Source: GlobeNewswire (MIL-OSI)
CALGARY, Alberta, May 08, 2025 (GLOBE NEWSWIRE) — Parex Resources Inc. (“Parex” or the “Company”) (TSX: PXT) is pleased to announce its financial and operating results for the three-month period ended March 31, 2025, the declaration of its Q2 2025 regular dividend of C$0.385 per share, as well as an operational update. All amounts herein are in United States Dollars (“USD”) unless otherwise stated.
“We entered the year with a disciplined and diversified plan aimed at delivering steady performance, and given current market volatility, are focused on sustaining base production and maintaining flexibility,” commented Imad Mohsen, President & Chief Executive Officer.
“After a measured first quarter, drilling activity is increasing consistent with our budget. The recent tuck-in acquisition of LLA-32, an asset integral to our development plans, along with encouraging exploration results, represent key milestones that will drive near-term production. While we are well-positioned to deliver a strong second half, we will closely monitor commodity prices and our capital allocation throughout the year to maximize shareholder value.”
Key Highlights
- Generated Q1 2025 funds flow provided by operations (“FFO”)(1) of $122 million and FFO per share(2)(3) of $1.24.
- Tracking to deliver FY 2025 average production guidance of 43,000 to 47,000 boe/d; YTD 2025 average production is approximately 43,100 boe/d(5)(7), with plans intact for a growing H2 2025 production profile.
- Positive initial results at two prospects in the Southern Llanos, which are driving near-field exploration momentum.
- Capital expenditure(6) guidance for FY 2025 remains at $285 to $315 million, though the Company continues to monitor commodity prices and could revise lower if warranted by market conditions.
- Executed a tuck-in acquisition of the remaining working interest at LLA-32 for total consideration of $16 million.
Q1 2025 Results
- Average oil & natural gas production was 43,658 boe/d(7).
- Realized net income of $81 million or $0.82 per share basic(3).
- Generated FFO(1) of $122 million and FFO per share(2)(3) of $1.24.
- Current taxes were $12 million; at current Brent crude oil strip pricing, the Company expects its FY 2025 effective current tax rate to be 0-3%.
- Produced an operating netback(2) of $39.40/boe and an FFO netback(2) of $30.90/boe from an average Brent price of $74.98/bbl.
- Incurred $57 million of capital expenditures(6), primarily from activities at Cabrestero, Capachos, and LLA-34.
- Generated $65 million of free funds flow(6) that was used for return of capital initiatives, $10 million of bank debt repayment and increasing working capital surplus(1); working capital surplus(1) was $69 million and cash $81 million at quarter end.
- Paid a C$0.385 per share(4) regular quarterly dividend and repurchased 524,900 shares.
(1) Capital management measure. See “Non-GAAP and Other Financial Measures Advisory.”
(2) Non-GAAP ratio. See “Non-GAAP and Other Financial Measures Advisory.”
(3) Based on weighted average basic shares for the period.
(4) Supplementary financial measure. See “Non-GAAP and Other Financial Measures Advisory.”
(5) Based on Q1 2025 actuals and estimated April 2025 average production; rounded for presentation purposes.
(6) Non-GAAP financial measure. See “Non-GAAP and Other Financial Measures Advisory.”
(7) See “Operational and Financial Highlights” for a breakdown of production by product type.
