreage and generate cash flow. Time and stock prices will be the ultimate arbiters.
Operational Review
Tyler County
The proposed second well on Pantheon's Tyler County acreage, Kara Farms #1("KF#1H"), is located west of the Vision Rice University #1 ("VRU#1") well on a structural nose in the Austin Chalk. This location also offsets Vision's Louisiana Pacific #2 well which produces from the Woodbine. The KF#1H well is scheduled to test both the Austin Chalk and Woodbine formations in a structurally optimum location. It should be remembered that the two targets are independent and totally separate plays.
A new completion method has been developed to ensure there is not a repeat of the rubble problems encountered in VRU#1. It is now planned to complete the KF#1H well using a wire wrapped slotted liner. This allows barite fines to flow but blocks the rubblised formations, which are small formation pebbles that were produced and blocked the well bore in the VRU#1 well.
Although Pantheon has not been active with the drill bit, the JV has optimised its acreage position. The latter is now over 30,000 acres. The JV has continued studying the play geologically. Recent work gives the JV an improved outlook for the Austin Chalk and also for the secondary target in the Woodbine.
Krescent Energy Company ("Krescent") has completed a well to the east, offsetting the JV's acreage. This well is located in a structurally similar position to Pantheon's Tyler County acreage. Any positive outcome would provide further confidence to the JV. Krescent has announced some initial test results recently which are encouraging. However the well remains in a clean-up phase and further information is awaited.
Bullseye
Gross production from Bullseye has declined throughout the year from 800 barrels oil equivalent per day ("boepd") in July 2009 to 280 boepd in July 2010 and 240 boepd currently. Lease operating costs have been lowered significantly due to improvements at the water disposal well. As a result, the economic limit on Bullseye wells is extremely low.
A recent study of the Laurel Ridge Field (Bullseye plus offset acreage) confirms that at least two additional Miogyp locations exist on Pantheon's Bullseye acreage in updip positions north of the existing wells. The operator estimates that these two locations should each have potential gross reserves of over 500 thousand barrels of oil. The key to exploiting these potential reserves is the ability to drill and complete efficiently in the Miogyp formation. At current oil prices and drilling a straight hole to control costs, a new Miogyp well is very economic.
Recent work indicates that the real upside at Bullseye resides in the Camerina formation where the operator estimates potential gross reserves to be in excess of five million barrels oil equivalent ("mmboe"). Offset wells in the area have had initial gross production rates of 500 barrels a day ("bopd") plus 1,200 thousand cubic feet a day ("mcfd") of natural gas. A study is under way to determine future drilling and completion costs at Bullseye. It is anticipated that a Miogyp well will be drilled in 2011. A drill stem test is also proposed for the Camerina as part of the plan for this well. Plans to drill a well are dependent upon costs being reduced significantly.
Production
During the 2010 financial year Pantheon's net production averaged 45.4 boepd. This is essentially unchanged from the 46.6 boepd achieved in the previous financial year. Flush production from Jumonville #2 ("J#2"), which came on stream in June 2009 and peaked in October, offset the decline from Jumonville #1 (J#1"). J#1 was shut in during February 2010 before resuming in March. The lower water disposal expenses at Bullseye reduced the economic operating threshold for J#1.
Baptiste continued as a small gas producer. For the 2010 financial year Pantheon was predominantly an oil producer in contrast to previous years when most of its output was natural gas. With the oil to gas price ratio at over 20:1 versus a normal 10:1, the Group has benefitted financially from this pricing anomaly.
Conclusion
Pantheon did not achieve its operational objectives for Tyler County in the year under review due to factors beyond its control. Three achievements were realised, however. First the JV increased its acreage position in the Tyler County area. Secondly further geological analyses enhanced both the outlook for the Tyler County acreage and the JV's confidence in the project. Finally Pantheon secured funding. The current financial year should witness Pantheon achieving its corporate objective of proving up the exciting Tyler County venture.
Jay Cheatham
17 November 2010
FINANCE DIRECTOR'S REPORT FOR THE YEAR ENDED 30 JUNE 2010
Financial Review
The Group made a loss for the financial year ended 30 June 2010 of £2,540,396 (2009: £3,048,360).
Approximately £1,400,000 of this loss related to the final costs incurred with the drilling of the Vision Rice University #1 ("VRU#1") well and to other impairment charges taken against the group assets as at 30 June 2010.
The decision to plug and abandon the VRU#1 well in September 2009 was solely for mechanical reasons, despite the well being considered a geological success by the operator, Vision Gas Resources LLC, and confirming the extension of the Brookeland field in Tyler County. It was therefore decided to adopt a conservative accounting treatment and write-off all direct costs relating to the well.
This write-off does not have any bearing on the prospectivity of the Tyler County acreage which continues to have the potential to be of significant value to the Group in the Directors' opinion.
Production
The Group's net total sales production for the financial year ended 30 June 2010 amounted to 42.7 (2009: 128.6) mcfd natural gas and 36.2 (2009: 25.3) bopd oil. Average realisations for the year for natural gas and oil were US$3.87 (2009: US$7.38) per mcf and US$72.00 (2009: US$53.57) per barrel respectively.
Revenue
Revenues for the year ended 30 June 2010 were higher than the previous year at £639,372 (2009: £515,639). This reflected a change to the production mix between the two financial years. In the financial year ended 30 June 2010 Pantheon produced more crude oil. Averagerealisedcrude oil prices rose 34% year-on-year.
Cost of Sales
Cost of sales for the year ended 30 June 2010 was higher than the previous year at £700,484 (2009: £459,771). The major component of this amount was depreciation of producing assets and facilities which accounted for £492,487 of the total cost of sales.
Impairments
The total impairment charge of £1,398,794 (2009: £2,317,579) comprised the final costs associated with the final write-off of costs associated with the Vision Rice University #1 well ("VRU#1") following the decision to plug and abandon the well in September 2009, and other impairment charges taken against the group assets as at 30 June 2010.
Accounting Policies
There have been no major changes to accounting policies during the year.
Debt Financing
Short term borrowings as at 30 June 2010 were £nil (2009: £1,072,816) having been repaid in full during the year.
Capital Structure
The Company undertook two separate equity capital raisings during the year. In August 2009 the Company placed 4,554,600 Ordinary shares with investors at an issue price of £0.12. This raised £0.507 million after costs. In December 2009 the Company placed 57,708,040 Ordinary shares with investors at an issue price of £0.1325 to raise £7.3 million after costs.
Additionally the Group implemented an executive long term incentive scheme. This was developed in conjunction with external executive compensation consultants, Deloitte LLP, and involved a change to the Group's options in issue. Full details of this can be found at Note 21.
As at 30 June 2010 there were 102,099,770 shares in issue.
Going Concern
The Group was successful in raising additional equity capital and repaying its debt finance during the year. The Group is satisfied with its ability to operate as a going concern for the next 12 months.
Taxation
The Group incurred a loss for the year and has not incurred a tax charge. The directors have not considered it appropriate to recognise a deferred tax asset to reflect the potential benefit arising from these timing differences.
Risk Assessment
The Group's oil and gas activities are subject to a variety of risks, both financial and operational, including but not limited to those outlined below. These and other risks have the potential to materially affect the financial performance of the Group.
Liquidity and Interest Rate Risk
Liquidity risk has increased for many companies as a result of the recent global economic crisis, in particular for companies with smaller market capitalisations.
Interest Rate risk and the cost and availability of debt and equity finance have been dramatically affected following the global economic crisis. The Group was pleased to have successfully completed two fundraisings within the period in the context of the economic climate.
Oil & Gas Price Risk
Oil and Gas sales revenues were subject to the volatility of the underlying commodity prices throughout the year. At the present time, the US energy sector is exhibiting stronger oil prices and weaker gas prices due to a variety of reasons. Paradoxically, despite a weaker gas price, demand for drilling unconventional gas plays in the US is at or near record high levels resulting in a very high cost environment for rigs and associated drilling services. This has resulted in the Group's activities at Tyler County being delayed, however operations are expected to commence in the near term.
The Group did not engage in any hedging activity during the year.
Currency Risk
Almost all capital expenditure and operational revenues for the year were denominated in US dollars. The Group keeps the majority of its cash resources denominated in US Dollars throughout the year to minimise volatility and foreign currency risk. The Group did not engage in any hedging activity during the year.
Financial Instruments
As this stage of the Group's activities it has not been considered appropriate or necessary to enter into any derivatives strategies or hedging strategies. Once the Group's production revenues increase substantially, such strategies will be reviewed on a more regular basis.
