ZOL.L Regulatory News (ZOL)

22 May 2018

Zoltav Resources Inc.

("Zoltav" or the "Company")

Final Results for the Year Ended 31 December 2017

Zoltav (AIM: ZOL), the Russia-focused oil and gas exploration and production company, announces final results for the year ended 31 December 2017.

Financial Highlights

· Revenues from production declined, in line with expectations, by 10% to RUB 1.79 billion (USD 30.68 million) (2016: RUB 1.99 billion (USD 29.69 million)) 

· EBITDA increased by 5% to RUB 888 million (USD 15.22 million) (2016: RUB 846 million (USD 12.62 million))

· EBITDA margin increased to 50% (2016: 43%) 

· Total cost of sales remained steady at RUB 1.15 billion (USD 19.71 million) (2016: RUB 1.15 billion (USD 17.16 million)) 

· G&A costs reduced significantly by 38% to RUB 185 million (USD 3.17 million) (2016: RUB 299 million (USD 4.46 million)), mostly achieved through administrative staff reduction, cutting non-strategic costs and maintenance optimisation

· Operating profit increased by 2% to RUB 450 million (USD 7.71 million) (2016: RUB 441 million (USD 6.58 million)) 

· Impairment allowance for RUB 1.69 billion (USD 29.34 million) taken in respect of the Koltogor Licences for which development is currently on hold, leading to a loss before tax of RUB 1.43 billion (USD 24.51 million) (2016: RUB 197 million (USD 2.94 million))

· Net loss including the impairment allowance for the Koltogor Licences was RUB 1.27 billion (USD 21.76 million) (2016: RUB 97 million net profit (USD 1.45 million))

· Net profit excluding the impairment allowance for the Koltogor Licences increased significantly by 87% to RUB 182 million (USD 3.12 million) (2016: RUB 97 million net profit (USD 1.45 million)) 

· Reduced borrowings further through repayment of RUB 300 million of PJSC Sberbank debt (USD 5.21 million) - reducing the principal amount to RUB 1.56 billion (USD 27.08 million) at 31 December 2017 (RUB 1.86 billion (USD 30.66 million) as at 31 December 2016) 

· Net cash generated from operating activities increased by 1% to RUB 728 million (USD 12.64 million) (2016: RUB 719 million (USD 11.85 million)) 

· Total cash at 31 December 2017 was RUB 286 million (USD 4.97 million) (31 December 2016: RUB 294 million (USD 4.85 million)) 

· The Group has sufficient liquidity to fund its current seismic programme and entered into an agreement after the year-end with its two largest shareholders for their provision of an unsecured loan facility of up to an aggregate USD 12 million in further support of the exploration programme

Note: USD comparisons are provided in the above Financial Highlights for illustrative purposes only and are calculated using an exchange rate of:

2017: 1 USD = 58.3529 RUB

As at 31 December 2017: 1 USD = 57.6002 RUB

2016: 1 USD = 67.0349 RUB

As at 31 December 2016: 1 USD = 60.6569 RUB

Operational Highlights - Bortovoy Licence

· Net production declined, in line with expectations, by 13% to 2.6 mmboe in 2017 (2016: 3 mmboe), made up of:

o Natural gas: 14.8 bcf (418 mmcm) or 2.5 mmboe (335.5 mtoe) (2016: 16.8 bcf (475.8 mmcm) or 2.8 mmboe (381.9 mtoe))

o Oil and condensate: 122,962 bbls (15,663 t) (2016: 163,967 bbls (20,888 t))

· Average net daily production was 7,075 boe/d (965 toe/d) (2016: 8,118 boe/d (1,108 toe/d)), made up of:

o Natural gas: 40.4 bcf/d (1.15 mmcm/d) (2016: 46.0 bcf/d (1.3 mmcm/d))

o Oil and condensate: 337 bbls/d (43 t/d) (2016: 449 bbls/d (57 t/d))

· High focus on operational efficiency maintained including the reduction of planned plant shutdowns through use of improved chemical agents for the treatment of gas and the re-use of light fractions of hydrocarbons which were previously flared

· Strategic decision to transition operational emphasis from production to exploration, while continuing to generate cash from Permian fields already in production - management believes there is potential to yield substantial additional reserves and production from Carbonian and Devonian horizons 

· Considerable 3D seismic programme over the Carbonian and Devonian (and prospective Permian) structures in the North Mokrous area of the Mokrousovskoye block undertaken in 2017 - preliminary interpretation of the first 180 sq km now complete

Operational Highlights - Koltogor Licences

· Koltogor Licences are not currently a focus of investment as the company is channeling capex into the exploration programme on the Bortovoy Licence

Corporate Highlights

· Board and management changes

o Lea Verny, previously Independent Non-executive Director, replaced Marcus Rhodes as Independent Non-executive Chairman on 22 March 2017

o Marcus Rhodes, previously Independent Non-executive Chairman and subsequently Senior Independent Director, did not stand for re-election at the Annual General Meeting on 23 May 2017

o Eduard Sleyn appointed as Group CEO on 15 May 2017

o Kirill Suetov appointed as Group Director of Finance on 1 January 2017

Lea Verny, Independent Non-executive Chairman, commented:

"Despite the anticipated decline in production revenues, our rigorous commitment to cost and operational efficiencies, including the limitation of plant shut-downs through the application of new and improved chemical processes in the gas treatment unit, enabled the Company to achieve a 5% increase in EBITDA to RUB 888 million (USD 15.22 million) (2016: RUB 846 million) (USD 12.62  million)).

We took the strategic decision in 2017 to transition the operational emphasis of the Company from production to exploration, while continuing to generate cash from the Permian fields already in production. Zoltav believes there is potential to yield substantial additional reserves and production from the Carbonian and Devonian horizons at Bortovoy which, if proven, would have a transformational impact on the size of the Bortovoy asset.

A considerable 3D seismic acquisition programme was undertaken in these horizons in 2017 and the exploration programme has continued to gather pace in the year to date including with the preliminary interpretation of data and the strengthening of the technical team in support of the work programme. We look forward to reporting further progress as the programme advances."

The full annual report is available to download from the Investor Relations section of the Company's website at www.zoltav.com.

Enquiries:

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.

About Zoltav

Zoltav is an oil and gas exploration and production company focused on Russia.

Zoltav holds the Bortovoy Licence in the Saratov region of South Western Russia, a 3,215 square kilometre area along the northern margin of the Pre-Caspian basin, one of the largest hydrocarbon basins in the CIS.

The Bortovoy Licence contains a number of productive gas fields, a processing plant and significant exploration prospectivity. It holds Proved plus Probable reserves of 750 bcf of gas and 3.8 mmbbls of oil and condensate. In 2017, the Bortovoy Licence produced 14.8 bcf of natural gas and 122,962 bbls of oil and condensate for sale (approximately 2.6 mmboe in total).

An exploration programme is underway on the Bortovoy Licence to assess the resource potential of the deeper Carbonian and Devonian structures.

Zoltav also holds the Koltogor E&P Licence, a 528 square kilometre area in the Khantiy-Mansisk Autonomous Okrug of Western Siberia. Development activities on the Koltogor Licences are currently on hold.

For further information on Zoltav or to sign up for our news alert service visit: www.zoltav.com.

Financial report

Chairman's statement

Zoltav entered an exciting new phase in 2017 which has continued to gather pace in the year to date.

Management took the strategic decision in 2017 to transition the operational emphasis of the Company from production to exploration, while continuing to generate cash from the Permian fields already in production. Zoltav believes there is potential to yield substantial additional reserves and production from the Carbonian and Devonian horizons at Bortovoy which, if proven, would have a transformational impact on the size of the Bortovoy asset. The availability of modern seismic imaging, drilling and production technologies has enabled the Company to develop a work programme targeting these deeper structures which lie approximately 3,500-5,000 m below surface.

A considerable 3D seismic acquisition programme was undertaken in 2017 over the Carbonian and Devonian (and also prospective Permian) structures in the North Mokrous area of the Mokrousovskoye block, and has continued into 2018, using first-class contractors to acquire, process and interpret data. Preliminary interpretation of the first 180 sq km has been completed, with encouraging results announced in March 2018; and up to a further 536 sq km of 3D seismic data (of which 140 sq km has been completed in the year to date prior to the autumn weather pause) is anticipated to be acquired through the remainder of this year. Sufficient interpretation of these data is expected to be completed in time to allow for the positioning and drilling of the first Devonian exploration well, on North Mokrous, now expected in Q1 2019.

In support of the Company's work programme, we were delighted to announce earlier this month the recruitment of a team of highly accomplished former Bashneft and TNK-BP technical executives, led by Yuri Krasnevsky who became Zoltav's Director for Geology and Field Development. They and the rest of the technical staff and consultants are focused on growing the resource and production potential of the Bortovoy Licence.

In the Permian Basin, the horizon from which gas and oil is currently produced on the Bortovoy Licence, varying reservoir thickness and underperforming wells on the Karpenskoye and Zhdanovskoye fields in 2017 caused management to suspend the drilling programme in this structure until the interpretation of high quality 3D seismic data is completed - and additional 3D seismic data is acquired - during the course of 2018.

As a result of the suspension of the Permian Basin drilling programme, revenues from production declined in 2017, in line with management's expectations, by 10% to RUB 1.79 billion (2016: RUB 1.99 billion); while the net production1 from the Western Gas Plant was an average of 7,075 boe/d (965 toe/d) in 2017, a decline of approximately 13% compared to 8,118 boe/d (1,108 toe/d) in 2016.

Despite this, however, as a result of Zoltav's rigorous commitment to cost and operational efficiencies, including the limitation of plant shut-downs through the application of new and improved chemical processes in the gas treatment unit, the Company was able to achieve a 5% increase in EBITDA2 to RUB 888 million (2016: RUB 846 million). The EBITDA margin increased to 50% compared to 43% in 2016. Net cash flow from operating activities increased slightly to RUB 728 million (2016: RUB 719 million).

In light of the strategic shift to capital intensive exploration at Bortovoy, development activities on the Koltogor Licences in Western Siberia remain on hold. As a result, the Company made an allowance in the 2017 accounts for the full impairment of this asset (RUB 1.69 billion), which caused a net loss of RUB 1.27 billion (2016: RUB 97 million net profit). Excluding this non-cash item, the Company generated a much-improved net profit of RUB 182 million (an increase of 87%).