| Operational and Financial Highlights |
Three Months Ended |
| (unaudited) |
Mar. 31, |
Mar. 31, |
Dec. 31, |
| |
2025 |
2024 |
2024 |
| Operational |
|
|
|
| Average daily production |
|
|
|
| Light Crude Oil and Medium Crude Oil (bbl/d) |
10,650 |
|
7,237 |
|
9,550 |
|
| Heavy Crude Oil (bbl/d) |
32,207 |
|
45,543 |
|
34,882 |
|
| Crude Oil (bbl/d) |
42,857 |
|
52,780 |
|
44,432 |
|
| Conventional Natural Gas (mcf/d) |
4,806 |
|
3,348 |
|
5,190 |
|
| Oil & Gas (boe/d)(1) |
43,658 |
|
53,338 |
|
45,297 |
|
| |
|
|
|
| Operating netback ($/boe) |
|
|
|
| Reference price – Brent ($/bbl) |
74.98 |
|
81.87 |
|
74.01 |
|
| Oil & gas sales(4) |
67.29 |
|
70.80 |
|
63.73 |
|
| Royalties(4) |
(9.22 |
) |
(11.21 |
) |
(9.43 |
) |
| Net revenue(4) |
58.07 |
|
59.59 |
|
54.30 |
|
| Production expense(4) |
(14.41 |
) |
(12.64 |
) |
(15.53 |
) |
| Transportation expense(4) |
(4.26 |
) |
(3.40 |
) |
(3.87 |
) |
| Operating netback ($/boe)(2) |
39.40 |
|
43.55 |
|
34.90 |
|
| |
|
|
|
| Funds flow provided by operations netback ($/boe)(2) |
30.90 |
|
31.32 |
|
32.39 |
|
| |
|
|
|
| Financial ($000s except per share amounts) |
|
|
|
| |
|
|
|
| Net income |
80,629 |
|
60,093 |
|
(69,051 |
) |
| Per share – basic(6) |
0.82 |
|
0.58 |
|
(0.70 |
) |
| |
|
|
|
| Funds flow provided by operations(5) |
121,944 |
|
148,307 |
|
141,201 |
|
| Per share – basic(2)(6) |
1.24 |
|
1.43 |
|
1.43 |
|
| |
|
|
|
| Capital expenditures(3) |
57,054 |
|
85,421 |
|
82,110 |
|
| |
|
|
|
| Free funds flow(3) |
64,890 |
|
62,886 |
|
59,091 |
|
| |
|
|
|
| EBITDA(3) |
139,032 |
|
192,078 |
|
(10,419 |
) |
| Adjusted EBITDA(3) |
135,407 |
|
188,228 |
|
137,312 |
|
| |
|
|
|
| Long-term inventory expenditures |
(4,648 |
) |
3,843 |
|
(2,569 |
) |
| |
|
|
|
| Dividends paid |
26,365 |
|
28,531 |
|
26,658 |
|
| Per share – Cdn$(4)(6) |
0.385 |
|
0.375 |
|
0.385 |
|
| |
|
|
|
| Shares repurchased |
5,239 |
|
15,291 |
|
16,408 |
|
| Number of shares repurchased (000s) |
525 |
|
920 |
|
1,692 |
|
| |
|
|
|
| Outstanding shares (end of period) (000s) |
|
|
|
| Basic |
97,814 |
|
102,914 |
|
98,339 |
|
| Weighted average basic |
98,115 |
|
103,474 |
|
99,063 |
|
| Diluted(8) |
99,105 |
|
103,829 |
|
99,238 |
|
| |
|
|
|
| Working capital surplus (deficit)(5) |
69,040 |
|
55,901 |
|
59,397 |
|
| Bank debt(7) |
50,000 |
|
60,000 |
|
60,000 |
|
| Cash |
81,025 |
|
61,052 |
|
98,022 |
|
(1) Reference to crude oil or natural gas in the above table and elsewhere in this press release refer to the light and medium crude oil and heavy crude oil and conventional natural gas, respectively, product types as defined in National Instrument 51-101 – Standards of Disclosure for Oil and Gas Activities.
(2) Non-GAAP ratio. See “Non-GAAP and Other Financial Measures Advisory”.
(3) Non-GAAP financial measure. See “Non-GAAP and Other Financial Measures Advisory”.
(4) Supplementary financial measure. See “Non-GAAP and Other Financial Measures Advisory”.
(5) Capital management measure. See “Non-GAAP and Other Financial Measures Advisory”.
(6) Per share amounts (with the exception of dividends) are based on weighted average common shares.
(7) Borrowing limit of $240.0 million as of March 31, 2025.
(8) Diluted shares as stated include common shares and stock options outstanding at period-end. The March 31, 2025 closing stock price was C$13.42 per share.
