Petroneft Resources Plc

Environmental & Social Information • Dec 21, 2021

National Storage Mechanism | Additional information

RNS Number : 2743W

Petroneft Resources PLC

21 December 2021

PetroNeft Resources plc

21st December 2021

THIS ANNOUNCEMENT CONTAINS INSIDE INFORMATION

PetroNeft Resources plc ('PetroNeft' or 'the Company')

2021 RESERVES & RESOURCE AUDIT

PetroNeft (AIM: PTR) an oil and gas exploration and production company, operating in the Tomsk Oblast, Russian Federation and 90% owner and operator of Licence 67 and 50% owner and operator of Licence 61 is pleased to provide the results of the reserves and resource audit, the first undertaken since 2016 for Licence 61, and 2011 for Licence 67.

Highlights

·    Miller & Lents (M&L), an independent oil and gas consulting firm, have completed the 2021 Reserves & Resource audit for both Licences 61 and 67, link available at: http://petroneft.com/investor-relations/reserve-reports/ This is the first review of reserves and resources in five years on Licence 61 and a decade for Licence 67.

·    Updated 2P reserves of 48.655 Mbbls and a 2P NPV10 valuation across Licences 61 and 67 of $522.2M net to PTR

All figures in Mbbls	Gross						Net Attributable
Asset Name	Proved	Proved &		Proved			Proved	Proved &	Proved
	Probable		Probable &			Probable	Probable &
			Possible				Possible
Licence 67	4.780	27.214		79.646			4.302	24.493	71.681
Licence 61	24.345	48.325		70.950			12.173	24.163	35.475
Total =	29.125	75.539		150.596			16.475	48.655	107.156
NPV10 $(US)M	Gross				Net Attributable
Asset Name	Proved		Proved &		Proved	Proved &
	Probable		Probable
Licence 67	50.186		281.895		45.167	253.706
Licence 61	266.302		536.998		133.151	268.499
Total =	316.488		818.893		178.318	522.205

·    Additional 3C Net contingent resource - 23.74 Mbbls

All figures in Mbbls	Gross			Net Attributable
Asset Name	1C	2C	3C	1C	2C	3C
Licence 67	0.566	3.387	24.512	0.509	3.048	22.061
Licence 61	0.499	1.471	3.369	0.250	0.736	1.685
Total =	1.065	4.858	27.881	0.759	3.784	23.745

·    Significant low risk prospective resource estimate for Licence 61 - Emtorskaya prospect, Gross Pmean 96.19 Mbbls with a geological Chance of Success of 49.7%, and Gross P10 upside of 253.35 Mbbls

·    The M&L report underlines the importance and value of License 67 for the Company's future, with the 2P and 3P gross reserves largely driven by the newly producing Cheremshanskoye field and further upside now recognised, supporting the Company's new strategy, and added forward focus on License 67

M&L has completed its assessment of the Group's petroleum reserves and resources with an effective date of 30th July 2021, in accordance with the standards of the Petroleum Resources Management System, prepared by the Oil and Gas Reserves Committee of the Society of Petroleum Engineers (SPE-PRMS). This is the first reserves and resource audit since Ryder Scott completed their assessment in 2016 for Licence 61 and 2011 for Licence 67.

The following is a comparison between the legacy audits carried out by Ryder Scott and the current Miller & Lents report. Such a comparison is partly complicated by updates to the PRMS standards, which have impacted the categorisation of the Emtorskaya prospect in Licence 61.

Table 1: Net reserves comparison between legacy (Ryder Scott) and 2021 (Miller & Lents) audits

All figures in Mbbls	Ryder Scott 2011/16			Miller & Lents 2021
Asset Name	Proved	Proved &	Proved	Proved	Proved &	Proved
	Probable	Probable &	Probable	Probable &
		Possible		Possible
Licence 67	1.500	14.000	17.400	4.302	24.493	71.681
Licence 61	14.170	49.390	86.810	12.173	24.163	35.475
Total =	15.670	63.390	104.210	16.475	48.655	107.156

Miller and Lents have also estimated additional net additional Contingent resource (3C) of 23.74 Mbbls (22.06 Mbbls in Licence 67 and 1.68 Mbbls in Licence 61) and net Pmean prospective resources for the Emtorskaya prospect of 48.09 Mbbls (Gross 96.18 Mbbls with a 49.7% geological chance of success).