Efficient procurement, cost-cutting initiatives and zero-based budgeting allowed Zoltav to generate impressive cost savings across the business, notably a 38% decrease (RUB 114 million) in administrative and operating expenses and a 75% decrease (RUB 107.6 million) in other expenses of non-operating companies of the Group. These cost reductions in 2017 are mostly recurring and accordingly this positions the Company very attractively to leverage the benefits of a future increase in production.

Notwithstanding the anticipated decline in production revenues through 2018 as a result of the suspension of the Permian Basin drilling programme, the Company remains in good financial health, servicing its debt commitments and advancing this exciting exploration programme targeting the deeper structures - a programme in support of which, as announced in April 2018, the Company's two largest shareholders have decided to provide an unsecured loan facility of up to an aggregate US$ 12 million.

We look forward to reporting further progress as the exploration programme progresses.

Lea Verny

Non-executive Chairman

21 May 2018

Note: 

 1 Net production is the volume actually sold to customers. It comprises all extracted hydrocarbons, less own consumption and losses. The Company uses net production volumes throughout the 2017 annual report instead of the previously used total extracted volumes.

2 The Company historically calculates consolidated EBITDA as Operating profit added back with Depreciation, Depletion and Amortization

Review of operations

Production

Production from Zoltav's Western Gas Plant on the Bortovoy Licence, Saratov, averaged 7,075 boe/d (965 toe/d) during 2017, a decline of 13% when compared to 8,118 boe/d (1,108 toe/d) in 2016. This comprised average production of 40.4 bcf/d (1.15 mmcm/d) of natural gas and 337 bbls/d (43 t/d) of oil and condensate (2016: 46.0 bcf/d (1.3 mmcm/d) of natural gas and 449 bbls/d (57 t/d) of oil and condensate).

Overall in 2017, the Company produced 2.6 mmboe (2016: 3 mmboe) of gas and liquids, made up of:

- Natural gas: 14.8 bcf (418 mmcm) or 2.5 mmboe (335.5 mtoe) (2016: 16.8 bcf (475.8 mmcm) or 2.8 mmboe (381.9 mtoe))

- Oil and condensate: 122,962 bbls (15,663 t) (2016: 163,967 bbls (20,888 t))

The decline in production volumes during 2017 resulted from the underperformance of certain wells, as announced in the Company's half-year report in September 2017. Karpenskoye Well 117 was shut down in early January 2017 due to water cut; the newly drilled Zhdanovskoye Well 108 was put on production in March 2017 and is delivering materially lower gas production than initially anticipated; the newly drilled Zhdanovskoye Well 30 sidetrack, as announced in October 2017, was unsuccessful and is contributing lower than expected volumes; and water intrusion occurred on Zhdanovskoye Well 8 resulting in the anticipated shutdown of this well in July 2018.

The negative impact of these wells caused an aggregate reduction in production in 2017 of 2.75 bcf (77.9 mmcm) of natural gas and 9,908 bbls (1,626 t) of condensate.

Notwithstanding the performance of these wells, the Company's remaining well stock of 13 continued to produce in line with normal well production profiles.

Zoltav maintained its high focus on operational efficiency to eliminate the impact on profitability arising from the decline in production. For example, the use of new and improved chemical agents for the treatment of gas enabled the Company to reduce planned plant shutdowns by two during the year and save on the associated downtime. Furthermore, Zoltav undertook a programme to modernise the propane compressor cooling system to reduce the temperature during the summer months and thereby reduce the dew point. This enabled the Company to produce additional condensate and improved the quality of the product. For the first time, Zoltav installed sucker-rod pumping units on Karpenskoye Wells 17 and 5D for the secondary recovery of heavy oil, adding 4,286 bbls (546 T) of oil production. To further drive operational efficiencies during the year, Zoltav implemented a system of individual goal-setting for middle-chain technical staff and incentives for bringing additional ideas for operational excellence. This resulted, for example, in a successful scheme to re-use light fractions of hydrocarbons which were previously flared, resulting in an increase in liquids available for sale.

Zoltav is establishing plans to set up a well-head compressor on the Karpenskoye field by July 2018, giving rise to an estimated 128,843 boe (17,567 toe) of additional production annually.

Exploration and development

Bortovoy

As a result of the significant variation in reservoir thickness encountered in the Permian Basin in the Western Fields of the Bortovoy Licence, and operational difficulties encountered with certain wells, management took the decision in October 2017 to suspend the drilling programme in this horizon until the interpretation of high quality 3D seismic data is completed - and additional 3D seismic data is acquired - during the course of 2018.

In parallel, management took the decision to divert capex for the remainder of 2017 and 2018 to an exploration programme targeting the deeper Devonian and Carbonian structures in the west of the Bortovoy Licence, which lie approximately 3,500-5,000 m below surface and which, if proven, would have a transformational impact on the size and production profile of the Bortovoy asset.

A 3D seismic acquisition programme was undertaken in 2017 over the Carbonian and Devonian (and also prospective Permian) structures in the North Mokrous area of the Mokrousovskoye block and has continued in the year to date. Preliminary interpretation of the first 180 sq km has been completed, with encouraging results announced in March 2018; and up to a further 536 sq km of 3D seismic data (of which 140 sq km has been completed in the year to date prior to the autumn weather pause) is anticipated to be acquired through the remainder of 2018. Sufficient interpretation of these data is expected to be completed in time to allow for the positioning and drilling of the first Devonian exploration well, on North Mokrous, now expected in Q1 2019.

In support of the work programme, the Company announced in May 2018 the recruitment of former Bashneft and TNK-BP technical executives, led by Yuri Krasnevsky who became Zoltav's Director for Geology and Field Development.

Koltogor

The Koltogor Licences in the Khantiy Mansisk Autonomous Okrug, Western Siberia are not currently a focus of investment, as the Company is channeling capex into the exploration programme on the Bortovoy Licence. Management notes, however, the activity of the Bazhen Technology Centre launched by Gazprom Neft in 2017 in the same region as the Koltogor Licence. The centre is focusing on the development of advanced independent skills and technologies required for the cost-effective development of hydrocarbons in the Bazhenov formation, in which management believes there is potential in the Koltogor Licences.

Group Reserves under PRMS as per latest report of DeGolyer and MacNaughton (May 2014):

The Company is planning a re-evaluation of reserves under PRMS following completion of the exploration programme currently ongoing on the Bortovoy Licence.

Conversion rates

Tonnes of crude oil produced are translated into barrels using conversion rates reflecting oil density from each of the fields. Crude oil and liquid hydrocarbons expressed in barrels are translated from tonnes using a conversion rate of 7.85 barrels per tonne. Translations of cubic feet to cubic metres are made at the rate of 35.3 cubic feet per cubic metre. Translations of barrels of crude oil and liquid hydrocarbons into barrels of oil equivalent ("boe") are made at the rate of 1 barrel per boe and of cubic feet into boe at the rate of 290 cubic feet per boe.

Financial review

Management continued to focus throughout 2017 on challenging non-strategic costs, analysing capital expenditures and operating efficiently. As a result, and despite the production decline, Zoltav was able to achieve a 5% increase in EBITDA to RUB 888 million (2016: RUB 846 million).

Revenue

The Group's revenues in 2017 decreased by 10% to RUB 1.79 billion, compared to RUB 1.99 billion in 2016, as a result of the decline in production.

85% of revenue was derived from gas sold to Mezhregiongaz, a Gazprom subsidiary, at the transfer point on entry to the Central Asia - Center gas pipeline system. The gas prices are fixed in a contract with Mezhregiongaz and are subject to indexation. The Russian Government approved a 3.9% gas price increase from 1 July 2017 and accordingly the Company signed an addendum to its contract with Mezhregiongaz. We anticipate that a further increase of 2% in gas price indexation will be approved by the Russian Government in June 2018 which will further benefit the Company.

The remaining revenue was from oil and condensate sold to a small number of different buyers either directly at the Western Gas Plant or via a petroleum storage depot with access to the railway. The sale price is set through a tender process starting each month following the publication of the Rosneft tender results, which influence domestic oil prices. In 2017, Zoltav started to sell heavy oil produced from Karpenskoye Wells 17 and 5D and priced on a formula linked to Brent quotes on Cortes (part of Thomson Reuters).

Oil prices were favourable in 2017 and Zoltav sold liquid products above the market, according to our net back calculations for oil in our region and with our qualities. The Company began diversifying its portfolio of buyers to reduce dependence on its main purchaser in 2016. These factors resulted in a positive impact on average oil and condensate sales prices which were RUB 2,100/bbl (RUB 16,500/t) in 2017 compared to RUB 1,700/bbl (RUB 13,200/t) in 2016.

Cost of sales and G&A costs

Total cost of sales was RUB 1.15 billion (2016: RUB 1.15 billion). This comprised RUB 371.6 million of mineral extraction tax (2016: RUB 406.5 million), RUB 437.2 million of depreciation and depletion of assets (2016: RUB 404.7 million) and RUB 338 million of other cost of sales (2016: RUB 344 million).

The Group's operational and G&A costs decreased by 38% to RUB 185 million (2016: RUB 299 million), while other expenses decreased by 75% to RUB 35 million (2016: RUB 143 million), mostly achieved through administrative staff reduction of 20%, cutting non-strategic costs and maintenance optimisation. Examples of material cost savings achieved in the year, include:

· containing the expenses of non-operational entities to a minimum and reducing the cost of administrative personnel - RUB 115 million saving;

· changing the contractor for heavy compressor parts and services - RUB 15 million saving;

· shutting down Heavy Compressor 1540 and redirecting its associated gas flow, allowing the Company to avoid associated maintenance costs; and turning off two out of three power generating units which were also maintenance heavy - RUB 12.8 million saving;

· switching to improved chemical agents for the treatment of gas, enabling the Company to reduce planned plant shutdowns by two during the year and save on the associated downtime - RUB 5 million saving;

· changing the methanol flow and regeneration unit and making the system 'closed-loop' with minimal waste and minimising the procurement of external methanol - RUB 4.6 million saving;

· renegotiating contractual terms for the renting of land plots - RUB 4 million saving; and

· identifying a Russian substitute for an expensive foreign catalyst which was previously used in the sulphur production unit - RUB 2.4 million saving.

