Saturn Oil & Gas Inc. Announces 62.9 Million BOE of Reserves and Proved Developed Producing Net Asset Value (NPV10 BT) Increases 54% to $6.92

per Fully Diluted Share

CALGARY, ALBERTA – March 14, 2023 – Saturn Oil & Gas Inc. (TSXV: SOIL) (FSE: SMKA)(OTCQX: OILSF) (“Saturn” or the

“Company”) is pleased to announce the results of the independent reserves evaluation of the Company’s crude oil and natural gas assets, dated February 21 2023 and effective December 31, 2022, in compliance with National Instrument 51-101 – Standards of Disclosure for Oil and Gas Activities (“NI 51-101”) and in accordance with the Canadian Oil and Gas Evaluation Handbook (the “Reserve Report”). The Reserve Report does not include the acquisition of Ridgeback Resources Inc. (“Ridgeback”) which occurred after year end 2022. The December 31, 2022 year-end reserves of Ridgeback are also summarized below.

Reserves Evaluation Highlights

The Company’s Reserve Report, prepared by Ryder Scott Company-Canada (“Ryder Scott”), evaluated the Company’s assets in Southeast Saskatchewan (the “Oxbow Asset”) and in West Central Saskatchewan (the “Viking Asset”) and is highlighted by:

• 9 million BOE of Total Proved + Probable (“TP+P”) reserves, representing a 24% year over year increase.
• $791.5 million net present value of future net revenue of the Proved Developed Producing (“PDP”) reserves discounted at 10% (“NPV10%”), in addition to $883.7 million of PDP NPV10% of Ridgeback reserves, as further described below.
• 452 booked gross drilling locations, 64% located in the Oxbow Asset and 36% in the Viking
• High oil weighting with TP+P reserves comprise 95% light & medium oil and natural gas liquids (“NGL”).
• Long reserve life index (“RLI”) of 6 years for PDP reserves and 13.8 years for TP+P¹ reserves.
• Two year average TP+P F&D costs of $13.93 /boe (4.6x recycle ratio)¹.
• Two year average TP+P FD&A costs of $12.99 /boe (4.6x recycle ratio)¹.
• Net asset value per fully diluted share⁴:
  • Proved Developed Producing of $6.92;
  • Total Proved of $9.27; and
  • Total Proved + Probable of $12.88.

Summary of Gross Oil and Gas Reserves and Net Present Value of Revenue

The following tables are a summary of the Ryder Scott estimated Company reserves (Company share gross volumes) and net present values (“NPV”) of future net revenue, before tax, based on forecast price and costs as contained in the Reserve Report². The Reserve Report encompasses 100% of the Company’s oil and gas properties at December 31, 2022.

 

	Light and Medium Oil	Natural Gas Liquids	Conventional Natural Gas	Barrels of Oil Equivalent	Liquids Ratio
Reserves Category2	(mbbls)	(mbbls)	(MMcf)	(Mboe)	(%)
Proved
Developed Producing	27,930	954	7,522	30,138	96
Developed Non-producing	34	2	45	44	82
Undeveloped	11,406	492	4,496	12,647	94
Total Proved	39,370	1,448	12,063	42,829	95
Probable	18,374	629	6,147	20,027	95
Total Proved + Probable	57,744	2,077	18,210	62,856	95

 

 

NPVs before tax2		Discounted at:
	0%	5%	10%	15%	20%
Reserves Category	(MM$)	(MM$)	(MM$)	(MM$)	(MM$)
Proved
Developed Producing	856.6	896.9	791.5	698.6	626.6
Developed Non-Producing	2.4	1.8	1.4	1.2	1.0
Undeveloped	451.4	323.2	238.5	180.7	139.9
Total Proved	1,310.4	1,221.8	1,031.4	880.5	767.5
Probable	1,001.5	578.2	370.4	256.2	187.7
Total Proved + Probable	2,311.9	1,800.1	1,401.8	1,136.7	955.2

 