Justin Hondris
17 November 2010
DIRECTORS' REPORT FOR THE YEAR ENDED 30 JUNE 2010
The Directors present their report together with the audited accounts of Pantheon Resources plc ("Pantheon" or "the Company") and its subsidiary undertakings (together "the Group") for the year ended 30 June 2010.
Principal activity
The Company is registered in England and Wales, having been incorporated under the Companies Act with registered number 05385506 as a public company limited by shares.
The principal activity of the Group is the investment in oil and gas exploration and development. The Group operates in the U.K. through its parent undertaking and in the USA through subsidiary companies, details of which are set out in the note 8 to these accounts.
Results and dividends
The Group results for the period are set out below. The Directors do not propose to recommend any distribution by way of a dividend for the year ended 30 June 2010.
Key operational risks and uncertainties
The Group is in the business of exploration and production of oil and gas. Accordingly, the principal operational risks and uncertainties affecting the Group include, but are not limited to, the time and monetary costs associated with the unsuccessful drilling of prospects; mechanical or other technical problems encountered during the drilling of prospects; mechanical or other technical problems which may from time to time affect existing production; the potential for increased costs for drilling in a tight rig market; the uncertainty surrounding potential recoverability of reserves; deterioration in commodity prices or economic conditions; and the potential for unexpected deterioration or abandonment of existing production. Pursuant to the terms of the respective joint ventures, and typical for the industry, the Group is also potentially exposed to the timing, financial and operational position of those joint ventures, in particular with respect to the timing, and therefore payment for the proposed drilling of wells.
Information to shareholders - website
The Group maintains its own website (www.pantheonresources.com) to facilitate provision of information to external stakeholders and potential investors and to comply with Rule 26 of the AIM rules for companies.
Capital raising
The Company undertook two equity capital raisings during the year. In August 2009 the Company placed with investors 4,554,600 Ordinary shares in the Company at an issue price of £0.12 to raise £0.507m after costs. Additionally, in December 2009 the Company placed with investors 57,708,040 Ordinary shares in the Company at an issue price of £0.1325 to raise £7.3m after costs.
Group structure and changes in share capital
Details of movements in share capital during the period are set out in note 15 to these accounts.
Directors
The following Directors held office during the period:
Susan Graham (Non-Executive Chairman)
John Cheatham (Chief Executive Officer)
Justin Hondris (Executive Director)
Andrew Waller (Non-Executive Director)
John Walmsley (Non-Executive Director)
Directors' interests
The beneficial and non-beneficial interests in the Company's shares of the Directors and their families were as follows:
|
Name |
30 June 2010 Number of Ordinary shares of £0.01 |
30 June 2009 Number of Ordinary shares of £0.01 |
|
S Graham |
200,000 |
114,925 |
|
J Cheatham |
2,609,249 |
1,140,849 |
|
J Hondris |
760,000 |
300,000 |
|
A Waller* |
698,427 |
450,000 |
|
J Walmsley** |
1,059,637 |
150,000 |
* 200,000 of these ordinary shares are held by Rosepoint Capital Pty Limited (a company in which A Waller is interested).
** 377,358 of these ordinary shares are held by John Walmsley's spouse.
Share options
Share options over Ordinary shares of £0.01 held by Directors on 30 June 2010 were as follows:
|
|
|
|
|
|
Number of options |
|||||
|
Exercise price |
£0.20 |
£0.30 |
£0.40 |
£0.50 |
£0.60 |
£1.00 |
£1.25 |
£1.50 |
£2.00 |
Total |
|
|
|
|
|
|
|
|
|
|
|
|
|
S Graham |
- |
- |
- |
- |
- |
250,000 |
250,000 |
200,000 |
200,000 |
900,000 |
|
J Cheatham* |
201,844 |
400,000 |
300,000 |
300,000 |
200,000 |
- |
- |
- |
- |
1,401,844 |
|
J Hondris* |
- |
350,000 |
250,000 |
200,000 |
100,000 |
- |
- |
- |
- |
900,000 |
|
A Waller |
- |
- |
- |
- |
- |
- |
- |
150,000 |
150,000 |
300,000 |
|
J Walmsley |
- |
- |
- |
- |
|
100,000 |
- |
100,000 |
100,000 |
300,000 |
|
Total |
201,844 |
750,000 |
550,000 |
500,000 |
300,000 |
350,000 |
250,000 |
450,000 |
450,000 |
3,801,844 |
*On 11 September 2009 under the long term executive incentive scheme, the options with exercise prices ranging from £0.30 to £0.60 were issued to Mr J. Cheatham and Mr J. Hondris. These options vest equally in three tranches on 11 September 2009, 30 June 2010 and 30 June 2011.
Report on Directors' remuneration and service contracts
The service contracts of all the Directors are subject to a six month termination period.
Pensions
The Group does not operate a pension scheme for Directors or employees.
Directors' remuneration
Remuneration of Directors was as follows:
|
|
Fees/basic |
Employers |
Benefits |
2010 |
|
|
salary |
NI/Payroll tax |
in kind |
Total |
|
|
£ |
£ |
£ |
£ |
|
S Graham |
62,500 |
6,537 |
- |
69,037 |
|
J Cheatham |
189,561 |
7,266 |
- |
196,827 |
|
J Hondris |
125,000 |
14,537 |
- |
139,537 |
|
A Waller* |
25,000 |
- |
- |
25,000 |
|
J Walmsley |
37,500 |
4,663 |
- |
42,163 |
|
|
439,561 |
33,003 |
- |
472,564 |
* The Directors' remuneration presented includes an accrual for £12,500 for unpaid Directors' fees as at 30 June 2010
Substantial shareholders
The Company has been notified, in accordance with Chapter 5 of the FSA Disclosure and Transparency Rules, of the under noted interests in its ordinary shares as at 12 November 2010:
|
|
Number of Ordinary Shares |
% of Share Capital |
|
|
|
|
|
Pershing Nominees Limited |
16,031,950 |
15.70 |
|
Argo Exploration Limited |
7,000,000 |
6.86 |
|
Rock (Nominees) Limited |
5,169,973 |
5.06 |
|
Barclayshare Nominees Limited |
5,005,889 |
4.90 |
|
Credit Suisse Client Nominees (UK) limited |
3,570,000 |
3.50 |
|
Lynchwood Nominees Limited |
3,430,238 |
3.36 |
|
HSBC Client Holdings Nominee (UK) Limited |
3,232,742 |
3.17 |
|
Nutraco Nominees Limited |
3,128,802 |
3.06 |
Supplier payment policy
The Company's policy is that payments to suppliers are made in accordance with those terms and conditions agreed between the Company and its suppliers, providing that all trading terms and conditions have been complied with.
Political and charitable contributions
There were no political or charitable contributions made by the Company during the year ended 30 June 2010.
Remuneration and Nomination Committee
The Board of Directors has established the Remuneration and Nomination Committee of the Board. Susan Graham is chairman of the Remuneration and Nomination Committee and John Walmsley is the other member. Both members are Non-Executive Directors of the Company. Other Directors may attend meetings by invitation.
The Remuneration and Nomination Committee meets as required, but at least twice a year. Its role is to assist the Board in determining the remuneration arrangements and contracts of executive Directors and senior employees, and the appointment or re-appointment of Directors. It also has the responsibility for reviewing the performance of the executive Directors and for overseeing administration of the Company's share option schemes. No Director is however involved in deciding his own remuneration.
The decision to appoint, or re-appoint, a Director is made by the Board following recommendation by the Nomination Committee.
Audit Committee
An Audit Committee of the Board has been established. The Audit Committee consists of John Walmsley as chairman and Susan Graham is the other member. This Committee provides a forum through which the Group's finance functions and auditors report to the non-executive Directors. Meetings may be attended, by invitation, by the Director of Finance and Corporate Development, the Company Secretary, other executive Directors and the Company's auditors.
The Audit Committee meets at least twice a year. Its terms of reference include review of the Annual and Interim Accounts, consideration of the Company and Group's accounting policies, the review of internal control, risk management and compliance procedures, and consideration of all issues surrounding the annual audit. The Audit Committee will also meet with the auditors and review their reports relating to accounts and internal control systems.
To follow best practice, and in accordance with International Standard ISA 260, the external auditors have held discussions with the Audit Committee on the subject of auditor independence and have confirmed their independence in writing.
Conflicts Committee
A Conflicts Committee of the Board has been established. This Committee consists of Susan Graham as chairman, John Walmsley and Jay Cheatham.
The role of the Conflicts Committee is to assist the Board in monitoring actual and potential conflicts under the definitions of the Companies Act 2006. Under the Companies Act 2006 Directors are responsible for their individual disclosures of actual or potential conflict. To follow best practice, the Conflicts Committee holds discussions with the Company's UK lawyers.