Other cost of sales is mainly operating expenses of Diall Alliance, the Bortovoy operating company, which decreased by 2% to RUB 338 million (2016: RUB 344.1 million) despite the expiration of a property tax incentive which was granted by the Saratov regional tax authority during gas plant construction (annual property tax increased from RUB 16.8 million to RUB 47.1 million).

Operating profit

Zoltav achieved an operating profit for 2017 of RUB 450 million, compared to RUB 441 million in 2016.

Finance costs of RUB 225 million (2016: RUB 268 million) are mainly represented by interest on the remaining RUB 1.56 billion Sberbank facility. The Company is negotiating terms which management believes will reduce finance costs in 2018.

Profit before tax

Zoltav generated a RUB 1.43 billion loss, compared to RUB 197 million profit in 2016, due to an impairment allowance amounting to RUB 1.69 billion in respect of the Koltogor Licences for which development activities are currently on hold.

Taxation

Production based tax for the period was RUB 372 million (2016: RUB 407 million) which is recognised in the cost of sales. The MET tax formula is based on multi-component gas composition, average gas prices and reservoir complexity and maturity. The effective MET rate applicable for the period was flat at RUB 24/mcf or RUB 849/mcm (2016: RUB 23/mcf or RUB 810/mcm).

In addition to production taxes, the Group was subject to a 2.2% property tax which is based on the net book value of Russian assets calculated for property tax purposes. Property tax on the major part of the Bortovoy operating company's assets, including the Western Gas Plant, is paid at a reduced tax rate of 0.1%, in line with tax incentives for regional investment projects. There was no clear legal instruction regarding the maturity of a tax incentive previously referred to in the Company's half-year report, resulting from management's inquiries with the tax authority. Accordingly, the Company recognised an additional tax charge in the amount of RUB 28 million during the year.

Net profit

As noted above, the Company made an allowance in the 2017 accounts for the full impairment of the Koltogor Licences (RUB 1.69 billion), which caused a net loss of RUB 1.27 billion (2016: RUB 97 million net profit). Excluding this non-cash item, the Company generated a much-improved net profit of RUB 182 million (an increase of 87%).

Cash

Net cash generated from operating activities was RUB 728 million (2016: RUB 719 million).

Diall Alliance successfully serviced its credit facility with PJSC Sberbank and repaid a further RUB 300 million of the principal amount (RUB 1,860 million at 31 December 2016) according to its schedule. The Company remains in line with the covenants of its credit facility agreement.

Zoltav has sufficient liquidity to fund its current seismic programme and announced in April that the Board of Directors approved an agreement with its two largest shareholders for their provision of an unsecured loan facility of up to an aggregate US$12 million in further support of the exploration programme.

Total cash at the end of the period was RUB 286.75 million (2016: RUB 294 million).

Kirill Suetov

Chief Financial Officer

21 May 2018

Independent auditor's report on the consolidated financial statements of Zoltav Resources Inc. and its subsidiaries

To the Shareholders and Board of Directors of Zoltav Resources Inc.

Opinion

We have audited the consolidated financial statements of Zoltav Resources Inc. and its subsidiaries (the Group), which comprise the consolidated statement of financial position as at 31 December 2017, and the consolidated statement of comprehensive income, consolidated statement of changes in equity and consolidated statement of cash flows for 2017, and notes to the consolidated financial statements, including a summary of significant accounting policies.

In our opinion, the accompanying consolidated financial statements present fairly, in all material respects, the consolidated financial position of the Group as at 31 December 2017 and its consolidated financial performance and its consolidated cash flows for 2017 in accordance with International Financial Reporting Standards (IFRSs).

Basis for opinion

We conducted our audit in accordance with International Standards on Auditing (ISAs). Our responsibilities under those standards are further described in the Auditor's responsibilities for the audit of the consolidated financial statements section of our report. We are independent of the Group in accordance with the International Ethics Standards Board for Accountants' Code of Ethics for Professional Accountants (IESBA Code) together with the ethical requirements that are relevant to our audit of the consolidated financial statements in the Russian Federation, and we have fulfilled our other ethical responsibilities in accordance with these requirements and the IESBA Code. We believe that the audit evidence we have obtained is sufficient and appropriate to provide a basis for our opinion.

Key audit matters

Key audit matters are those matters that, in our professional judgment, were of most significance in our audit of the consolidated financial statements of the current period. These matters were addressed in the context of our audit of the consolidated financial statements as a whole, and in forming our opinion thereon, and we do not provide a separate opinion on these matters. For the matter below, our description of how our audit addressed this matter is provided in that context.

We have fulfilled the responsibilities described in the Auditor's responsibilities for the audit of the consolidated financial statements section of our report, including in relation to this matter. Accordingly, our audit included the performance of procedures designed to respond to our assessment of the risks of material misstatement of the consolidated financial statements. The results of our audit procedures, including the procedures performed to address the matter below, provide the basis for our audit opinion on the accompanying consolidated financial statements.

Other information included in the Annual Report for 2017

Other information consists of the information included in the Annual Report for 2017, other than the consolidated financial statements and our auditor's report thereon. Management is responsible for the other information.

Our opinion on the consolidated financial statements does not cover the other information and we do not express any form of assurance conclusion thereon.

In connection with our audit of the consolidated financial statements, our responsibility is to read the other information and, in doing so, consider whether the other information is materially inconsistent with the consolidated financial statements or our knowledge obtained in the audit or otherwise appears to be materially misstated. If, based on the work we have performed, we conclude that there is a material misstatement of this other information, we are required to report that fact. We have nothing to report in this regard.

Responsibilities of management and the Audit Committee for the consolidated financial statements

Management is responsible for the preparation and fair presentation of the consolidated financial statements in accordance with IFRSs, and for such internal control as management determines is necessary to enable the preparation of consolidated financial statements that are free from material misstatement, whether due to fraud or error.

In preparing the consolidated financial statements, management is responsible for assessing the Group's ability to continue as a going concern, disclosing, as applicable, matters related to going concern and using the going concern basis of accounting unless management either intends to liquidate the Group or to cease operations, or has no realistic alternative but to do so. 

The Audit Committee is responsible for overseeing the Group's financial reporting process.

Auditor's responsibilities for the audit of the financial statements

Our objectives are to obtain reasonable assurance about whether the consolidated financial statements as a whole are free from material misstatement, whether due to fraud or error, and to issue an auditor's report that includes our opinion. Reasonable assurance is a high level of assurance, but is not a guarantee that an audit conducted in accordance with ISAs will always detect a material misstatement when it exists. Misstatements can arise from fraud or error and are considered material if, individually or in the aggregate, they could reasonably be expected to influence the economic decisions of users taken on the basis of these consolidated financial statements.

As part of an audit in accordance with ISAs, we exercise professional judgment and maintain professional skepticism throughout the audit. We also:

· Identify and assess the risks of material misstatement of the consolidated financial statements, whether due to fraud or error, design and perform audit procedures responsive to those risks, and obtain audit evidence that is sufficient and appropriate to provide a basis for our opinion. The risk of not detecting a material misstatement resulting from fraud is higher than for one resulting from error, as fraud may involve collusion, forgery, intentional omissions, misrepresentations, or the override of internal control.

· Obtain an understanding of internal control relevant to the audit in order to design audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Group's internal control.

· Evaluate the appropriateness of accounting policies used and the reasonableness of accounting estimates and related disclosures made by management.

· Conclude on the appropriateness of management's use of the going concern basis of accounting and, based on the audit evidence obtained, whether a material uncertainty exists related to events or conditions that may cast significant doubt on the Group's ability to continue as a going concern. If we conclude that a material uncertainty exists, we are required to draw attention in our auditor's report to the related disclosures in the consolidated financial statements or, if such disclosures are inadequate, to modify our opinion. Our conclusions are based on the audit evidence obtained up to the date of our auditor's report. However, future events or conditions may cause the Company Group to cease to continue as a going concern.

· Evaluate the overall presentation, structure and content of the consolidated financial statements, including the disclosures, and whether the consolidated financial statements represent the underlying transactions and events in a manner that achieves fair presentation.

· Obtain sufficient appropriate audit evidence regarding the financial information of the entities or business activities within the Group to express an opinion on the consolidated financial statements. We are responsible for the direction, supervision and performance of the group audit. We remain solely responsible for our audit opinion.

We communicate with the Audit Committee regarding, among other matters, the planned scope and timing of the audit and significant audit findings, including any significant deficiencies in internal control that we identify during our audit.

We also provide the Audit Committee with a statement that we have complied with relevant ethical requirements regarding independence, and to communicate with it all relationships and other matters that may reasonably be thought to bear on our independence, and where applicable, related safeguards.

From the matters communicated with the Audit Committee, we determine those matters that were of most significance in the audit of the consolidated financial statements of the current period and are therefore the key audit matters. We describe these matters in our auditor's report unless law or regulation precludes public disclosure about the matter or when, in extremely rare circumstances, we determine that a matter should not be communicated in our report because the adverse consequences of doing so would reasonably be expected to outweigh the public interest benefits of such communication.

The partner in charge of the audit resulting in this independent auditor's report is T.L. Okolotina.

T.L. Okolotina

Partner

Ernst & Young LLC

21 May 2018

Details of the audited entity

Name: Zoltav Resources Inc.

Record made in the Registar of Companies, Cayman Islands on 18 November 2003, Registration Number 130605.

Address: PO Box 10008, Willow House, Cricket Square, Grand Cayman KY1-1001, Cayman Islands.

Details of the auditor

Name: Ernst & Young LLC

Record made in the State Register of Legal Entities on 5 December 2002, State Registration Number 1027739707203.

Address: Russia 115035, Moscow, Sadovnicheskaya naberezhnaya, 77, building 1.

Ernst & Young LLC is a member of Self-regulated organization of auditors "Russian Union of auditors" (Association) ("SRO RUA"). Ernst & Young LLC is included in the control copy of the register of auditors and audit organizations, main registration number 11603050648.