Net Asset Value

The following table sets out a calculation of NAV based on the estimated before-tax estimated net present value of future net revenue discounted at 10% (“NPV10 BT”) associated with the PDP, Total Proved (“TP”) and TP+P reserves, as evaluated in the Reserve Report, including deductions for future development costs, abandonment and reclamation obligations:

 

	Proved Developed Producing	Total Proved	Total Proved + Probable
NPV10 BT (MM$)	791.5	1,031.4	1,401.8
Estimated net debt December 31, 2022 (MM$)3	220.9	220.9	220.9
Net Asset Value (MM$)1	570.6	810.5	1,180.9
Basic shares outstanding (MM)	59.8	59.8	59.8
Estimated NAV/ basic share ($)3	9.53	13.53	19.72
Estimated NAV/ fully diluted share ($)4	6.92	9.27	12.88

 

Reconciliation of Reserves

The following table provides a summary of the reconciliation of the changes in the Company’s gross reserves as of December 31, 2022 against reserves at December 31, 2021, based on forecast prices and costs assumptions in effect at the applicable reserve evaluation date:

 

Light and Medium Oil			Natural Gas Liquids		Natural Gas		Total BOE
	Total Proved	T. Proved	Total Proved	T. Proved	Total Proved	T. Proved	Total Proved	T. Proved
		+ Probable		+ Probable		+ Probable		+ Probable
	(Mbbl)	(Mbbl)	(Mbbl)	(Mbbl)	(MMcf)	(MMcf)	(Mboe)	(Mboe)
December 31, 2021	30,949	46,374	1,357	2,067	8,864	13,330	33,783	50,663
Extensions	168	186	6	7	59	69	184	205
Improved Recovery	34	56	2	3	45	49	44	67
Infill Drilling	1,854	1,981	49	58	552	614	1,995	2,141
Technical Revisions	(2,075)	(2,826)	(163)	(338)	420	1,114	(2,168)	(2,978)
Acquisitions	6,537	9,131	51	71	1,328	1,871	6,809	9,514
Economic Factors	4,492	5,431	269	332	1,569	1,937	5,023	6,086
Production	(2,589)	(2,589)	(122)	(122)	(774)	(774)	(2,840)	(2,840)
December 31, 2022	39,370	57,744	1,448	2,077	12,063	18,210	42,829	62,856
Year over year change	27%	25%	7%	0%	36%	37%	27%	24%

 

Future Development Costs

The following table provides a summary of the estimated Future Development Costs (“FDC”) required to bring Saturn’s Total Proved and Total Proved + Probable undeveloped reserves to production, as reflected in the Reserve Report, which costs have been deducted in Ryder Scott’s estimation of future net revenue associated with such reserves:

 

	Total	Total Proved
Future Development Costs (MM$)	Proved	+ Probable
2023	60.0	71.9
2024	59.9	71.6
2025	55.3	66.2
2026	57.5	68.4
2027	55.1	74.5
Remainder	–	133.9
Total FDC undiscounted	287.8	486.5

 

Performance Measures

The following table highlights Finding, Development and Acquisition (“FD&A”)¹ costs and associated recycle ratios based on the evaluation of reserves prepared by Ryder Scott:

 

Proved plus Probable FD&A costs1	2022	2021	Two Year Totals and Weighted Average
Capital expenditures ($MM)	$86.9	$8.1	$95.0
Net acquisition expenditures ($MM)	$248.4	$82.3	$330.7
Total expenditures ($MM)	$335.3	$90.4	$425.7
Gross reserve additions (Mboe)	15,034	45,612	60,646
FD&A cost (per BOE) 1	$22.30	$1.98	$7.02
Average Operating Netback (per BOE) 3	$65.92	$36.38	$59.65
Recycle Ratio1	3.0x	18.4x	8.5x
Change in FDC ($MM)	$183.1	$179.2	362.3
FD&A Cost, including change in FDC (per BOE) 1	$34.48	$5.91	$12.99
Recycle Ratio, including change in FDC1	1.9x	6.2x	4.6x

 

The following table highlights Finding and Development (“F&D”)¹ costs and associated recycle ratios based on the evaluation of reserves prepared by Ryder Scott:

 

Proved plus Probable F&D costs	2022	2021	Two Year Totals and Weighted Average
Capital expenditures ($MM)	$86.9	$8.1	$95.0
Gross reserve additions from capital expenditure (Mboe)	5,521	1,299	6,820
F&D cost (per BOE) 3	$15.74	$6.24	$13.93
Average Operating Netback (per BOE) 3	$65.92	$36.38	$63.40
Recycle Ratio1	4.2x	5.8x	4.6x

 

Price Forecast

The following table summarizes the commodity price forecasts and foreign exchange rate assumptions of three consultant’s

average forecasts⁵ as of January 1, 2023 as applied in the Reserve Report, for the next five years.

 

	Exchange Rate	WTI @ Cushing	Canadian Light Sweet 40º API	AECO Spot	Butane
Year	$US/$C	(US$/bbl)	(C$/bbl)	(C$/MMbtu)	(C$/bbl)
2023	0.745	80.33	103.76	4.23	53.88
2024	0.765	78.50	97.74	4.40	52.67
2025	0.768	76.95	95.27	4.21	51.42
2026	0.772	77.61	95.58	4.27	51.61
2027	0.775	79.16	97.07	4.43	52.39

 

Total Location Summary

The following table summarizes the gross drilling locations identified for future development in the Reserve Report:

 

Field	Locations Year End 2022	Previous Locations Year End 2021
Glen Ewen	137	127
Ingoldsby	12	20
Manor	78	82
Weir Hill	63	72
West Central (Viking)	162	53
Total Locations	452	354

 

Ridgeback Resources Inc. Summary of Gross Oil and Gas Reserves and Net Present Value of Revenue

Saturn completed the acquisition of Ridgeback Resources Inc. on February 28, 2023. The following tables are a summary of the Ridgeback’s estimated corporate reserves (Ridgeback’s share of gross volumes) and net present values of future net revenue, before tax, based on escalated prices and costs as forecasted by Sproule Associates Ltd. (“Sproule”) effective December 31, 2022. The evaluation of Ridgeback’s reserves, dated February 17, 2023, encompasses 100% of Ridgeback’s oil and gas properties at December 31, 2022 (the “Sproule Report”) and was prepared in accordance with NI 51-101 by Sproule:

 

	Light and Medium Oil	Natural Gas Liquids	Conventional Natural Gas	Coal Bed Methane	Barrels of Oil Equivalent	Liquids Ratio
Reserves Category2	(mbbls)	(mbbls)	(MMcf)	(MMcf)	(Mboe)	(%)
Proved
Developed Producing	21,065	4,771	70,133	23	37,529	69
Developed Non-producing	382	121	1,724	–	790	64
Undeveloped	18,416	2,652	40,694	–	27,850	76
Total Proved	39,863	7,544	112,550	23	66,169	72
Probable	18,780	3,210	48,683	8	30,105	73
Total Proved + Probable	58,643	10,754	161,233	31	96,274	72

 

 

NPVs before tax2		Discounted at:
	0%	5%	10%	15%	20%
Reserves Category	(MM$)	(MM$)	(MM$)	(MM$)	(MM$)
Proved
Developed Producing	1,107.5	1,024.3	883.7	773.8	690.9
Developed Non-Producing	27.9	21.7	18.0	15.6	13.8
Undeveloped	451.4	323.2	238.5	180.7	139.9
Total Proved	1,893.4	1,534.9	1,231.5	1,018.4	866.4
Probable	1,194.2	736.6	507.9	376.8	294.3
Total Proved + Probable	3,087.5	2,271.6	1,739.4	1,395.2	1,160.8

 

Price Forecast for Sproule Report

The following table summarizes the commodity price forecasts and foreign exchange rate assumptions as of December 31, 2022 as applied in the Sproule Report, for the next five years.

