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Petrus Resources Announces Year End 2020 Financial, Operating & Reserves Results; Significant Net Debt Reduction


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CALGARY, Alberta, Feb. 25, 2021 (GLOBE NEWSWIRE) — Petrus Resources Ltd. (“Petrus” or the “Company”) (TSX: PRQ) is pleased to report financial and operating results as at and for the three and twelve months ended December 31, 2020 and to provide 2020 year end reserves information as evaluated by Sproule Associates Limited (“Sproule”). The Company’s Management’s Discussion and Analysis (“MD&A”) and audited consolidated financial statements are available on SEDAR (the System for Electronic Document Analysis and Retrieval) at www.sedar.com.

Given the significant turmoil in global energy markets in 2020, Petrus is pleased to report annual results that achieved the objectives management laid out for the year. This includes the generation of free cash flow in excess of capital expenditures used to repay debt and continue to strengthen the Company’s balance sheet. Petrus generated $26.4 million of funds flow in 2020. This was used to fund a capital program of $14.3 million, the lowest in the Company’s history, with the remainder used to reduce the balance drawn on the company’s Revolving Credit Facility (“RCF”). In light of the volatile commodity prices during the outbreak of the COVID-19 pandemic, the Company pursued a very disciplined capital program. To conserve cash, Petrus drilled 4 gross wells (3.2 net) during the year. The Company continues to focus the majority of capital spending in its Ferrier core area where ownership of key infrastructure generates low operating costs, high netbacks and quick capital payouts.

  • Debt repayment – Reduction of debt was the top priority for the Company in 2020 and Petrus was successful in reducing net debt by $9.4 million during the year. Since December 31, 2015 Petrus has repaid $112.4 million (50%) of net debt. As part of the extension agreement reached in mid-2020 in respect of Petrus’ second lien term loan (“Term Loan”), interest is now paid-in-kind and is added to the balance of the loan outstanding. Petrus focused on paying down the balance of the RCF, which was reduced by $14.8 million during the year, and is ahead of its required scheduled repayments.
  • Stronger natural gas pricing – Natural gas prices showed marked improvement from the prior year and continue to strengthen. Petrus’ average realized price was $2.57/mcf in 2020, compared to $1.89/mcf in 2019, a 36% improvement. Company production was weighted 70% towards natural gas in 2020.
  • Free funds flow – In 2020 Petrus generated funds flow of $26.4 million ($0.53/share), and invested $14.3 million in capital projects including the drilling of three 100% working interest wells. During the fourth quarter of 2020, Petrus generated funds flow of $6.4 million.
  • Increased PDP reserves – In 2020, Petrus’ development program generated PDP reserve volume additions of 2.9 mmboe, or 1.2x production in the year. Despite decreased capital spending, the Company produced 2.4 mmboe during 2020 and ended the year with 12.2 mmboe of PDP reserves. Petrus realized Finding Development and Acquisition (“FD&A”) costs of $4.83/boe for PDP reserves, which are the best in the Company’s history.
  • Low operating costs – Total annual operating costs were $4.64/boe in 2020. The Company continues to focus on optimizing its cost structure, particularly in the Ferrier area, through facility ownership and control.
  • Reduced general and administrative costs – Petrus reduced gross general and administrative expenses (“G&A”) by $1.0 million in 2020, in comparison to 2019, to a total of $5.2 million. This marks the fourth consecutive year of G&A cost reductions and a 40% reduction since 2017.

2021 OUTLOOK

Petrus’ Board of Directors has approved a first quarter 2021 capital budget of $9.0 million to drill 3 gross (2.1 net) Cardium wells in its Ferrier area. With current commodity prices and the low operating cost structure utilizing company owned infrastructure, new wells operated by Petrus in the Ferrier area are expected to reach payout in under one year.