LLA-32 Tuck-In Acquisition
On March 14, 2025, Parex executed a tuck-in acquisition for the remaining working interest at LLA-32 for total consideration of $16 million. LLA-32 is located to the north and adjacent to the Company’s core LLA-34 and Cabrestero blocks.
The strategic rationale for the acquisition was to gain full control of the asset, grow production, expand inventory, and add low-cost recompletion opportunities.
Following the close of the acquisition, Parex started a workover program with positive results thus far, and in Q2 2025, initiated a five-well development campaign. Current production from LLA-32 is roughly 4,000 boe/d(1).
Operational Update
2025 Corporate Guidance & Outlook
While Parex’s 2025 corporate guidance of average production of 43,000 to 47,000 boe/d and capital expenditures of $285 to $315 million remains unchanged as previously disclosed, the Company is closely monitoring oil price volatility to ensure that project economics remain robust.
Given the conventional nature of Parex’s business and the structure of its drilling and service contracts, optionality exists to adjust activity levels in response to prevailing market conditions in order to ensure efficient capital allocation and maximization of shareholder value.
For Q2 2025, average production is expected to be similar to Q1 2025, supported by increased development activity and preliminary near-field exploration success.
Operational Update
Average production for Q1 2025 of 43,658 boe/d(2) was in line with Management expectations. The quarter progressed steadily, which is aligned with the Company’s activity plan to support a growing H2 2025 production profile, as previously disclosed.
April 2025 average production was 41,400 boe/d(3), with production generally consistent with lower activity levels and modest capital outlay in Q1 2025, as well as higher than budgeted downtime due to weather factors. Downtime levels have normalized and initial average production rates in May are roughly 43,200 boe/d(4).
With budgeted activity underway, operational momentum is expected to build through the remainder of the year. Parex currently has three drilling rigs operating (two operated and one non-operated). In addition to enhanced oil recovery initiatives at Cabrestero and LLA-34, activity for Q2 2025 is primarily focused on development wells that are planned to be sequential in nature and located on existing pads that enable efficient production across parallel operations.
Near-Term Development Activity
- Drilling at LLA-34 that is expected to continue through Q2 2025, resulting in the expected completion of six in-fill wells;
- Commencing operations at LLA-32, with the first well of the campaign to be completed in late Q2 2025; and
- Achieving initial access in the Putumayo, with activity starting with a workover rig in Q2 2025.
Near-Field Exploration Program plus Follow-Up Drilling
As part of this program, two separate prospects have yielded positive initial results in the Southern Llanos, where operations are ongoing:
- On LLA-74, a prospect was drilled successfully.
- Initial production began in early May, with current output of approximately 1,200 bbl/d of heavy crude oil(5).
- Also on LLA-74, a prospect was drilled via a vertical well.
- Based on management’s positive initial assessment, the program has progressed with the design of two horizontal wells to optimize production and recovery.
- The first follow-up horizontal well is currently being drilled, with expected production in late May.
(1) Estimated average production for April 1, 2025 to April 30, 2025; light & medium crude oil: ~3,409 bbl/d, conventional natural gas: ~3,544 mcf/d; rounded for presentation purposes.
(2) See “Operational and Financial Highlights” for a breakdown of production by product type.
(3) Estimated average production for April 1, 2025 to April 30, 2025; light & medium crude oil: ~10,099 bbl/d, heavy crude oil: ~30,541 bbl/d, conventional natural gas: ~4,557 mcf/d; rounded for presentation purposes.
(4) Estimated average production for May 1, 2025 to May 6, 2025; light & medium crude oil: ~10,538 bbl/d, heavy crude oil: ~31,869 bbl/d, conventional natural gas: ~4,756 mcf/d; rounded for presentation purposes.
(5) Short-term production rate. See “Oil & Gas Matters Advisory.”
Risk Management
For Q1 2025, Parex entered into a Brent crude oil hedge to manage price risk on approximately 25% of planned net crude oil production, utilizing a Brent put spread at $60/bbl and $70/bbl. For Q2 2025, Parex entered into similar hedges for the months of April 2025 and May 2025.
