Final Results for the Year Ended 31 December 2019

RNS Number : 2213L

Baron Oil PLC

29 April 2020

Market Abuse Regulation (MAR) Disclosure

Certain information contained in this announcement would have been deemed inside information for the purposes of Article 7 of Regulation (EU) No 596/2014 until the release of this announcement.

29 April 2020

Baron Oil Plc

("Baron Oil" or "the Company")

Final Results for the Year Ended 31 December 2019

Baron Oil Plc (AIM:BOIL), the AIM-quoted oil and gas exploration and production company focused on opportunities in SE Asia, Latin America and the UK, is pleased to announce its audited financial results for the year ended 31 December 2019.

Operations

Chuditch PSC: The award in November of the TL-SO-19-16 Production Sharing Contract ("Chuditch PSC"), offshore Democratic Republic of Timor-Leste, marks a major step forward for the Company. Shell's internal analyses following the drilling of the Chuditch-1 discovery in 1999, indicate a Mean Gas Initially in Place (GIIP) for the surrounding group of prospects in the Chuditch PSC of 2,320 BCF, considered by Baron to be low-risk GIIP Pmean Prospective Resources (but not SPE PRMS compliant). Baron has an indirect interest of 25% in the Chuditch PSC, held through its shareholding in SundaGas (Timor-Leste Sahul) Pte. Ltd.

Block XXI: The Company continues to pursue efforts to drill the El Barco-3X well in Peru, including introducing a partner. However, plans for drilling are currently halted by COVID-19 issues, with strict movement restrictions including the inability to visit the site. Baron has a 100% interest.

Inner Moray Firth (UK): Initial subsurface work on Licence P2478, which contains the large Dunrobin and smaller Golspie prospects, is under review and further seismic reprocessing is planned. Licences P2470 and P2235 have been relinquished. Baron has a 15% interest in the Inner Moray Firth.

Dorset (UK): The latest analysis of the Colter South Prospect (on Licence P1918), in which oil was found during 2019, indicates that a further appraisal well is required to define the resources before development can be planned. The current oil price collapse and short remaining duration of the Licence mean efforts to bring in a new drilling partner are now unlikely to succeed. Hence, under IFRS6, the entire carrying amount for Colter has been impaired. The status of PEDL330 and PEDL345 onshore Licences, lying to the south of Wytch Farm oilfield, continue to be reviewed in light of the current business environment. Baron has an 8% interest in the Dorset Licences.

Financials

· Net result for the year was a loss before taxation of £1,674,000 (2018: loss of £3,280,000)

· Loss after taxation attributable to shareholders was £1,674,000 (2018: loss of £2,495,000)

· Exploration and evaluation expenditure of £1,207,000 (2018: £1,592,000)

· IFRS6 intangible asset impairment charge of £1,047,000, mainly relating to P1918 Colter (2018: IFRS6 charge of £1,360,000 relating to Block XXI, Peru)

· Administration expenditure for the year was £442,000 (2018: £549,000), a 20% reduction

· The end of year free cash balance was £347,000 (2018: £1,709,000). Excluding the proceeds of a share placing in June 2019 amounting to £440,000 gross (£408,000 net), the overall cash outflow during the year amounted to £1,770,000.

· In Q1 2020, the Company undertook a further capital raise of £2.5m gross (£2.3m net) at 0.1p per share.

The Company intends to hold its AGM in June 2020 and the Notice of Annual General Meeting to that effect will be sent to Shareholders in due course.

Competent Person's Statement

Pursuant to the requirements of the AIM Rules for Companies, the technical information and resource reporting contained in this announcement has been reviewed by Dr Malcolm Butler BSc, PhD, FGS, Executive Chairman of the Company. Dr Butler has more than 45 years' experience as a petroleum geologist. He has compiled, read and approved the technical disclosure in this regulatory announcement. The technical disclosures in this announcement comply with the Society of Petroleum Engineers ' standard, except as stated.

Commenting on the results, Malcolm Butler, Executive Chairman, said:

"The final award of the Chuditch PSC was a great result for your Company and marks a step-change in Baron's asset base. However, our industry is currently faced with the dual global impact of significantly lower oil prices and the rapid spread of the COVID-19 virus. While Baron is not insulated from the oil price shock, it should be noted that the Company's assets are all in the pre-cashflow exploration phase and, following the award of the Chuditch PSC, are now heavily weighted towards gas where regional markets play a much greater role in pricing.

In Timor-Leste, there is no obligation to drill before 2022 and any commercial production is unlikely to be achieved before 2025. There are no plans to fund drilling in the UK for the foreseeable future. In both cases, work on these projects over the next 12 months is desk and computer-based and should not be affected by current movement restrictions, although gaining access to the necessary data is being delayed.

As regards the El Barco-3X well in Peru, it is unclear how much local oil companies' appetite for drilling will be affected by oil price movements and although it is unlikely that local gas prices in this part of Peru will be affected by the drop in oil prices, it is impossible to predict the effects on short term gas demand of a COVID-19 related recession.

Critically for shareholders, following our £2.5m (gross) fund raise in Q1 2020, our proposed work programme for 2020 and into 2021 is funded."

For further information, please contact:

Baron Oil Plc	+44 (0)20 7117 2849
Dr Malcolm Butler, Executive Chairman
Andy Yeo, Managing Director

SP Angel Corporate Finance LLP	+44 (0)20 3470 0470
Nominated Adviser and Joint Broker
Stuart Gledhill, Caroline Rowe

Turner Pope Investments (TPI) Limited	+44 (0)20 3657 0050
Joint Broker
Andy Thacker, Zoe Alexander

CHAIRMAN'S STATEMENT & OPERATIONS REPORT

Financial and Financial Results

The net result for the year was a loss before taxation of £1,674,000, which compares to a loss of £3,280,000 for the preceding financial year; the loss after taxation attributable to Baron Oil shareholders was £1,674,000, compared to a loss of £2,495,000 in the preceding year.

Turnover for the year was £nil (2018: £nil), there being no sales activity during the period.

Exploration and evaluation expenditure written off included in the Income Statement amounts to £160,000. This arises from expenditure of £133,000 in Peru on Block XXI, £42,000 in costs regarding the South East Asia Joint Study Agreement with SundaGas prior to the award of the TL-SO-19-16 Production Sharing Contract in November 2019, minor pre-licence expenditures of £9,000 relating to the UK Offshore 31^st Licensing Round and technical consultancy, less £24,000 recovered in respect of 2018 exploration activities in Licence P2235 (Wick).

On the Colter prospect (licence P1918), wells 98/11a-6 and its sidetrack 98/11a-6z were drilled in February and March 2019 at a total cost to Baron of £996,000. £376,000 had been invoiced during 2018 in respect of preparations for the drilling of the well and had previously been treated as a prepayment. Including other licence costs, total expenditure in the year was £1,042,000, which was capitalised to give a total intangible asset value of £1,108,000. The initial evaluation of the well results indicated that the Colter South Prospect had the potential to contain commercial quantities of oil and the licence was therefore continued into its second term in February 2020. However, re-evaluation of the geophysical information, the failure of attempts to bring in an additional partner, and, most recently, the precipitous drop in oil prices in March 2020 has led to a further reassessment of the economic case, increasing the likelihood that the licence will be relinquished before expiry of the Second Term of the licence on 31 January 2021. IFRS6 (the relevant accounting standard) states that an asset should be impaired if there is a prospect of a licence coming to an end in the near future, which for the purposes of this Annual Report would be the next 12 months. On this basis, the decision has now been taken to impair the entire carrying amount for Colter of £1,108,000.There was a small reduction in the provision relating to Peru Block XXI of £61,000 due to exchange rate fluctuations, leading to a total net cost of impairment amounting to £1,047,000.

In Colombia, the liquidation of Inversiones Petroleras de Colombia SAS ("Invepetrol"), in which the Company held a 50% interest, was completed on 2 October 2019, with no further liability to the Company.

Administration expenditure for the year was £442,000, compared to £549,000 in the preceding year, excluding the effects of exchange rate movements. Directors and employee costs amounted to £258,000, listing compliance and other professional fees £133,000 and other overheads £51,000. During the year, the directors agreed to a temporary reduction in their contracted salaries which resulted in cost savings of £89,000.

We saw a modest strengthening of the Pound Sterling against the US Dollar and, with the majority of the group's assets being denominated in US dollars, this has given rise to a loss of £41,000. This compares with a gain of £130,000 in the preceding year, when the Pound Sterling showed relative weakness against the US Dollar.

At the end of the financial year, free cash reserves of the Group had decreased to £347,000 from a level at the preceding year end of £1,709,000. Excluding the proceeds of a share placing in June 2019 amounting to £440,000 gross (£408,000 net of costs), the overall cash outflow amounted to £1,770,000, consisting of £1,207,000 in respect of exploration and evaluation activity and £563,000 operating cash outflow. In Q1 2020, the Company undertook a further capital raise with a new ordinary share Placing of £2,500,000 gross (£2,306,000 net).

The Group continues to pursue a conservative view of its asset impairment policy, giving it a Balance Sheet that consists largely of net current assets and what it considers to be a realistic value for its exploration assets. Given limited cash resources, the Board will take a prudent approach in entering into new capital expenditures beyond those expected to be committed to existing ventures.

Report On Operations

Introduction

The directors are pleased to report the success of SundaGas Pte.Ltd. in gaining the award of the TL-SO-19-16 Production Sharing Contract in Timor-Leste. As shareholders will be aware, this follows an application made in early 2016, during the period of the Joint Study Agreement between Baron and SundaGas. Baron now holds a 33.33% interest in SundaGas (Timor-Leste Sahul) Pte.Ltd, whichgives it an indirect interest of 25% in a substantial gas discovery. The Company continues to pursue efforts to drill the El Barco-3X well on Block XXI in Peru in 2020. As announced during the year, Baron participated in the drilling of two vertical wells and a sidetrack in offshore UK waters. Although oil was encountered in Triassic Sherwood Sandstones on the Colter South Prospect by well 98/11a-06, the results of subsequent analysis indicate that a further appraisal well must be drilled before Colter South can be moved towards development. Efforts to bring in a new partner to participate in the necessary additional work have been unsuccessful so far and the recent precipitous drop in oil prices makes it unlikely that such work can be carried out before the expiry of the current licence term in January 2021.

