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, 2022 and to provide 2022
year end reserves information as evaluated by Insite Petroleum
Consultants Ltd. ("Insite"). 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.
An updated corporate presentation as well as the
monthly activity update can be found on the Company's website at
www.petrusresources.com.
Q4 2022 HIGHLIGHTS
- Increased
production – Total production increased by 55% to 9,113
boe/d in the fourth quarter of 2022, compared to 5,880 boe/d in the
fourth quarter of 2021. Petrus achieved its exit production rate
averaging 10,635 boe/d(1) during the last week of December
2022.
- Total funds flow up
228% – Petrus generated funds flow(2) and corporate
netback(2) of $34.1 million and $40.70/boe in the fourth quarter of
2022, 228% and 111% higher, respectively, than the fourth quarter
of the prior year.
- Increased capital
activity – Petrus incurred capital expenditures of $37.8
million in the fourth quarter of 2022 compared to $12.2 million in
the fourth quarter of 2021. The Company drilled and completed 6
gross (5.3 net) wells and spent $4.9 million on pipeline, equipment
and facilities.
- Operating netback per boe
up 20% – Operating netback(2) increased by 20% to
$39.84/boe in the fourth quarter of 2022 up from $33.12/boe in the
fourth quarter of 2021, due to significantly higher realized
prices.
- Commodity price
improvement – Petrus' total realized price of $57.81/boe
increased by 25% in the fourth quarter of 2022 compared to the
fourth quarter of 2021 ($46.29/boe) as a result of higher commodity
prices across all products.
2022 ANNUAL HIGHLIGHTS
- Total funds flow up
163% – Petrus generated funds flow and corporate netback
of $87.7 million and $31.60/boe in 2022, 163% and 108% higher,
respectively, than funds flow of $33.4 million and $15.19/boe in
2021. The Company achieved its target funds flow guidance for
2022.
- Successfully executed 2022
capital program – Petrus incurred $96.7 million of capital
expenditures in 2022 (excluding acquisitions and dispositions),
compared to $26.9 million in 2021. 85% of total capital went to
drilling and completion costs related to 21 gross (15.6 net) wells
in Ferrier and North Ferrier, 12% of capital went to pipeline,
equipment and facilities costs, and the remaining capital went to
land and corporate costs. 2022 capital spending was in line with
budget guidance.
- Increased
production – Petrus increased average annual production by
27% from 6,009 boe/d in 2021 to 7,604 boe/d in 2022.
- Debt restructuring
complete – The Company entered into agreements with new
lenders providing two new credit facilities ("New Facilities")
totaling $55 million; at December 31, 2022, $28.9 million was drawn
on the New Facilities. The refinancing completed the Company’s debt
restructuring.
- Net debt reduction
– Net debt(2) was $50.8 million at December 31, 2022, an 18%
decrease from $61.8 million at December 31, 2021. The Company
continues to manage its balance sheet with the goal of maintaining
a net debt to funds flow ratio(2) of under 1x.
- Rights offering –
Petrus closed a $20 million rights offering that was oversubscribed
by 84%.
2023
OUTLOOK(3)
In early January, the Petrus team returned to
drilling in Ferrier to kick off the 2023 capital program. We have
successfully drilled and completed all of the wells on the first
pad site and production associated with these new wells came on in
early March. The rig has moved to the second pad site where
drilling operations are well underway. We expect to complete
drilling by the end of March and we will suspend drilling and
completion operations over spring break-up.
Given the inherent volatility of our
commodity-based business, Petrus has always been committed to being
disciplined and flexible. The Company is continuously evaluating
its 2023 capital program to ensure it meets the investment
threshold to optimize shareholder return. By investing capital
wisely and generating strong cash flow, Petrus aims to ensure the
value of this cash flow is realized by its shareholders. The
Company is now in a position to analyze options available to
maximize shareholder value and is in the process of determining the
optimum way forward.
(1)Disclosure of production on a per boe basis consists of the
constituent product types and their respective
quantities. Refer to "BOE Presentation" and "Production and
Product Type Information" for further details.(2)Non-GAAP measure
or non-GAAP ratio. Refer to "Non-GAAP and Other Financial Measures"
below.(3)Refer to "Advisories - Forward-Looking Statements"
below.