Statement of Directors' responsibilities
The Directors are responsible for preparing the financial statements in accordance with applicable laws and International Financial Reporting Standards ("IFRS") as adopted by the European Union. Company Law requires the Directors to prepare financial statements for each financial period which give a true and fair view of the state of affairs of the Group and of the Company and of the profit or loss of the Group for that period. In preparing those financial statements, the Directors are required to:
a) select suitable accounting policies and then apply them consistently;
b) make judgements and estimates that are reasonable and prudent;
c) prepare the financial statements on the going concern basis unless it is inappropriate to presume that the Group will continue in business; and
d) state whether applicable accounting standards have been followed, subject to any material departures disclosed and explained in the financial statements.
The Directors confirm that the financial statements comply with the above requirements.
The Directors are responsible for keeping proper accounting records which disclose with reasonable accuracy at any time the financial position of the Group and Company and to enable them to ensure that the financial statements comply with the Companies Act 2006. The Directors are also responsible for safeguarding the assets of the Group and hence for taking steps for the prevention and detection of fraud and other irregularities. The Directors are responsible for the maintenance and integrity of the corporate and financial information included on the Company's website.
Statement of disclosure to the auditors
So far as the Directors are aware:
a) there is no relevant audit information of which the Company's auditors are unaware; and
b) all the Directors have taken all the steps that they ought to have taken to make themselves aware of any relevant audit information and to establish that the auditors are aware of that information.
Auditors
In accordance with Section 489 of the Companies Act 2006, a resolution proposing that UHY Hacker Young be reappointed as auditors of the Company and that the Directors be authorised to determine their remuneration will be put to the next Annual General Meeting.
By order of the board
Justin Hondris
Director
17 November 2010
Company Number 05385506
DIRECTORS' BIOGRAPHIES FOR THE YEAR ENDED 30 JUNE 2010
Susan Graham, Chairman
Susan Graham has many years of experience in the oil and gas sector. She joined Merrill Lynch in 1986 and was Managing Director and Global Head of the Energy Team from 1998 until her retirement in 2003. During her 27 year City career, she gained extensive experience in both primary and secondary equity markets on a global basis. This involved lead roles in the privatisations of British Gas, Britoil, CNOOC, Elf Aquitaine, ENI, MOL, Norsk Hydro, OMV, Petrobras, Repsol, Total and YPF. She assisted in the introduction of Enterprise Oil and LASMO to US markets and was also involved in M&A activity including Total's mergers with PetroFina and Elf. She acts as Chairman of Pantheon's Remuneration and Nomination Committee.
She has an M.A. in Chemistry from Lady Margaret Hall, Oxford and an MSc in Forensic Archaeological Science from University College London. She is a member of the Securities Institute and the National Association of Petroleum Investment Analysts.
John Cheatham, Chief Executive Officer
Jay Cheatham has more than 35 years' experience in all aspects of the petroleum business. He has extensive international experience in both oil and natural gas, primarily for ARCO. At ARCO, Jay held a series of senior appointments. These include Senior Vice President and District Manager (ARCO eastern District) with direct responsibility for Gulf Coast US operations and exploration and President of ARCO International where he had responsibility for all exploration and production outside the U.S. Jay's most recent appointment was as President and CEO of Rolls-Royce Power Ventures, where he had the key responsibility for restructuring the company.
Jay also has considerable financial skills in addition to his corporate and operational expertise. He has acted as Chief Financial Officer for ARCO's US oil and natural gas company (ARCO Oil & Gas). Moreover he has understanding of the capital markets through his past position as CEO to the Petrogen Fund, a private equity fund.
Justin Hondris, Director - Finance and Corporate Development
Justin Hondris brings international experience in Private Equity investment management, corporate finance and investment banking. He previously qualified as a Chartered Accountant (although is no longer an active member), and as an Associate of the Securities Institute of Australia. He spent nearly 5 years at Cazenove & Co, in London, and prior to that at Hartley Poynton, an Australian based investment bank with a strong presence in the junior resources sector.
Andrew Waller, Director
Andrew Waller has extensive public company experience spanning various sectors, although heavily weighted towards the mining sector in areas including oil and gas, uranium, gold and chrome. He also brings relevant skills in capital raising and project management, in Europe, Africa and Australasia.
John Walmsley, Director
John Walmsley has over 30 years' experience in the energy sector as either adviser or principal. This includes periods as Chief Executive of Hardy Oil & Gas (1994 - 1998) and Managing Director, Finance and Business Development, of Enterprise Oil plc (1984 - 1993). He is currently Executive Chairman of Consilience Energy Advisory Group Ltd (CEAG). He has international business and financial experience in Europe, Asia-Pacific and North America at the corporate, institutional and senior government level. He is a fellow of the Institute of Chartered Accountants in England and Wales and was a Tax Partner at Arthur Anderson prior to joining Enterprise Oil. He acts as Chairman of Pantheon's Audit Committee.
INDEPENDENT AUDITOR'S REPORT TO THE MEMBERS OF PANTHEON RESOURCES PLC
FOR THE YEAR ENDED 30 JUNE 2010
We have audited the financial statements of Pantheon Resources plc for the year ended 30 June 2010 which comprise the Consolidated Statement of Comprehensive Income, the Consolidated and Parent Company Statements of Changes in Equity, the Consolidated and Parent Company Balance Sheets, the Consolidated and Parent Company Cash Flow Statements and the related notes. The financial reporting framework that has been applied in their preparation is applicable law and International Financial Reporting Standards (IFRSs) as adopted by the European Union.
This report is made solely to the Company's members, as a body, in accordance with Chapter 3 of Part 16 of the Companies Act 2006. Our audit work has been undertaken so that we might state to the Company's members those matters we are required to state to them in an auditor's report and for no other purpose. To the fullest extent permitted by law, we do not accept or assume responsibility to anyone other than the Company and the Company's members as a body, for our audit work, for this report, or for the opinions we have formed.
Respective Responsibilities of Directors and Auditors
As explained more fully in the Statement of Directors' Responsibilities, set out above, the Directors are responsible for the preparation of the financial statements and for being satisfied that they give a true and fair view. Our responsibility is to audit the financial statements in accordance with applicable law and International Standards on Auditing (UK and Ireland). Those standards require us to comply with the Auditing Practices Board's (APB's) Ethical Standards for Auditors.
Scope of the audit of the financial statements
A description of the scope of an audit of financial statements is provided on the APB's web-site at www.frc.org.uk/apb/scope/UKNP.
Opinion on financial statements
In our opinion:
· the financial statements give a true and fair view of the state of the Group's and of the Parent Company's affairs as at 30 June 2010 and of the Group's loss for the year then ended;
· the financial statements have been properly prepared in accordance with IFRSs as adopted by the European Union; and
· the financial statements have been prepared in accordance with the requirements of the Companies Act 2006.
Opinion on other matters prescribed by the Companies Act 2006
In our opinion the information given in Directors' Report for the financial year for which the financial statements are prepared is consistent with the financial statements.
Matters on which we are required to report by exception
We have nothing to report in respect of the following matters where the Companies Act 2006 requires us to report to you if, in our opinion:
· adequate accounting records have not been kept by the Parent Company, or returns adequate for our audit have not been received from branches not visited by us; or
· the Parent company financial statements are not in agreement with the accounting records and returns; or
· certain disclosures of Directors' remuneration specified by law are not made; or
· we have not received all the information and explanations we require for our audit.
Michael Egan (Senior Statutory Auditor)
For and on behalf of
UHY Hacker Young, Statutory Auditor
Quadrant House
4 Thomas More Square
London E1W 1YW
17 November 2010
CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME FOR THE YEAR ENDED 30 JUNE 2010
|
|
|
|
|
|
|
Notes |
2010 |
2009 |
|
|
|
£ |
£ |
|
|
|
|
|
|
Turnover |
3 |
639,372 |
515,639 |
|
Cost of sales |
|
(700,484) |
(459,771) |
|
|
|
|
|
|
Gross (loss) / profit |
|
(61,112) |
55,868 |
|
|
|
|
|
|
Administrative expenses before share based payments and impairment losses |
|
(779,763) |
(801,892) |
|
Share based payments |
21 |
(84,489) |
(102,506) |
|
Impairment of intangible assets |
13 |
(312,758) |
(2,317,579) |
|
Impairment of tangible assets |
14 |
(1,086,036) |
- |
|
Total administration expenses |
4 |
(2,263,046) |
(3,221,977) |
|
|
|
|
|
|
Operating loss |
|
(2,324,158) |
(3,166,109) |
|
|
|
|
|
|
Interest payable |
6 |
(222,074) |
- |
|
Interest receivable |
6 |
5,836 |
117,749 |
|
|
|
|
|
|
Loss before taxation |
|
(2,540,396) |
(3,048,360) |
|
|
|
|
|
|
Taxation |
7 |
- |
- |
|
|
|
|
|
|
Loss for the year |
|
(2,540,396) |
(3,048,360) |
|
|
|
|
|
|
Other comprehensive income for the year |
|
|
|
|
|
|
|
|
|
Foreign currency movement |
|
660,535 |
673,314 |
|
|
|
|
|
|
Total comprehensive income for the year |
|
(1,879,861) |
(2,375,046) |
|
|
|
|
|
|
Loss per ordinary share - basic and diluted |
2 |
(3.34) p |
(7.07)p |
All of the above amounts are in respect of continuing operations.