 

	Exchange Rate	WTI @ Cushing	Canadian Light Sweet 40º API	AECO Spot	Butane
Year	$US/$C	(US$/bbl)	(C$/bbl)	(C$/MMbtu)	(C$/bbl)
2023	0.75	86.00	110.67	4.33	54.47
2024	0.80	84.00	101.25	4.34	52.50
2025	0.80	80.00	96.18	4.00	50.00
2026	0.80	81.60	98.10	4.08	51.00
2027	0.80	83.23	100.06	4.16	52.02

 

Total Location Summary of Sproule Report

The following table summarizes the gross drilling locations identified for future development in the Sproule Report:

 

Field	Locations Year End 2022
SE Saskatchewan	293
Cardium & Southern Alberta	175
Deer Mountain	22
Kaybob	22
Total Locations	512

 

Granting of Incentive Stock Options and Expiry of Warrants.

The board of directors of Saturn has authorized the granting of inventive stock options to directors, officers, employees and consultants entitling them to purchase up to a total of 1,508,000 common shares at a price of $2.50 per share for a period of five years, vesting as to 1/3 per year on the first, second and third anniversary of the date of grant. In addition, the Company issued an aggregate of 97,500 restricted share units at a reference price of $2.50 vesting as to 1/3 per year on the first, second and third anniversary of the date of grant.

On February 28, 2023 approximately 2.2 million share purchase warrants, that were issued to a previous lender to the Company, expired unexercised.

On March 1, 2023: Net debt was estimated at approximately $550 million; Saturn has approximately 138.5 million common shares outstanding; warrants and options issued that are convertible into approximately 48.9 million common shares with an average exercise price of $3.12 per share for aggregate exercise proceeds of approximately $152.8 million.

 

Year End Disclosures

The 2022 financial information in this news release is unaudited and accordingly, such financial information is subject to change based on the results of the Company’s year-end audit, schedule to be released on or about March 28, 2023.

Additional reserve information as required under NI 51-101 will be included in the Company’s annual information form which

will be filed on SEDAR on or about March 28, 2023.

About Saturn Oil & Gas Inc.

Saturn Oil & Gas Inc. is a growing Canadian energy company focused on generating positive shareholder returns through the continued responsible development of high-quality, light oil weighted assets, supported by an acquisition strategy that targets highly accretive, complementary opportunities. Saturn has an ESG-focused culture, Saturn’s goal is to increase reserves, production and cash flows at an attractive return on invested capital. Saturn’s shares are listed for trading on the TSX.V under ticker ‘SOIL’ on the Frankfurt Stock Exchange under symbol ‘SMKA’ and on the OTCQX under the ticker ‘OILSF’.

Saturn Oil & Gas Investor & Media Contacts:

John Jeffrey, MBA – Chief Executive Officer Tel: +1 (587) 392-7902

www.saturnoil.com

 

Kevin Smith, MBA – VP Corporate Development Tel: +1 (587) 392-7900

info@saturnoil.com

 

Notes:

• See Reader Advisory “Oil and Gas Metrics”.
• Total values may not add due to
• See Reader Advisory “Non-GAAP and Other Financial Measures”.
• Includes basic common shares outstanding of 59.9 million, warrants and options issued that are convertible into approximately 42.5 million common shares with an average exercise price of $3.25 per share for aggregate exercise proceeds of approximately $138.3 million for fully diluted common shares of 4 million, net debt of approximately

$220.9 million as at December 31, 2022, and net debt adjusted for approximately $138.3 million of common share purchase warrant and option exercise proceeds that would be in-the-money at the corresponding NAV per share value. The estimated NPV does not represent fair market value of the reserves.

• Average forecasts of GLJ Ltd., McDaniel & Associates Consultants Ltd. and Sproule Associates Ltd. and includes 2.33% inflation in Year 2024 and 2% per annum thereafter.

 

Reader Advisory

Non-GAAP and Other Financial Measures

Throughout this news release and in other materials disclosed by the Company, we employ certain measures to analyze financial performance, financial position and cash flow. These non-GAAP and other financial measures do not have any standardized meaning prescribed by IFRS and therefore may not be comparable to similar measures provided by other issuers. Non-GAAP and other financial measures should not be considered to be more meaningful than GAAP measures which are determined in accordance with IFRS. The Company’s unaudited condensed consolidated interim financial statements and MD&A as at and for the three and nine months ended September 30, 2022 are available on the Company’s website at www.saturnoil.com and under our SEDAR profile at www.sedar.com. The disclosure under the section “Non-GAAP and Other Financial Measures” including non-GAAP financial measures and ratios, capital management measures and supplementary financial measures in the MD&A is incorporated by reference into this news release.