SELECTED FINANCIAL INFORMATION
OPERATIONS |
Twelve months
ended Dec. 31,
2022 |
Twelve months
ended Dec. 31,
2021 |
Three months
ended Dec. 31,
2022 |
Three months
ended Sept. 30,
2022 |
Three months
ended Jun. 30,
2022 |
Three months
ended Mar. 31,
2022 |
Average production |
|
|
|
|
|
|
Natural gas (mcf/d) |
30,441 |
|
23,680 |
|
33,201 |
|
28,107 |
|
30,913 |
|
29,530 |
|
Oil (bbl/d) |
1,436 |
|
1,019 |
|
2,458 |
|
957 |
|
1,073 |
|
1,250 |
|
NGLs (bbl/d) |
1,094 |
|
1,043 |
|
1,121 |
|
997 |
|
1,055 |
|
1,207 |
|
Total (boe/d) |
7,604 |
|
6,009 |
|
9,113 |
|
6,639 |
|
7,280 |
|
7,379 |
|
Total (boe) |
2,775,561 |
|
2,193,432 |
|
838,375 |
|
610,722 |
|
662,456 |
|
664,010 |
|
Light oil weighting |
19 |
% |
17 |
% |
27 |
% |
14 |
% |
15 |
% |
17 |
% |
Realized Prices |
|
|
|
|
|
|
Natural gas ($/mcf) |
6.03 |
|
4.03 |
|
6.04 |
|
5.02 |
|
7.74 |
|
5.20 |
|
Oil ($/bbl) |
113.19 |
|
78.82 |
|
106.85 |
|
111.04 |
|
133.36 |
|
110.12 |
|
NGLs ($/bbl) |
63.26 |
|
44.09 |
|
56.90 |
|
62.25 |
|
74.63 |
|
60.12 |
|
Total realized price ($/boe) |
54.63 |
|
36.90 |
|
57.81 |
|
46.62 |
|
63.33 |
|
49.31 |
|
Royalty income |
0.26 |
|
0.14 |
|
0.15 |
|
0.37 |
|
0.25 |
|
0.29 |
|
Royalty expense |
(8.70 |
) |
(4.72 |
) |
(7.92 |
) |
(11.84 |
) |
(8.64 |
) |
(6.89 |
) |
Loss on risk management activities |
(2.17 |
) |
— |
|
(1.26 |
) |
(0.81 |
) |
(6.76 |
) |
— |
|
Net oil and natural gas revenue ($/boe) |
44.02 |
|
32.32 |
|
48.78 |
|
34.34 |
|
48.18 |
|
42.71 |
|
Operating expense |
(7.45 |
) |
(5.89 |
) |
(6.86 |
) |
(8.47 |
) |
(7.92 |
) |
(6.76 |
) |
Transportation expense |
(2.08 |
) |
(1.79 |
) |
(2.08 |
) |
(1.89 |
) |
(2.16 |
) |
(2.17 |
) |
Operating netback(1) ($/boe) |
34.49 |
|
24.64 |
|
39.84 |
|
23.98 |
|
38.10 |
|
33.78 |
|
Realized gain (loss) on financial derivatives ($/boe) |
(0.58 |
) |
(5.34 |
) |
2.89 |
|
1.00 |
|
— |
|
(6.98 |
) |
Other income (cash) |
0.10 |
|
0.49 |
|
0.22 |
|
0.05 |
|
0.04 |
|
0.07 |
|
General & administrative expense |
(1.22 |
) |
(1.95 |
) |
(1.10 |
) |
(1.30 |
) |
(1.70 |
) |
(0.82 |
) |
Cash finance expense |
(1.14 |
) |
(2.34 |
) |
(1.18 |
) |
(0.87 |
) |
(1.46 |
) |
(1.04 |
) |
Decommissioning expenditures |
(0.05 |
) |
(0.31 |
) |
0.03 |
|
(0.29 |
) |
0.06 |
|
(0.02 |
) |
Funds flow & corporate netback(1)
($/boe) |
31.60 |
|
15.19 |
|
40.70 |
|
22.57 |
|
35.04 |
|
24.99 |
|
|
|
|
|
|
|
|
FINANCIAL (000s except $ per share) |
Twelve months
ended Dec. 31,
2022 |
Twelve months
ended Dec. 31,
2021 |
Three months
ended Dec. 31,
2022 |
Three months
ended Sept. 30,
2022 |
Three months
ended Jun. 30,
2022 |
Three months
ended Mar. 31,
2022 |
Oil and natural gas revenue |
152,350 |