It is difficult to predict what effect the COVID-19 pandemic will have on operations planned for 2020 but it is already clear that drilling activities will suffer significant delays, which will impact plans for Peru Block XXI. In addition, it is impossible to predict the effects on short term gas demand in Peru and longer term gas demand in Southeast Asia of a potential global recession.

Southeast Asia: Timor-Leste Tl-S0-19-16 Psc (Baron 25%, Effective)

The award in November 2019 to a subsidiary of SundaGas Pte.Ltd. of the TL-SO-19-16 Production Sharing Contract (the "Chuditch PSC"), offshore Democratic Republic of Timor-Leste, marks a major step forward for the Company. Baron supported the original application for a PSC in this area made by the SundaGas group in October 2016, which gave it the right to an interest in the subsequent award. A Shareholders' Agreement ("SHA") has been executed with SundaGas Resources Pte. Ltd ("SundaGas") governing the operation of SundaGas (Timor-Leste Sahul) Pte.Ltd ("SundaGas TLS"), in which Baron now has a 33.33% shareholding and SundaGas retains 66.67%. The sole asset of SundaGas TLS is its 100% shareholding in SundaGas Banda Unipessoal Lda., Operator of the Chuditch PSC, in which it holds a 75% interest.

The SHA contains provisions typical of an agreement of this nature including, but not limited to, mutual undertakings, the right to appoint one of the three directors of SundaGas TLS and certain shareholder rights protections.

Under the terms of the Carry Agreement, executed between SundaGas and Baron on 27^th January 2020, and the SHA, US$521,149 was paid to SundaGas on 21^st April 2020 to reimburse Baron's 33.33% share of costs incurred since the Chuditch PSC was signed on 8 November 2019. This amount includes Baron's 33.33% share of the $1,000,000 Bank Guarantee and the subscription for 3,333 shares in SundaGas TLS, representing 33.33% of the issued share capital of that company. Baron now plans to maintain its interest by continuing to pay 33.33% of the costs incurred on the Chuditch PSC through additional investment into SundaGas TLS. The Company's 33.33% interest in SundaGas TLS equates to an indirect 25% interest in the Chuditch PSC after accounting for the 25% carried interest of the Timor-Leste state company. Information has been derived from publicly released reports on the area, prepared by Shell Development (Australia) Pty. Ltd. ("Shell") in 1998 and 2001 after the drilling of the discovery well Chuditch-1. These indicate that the well, drilled in 64 metres water depth in a total of 25 days for US$8 million, encountered a 25m gas column in Jurassic Plover Formation reservoir sandstones on the flank of a large faulted structure. The reports include estimated ranges of gas in place and recovery factors derived from Shell's internal analyses and, whilst not compliant with the 2018 SPE PRMS Prospective Resources standard, are considered to be a valid indication of the potential for the Chuditch gas accumulation.

The key Shell estimates for the combined Chuditch, Chuditch North and Chuditch South closures ("Greater Chuditch") tested by Chuditch-1 within the area of the PSC are:

1. Estimated Mean Gas in Place (GIIP) of 2,320 BCF, considered by Baron to be Pmean Prospective Resources;

2. Gas recovery factors in the range of 55% to 75%, leading Baron to estimate Mean Recoverable Gas of 1,276 to 1,740 BCF, considered by Baron to be recoverable Pmean Prospective Resources;

3. Risks associated with trap, reservoir and charge for the Greater Chuditch closure considered to be zero (that is, the Geological Chance of Success is 100%), with remaining uncertainty around in place and recoverable volumes.

Further information is available on the Company's website ( www.baronoilplc.com ) and a glossary of terms is included at the end of the report.

SundaGas has put in place the $1 million Performance Guarantee Bond and is moving forward with the initial agreed work programme commitment to reprocess existing 2D and 3D seismic data over the PSC area. Subject to satisfactory results from the reprocessing, the subsequent commitment is for a well to be drilled in the third year of the Initial Term of the Chuditch PSC.

Peru Onshore Block XXI (Baron Oil 100%)

The Company continues to strive to drill on Block XXI, in the Sechura Basin of northern Peru. An experienced local operator with onshore drilling capacity is available and together we are looking at funding options which, subject to local community approval, should see the El Barco-3X well drilled in 2020. However, plans for drilling are currently halted by COVID-19 issues, with strict movement restrictions and the inability to visit the site. It is unclear how much our proposed partner's appetite for drilling will be affected by this and by oil price movements. Gas production in this part of Peru is sold at a price determined by local industries. Although it is unlikely that local gas prices will be greatly affected by the drop in oil prices, it is impossible to predict the effects on short term gas demand in Peru of a potential global recession.

Gold Oil Peru SAC ("GOP"), Baron's Peruvian subsidiary, currently operates Block XXI with 100% interest but it is likely that the interest will reduce to between 50% and 70% on farming out to bring in a new partner.

The well is planned to be drilled to a total depth of 1,850 metres to test a prospect for which Baron estimates unrisked recoverable SPE-PRMS-compliant Prospective Resources (2U-P50) of 14 BCF of gas from the shallower Mancora Sand target, with a 55% Chance of Geological Success, and 8.5 MMBBLS, with associated gas and a 27% Chance of Geological Success, from the higher-risk fractured Amotape Basement. This Basement structure may be larger than presently mapped because it extends beyond the edge of existing 2D seismic data.

The current estimated cost of site preparation and drilling of El Barco-3X is US$1.2 million. The proposed location is approximately 19 kilometres east of the Pan-American Highway and only 1.5 kilometres from the Oleoducto Nor Peruano, the oil pipeline that crosses the Andes from the Amazon Basin and runs to the coast at Bayovar.

The Block is in the fifth and last exploration phase with approximately 6 months left in which to drill once Force Majeure is lifted, which will occur when access details are agreed with the local community. Once the well is drilled, the Company has an agreement in principle with PeruPetro that Baron will have the option of a three-year extension. Under the terms of the current period, GOP is entitled to the return of its US$160,000 government performance bond if the well is drilled.

United Kingdom Offshore Licences P2470 And P2478 (Baron 15%)

Baron Oil and its partners were formally awarded these two new licences in the Inner Moray Firth area of the North Sea by the UK Oil & Gas Authority in September 2019, following the UK 31st Offshore Licensing Round. These Innovate Licences are held by Corallian Energy Limited ("Corallian") (Operator, with 45%), Upland Resources (UK Onshore) Limited (40%) and Baron (15%).

Licence P2478, over blocks 12/27c, 17/5, 18/1 and 18/2, contains the Dunrobin prospect which consists of three large shallow Jurassic rotated fault blocks that are mapped mostly on 3D seismic data within a single culmination with Direct Hydrocarbon Indicators. The lowest closing contour covers 40 square kilometres and Corallian estimates the prospect to have Pmean Prospective Resources of 172 mmboe, with upside potential of c. 400 mmboe (P10). These resource estimates are non-SPE-PRMS compliant recoverable Prospective Resources for the Jurassic sands primary target. . Additional Pmean Prospective Resources of 23.5 mmboe are estimated by Corallian for the smaller Golspie Prospect also contained within the licence. Both prospects are already defined by existing 3D seismic and reprocessing of these data, together with supporting 2D seismic, is underway.

Licence P2470 includes blocks 11/23, 11/24c and 11/25b, surrounding the Wick Prospect, on which Baron Oil participated in the dry Wick Well (11/24b-4) at the beginning of 2019. These blocks were applied for before the results of 11/24b-4 were known and, although they contain the small Knockinnon oil discovery and several small prospects, they have been downgraded by the Wick well result. The modest work commitment on this licence consists of a small volume of 3D seismic reprocessing, which has now been completed. The results of such work were not encouraging and the Licence was relinquished with effect from 31^st March 2020.

Former Licence P2235, on which the unsuccessful Wick Well was drilled, was relinquished at the end of Q3 2019.

United Kingdom Offshore Licence P1918 (Colter) (Baron 8%)

The Colter area lies in UKCS Licence P1918 in Poole Bay, immediately southeast of the Wytch Farm oilfield, which has been developed from onshore facilities. The Colter well (98/11a-06) and its sidetrack (98/11a-06z) were drilled in February and March 2019 and indicated the presence of an oil accumulation with commercial potential in the Colter South Prospect within P1918. Efforts since then have been concentrated on Colter South, where a review of the seismic data and mapping was undertaken in an attempt to improve the subsurface imaging of this complex area. Although the Operator, Corallian Energy Limited, estimated nonSPE-PRMS compliant Pmean recoverable Prospective Resources of 16 mmboe in the Colter South Prospect (1.2 mmboe net to Baron), it has become clear that an additional vertical appraisal well is necessary before any plans can be made for development.

The P1918 group has elected to proceed into the Second Term of the Licence, expiring on 31 January 2021, and has simultaneously reduced the Licence area to incorporate only that acreage surrounding the Colter and Colter South Prospects. The Joint Venture participants have been seeking an additional partner to help fund the drilling of the required vertical well and thereafter to move it forward into development. However, given the short time frame to expiry of the licence and the current oil price situation it is considered unlikely that this can take place before the Second Term expires. On this basis, the directors have elected to impair costs previously capitalised in respect of 98/11a-06 and 98/11a-06z.

United Kingdom Onshore Licences PEDL330 & PEDL345 (Baron 8%)

PEDL330 and PEDL345 are onshore Licences, lying to the south of Wytch Farm oilfield. PEDL345 includes a major part of the Purbeck Prospect, which is being evaluated. However, the combination of the current low oil price and the environmental issues associated with drilling in this coastal area of Dorset has led the directors to conclude that it will be difficult for drilling to take place before these licences expire in July 2021.

Conclusions

Baron is currently faced with the dual global impact of significantly lower oil prices and the rapid spread of the COVID-19 virus. While we are not insulated from the oil price shock, it should be noted that the Company's assets are all in the pre-cashflow exploration phase and, following the award of the Chuditch PSC, are now heavily weighted towards gas where regional markets play a much greater role in pricing.

There is no obligation to drill before 2022 in Timor-Leste and there are no plans to fund drilling in the UK in the foreseeable future. In both cases, planned work for at least the next 12 months is desk and computer-based and should not be affected by current movement restrictions, although gaining access to the necessary data is being delayed. As regards the El Barco-3X well in Peru, plans for drilling are currently halted by strict movement restrictions and the inability to visit the site. It is unclear how much our proposed partner's appetite for drilling will be affected by oil price movements. Although it is unlikely that local gas prices in this part of Peru will be affected by the drop in oil prices, it is impossible to predict the effects on short term gas demand in Peru. Moreover, the impact on longer term gas demand and the currently depressed regional gas prices in Southeast Asia from a steep economic recession brought on by the COVID-19 pandemic remains to be seen.