This press release uses the term “Capital Expenditures”, “Net Debt” and “Operating Netback”, which are a non-GAAP financial measure. This non-GAAP financial measure is not a standardized financial measure under IFRS and might not be comparable

 

to similar financial measures disclosed by other issuers. See the disclosure under the section “Non-GAAP Financial Measures and Ratios” in our MD&A for the three and nine months ended September 30, 2022, for an explanation of the composition of these measures and how these measures provide useful information to an investor, and the additional purposes, if any, for which management uses these measures.

Where applicable, the supplementary financial measures used in this news release are either a per unit disclosure of a corresponding GAAP measure, or a component of a corresponding GAAP measure, presented in the unaudited condensed consolidated interim financial statements. Supplementary financial measures that are disclosed on a per unit basis are calculated by dividing the aggregate GAAP measure (or component thereof) by the applicable unit for the period. Supplementary financial measures that are disclosed on a component basis of a corresponding GAAP measure are a granular representation of a financial statement line item and are determined in accordance with GAAP.

 

Oil and Gas Metrics

This press release contains metrics commonly used in the oil and gas industry which have been prepared by management, such as “FD&A costs”, “F&D costs”, “Net Asset Value”, “Recycle Ratio” and “Reserve Life Index”. These terms do not have a standardized meaning and may not be comparable to similar measures presented by other companies, and therefore should not be used to make such comparisons.

 

“FD&A Cost” represents finding, developing and acquisition cost as calculated as the sum of 2022 capital expenditures not including capitalized general and administration expenses ($86.9 million) plus net acquisition costs ($248.4 million), divided by the change in reserves within the applicable reserves category, inclusive of changes due to acquisitions and dispositions.

 

“F&D Cost” represents finding and developing cost as calculated as the sum of 2022 capital expenditures, not including capitalized general and administration expenses, ($86.9 million) divided by the change in reserves within the applicable reserves category, without including changes in reserves due to acquisitions and dispositions.

 

“Net Asset Value” has been calculated based on the estimated net present value of all future revenue from the Company’s reserves, before income taxes as estimated by Ryder Scott effective December 31, 2022, including expenditures for abandonment, decommissioning and reclamation costs for all producing and non-producing wells and facilities, less net debt.

 

“Recycle Ratio” is calculated by dividing operating netback per boe by F&D costs or F&D costs for a year or for an average over two years.

 

“Reserve life index” or “RLI” is calculated by dividing the applicable reserves category volumes by 2022 fourth quarter production of 12,514 boe/d for 365 days as an estimation of how many years at a steady production level would the reserve volumes support.

 

 

BOE PRESENTATION

BOE means barrel of oil equivalent. All boe conversions in this news release are derived by converting gas to oil at the ratio of six thousand cubic feet (“Mcf”) of natural gas to one barrel (“Bbl”) of oil. Boe may be misleading, particularly if used in isolation. A Boe conversion rate of 1 Bbl : 6 Mcf is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio of oil compared to natural gas based on currently prevailing prices is significantly different than the energy equivalency ratio of 1 Bbl : 6 Mcf, utilizing a conversion ratio of 1 Bbl : 6 Mcf may be misleading as an indication of value.

Reserve Definitions

“Proved” reserves are those reserves that can be estimated with a high degree of certainty to be recoverable. It is likely that the actual remaining quantities recovered will exceed the estimated proved reserves.

“Probable” reserves are those additional reserves that are less certain to be recovered than proved reserves. It is equally likely that the actual remaining quantities recovered will be greater or less than the sum of the estimated proved plus probable reserves.