Parex plans to regularly evaluate market conditions, operational requirements, and other pertinent factors, to assess the need for any additional hedging actions as it progresses through 2025.
Return of Capital Update
Q2 2025 Dividend
Parex’s Board of Directors have approved a Q2 2025 regular dividend of C$0.385 per share to shareholders of record on June 9, 2025, to be paid on June 16, 2025. This regular dividend payment to shareholders is designated as an “eligible dividend” for purposes of the Income Tax Act (Canada).
Normal Course Issuer Bids
In 2025, Parex has repurchased approximately 0.7 million shares under its NCIBs, for total consideration of roughly C$10 million.
Q1 2025 Results – Conference Call & Webcast
Parex will host a conference call and webcast to discuss its Q1 2025 results on Thursday, May 8, 2025, beginning at 9:30 am MT (11:30 am ET). To participate in the conference call or webcast, please see the access information below:
Conference ID: 5403995
Participant Toll-Free Dial-In Number: 1-646-307-1963
Participant Dial-In Number: 1-647-932-3411
Webcast: https://events.q4inc.com/attendee/867962059
Annual General Meeting
On Thursday, May 8, 2025, Parex will hold its Annual General Meeting at 11:00 am MT (1:00 pm ET) both in-person and virtually. Participants may attend at the 4th Floor Conference Center, Eight Avenue Place, East Tower, 525, 8th Ave SW, Calgary, Alberta – and virtual participants can join through the following link: https:meetnow.global/M4SULLK.
Additional information regarding the Annual General Meeting, including meeting materials, can be found at www.parexresources.com under Investors.
About Parex Resources Inc.
Parex is one of the largest independent oil and gas companies in Colombia, focusing on sustainable conventional production. The Company’s corporate headquarters are in Calgary, Canada, with an operating office in Bogotá, Colombia. Parex shares trade on the Toronto Stock Exchange under the symbol PXT.
For more information, please contact:
Mike Kruchten
Senior Vice President, Capital Markets & Corporate Planning
Parex Resources Inc.
403-517-1733
investor.relations@parexresources.com
Steven Eirich
Senior Investor Relations & Communications Advisor
Parex Resources Inc.
587-293-3286
investor.relations@parexresources.com
NOT FOR DISTRIBUTION OR FOR DISSEMINATION IN THE UNITED STATES
Non-GAAP and Other Financial Measures Advisory
This press release uses various “non-GAAP financial measures”, “non-GAAP ratios”, “supplementary financial measures” and “capital management measures” (as such terms are defined in NI 52-112), which are described in further detail below. Such measures are not standardized financial measures under IFRS and might not be comparable to similar financial measures disclosed by other issuers. Investors are cautioned that non-GAAP financial measures should not be construed as alternatives to or more meaningful than the most directly comparable GAAP measures as indicators of Parex’s performance.
These measures facilitate management’s comparisons to the Company’s historical operating results in assessing its results and strategic and operational decision-making and may be used by financial analysts and others in the oil and natural gas industry to evaluate the Company’s performance. Further, management believes that such financial measures are useful supplemental information to analyze operating performance and provide an indication of the results generated by the Company’s principal business activities.
Set forth below is a description of the non-GAAP financial measures, non-GAAP ratios, supplementary financial measures and capital management measures used in this press release.