Following our £2.5m (gross) fund raise in February 2020, our proposed work programme for 2020 and into 2021 is funded. The majority of the funds are planned to be used to pay Baron's share of the ongoing TL-SO-19-16 PSC ("Chuditch PSC") work programme and the drilling of the onshore El Barco-3X well in Peru.

Once the global economic outlook becomes clearer, we look forward to progressing the drilling of El Barco-3X and moving forward with the Timor-Leste project, which has the potential to make a step-change in the value of your Company .

This has been a stressful period that has required intense effort by our small team and I would like to record my particular thanks to Andy Yeo for the long hours he has put in to maintain and strengthen the Company's financial capability.

CONSOLIDATED INCOME STATEMENT FOR THE YEAR ENDED 31 DECEMBER 2019


	Notes	2019	2018
		£'000	£'000

Revenue		-	-

Cost of sales		-	-

Gross profit		-	-

Exploration and evaluation expenditure		(160)	(1,526)
Intangible asset impairment	11	(1,047)	(1,360)
Receivables impairment	3	16	(54)
Administration expenses		(442)	(549)
(Loss)/profit on exchange	3	(41)	130
Other operating Income	4	-	83

Operating loss	3	(1,674)	(3,276)

Finance cost	6	(1)	(10)
Finance income	6	1	6

Loss on ordinary activities
before taxation		(1,674)	(3,280)

Income tax credit/(expense)	7	-	785

Loss on ordinary activities
after taxation		(1,674)	(2,495)

Dividends		-	-

Loss for the year		(1,674)	(2,495)

Loss on ordinary activities
after taxation is attributable to:
Equity shareholders		(1,674)	(2,495)
Non-controlling interests		-	-

Loss for the year		(1,674)	(2,495)

Earnings per ordinary share - continuing	9
Basic		(0.099p)	(0.181p)
Diluted		(0.099p)	(0.181p)

CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME FOR THE
YEAR ENDED 31 DECEMBER 2019


	Notes	2019	2018
		£'000	£'000

Loss on ordinary activities after taxation attributable to the parent		(1,674)	(2,495)

Other comprehensive income:
Exchange difference on translating foreign operations		(69)	(11)

Total comprehensive income for the year		(1,743)	(2,506)

Total comprehensive income attributable to
Owners of the parent		(1,743)	(2,506)

CONSOLIDATED STATEMENT OF FINANCIAL POSITION AT 31 DECEMBER 2019
					Notes				2019					2018
									£'000					£'000
Assets

Non current assets
Property plant and equipment
--- oil and gas assets					10				-					-
--- others					10				-					-
Intangibles					11				5					66
Goodwill					12				-					-

									5					66
Current assets
Trade and other receivables					14				49					503
Cash and cash equivalents					15				472					1,838

									521					2,341

Total assets									526					2,407

Equity and liabilities

Capital and reserves attributable to owners of the parent
Share capital					17				482					344
Share premium account					18				30,507					30,237
Share option reserve					18				74					74
Foreign exchange translation reserve					18				1,643					1,712
Retained earnings					18				(32,251)					(30,577)

Total equity									455					1,790

Current liabilities
Trade and other payables					16				64					594
Taxes payable					16				7					23

									71					617

Total equity and liabilities									526					2,407


COMPANY STATEMENT OF FINANCIAL POSITION AT 31 DECEMBER 2019
						Notes		2019					2018
								£'000					£'000
Assets
Non current assets
Property plant and equipment
--- oil and gas assets								-					-
Intangibles						11		5					66
Investments						13		25					25

								30					91
Current assets
Trade and other receivables						14		46					502
Cash and cash equivalents						15		336					1,692

								382					2,194

Total assets								412					2,285

Equity and liabilities
Capital and reserves attributable to owners of the parent
Share capital						17		482					344
Share premium account						18		30,507					30,237
Share option reserve						18		74					74
Foreign exchange translation reserve						18		(163)					(163)
Retained earnings						18		(32,261)					(30,510)

Total equity								(1,361)					(18)

Current liabilities
Trade and other payables						16		1,766					2,295
Taxes payable						16		7					8

								1,773					2,303

Total equity and liabilities								412					2,285

The financial statements were approved and authorised for issue by the Board of Directors on 28 April 2020.


CONSOLIDATED AND COMPANY STATEMENT OF CHANGES IN EQUITY FOR THE YEAR ENDED 31 DECEMBER 2019

		Share	Share	Retained			Share option				Foreign exchange				Total
		capital	premium	earnings			reserve				translation				equity
Group		£'000	£'000	£'000			£'000				£'000				£'000
As at 1 January 2018		344	30,237	(28,163)			122				1,723				4,263
Shares issued		-	-	-			-				-				-
Transactions with owners		-	-	-			-				-				-
(Loss) for the year attributable to equity shareholders		-	-	(2,495)							-				(2,495)
Share based payments		-	-	-			33				-				33
Release of option reserve		-	-	81			(81)				-				-
Foreign exchange translation adjustments		-	-	-			-				(11)				(11)
Total comprehensive income for the period		-	-	(2,414)			(48)				(11)				(2,473)

As at 1 January 2019		344	30,237	(30,577)			74				1,712				1,790

Shares issued		138	270	-			-				-				408
Transactions with owners		138	270	-			-				-				408
(Loss) for the year attributable to equity shareholders		-	-	(1,674)			-				-				(1,674)
Foreign exchange translation adjustments		-	-	-			-				(69)				(69)
Total comprehensive income for the period		-	-	(1,674)			-				(69)				(1,743)
As at 31 December 2019		482	30,507	(32,251)			74				1,643				455

CONSOLIDATED AND COMPANY STATEMENT OF CHANGES IN EQUITY FOR THE YEAR ENDED 31 DECEMBER 2019

	Share		Share		Retained		Share option			Foreign exchange					Total
	capital		premium		earnings		reserve			translation					equity
	£'000		£'000		£'000		£'000			£'000					£'000
Company
As at 1 January 2018	344		30,237		(27,892)		122			(163)					2,648
Shares issued	-		-		-		-			-					-
Transactions with owners	-		-		-		-			-					-

(Loss) for the year	-		-		(2,699)		-			-					(2,699)
Share based payments	-		-		-		33			-					33
Release of option reserve	-		-		81		(81)			-					-
Total comprehensive income for the period	-		-		(2,618)		(48)			-					(2,666)

As at 1 January 2019	344		30,237		(30,510)		74			(163)					(18)

Shares issued	138		270		-		-			-					408
Transactions with owners	138		270		-		-			-					408
(Loss) for the year	-		-		(1,751)		-			-					(1,751)
Total comprehensive income for the period	-		-		(1,751)		-			-					(1,751)

As at 31 December 2019	482		30,507		(32,261)		74			(163)					(1,361)

Share capital is the amount subscribed for shares at nominal value.
Share premium represents the excess of the amount subscribed for share capital over the nominal value of those shares net of share issue expenses.
Retained earnings represents the cumulative loss of the group attributable to equity shareholders.
Foreign exchange translation occurs on consolidation of the translation of the subsidiaries balance sheets at the closing rate of exchange and their income statements at the average rate.

CONSOLIDATED AND COMPANY STATEMENT OF CASH FLOWS FOR THE
YEAR ENDED 31 DECEMBER 2019

				Group			Company					Group			Company
				2019			2019					2018			2018
				£'000			£'000					£'000			£'000

Operating activities				(724)			(563)					(2,104)			(1,875)

Investing activities
Return from investment and servicing of finance				1			1					6			6
Loan to subsidiary advanced				-			(155)					-			(236)
Acquisition of intangible assets				(1,047)			(1,047)					(66)			(66)

				(1,046)			(1,201)					(60)			(296)
Financing activities
Proceeds from issue of share capital				408			408					-			-

Net cash outflow				(1,362)			(1,356)					(2,164)			(2,171)

Cash and cash equivalents at the beginning of the year				1,709			1,692					3,873			3,863

Cash and cash equivalents at the end of the year				347			336					1,709			1,692

Reconciliation to Consolidated Statement of Financial Position
Cash not available for use				125			-					129			-

Cash and cash equivalents as shown in the Consolidated Statement of Financial Position				472			336					1,838			1,692

CONSOLIDATED AND COMPANY STATEMENT OF CASH FLOWS FOR THE
YEAR ENDED 31 DECEMBER 2019
	Group	Company	Group	Company
	2019	2019	2018	2018
	£'000	£'000	£'000	£'000
Operating activities
Loss for the year attributable to controlling interests	(1,674)	(1,751)	(2,495)	(2,699)
Depreciation, amortisation and impairment charges	1,047	1,240	1,360	923
Share based payments	-	-	33	33
Finance income shown as an investing activity	(1)	(1)	(6)	(6)
Tax benefit	-	-	(785)	-
Foreign exchange translation	(4)	23	(73)	(122)

Operating cash outflow before movements in working capital	(632)	(489)	(1,966)	(1,871)

Decrease/(increase) in receivables	454	456	(485)	(488)
Tax paid	-	-	(53)	-
(Decrease)/increase in payables	(546)	(530)	400	484

Net cash outflow from operating activities	(724)	(563)	(2,104)	(1,875)

NOTES TO THE FINANCIAL STATEMENTS

General Information

Baron Oil Plc is a company incorporated in England and Wales and quoted on the AIM market of the London Stock Exchange. The address of the registered office is disclosed in the financial statements. The principal activity of the Group is described in the Strategic Report.

(1) Significant accounting policies

The principal accounting policies applied in the preparation of these consolidated financial statements are set out below. These policies have been consistently applied to all the periods presented, unless otherwise stated.

Going concern basis

The directors have prepared a cash ﬂow forecast covering a period extending beyond 12 months from the date of these ﬁnancial statements which contains certain assumptions about the development and strategy of the business. The directors are aware of the risks and uncertainties facing the business but the assumptions used are the directors' best estimate of its future development.

After considering the forecasts and the risks, the directors have a reasonable expectation that the Group has adequate resources to continue in operational existence for the foreseeable future. For these reasons, they continue to adopt the going concern basis of accounting in preparing the annual ﬁnancial statements.

The ﬁnancial statements do not include any adjustments that would result if the Group was unable to continue as a going concern.