Petrus is committed to maintaining its financial flexibility and the Company will determine subsequent quarter capital spending as the year progresses. With stronger forward oil and gas prices than were experienced through most of 2020, Petrus management is forecasting stronger cash flow in 2021 than 2020 that will be used to fund a larger capital program and grow production from 2020 levels. Management anticipates that the 2020 capital plan will be funded by funds flow, with free funds flow used to continue significant debt reduction targets. With improved commodity pricing so far in 2021, Petrus has been active in adding price protection for the remainder of the year through additional forward sale contracts. The average volume of oil hedged for 2021 (825 bbl/d) represents 41% of fourth quarter 2020 average oil production. The 15,250 GJ/day average natural gas hedged for 2021 represents 61% of fourth quarter 2020 average natural gas production. Petrus’ management continues to layer in additional hedged volumes into 2022.

Refer to “Non-GAAP Financial Measures”.
Refer to “Advisories – Forward-Looking Statements”.
Refer to “Advisories – Presentation”.


SELECTED FINANCIAL INFORMATION

OPERATIONS Twelve months ended

Dec. 31, 2020

Twelve months ended

Dec. 31, 2019

Three months ended

Dec. 31, 2020

Three months ended

Sept. 30, 2020

Three months ended

Jun. 30, 2020

Three months ended

Mar. 31, 2020

Average Production
Natural gas (mcf/d) 27,640 32,032 26,177 26,181 27,630 30,604
Oil (bbl/d) 1,021 1,616 980 1,103 867 1,134
NGLs (bbl/d) 980 1,351 1,014 997 819 1,088
Total (boe/d) 6,608 8,306 6,357 6,463 6,291 7,323
Total (boe) 2,418,259 3,031,659 584,860 594,599 572,440 666,361
Light oil weighting 15 % 19 % 15 % 17 % 14 % 15 %
Realized Prices
Natural gas ($/mcf) 2.57 1.89 3.07 2.51 2.35 2.40
Oil ($/bbl) 44.14 64.11 49.64 46.46 27.18 50.02
NGLs ($/bbl) 20.84 22.13 23.52 22.05 12.87 23.19
Total realized price ($/boe) 20.67 23.35 24.05 21.48 15.73 21.23
Royalty income 0.16 0.20 0.13 0.12 0.06 0.30
Royalty expense (2.15 ) (2.35 ) (2.02 ) (2.09 ) (1.51 ) (2.85 )
Net oil and natural gas revenue ($/boe) 18.68 21.20 22.16 19.51 14.28 18.68
Operating expense (4.64 ) (4.25 ) (5.53 ) (4.05 ) (4.44 ) (4.55 )
Transportation expense (1.43 ) (1.26 ) (1.68 ) (1.63 ) (1.40 ) (1.05 )
Operating netback(1) ($/boe) 12.61 15.69 14.95 13.83 8.44 13.08
Realized gain (loss) on derivatives ($/boe) 2.70 (0.44 ) 0.65 2.20 6.39 1.76
Other income 0.15 0.03 0.31 0.04 0.17 0.07
General & administrative expense (1.41 ) (1.20 ) (1.81 ) (1.07 ) (1.43 ) (1.35 )
Cash finance expense (2.75 ) (2.72 ) (2.49 ) (2.16 ) (3.20 ) (3.13 )
Decommissioning expenditures (0.37 ) (0.28 ) (0.63 ) (0.13 ) (0.15 ) (0.56 )
Funds flow & corporate netback(1)(2) ($/boe) 10.93 11.08 10.98 12.71 10.22 9.87
FINANCIAL (000s except $ per share) Twelve months ended