|
81,268 |
|
48,590 |
|
28,701 |
|
42,119 |
|
32,940 |
|
Net income |
60,868 |
|
114,556 |
|
22,097 |
|
9,822 |
|
18,046 |
|
10,903 |
|
Net income per share |
|
|
|
|
|
|
Basic |
0.53 |
|
1.83 |
|
0.18 |
|
0.08 |
|
0.16 |
|
0.11 |
|
Fully diluted |
0.51 |
|
1.76 |
|
0.17 |
|
0.08 |
|
0.15 |
|
0.11 |
|
Funds flow(1) |
87,716 |
|
33,354 |
|
34,117 |
|
13,789 |
|
23,208 |
|
16,601 |
|
Funds flow per share (1) |
|
|
|
|
|
|
Basic |
0.76 |
|
0.53 |
|
0.28 |
|
0.11 |
|
0.21 |
|
0.17 |
|
Fully diluted |
0.73 |
|
0.51 |
|
0.27 |
|
0.11 |
|
0.20 |
|
0.16 |
|
Capital expenditures |
96,744 |
|
26,916 |
|
37,792 |
|
49,513 |
|
4,932 |
|
5,064 |
|
Weighted average shares outstanding |
|
|
|
|
|
|
Basic |
115,189 |
|
62,557 |
|
122,545 |
|
122,058 |
|
111,795 |
|
99,189 |
|
Fully diluted |
119,525 |
|
65,207 |
|
127,600 |
|
126,822 |
|
117,203 |
|
103,250 |
|
As at period
end |
|
|
|
|
|
|
Common shares outstanding |
|
|
|
|
|
|
Basic |
123,239 |
|
96,708 |
|
123,239 |
|
122,197 |
|
122,017 |
|
106,907 |
|
Fully diluted |
133,377 |
|
103,889 |
|
133,377 |
|
131,482 |
|
131,302 |
|
113,883 |
|
Total assets |
381,057 |
|
290,492 |
|
381,057 |
|
356,050 |
|
302,472 |
|
308,744 |
|
Non-current liabilities |
63,021 |
|
42,172 |
|
63,021 |
|
61,778 |
|
50,924 |
|
46,702 |
|
Net debt(1) |
50,808 |
|
61,779 |
|
50,808 |
|
48,465 |
|
13,895 |
|
50,044 |
|
(1) Non-GAAP financial measure or non-GAAP
ratio. Refer to "Non-GAAP and Other Financial Measures".
OPERATIONS UPDATE
Fourth quarter average production by area was as
follows:
For the three months ended December 31, 2022 |
Ferrier |
North Ferrier |
Foothills |
Central Alberta |
Kakwa |
Total |
Natural gas (mcf/d) |
21,198 |
4,498 |
2,360 |
4,993 |
150 |
33,199 |
Oil (bbl/d) |
1,872 |
237 |
81 |
247 |
21 |
2,458 |
NGLs (bbl/d) |
834 |
120 |
7 |
150 |
10 |
1,121 |
Total (boe/d) |
6,239 |
1,107 |
481 |
1,230 |
56 |
9,113 |
Fourth quarter 2022 production averaged 9,113
boe/d compared to 5,880 boe/d in the fourth quarter of 2021. Five
gross (4.6 net) wells were spud in the Ferrier area during the
quarter. Of these, four (3.6 net) wells were completed and on
production by December 31, 2022.
RESERVES
Petrus’ 2022 year end reserves were evaluated by
independent reserves evaluator, InSite Petroleum Consultants Ltd.
("Insite"), 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, 2022 ("2022 Insite Report"). Additional
reserve information as required under NI 51-101 will be included in
our Annual Information Form for the year ended December 31,
2022, 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 a
majority 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 2022 Insite Report.