Basis of preparation

The financial statements have been prepared in accordance with International Financial Reporting Standards (IFRSs) and IFRIC interpretations issued by the International Accounting Standards Board (IASB) as adopted by the European Union and with those parts of the Companies Act 2006 applicable to companies reporting under IFRS. The financial statements have been prepared under the historical cost convention. The principal accounting policies adopted are set out below.

Changes in accounting policies and disclosures

New and amended standards adopted by the Group

IFRS 16 'Leases' became effective for the Group from 1 January 2019. The core principle of IFRS 16 is to provide a single lessee accounting model, requiring lessees to recognise a right-of-use asset and lease liability for all leases unless the term is less than 12 months, or the underlying asset has a low value.

As a result of applying IFRS 16, the Group is not impacted by IFRS 16, as no operating leases exists within the Group.

New and amended standards not yet adopted

A number of new and amended accounting standards and interpretations have been published that are not mandatory for the Group's accounts ended 31 December 2019, nor have they been early adopted. These standards and interpretations are not expected to have a material impact on the Group's consolidated Financial Statements:

• Amendments to References to Conceptual Framework in IFRS Standards (effective from 1 January 2020);

• Amendments to IFRS 3 'Definition of a Business' (effective from 1 January 2020);

• Amendments to IFRS 10 and IAS 28 - Sale or Contribution of Assets between an Investor and its Associate or Joint Venture (effective date not yet confirmed); and

• IFRS 17 'Insurance Contracts' (effective from 1 January 2022).

Basis of consolidation

The consolidated financial statements include the financial statements of the Company and its subsidiaries and associated undertakings.

Subsidiaries

Subsidiaries are all entities over which Baron Oil Plc has the power to govern the financial and operating policies generally accompanying a shareholding of more than one half of the voting rights, or where Baron Oil Plc exercises effective operational control. The existence and effect of potential voting rights that are currently exercisable or convertible are considered when assessing whether the Group controls another entity. Subsidiaries are fully consolidated from the date on which control is transferred to the Company. 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. If the cost of acquisition is less than the fair value of the net assets of the subsidiary acquired, the difference is recognised directly in the income statement.

Inter-company transactions, balances and unrealised gains on transactions between Group companies are eliminated. Unrealised losses are also eliminated but considered an impairment indicator of the asset transferred. Accounting policies of subsidiaries have been changed where necessary to ensure consistency with the policies adopted by the Group.

Joint ventures

Where the Group is engaged in oil and gas exploration and appraisal through unincorporated joint ventures, the Group accounts for its share of the results and net assets of these joint ventures as jointly controlled assets. The Group's interests in jointly controlled entities are accounted for by proportionate consolidation. The Group combines its share of the joint ventures' individual income and expenses, assets and liabilities and cash flows on a line-by-line basis with similar items in the Group's financial statements. The Group recognises the portion of gains or losses on the sale of assets by the group to the joint venture that is attributable to the other venturers. The Group does not recognise its share of profits or losses from the joint venture that result from the Group's purchase of assets from the joint venture until it re-sells the assets to an independent party. However, a loss on the transaction is recognised immediately if the loss provides evidence of a reduction in the net realisable value of current assets, or an impairment loss. In addition, where the Group acts as operator of the joint venture, the gross liabilities and receivables (including amounts due to or from non-operating partners) of the joint venture are included in the Consolidated Statement of Financial Position.

Goodwill

Goodwill represents the excess of the cost of an acquisition over the fair value of the Group's share of the net identifiable assets of the acquired subsidiary or associate at the date of acquisition. Goodwill on acquisitions of subsidiaries is included in 'intangible assets'. Separately recognised goodwill is tested annually for impairment and carried at cost less accumulated impairment losses. Impairment losses on goodwill are not reversed. Gains and losses on the disposal of an entity include the carrying amount of goodwill relating to the entity sold.

Goodwill is allocated to cash-generating units for the purpose of impairment testing. The allocation is made to those cash-generating units or groups of cash-generating units that are expected to benefit from the business combination in which the goodwill arose. The Group allocates goodwill to each business segment in each country in which it operates.

Impairment of non-financial assets

Assets that have an indefinite useful life, for example goodwill, are not subject to amortisation and are tested annually for impairment.

At each statement of financial position date, the Group reviews the carrying amounts of its tangible and intangible assets to determine whether there is any indication that those assets have suffered an impairment loss. If any such indication exists, the recoverable amount of the asset is estimated in order to determine the extent of the impairment loss (if any). Where the asset does not generate cash flows that are independent from other assets, the Group estimates the recoverable amount of the cash-generating unit to which the asset belongs. An intangible asset with an indefinite useful life is tested for impairment annually and whenever there is an indication that the asset may be impaired.

Recoverable amount is the higher of fair value less costs to sell and value in use. In assessing value in use, the estimated future cash flows are discounted to their present value using a pre-tax discount rate that reflects current market assessments of the time value of money and the risks specific to the asset for which the estimates of future cash flows have not been adjusted.

If the recoverable amount of an asset (or cash-generating unit) is estimated to be less than its carrying amount, the carrying amount of the asset (cash-generating unit) is reduced to its recoverable amount. An impairment loss is recognised as an expense immediately, unless the relevant asset is carried at a re-valued amount, in which case the impairment loss is treated as a revaluation decrease.

Where an impairment loss subsequently reverses, the carrying amount of the asset (cash-generating unit) is increased to the revised estimate of its recoverable amount, but so that the increased carrying amount does not exceed the carrying amount that would have been determined had no impairment loss been recognised for the asset (cash-generating unit) in prior periods. A reversal of an impairment loss is recognised as income immediately, unless the relevant asset is carried at a revalued amount, in which case the reversal of the impairment loss is treated as a revaluation increase.

Intangible Assets

Oil and gas assets: exploration and evaluation

The Group has continued to apply the 'successful efforts' method of accounting for Exploration and Evaluation ("E&E") costs, having regard to the requirements of IFRS 6 'Exploration for the Evaluation of Mineral Resources'.

The successful efforts method means that only the costs which relate directly to the discovery and development of specific oil and gas reserves are capitalised. Such costs may include costs of licence acquisition, technical services and studies, seismic acquisition; exploration drilling and testing but do not include costs incurred prior to having obtained the legal rights to explore the area. Under successful efforts accounting, exploration expenditure which is general in nature is charged directly to the income statement and that which relates to unsuccessful drilling operations, though initially capitalised pending determination, is subsequently written off. Only costs which relate directly to the discovery and development of specific commercial oil and gas reserves will remain capitalised and to be depreciated over the lives of these reserves. The success or failure of each exploration effort will be judged on a well-by-well basis as each potentially hydrocarbon-bearing structure is identified and tested. Exploration and evaluation costs are capitalised within intangible assets. Capital expenditure on producing assets is accounted for in accordance with SORP 'Accounting for Oil and Gas Exploration'. Costs incurred prior to obtaining legal rights to explore are expensed immediately to the income statement.

All lease and licence acquisition costs, geological and geophysical costs and other direct costs of exploration, evaluation and development are capitalised as intangible or property, plant and equipment according to their nature. Intangible assets comprise costs relating to the exploration and evaluation of properties which the directors consider to be unevaluated until reserves are appraised as commercial, at which time they are transferred to tangible assets as 'Developed oil and gas assets' following an impairment review and depreciated accordingly. Where properties are appraised to have no commercial value, the associated costs are treated as an impairment loss in the period in which the determination is made.

Costs are amortised on a field by field unit of production method based on commercial proven and probable reserves, or to the expiry of the licence, whichever is earlier.

The calculation of the 'unit of production' amortisation takes account of the estimated future development costs and is based on the current period and un-escalated price levels. Changes in reserves and cost estimates are recognised prospectively.

E&E costs are not amortised prior to the conclusion of appraisal activities.

Property, plant and equipment

Oil and gas assets: development and production

Development and production ("D&P") assets are accumulated on a well by well basis and represent the cost of developing the commercial reserves discovered and bringing them into production, together with the E&E expenditures incurred in finding commercial reserves transferred from intangible E&E assets as outlined above. The carrying values of producing assets are depreciated on a well by well basis using the unit of production method based on entitlement to provide by reference to the ratio of production in the period to the related commercial reserves of the well, taking into account any estimated future development expenditures necessary to bring additional non producing reserves into production.

An impairment test is performed for D&P assets whenever events and circumstances arise that indicate that the carrying value of development or production phase assets may exceed its recoverable amount. The aggregate carrying value is compared against the expected recoverable amount of each well, generally by reference to the present value of the future net cash flows expected to be derived from production of commercial reserves.

The cost of the workovers and extended production testing is capitalised within property, plant and equipment as a D&P asset.

Decommissioning

Site restoration provisions are made in respect of the estimated future costs of closure and restoration, and for environmental rehabilitation costs (which include the dismantling and demolition of infrastructure, removal of residual materials and remediation of disturbed areas) in the accounting period when the related environmental disturbance occurs. The provision is discounted where material and the unwinding of the discount is included in finance costs. Over time, the discounted provision is increased for the change in present value based on the discount rates that reflect current market assessments and the risks specific to the liability. At the time of establishing the provision, a corresponding asset is capitalised where it gives rise to a future benefit and depreciated over future production from the field to which it relates. The provision is reviewed on an annual basis for changes in cost estimates, discount rates or life of operations. Any change in restoration costs or assumptions will be recognised as additions or charges to the corresponding asset and provision when they occur. For permanently closed sites, changes to estimated costs are recognised immediately in the income statement.

Non oil and gas assets

Non oil and gas assets are stated at cost of acquisition less accumulated depreciation and impairment losses. Depreciation is provided on a straight-line basis at rates calculated to write off the cost less the estimated residual value of each asset over its expected useful economic life. The residual value is the estimated amount that would currently be obtained from disposal of the asset if the asset were already of the age and in the condition expected at the end of its useful life.

Buildings, plant and equipment unrelated to production are depreciated using the straight-line method based on estimated useful lives.

The annual rate of depreciation for each class of depreciable asset is:

Equipment and machinery 4-10 years

The carrying value of tangible fixed assets is assessed annually and any impairment is charged to the income statement.

Investments

Investments are stated at cost less provision for any impairment in value.

Trade and other receivables

Trade receivables are recognised initially at fair value and subsequently measured at amortised cost using the effective interest method, less provision for impairment. A provision for impairment is established when there is objective evidence that the Group will not be able to collect all amounts due according to the original terms of the receivables. Significant financial difficulties of the debtor, probability that the debtor will enter bankruptcy or financial reorganisation, and default or delinquency in payments are considered indicators that the trade receivable is impaired.