Consolidated statement of comprehensive income for the year ended 31 December 2017

(in '000s of Russian rubles, unless otherwise stated)

Kirill Suetov

Chief Financial Officer

21 May 2018

Consolidated statement of financial position as at 31 December 2017

(in '000s of Russian rubles, unless otherwise stated)

Consolidated statement of cash flows for the year ended 31 December 2017

(in '000s of Russian rubles, unless otherwise stated)

Consolidated statement of changes in equity for the year ended 31 December 2017

(in '000s of Russian rubles, unless otherwise stated)

Notes to the consolidated financial statements for the year ended 31 December 2017

(in '000s of Russian rubles, unless otherwise stated)

1. Background

1.1 The Company and its operations

Zoltav Group (the Group) comprises Zoltav Resources Inc. (the Company), together with its subsidiaries:

The Company was incorporated in the Cayman Islands on 18 November 2003. The principal activities of the Company and its subsidiaries is the acquisition, exploration, development and production of hydrocarbons in the Russian Federation. The Company's shares are listed on the Alternative Investment Market of the London Stock Exchange.

1.2 Russian business environment

The Group's operations are primarily located in the Russian Federation.

The Russian Federation displays certain characteristics of an emerging market. Its economy is particularly sensitive to oil and gas prices. The legal, tax and regulatory frameworks continue to develop and are subject to frequent changes and varying interpretations. The Russian economy was growing in 2017, after overcoming the economic recession of 2015 and 2016. The economy is negatively impacted by low oil prices, ongoing political tension in the region and international sanctions against certain Russian companies and individuals. The financial markets continue to be volatile.

The combination of the above resulted in reduced access to capital, a higher cost of capital and uncertainty regarding economic growth, which could negatively affect the Group's future financial position, results of operations and business prospects. Management believes it is taking appropriate measures to support the sustainability of the Group's business in the current circumstances.

1.3 Basis of preparation

The consolidated financial statements of the Group have been prepared in accordance with International Financial Reporting Standards (IFRS), as adopted by the European Union (EU), International Financial Reporting Interpretations Committee (IFRIC) interpretations, and the Companies Act 2006 applicable to companies reporting under IFRS. The consolidated financial statements have been prepared under the historical cost convention, as modified by the revaluation of financial assets and financial liabilities (including derivative instruments) at fair value through profit or loss.

The preparation of financial statements in conformity with IFRS requires the use of certain critical accounting estimates. It also requires management to exercise its judgement in the process of applying the Group's accounting policies. The areas involving a higher degree of judgement or complexity, or areas where assumptions and estimates are significant to the consolidated financial statements are disclosed in Note 2.

1.4 Going concern

The consolidated financial statements have been prepared on a going concern basis as the Directors have concluded that the Group will continue to have access to sufficient funds in order to meet its obligations as they fall due for at least the foreseeable future as explained further in the Directors Report. The Group's current liabilities exceed current assets by 22,471 as at 31 December 2017. For mitigation factors, please, see Note 26.1.

1.5 Disclosure of impact of new and future accounting standards

a) Adoption of new and amended standards

In the preparation of these consolidated financial statements, the Group followed the same accounting policies and methods of computation as compared with those applied in the previous year, except for the adoption of new standards and interpretations and revision of the existing standards as of 1 January 2017. The Group has not early adopted any other standard, interpretation or amendment that has been issued but is not yet effective.

Although these new standards and amendments applied for the first time in 2017, they did not have a material impact on the annual consolidated financial statements of the Group.

b) New accounting pronouncements

A number of new and amended standards were not effective for the year ended 31 December 2017 and have not been applied in these consolidated financial statements.

* Subject to EU endorsement.

IFRS 9 Financial Instruments: Classification and Measurement

In July 2014, the IASB issued the final version of IFRS 9 Financial Instruments which reflects all phases of the financial instruments project and replaces IAS 39 Financial Instruments: Recognition and Measurement and all previous versions of IFRS 9. The standard introduces new requirements for classification and measurement, impairment, and hedge accounting. IFRS 9 is effective for annual periods beginning on or after 1 January 2018, with early application permitted. Retrospective application is required, but comparative information is not compulsory.

a) Classification

Loans as well as trade receivables are held to collect contractual cash flows and are expected to give rise to cash flows representing solely payments of principal and interest. The Group analysed the contractual cash flow characteristics of those instruments and concluded that they meet the criteria for amortised cost measurement under IFRS 9. Therefore, reclassification for these instruments is not required.

b) Impairment

IFRS 9 requires the Group to now use an expected credit loss model for its trade receivables measured at amortised cost and cash in banks, either on a 12-month or lifetime basis. The Group expects to apply the simplified approach and record lifetime expected losses on all trade receivables measured at amortised cost and cash in banks. Given the short-term nature of these assets, the Group considered these changes had insignificant impact.

IFRS 15 Revenue from Contracts with Customers

IFRS 15 was issued in May 2014 and establishes a new five-step model that will apply to revenue arising from contracts with customers. Under IFRS 15 revenue is recognised at an amount that reflects the consideration to which an entity expects to be entitled in exchange for transferring goods or services to a customer.

The principles in IFRS 15 provide a more structured approach to measuring and recognizing revenue. The new revenue standard is applicable to all entities and will supersede all current revenue recognition requirements under IFRS. Either a full or modified retrospective application is required for annual periods beginning on or after 1 January 2018 with early adoption permitted. Given the basic terms of revenue contracts, reliable customers and absence of significant finance component in sales, the Group preliminary assessed that the impact of IFRS 15 will not be significant. Final evaluation has not been completed yet.

IFRS 16 Leases

IFRS 16 was issued in January 2016 and it replaces IAS 17 Leases, IFRIC 4 Determining whether an Arrangement contains a Lease, SIC-15 Operating Leases - Incentives and SIC-27 Evaluating the Substance of Transactions Involving the Legal Form of a Lease. IFRS 16 sets out the principles for the recognition, measurement, presentation and disclosure of leases and requires lessees to account for all leases under a single on-balance sheet model similar to the accounting for finance leases under IAS 17.

IFRS 16 is effective for annual periods beginning on or after 1 January 2019. Early application is permitted, but not before an entity applies IFRS 15. A lessee can choose to apply the standard using either a full retrospective or a modified retrospective approach. The standard's transition provisions permit certain reliefs.

In 2018, the Group will continue to assess the potential effect of IFRS 16 on its financial statements.

From application of the other standards issued but not yet effective the Group expects no effect on its consolidated financial statements.

1.6 Basis of consolidation

The consolidated financial statements comprise the financial statements of the Group and its subsidiaries as at 31 December 2017. Control is achieved when the Group is exposed, or has rights, to variable returns from its involvement with the investee and has the ability to affect those returns through its power over the investee.

Specifically, the Group controls an investee if, and only if, the Group has:

· Power over the investee (i.e., existing rights that give it the current ability to direct the relevant activities of the investee);

· Exposure, or rights, to variable returns from its involvement with the investee;

· The ability to use its power over the investee to affect its returns.

Generally, there is a presumption that a majority of voting rights results in control. To support this presumption and when the Group has less than a majority of the voting or similar rights of an investee, the Group considers all relevant facts and circumstances in assessing whether it has power over an investee, including:

· The contractual arrangement(s) with the other vote holders of the investee;

· Rights arising from other contractual arrangements;

· The Group's voting rights and potential voting rights.

The Group re-assesses whether or not it controls an investee if facts and circumstances indicate that there are changes to one or more of the three elements of control. Consolidation of a subsidiary begins when the Group obtains control over the subsidiary and ceases when the Group loses control of the subsidiary. Assets, liabilities, income and expenses of a subsidiary acquired or disposed of during the year are included in the consolidated financial statements from the date the Group gains control until the date the Group ceases to control the subsidiary.

When necessary, adjustments are made to the financial statements of subsidiaries to bring their accounting policies into line with the Group's accounting policies. All intra-group assets and liabilities, equity, income, expenses and cash flows relating to transactions between members of the Group are eliminated in full on consolidation.

A change in the ownership interest of a subsidiary, without a loss of control, is accounted for as an equity transaction.

If the Group loses control over a subsidiary, it derecognises the related assets (including goodwill), liabilities and components of equity, while any resultant gain or loss is recognised in profit or loss. Any investment retained is recognised at fair value.

1.7 Acquisitions, asset purchases and disposals

Transactions involving the purchases of an individual field interest, or a group of field interests, that do not qualify as a business combination are treated as asset purchases, irrespective of whether the specific transactions involved the transfer of the field interests directly or the transfer of an incorporated entity. Accordingly, no goodwill or deferred tax gross up arises. The purchase consideration is allocated to the assets and liabilities purchased on an appropriate basis. Proceeds from the disposal are applied to the carrying amount of the specific intangible asset or development and production assets disposed of and any surplus is recorded as a gain on disposal in the statement of comprehensive income.

1.8 Business combinations

Business combinations are accounted for using the acquisition method. The cost of an acquisition is measured as the aggregate of the consideration transferred, which is measured at acquisition date fair value, and the amount of any non-controlling interests in the acquiree. For each business combination, the Group elects whether to measure the non-controlling interests in the acquiree at fair value or at the proportionate share of the acquiree's identifiable net assets. Acquisition-related costs are expensed as incurred and included in administrative expenses.

When the Group acquires a business, it assesses the financial assets and liabilities assumed for appropriate classification and designation in accordance with the contractual terms, economic circumstances and pertinent conditions as at the acquisition date. This includes the separation of embedded derivatives in host contracts by the acquiree.

Any contingent consideration to be transferred by the acquirer will be recognised at fair value at the acquisition date. Contingent consideration classified as an asset or liability that is a financial instrument and within the scope of IAS 39 Financial Instruments: Recognition and Measurement is measured at fair value with the changes in fair value recognised in the statement of profit or loss.

Goodwill is initially measured at cost being the excess of the aggregate of the consideration transferred and the amount recognised for non-controlling interests and any previous interest held over the net identifiable assets acquired and liabilities assumed. If the fair value of the net assets acquired is in excess of the aggregate consideration transferred, the Group re-assesses whether it has correctly identified all of the assets acquired and all of the liabilities assumed and reviews the procedures used to measure the amounts to be recognised at the acquisition date. If the reassessment still results in an excess of the fair value of net assets acquired over the aggregate consideration transferred, then the gain is recognised in profit or loss.