Non-GAAP Financial Measures
Capital expenditures, is a non-GAAP financial measure which the Company uses to describe its capital costs associated with oil and gas expenditures. The measure considers both property, plant and equipment expenditures and exploration and evaluation asset expenditures which are items in the Company’s statement of cash flows for the period and is calculated as follows:
| |
For the three months ended |
| |
Mar. 31, |
|
Mar. 31, |
|
Dec. 31, |
| ($000s) |
|
2025 |
|
|
2024 |
|
|
2024 |
| Property, plant and equipment expenditures |
$ |
44,951 |
|
$ |
40,831 |
|
$ |
62,799 |
| Exploration and evaluation expenditures |
|
12,103 |
|
|
44,590 |
|
|
19,311 |
| Capital expenditures |
$ |
57,054 |
|
$ |
85,421 |
|
$ |
82,110 |
Free funds flow, is a non-GAAP financial measure that is determined by funds flow provided by operations less capital expenditures. The Company considers free funds flow to be a key measure as it demonstrates Parex’s ability to fund return of capital, such as the normal course issuer bid and dividends, without accessing outside funds and is calculated as follows:
| |
For the three months ended |
| |
Mar. 31, |
|
Mar. 31, |
|
Dec. 31, |
| ($000s) |
|
2025 |
|
|
2024 |
|
|
2024 |
| Cash provided by operating activities |
$ |
87,621 |
|
$ |
97,412 |
|
$ |
67,847 |
| Net change in non-cash assets and liabilities |
|
34,323 |
|
|
50,895 |
|
|
73,354 |
| Funds flow provided by operations |
|
121,944 |
|
|
148,307 |
|
|
141,201 |
| Capital expenditures |
|
57,054 |
|
|
85,421 |
|
|
82,110 |
| Free funds flow |
$ |
64,890 |
|
$ |
62,886 |
|
$ |
59,091 |
EBITDA, is a non-GAAP financial measure that is defined as net income (loss) adjusted for finance income and expenses, other expenses, income tax expense (recovery) and depletion, depreciation and amortization.
Adjusted EBITDA, is a non-GAAP financial measure defined as EBITDA adjusted for non-cash impairment charges, share-based compensation expense (recovery), unrealized foreign exchange gains (losses) and unrealized gains (losses) on risk management contracts.
The Company considers EBITDA and Adjusted EBITDA to be key measures as they demonstrate Parex’s profitability before finance income and expenses, taxes, depletion, depreciation and amortization and other non-cash items. A reconciliation from net income to EBITDA and Adjusted EBITDA is as follows:
| |
For the three months ended |
| |
Mar. 31, |
|
Mar. 31, |
|
Dec. 31, |
| ($000s) |
|
2025 |
|
|
2024 |
|
|
2024 |
| Net income (loss) |
$ |
80,629 |
|
|
$ |
60,093 |
|
|
$ |
(69,051 |
) |
| Adjustments to reconcile net income (loss) to EBITDA: |
|
|
|
|
|
| Finance income |
|
(1,297 |
) |
|
|
(1,257 |
) |
|
|
(998 |
) |
| Finance expense |
|
5,056 |
|
|
|
4,455 |
|
|
|
4,318 |
|
| Other expenses |
|
1,147 |
|
|
|
739 |
|
|
|
2,208 |
|
| Income tax expense (recovery) |
|
3,078 |
|
|
|
75,817 |
|
|
|
(880 |
) |
| Depletion, depreciation and amortization |
|
50,419 |
|
|
|
52,231 |
|
|
|
53,984 |
|
| EBITDA |
$ |
139,032 |
|
|
$ |
192,078 |
|
|
$ |
(10,419 |
) |
| Non-cash impairment charges |
|
— |
|
|
|
— |
|
|
|
137,841 |
|
| Share-based compensation expense (recovery) |
|
2,092 |
|
|
|
(2,463 |
) |
|
|
6,149 |
|
| Unrealized foreign exchange (gain) loss |
|
(4,919 |
) |
|
|
(1,387 |
) |
|
|
2,581 |
|
| Unrealized (gain) loss on risk management contracts |
|
(798 |
) |
|
|
— |
|
|
|
1,160 |
|
| Adjusted EBITDA |
$ |
135,407 |
|
|
$ |
188,228 |
|
|
$ |
137,312 |
|
Non-GAAP Ratios
Operating netback per boe, is a non-GAAP ratio that the Company considers to be a key measure as it demonstrates Parex’ profitability relative to current commodity prices. Parex calculates operating netback per boe as operating netback (calculated as oil and natural gas sales from production, less royalties, operating, and transportation expense) divided by the total equivalent sales volume including purchased oil volumes for oil and natural gas sales price and transportation expense per boe and by the total equivalent sales volume excluding purchased oil volumes for royalties and operating expense per boe.