Cash and cash equivalents

Cash and cash equivalents include cash in hand, deposits held on call with banks, other short-term highly liquid investments with original maturities of three months or less, and bank overdrafts. Bank overdrafts are shown within borrowings in current liabilities on the statement of financial position.

Inventories

Inventories, including materials, equipment and inventories of gas and oil held for sale in the ordinary course of business, are stated at weighted average historical cost, less provision for deterioration and obsolescence or, if lower, net realisable value.

Revenue

Oil and gas sales revenue is measured at the fair value of the consideration received or receivable and represents amounts receivable for the Group's share of oil and gas supplied in the period. Revenue is shown net of value-added tax, returns, rebates and discounts and after eliminating sales within the Group. Revenue is recognised when the oil and gas produced is despatched and received by the customers.

Taxation

Income tax

Income tax expense represents the sum of the tax currently payable and deferred tax.

The tax currently payable is based on taxable profit or loss for the year. Taxable profit or loss differs from profit or loss as reported in the same income statement because it excludes items of income or expense that are taxable or deductible in other periods and it further excludes items that are never taxable or deductible. The Company's liability for current tax is calculated using tax rates that have been enacted or substantively enacted by the statement of financial position date.

Deferred tax

Deferred tax is recognised on differences between the carrying amounts of assets and liabilities in the financial statements and the corresponding tax bases used in the computation of taxable profit, and is accounted for using the statement of financial position liability method. Deferred tax liabilities are generally recognised for all taxable temporary differences and deferred tax assets are recognised to the extent that it is probable that taxable profits will be available against which deductible temporary differences can be utilised. Such assets and liabilities are not recognised if the temporary difference arises from goodwill or from the initial recognition (other than in a business combination) of other assets and liabilities in a transaction that affects neither the taxable profit nor the accounting profit.

The carrying amount of deferred tax is reviewed at each statement of financial position date and reduced to the extent that it is no longer probable that sufficient taxable profits will be available to allow all or part of the asset to be recovered.

Deferred tax is calculated at the tax rates that are expected to apply in the period when the liability is settled or the asset realised. Deferred tax is charged or credited to income statement, except when it relates to items charged or credited directly to equity, in which case the deferred tax is also dealt with in equity.

Deferred tax assets and liabilities are offset when there is a legally enforceable right to set off current tax assets against current tax liabilities and when they relate to income taxes levied by the same taxation authority and the Company intends to settle its current tax assets and liabilities on a net basis.

Trade and other payables

Trade payables are not interest bearing and are stated at their nominal value. Trade and other payables are initially recognised at fair value. They are subsequently measured at amortised cost using the effective interest method unless the effect of discounting would be immaterial, in which case they are stated at cost.

Fair values

The carrying amounts of the financial assets and liabilities such as cash and cash equivalents, receivables and payables of the Group at the statement of financial position date approximated their fair values, due to relatively short term nature of these financial instruments.

Share-based compensation

The fair value of the employee and suppliers services received in exchange for the grant of the options is recognised as an expense. The total amount to be expensed over the vesting period is determined by reference to the fair value of the options granted, excluding the impact of any non-market vesting conditions (for example, profitability and sales growth targets). Non-market vesting conditions are included in assumptions about the number of options that are expected to vest. At each statement of financial position date, the entity revises its estimates of the number of options that are expected to vest. It recognises the impact of the revision to original estimates, if any, in the income statement, with a corresponding adjustment to equity.

The proceeds received net of any directly attributable transaction costs are credited to share capital (nominal value) and share premium when the options are exercised.

Share based payments (Note 19)

The fair value of share-based payments recognised in the income statement is measured by use of the Black Scholes model, which takes into account conditions attached to the vesting and exercise of the equity instruments. The expected life used in the model is adjusted based on management's best estimate, for the effects of non-transferability, exercise restrictions and behavioural considerations. The share price volatility percentage factor used in the calculation is based on management's best estimate of future share price behaviour and is selected based on past experience, future expectations and benchmarked against peer companies in the industry.

Equity instruments

Ordinary shares are classified as equity.

Incremental costs directly attributable to the issue of new shares or options are shown in equity as a deduction, net of tax, from proceeds.

Financial assets

On initial recognition, financial assets are classified as either financial assets at fair value through the statement of profit or loss, held-to-maturity investments, loans and receivables financial assets, or available-for-sale financial assets, as appropriate.

Loans and receivables

The Group classifies all its financial assets as trade and other receivables. The classification depends on the purpose for which the financial assets were acquired.

Trade receivables and other receivables that have fixed or determinable payments that are not quoted in an active market are classified as loans and receivables financial assets. Loans and receivables financial assets are measured at amortised cost using the effective interest method, less any impairment loss.

The Group's loans and receivables financial assets comprise other receivables (excluding prepayments) and cash and cash equivalents included in the Statement of Financial Position.

Financial liabilities

Financial liabilities are recognised when, and only when, the Group becomes a party to the contracts which give rise to them and are classified as financial liabilities at fair value through the profit and loss or loans and payables as appropriate. The Group's loans and payable comprise trade and other.

When financial liabilities are recognised initially, they are measured at fair value plus directly attributable transaction costs and subsequently measured at amortised cost using the effective interest method other than those categorised as fair value through income statement.

Fair value through the income statement category comprises financial liabilities that are either held for trading or are designated to eliminate or significantly reduce a measurement or recognition inconsistency that would otherwise arise. Derivatives are also classified as held for trading unless they are designated as hedges. There were no financial liabilities classified under this category.

The Group determines the classification of its financial liabilities at initial recognition and re-evaluate the designation at each financial year end.

A financial liability is derecognised when the obligation under the liability is discharged, cancelled or expires.

When an existing financial liability is replaced by another from the same party on substantially different terms, or the terms of an existing liability are substantially modified, such an exchange or modification is treated as a de-recognition of the original liability and the recognition of a new liability, and the difference in the respective carrying amounts is recognised in the income statement.

Provisions

Provisions are recognised when the Company has a present obligation as a result of a past event, and it is probable that the Company will be required to settle that obligation. Provisions are measured at the directors' best estimate of the expenditure required to settle the obligation at the statement of financial position date, and are discounted to present value where the effect is material.

Financial instruments

Non-derivative financial instruments comprise investments in equity and debt securities, trade and other receivables, cash and cash equivalents, loans and borrowings, and trade and other payables.

Non-derivative financial instruments are recognised initially at fair value plus, for instruments not at fair value through profit or loss, any directly attributable transactions costs, except as described below. Subsequent to initial recognition non-derivative financial instruments are measured as described below.

A financial instrument is recognised when the Group becomes a party to the contractual provisions of the instrument. Financial assets are derecognised if the Group's contractual rights to the cash flows from the financial assets expire or if the Group transfers the financial assets to another party without retaining control or substantially all risks and rewards of the asset. Regular purchases and sales of financial assets are accounted for at trade date, i.e. the date that the Group commits itself to purchase or sell the asset. Financial liabilities are derecognised if the Group's obligations specified in the contract expire or are discharged or cancelled.

Foreign currencies

i) Functional and presentation currency

Items included in the financial statements of the Group are measured using the currency of the primary economic environment in which the entity operates (the functional currency), which are mainly in Pounds Sterling (£), US Dollars (USD), and Peruvian Nuevo Sol (PEN). The financial statements are presented in Pounds Sterling (£), which is the Group's presentation currency.

ii) Transactions and balances

Foreign currency transactions are translated into the presentational currency using 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 at period-end exchange rates of monetary assets and liabilities denominated in foreign currencies are recognised in the income statement.

iii) Group companies

The results and financial position of all Group entities (none of which has the currency of a hyper-inflationary economy) that have a functional currency different from the presentation currency are translated into the presentation currency as follows:

(a) assets and liabilities for each statement of financial position presented are translated at the closing rate at the date of that statement of financial position;

(b) income and expenses for each income statement are translated at average exchange rates (unless this average 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 rate on the dates of the transactions); and

On consolidation, exchange differences arising from the translation of the net investment in foreign operations, and of borrowings and other currency instruments designated as hedges of such investments, are taken to shareholders' equity. When a foreign operation is partially disposed of or sold, exchange differences that were recorded in equity are recognised in the income statement as part of the gain or loss on sale.

Goodwill and fair value adjustments arising on the acquisition of a foreign entity are treated as assets and liabilities of the foreign entity and translated at the closing rate.

Management of capital

The Group's policy is to ensure that it will always have sufficient cash to allow it to meet its liabilities when they become due. The principal liabilities of the Group arise in respect of committed expenditure in respect of its ongoing exploration work. To achieve this aim, it seeks to raise new equity finance and debt sufficient to meet the next phase of exploration and where relevant development expenditure.

The Board receives cash flow projections on a monthly basis as well as information on cash balances. The Board will not commit to material expenditure in respect of its ongoing exploration work prior to being satisfied that sufficient funding is available to the Group to finance the planned programmes.

Dividends cannot be issued until there are sufficient reserves available.

Critica l accounting judgments and key sources of estimation uncertainty

The preparation of the consolidated financial statements requires management to make estimates and assumptions concerning the future that affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the dates of the financial statements and the reported amounts of revenues and expenses during the reporting periods. The resulting accounting estimates will, by definition, differ from the related actual results.

Carrying value of intangible exploration and evaluation assets

Valuation of oil and gas properties: judgements regarding timing of regulatory approval, the general economic environment, and the ability to finance future activities has an impact on the impairment analysis of intangible exploration and evaluation assets. All these factors may impact the viability of future commercial production from unproved properties, and therefore may be a need to recognise an impairment. The timing of an impairment review and the judgement of when there could be a significant change affecting the carrying value of the intangible exploration and and evaluation asset is a critical accounting judgement in itself.

Commercial reserves estimates

Oil and gas reserve estimates: estimation of recoverable reserves include assumptions regarding commodity prices, exchange rates, discount rates, production and transportation costs all of which impact future cashflows. It also requires the interpretation of complex geological and geophysical models in order to make an assessment of the size, shape, depth and quality of reservoirs and their anticipated recoveries. The economic, geological and technical factors used to estimate reserves may change from period to period. Changes in estimated reserves can impact developed and undeveloped property carrying values, asset retirement costs and the recognition of income tax assets, due to changes in expected future cash flows. Reserve estimates are also integral to the amount of depletion and depreciation charged to income.