After initial recognition, goodwill is measured at cost less any accumulated impairment losses. For the purpose of impairment testing, goodwill acquired in a business combination is, from the acquisition date, allocated to each of the Group's cash-generating units that are expected to benefit from the combination, irrespective of whether other assets or liabilities of the acquiree are assigned to those units.

Where goodwill has been allocated to a cash-generating unit (CGU) and part of the operation within that unit is disposed of, the goodwill associated with the disposed operation is included in the carrying amount of the operation when determining the gain or loss on disposal. Goodwill disposed in these circumstances is measured based on the relative values of the disposed operation and the portion of the cash-generating unit retained.

1.9 Segment reporting

Segment reporting follows the Group's internal reporting structure.

Operating segments are defined as components of the Group where separate financial information is available and reported regularly to the chief operating decision maker ("CODM"), which is determined to be the Board of Directors of the Company. The Board of Directors decides how to allocate resources and assesses operational and financial performance using the information provided.

The CODM receives monthly IFRS-based financial information for the Group and its development and production entities. The Group has other entities that engage as either head office or in a corporate capacity, or as holding companies. Management has concluded that, due to the application of aggregation criteria, separate financial information for segments is not required. No geographic segmental information is presented, as all of the companies' operating activities are based in the Russian Federation.

Management has therefore determined that the operations of the Group comprise one operating segment and the Group operates in only one geographic area - the Russian Federation.

1.10 Foreign currency translation

a) Functional and presentation currency

The functional currency of the Group entities is the Russian ruble ("RUB"), the currency of the primary economic environment in which the Group operates.

The presentation currency is RUB, which the Board considers more representative for users of these consolidated financial statements to better assess the performance of the Group.

b) Transactions and balances

Transactions in foreign currencies are initially recorded by the Group's entities at their respective functional currency spot rates at the date the transaction first qualifies for recognition.

Monetary assets and liabilities denominated in foreign currencies are translated at the functional currency spot rates of exchange at the reporting date.

Differences arising on the settlement or translation of monetary items are recognised in profit or loss.

Non-monetary items that are measured in terms of historical cost in a foreign currency are translated using the exchange rates at the dates of the initial transactions.

c) Group companies

Loans between Group entities and related foreign exchange gains or losses are eliminated upon consolidation.

Any goodwill arising on the acquisition of a foreign operation and any fair value adjustments to the carrying amounts of assets and liabilities on the acquisition are treated as assets and liabilities of foreign operation and translated at the spot rate of exchange at the reporting date.

The period-end exchange rates and the average exchange rates for the respective reporting periods are indicated below.

1.11 Exploration and evaluation assets

The Company and its subsidiaries apply the successful efforts method of accounting for Exploration and Evaluation ("E&E") costs, in accordance with IFRS 6 Exploration for and Evaluation of Mineral Resources. Costs are accumulated on a field-by-field basis.

a) Drilling, seismic and other costs

Costs directly associated with an exploration well, including certain geological and geophysical costs, and exploration and property leasehold acquisition costs, are capitalised until the reserves are evaluated. If it is determined that a commercial discovery has not been achieved, these costs are charged to expense after the conclusion of appraisal activities. Exploration costs such as geological and geophysical that are not directly related to an exploration well are expensed as incurred.

Capital expenditure is recognised as property, plant and equipment or intangible assets in the financial statements in accordance with the nature of the expenditure and the stage of development of the associated field, i.e. exploration, development, or production. Once commercial reserves are found, exploration and evaluation assets are tested for impairment and transferred to development property, plant and equipment or intangible assets. No depreciation or amortisation is charged during the exploration and evaluation phase.

b) Sub-soil licences

Costs incurred prior to the award of oil and gas licences, concessions and other exploration rights are expensed in profit or loss. Costs incurred on the acquisition of a licence interest are initially capitalised on a licence by licence basis and are capitalised within exploration and evaluation assets and held un-depleted until the exploration phase of the licence is complete or commercial reserves have been discovered at which time the costs are transferred to development assets as part of property, plant and equipment - oil and gas assets.

1.12 Property, plant and equipment

a) Property, plant and equipment - oil and gas assets

Oil and gas assets are stated at cost less accumulated depletion or accumulated depreciation and, where relevant, impairment costs.

Expenditure on the construction, installation or completion of infrastructure facilities such as platforms and pipelines, as well as on the drilling of development wells into commercially proved reserves, is capitalised within property, plant and equipment. When development is completed on a specific field, it is transferred to producing assets within property, plant and equipment. No depreciation or amortisation is charged during the development phase.

Development and production assets are accumulated generally on a field by field basis and represent the cost of developing the commercial reserves discovered and bringing them into production, together with E&E expenditures incurred in finding commercial reserves and transferred from intangible E&E assets as described above. The cost of development and production assets also includes the cost of acquisitions and purchases of such assets, directly attributable overheads, any costs directly attributable to bringing the asset into operation, and the cost of recognising provisions for future restoration and decommissioning, if any.

Major facilities may be capitalised separately if they relate to more than one field or to the licence area as a whole. Subsequent expenditure is capitalised only if it either enhances the economic benefits of the development/production asset or replaces part of the existing development/ production asset. Any costs remaining associated with the part replaced are expensed. Directly attributed overheads are capitalised where they relate to specific exploration and development activities. 

i) Depletion

Oil and gas properties in production, including wells and directly related pipeline costs, are depreciated using the unit-of-production method. Sub-soil licences and other licences capitalised as part of oil and gas properties in production are amortised also using the unit-of-production method. Unit-of-production rates are based on proved reserves of the field concerned, which are oil, gas and other mineral reserves estimated to be recovered from existing facilities using current operating methods. The unit-of-production rate for the amortisation of field development costs takes into account expenditures incurred to date.

ii) Depreciation

Major oil and gas facilities that have a shorter useful life than the lifetime of the related fields are depreciated on a straight-line basis over the expected useful life of the facility. Depreciation of items of such assets is calculated using the straight-line method to allocate their cost to their residual values over their estimated useful lives:

The asset's residual values and useful lives are reviewed, and adjusted as appropriate, at the end of each reporting period.

b) Property, plant and equipment - other business and corporate assets

Property, plant and equipment are stated at cost less accumulated depreciation and impairment losses. The cost of an asset comprises its purchase price and any directly attributable costs of bringing asset to the working condition and to the location for its intended use. Subsequent costs are included in the asset's carrying amount or recognised as a separate asset, as appropriate, only when it is probable that future economic benefits associated with the item will flow to the Group and the cost of the item can be measured reliably. All other costs, such as repairs and maintenance are charged to the income statement during the financial period in which they are incurred.

The gain or loss arising from a retirement or disposal is determined as the difference between the sales proceeds and the carrying amount of the assets, and is recognised in the income statement.

Depreciation is provided on buildings and facilities, motor vehicles, office equipment and furniture at rates calculated to write off the cost, less estimated residual value, evenly over the asset's expected useful life.

For depreciation purposes, useful lives are estimated as follows:

1.13 Impairment of non-current assets

i) Impairment indicators

The Group assesses, at each reporting date, whether there is an indication that an asset may be impaired. If any indication exists, or when annual impairment testing for an asset is required, the Group estimates the asset's recoverable amount. An asset's recoverable amount is the higher of an asset's or CGU's fair value less costs of disposal and its value in use. The recoverable amount is determined for an individual asset, unless the asset does not generate cash inflows that are largely independent of those from other assets or groups of assets. When the carrying amount of an asset or CGU exceeds its recoverable amount, the asset is considered impaired and is written down to its recoverable amount.

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. In determining fair value less costs of disposal, recent market transactions are taken into account. If no such transactions can be identified, an appropriate valuation model is used. These calculations are corroborated by valuation multiples, quoted share prices for publicly traded companies or other available fair value indicators.

The Group bases its impairment calculation on detailed budgets and forecast calculations, which are prepared separately for each of the Group's CGUs to which the individual assets are allocated. These budgets and forecast calculations generally cover a period of five years. A long-term growth rate is calculated and applied to project future cash flows after the fifth year.

Impairment losses of continuing operations are recognised in the statement of profit or loss in expense categories consistent with the function of the impaired asset, except for properties previously revalued with the revaluation taken to OCI. For such properties, the impairment is recognised in OCI up to the amount of any previous revaluation.

For assets excluding goodwill, an assessment is made at each reporting date to determine whether there is an indication that previously recognised impairment losses no longer exist or have decreased. If such indication exists, the Group estimates the asset's or CGU's recoverable amount. A previously recognised impairment loss is reversed only if there has been a change in the assumptions used to determine the asset's recoverable amount since the last impairment loss was recognised. The reversal is limited so that the carrying amount of the asset does not exceed its recoverable amount or the carrying amount that would have been determined, net of depreciation, had no impairment loss been recognised for the asset in prior years. Such reversal is recognised in the statement of profit or loss unless the asset is carried at a revalued amount, in which case the reversal is treated as a revaluation increase.

ii) Calculation of recoverable amount

The recoverable amount of assets is the greater of their value in use and fair value less costs to sell. 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.

iii) Cash generating units

For an asset that does not generate cash inflows largely independent of those from other assets, the recoverable amount is determined for the cash generating unit to which the asset belongs. The Group's cash generating units are the smallest identifiable groups of assets that generate cash inflows that are largely independent of the cash inflows from other assets or groups of assets.

For the purposes of assessing impairment, exploration and evaluation assets subject to testing are grouped with existing cash generating units of production fields that are located in the same geographical region. For development and production assets the cash generating unit applied for impairment test purposes is generally the field. For shared infrastructure a number of field interests may be grouped together where surface infrastructure is used by several fields in order to process production for sale.

iv) Reversals of impairment

An impairment loss is reversed to the extent that the factors giving rise to the impairment charge are no longer prevalent. An impairment loss is reversed only to the extent that the asset's carrying amount does not exceed the carrying amount that would have been determined, net of depletion, depreciation or amortisation, if no impairment loss had been recognised.

Taxes on income in the interim periods are accrued using the tax rate that would be applicable to expected total annual profit or loss.

1.14 Inventories

Unsold natural gas and hydrocarbon liquids and sulphur in storage are stated at the lower of cost of production or net realisable value. Net realisable value is the estimated selling price in the ordinary course of business, less the estimated costs of completion and selling expenses.