Funds flow provided by operations netback per boe or FFO netback per boe, is a non-GAAP ratio that includes all cash generated from operating activities and is calculated before changes in non-cash assets and liabilities, divided by produced oil and natural gas sales volumes. The Company considers funds flow provided by operations netback per boe to be a key measure as it demonstrates Parex’s profitability after all cash costs relative to current commodity prices.
Basic funds flow provided by operations per share or FFO per share, is a non-GAAP ratio that is calculated by dividing funds flow provided by operations by the weighted average number of basic shares outstanding. Parex presents basic funds flow provided by operations per share whereby per share amounts are calculated using weighted-average shares outstanding, consistent with the calculation of earnings per share. The Company considers basic funds flow provided by operations per share or FFO per share to be a key measure as it demonstrates Parex’s profitability after all cash costs relative to the weighted average number of basic shares outstanding.
Capital Management Measures
Funds flow provided by operations, is a capital management measure that includes all cash generated from operating activities and is calculated before changes in non-cash assets and liabilities. The Company considers funds flow provided by operations to be a key measure as it demonstrates Parex’s profitability after all cash costs. A reconciliation from cash provided by operating activities to funds flow provided by operations is as follows:
| |
For the three months ended |
| |
Mar. 31, |
|
Mar. 31, |
|
Dec. 31, |
| ($000s) |
|
2025 |
|
|
2024 |
|
|
2024 |
| Cash provided by operating activities |
$ |
87,621 |
|
$ |
97,412 |
|
$ |
67,847 |
| Net change in non-cash assets and liabilities |
|
34,323 |
|
|
50,895 |
|
|
73,354 |
| Funds flow provided by operations |
$ |
121,944 |
|
$ |
148,307 |
|
$ |
141,201 |
Working capital surplus, is a capital management measure which the Company uses to describe its liquidity position and ability to meet its short-term liabilities. Working capital surplus is defined as current assets less current liabilities.
| |
For the three months ended |
| |
Mar. 31, |
|
Mar. 31, |
|
Dec. 31, |
| ($000s) |
|
2025 |
|
|
2024 |
|
|
2024 |
| Current assets |
$ |
259,256 |
|
$ |
276,113 |
|
$ |
245,943 |
| Current liabilities |
|
190,216 |
|
|
220,212 |
|
|
186,546 |
| Working capital surplus |
$ |
69,040 |
|
$ |
55,901 |
|
$ |
59,397 |
Supplementary Financial Measures
“Oil and natural gas sales price per boe” is comprised of total commodity sales from oil and natural gas production, as determined in accordance with IFRS, divided by the total oil and natural gas sales volumes including purchased oil volumes.
“Royalties per boe” is comprised of royalties, as determined in accordance with IFRS, divided by the total equivalent sales volume and excludes purchased oil volumes.
“Net revenue per boe” is comprised of net revenue, as determined in accordance with IFRS, divided by the total equivalent sales volume and includes purchased oil volumes.
“Production expense per boe” is comprised of production expense, as determined in accordance with IFRS, divided by the total equivalent sales volume and excludes purchased oil volumes.
“Transportation expense per boe” is comprised of transportation expense, as determined in accordance with IFRS, divided by the total equivalent sales volumes including purchased oil volumes.
“Dividends paid per share” is comprised of dividends declared, as determined in accordance with IFRS, divided by the number of shares outstanding at the dividend record date.
Oil & Gas Matters Advisory
The term “Boe” means a barrel of oil equivalent on the basis of 6 Mcf of natural gas to 1 barrel of oil (“bbl”). Boe’s may be misleading, particularly if used in isolation. A boe conversation ratio of 6 Mcf: 1 Bbl 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 the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6 Mcf: 1Bbl, utilizing a conversion ratio at 6 Mcf: 1 Bbl may be misleading as an indication of value.