Dec. 31, 2020

Twelve months ended

Dec. 31, 2019

Three months ended

Dec. 31, 2020

Three months ended

Sept. 30, 2020

Three months ended

Jun. 30, 2020

Three months ended

Mar. 31, 2020

Oil and natural gas revenue 50,368 71,398 14,143 12,840 9,041 14,344
Net loss (97,554 ) (42,176 ) (151 ) (3,678 ) (6,281 ) (87,444 )
Net loss per share
Basic (1.97 ) (0.85 ) (0.07 ) (0.13 ) (1.77 )
Fully diluted (1.97 ) (0.85 ) (0.07 ) (0.13 ) (1.77 )
Funds flow 26,397 33,625 6,423 7,551 5,855 6,566
Funds flow per share
Basic 0.53 0.68 0.13 0.15 0.12 0.13
Fully diluted 0.53 0.68 0.13 0.15 0.12 0.13
Capital expenditures 14,298 18,073 2,797 2,543 305 8,655
Net dispositions 651
Weighted average shares outstanding
Basic 49,469 49,472 49,469 49,469 49,469 49,469
Fully diluted 49,469 49,472 49,469 49,469 49,469 49,469
As at year end
Common shares outstanding
Basic 49,469 49,469 49,469 49,469 49,469 49,469
Fully Diluted 49,469 49,469 49,469 49,469 49,469 49,469
Fully diluted Total assets 177,914 289,225 177,914 179,895 184,532 193,679
Non-current liabilities 45,321 42,346 45,321 44,471 43,017 38,533
Net debt(1) 114,361 123,744 114,361 116,717 120,570 125,974

(1)Refer to “Non-GAAP Financial Measures”.
(2)Corporate netback is equal to funds flow which is a comparable additional GAAP measure. Petrus analyzes these measures on an absolute value and per unit basis.


OPERATIONS UPDATE

Fourth quarter average production by area was as follows:

For the three months ended December 31, 2020
Ferrier Foothills Central Alberta Total
Natural gas (mcf/d) 19,637 1,425 5,118 26,180
Oil (bbl/d) 569 113 298 980
NGLs (bbl/d) 860 7 147 1,014
Total (boe/d) 4,702 357 1,298 6,357

Fourth quarter production averaged 6,357 boe/d in 2020 versus 6,463 boe/d in the third quarter. Production was lower due to natural declines as no new wells were brought on production during the quarter. One well completed during the fourth quarter is awaiting tie-in and is expected to be brought on production in the first quarter of 2021.

Petrus’ Board of Directors has approved a first quarter 2021 capital budget of $9.0 million to drill 3 gross (2.1 net) Cardium wells in the Ferrier area. With current commodity prices and the low operating cost structure utilizing company owned infrastructure, new wells operated by Petrus in the Ferrier area are expected to reach payout in under one year.

With stronger forward oil and natural gas prices than were experienced through most of 2020, Petrus management is forecasting stronger cash flow in 2021 than 2020 that will be used to fund a larger capital program and grow production from 2020 levels. Management anticipates that the 2020 capital plan will be funded by funds flow, with free funds flow used to continue significant debt reduction targets. With improved commodity pricing so far in 2021, Petrus has been active in adding price protection for the remainder of the year through additional forward sale contracts. The average volume of oil hedged for 2021 (825 bbl/d) represents 41% of fourth quarter 2020 average oil production. The 15,250 GJ/day average natural gas hedged for 2021 represents 61% of fourth quarter 2020 average natural gas production.

RESERVES

Petrus’ 2020 year end reserves were evaluated by independent reserves evaluator, Sproule Associates Limited, in accordance with the definitions, standards and procedures contained in the Canadian Oil and Gas Evaluation Handbook (“COGE Handbook”) and National instrument 51-101 – Standards of Disclosure for Oil and Gas Activities (“NI 51-101”) as of December 31, 2020 (“2020 Sproule Report”). Additional reserve information as required under NI 51-101 will be included in our Annual Information Form for the year ended December 31, 2020, which will be available under the Company’s profile on SEDAR (the System for Electronic Document Analysis and Retrieval) at www.sedar.com.

Petrus has a reserves committee, comprised of independent board members, that reviews the qualifications and appointment of the independent reserves evaluator. The committee also reviews the procedures for providing information to the evaluators. All booked reserves are based upon annual evaluations by the independent qualified reserve evaluator conducted in accordance with the COGE Handbook and NI 51-101. The evaluations are conducted using all available geological and engineering data. The reserves committee has reviewed the reserves information and approved the 2020 Sproule Report.