Decommissioning costs

Asset retirement obligations: the amounts recorded for asset retirement obligations are based on each field's operator's best estimate of future costs and the remaining time to abandonment of oil and gas properties, which may also depend on commodity prices.

2. Segmental information
In the opinion of the Directors the Group has one class of business, being the exploration for, and development and production of, oil and gas reserves, and other related activities.

The Group's primary reporting format is determined to be the geographical segment according to the location of the oil and gas asset. There are currently three geographic reporting segments: South America, which has been involved in production, development and exploration activity, South East Asia where production, development and exploration activity is being assessed, and the United Kingdom being the head office and where exploration activity is taking place.

Exploration and production year ended 31 December 2019
	United	South	South East
	Kingdom	America	Asia	Total
	£'000	£'000	£'000	£'000
Revenue - oil	-	-	-	-
Cost of sales	-	-	-	-

Gross profit	-	-	-	-
Exploration and evaluation expenditure	15	(133)	(42)	(160)
Intangible asset impairment	(1,108)	61	-	(1,047)
Receivables and inventory impairment	-	16	-	16
Administration expenses	(442)	-	-	(442)
Loss on exchange	(41)	-	-	(41)
Other operating income	-	-	-	-

Operating loss	(1,576)	(56)	(42)	(1,674)

Finance costs	-	(1)	-	(1)
Finance income	1	-	-	1

Loss on ordinary activities before taxation	(1,575)	(57)	(42)	(1,674)
Income tax expense	-	-	-	-

Loss on ordinary activities after taxation	(1,575)	(57)	(42)	(1,674)

Assets and liabilities
Segment assets	46	8	-	54
Cash and cash equivalents	336	136	-	472

Total assets	382	144	-	526

Segment liabilities	62	2	-	64
Current tax liabilities	-	7	-	7

Total liabilities	62	9	-	71

Other segment items
Capital expenditure	1,047	-	-	1,047
Depreciation, amortisation and impairment charges	1,108	(77)	-	1,031

2. Segmental information (continued)
Exploration and production year ended 31 December 2018
	United	South	South East
	Kingdom	America	Asia	Total
	£'000	£'000	£'000	£'000
Revenue - oil	-	-	-	-
Cost of sales	-	-	-	-

Gross profit	-	-	-	-
Exploration and evaluation expenditure	(1,323)	(164)	(39)	(1,526)
Intangible asset impairment	-	(1,360)	-	(1,360)
Receivables and inventory impairment	-	(54)	-	(54)
Administration expenses	(534)	(15)	-	(549)
Profit on exchange	130	-	-	130
Other operating income	-	83	-	83

Operating loss	(1,727)	(1,510)	(39)	(3,276)

Finance costs	-	(10)	-	(10)
Finance income	6	-	-	6

Loss on ordinary activities before taxation	(1,721)	(1,520)	(39)	(3,280)
Income tax expense	-	785	-	785

Loss on ordinary activities after taxation	(1,721)	(735)	(39)	(2,495)

Assets and liabilities
Segment assets	502	67	-	569
Cash and cash equivalents	1,692	146	-	1,838

Total assets	2,194	213	-	2,407

Segment liabilities	591	3	-	594
Current tax liabilities	-	23	-	23

Total liabilities	591	26	-	617

Other segment items
Capital expenditure	66	-	-	66
Depreciation, amortisation and impairment charges	-	1,414	-	1,414

3. (Loss) from operations	2019	2018
	£'000	£'000
The loss on ordinary activities before taxation is stated after charging:

Auditors' remuneration
Group - audit	21	22
Company - audit	21	22
Group - other non-audit services	5	5
Company - other non-audit services	5	5
Exploration and evaluation expenditure	160	1,526
Impairment of intangible assets	1,047	1,360

Impairment of foreign tax receivables	(16)	54
Loss/(gain on exchange	41	(130)


The analysis of development and administrative expenses in the consolidated income statement by nature of expense is:
	2019	2018
	£'000	£'000
Employee benefit expense	258	323
Exploration and evaluation expenditure	160	1,526
Depreciation, amortisation and impairment charges	1,031	1,414
Legal and professional fees	133	159
Loss/(gain) on exchange	41	(130)
Other expenses	51	67

	1,674	3,359

4. Other operating income	2019	2018
	£'000	£'000
Release of historic liabilities	-	83

	-	83

5. Staff numbers and cost
The average number of persons employed by the Group (including directors) during the year, analysed by category, were as follows:
	2019	2018
	Number	Number

Directors	3	3
Technical and production	-	-
Administration	1	-

Total	4	3


The aggregate payroll costs of these persons were as follows:	£'000	£'000

Wages and salaries	43	-
Directors' fees, salaries and benefits	192	264
Share based payments	-	33
Social security costs	23	27

	258	324


6. Finance income	2019	2018
	£'000	£'000
Bank and other interest received	1	6
Finance cost	(1)	(10)

Total	-	(4)



7. Income tax expense	2019		2018
	£'000		£'000
The tax charge on the loss on ordinary activities was:-

UK Corporation Tax - current	-		-
Foreign taxation	-		(785)

	-		(785)

The total charge for the year can be reconciled to the accounting profit as follows:
	2019		2018
	£'000		£'000
(Loss) before tax
Continuing operations	(1,674)		(3,280)

Tax at composite group rate of 19% (2018: 19%)	(318)		(623)

Effects of:
Losses/(profits) not subject to tax	221		206
Movement on capital allowances	(153)		95
Increase in tax losses	250		322
Foreign taxation	-		(785)

Tax expense	-		(785)


At 31 December 2019, the Group has tax losses of £28,208,000 (2018 - £26,828,000) to carry forward against future profits. The deferred tax asset on these tax losses at 19% of £5,359,000 (2018: at 17%, £4,465,000) has not been recognised due to the uncertainty of the recovery.
8. Loss for the period

As permitted by section 408 of the Companies Act 2006, the Parent Company's income statement has not been included in these financial statements. The loss for the financial year is made up as follows:
	2019		2018
	£'000		£'000

Parent company's loss	(1,751)		(2,699)

9. Earnings per share
	2019	2018
Loss per ordinary share
- Basic	(0.099p)	(0.181p)
- Diluted	(0.099p)	(0.181p)


Earnings per ordinary share is based on the Group's loss attributable to controlling interests for the year of £1,674,000 (2018: £2,495,000).
The weighted average number of shares used in the calculation is the weighted average ordinary shares in issue during the year.

	2019	2018
	Number	Number
Weighted average ordinary shares in issue during the year	1,685,313,686	1,376,409,576
Weighted average potentially dilutive options and warrants issued	82,150,685	46,671,139

Weighted average ordinary shares for diluted earnings per share	1,767,464,371	1,423,080,715

Due to the Group's results, the diluted earnings per share was deemed to be the same as the basic earnings per share for that year.

10. Property, plant and equipment
	Development and	Equipment and
	production costs	machinery	Total
	£'000	£'000	£'000
Group
Cost
At 1 January 2018	-	32	32
Foreign exchange translation adjustment	-	2	2

At 1 January 2019	-	34	34
Foreign exchange translation adjustment	-	(4)	(4)

At 31 December 2019	-	30	30

Depreciation
At 1 January 2018	-	32	32
Foreign exchange translation adjustment	-	2	2

At 1 January 2019	-	34	34
Foreign exchange translation adjustment	-	(4)	(4)

At 31 December 2019	-	30	30

Net book value
At 31 December 2019	-	-	-


At 31 December 2018	-	-	-

11. Intangible fixed assets		Exploration
		and evaluation
	Licence	costs	Total
	£'000	£'000	£'000
Group
Cost
At 1 January 2018	-	2,320	2,320
Foreign exchange translation adjustment	-	100	100
Expenditure	-	66	66
Disposals	-	-	-
At 1 January 2019	-	2,486	2,486
Foreign exchange translation adjustment	-	(61)	(61)
Expenditure	-	1,047	1,047
Disposals	-	-	-
At 31 December 2019	-	3,472	3,472

Impairment
At 1 January 2018	-	1,060	1,060
Charge for the period	-	1,360	1,360
At 1 January 2019	-	2,420	2,420
Charge for the period	-	1,047	1,047
At 31 December 2019	-	3,467	3,467

Net book value
At 31 December 2019	-	5	5


At 31 December 2018	-	66	66

11. Intangible fixed assets (continued)		Exploration
		and evaluation
	Licence	costs	Total
	£'000	£'000	£'000
Company
Cost
At 1 January 2018	-	634	634
Expenditure	-	67	67
At 1 January 2019	-	701	701
Expenditure	-	1,047	1,047
At 31 December 2019	-	1,748	1,748

Impairment
At 1 January 2018	-	69	69
Charge for the year	-	566	566
At 1 January 2019	-	635	635
Charge for the year	-	1,108	1,108
At 31 December 2019	-	1,743	1,743

Net book value
At 31 December 2019	-	5	1,113

At 31 December 2018	-	66	66

The exploration and evaluation costs above represent the cost in acquiring, exploring and evaluating the company's and group's assets.

The impairment of all intangible assets has been reviewed, giving rise to the following impairment charges, or reduction in impairment charges.

Block XXI Peru: this licence was fully impaired in 2018.

UK offshore block P2235 ("Wick"): the drilling of an exploration well commenced on 25 December 2018 and concluded on 16 January 2019 without success. As a result all costs relating to this activity, included accrued amounts expended in 2019, have been fully expensed.

UK offshore block P1918 ("Colter"): the drilling of an exploration well commenced on 6 February 2019 and was completed on 25 February 2019, with a further side-track well being drilled, completing on 8 March 2019. This licence continued into the Second Term with effect from 1 February 2020 but the Company has impaired the asset as it is likely that this licence will be relinquished within the next 12 months.

12. Goodwill					Goodwill on
					Consolidation
					of subsidiaries
					£'000
Group
Cost
At 1 January 2018, 1 January and 31 December 2019					81

Impairment
At 1 January 2018, 1 January and 31 December 2019					81

Net book value
At 31 December 2019					-


At 31 December 2018					-


The carrying value of goodwill represents the purchase of shares in Gold Oil Peru SAC.