This press release contains a number of oil and gas metrics, including, operating netbacks and FFO netbacks. These oil and gas metrics have been prepared by management and do not have standardized meanings or standard methods of calculation and therefore such measures may not be comparable to similar measures used by other companies and should not be used to make comparisons. Such metrics have been included herein to provide readers with additional measures to evaluate the Company’s performance; however, such measures are not reliable indicators of the future performance of the Company and future performance may not compare to the performance in previous periods and therefore such metrics should not be unduly relied upon. Management uses these oil and gas metrics for its own performance measurements and to provide security holders with measures to compare the Company’s operations over time. Readers are cautioned that the information provided by these metrics, or that can be derived from the metrics presented in this news release, should not be relied upon for investment or other purposes.
Any reference in this press release to short-term production rates are useful in confirming the presence of hydrocarbons, however such rates are not determination of the rates at which such wells will continue production and decline thereafter and readers are cautioned not to place reliance on such rates in calculating the aggregate production of Parex.
Distribution Advisory
The Company’s future shareholder distributions, including but not limited to the payment of dividends and the acquisition by the Company of its shares pursuant to an NCIB, if any, and the level thereof is uncertain. Any decision to pay further dividends on the common shares (including the actual amount, the declaration date, the record date and the payment date in connection therewith and any special dividends) or acquire shares of the Company will be subject to the discretion of the Board of Directors of Parex and may depend on a variety of factors, including, without limitation the Company’s business performance, financial condition, financial requirements, growth plans, expected capital requirements and other conditions existing at such future time including, without limitation, contractual restrictions and satisfaction of the solvency tests imposed on the Company under applicable corporate law. Further, the actual amount, the declaration date, the record date and the payment date of any dividend are subject to the discretion of the Board. There can be no assurance that the Company will pay dividends or repurchase any shares of the Company in the future.
Advisory on Forward Looking Statements
Certain information regarding Parex set forth in this document contains forward-looking statements that involve substantial known and unknown risks and uncertainties. The use of any of the words “plan”, “expect”, “prospective”, “project”, “intend”, “believe”, “should”, “anticipate”, “estimate”, “forecast”, “guidance”, “budget” or other similar words, or statements that certain events or conditions “may” or “will” occur are intended to identify forward-looking statements. Such statements represent Parex’s internal projections, estimates or beliefs concerning, among other things, future growth, results of operations, production, future capital and other expenditures (including the amount, nature and sources of funding thereof), competitive advantages, plans for and results of drilling activity, environmental matters, business prospects and opportunities. These statements are only predictions and actual events or results may differ materially. Although the Company’s management 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 Parex’s actual results to differ materially from those expressed or implied in any forward-looking statements made by, or on behalf of, Parex.
In particular, forward-looking statements contained in this document include, but are not limited to, statements with respect to: the Company’s focus, plans, priorities and strategies; average production guidance and capital expenditure guidance; expectations and plans regarding the Company’s drilling activity, the Company’s production profile, prospects in the Southern Llanos, the LLA-32 tuck-in acquisition, drilling and programs at LLA-34, LLA-32, Putumayo, and LLA-74; expectations about the Company’s FY 2025 tax rate; plans with respect to assessing the need for additional hedging in 2025; the anticipated terms of the Company’s Q2 2025 regular quarterly dividend, including its expectation that it will be designated as an “eligible dividend”; and the anticipated date and time of Parex’s conference call to discuss Q1 2025 results.