In Table 2 below, the 2P NPV10 has increased significantly from $255.716M in 2011/16 to $522.21M as of 30th June 2021. The increased valuation is mainly a reflection of the materially improved long term oil pricing environment both internationally and domestically within Russia since the last report. The total valuation uplift is further increased by the recent acquisition of an additional 40% interest in Licence 67 in 2021.

Table 2: Discounted cashflow (NPV10) comparison between legacy (Ryder Scott) and 2021 (Miller & Lents) audits

Net NPV10 $(US)M	Ryder Scott 2011/16		Miller & Lents 2021
Asset Name	Proved	Proved &	Proved	Proved &
	Probable	Probable
Licence 67	8.590	76.642	45.167	253.706
Licence 61	55.409	179.074	133.151	268.499
Total =	63.999	255.716	178.318	522.205
Note: Ryder Scott L67 at 50%, Miller & Lents L67 at 90%

While full copies of the actual reserve reports, which are by operational unit on a gross and net attributable basis, can be downloaded by clicking on the following link  http://petroneft.com/investor-relations/reserve-reports/ , below is a management summary of the audit results.

David Sturt, CEO PetroNeft commented:

'We are delighted to be able to finally publish the results from our recent reserves and resource audit.

This has been a painstaking interactive process and we are pleased to have engaged Miller & Lents due to their depth of expertise and considerable experience of working with significant Russian oil operators, some with assets near our licenses and fields that are likely analogous to ours.

We feel the audit results fully supports our on-going strategy, with the Cheremshanskoye field on License 67 providing the most exciting near-term upside for our continued growth, reflected in the strong reserves numbers, which are all new and not reported at all in the last reserves audit.

On License 61, it is satisfying to see the exciting upside and running room potential of our northern hub, particularly at Emtorskaya, beginning to show through numerically. An extensive inventory of reserves remains at our other License 61 fields. Whilst comparison with the 2016 report is not straightforward due to the evolution of assessment methodology which has become more rigorous in the intervening years of production, we are satisfied that the latest audit gives a suitably robust view of our reserve base and wish to thank Miller & Lents for their thoroughness and professionalism. 

The NPV10 valuation of our 2P reserves of over $520M is a clear indicator of our material value proposition, and we will continue to focus on building our production and cashflow to deliver the underlying values of our assets to our shareholders.'

Licence 67

PTR own and operate a 90% interest in the licence. The last reserves audit was carried out by Ryder Scott from existing legacy data in 2011, just after the award of the licence. Since then, the C-3 and C-4 wells on the Cheremshanskoye field and the L-2a well on the Ledovoye field have been drilled. Due to improved oil prices and cost optimisation initiatives, the 2P NPV10 per barrel has increased from approximately $3.50/bbl in 2011 to approximately $10.36/bbl in 2021.

Table 3: Licence 67 - Net Reserves and Cash flow value (NPV10), as of 30th June 2021

All reserve figures in Mbbls		Gross			Net Attributable
Licence 67	Reservoir	Proved	Proved &	Proved	Proved	Proved &	Proved
Fields		Probable	Probable &	Probable	Probable &
			Possible		Possible
Cheremshanskoye	U. Jurassic	4.556	22.900	34.467	4.100	20.610	31.020
	L. Jurassic	0.067	0.244	17.589	0.060	0.220	15.830
Ledovoye	U. Jurassic	0.156	4.067	27.600	0.140	3.660	24.840
Total Reserve =		4.778	27.211	79.656	4.300	24.490	71.690
Total NPV 10 $M=		50.189	281.900		45.170	253.710
NPV10 $/bbl =		10.50	10.36		10.50	10.36

Cheremshanskoye Field

There were no reserves calculated for this field by Ryder Scott in 2011. Since the last audit the C-3 and C-4 wells have been successfully drilled with the C-4 well currently producing.

The results demonstrate sizeable and well-defined reserves in two reservoirs (J1 ad J14) of the main Upper Jurassic zone, currently producing in the C-4 well. In addition, recognition is also made of the upside potential within the Lower Jurassic Tyumen formation with 15.83 Mbbls 3P net reserves, albeit with very modest 1P and 2P numbers at this early stage. The Tyumen formation is an economically attractive target as any production qualifies for a 20% reduction in the Mineral Extraction Tax.