Materials and supplies inventories include chemicals necessary for production activities and spare parts for the maintenance of production facilities. Materials and supplies inventories are recorded at cost and are carried at amounts which do not exceed the expected recoverable amount from use in the normal course of business. Cost of inventory is determined on a weighted average basis. Cost of finished goods comprises direct materials and, where applicable, direct labour plus attributable overheads based on a normal level of activity and other costs associated in bringing inventories to their present location and condition, but excludes borrowing costs.

1.15 Financial instruments

A financial instrument is any contract that gives rise to a financial asset of one entity and a financial liability or equity instrument of another entity. Financial assets and financial liabilities are recognised when, and only when, the Group becomes a party to the contractual provisions of the instrument. Financial assets and financial liabilities are initially measured at fair value. Transaction costs that are directly attributable to the acquisition or issue of financial assets and financial liabilities (other than financial assets and financial liabilities at fair value through profit or loss) are added to or deducted from the fair value of the financial assets or financial liabilities, as appropriate, on initial recognition. Transaction costs directly attributable to the acquisition of financial assets or financial liabilities at fair value through profit or loss are recognised immediately in the statement of comprehensive income. 

a) Financial assets

The Group classifies its financial assets into one of the following categories: financial assets at fair value through profit or loss and loans and receivables.

Regular purchases of financial assets are recognised on the trade date. Management determines the classification of its financial assets at initial recognition depending on the purpose for which the financial assets were acquired and, where allowed and appropriate, re-evaluates this designation at every reporting date. The accounting policies adopted for each category are:

Financial assets at fair value through profit or loss

Financial assets at fair value through profit or loss include financial assets held for trading and financial assets designated upon initial recognition at fair value through profit or loss. Financial assets are classified as held for trading if they are acquired for the purpose of selling in the near term, or if they are part of a portfolio of identified financial instruments that are managed together and for which there is evidence of a recent pattern of short-term profit-taking.

Financial assets may be designated at initial recognition at fair value through profit or loss if the following criteria are met:

· The designation eliminates or significantly reduces the inconsistent treatment that would otherwise arise from measuring the assets or recognising gains or losses on them on a different basis; or

· The assets are part of a group of financial assets which are managed and their performance is evaluated on a fair value basis, in accordance with a documented risk management strategy and information about the group of financial assets is provided internally on that basis to the key management personnel.

Subsequent to initial recognition, the financial assets included in this category are measured at fair value, with changes in fair value recognised in the statement of comprehensive income. Fair value is determined by reference to active market transactions or using a valuation technique where no active market exists. Fair value gains or losses do not include any dividend or interest earned on these financial assets. Dividend and interest income is recognised on an accruals basis.

Other receivables

Other receivables are non-derivative financial assets with fixed or determinable payments that are not quoted in an active market. They are initially measured at fair value and subsequently measured at amortised cost using the effective interest method, less any impairment losses. Amortised cost is calculated taking into account any discount or premium on acquisition and includes fees that are an integral part of the effective interest rate and transaction cost.

Impairment losses on other receivables are provided for when objective evidence is received that the Group will not be able to collect amounts due to it in accordance with the original terms of the receivables. The amount of the loss is measured as the difference between the asset's carrying amount and the present value of estimated future cash flows, excluding future credit losses that have not been incurred, discounted at the financial asset's original effective interest rate (i.e. the effective interest rate computed at initial recognition). The amount of the loss is recognised in the statement of comprehensive income for the period in which the impairment occurs.

Objective evidence of impairment of individual financial assets includes observable data that comes to the attention of the Group about one or more of the following loss events:

· Significant financial difficulty of the debtor;

· A breach of contract, such as default or delinquency in interest or principal payments;

· It becoming probable that the debtor will enter bankruptcy or other financial reorganisation; and

· Significant changes in the technological, market, economic or legal environment that have an adverse effect on the debtor.

Loss events in respect of a group of financial assets include observable data indicating that there is a measurable decrease in the estimated future cash flows from the group of financial assets. Such observable data includes but is not limited to adverse changes in the payment status of debtors in the group, and national or local economic conditions that correlate with defaults on the assets in the group.

If, in a subsequent period, the amount of the impairment loss decreases and the decrease can be related objectively to an event occurring after the impairment was recognised, the previously recognised impairment loss is reversed to the extent that it does not result in a carrying amount of the financial asset exceeding what the amortised cost would have been had the impairment not been recognised at the date the impairment is reversed.

The amount of the reversal is recognised in OCI in the period in which the reversal occurs.

b) Financial liabilities and equity

Financial liabilities and equity instruments issued by the Group are classified according to the substance of the contractual arrangements entered into and the definitions of a financial liability and an equity instrument. An equity instrument is any contract that evidences a residual interest in the assets of the Group after deducting all of its liabilities. The accounting policies adopted in respect of financial liabilities and equity instruments are set out below.

Other financial liabilities

Other financial liabilities include trade and other payables and are recognised initially at fair value and subsequently measured at amortised cost, using the effective interest method.

Equity instruments

Equity instruments issued by the Group are recorded at the proceeds received, net of direct issue costs.

c) Derecognition

Financial assets are derecognised when the rights to receive cash flows from the assets expire, or the financial assets are transferred and the Group has transferred substantially all the risks and rewards of ownership of the financial assets. On derecognition of a financial asset, the difference between the asset's carrying amount and the sum of the consideration received and the cumulative gain or loss that had been recognised directly in equity is recognised in the statement of comprehensive income. 

For financial liabilities, they are removed from the balance sheet when the obligation specified in the relevant contract is discharged, cancelled or expires. The difference between the carrying amount of the financial liability derecognised and the consideration paid is recognised in the statement of comprehensive income.

1.16 Cash and cash equivalents

Cash and short-term deposits in the statement of financial position comprise cash at banks and on hand and short-term deposits with a maturity of three months or less, which are subject to an insignificant risk of changes in value. For the purpose of the consolidated statement of cash flows, cash and cash equivalents consist of cash and short-term deposits, as defined above, net of outstanding bank overdrafts as they are considered an integral part of the Group's cash management.

1.17 Borrowings

After initial recognition, interest-bearing loans and borrowings are subsequently measured at amortised cost using the EIR method. Gains and losses are recognised in profit or loss when the liabilities are derecognised as well as through the EIR amortisation process. Amortised cost is calculated by taking into account any discount or premium on acquisition and fees or costs that are an integral part of the EIR. The EIR amortisation is included as finance costs in the statement of profit or loss.

1.18 Provisions

Provisions are recognised when the Group has a present obligation (legal or constructive) as a result of a past event, and it is probable that an outflow of economic benefits will be required to settle the obligation and a reliable estimate of the amount of the obligation can be made. Where the time value of money is material, provisions are stated at the present value of the expenditure expected to settle the obligation.

All provisions are reviewed at each reporting date and adjusted to reflect the current best estimate.

Where it is not probable that an outflow of economic benefits will be required, or the amount cannot be estimated reliably, the obligation is disclosed as a contingent liability, unless the probability of outflow of economic benefits is remote. Possible obligations, whose existence will only be confirmed by the occurrence or non-occurrence of one or more future uncertain events not wholly within the control of the Group are also disclosed as contingent liabilities unless the probability of outflow of economic benefits is remote.

A provision for decommissioning is made for the cost of decommissioning assets at the time when the obligation to decommission arises. Such provision represents the estimated discounted liability for costs which are expected to be incurred in removing production facilities and site restoration at the end of the producing life of each field. A corresponding item of property, plant and equipment is also created at an amount equal to the provision. This is subsequently depreciated as part of the capital costs of the production facilities. Any change in the present value of the estimated expenditure attributable to changes in the estimates of the cash flow or the current estimate of the discount rate used are reflected as an adjustment to the provision and the property, plant and equipment. The unwinding of the discount is recognised as a finance cost.

Provisions for environmental restoration, restructuring costs and legal claims are recognised when: the group has a present legal or constructive obligation as a result of past events; it is probable that an outflow of resources will be required to settle the obligation; and the amount has been reliably estimated. Restructuring provisions comprise lease termination penalties and employee termination payments. Provisions are not recognised for future operating losses.

Where there are a number of similar obligations, the likelihood that an outflow will be required in settlement is determined by considering the class of obligations as a whole. A provision is recognised even if the likelihood of an outflow with respect to any one item included in the same class of obligations may be small.

Provisions are measured at the present value of the expenditures expected to be required to settle the obligation using a pre-tax rate that reflects current market assessments of the time value of money and the risks specific to the obligation. The increase in the provision due to passage of time is recognised as interest expense.

1.19 Share capital, share premium and capital reserves

Ordinary shares are classified as equity. Share capital is determined using the nominal value of shares that have been issued. Any transaction costs associated with the issuing of shares are deducted from the share premium (net of any related income tax benefit) to the extent they are incremental costs directly attributable to the equity transaction. Any discount on the issue of ordinary shares is deducted from the share premium account.

The share premium is recognised on the difference between the par value of a share and its selling price.

The capital reserve brought forward arose on the disposal of all the subsidiaries to its former holding company (Crosby Capital Limited), reverse acquisition of Crosby Capital Limited and on a group reorganization during the years ended 31 December 2010, 31 December 2004 and 31 December 2000 respectively.

1.20 Revenue recognition

Revenue, which is the fair value of consideration received or receivable, is recognised when it is probable that economic benefits will flow to the Group and when the revenue can be measured reliably. Revenue is shown net of value added tax, returns, rebates and discounts and after eliminating sales within the Group. The following criteria must also be met before revenue is recognised:

i) Sale of goods

Revenue from the sale of oil, gas, and condensate is recognised when significant risks and rewards pass to the customer.

ii) Interest income

Interest income is recognised on a time-proportion basis using the effective interest method.

1.21 Mineral extraction tax

In the Russian Federation MET is payable on the extraction of hydrocarbons, including natural gas, crude oil and condensate, and is levied based on quantities of natural resources extracted multiplied by the applicable MET rate for the product and field in question. MET is a production based tax (as opposed to income) and is accrued as a tax on production and recorded within cost of sales.

1.22 Current and deferred income tax

The tax expense for the period comprises current and deferred tax. Tax is recognised in the statement of comprehensive income, except to the extent that it relates to items recognised in other comprehensive income or directly in equity. In this case the tax is also recognised in other comprehensive income or directly in equity, respectively.