CONSOLIDATED CHANGES IN EQUITY FOR THE YEAR ENDED 30 JUNE 2010
|
|
Share |
Share |
Retained |
Currency |
Equity |
Total |
|
|
capital |
premium |
earnings |
reserve |
reserve |
|
|
|
£ |
£ |
£ |
£ |
£ |
£ |
|
Group |
|
|
|
|
|
|
|
At 1 July 2009 |
398,372 |
14,723,365 |
(13,280,569) |
431,664 |
758,412 |
3,031,244 |
|
Net loss for the year |
- |
- |
(2,540,396) |
- |
- |
(2,540,396) |
|
Other comprehensive income: |
|
|
|
|
|
|
|
Foreign currency translation |
- |
- |
- |
660,535 |
- |
660,535 |
|
Total comprehensive income for the period |
- |
- |
(2,540,396) |
660,535 |
- |
(1,879,861) |
|
Issue of shares |
622,626 |
7,192,439 |
- |
- |
- |
7,815,065 |
|
Share based payment- issue of options |
- |
- |
- |
- |
84,489 |
84,489 |
|
Transfer of previously expensed share based payment on cancellation of options |
- |
- |
172,984 |
- |
(172,984) |
- |
|
Balance at 30 June 2010 |
1,020,998 |
21,915,804 |
(15,647,981) |
1,092,199 |
669,917 |
9,050,937 |
|
|
|
|
|
|
|
|
CONSOLIDATED CHANGES IN EQUITY FOR THE YEAR ENDED 30 JUNE 2010
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Share |
Share |
Retained |
Currency |
Equity |
Total |
|
|
capital |
premium |
earnings |
reserve |
reserve |
|
|
|
£ |
£ |
£ |
£ |
£ |
£ |
|
Group |
|
|
|
|
|
|
|
At 1 July 2008 |
397,339 |
14,723,365 |
(10,281,176) |
(241,650) |
704,873 |
5,302,751 |
|
Net loss for the year |
- |
- |
(3,048,360) |
- |
- |
(3,048,360) |
|
Other comprehensive income: |
|
|
|
|
|
|
|
Foreign currency translation |
- |
- |
- |
673,314 |
- |
673,314 |
|
Total comprehensive income for the period |
- |
- |
(3,048,360) |
673,314 |
- |
(2,375,046) |
|
Share based payment- issue of shares |
1,033 |
- |
- |
- |
48,967 |
50,000 |
|
Share based payment- issue of options |
- |
- |
- |
- |
53,539 |
53,539 |
|
Excess of share based payment over par value of issued shares |
- |
- |
48,967 |
- |
(48,967) |
- |
|
Balance at 30 June 2009 |
398,372 |
14,723,365 |
(13,280,569) |
431,664 |
758,412 |
3,031,244 |
CONSOLIDATED BALANCE SHEET AS AT 30 JUNE 2010
|
|
|
|
|
|
|
Notes |
2010 |
2009 |
|
|
|
£ |
£ |
|
ASSETS |
|
|
|
|
Fixed assets |
|
|
|
|
Intangible fixed assets |
13 |
3,539,252 |
2,202,814 |
|
Tangible fixed assets |
14 |
1,597,093 |
2,238,513 |
|
|
|
5,136,345 |
4,441,327 |
|
|
|
|
|
|
Current assets |
|
|
|
|
Trade and other receivables |
9 |
345,572 |
78,761 |
|
Cash and cash equivalents |
10 |
3,848,111 |
52,682 |
|
|
|
4,193,683 |
131,443 |
|
Total assets |
|
9,330,028 |
4,572,770 |
|
|
|
|
|
|
LIABILITIES |
|
|
|
|
Creditors: amounts falling due within one year Short term borrowings |
11 12 |
279,091 - |
468,710 1,072,816 |
|
Total liabilities |
|
279,091 |
1,541,526 |
|
|
|
|
|
|
Net assets |
|
9,050,937 |
3,031,244 |
|
|
|
|
|
|
EQUITY |
|
|
|
|
Capital and reserves |
|
|
|
|
Called up share capital |
15 |
1,020,998 |
398,372 |
|
Share premium account |
15 |
21,915,804 |
14,723,365 |
|
Retained losses |
|
(15,647,981) |
(13,280,569) |
|
Currency reserve |
|
1,092,199 |
431,664 |
|
Equity reserve |
|
669,917 |
758,412 |
|
|
|
|
|
|
Shareholders' funds |
|
9,050,937 |
3,031,244 |
The financial statements were approved by the Board on 17 November 2010
Justin Hondris
Director
Justin Hondris
Director
CONSOLIDATED CASH FLOW STATEMENT FOR THE YEAR ENDED 30 JUNE 2010
|
|
|
|
|
|
|
Notes |
2010 |
2009 |
|
|
|
£ |
£ |
|
Net cash (outflow)/ inflow from operating activities |
16 |
(1,136,567) |
(294,693) |
|
|
|
|
|
|
Cash flows from investing activities |
|
|
|
|
Interest received |
|
5,836 |
117,749 |
|
Interest paid |
|
(170,227) |
- |
|
Acquisition of tangible fixed assets |
|
(206,047) |
(2,223,420) |
|
Funds used for drilling and exploration |
|
(2,048,504) |
(2,385,842) |
|
Net cash outflow from investing activities |
|
(2,418,942) |
(4,491,513) |
|
|
|
|
|
|
Cash flows from financing activities |
|
|
|
|
Proceeds from issue of shares |
|
7,843,741 |
1,033 |
|
Issue costs Short term loan received |
|
(377,802) 61,000 |
- 1,072,816 |
|
Short term loan repaid |
|
(836,536) |
- |
|
Net cash inflow from financing activities |
|
6,690,403 |
1,073,849 |
|
|
|
|
|
|
Net increase/ (decrease) in cash and cash equivalents |
|
3,134,894 |
(3,712,357) |
|
|
|
|
|
|
Effect of foreign currency translation |
|
660,535 |
673,314 |
|
|
|
|
|
|
Cash and cash equivalents at the beginning of the year |
|
52,682 |
3,091,725 |
|
|
|
|
|
|
Cash and cash equivalents at the end of the year |
10 |
3,848,111 |
52,682 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
NOTES TO THE FINANCIAL STATEMENTS FOR THE YEAR ENDED 30 JUNE 2010
1. Accounting policies
A summary of the principal accounting policies, all of which have been applied consistently throughout the period, is set out below.
1.1. Basis of preparation
The financial statements have been prepared using the historical cost convention. In addition, the financial statements have been prepared in accordance with the International Financial Reporting Standards ("IFRS") including IFRS 6, Exploration for and Evaluation of Mineral Resources, as adopted by the European Union ("EU") and in accordance with the provisions of the Companies Act 2006.
The Group's financial statements for the year ended 30 June 2010 were authorised for issue by the board of Directors on 17 November 2010 and the balance sheets were signed on the Board's behalf by Mr J Hondris.
The Group financial statements are presented in UK pounds sterling.
In accordance with the provisions of Section 408 of the Companies Act 2006, the Company has not presented a profit and loss account. A loss for the year ended 30 June 2010 of £815,739 (2009: loss of £592,750) has been included in the income statement.
1.2. Basis of consolidation
Subsidiaries are fully consolidated from the date on which control is transferred to the Group. They are de-consolidated from the date that control ceases. The purchase method of accounting is used to account for the acquisition of subsidiaries by the Group. The cost of an acquisition is measured as the fair value of the assets given, equity instruments issued and liabilities incurred or assumed at the date of exchange, plus costs directly attributable to the acquisition. Identifiable assets acquired and liabilities and contingent liabilities assumed in a business combination are measured initially at their fair values at the acquisition date, irrespective of the extent of any minority interest. The excess of the cost of acquisition over the fair value of the Group's share of the identifiable net assets acquired is recorded as goodwill. Goodwill arising on acquisitions is capitalised and subject to impairment review, both annually and when there are indications that the carrying value may not be recoverable.