Ledovoye Field

The field was last audited in 2011 soon after the licence award and before the acquisition of the 3D seismic data with a net 2P reserve of 14.0 Mbbls. Since then, the L2a well was drilled in 2012, which encountered oil but with a higher Oil Water Contact. This created uncertainty about the precise location of the Oil Water Contact, which has led to a significant portion of the 2P reserves now being moved to 3P with the 2P net reserve reduced from 14Mbbls in 2011 to the current 3.66Mbbls

Following the successful re-entry of the L-2a well earlier this year and the recovery of oil to surface on test, we are evaluating forward options for this field.

Licence 61

PTR own a 50% operated interest in the licence which was last audited by Ryder Scott in 2016.  The NPV10 per barrel has increased from approximately $3.50/bbl in 2016 to over $11.00/bbl on a 2P basis.

Table 4: Licence 61 - Net Reserves and Cash flow value (NPV10), as of 30th June 2021

All reserve figures in Mbbls		Gross			Net Attributable
Licence 61	Reservoir	Proved	Proved &	Proved	Proved	Proved &	Proved
Fields		Probable	Probable &	Probable	Probable &
			Possible		Possible
Lineynoye incl. west	U. Jurassic	7.380	16.280	16.920	3.690	8.140	8.460
Arbuzovskoye	U. Jurassic	5.060	6.180	7.800	2.530	3.090	3.900
Sibkrayevskoye	U. Jurassic	11.700	24.160	42.520	5.850	12.080	21.260
Tungolskoye	U. Jurassic	0.180	1.560	3.480	0.090	0.780	1.740
Kondrashevskoye	U. Jurassic	0.020	0.160	0.240	0.010	0.080	0.120
Total Reserve =		24.340	48.340	70.960	12.170	24.170	35.480
Total NPV 10 $M=		266.300	537.000		133.150	268.500
NPV10 $/bbl =		10.94	11.11		10.94	11.11

Lineynoye & West Lineynoye Field

There is a reduction of 2P reserves on a net basis of 4Mbbls, this is due to a more rigorous well log interpretation reducing overall net pay. Recent engineering studies based on historical production (material balance calculations) provided a degree of verification of the new volumes calculated.

This field cluster is a key producing asset of the Company. The production wells at Pad 1 continue to perform well, with three producing over 700,000 bbls and two more over 300,000 bbls cumulative production to date. The recent re-frac of the L-115 well has proven highly successful, with additional wells planned to be fracked this winter (Q1 2022).

Sibkrayevskoye Field

The unsuccessful drilling of two appraisal / development wells (S-374 and S-375) in 2016 and 2017 has resulted in a significant reduction  of 2P reserves at this field compared to the 2016 report, with the southern extension of the field being written off.

Despite this, management remains very confident that this field will continue to provide an engine room for production growth and are particularly enthusiastic regarding last year's frac of the S-373 well having added more than 500 bopd post frac. While the field still has a substantial reserve base and future upside, management focus will be on the further development of the frac programme, which is expected to provide a continuing and growing revenue stream.  The earlier unsuccessful drilling results have confirmed management's view of the pitfalls of drilling certain development wells, prior to 3D seismic and therefore no further drilling is anticipated to take place prior to 3D seismic.

Arbuzovskoye Field

There has been a small 0.36 Mbbls net reduction in 2P reserve, but we are pleased to see a 1.6Mbbls net increase in 1P reserves due to the drilling of the horizontal wells at PAD 2 in 2016.

The performance of these two horizontal wells has been excellent, with the A-214 Hz well recovering 750,000 bbls and the A-215 Hz well recovering almost 400,000 bbls.

Tungolskoye Field

There has been a reduction of 2Mbbls (net) of 2P reserves due to the poor performance of the wells drilled in 2015 when four horizontal and four vertical wells were drilled. Initial rates on the horizontal wells were very encouraging with rates over 500 bopd but declined rapidly. As reported earlier, the field was suspended in early 2019 due to low flow rates leading to non-commercial production.  There are plans to re-enter the T-501 horizontal well during this coming winter season, and if successful, the program could expand. Upon success, we would expect reserve numbers to increase at the next reserve audit.