The following table provides a summary of the Company’s before tax reserves as evaluated by Sproule:

As at December 31, 2020 Total Company Interest (1)(3)
Reserve Category Conventional Natural Gas (mmcf) Light and Medium Crude Oil (mbbl) NGL
(mbbl)
Total
(mboe)
NPV 0%(2)
($000s)
NPV 5%(2)
($000s)
NPV 10%(2)
($000s)
Proved Producing 53,172 1,158 2,150 12,170 120,922 130,024 119,122
Proved Non-Producing 309 8 14 74 726 639 571
Proved Undeveloped 52,448 943 3,492 13,177 113,185 68,344 39,745
Total Proved 105,929 2,109 5,657 25,421 234,833 199,007 159,438
Proved + Probable Producing 66,071 1,435 2,650 15,097 167,144 154,424 133,562
Total Probable 65,186 2,231 2,894 15,989 224,418 142,949 97,553
Total Proved Plus Probable 171,115 4,340 8,551 41,410 459,251 341,956 256,991

(1)Tables may not add due to rounding.
(2)NPV 0%, NPV 5% and NPV 10% refer to the risked net present value of the future net revenue of the Company’s reserves, discounted by 0%, 5% and 10%, respectively and is presented before tax and based on Sproule’s pricing assumptions.
(3)Total company interest reserve volumes presented above and in the remainder of this Annual Report are presented as the Company’s total working interest before the deduction of royalties (but after including any royalty interests of Petrus).

In 2020, Petrus’ development program generated Proved Developed Producing (“PDP”) reserve volume additions of 1.3 mmboe. The Company produced 2.4 mmboe during 2019 and ended the year with 12.2 mmboe of PDP reserve volume (34% oil and liquids).

Petrus ended 2020 with $119.7 million, $159.4 million and $257.0 million of Proved Developed (“PD”), Total Proved (“TP”), and Proved plus Probable (“P+P”), respectively, reserve value before-tax, discounted at 10%, based on the 2020 Sproule Report. In 2020, the Company realized Finding and Development (“FD&A”)(1)(2) costs of $4.83/boe for PDP reserves.

Based on the 2020 Sproule Report, the Company’s PDP reserve value before-tax, discounted at 10% is $2.41 per share. On the same basis, the P+P reserve value is $5.20 per share.

(1)Refer to “Oil and Gas Disclosures”.
(2)Certain changes in FD&A and F&D produce non-meaningful figures as discussed in “Oil and Gas Disclosures”.
While FD&A and F&D costs, reserve life index, reserve replacement ratio and finding and development costs are commonly used in the oil and nature gas industry and have been prepared by management, 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.

FUTURE DEVELOPMENT COST

Future Development Cost (“FDC”) reflects Sproule’s best estimate of what it will cost to bring the P+P undeveloped reserves on production. The following table provides a summary of the Company’s FDC as set forth in the 2020 Sproule Report:


Future Development Cost ($000s)
Total Proved Total Proved + Probable
2021 28,582 36,242
2022 45,758 70,913
2023 57,783 65,731
2024 6,164 20,582
2025 12,944 28,895
2026 5,583 11,129
2027 18,844
Thereafter
Total FDC, Undiscounted 156,815 252,335
Total FDC, Discounted at 10% 129,059 198,745

PERFORMANCE RATIOS
The following table highlights annual performance ratios for the Company from 2016 to 2020:

December 31, 2020 December 31, 2019 December 31, 2018 December 31, 2017 December 31, 2016
Proved Producing
FD&A ($/boe) (1)(2) 4.83 13.31 37.76 13.05 (0.43 )
F&D ($/boe) (1)(2) 4.83 12.81 42.27 11.57 9.89
Reserve Life Index (yr) (1) 5.2 3.8 4.6 4.1 4.4
Reserve Replacement Ratio (1) 1.2 0.4 0.2 1.6 0.4
FD&A Recycle Ratio (1) 2.6 1.2 0.4 1.1 (24.8 )
Proved Developed
FD&A ($/boe) (1)(2) 4.71 12.49 11.34 16.74 (0.23 )
F&D ($/boe) (1)(2) 4.71 12.03 11.55 14.62 7.69
Reserve Life Index (yr) (1) 5.2 4.8 5.6 4.5 5.3
Reserve Replacement Ratio (1) 1.2 0.5 0.6 1.2 0.7
FD&A Recycle Ratio (1) 2.7 1.3 1.4 0.9 (46.3 )
Total Proved
FD&A ($/boe) (1)(2) 1.29 1.09 8.73 14.33 (15.78 )
F&D ($/boe) (1)(2) 1.29 (6.83 ) 8.16 12.03 2.46
Reserve Life Index (yr) (1) 10.9 9.9 11.1 8.0 9.8
Reserve Replacement Ratio (1) (1.0 ) 0.3 1.3 1.1 0.5
FD&A Recycle Ratio (1) 9.8 14.4 1.8 1.0 (0.7 )
Future Development Cost ($000s) 156,815 174,027 194,757 182,086 201,556
Total Proved + Probable
FD&A ($/boe) (1)(2) 0.37 (7.32 ) 6.49 14.87 350.09
F&D ($/boe) (1)(2) 0.37 190.21 5.15 17.28 (8.06 )
Reserve Life Index (yr) (1) 17.7 15.4 17.1 12.3 14.6
Reserve Replacement Ratio (1) (1.3 ) 1.5 1.7 (0.1 )
FD&A Recycle Ratio (1) 33.7 (2.1 ) 2.4 1.0
Future Development Cost ($000s) 252,335 267,652 290,876 283,030 269,144

(1)Refer to “Oil and Gas Disclosures”.
(2)Certain changes in FD&A and F&D produce non-meaningful figures as discussed in “Oil and Gas Disclosures”. While FD&A and F&D costs, reserve life index, reserve replacement ratio and finding and development costs are commonly used in the oil and nature gas industry and have been prepared by management, 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.

NET ASSET VALUE
The following table shows the Company’s Net Asset Value (“NAV”), calculated using Sproule’s December 31, 2020 price forecast:

As at December 31, 2020 ($000s except per share) 
Proved Developed Producing Total Proved Proved + Probable
Present Value Reserves, before tax (discounted at 10%) (1) 119,122 159,438 256,991
Undeveloped Land Value (2) 17,568 17,568 17,568
Net Debt (3) (114,361 ) (114,361 ) (114,361 )
Net Asset Value 22,329 62,645 160,198
Estimated Net Asset Value per Share $0.45 $1.27 $3.24

(1)Based on the 2020 Sproule Report, using the forecast future prices and costs.
(2)Based on the exploration and evaluation assets as per the Company’s December 31, 2020 audited consolidated financial statements.
(3)See “Non-GAAP Financial Measures”.

ANNUAL GENERAL MEETING
The Corporation currently intends to hold its Annual General Meeting (“Meeting”) on Thursday, May 13, 2021 at 2:00 p.m. (Calgary time). Due to the COVID-19 pandemic and restrictions on indoor gatherings implemented by the Government of Alberta in response thereto, and out of concern for the wellbeing of all participants, access to the Meeting may be limited. The Company does not plan to have a formal presentation at the conclusion of the Meeting. We encourage all shareholders and proxyholders not to attend the meeting in person, particularly if they are experiencing any of the described COVID-19 symptoms. Shareholders and guests can listen to the Meeting via teleconference at 1-888-433-2192 (participant code 6841494) however shareholders and proxyholders will not be able to vote their shares via teleconference. We encourage all shareholders to submit their proxies in advance of the Meeting.

An updated corporate presentation can be found on the Company’s website at www.petrusresources.com.

For further information, please contact:

Neil Korchinski, P.Eng.
President and Chief Executive Officer T: (403) 930-0889
E: nkorchinski@petrusresources.com

NON-GAAP FINANCIAL MEASURES
This press release makes reference to the terms “operating netback”, “corporate netback” and “net debt”. These indicators are not recognized measures under GAAP (IFRS) and do not have a standardized meaning prescribed by GAAP (IFRS). Accordingly, the Company’s use of these terms may not be comparable to similarly defined measures presented by other companies. Management uses these terms for the reasons set forth below.