13. Investments
		Loans to		Shares in
		group		group
		undertaking		undertaking		Total
		£'000		£'000		£'000
Company
Cost
At 1 January 2018		2,348		3,672		6,020
Exchange rate adjustment		41		-		41
Additions		-		1,947		1,947
Disposals		-		(150)		(150)
Net loan movements		(1,834)		-		(1,834)
At 1 January 2019		555		5,469		6,024
Exchange rate adjustment		(23)		-		(23)
Net loan movements		155		-		155
At 31 December 2019		687		5,469		6,156

Impairment
At 1 January 2018		2,348		3,647		5,995
Charge/(release) for the year		(1,793)		1,947		154
Disposals		-		(150)		(150)
At 1 January 2019		555		5,444		5,999
Charge for the year		132		-		132
At 31 December 2019		687		5,444		6,131

Carrying value
At 31 December 2019		-		25		25


At 31 December 2018		-		25		25


The company has made provision on the the investment in Gold Oil Peru S.A.C. of £6,131,000 (2018: £5,999,000). During 2018, the Group capitalised £1,949,000 of an intercompany loan to Gold Oil Peru S.A.C. as equity In April 2014, the Group disposed of a 50% interest in Inversiones Petroleras de Colombia SA ("Invepetrol"), incorporated in Colombia. In previous years, the Company had effective control of the operations and the results of the Company's operations were consolidated with the 50% no longer held by the Group being shown as a non-controlling interest. In March 2017, the 50% partner, CI International Fuels of Colombia, took control of the board of Invepetrol and, as a result, the Company no longer had operational control and the results and financial position of that company were deconsolidated in 2017. Invepetrol was put in liquidation in March 2018 and the liquidation was completed in October 2019. The Company's interest in that company has been fully written off.
Ayoopco Limited, a UK subsidiary, was dissolved on 21 August 2018.
13. Investments continued

The Company's subsidiary undertakings at the year end were as follows:
Subsidiary/controlled entity	Place of incorporation and operation	Proportion of ownership interest	Proportion of voting power held		Method used to account for investment		Nature of business
		%	%
Gold Oil Peru S.A.C	Peru	100	100		equity method		Exploration of oil and gas
Gold Oil Caribbean Limited	Commonwealth of Dominica	100	100		equity method		Exploration of oil and gas

All shareholdings are in ordinary, voting shares.

The results of subsidiaries are as follows:
					2019		2018
					£'000		£'000
Gold Oil Peru S.A.C
Aggregate capital and reserves					1,947		1,460
Profit/ (Loss) for the year					(65)		194
Gold Oil Caribbean Limited
Aggregate capital and reserves					1,421		1,421
Profit for the year					-		-

14. Trade and other receivables	2019		2018
	Group	Company	Group	Company
	£'000	£'000	£'000	£'000
Other receivables	8	8	111	111
Prepayments and accrued income	41	38	392	391
	49	46	503	502


15. Cash and cash equivalents	2019		2018
	Group	Company	Group	Company
	£'000	£'000	£'000	£'000
Bank current accounts	335	335	898	898
Bank deposit accounts	137	1	940	794
	472	336	1,838	1,692

Bank deposit accounts comprise cash held by the Group and short-term bank deposits with an original maturity of three months or less and earn interest at respective short-term deposit rates. The carrying amount of these assets approximates to their fair value.
As at 31 December 2019, bank deposits included £125,000 (2018: £129,000) that is being held as a guarantee until the Group fulfills certain licence commitments in Peru and is not available for use . This is not considered to be liquid cash and has therefore been excluded from the cash flow statement.

16. Trade and other payables	2019		2018
	Group	Company	Group	Company
	£'000	£'000	£'000	£'000

Trade payables	32	29	362	358
Amounts owed to subsidiary and associate undertakings	-	1,705	-	1,705
Accruals and deferred income	32	32	232	232
Taxation	7	7	23	8

	71	1,773	617	2,303


17. Share capital			2019	2018
			£'000	£'000
Allotted, called up and fully paid
Equity: 1,926,409,576 (2018: 1,376,409,576) ordinary shares of £0.00025 each			482	344

			482	344

During the period, the Company issued 550,000,000 new ordinary shares of £0.00025 each for cash at £0.001 per share.

18. Share premium and reserves			Foreign
	Share	Share	exchange	Profit
	premium	Option	translation	and loss
	account	reserve	reserve	account
	£'000	£'000	£'000	£'000
Group
At beginning of the year	30,237	74	1,712	(30,577)
Loss for the year attributable to controlling interests	-	-	-	(1,674)
Issue of new shares	303	-	-	-
Share issue costs	(33)	-	-	-
Foreign exchange translation adjustments	-	-	(69)	-
	30,507	74	1,643	(32,251)

Company
At beginning of the year	30,237	74	(163)	(30,510)
Loss for the year	-	-	-	(1,751)
Issue of new shares	303	-	-	-
Share issue costs	(33)	-	-	-
	30,507	74	(163)	(32,261)

Details of options and warrants issued, exercised and lapsed during the year together with options outstanding at 31 December 2019 are as follows:
			1 January	New			31 December
		Exercise	2019	Issue	Exercised	Lapsed	2019
Issue date	Final exercise date	price	Number	Number	Number	Number	Number
7 July 2017	7 July 2020	£0.00350	41,000,000	-	-	-	41,000,000
27 November 2018	27 November 2021	£0.00435	20,000,000	-	-	-	20,000,000
3 December 2018	3 December 2021	£0.00440	10,000,000	-	-	-	10,000,000
6 August 2019	6 August 2020	£0.00080	-	27,500,000	-	-	27,500,000
			71,000,000	27,500,000	-	-	98,500,000

Details of options issued, exercised and lapsed during the year together with options outstanding at 31 December 2018 are as follows:
			1 January	New			31 December
		Exercise	2018	Issue	Exercised	Lapsed	2018
Issue date	Final exercise date	price	Number	Number	Number	Number	Number
23 March 2015	23 March 2018	£0.0145	35,172,414	-	-	35,172,414	-
7 July 2017	7 July 2020	£0.0035	41,000,000	-	-	-	41,000,000
27 November 2018	27 November 2021	£0.00435	-	20,000,000	-	-	20,000,000
3 December 2018	3 December 2021	£0.00440	-	10,000,000	-	-	10,000,000
			76,172,414	30,000,000	-	35,172,414	71,000,000

19. Share based payments

The fair values of the options and warrants granted have been calculated using Black--Scholes model assuming the inputs shown below:
Grant date	6 August 2019	3 December 2018	27 November 2018	7 July 2017

Number of ptions or warrants granted	27,500,000	10,000,000	20,000,000	41,000,000
Share price at grant date	0.06p	0.44p	0.435p	0.35p
Exercise price at grant date	0.08p	0.44p	0.435p	0.35p
Option life	3 years	3 years	3 years	3 years
Risk free rate	0.86%	0.85%	0.85%	1.40%
Expected volatility	80%	75%	75%	75%
Expected dividend yield	0%	0%	0%	0%
Fair value of option	0.01p	0.11p	0.11p	0.10p


The options and warrants will not normally be exercisable during a closed period, and furthermore can only be exercisable if the performance conditions are satisfied. Subsisting warrants and options will lapse no later than 3 years after the date of grant. Warrants and options, which have vested immediately before either the death of a participant or his ceasing to be an eligible employee by reason of injury, disability, redundancy, retirement or dismissal (otherwise than for good cause) shall remain, exercisable (to the extent vested) for 12 months after such cessation, and all non--vested options shall lapse.

20. Directors' emoluments
			2019	2018
			£'000	£'000

Directors' remuneration			198	264
Compensation for loss of office			10	-
Share based payments			-	33
			208	297


Highest paid director emoluments and other benefits are as listed below.
			2019	2018
			£'000	£'000
Remuneration			103	150
Share based payments			-	11

			103	161

21. Financial instruments

The Group's activities expose it to a variety of financial risks: credit risk, cash flow interest rate risk, foreign currency risk, liquidity risk, price risk and capital risk. The Group's activities also expose it to non-financial risks: market risk. The Group's overall risk management programme focuses on unpredictability and seeks to minimise the potential adverse effects on the Group's financial performance. The Board, on a regular basis, reviews key risks and, where appropriate, actions are taken to mitigate the key risks identified.

Financial instruments - Risk Management

The Group is exposed through its operations to the following risks:

Ø Credit risk

Ø Cash flow interest rate risk

Ø Foreign Exchange Risk

Ø Liquidity risk

Ø Price risk

Ø Capital risk

Ø Market risk

In common with all other businesses, the Group is exposed to risks that arise from its use of financial instruments. This note describes the Group's objectives, policies and processes for managing those risks and the methods used to measure them. Further quantitative information in respect of these risks is presented throughout these financial statements.

There have been no substantive changes in the Group's exposure to financial instrument risks, its objectives, policies and processes for managing those risks or the methods used to measure them from previous periods unless otherwise stated in this note.

Principal financial instruments

The principal financial instruments used by the Group, from which financial instrument risk arises are as follows:

Ø Loans and receivables

Ø Trade and other receivables

Ø Cash and cash equivalents

Ø Short term investments

Ø Trade and other payables

General objectives, policies and processes

The Board has overall responsibility for the determination of the Group's risk management objectives and policies and, whilst retaining responsibility for them, it has delegated the authority for designing and operating processes that ensure the effective implementation of the objectives and policies to the Group's finance function. The Board receives regular updates from the Executive Directors through which it reviews the effectiveness of the processes put in place and the appropriateness of the objectives and policies it sets. The overall objective of the Board is to set policies that seek to reduce as far as possible without unduly affecting the Group's competitiveness and flexibility. Further details regarding these policies are set out below:

Credit risk

The Group's principal financial assets are bank balances and cash, trade and other receivables. The credit risk on liquid funds is limited because the counterparties are banks with high credit ratings assigned by international credit-rating agencies. The Group's credit risk is primarily attributable to its trade. The amounts presented in the statement of financial position are net of allowance for doubtful receivables. An allowance for impairment is made where there is an identified loss event which, based on previous experiences, is evidence of a reduction in the recoverability of the cash flows. The Group has no significant concentration of credit risk, with exposure spread over a number of counterparties and customers.

As at 31 December 2019 and 2018 there were no trade receivables.

Cash flow interest rate risk

The Group is exposed to cash flow interest rate risk from its deposits of cash and cash equivalents with banks. The cash balances maintained by the Group are proactively managed in order to ensure that the maximum level of interest is received for the available funds but without affecting the working capital flexibility the Group requires.

The Group is not at present exposed to cash flow interest rate risk on borrowings as it has no significant debt. No subsidiary company of the Group is permitted to enter into any borrowing facility or lease agreement without the prior consent of the Company.