Emtorskaya Prospect

The Emtorskaya prospect sits on the northern margin of the licence up dip and between the Lineynoye field to the south and the Sibkrayevskoye field to the east. This prospect provides material risked upside for License 61.

Table 5: Licence 61 - Gross Unrisked Prospective Resources (M&L), as of 30th June 2021

Prospect	Gross				Net Attributable
P90	P50	Pmean	P10	P90	P50	Pmean	P10
Mbbls	Mbbls	Mbbls	Mbbls	Mbbls	Mbbls	Mbbls	Mbbls
Emtorskaya	10.50	55.52	96.18	253.35	5.25	27.76	48.09	126.68
Geological Chance of Success = 49.7%

The prospect was also evaluated in 2016 by Ryder Scott, but due to changes in assessment methodology associated with reserve audit regulations, direct comparison is not straightforward.  PTR believes the 2016 P3 figure of 46.78 Mbbls as not fully reflecting the more robust upside seen with additional in-house integrated evaluation of legacy wells in the vicinity and newer 2D seismic data.

M&L estimated the (gross) Pmean of 96.18 Mbbls with an estimated geological chance of success of 49.7% which PTR believes is a more accurate reflection of the potential value of the prospect to the Company.

In 2016, the Company also had 11 prospects in the southern part of the licence audited by Ryder Scott as potential prospective resources. This portfolio of dependent prospects presents future significant upside unrisked gross potential of ca.287Mbbls.  However, as very little new information is available on these prospects since the last audit, combined with the operational focus of the value creation being around existing fields and the northern hub, a decision was taken to exclude this resource in the current audit report.

For further information, contact:

David Sturt, CEO, PetroNeft Resources plc	+44 7903 869 608
John Frain / Ciara O'Mongain, Davy (NOMAD and Joint Broker)	+353 1 679 6363
Joe Heron / Douglas Keatinge, Murray Consultants	+353 1 498 0300

Notes and Glossary

These assessments are made in accordance with the standards defined in the Petroleum Resources Management System (Revised June 2018) jointly sponsored by SPE, WPC, AAPG, SPEE, SEG, SPWLA, and EAGE.

The information contained in this announcement has been reviewed and verified by Mr. David Sturt, Chief Executive Officer and Executive Director of PetroNeft, for the purposes of the Guidance Note for Mining and Oil & Gas Companies issued by the London Stock Exchange in June 2009. Mr. Sturt holds a B.Sc. Degree in Earth Sciences from Kingston University and an MSc. in Exploration Geophysics from The University of Leeds. He is a member of the Petroleum Exploration Society Great Britain and has over 35 years' experience in oil and gas exploration and development.

1P	Proved Reserves, those quantities of petroleum, which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be commercially recoverable, from a given date forward, from known reservoirs and under defined economic conditions, operating methods, and government regulations.
2P	Proved + Probable Reserves, those additional Reserves which analysis of geoscience and engineering data indicate are less likely to be recovered than Proved Reserves but more certain to be recovered than Possible Reserves. It is equally likely that actual remaining quantities recovered will be greater than or less than the sum of the estimated Proved plus Probable Reserves
3P	Proved + Probable + Possible Reserves, those additional reserves which analysis of geoscience and engineering data suggest are less likely to be recoverable than Probable Reserves.
$M	US $ Million
NPV10	Net Present Value discounting at 10%.
P10 / P50 / P90 / Pmean	A probability methodology used to describe the size of the Reserves in a Field or resources in a prospect.
PRMS	Petroleum Resource Management System of reserve and resource classification under the Society of Petroleum Engineers (PRMS-SPE)
U. Jurassic	Upper Jurassic
L. Jurassic	Lower Jurassic
3C	Contingent Resource category 3 (PRMS-SPE)
bbl	Barrel
Mbbls	Millions of barrels
3D	Three Dimensional
Hz	Horizontal

This announcement contains inside information as defined in Article 7 of the Market Abuse Regulation and is disclosed in accordance with the Issuer's obligations under Article 17 of the Market Abuse Regulations

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

RNS may use your IP address to confirm compliance with the terms and conditions, to analyse how you engage with the information contained in this communication, and to share such analysis on an anonymised basis with others as part of our commercial services. For further information about how RNS and the London Stock Exchange use the personal data you provide us, please see our Privacy Policy.

END

MSCEADAEADEFFAA