Inter-company transactions, balances and unrealised gains on transactions between group companies are eliminated.
All the companies over which the Company has control apply, where appropriate, the same accounting policies as the Company.
1.3. New standards and amendments
The following amendments to standards are mandatory for the first time for the financial periods commencing on or after 1 January 2009:
IAS1 (revised) 'Presentation of financial statements' includes the requirement to present a Statement of Changes in Equity as a primary statement and introduces the possibility of either a single Statement of Comprehensive Income (combining the Income Statement and a Statement of Comprehensive Income) or to retain the Income Statement with a supplementary Statement of Comprehensive Income. The Directors have chosen the first option. As this standard is concerned with presentation only it does not have any impact on the results or net assets of the Group.
IFRS8 'Operating segments'. IFRS8 replaces IAS 14 'Segment reporting'. It requires a 'management approach' under which segment information is presented on the same basis as that used for internal reporting purposes. Following a review of the Group's internal management information, the Group maintains that it only has one class of business, the production, exploration and development of mineral resources and that primary segmental reporting is determined by geography according to the location of assets.
Operating segments are reported in a manner consistent with the internal reporting provided to the chief operating decision maker. The chief operating decision maker has been identified as the Board of Directors.
1.4. Going Concern
The Group incurred a loss of £2,540,396 for the year (2009: £3,048,360). Approximately £1,400,000 of this loss related to the costs associated with the write off of the Vision Rice University #1 ("VRU#1") well which was plugged and abandoned in September 2009, and to other impairment charges taken against the Group's assets as at 30 June 2010.
Importantly, the VRU#1 well was a geological success and confirmed the extension of the Brookeland field in Tyler County. The Tyler County project has the potential to be of significant value to the Group in the Directors' opinion. However as the VRU#1 well was a non-producer it was decided to adopt a conservative accounting treatment and write-off all direct drilling costs relating to the well.
The Directors believe the Tyler County Joint Venture to be of material potential value to the Group, based upon the geological success of the VRU#1 well, coupled with the very high success rates enjoyed by the drilling activity adjacent to the JV acreage. Additionally, further potential for material shareholder value arises from the independent and totally separate Woodbine target, which lies below the primary Austin Chalk target, and is anticipated to be tested in the forthcoming well.
Accordingly, the Directors believe the inherent value in the Group's projects, coupled with the revenues from the Bullseye project are sufficient to ensure the going concern of the Group, and have prepared the financial statements on a going concern basis.
1.5. Revenue
Oil and Gas revenue represents amounts invoiced (exclusive of sales related taxes) for the Group's share of oil and gas sales in the year.
Interest revenue is recognised on a proportional basis taking into account the interest rates applicable to the financial assets.
1.6. Foreign currency translation
(i) Functional and presentational currency
The financial statements are presented in Pounds Sterling ("£"), which is the functional currency of the Company and is the Group's presentation currency.
Items included in the Company's subsidiary entities are measured using United States Dollars ("US$"), which is the currency of the primary economic environment in which they operate.
(ii) Transactions and balances
Transactions in foreign currencies are translated into Sterling at the rate of exchange ruling at the date of the transaction. Monetary assets and liabilities denominated in foreign currencies are translated at the rate of exchange ruling at the balance sheet date. The resulting exchange gain or loss is dealt with in the income statement.
The assets, liabilities and the results of the foreign subsidiary undertakings are translated into Sterling at the rates of exchange ruling at the year end. Exchange differences resulting from the retranslation of net investments in subsidiary undertakings are treated as movements on reserves.
1.7. Cash and cash equivalents
The Company considers all highly liquid investments, with a maturity of 90 days or less to be cash equivalents, carried at the lower of cost or market value.
1.8. Deferred taxation
Deferred tax is provided in full, using the liability method, on temporary differences arising between the tax bases of assets and liabilities and their carrying amounts in the financial statements. Deferred tax is determined using tax rates (and laws) that have been enacted or substantially enacted by the balance sheet date and expected to apply when the related deferred tax is realised or the deferred liability is settled.
Deferred tax assets are recognised to the extent that it is probable that the future taxable profit will be available against which the temporary differences can be utilized.
1.9. Exploration and development costs
The Group follows the 'successful efforts' method of accounting for exploration and evaluation costs. All costs associated with oil, gas and mineral exploration and investments are capitalised on a project by project basis, pending determination of the feasibility of the project. Costs incurred include appropriate technical and administrative expenses but not general corporate overheads. If an exploration project is successful, the related expenditures will be transferred to Developed Oil and Gas Properties and amortised over the estimated life of the commercial reserves on a unit of production basis. Where a licence is relinquished or project abandoned, the related costs are written off. Where the Group maintains an interest in a project, but the value of the project is considered to be impaired, a provision against the relevant capitalised costs will be raised.
The recoverability of all exploration and development costs is dependent upon the discovery of economically recoverable reserves, the ability of the Group to obtain necessary financing to complete the development of the reserves and future profitable production or proceeds from the disposition thereof. When production commences the accumulated costs for the relevant area are transferred from intangible fixed assets to tangible fixed assets as 'Developed Oil & Gas Assets' or 'Production Facilities and Equipment', as appropriate.
Amounts recorded for these assets represent costs and are not intended to reflect present or future values.
1.10. Impairment of exploration and development costs and depreciation of fixed assets
Impairment reviews on development and producing assets are carried out regularly. When events or changes in circumstances indicate that the carrying amount of expenditure attributable to a successful well may not be recoverable from future net revenues from oil and gas reserves attributable to that well, a comparison between the net book value of the cost attributable to that well and the discounted future cash flows from that well is undertaken. To the extent that the carrying amount exceeds the recoverable amount, the cost attributable to that well is written down to its recoverable amount and charged as an impairment.
Discounted cash flow calculations were conducted on all developed oil and gas assets in the portfolio as at 30 June 2010. Estimates of future net cash flows are based on various factors including but not limited to estimated remaining oil and gas reserves, future prices for sales of oil and natural gas and future operating and development costs. Such amounts are estimates based upon available knowledge and can therefore be subject to error or change. All discounted future cash flow estimates were performed using an appropriate discount rate of 10% and commodity prices assumptions of $75.00 per barrel of oil and $4.50 per mcf natural gas.
In relation to the Bullseye project, estimates of recoverable oil and gas reserves have been developed by the Group after consultations with the operator and an outside geological consultant. The Group has used an estimation of 3.5 million BOE of gross reserves for the basis of depreciation charges. Future operating and development costs were based upon current cost levels. For impairment purposes, the Group further discounted the Camerina reserves by 40% to reflect the risk of entering this new formation.
In relation to the Tyler County project, pursuant to the successful efforts method of accounting, all direct costs relating to the VRU#1 well have been written off. Accordingly, the carrying value as at 30 June 2010 solely represents back costs paid in relation to the project and prepaid costs towards the forthcoming well. Based on estimates by a third party technical consultant, the Group estimates potential for up to or exceeding 40 wells at an average gross reserve of 8 bcfe natural gas per well. Based upon those estimates the directors believe the carrying values at 30 June 2010 are supported.
Developed Oil and Gas Properties are amortised over the estimated life of the commercial reserves on a unit of production basis.
Other tangible fixed assets are stated at cost less depreciation. Depreciation is provided at rates calculated to write off the costs less estimated residual value of each asset over its estimated useful life as follows:
- Production Facilities and Equipment are depreciated by equal instalments over their expected useful lives, being seven years.
- Office equipment is depreciated by equal annual instalments over their expected useful lives, being four years.
1.11. Financial instruments
IFRS7 requires information to be disclosed about the impact of financial instruments on the Group's risk profile, how the risks arising from financial instruments might affect the entity's performance, and how these risks are being managed.
The Group's policies include that no trading in derivative financial instruments shall be undertaken. Thesedisclosures have been made in Note 20 to the accounts.
1.12. Share based payments
On occasion the Company made share-based payments to certain Directors and advisers by way of issue of share options. The fair value of these payments is calculated by the Company using the Black-Scholes option pricing model. The expense is recognised on a straight line basis over the period from the date of award to the date of vesting, based on the Company's best estimate of the number of shares that will eventually vest.
1.13. Critical accounting estimates and judgements
The preparation of financial statements in conformity with International Financial Reporting Standards requires the use of accounting estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of income and expenses during the reporting period. Although these estimates are based on management's best knowledge of current events and actions, actual results ultimately may differ from those estimates. IFRS also require management to exercise its judgement in the process of applying the Group's accounting policies.