The current income tax charge is calculated on the basis of the tax laws enacted or substantively enacted at the end of the reporting period in the countries where the Company's subsidiaries operate and generate taxable income. Management periodically evaluates positions taken in tax returns with respect to situations in which applicable tax regulation is subject to interpretation. It establishes provisions where appropriate on the basis of amounts expected to be paid to the tax authorities.

Deferred income tax is recognised, using the liability method, on temporary differences arising between the tax bases of assets and liabilities and their carrying amounts in the consolidated financial statements. However, deferred income tax is not accounted for if it arises from the initial recognition of an asset or liability in a transaction other than a business combination that at the time of the transaction affects neither accounting nor taxable profit or loss. Deferred income tax is determined using tax rates (and laws) that have been enacted or substantively enacted by the end of the reporting period and are expected to apply when the related deferred income tax asset is realised or the deferred income tax liability is settled.

Deferred income tax assets are recognised to the extent that it is probable that future taxable profit will be available against which the temporary differences can be utilised.

Deferred income tax assets and liabilities are offset when there is a legally enforceable right to offset current tax assets against current tax liabilities and when the deferred income tax assets and liabilities relate to income taxes levied by the same taxation authority on either the same taxable entity or different taxable entities where there is an intention to settle the balances on a net basis.

1.23 Employee benefits

a) Retirement benefit schemes

No pension contributions were payable in the year. The Group participated only in defined contribution pension schemes and paid contributions to independently administered funds on a mandatory or contractual basis. The assets of these schemes are held separately from those of the Group in independently administered funds. The retirement benefit schemes are generally funded by payments from employees and by the relevant company. The Group has no further payment obligations once the contributions have been paid. The contributions are recognised as an employee benefit expense on an accruals basis.

b) Share-based employee compensation

The Group operates equity-settled share-based compensation plans to remunerate its Directors and key management.

All services received in exchange for the grant of any share-based compensation are measured at their fair values. These are indirectly determined by reference to the fair value of the share options and warrants awarded. Their value is appraised at the grant date and excludes the impact of any non-market vesting conditions.

All share-based compensation is ultimately recognised as an expense in the statement of comprehensive income unless it qualifies for recognition as an asset, with a corresponding credit to the employee share-based compensation reserve in equity. If vesting periods or other vesting conditions apply, the expense is allocated over the vesting period, based on the best available estimate of the number of share options expected to vest. Non-market vesting conditions are included in assumptions about the number of options that are expected to become exercisable. Estimates are subsequently revised if there is any indication that the number of share options expected to vest differs from previous estimates. No adjustment to expense recognised in prior periods is made if fewer share options ultimately are exercised than vested.

Upon exercise of share options or warrants the proceeds received net of any directly attributable transaction costs up to the nominal value of the shares issued are allocated to share capital and the amount previously recognised in the employee share-based compensation reserve will be transferred out with any excess being recorded as share premium.

When the share options or warrants have vested and then lapsed, the amount previously recognised in the employee share-based compensation reserve is transferred to retained earnings or accumulated losses.

c) Bonus plans

The Group recognises a liability and an expense for bonuses where contractually obliged or where there is a past practice that has created a constructive obligation.

d) Social obligations

Wages, salaries, contributions to the Russian Federation state pension and social insurance funds, paid annual leave, sick leave and bonuses are accrued in the year in which the associated services are rendered by the employees of the Group.

e) Valuations of share options or warrants granted

Estimating fair value for share-based payment transactions requires determination of the most appropriate valuation model, which depends on the terms and conditions of the grant. This estimate also requires determination of the most appropriate inputs to the valuation model, including the expected life of the share option or appreciation right, volatility and dividend yield, and making assumptions about them. The fair value of share options or warrants granted was calculated using the Black-Scholes Pricing Model, which requires the input of highly subjective assumptions, including the volatility of the share price. Because changes in subjective input assumptions can materially affect the fair value estimate, in the opinion of the Directors of the Group the existing model will not always necessarily provide a reliable single measure of the fair value of the share options. Details of the inputs are set out in Note 19 to the financial statements.

2. Critical accounting estimates and judgements

The preparation of consolidated financial statements in conformity with IFRS requires management to make judgements, estimates and assumptions that affect the application of accounting policies and the reported amounts of assets, liabilities, income and expenses. Actual results may differ from these estimates.

Estimates and underlying assumptions are reviewed on an ongoing basis. Revisions to accounting estimates are recognised in the year in which the estimates are revised and in any future years affected. The estimates and assumptions that have a significant risk of causing a material adjustment to the carrying amounts of assets and liabilities within the next financial year are discussed below:

2.1 Income taxes

The Group is subject to income and other taxes. Significant judgement is required in determining the provision for income tax and other taxes due to the complexity of tax legislation of the Russian Federation. The taxation system in the Russian Federation continues to evolve and is characterised by frequent changes in legislation, as well as official pronouncements and court decisions which are sometimes contradictory and subject to varying interpretation by different tax authorities. Taxes are subject to review and investigation by a number of authorities which have the authority to impose severe fines, penalties and interest charges. A tax year remains open for review by the tax authorities during the three subsequent calendar years; however, under certain circumstances a tax year may remain open longer.

Deferred tax assets are recognised to the extent that it is probable for each subsidiary to generate enough taxable profits to utilise deferred income tax recognised. Significant management judgement is required to determine the amount of deferred tax assets recognised, based upon the likely timing and the level of future taxable profits. Management prepares cash-flow forecasts to support the recoverability of deferred tax assets. Cash flow models are based on a number of assumptions relating to oil prices, operating expenses, production volumes, etc. These assumptions are consistent with those used by independent reserve engineers. Management also takes into account uncertainties related to future activities of the subsidiaries and going concern considerations. When significant uncertainties exist, deferred tax losses are not recognised even if the recoverability of these is supported by cash flow forecasts. Refer to further details in Note 22.

2.2 Provision for decommissioning and environmental restoration

This provision is significantly affected by changes in technology, laws and regulations which may affect the actual cost of decommissioning and environmental restoration to be incurred at a future date. The estimate is also impacted by the discount rates used in the provisioning calculations. The discount rates used are the Russian government bond rates.

Under the current levels of enforcement of existing legislation, management believes there are no significant liabilities in addition to amounts which are already accrued and which would have a material adverse effect on the financial position of the Group.

The Group's exploration, development and production activities involve the use of wells, related equipment and operating sites. Generally, licences and other regulatory acts require that such assets be decommissioned upon the completion of production. According to these requirements, the Group is obliged to decommission wells, dismantle equipment, restore the sites and perform other related activities. The Group's estimates of these obligations are based on current regulatory or licence requirements, as well as actual dismantling and other related costs. These liabilities are measured by the Group using the present value of the estimated future costs of decommissioning of these assets. The discount rate is reviewed at each reporting date and reflects risk free rate. The Group adjusts specific cash flows for risk.

2.3 Impairment of assets

a) Exploration and evaluation

An impairment exercise will be performed at the end of the exploration and evaluation process.

When, at the end of the exploration and evaluation stage, commercial reserves are determined to exist in respect of a particular field, the Group performs an impairment test in relation to costs capitalised. Where reserves are determined in sufficient quantity to justify development, the associated assets are transferred to property, plant and equipment.

If no potentially commercial hydrocarbons are discovered, the exploration asset is written off through the statement of profit or loss and other comprehensive income as a dry hole. If extractable hydrocarbons are found and, subject to further appraisal activity (e.g., the drilling of additional wells), it is probable that they can be commercially developed, the costs continue to be carried as an intangible asset while sufficient/continued progress is made in assessing the commerciality of the hydrocarbons. Costs directly associated with appraisal activity undertaken to determine the size, characteristics and commercial potential of a reservoir following the initial discovery of hydrocarbons, including the costs of appraisal wells where hydrocarbons were not found, are initially capitalised as an intangible asset.

b) Development and production

When the fields enter the production phase, the recoverable amounts of cash-generating units and individual assets will be determined based on the higher of value-in-use calculations and fair values less costs to sell. These calculations will require the use of estimates and assumptions. It is reasonably possible that the oil price assumption may change which may then impact the estimated life of the field and may then require a material adjustment to the carrying value of long-term assets.

The Group monitors internal and external indicators of impairment relating to its tangible and intangible assets. There were no such indicators of possible impairment identified during the reporting years covered by these consolidated financial statements.

2.4 Evaluation of reserves and resources

Estimates of proved reserves are used in determining the depletion and amortization charge for the period and assessing whether any impairment charge or reversal of impairment is required for development and producing assets. As of 31 December 2017 and 2016 proved reserves were estimated by reference to an independent international oil and gas engineering firm report dated 22 May 2014, by reference to available geological and engineering data, and only include volumes for which access to market is assured with reasonable certainty.

When the fields enter the development and production phase, estimates of reserves are inherently imprecise, require the application of judgments and are subject to regular revision, either upward or downward, based on new information such as from the drilling of additional wells and changes in economic factors, including product prices, contract terms or development plans. Changes to the Group's estimates of proved reserves affect prospectively the amounts of the depletion and amortization charge, decommissioning assets and provisions where changes in reserve estimates cause the estimated useful lives of assets to be revised.

Depletion is provided for based on the production profile on a field by field basis, which may exceed the existing licence period. Licence extensions are generally awarded by the licence authorities in Russia as a matter of course, provided that production plans demonstrate that additional time is required to economically produce at the field and that the development and production requirements of the initial licence grant have been met.

2.5 Sub-soil licences

The Group is subject to periodic reviews of its activities by governmental authorities in Russia with respect to the requirements of its sub-soil licences, and seeks amendments to the licences when supported by the results of ongoing exploration and development activities. The requirements under the licences are subject to interpretation and enforcement policies of the relevant authorities. In management's opinion, as of 31 December 2017, there are no non-compliance issues that will have an adverse effect on the financial position or operating results of the Group.

3. Determination of fair value

Fair values have been determined for measurement and/or disclosure purposes based on the following methods. When applicable, further information about the assumptions made in determining fair values is disclosed in the notes specific to that asset or liability.

3.1 Other receivables

The fair value of other receivables is estimated as the present value of future cash flows, discounted at the market rate of interest at the reporting date. This fair value is determined for disclosure purposes.