The following table provides a summary of the
Company’s before tax reserves as evaluated by Insite:
As at December 31, 2022 |
Total Company Interest
(1)(3) |
Reserve Category |
Conventional Natural
Gas(mmcf) |
Light and Medium Crude
Oil(mbbl) |
Condensate NGL(mmbl) |
OtherNGL(mbbl) |
Total(mboe) |
NPV
0%(2)($000s) |
NPV
5%(2)($000s) |
NPV
10%(2)($000s) |
Proved Producing |
73,413 |
958 |
2,311 |
2,305 |
17,809 |
381,134 |
311,376 |
266,264 |
Proved Non-Producing |
1,188 |
— |
30 |
34 |
262 |
4,196 |
2,926 |
2,148 |
Proved
Undeveloped |
90,510 |
2,169 |
2,469 |
3,055 |
22,777 |
327,233 |
210,153 |
139,021 |
Total Proved |
165,111 |
3,127 |
4,810 |
5,394 |
40,848 |
712,562 |
524,456 |
407,433 |
Proved
+ Probable Producing |
89,582 |
1,131 |
2,808 |
2,845 |
21,715 |
483,857 |
366,124 |
300,905 |
Total Probable |
99,966 |
3,107 |
2,065 |
3,332 |
25,164 |
476,819 |
280,470 |
181,937 |
Total Proved Plus Probable |
265,076 |
6,233 |
6,875 |
8,725 |
66,013 |
1,189,381 |
804,925 |
589,370 |
(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 Insite's pricing assumptions. (3)Total company interest reserve
volumes presented above and in the remainder of this press release
are presented as the Company's total working interest before the
deduction of royalties (but after including any royalty interests
of Petrus).
In 2022, Petrus’ development program generated
proved developed producing ("PDP") reserve volume additions of 7.5
mmboe. The Company also produced 2.8 mmboe and acquired 1.4 mmboe
of PDP reserves. The Company ended the year with 17.8 mmboe of PDP
reserves (31% crude oil and liquids).
Petrus ended 2022 with $266.3 million, $407.4
million and $589.4 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 2022 Insite
Report. In 2022, the Company realized Finding, Development and
Acquisition (“FD&A”) costs of $12.50/boe for PDP reserves.
Based on the 2022 Insite Report, the Company’s
PDP reserve value before-tax, discounted at 10% is $2.16 per share
(123,238,528 basic common shares outstanding at December 31,
2022). On the same basis, the P+P reserve value before tax,
discounted at 10%, is $4.78 per share.
FUTURE DEVELOPMENT COSTFuture
Development Cost ("FDC") reflects Insite'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 2022 Insite Report:
Future Development Cost ($000s) |
Total Proved |
Total Proved + Probable |
2023 |
112,557 |
122,732 |
2024 |
119,861 |
177,167 |
2025 |
81,369 |
158,927 |
2026 |
— |
60,998 |
Total FDC, Undiscounted |
313,786 |
519,823 |
Total FDC, Discounted at 10% |
277,551 |
442,376 |
PERFORMANCE RATIOSThe following table
highlights annual performance ratios for the Company from 2018 to
2022(3):
|
December 31, 2022 |
December 31, 2021 |
December 31, 2020 |
December 31, 2019 |
December 31, 2018 |
Proved Producing |
|
|
|
|
|
FD&A ($/boe) (1)(2) |
12.58 |
15.64 |
4.83 |
|
13.31 |
|
37.76 |
F&D ($/boe) (1)(2) |
12.70 |
8.90 |
4.83 |
|
12.81 |
|
42.27 |
Reserve Life Index (yr) (1) |
5.31 |
5.41 |
5.20 |
|
3.80 |
|
4.60 |
Reserve Replacement Ratio (1) |
3.20 |
0.78 |
1.20 |
|
0.40 |
|
0.20 |
FD&A Recycle Ratio (1) |
2.91 |
1.58 |
2.60 |
|
1.20 |
|
0.40 |
Proved Developed |
|
|
|
|
|
FD&A ($/boe) (1)(2) |
12.50 |
14.54 |
4.71 |
|
12.49 |
|
11.34 |
F&D ($/boe) (1)(2) |
12.61 |
8.53 |
4.71 |
|
12.03 |
|
11.55 |
Reserve Life Index (yr) (1) |
5.39 |
5.50 |
5.20 |
|
4.80 |
|
5.60 |
Reserve Replacement Ratio (1) |
3.22 |
0.84 |
1.20 |
|
0.50 |
|
0.60 |