The areas involving a higher degree of judgement or complexity, or areas where assumptions and estimates are significant to the financial statements are as follows:
Impairment of intangible assets
Determining whether an intangible asset is impaired requires an estimation of whether there are any indications that its carrying value is not recoverable.
At each reporting date, the Company reviews the carrying value of its tangible and intangible assets to determine whether there is any indication that those assets have been impaired. If such an indication exists, the recoverable amount of the asset, being the higher of the asset's fair value less costs to sell and value in use, is compared to the asset's carrying value. Any excess of the asset's carrying value over its recoverable amount is expensed to the income statement.
Developed Oil & Gas Properties
Developed Oil & Gas Properties are amortised over the life of the area according to the estimated rate of depletion of the economically recoverable reserves. If the amount of economically recoverable reserves varies, this will impact on the amount of the asset which should be carried on the balance sheet.
Share based payments
The Group records charges for share based payments.
For option based share based payments, to determine the value of the options management estimate certain factors used in the option pricing model, including volatility, vesting date, exercise date of options and the number of options likely to vest.
At each reporting date during the vesting period management estimate the number of shares that will vest after considering the vesting criteria.
If these estimates vary from actual occurrence, this will impact on the value of the equity carried in the reserves.
1.14. New standards and interpretations not applied
During the year, the IASB and IFRIC have issued a number of new standards, amendments and interpretations with an effective date after the date of these financial statements. Of these, only the following are expected to be relevant to the Group:
Standard Subject Effective from
IFRS 2 Share Based Payment - Amendment relating to group
cash-settled share-based payment transactions 1 January 2010
IFRS5 Non-current assets held for sale and discontinued operations
- Amendments resulting from May 2008 Annual Improvements to IFRSs 1 January 2010
IFRS 8 Operating Segments -Amendments resulting from 2009 Annual
Improvements to IFRSs 1 January 2010
IFRS 9 Financial Instruments - Classification and Measurement 1 January 2013
IAS 1 Presentation of Financial Statements - Amendments resulting
from April 2009 Annual Improvements to IFRSs 1 January 2010
IAS 7 Statement of Cash Flows - Amendments resulting from April
2009 Annual Improvements to IFRSs 1 January 2010
IAS 17 Leases - Amendments resulting from April 2009 Annual
Improvements to IFRSs 1 January 2010
IAS 24 Related Party Disclosures - Revised definition of related parties 1 January 2011
IAS 32 Financial Instruments: Presentation - Amendments relating to
classification of rights issues 1 February 2010
IAS 36 Impairment of Assets - Amendments resulting from April 2009
Annual Improvements to IFRSs 1 January 2010
IAS 38 Intangible Assets - Amendments resulting from April 2009
Annual Improvements to IFRSs 1 July 2010
IAS 39 Financial Instruments: Recognition and Measurement - Amendments 1 January 2010
IFRIC19 Extinguishing Financial Liabilities with Equity Instruments 1 July 2010
2. Loss per share
The basic loss per share of 3.34p (2009: 7.07p) for the Group is calculated by dividing the loss for the year by the weighted average number of ordinary shares in issue of 74,876,908 (2009: 39,826,654).
The diluted loss per share has been kept the same as the basic loss per share as the conversion of share options decreases the basic loss per share, thus being anti-dilutive.
3. Segmental information
The Group's activities involve production of and exploration for oil and gas. There are two reportable operating segments: USA and Head Office. Fixed Assets, income and operating liabilities are attributable to the USA, whilst most of the corporate administration is conducted through Head Office.
Each reportable segment adopts the same accounting policies.
In compliance with IFRS 8 the following tables reconcile the operational loss and the assets and liabilities of each reportable segment with the consolidated figures presented in these Financial Statements, together with comparative figures for the year ended 30 June 2009.
Year ended 30 June 2010
|
Geographical segment (Group) |
Head Office |
USA |
Consolidated |
|
|
£ |
£ |
£ |
|
Turnover |
- |
639,372 |
639,372 |
|
Cost of sales |
- |
(700,484) |
(700,484) |
|
Interest payable |
(222,074) |
- |
(222,074) |
|
Interest receivable |
1,651 |
4,185 |
5,836 |
|
Impairment of assets |
- |
(1,398,794) |
(1,398,794) |
|
Share-based payments |
(84,489) |
- |
(84,489) |
|
Administration expenses |
(510,828) |
(268,935) |
(779,763) |
|
Loss by reportable segment |
(815,740) |
(1,724,656) |
(2,540,396) |
|
|
|
|
|
|
|
|
|
|
|
Developed oil & gas properties |
- |
1,055,932 |
1,055,932 |
|
Exploration and development costs |
- |
3,539,252 |
3,539,252 |
|
Tangible fixed assets |
1,004 |
540,157 |
541,161 |
|
Trade and other receivables |
59,122 |
286,450 |
345,572 |
|
Cash and cash equivalents |
479,400 |
3,368,711 |
3,848,111 |
|
Intercompany balances |
16,073,576 |
(16,073,576) |
- |
|
Total assets by reportable segment |
16,613,102 |
(7,283,074) |
9,330,028 |
|
|
|
|
|
|
Total liabilities by reportable segment |
(65,415) |
(213,676) |
(279,091) |
|
|
|
|
|
3. Segmental information
Year ended 30 June 2009
|
Geographical segment (Group) |
Head Office |
USA |
Consolidated |
|
|
£ |
£ |
£ |
|
Turnover |
- |
515,639 |
515,639 |
|
Cost of sales |
- |
(459,771) |
(459,771) |
|
Interest received |
110,147 |
7,602 |
117,749 |
|
Impairment of investment |
- |
(2,317,579) |
(2,317,579) |
|
Share-based payments |
(102,506) |
- |
(102,506) |
|
Administration expenses |
(600,391) |
(201,501) |
(801,892) |
|
Loss by reportable segment |
(592,750) |
(2,455,610) |
(3,048,360) |
|
|
|
|
|
|
Exploration and development costs |
- |
2,202,814 |
2,202,814 |
|
Developed oil & gas properties |
- |
2,236,150 |
2,236,150 |
|
Fixed assets |
2,362 |
- |
2,362 |
|
Trade and other receivables |
63,858 |
14,903 |
78,761 |
|
Cash and cash equivalents |
38,643 |
14,039 |
52,682 |
|
Intercompany balances |
10,693,805 |
(10,693,805) |
- |
|
Total assets by reportable segment |
10,798,668 |
(6,225,899) |
4,572,769 |
|
|
|
|
|
|
Total liabilities by reportable segment |
(1,334,797) |
(206,728) |
(1,541,525) |
4. Operating loss
|
|
|
2010 |
2009 |
|
This is stated after charging: |
|
£ |
£ |
|
Auditor's remuneration |
|
|
|
|
- group and parent company audit services |
|
13,000 |
15,000 |
|
Auditor's remuneration for non audit services |
|
|
|
|
- taxation services |
|
4,490 |
2,784 |
|
|
|
17,490 |
17,784 |
5. Directors' emoluments
|
|
|
2010 |
2009 |
|
|
|
£ |
£ |
|
|
|
|
|
|
Wages and salaries |
|
439,561 |
443,199 |
|
Social security costs |
|
33,003 |
43,457 |
|
|
|
472,564 |
486,656 |
There are no employees other than the Directors.
Further details on Directors' emoluments are recorded in the Directors' Report.
|
6. Interest payable and receivable |
|
|
|
|
Interest payable |
|
2010 |
2009 |
|
|
|
£ |
£ |
|
|
|
|
|
|
Interest on short term borrowings |
|
222,074 |
- |
|
|
|
|
|
|
Interest receivable |
|
2010 |
2009 |
|
|
|
£ |
£ |
|
|
|
|
|
|
Bank interest |
|
5,836 |
117,749 |
|
|
|
|
|
|
7. Taxation |
|
|
|
|
2010 |
2009 |
|
|
£ |
£ |
|
|
|
|
|
|
|
|
|
Factors affecting the tax charge for the period |
|
|
|
Loss on ordinary activities before taxation |
(2,540,396) |
(3,048,360) |
|
|
|
|
|
Loss on ordinary activities before taxation |
|
|
|
multiplied by standard rate of corporation |
|
|
|
tax of 28.0% (2009 28.0%) |
(711,311) |
(853,541) |
|
|
|
|
|
Effects of: |
|
|
|
Non deductible expenses |
415,319 |
21,467 |
|
Timing differences not recognised |
11,711 |
26,063 |
|
Losses in the period not used |
284,281 |
806,011 |
|
|
|
|
|
Total tax charge |
- |
- |
|
|
|
|
Factors that may affect future tax charges
At the balance sheet date the Group has unused losses carried forward of approximately £17,000,000 (2009: £12,100,000) for offset against future suitable profits. Approximately £15,000,000 (2009: £12,000,000) of the losses were sustained in the USA. Unrecognised US tax losses expire within 20 years of the year in which they were sustained.