Operating Netback
Operating netback is a common non-GAAP financial measure used in the oil and natural gas industry which is a useful supplemental measure to evaluate the specific operating performance by product at the oil and natural gas lease level. The most directly comparable GAAP measure to operating netback is funds flow. Operating netback is calculated as oil and natural gas revenue less royalties, operating and transportation expenses. It is presented on an absolute value and per unit basis.

Funds Flow and Corporate Netback
Corporate netback is a common non-GAAP financial measure used in the oil and natural gas industry which evaluates the Company’s profitability at the corporate level. Corporate netback is equal to funds flow which is a directly comparable GAAP measure. Petrus analyzes these measures on an absolute value and per unit basis. Management believes that funds flow and corporate netback provide information to assist a reader in understanding the Company’s profitability relative to current commodity prices. It is calculated, in the following table, as the operating netback less general and administrative expense, finance expense, decommissioning expenditures, plus other income and the net realized gain (loss) on financial derivatives.

Net Debt
Net debt is a non-GAAP financial measure and is calculated as current assets (excluding unrealized financial derivative assets) less current liabilities (excluding unrealized financial derivative liabilities, right-of-use lease obligations, and deferred share unit liabilities) and long term debt. Petrus uses net debt as a key indicator of its leverage and strength of its balance sheet. There is no GAAP measure that is reasonably comparable to net debt.

OIL AND GAS DISCLOSURES

Our oil and gas reserves statement for the year ended December 31, 2020, which includes disclosure of our oil and natural gas reserves and other oil and natural gas information in accordance with NI 51-101, is contained in the AIF. The recovery and reserve estimates contained herein are estimates only and there is no guarantee that the estimated reserves will be recovered.

F&D and FD&A Costs
FD&A cost is defined as capital costs for the time period including change in FDC divided by change in reserves including revisions and production for that same time period. F&D cost is defined as capital costs for the time period including change in FDC divided by change in reserves including revisions and production for that same time period, excluding acquisitions and dispositions. Both F&D and FD&A costs take into account reserves revisions during the year on a per boe basis. The methodology used to calculate F&D costs includes disclosure required to bring the proved undeveloped and probable reserves to production. Annually, changes in forecast FDC occur as a result of Petrus’ development, acquisition and disposition activities, undeveloped reserve revision and capital cost estimates. These values reflect the independent evaluator’s best estimate of the cost to bring the proved and probable undeveloped reserves to production. In 2019, the P+P FD&A and F&D costs including changes in FDC can generate non meaningful information because acquisitions and dispositions can have a significant impact on our ongoing reserves replacement costs.

Reserve Life Index
Reserve life index is defined as total reserves by category divided by the annualized fourth quarter production.

Reserve Replacement Ratio
The reserve replacement ratio is calculated by dividing the yearly change in reserves net of production by the actual annual production for the year.

Management uses oil and gas metrics for its own performance measurements and to provide shareholders with measures to compare Petrus’ operations over time. Readers are cautioned that the information provided by these metrics, or that can be derived from the metrics presented in this MD&A, should not be relied upon for investment or other purposes.

FD&A Recycle Ratio
The FD&A recycle ratio is calculated by dividing field netback by FD&A.

Management uses oil and gas metrics for its own performance measurements and to provide shareholders with measures to compare Petrus’ operations overtime. Readers are cautioned that the information provided by these metrics, or that can be derived from the metrics presented in this MD&A, should not be relied upon for investment.

ADVISORIES

Basis of Presentation
Financial data presented above has largely been derived from the Company’s financial statements, prepared in accordance with GAAP which require publicly accountable enterprises to prepare their financial statements using IFRS. Accounting policies adopted by the Company are set out in the notes to the consolidated financial statements as at and for the twelve months ended December 31, 2020. The reporting and the measurement currency is the Canadian dollar. All financial information is expressed in Canadian dollars, unless otherwise stated.