FD&A Recycle Ratio (1) |
2.93 |
1.70 |
2.70 |
|
1.30 |
|
1.40 |
Total Proved |
|
|
|
|
|
FD&A ($/boe) (1)(2) |
18.24 |
10.51 |
1.29 |
|
1.09 |
|
8.73 |
F&D ($/boe) (1)(2) |
33.99 |
9.24 |
1.29 |
|
(6.83 |
) |
8.16 |
Reserve Life Index (yr) (1) |
12.18 |
15.30 |
10.90 |
|
9.90 |
|
11.10 |
Reserve Replacement Ratio (1) |
3.79 |
4.50 |
(1.00 |
) |
0.30 |
|
1.30 |
FD&A Recycle Ratio (1) |
2.01 |
2.35 |
9.80 |
|
14.40 |
|
1.80 |
Future Development Cost (undiscounted) ($000s) |
313,786 |
233,684 |
156,815 |
|
174,027 |
|
194,757 |
Total Proved + Probable |
|
|
|
|
|
FD&A ($/boe) (1)(2) |
15.66 |
10.57 |
0.37 |
|
(7.32 |
) |
6.49 |
F&D ($/boe) (1)(2) |
36.12 |
8.36 |
0.37 |
|
190.21 |
|
5.15 |
Reserve Life Index (yr) (1) |
19.68 |
23.29 |
17.70 |
|
15.40 |
|
17.10 |
Reserve Replacement Ratio (1) |
6.63 |
5.10 |
(1.30 |
) |
— |
|
1.50 |
FD&A Recycle Ratio (1) |
2.34 |
2.33 |
33.70 |
|
(2.10 |
) |
2.40 |
Future Development Cost (undiscounted) ($000s) |
519,823 |
343,489 |
252,335 |
|
267,652 |
|
290,876 |
(1)Refer to "Oil and Gas Disclosures"
below.(2)Certain changes in FD&A costs and F&D costs
produce non-meaningful figures as discussed in "Oil and Gas
Disclosures" below.(3)While FD&A costs and F&D costs,
reserve life index, reserve replacement ratio and FD&A recycle
ratio 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 VALUEThe following
table shows the Company's Net Asset Value ("NAV"), calculated using
the 2022 Insite Report and Insite's December 31, 2022 price
forecast:
As at December 31, 2022 ($000s except per
share) |
Proved Developed Producing |
|
Total Proved |
|
Proved + Probable |
|
Present Value Reserves, before tax (discounted at 10%) (1) |
|
266,264 |
|
|
407,433 |
|
|
589,370 |
|
Undeveloped Land Value
(2) |
|
34,837 |
|
|
34,837 |
|
|
34,837 |
|
Net
Debt (3) |
|
(50,808 |
) |
|
(50,808 |
) |
|
(50,808 |
) |
Net Asset Value |
|
250,293 |
|
|
391,462 |
|
|
573,399 |
|
Fully
Diluted Shares Outstanding |
|
133,377 |
|
|
133,377 |
|
|
133,377 |
|
Estimated Net Asset Value per Fully Diluted
Share |
$1.88 |
|
$2.94 |
|
$4.30 |
|
(1)Based on the 2022 Insite Report, using the
forecast future prices and costs.(2)Based on the exploration and
evaluation assets as per the Company's December 31, 2022 audited
consolidated financial statements.(3)See "Non-GAAP and Other
Financial Measures" below.
ANNUAL GENERAL MEETING The
Company's Annual General Meeting will be held at 240FOURTH
(previously BP Centre) suite 2400 - 240, 4th Ave SW Calgary,
Alberta, on Thursday May 18, 2023 at 1:30 p.m. (Calgary time).
NON-GAAP AND OTHER FINANCIAL
MEASURESThis press release makes reference to the terms
"operating netback" (on an absolute and $/boe basis), "corporate
netback" (on an absolute and $/boe basis), "funds flow" (on an
absolute, per share (basic and fully diluted) and $/boe basis),
"net debt" and "net debt to funds flow ratio". These non-GAAP and
other financial measures are not recognized measures under GAAP
(IFRS) and do not have a standardized meaning prescribed by GAAP
(IFRS). Accordingly, the Company's use of these terms may not be
comparable to similarly defined measures presented by other
companies. These non-GAAP and other financial measures should not
be considered to be more meaningful than GAAP measures which are
determined in accordance with IFRS as indicators of our
performance. Management uses these non-GAAP and other financial
measures for the reasons set forth below.