The Directors do not consider it appropriate to recognise a deferred tax asset in respect of such losses or in respect of accelerated tax depreciation allowances, due to the uncertainty of future profit streams. The contingent deferred tax assets are estimated to be £5.6m (2009: £4.2m) in respect of losses carried forward and £15,000 (2009: £38,000) in respect of accelerated depreciation allowances.
8. Subsidiary entities
The Company currently has the following wholly owned subsidiaries all of which were incorporated on 3 February 2006:
Country of Percentage
Name Incorporation ownership Activity
Hadrian Oil & Gas LLC United States 100% Holding company
Agrippa LLC United States 100% Holding company
Pantheon Oil & Gas LP United States 100% Oil & gas exploration
Pantheon Oil & Gas LP is 99% owned by Agrippa LLC as its limited partner and 1% by Hadrian Oil & Gas LLC as its general partner.
|
9. Trade and other receivables |
|
|
|
|
Group |
Group |
|
|
2010 |
2009 |
|
|
£ |
£ |
|
|
|
|
|
Amounts falling due within one year: |
|
|
|
Trade receivables |
286,450 |
14,903 |
|
Prepayments and accrued income |
46,464 |
51,909 |
|
Other receivables |
12,658 |
11,949 |
|
|
345,572 |
78,761 |
|
Amounts falling due after more than one year : |
|
|
|
|
|
|
|
Amount due from subsidiary undertakings |
- |
- |
|
|
|
|
|
10. Cash and cash equivalents |
|
|
|
|
Group |
Group |
|
|
2010 |
2009 |
|
|
£ |
£ |
|
|
|
|
|
Cash at bank and in hand |
3,848,111 |
52,682 |
|
11. Trade and other payables |
|
|
|
|
Group |
Group |
|
|
2010 |
2009 |
|
|
|
£ |
|
|
|
|
|
Trade creditors |
38,501 |
61,633 |
|
Accruals |
240,590 |
407,077 |
|
|
279,091 |
468,710 |
|
12. Short term borrowings |
|
|
|
|
Group |
Group |
|
|
2010 |
2009 |
|
|
|
£ |
|
|
|
|
|
Amounts falling due within one year: |
|
|
|
Bridging finance facility |
- |
1,072,816 |
|
As at 30 June 2010 |
- |
1,072,816 |
The Bridging finance facilities were issued for a period of one year and bear interest at 24% per annum. The Bridging finance facility is secured on the future revenues of the Bullseye Project, Louisiana and Tyler County, East Texas.
|
13. Intangible fixed assets
|
|
Exploration and development costs
|
|
|
Group |
|
2010 £ |
2009 £ |
|
|
|
|
|
|
Cost |
|
|
|
|
At 1 July |
|
13,672,059 |
11,286,217 |
|
Additions |
|
2,048,504 |
2,385,842 |
|
Retirements of previously abandoned wells |
|
(11,775,592) |
- |
|
Transfer to fixed assets |
|
(552,873) |
- |
|
Effects of foreign exchange |
|
147,154 |
- |
|
At 30 June |
|
3,539,252 |
13,672,059 |
|
Impairment |
|
|
|
|
At 1 July |
|
11,469,245 |
9,151,666 |
|
Impairment during the period |
|
312,758 |
2,317,579 |
|
Transfer to fixed assets |
|
(6,411) |
- |
|
Retirements of previously abandoned wells |
|
(11,775,592) |
- |
|
At 30 June |
|
- |
11,469,245 |
|
|
|
|
|
|
Net book value |
|
|
|
|
At 30 June 2010 and 30 June 2009 |
|
3,539,252 |
2,202,814 |
|
At 30 June 2009 and 30 June 2008 |
|
2,202,814 |
2,134,551 |
|
|
|||
The Company had no intangible assets at either 30 June 2010 or 30 June 2009.
14. Tangible fixed assets
|
Group |
Developed Oil & Gas Properties £ |
Production Facilities and Equipment £ |
Office Equipment £ |
Total £ |
|
Cost |
|
|
|
|
|
At 30 June 2009 |
2,492,243 |
- |
5,424 |
2,497,667 |
|
Transferred from intangible assets |
- |
552,873 |
- |
552,873 |
|
Additions |
175,700 |
30,347 |
- |
206,047 |
|
Retirement of assets |
(246,495) |
- |
- |
(246,495) |
|
Effects of foreign exchange |
233,423 |
56,221 |
- |
289,644 |
|
At 30 June 2010 |
2,654,871 |
639,441 |
5,424 |
3,299,736 |
|
Depreciation |
|
|
|
|
|
At 30 June 2009 |
256,093 |
- |
3,061 |
259,154 |
|
Transferred from intangible assets |
- |
6,411 |
- |
6,411 |
|
Depreciation for the year |
406,300 |
86,188 |
1,359 |
493,847 |
|
Impairments for the year |
1,086,036 |
- |
- |
1,086,036 |
|
Depreciation on retired assets |
(237,159) |
- |
- |
(237,159) |
|
Effects of foreign exchange |
88,699 |
5,655 |
- |
94,354 |
|
At 30 June 2010 |
1,599,969 |
98,254 |
4,420 |
1,702,643 |
|
|
|
|
|
|
|
Net book value |
|
|
|
|
|
At 30 June 2010 |
1,054,907 |
541,187 |
1,004 |
1,597,093 |
|
At 30 June 2009 |
1,790,069 |
- |
2,363 |
2,238,513 |
|
Group |
|
Developed Oil & Gas Properties £ |
Office Equipment £ |
Total £ |
|
Cost |
|
|
|
|
|
At 30 June 2008 |
|
268,823 |
5,424 |
274,247 |
|
Additions |
|
2,223,420 |
- |
2,223,420 |
|
At 30 June 2009 |
|
2,492,243 |
5,424 |
2,497,667 |
|
Depreciation |
|
|
|
|
|
At 30 June 2008 |
|
104,779 |
1,713 |
106,492 |
|
Depreciation for the year |
|
151,314 |
1,348 |
152,662 |
|
At 30 June 2009 |
|
256,093 |
3,061 |
259,154 |
|
|
|
|
|
|
|
Net book value |
|
|
|
|
|
At 30 June 2009 |
|
2,236,150 |
2,363 |
2,238,513 |
|
At 30 June 2008 |
|
164,044 |
3,711 |
167,755 |
|
15. Called up share capital |
|
2010 |
2009 |
|
|
|
£ |
£ |
|
|
|
|
|
|
Allotted, issued and fully paid: |
|
|
|
|
102,099,770 ordinary shares of £0.01 each |
|
1,020,998 |
398,372 |
Following the implementation of the Companies Act 2006 the company's authorised share capital was abolished.
|
|
|
Number |
Issued and fully paid Capital |
Share Premium Reserve |
|
|
|
|
£ |
£ |
|
Movement in issued Capital: |
|
|
|
|
|
As at 1 July 2009 |
|
39,837,130 |
398,372 |
14,723,365 |
|
Issue of 4,554,600 shares on 23 August 2009 |
|
4,554,600 |
45,546 |
501,006 |
|
Share issue costs |
|
- |
- |
(38,952) |
|
Issue of 57,708,040 shares on 16 December 2009 |
|
57,708,040 |
577,080 |
7,069,235 |
|
Share issue costs |
|
- |
- |
(338,850) |
|
As at 30 June 2010 |
|
102,099,770 |
1,020,998 |
21,915,804 |
The ordinary shares rank pari passu in all respects including the right to receive dividends and other distributions declared, made or paid.
16. Net cash (outflow)/ inflow from operating activities
|
|
Group |
Group |
|
|
2010 |
2009 |
|
|
£ |
£ |
|
|
|
|
|
Operating loss |
(2,324,158) |
(3,166,109) |
|
Impairment |
1,398,794 |
2,317,579 |
|
Depreciation |
493,846 |
152,662 |
|
Loss on retirement of assets |
9,336 |
- |
|
Cost of issuing share options |
84,489 |
102,506 |
|
Decrease/(increase) in trade and other receivables |
(266,811) |
1,300,961 |
|
(Decrease)/increase in trade and other payables |
(189,620) |
(1,002,292) |
|
Effect of translation differences |
(342,443) |
- |
|
Net cash (outflow)/ inflow from operating activities |
(1,136,567) |
(294,693) |
17. Control
No one party is identified as controlling the Company.