Forward-Looking Statements
In particular, forward-looking statements included in this MD&A include, but are not limited to, statements with respect to: Petrus focus on paying down the balance of the RCF; the Company’s focus on optimizing its cost structure, particularly in the Ferrier area, through facility ownership and control; Petrus’ commitment to maintaining its financial flexibility and expectation that it will determine subsequent quarter capital spending as the year progresses; forecast cash flow in 2021 and the use thereof; managements expectation that the 2020 capital plan will be funded by funds flow, with free funds flow used to continue significant debt reduction targets; management expectation that it will continue to layer in hedges; expectations regarding the payout of new wells in the Ferrier area; the drilling 3 gross (2.1 net) Cardium wells under Petrus’ first quarter 2021 capital budget; the Company’s strategy to prioritize debt repayment and moderate capital spending; Petrus’ ability to modify its operations according to NGL market pricing; the intent of the Company’s hedging strategy; expectations regarding the adequacy of Petrus’ liquidity and the funding of its financial liabilities; the impact of the current economic environment on Petrus; the performance characteristics of the Company’s crude oil, NGL and natural gas properties; future prospects; the focus of and timing of capital expenditures; access to debt and equity markets; Petrus’ future operating and financial results; capital investment programs; supply and demand for crude oil, NGL and natural gas; future royalty rates; drilling, development and completion plans and the results therefrom; and treatment under governmental regulatory regimes and tax laws.

In addition, statements relating to “reserves” are deemed to be forward-looking statements, as they involve the implied assessment, based on certain estimates and assumptions, that the reserves described can be profitably produced in the future.

This MD&A contains future-oriented financial information and financial outlook information (collectively, “FOFI”) about Petrus’ prospective results of operations including, without limitation, forecast cash flow in 2021, managements expectation that the 2020 capital plan will be funded by funds flow, expectations regarding the payout of new wells in the Ferrier area, Petrus’ liquidity to execute the Company’s business plan over the coming year and ability to repay debt, which are subject to the same assumptions, risk factors, limitations, and qualifications as set forth above. Readers are cautioned that the assumptions used in the preparation of such information, although considered reasonable at the time of preparation, may prove to be imprecise and, as such, undue reliance should not be placed on FOFI. Petrus’ actual results, performance or achievement could differ materially from those expressed in, or implied by, these FOFI, or if any of them do so, what benefits Petrus will derive therefrom. Petrus has included the FOFI in order to provide readers with a more complete perspective on Petrus’ future operations and such information may not be appropriate for other purposes.

These forward-looking statements and FOFI are made as of the date of this MD&A and the Company disclaims any intent or obligation to update any forward-looking statements and FOFI, whether as a result of new information, future events or results or otherwise, other than as required by applicable securities laws.

BOE Presentation
The oil and natural gas industry commonly expresses production volumes and reserves on a barrel of oil equivalent (“boe”) basis whereby natural gas volumes are converted at the ratio of six thousand cubic feet to one barrel of oil. The intention is to sum oil and natural gas measurement units into one basis for improved measurement of results and comparisons with other industry participants. Petrus uses the 6:1 boe measure which is the approximate energy equivalence of the two commodities at the burner tip. Boe’s do not represent an economic value equivalence at the wellhead and therefore may be a misleading measure if used in isolation.

Abbreviations
$000’s
$/bbl
$/boe
$/GJ
$/mcf
bbl
bbl/d 
boe 
mboe
mmboe
boe/d
GJ
GJ/d
mcf 
mcf/d
mmcf/d
NGLs 
WTI
thousand dollars
dollars per barrel
dollars per barrel of oil equivalent
dollars per gigajoule
dollars per thousand cubic feet
barrel
barrels per day
barrel of oil equivalent
barrel of oil equivalent
thousand barrel of oil equivalent
million barrel of oil equivalent per day
gigajoule
gigajoules per day
thousand cubic feet
thousand cubic feet per day
million cubic feet per day
natural gas liquids
West Texas Intermediate


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