Operating NetbackOperating
netback is a common non-GAAP financial measure used in the oil and
natural gas industry which is a useful supplemental measure to
evaluate the specific operating performance by product type at the
oil and natural gas lease level. The most directly comparable GAAP
measure to operating netback is oil and natural gas revenue.
Operating netback is calculated as oil and natural gas revenue less
royalty expenses, operating expenses, transportation expenses and
loss on risk management activities. See below for a reconciliation
of operating netback to oil and natural gas revenue.
Operating netback ($/boe) is a non-GAAP ratio
used in the oil and natural gas industry which is a useful
supplemental measure to evaluate the specific operating performance
by product type at the oil and natural gas lease level. It is
calculated as operating netbacks divided by weighted average daily
production on a per boe basis. See below.
Corporate Netback and Funds
FlowCorporate netback or funds flow 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 and funds flow are used interchangeably. Petrus
analyzes these measures on an absolute value and on a per unit
(boe) and per share (basic and fully diluted) basis as non-GAAP
ratios. 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. They
are calculated as the operating netback less general and
administrative expense, cash finance expense, decommissioning
expenditures, plus other income and the net realized gain (loss) on
financial derivatives and risk management activities. See below for
a reconciliation of funds flow and corporate netback to oil and
natural gas revenue.
Corporate netback ($/boe) or funds flow ($/boe)
is a non-GAAP ratio used in the oil and natural gas industry which
evaluates the Company’s profitability at the corporate level.
Management believes that funds flow ($/boe) or corporate netback
($/boe) provide information to assist a reader in understanding the
Company's profitability relative to current commodity prices. It is
calculated as corporate netbacks or funds flow divided by weighted
average daily production on a per boe basis. See below.
Funds flow per share (basic and fully diluted)
is comprised of funds flow divided by basic or fully diluted
weighted average common shares outstanding.
|
Three months
ended December 31,
2022 |
Three months
ended December 31,
2021 |
Twelve months
ended December 31,
2022 |
Twelve months
ended December 31,
2021 |
|
$000s |
$/boe |
$000s |
$/boe |
$000s |
$/boe |
$000s |
$/boe |
Oil and natural gas revenue |
48,590 |
|
57.96 |
|
25,070 |
|
46.35 |
|
152,350 |
|
54.89 |
|
81,268 |
|
37.04 |
|
Royalty expense |
(6,636 |
) |
(7.92 |
) |
(3,429 |
) |
(6.34 |
) |
(24,161 |
) |
(8.70 |
) |
(10,361 |
) |
(4.72 |
) |
Loss on
risk management activities |
(1,056 |
) |
(1.26 |
) |
— |
|
— |
|
(6,029 |
) |
(2.17 |
) |
— |
|
— |
|
Net oil and natural gas revenue |
40,898 |
|
48.78 |
|
21,641 |
|
40.01 |
|
122,160 |
|
44.02 |
|
70,907 |
|
32.32 |
|
Transportation expense |
(1,743 |
) |
(2.08 |
) |
(1,010 |
) |
(1.87 |
) |
(5,772 |
) |
(2.08 |
) |
(3,920 |
) |
(1.79 |
) |
Operating expense |
(5,753 |
) |
(6.86 |
) |
(2,715 |
) |
(5.02 |
) |
(20,665 |
) |
(7.45 |
) |
(12,914 |
) |
(5.89 |
) |
Operating netback |
33,402 |
|
39.84 |
|
17,916 |
|
33.12 |
|
95,723 |
|
34.49 |
|
54,073 |
|
24.64 |
|
Realized gain (loss) on financial derivatives |
2,421 |
|
2.89 |
|
(5,148 |
) |
(9.52 |
) |
(1,601 |
) |
(0.58 |
) |
(11,713 |
) |
(5.34 |
) |
Other income(1) |
186 |
|
0.22 |
|
21 |
|
0.04 |
|
291 |
|
0.10 |
|
1,075 |
|
0.49 |
|
General & administrative
expense |
(926 |
) |
(1.10 |
) |
(1,213 |
) |
(2.24 |
) |
(3,389 |
) |
(1.22 |
) |
(4,274 |
) |
(1.95 |
) |
Cash finance expense(2) |
(987 |
) |
(1.18 |
) |
(856 |
) |
(1.58 |
) |
(3,171 |
) |
(1.14 |
) |
(5,133 |
) |
(2.34 |
) |
Decommissioning expenditures |
21 |
|
0.03 |
|
(302 |
) |
(0.56 |
) |
(137 |
) |
(0.05 |
) |
(674 |
) |
(0.31 |
) |
Funds flow and corporate netback |
34,117 |
|
40.70 |
|
10,418 |
|
19.26 |
|
87,716 |
|
31.60 |
|
33,354 |
|
15.19 |
|
(1)Excludes non-cash government grant related to decommissioning
expenditures.(2)Excludes non-cash Term Loan interest
payment-in-kind.