 

“Developed” reserves are those reserves that are expected to be recovered from existing wells and installed facilities or, if facilities have not been installed, that would involve a low expenditure (e.g. when compared to the cost of drilling a well) to put the reserves on production.

“Developed Producing” reserves are those reserves that are expected to be recovered from completion intervals open at the time of the estimate. These reserves may be currently producing or, if shut-in, they must have previously been on production, and the date of resumption of production must be known with reasonable certainty.

“Developed Non-Producing” reserves are those reserves that either have not been on production, or have previously been on production, but are shut in, and the date of resumption of production is unknown.

“Undeveloped” reserves are those reserves expected to be recovered from known accumulations where a significant expenditure (for example, when compared to the cost of drilling a well) is required to render them capable of production. They must fully meet the requirements of the reserves classification (proved, probable, possible) to which they are assigned.

 

FORWARD-LOOKING INFORMATION AND STATEMENTS.

Certain information included in this press release constitutes forward-looking information under applicable securities legislation. Forward-looking information typically contains statements with words such as “anticipate”, “believe”, “expect”, “plan”, “intend”, “estimate”, “propose”, “project”, “scheduled”, “will” or similar words suggesting future outcomes or statements regarding an outlook. Forward-looking information in this press release may include, but is not limited to, the drilling of wells, and the business plan, cost model and strategy of the Company. Reserves disclosure is, by its nature, forward looking.

The forward-looking statements contained in this press release are based on certain key expectations and assumptions made by Saturn, including expectations and assumptions concerning: the timing of and success of future drilling, development and completion activities, the performance of existing wells, the performance of new wells, the availability and performance of facilities and pipelines, the geological characteristics of Saturn’s properties, the application of regulatory and licensing requirements, the availability of capital, labour and services, the creditworthiness of industry partners and the ability to source and complete asset acquisitions.

Although Saturn believes that the expectations and assumptions on which the forward-looking statements are based are reasonable, undue reliance should not be placed on the forward-looking statements because Saturn can give no assurance that they will prove to be correct. Since forward-looking statements address future events and conditions, by their very nature they involve inherent risks and uncertainties. Actual results could differ materially from those currently anticipated due to a number of factors and risks. These include, but are not limited to, risks associated with the oil and gas industry in general (e.g., operational risks in development, exploration and production; the uncertainty of reserve estimates; the uncertainty of estimates and projections relating to production, costs and expenses, and health, safety and environmental risks), constraint in the availability of services, commodity price and exchange rate fluctuations, actions of OPEC and OPEC+ members, changes in legislation impacting the oil and gas industry, adverse weather or break-up conditions and uncertainties resulting from potential delays or changes in plans with respect to exploration or development projects or capital expenditures. These and other risks are set out in more detail in Saturn’s Annual Information Form for the year ended December 31, 2021.

Forward-looking information is based on a number of factors and assumptions which have been used to develop such information, but which may prove to be incorrect. Although Saturn believes that the expectations reflected in its forward- looking information are reasonable, undue reliance should not be placed on forward-looking information because Saturn can give no assurance that such expectations will prove to be correct. In addition to other factors and assumptions which may be identified in this press release, assumptions have been made regarding and are implicit in, among other things, anticipated timing and results of capital expenditures; the success obtained in drilling new wells; the sufficiency of budgeted capital expenditures in carrying out planned activities; the timing, location and extent of future drilling operations; the expected timing of release of our audited financials and AIF; results of operations; performance; business prospects and opportunities; the availability and cost of financing. Readers are cautioned that the foregoing list is not exhaustive of all factors and assumptions which have been used.

The forward-looking information contained in this press release is made as of the date hereof and Saturn undertakes no obligation to update publicly or revise any forward-looking information, whether as a result of new information, future events

 

or otherwise, unless required by applicable securities laws. The forward-looking information contained in this press release is expressly qualified by this cautionary statement.

Neither the TSX Venture Exchange nor its Regulation Services Provider (as that term is defined in the policies of the TSX Venture Exchange) accepts responsibility for the adequacy or accuracy of this press release.

All dollar figures included herein are presented in Canadian dollars, unless otherwise noted.