18. Decommissioning expenditure
The Directors have considered the environmental issues and the need for any necessary provision for the cost of rectifying any environmental damage, as might be required under local legislation. In their view, no provision is necessary for any future costs of decommissioning or any environmental damage.
19. Capital commitments
The Group has no obligation to drill any further wells or make any further payments in respect of any new wells in any of its joint ventures. Should the Group elect to not participate in any wells beyond the first well in the Tyler County joint venture then it would forfeit its interest over the remainder of the programme.
As at 30 June 2010, the Group has no fixed financial commitments in respect of any other programmes other than maintaining its interest in its existing joint ventures. Before any new wells are commenced in relation to these joint ventures, the Group must first elect to participate in any proposed well thereby allowing the Group to decline participation if it deems appropriate.
20. Financial instruments
The Group's principal financial instruments comprise cash and cash equivalents, trade and other receivables and trade and other payables.
The main purpose of cash and cash equivalents financial instruments is to finance the Group's operations. The Group's other financial assets and liabilities such as receivables and trade payables, arise directly from its operations. It is, and has been throughout the entire period, the Group's policy that no trading in financial instruments shall be undertaken.
The main risk arising from the Group's financial instruments is market risk. Other minor risks are summarised below. The Board reviews and agrees policies for managing each of these risks.
Market risk
Market risk is the risk that changes in market prices, and market factors such as foreign exchange rates and interest rates will affect the entity's income or the value of its holdings of financial instruments.
The objective of market risk management is to manage and control market risk exposures within acceptable parameters while optimising the return.
The Company does not use derivative products to hedge foreign exchange risk and has exposure to foreign exchange rates prevailing at the dates when funds are transferred into different currencies.
Cash flow interest rate risk
The Group's exposure to the risks of changes in market interest rates relates primarily to the Group's cash and cash equivalents with a floating interest rate. These financial assets with variable rates expose the Group to cash flow interest rate risk. All other financial assets and liabilities in the form of receivables and payables are non-interest bearing. The Group does not engage in any hedging or derivative transactions to manage interest rate risk.
In regard to its interest rate risk, the Group continuously analyses its exposure. Within this analysis consideration is given to potential renewals of existing positions, alternative investments and the mix of fixed and variable interest rates. The Group has no policy as to maximum or minimum level of fixed or floating instruments.
Interest rate risk is measured as the value of assets and liabilities at fixed rate compared to those at variable rate.
Weighted average Fixed Non - interest
interest rate interest rate
Financial assets: % £ £
Cash on Deposit 0.025 3,848,111 -
Trade and other receivables - - 345,572
Net fair value
The net fair value of financial assets and financial liabilities approximates to their carrying amount as disclosed in the balance sheet and in the related notes.
Currency risk
The functional currency for the Group's operating activities is the Pound Sterling and for exploration activities the United States of America dollar. The Group has not hedged against currency depreciation but continues to keep the matter under review.
Financial risk management
The Directors recognise that this is an area in which they may need to develop specific policies should the Group become exposed to wider financial risks as the business develops.
Liquidity risk
Liquidity risk is the risk that the entity will not be able to meet its financial obligations as they fall due.
The objective of managing liquidity risk is to ensure as far as possible, that it will always have sufficient liquidity to meet its liabilities when they fall due, under both normal and stressed conditions.
The entity has established a number of policies and processes for managing liquidity risk. These include:
- Continuously monitoring actual and budgeted cash flows and longer term forecasting cash flows;
- Monitoring the maturity profiles of financial assets and liabilities in order to match inflows and outflows; and
- Monitoring liquidity ratios (working capital).
Credit risk management
Credit risk refers to the risk that a counterparty will default on its contractual obligations resulting in financial loss to the Group. The Group's main counterparties are the operators of the respective projects. Funds are normally only remitted on a prepayment basis a short period before the expected commencement of drilling. The Group has adopted a policy of only dealing with what it believes to be creditworthy counterparties and would consider obtaining sufficient collateral where appropriate, as a means of mitigating the risk of financial loss from defaults. The Group's exposure and the credit ratings of its counterparties are continuously monitored and the aggregate value of transactions concluded is spread amongst approved counterparties.
Trade receivables at 30 June 2010 consist primarily of revenues owed for production. Ongoing credit evaluation is performed on the financial condition of accounts receivable.
Capital management
The Group's objective when managing capital is to ensure that adequate funding and resources are obtained to enable it to develop its projects through to profitable production, while in the meantime safeguarding the Group's ability to continue as a going concern. This is aimed at enabling it, once the projects come to fruition, to provide appropriate returns for shareholders and benefits for other stakeholders. Capital will continue to be sourced from equity and from borrowings as appropriate.
21. Share based payments
Included within administration expenses is a charge for issuing shares and share options.
|
|
|
|
|
|
Group |
Group |
|
|
2010 |
2009 |
|
|
£ |
£ |
|
|
|
|
|
Cost of issuing share options |
84,489 |
53,539 |
|
Cost of issuing shares |
- |
48,967 |
|
|
84,489 |
102,506 |
|
Movements in share options in issue |
|
|
|
|
|
Exercise price |
Number of options issued as of 30 June 2009 |
Issued during year |
Cancelled or exercised during year |
Number of options issued as of 30 June 2010 |
|
£0.20 |
321,844 |
18,300 |
- |
340,144 |
|
£0.30 |
- |
750,000 |
- |
750,000 |
|
£0.40 |
- |
550,000 |
- |
550,000 |
|
£0.50 |
- |
500,000 |
- |
500,000 |
|
£0.60 |
- |
300,000 |
- |
300,000 |
|
£1.00 |
833,284 |
- |
(250,000) |
583,284 |
|
£1.25 |
500,000 |
- |
(250,000) |
250,000 |
|
£1.50 |
950,000 |
- |
(350,000) |
600,000 |
|
£2.00 |
1,050,000 |
- |
(450,000) |
600,000 |
|
Total |
3,655,128 |
2,118,300 |
(1,300,000) |
4,473,428 |
During the period 18,300 options to acquire fully paid shares in the Company were issued in conjunction with the Bridging loan facility. These options vested on issue, have an exercise price of £0.20 per share and expire in December 2011.
On 11 September 2009 the Company implemented a long term executive incentive scheme which was developed in conjunction with external executive compensation consultants, Deloitte LLP. As part of this scheme, Jay Cheatham and Justin Hondris have been granted options to acquire fully paid shares in the company as outlined in Table 1 below. These options expire five years from date of grant and vest in three equal tranches on 11 September 2009, 30 June 2010 and 30 June 2011. Each tranche comprises one third of the number of options at each exercise price.
Table 1
|
Exercise price |
£0.30 |
£0.40 |
£0.50 |
£0.60 |
Total number of options issued |
|
J Cheatham |
400,000 |
300,000 |
300,000 |
200,000 |
1,200,000 |
|
J Hondris |
350,000 |
250,000 |
200,000 |
100,000 |
900,000 |
Upon vesting of the first tranche of these options, Mr Cheatham's existing options (one million in total with exercise prices ranging between £1.00 to £2.00) and Mr Hondris's existing options (300,000 in total with prices ranging between £1.50 and £2.00) were cancelled.
No other options were exercised, forfeited or expired during the year.
The share options issued during the year were valued at £37,659 with reference to the Black-Scholes option pricing model taking into account the following input assumptions as outlined below:
Dates issued ranging 20 July 2009 to 11 September 2009
Share price ranging £0.1225 to £0.1475
Exercise Price ranging £0.20 - £0.60
Expected volatility ranging 69.2% to 83.4%
Vesting period ranging 20 July 2009 to 30 June 2011
Expected dividends Nil
Risk free interest rate 0.50%
Discount for illiquidity of unlisted options 30%
The volatility percentage is an estimation of the expected volatility in the share price for a junior exploration Company which is listed on AIM having regard to comparative companies, quantum of cash raised, targeted (institutional) investment group and risk profile.
Additionally, as required under relevant accounting standards an expense of £46,830 was taken during the year which comprised the unexpensed element of Jay Cheatham's cancelled options which would have been expensed in future periods had the options not been cancelled.
All other options in existence during the year were fully expensed in prior years.
22. Post balance sheet events
There were no material post balance sheet events.
23. Related party transactions
The Company's related party transactions, comprising loans extended to the Company by Mr J. Cheatham were repaid in full during the year. The maximum value of the loan during the year amounted to £672,815 (2009: £672,815).
This information is provided by RNS
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