Net debt is a non-GAAP financial measure and is
calculated as the sum of long term debt and working capital
(current assets and current liabilities), excluding the current
financial derivative contracts and current portion of the lease
obligation. Petrus uses net debt as a key indicator of its leverage
and strength of its balance sheet. Net debt is reconciled, in the
table below, to long-term debt which is the most directly
comparable GAAP measure.
($000s) |
As at December 31, 2022 |
As at September 30, 2022 |
As at June 30, 2022 |
As at March 31, 2022 |
Long-term debt |
25,000 |
|
22,000 |
|
12,000 |
|
— |
|
Current assets |
(29,849 |
) |
(29,905 |
) |
(18,783 |
) |
(17,356 |
) |
Current liabilities |
51,395 |
|
51,102 |
|
18,785 |
|
67,625 |
|
Current financial
derivatives |
4,502 |
|
5,503 |
|
2,124 |
|
— |
|
Current
portion of lease obligation |
(240 |
) |
(235 |
) |
(231 |
) |
(225 |
) |
Net debt |
50,808 |
|
48,465 |
|
13,895 |
|
50,044 |
|
Net debt to funds flow ratio is a non-GAAP ratio
used as a key indicator of our leverage and strength of our balance
sheet. It is calculated as net debt divided by funds flow for the
relevant period.
OIL AND GAS DISCLOSURESOur oil
and gas reserves statement for the year ended December 31, 2022,
which includes disclosure of our oil and natural gas reserves and
other oil and natural gas information in accordance with NI 51-101,
will be contained in our Annual Information Form for the year ended
December 31, 2022, which will be filed on SEDAR at
www.sedar.com.
It should not be assumed that the present worth
of estimated future amounts presented in the tables above
represents the fair market value of the reserves. There is no
assurance that the forecast prices and costs assumptions will be
attained, and variances could be material. The recovery and reserve
estimates contained herein are estimates only and there is no
guarantee that the estimated reserves will be recovered. Actual
reserves may be greater than or less than the estimates provided
herein.
This press release contains metrics commonly
used in the oil and natural gas industry which 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. 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 press release, should not be
relied upon for investment or other purposes.
F&D Costs and FD&A
CostsFD&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 costs 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 2021 and 2022, the P+P FD&A costs
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 IndexReserve life
index is defined as total reserves by category divided by the
annualized fourth quarter production.
Reserve Replacement RatioThe
reserve replacement ratio is calculated by dividing the yearly
change in reserves net of production by the actual annual
production for the year.
FD&A Recycle RatioThe
FD&A recycle ratio is calculated by dividing operating netback
by FD&A.
BOE PresentationThe 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.
Production and Product Type
InformationThe Company's 2022 exit production rate average
during the last week of December 2022 disclosed in this press
release consist of the following product types, as defined in
National Instrument 51-101 and using the conversion ratio described
above, where applicable: 10,635 boe/d 2022 exit production rate –
25% light oil and condensate, 13% natural gas liquids and 62%
conventional natural gas.
ADVISORIES
Basis of PresentationFinancial
data presented above has largely been derived from the Company’s
financial statements, prepared in accordance with Canadian
generally accepted accounting principles ("GAAP") which require
publicly accountable enterprises to prepare their financial
statements using International Financial Reporting Standards
("IFRS"). Accounting policies adopted by the Company are set out in
the notes to the audited consolidated financial statements as at
and for the twelve months ended December 31, 2022. The reporting
and the measurement currency is the Canadian dollar. All financial
information is expressed in Canadian dollars, unless otherwise
stated.