Interest rates on financial assets

The Group's financial assets consist of cash and cash equivalents, loans, trade and other receivables. The interest rate profile at period end of these assets was as follows:

31 December 2019	Financial assets on which interest earned	Financial assets on which interest not earned	Total
	£'000	£'000	£'000

UK sterling	-	329	329
US dollar (USD)	125	53	178
Peruvian Nuevo Sol (PEN)	-	14	14
	125	396	521

31 December 2018	Financial assets on which interest earned	Financial assets on which interest not earned	Total
	£'000	£'000	£'000

UK sterling	-	1,213	1,213
US dollar (USD)	923	202	1,125
Peruvian Nuevo Sol (PEN)	-	3	3
	923	1,418	2,341

The Group earned interest on its interest bearing financial assets at rates between 0.1% and 3% (2018 0.1% and 3%) during the period.

A change in interest rates on the statement of financial position date would increase/(decrease) the equity and the anticipated annual income or loss by the theoretical amounts presented below. The analysis is made on the assumption that the rest of the variables remain constant. The analysis with respect to 31 December 2018 was prepared under the same assumptions.

	Change of 1.0% in the interest rate as of
	31 December 2019		31 December 2018
	Increase of 1.0%	Decrease of 1.0%	Increase of 1.0%	Decrease of 1.0%
Instruments bearing variable interest (£'000)	1	(1)	9	(9)

It is considered that there have been no significant changes in cash flow interest rate risk at the reporting date compared to the previous period end and that therefore this risk has had no material impact on earnings or shareholders' equity.

Foreign exchange risk

Foreign exchange risk arises because the Group has operations located in various parts of the world whose functional currency is not the same as the functional currency in which other Group companies are operating. Although its geographical spread reduces the Group's operation risk, the Group's net assets arising from such overseas operations are exposed to currency risk resulting in gains and losses on retranslation into Sterling. Only in exceptional circumstances will the Group consider hedging its net investments in overseas operations, as generally it does not consider that the reduction in foreign currency exposure warrants the cash flow risk created from such hedging techniques. It is the Group's policy to ensure that individual Group entities enter into local transactions in their functional currency wherever possible and that only surplus funds over and above working capital requirements should be transferred to the parent company treasury. The Group considers this policy minimises any unnecessary foreign exchange exposure.

In order to monitor the continuing effectiveness of this policy the Board, through its approval of both corporate and capital expenditure budgets and review of the currency profile of cash balances and management accounts, considers the effectiveness of the policy on an ongoing basis.

The following table discloses the major exchange rates of those currencies utilised by the Group:

	USD	PEN
Average for year ended 31 December 2019	1.28	4.28
At 31 December 2019	1.32	4.37
Average for year ended 31 December 2018	1.33	4.37
At 31 December 2018	1.27	4.28

Liquidity risk

Liquidity risk arises from the Group's management of working capital and the finance charges and principal repayments on its debt instruments. It is the risk that the Group will encounter difficulty in meeting its financial obligations as they fall due.

The Group's policy is to ensure that it will always have sufficient cash to allow it to meet its liabilities when they become due. To achieve this aim, it seeks to maintain readily available cash balances (or agreed facilities) to meet expected requirements for a period of at least 60 days. The Group currently has no long term borrowings.

Price risk

Oil and gas sales revenue is subject to energy market price risk.

Given current production levels, it is not considered appropriate for the Group to enter into any hedging activities or trade in any financial instruments, such as derivatives. This strategy will continue to be subject to regular review.

It is considered that price risk of the Group at the reporting date has not increased compared to the previous period end.

Volatility of crude oil prices

A material part of the Group's revenue will be derived from the sale of oil that it expects to produce. A substantial or extended decline in prices for crude oil and refined products could adversely affect the Group's revenues, cash flows, profitability and ability to finance its planned capital expenditure. The movement of crude oil prices is shown below:


	31 December 2019	Average price 2019	31 December 2018

Per barrel - US$	61	56	45
Per barrel - £	46	44	36
	═	═	═

Oil prices are dependent on a number of factors impacting world supply and demand. Due to these factors, oil prices may be subject to significant fluctuations from year to year. The Group's normal policy is to sell its products under contract at prices determined by reference to prevailing market prices on international petroleum exchanges. However, these prices had no effect on on the Group's results for 2019, since it had no production.

Capital risk

The Group's objectives when managing capital are to safeguard the ability to continue as a going concern in order to provide returns for shareholders and benefits to other stakeholders and to maintain an optimal capital structure to reduce the cost of capital.

Market risk

The market may not grow as rapidly as anticipated. The Group may lose customers to its competitors. The Group's major competitors may have significantly greater financial resources than those available to the group. There is no certainty that the group will be able to achieve its projected levels of sales or profitability.

22. Capital commitments

As of 31 December 2019, there were no capital commitments (2018 £703,000).

23. Contingent Liabilities

The Group and the Company have given guarantees of US$160,000 (31 December 2018: - US$160,000) to Perupetro SA to fulfil licence commitments for Block XXI. The Company considers that there are no potential decommissioning costs in respect of abandoned fields.

24. Events after the reporting period

On 19 February 2020, the Company issued 735,714,286 new ordinary shares of 0.025p each, followed by a further issue of 1,764,285,714 new ordinary shares of 0.025p each on 11 March 2020. The two share issues combined was for new capital of £2,500,000 gross, £2,306,000 net of costs. It is intended that the proceeds of the placing will be largely used to fund the Company's share of the ongoing TL-SO-19-16 PSC ("Chuditch PSC") work programme in Timor-Leste, the drilling of the onshore El Barco-3x well in Peru and provide additional working capital.

A Shareholders' Agreement ("SHA") has been executed withSundaGas Resources Pte. Ltd ("SundaGas") governing the operation of SundaGas (Timor-Leste Sahul) Pte.Ltd ("SundaGas TLS"), in which the Company now has a 33.33% shareholding. The sole asset of SundaGas TLS is its 100% shareholding in SundaGas Banda Unipessoal Lda., Operator of the Chuditch PSC, in which it holds a 75% interest.

Under the terms of the Carry Agreement, executed between SundaGas and the Company on 27^t January 2020, and the SHA, US$521,149 was paid to SundaGas on 21 April 2020 to reimburse the Company's 33.33% share of costs incurred since the Chuditch PSC was signed on 8 November 2019. This amount includes the Company's33.33% share of a $1,000,000 Bank Guarantee and the subscription for 3,333 shares in SundaGas TLS, representing 33.33% of the issued share capital of that company.

25. Ultimate controlling party

Baron Oil Plc is listed on the AIM market operated by the London Stock Exchange. At the date of the Annual Report in the directors' opinion there is no controlling party.

26. Related party transactions

Company
During the year, the Company advanced loans to its subsidiaries. The details of the transactions and the amount owed by the subsidiaries at the year end were.
	Year ended 31 December 2019		Year ended 31 December 2018
	Balance	Loan advance/(repayment)	Balance	Loan advance
	£'000	£'000	£'000	£'000

Gold Oil Peru S.A.C *	688	133	555	(1,793)


* The company has provided for an impairment of £688,000 (2018: £555,000) on the outstanding loans.


Group and company

The company paid £nil (2018: £9,000) for services rendered by Praetorian Advisors 2 Limited, a company controlled by Mr A Yeo, a director.
The company paid £9,915 (2018: £nil) for services rendered by Tedstone Oil and Gas Limited, a company controlled by Mr J Ford, a director.
The company paid £2,250 (2019:£9,000) for services rendered by Langley Associates Limited, a company controlled by Mr G Barnes, a director.

Glossary of Technical Terms

BCF	Billion cubic feet.

Geological chance of success	The estimated probability that exploration activities will confirm the existence of a significant accumulation of potentially recoverable petroleum.

GIIP	Volume of natural gas initially in-place in a reservoir.

Oil equivalent		Volume derived by dividing the estimate of the volume of natural gas in billion cubic feet by six in order to convert it to an equivalent in million barrels of oil and adding this to the estimate of the volume of oil in millions of barrels.

MMBBLS		Million barrels of oil.

Prospective Resources	Quantities of petroleum that are estimated to exist originally in naturally occurring reservoirs, as of a given date. Crude oil in-place, natural gas in-place, and natural bitumen in-place are defined in the same manner.

SPE PRMS Prospective Resources	The Society of Petroleum Engineers' ("SPE") Petroleum Resources Management System ("PRMS") is a system developed for consistent and reliable definition, classification, and estimation of hydrocarbon resources prepared by the Oil and Gas Reserves Committee of SPE and approved by the SPE Board in June 2018 following input from six sponsoring societies: the World Petroleum Council, the American Association of Petroleum Geologists, the Society of Petroleum Evaluation Engineers, the Society of Exploration Geophysicists, the European Association of Geoscientists and Engineers, and the Society of Petrophysicists and Well Log Analysts. Quantities of petroleum estimated, as of a given date, to be potentially recoverable from undiscovered accumulations by application of future development projects. The total quantity of petroleum that is estimated to exist originally in naturally occurring reservoirs, as of a given date. Crude oil in-place, natural gas in-place, and natural bitumen in-place are defined in the same manner.

SPE PRMS Unrisked Prospective Resources		Denotes the unrisked estimate qualifying as SPE PRMS Prospective Resources.
1U or P90 Prospective Resources		Denotes the low estimate qualifying as Prospective Resources. Reflects a volume estimate that there is a 90% probability that the quantities actually recovered will equal or exceed the estimate.
2U or P50 Prospective Resources		Denotes the median or best case estimate qualifying as Prospective Resources. Reflects a volume estimate that there is a 50% probability that the quantities actually recovered will equal or exceed the estimate.
3U or P10 Prospective Resources		Denotes the high estimate qualifying as Prospective Resources. Reflects a volume estimate that there is a 10% probability that the quantities actually recovered will equal or exceed the estimate.
Pmean		Reflects an unrisked median or best case volume estimate of resource derived using probabilistic methodology. This is the mean of the probability distribution for the resource estimates and is often not the same as 2U as the distribution can be skewed by high resource numbers with relatively low probabilities.

This information is provided by RNS, the news service of the London Stock Exchange. RNS is approved by the Financial Conduct Authority to act as a Primary Information Provider in the United Kingdom. Terms and conditions relating to the use and distribution of this information may apply. For further information, please contact rns@lseg.com or visit www.rns.com.

END

FR SEEFIAESSELL

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Wednesday, 18th December 2024

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