3.2 Non-derivative financial liabilities

Fair value, which is determined for disclosure purposes, is calculated based on the present value of future principal and interest cash flows, discounted at the market rate of interest at the reporting date. Fair value of the non-derivative financial assets is disclosed in Note 3.3 to the financial statements.

3.3 Assets and liabilities not measured at fair value but for which fair value is disclosed

Fair values analysed by level in the fair value hierarchy of assets and liabilities of the Group not measured at fair value are as follows:

The fair value of borrowings and other non-current payables is based on cash flows discounted using a market rate of 9.34% (2016: 11.93%). The fair values of borrowings and other non-current payables are within level 2 of the fair value hierarchy. The fair value of trade and other receivables is within level 3 hierarchy.

4. Revenue

The Group's operations comprise one class of business being oil and gas exploration, development and production and all revenues are from one geographic region, the Saratov Region in the Russian Federation. Companies incorporated outside of Russia provide support to the operations in Russia.

Revenue is primarily from the sale of three products:

All gas sales are made to one customer, Gazprom Mezhregiongaz Saratov LLC, under a long-term contract effective until 31 December 2020 with terms reviewed annually. Condensate and oil are sold to local buyers. The sales of all products are denominated in RUB.

5. Cost of sales

6. Operating, administrative and selling expenses

7. Salaries and other employee benefits

Salaries and other employee benefits are included in other cost of sales and operating, administrative and selling expenses.

Average monthly number of employees for the year (including executive directors):

8. Other income and expenses

9. Finance income and finance costs

10. Income tax benefit/(expense)

The tax charge for the year comprises:

Reconciliation between expected and actual taxation charge is provided below.

The Group's income was subject to tax at the following tax rates:

The Group is subject to Cayman income tax, otherwise the majority of the Group's operations are located in the Russian Federation. Thus 20% tax rate is used for theoretical tax charge calculations.

11. Exploration and evaluation assets

Аdditions during 2017 are mostly represented by seismic works at the North Mokrousovskoye field (during 2016: exploration and production licence acquisition at the West Koltogor oil field).

In management's opinion, as at 31 December 2017 there were no non-compliance issues in respect of the licences that would have an adverse effect on the financial position or the operating results of the Group.

Impairment

In 2017 the Group revised its investment strategy with a primary focus on exploration and further development of the Deep Devonian structure on the Bortovoy Licence. As a result, the forecasted amount of investments in the development of the Koltogor Licences cannot be confirmed. Accordingly, the probability of the Koltogor Licences' development becomes uncertain. The Group recognised an impairment loss of the total book value of exploration and evaluation assets of the Koltogor Licences as of 31 December 2017.

12. Property, plant and equipment

13. Inventories

Materials and supplies mainly comprised liquid feedstock and maintenance parts.

14. Trade and other receivables and other current non-financial assets

As of 31 December 2017 trade and other receivables in the amount 152,574 (31 December 2016: 172,294) were neither past due, nor impaired. As of 31 December 2017 trade and other receivables in the amount of 916 (31 December 2016: 0) were past due and impaired.

Prepayments are advance payments for services to be rendered within the next twelve months.

Current VAT receivable is expected to be recovered within the next twelve months.

15. Cash and cash equivalents

Cash and cash equivalents consist of cash at bank and the majority of cash held is denominated in RUB.

The Group's exposure to credit risk related to cash and cash equivalents are disclosed in Note 27.

16. Share capital

17. Dividends

In accordance with the relevant legislation applicable to the Group, the Group's distributable reserves are limited to the balance of retained earnings as recorded in the Company's statutory financial statements prepared in accordance with International Financial Reporting Standards. No dividends were declared or paid in 2017 and 2016.

18. Other taxes payable

19. Earnings per share

Basic earnings per share is calculated by dividing the profit attributable to owners of the Company by the weighted average number of ordinary shares in issue during the year.

Diluted earnings per share is calculated by adjusting the weighted average number of ordinary shares outstanding to assume conversion of all dilutive potential ordinary shares. During the year ended 31 December 2017 share options had an antidilutive effect on the loss per share. During the year ended 31 December 2016 share options had a dilutive effect on the earnings per share.

20. Share-based payments

20.1 Share options

At 31 December 2017, the Company had a total of 202,500 outstanding share options (31 December 2016: 1,952,500).

Options which are lapsed or are cancelled prior to their exercise date are deleted from the register of outstanding options and are available for re-use.

No share options were granted during the year ended 31 December 2017.

20.2 Initial share options

The Company adopted an employee Share Option Scheme on 4 March 2005 (the "Share Option Scheme") in order to incentivise key management and staff at that time. The following share options were granted to former employees and directors of the Company under the Initial Share Option Scheme adopted on 4 March 2005 ("Initial Share Options") and are still in existence:

Share options granted under the Initial Share Option Scheme were exercisable as follows:

· The first 30% of the options between the first and tenth anniversary of the grant date;

· The next 30% of the options between the second and tenth anniversary of the grant date; and

· The remaining options between the third and tenth anniversary of the grant date.

Equity-settled share-based payments are measured at fair value (excluding the effect of non market-based vesting conditions) as determined through use of the binomial option pricing model, at the grant date. The fair value determined at the grant date of the equity-settled share-based payments is expensed on a straight-line basis over the vesting period, based on the Company's estimate of shares that will eventually vest.

The binomial option pricing model is applied to the granting of share options in respect of calculating the fair values. Key inputs to the model are as follows:

Volatility has been based on the historical trading performance of the Company and comparable companies. The risk free rate has been determined based on 10-year government bonds.

20.3 Directors share options

Share options granted to certain existing Directors of the Company on 31 October 2012 ("Directors Share Options") were exercisable at any time between the commencement of the option period and third anniversary of the grant date. Share options granted under this scheme were as follows:

During 2014 the exercisable period of the remaining options was extended from 30 October 2015 to 30 October 2017. As of 31 December 2017 all Directors Share options have expired.

The Black-Scholes formula is the option pricing model applied to the grant of share options in respect of calculating the fair values. Key inputs to the model are as follows:

Volatility has been based on the Company's trading performance from 1 January 2011. The risk free rate has been determined based on 5-year government bonds.

21. Borrowings

In 2014, the Group entered into non-revolving credit facility agreement with Sberbank of Russia OJSC with a maximum facility amount of 2,400,000. Contractual currency is RUB. The facility was drawn down in full in 2014. The maturity date is 30 April 2021, being the 7-year anniversary of the facility entered into. The Group is obliged to repay the principal amount of the loan in 24 tranches commencing on 11 May 2015 and on a quarterly basis from then on with a final repayment tranche payable on the maturity date. The interest rate is fixed and contracted as 10.98% per annum. In October 2017 the Group concluded additional agreement, where the interest rate was resettled as 10.73% per annum. Sberbank may unilaterally amend the interest rate in the event of increases in the refinancing rate of the Central Bank of Russia. The Group paid an upfront commission on the facility of 1% of the facility amount (24,000) and there is a drawdown charge of 0.25% per year on the balance of the facility not drawn by the Group within the established timeframe. The Group has the option to prepay the loan in whole or in part at any time, subject to the payment of a fee. The Group provided certain warranties and representations to Sberbank in the agreement. The agreement contains certain loan covenants and events of default which are customary for a facility of this type. The Group was in compliance with all covenants as of 31 December 2017 and 31 December 2016. The loan is secured by the Group, such security being granted pursuant to various pledge and mortgage deeds entered into by the Group on or about the date of the Sberbank Facility. The carrying value of property, plant and equipment pledged as of 31 December 2017 amounted to 2,775,473 (31 December 2016: 2,901,916).

The outstanding principal amount of the facility as of 31 December 2017 was 1,560,000 (31 December 2016: 1,860,000). The credit facility debt is measured at amortised cost, using the effective interest method.

Additionally the Group entered into 100,000 revolving loan facility on 13 December 2017. The interest is 10,5% for disbursed amount and 0,5% for remaining part of the limit. The maturity date is 12 December 2018. There were no drawings in 2017.

22. Decommissioning and environmental restoration provision

The decommissioning and environmental restoration provision represents the net present value of the estimated future obligations for abandonment and site restoration costs which are expected to be incurred at the end of the production lives of the gas and oil fields which is estimated to be within 20 years.

This provision has been created based on the Group's internal estimates. Assumptions based on the current economic environment have been made which the directors believe are a reasonable basis upon which to estimate the future liability. These estimates are reviewed regularly to take into account any material changes to the assumptions. However, actual decommissioning costs will ultimately depend upon future market prices for the necessary dismantlement works required, which will reflect market conditions at the relevant time. Furthermore, the timing is likely to depend on when the fields cease to produce at economically viable rates. This in turn will depend upon future oil prices and future operating costs, which are inherently uncertain.

The provision reflects two liabilities: one is to dismantle the property, plant and equipment assets and the other is to restore the environment. The decommissioning part of the provision is reversed when an oil well is abandoned and corresponding capitalised costs are expensed. The environmental part of the provision is reversed when the expenses on restoration are actually incurred.

The provision is reversed when the corresponding capitalised costs directly attributable to an exploration and evaluation asset are expensed as it is determined that a commercial discovery has not been achieved and the restoration of the corresponding environment has been completed.

The Group reviews the application of inflation rates used for the provision estimation each half-year end. The inflation rate used in the estimation of the provision as of 31 December 2017 was 3.77% in 2017, decreasing to 3.64% in 2036 (as of 31 December 2016: 5.8% in 2017, decreasing to 4.0% in 2036). The discount rates used to determine the decommissioning and environmental restoration provision are based on Russian government bond rates. As of 31 December 2017 discount rate varies from 7.62% to 7.79% (as of 31 December 2016: from 8.53% to 8.57%) depending on expected period of abandonment and site restoration for each gas and oil fields.

23. Deferred tax liabilities

Movements in temporary differences during the year:

Deferred income tax assets are not fully recognised for impairment of exploration and evaluation assets and tax losses mainly carried forward for SibGeCo to the extent that the utilisation of the related tax benefit through future taxable profits is not probable. The Group has not recognised deferred income tax assets of 591,346 (2016: 482,631) The Group has tax losses that are available indefinitely for offsetting against future taxable profits of the companies in which the losses arose.

Management assessed that recognised deferred tax assets will be fully offset against future taxable profits in 2020-2026.

24. Trade and other payables