Forward-Looking
StatementsCertain information regarding Petrus set forth
in this news release contains forward-looking statements within the
meaning of applicable securities law, that involve substantial
known and unknown risks and uncertainties. The use of any of the
words “anticipate”, “continue”, “estimate”, “expect”, “may”,
“will”, “project”, “should”, “believe” and similar expressions are
intended to identify forward-looking statements. Such statements
represent Petrus’ internal projections, estimates, beliefs, plans,
objectives, assumptions, intentions or statements about future
events or performance. These statements are only predictions and
actual events or results may differ materially. Although Petrus
believes that the expectations reflected in the forward-looking
statements are reasonable, it cannot guarantee future results,
levels of activity, performance or achievement since such
expectations are inherently subject to significant business,
economic, competitive, political and social uncertainties and
contingencies. Many factors could cause Petrus’ actual results to
differ materially from those expressed or implied in any
forward-looking statements made by, or on behalf of, Petrus.
In particular, forward-looking statements
included in this press release include, but are not limited to,
statements with respect to: our intention to continue to manage our
balance sheet with the goal of maintaining a net debt to funds flow
ratio of under 1x; our expectations for our drilling and completion
operations through spring break-up; and the forecast for the future
development costs required to bring our reserves on production. 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.
These forward-looking statements are subject to
numerous risks and uncertainties, most of which are beyond the
Company’s control, including: the impact of general economic
conditions; volatility in market prices for crude oil, NGL and
natural gas; industry conditions; currency fluctuation; changes in
interest rates and inflation rates; imprecision of reserve
estimates; liabilities inherent in crude oil and natural gas
operations; environmental risks; incorrect assessments of the value
of acquisitions and exploration and development programs;
competition; the lack of availability of qualified personnel or
management; changes in income tax laws or changes in tax laws and
incentive programs relating to the oil and gas industry; hazards
such as fire, explosion, blowouts, cratering, and spills, each of
which could result in substantial damage to wells, production
facilities, other property and the environment or in personal
injury; stock market volatility; ability to access sufficient
capital from internal and external sources; and the other risks and
uncertainties described in our annual information form. With
respect to forward-looking statements contained in this press
release, Petrus has made assumptions regarding: future commodity
prices (including as disclosed herein) and royalty regimes;
availability of skilled labour; timing and amount of capital
expenditures; future exchange rates; the impact of increasing
competition; conditions in general economic and financial markets;
availability of drilling and related equipment and services;
effects of regulation by governmental agencies; the effects of
inflation on our costs and profitability; future interest rates;
and future operating costs. Management has included the above
summary of assumptions and risks related to forward-looking
information provided in this press release in order to provide
investors with a more complete perspective on Petrus’ future
operations and such information may not be appropriate for other
purposes. Petrus’ actual results, performance or achievement could
differ materially from those expressed in, or implied by, these
forward-looking statements and, accordingly, no assurance can be
given that any of the events anticipated by the forward-looking
statements will transpire or occur, or if any of them do so, what
benefits that the Company will derive therefrom. Readers are
cautioned that the foregoing lists of factors are not
exhaustive.
This press release contains future-oriented
financial information and financial outlook information
(collectively, "FOFI") about Petrus' prospective results of
operations including, without limitation, its forecasts for: net
debt to funds flow ratio; 2023 capital budget range; and 2023
average daily production rate range; 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 press release 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.
Abbreviations |
|
$000’s |
thousand dollars |
$/bbl |
dollars per barrel |
$/boe |
dollars per barrel of oil equivalent |
$/GJ |
dollars per gigajoule |
$/mcf |
dollars per thousand cubic feet |
bbl |
barrel |
bbl/d |
barrels per day |
boe |
barrel of oil equivalent |
mboe |
thousand barrel of oil equivalent |
mmboe |
million barrel of oil equivalent |
boe/d |
barrel of oil equivalent per day |
GJ |
gigajoule |
GJ/d |
gigajoules per day |
mcf |
thousand cubic feet |
mcf/d |
thousand cubic feet per day |
mmcf/d |
million cubic feet per day |
NGLs |
natural gas liquids |
WTI |
West Texas Intermediate |
For further information, please contact:
Ken Gray, P.Eng.
President and Chief Executive Officer
T: (403) 930-0889
E: kgray@petrusresources.com
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