These forward-looking statements are subject to numerous risks and uncertainties, including but not limited to, the impact of general economic conditions in Canada and Colombia; an unpredictable tariff and trade environment; prolonged volatility in commodity prices; industry conditions including changes in laws and regulations including adoption of new environmental laws and regulations, and changes in how they are interpreted and enforced in Canada and Colombia; determinations by OPEC and other countries as to production levels; competition; lack of availability of qualified personnel; the results of exploration and development drilling and related activities; obtaining required approvals of regulatory authorities in Canada and Colombia; the risks associated with negotiating with foreign governments as well as country risk associated with conducting international activities; volatility in market prices for oil; fluctuations in foreign exchange or interest rates; environmental risks; changes in income tax laws or changes in tax laws and incentive programs relating to the oil industry; changes to pipeline capacity; ability to access sufficient capital from internal and external sources; failure of counterparties to perform under contracts; the risk that Brent oil prices may be lower than anticipated; the risk that Parex’s evaluation of its existing portfolio of development and exploration opportunities may not be consistent with its expectations; the risk that Parex may not have sufficient financial resources in the future to provide distributions to its shareholders; the risk that the Board may not declare dividends in the future or that Parex’s dividend policy changes; the risk that Parex may not be responsive to changes in commodity prices; the risk that Parex may not meet its production guidance for the year ended December 31, 2025; the risk that Parex’s 2025 capital expenditures may be greater or less than anticipated; the risk that plans and expectations related to Parex’s drilling program as disclosed herein do not materialize as expected and/or at all; and other factors, many of which are beyond the control of the Company.
Readers are cautioned that the foregoing list of factors is not exhaustive. Additional information on these and other factors that could affect Parex’s operations and financial results are included in reports on file with Canadian securities regulatory authorities and may be accessed through the SEDAR+ website (www.sedarplus.ca).
Although the forward-looking statements contained in this document are based upon assumptions which Management believes to be reasonable, the Company cannot assure investors that actual results will be consistent with these forward-looking statements. With respect to forward-looking statements contained in this document, Parex has made assumptions regarding, among other things: current and anticipated commodity prices and royalty regimes; availability of skilled labour; timing and amount of capital expenditures; future exchange rates; the price of oil, including the anticipated Brent oil price; the impact of increasing competition; conditions in general economic and financial markets; availability of drilling and related equipment; effects of regulation by governmental agencies; receipt of partner, regulatory and community approvals; royalty rates; future operating costs; uninterrupted access to areas of Parex’s operations and infrastructure; recoverability of reserves and future production rates; the status of litigation; timing of drilling and completion of wells; on-stream timing of production from successful exploration wells; operational performance of non-operated producing fields; pipeline capacity; that Parex will have sufficient cash flow, debt or equity sources or other financial resources required to fund its capital and operating expenditures and requirements as needed; that Parex’s conduct and results of operations will be consistent with its expectations; that Parex will have the ability to develop its oil and gas properties in the manner currently contemplated; that Parex’s evaluation of its existing portfolio of development and exploration opportunities is consistent with its expectations; current or, where applicable, proposed industry conditions, laws and regulations will continue in effect or as anticipated as described herein; that the estimates of Parex’s production and reserves volumes and the assumptions related thereto (including commodity prices and development costs) are accurate in all material respects; that Parex will be able to obtain contract extensions or fulfill the contractual obligations required to retain its rights to explore, develop and exploit any of its undeveloped properties; that Parex will have sufficient financial resources to pay dividends and acquire shares pursuant to its NCIB in the future; that Parex is able to execute its plans with respect to the Company’s drilling program as disclosed herein; and other matters.
Management has included the above summary of assumptions and risks related to forward-looking information provided in this document in order to provide shareholders with a more complete perspective on Parex’s current and future operations and such information may not be appropriate for other purposes. Parex’s 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, what benefits Parex will derive. These forward-looking statements are made as of the date of this document and Parex disclaims any intent or obligation to update publicly any forward-looking statements, whether as a result of new information, future events or results or otherwise, other than as required by applicable securities laws.
This press release contains information that may be considered a financial outlook under applicable securities laws about the Company’s potential financial position, including, but not limited to; Parex’s FY 2025 capital expenditure guidance; Parex 2025 guidance, including anticipated Brent crude oil average prices, funds flow provided by operations netback; funds flow provided by operations, capital expenditures, free funds flow; and the anticipated terms of the Company’s Q2 2025 regular quarterly dividend including its expectation that it will be designated as an “eligible dividend”, all of which are subject to numerous assumptions, risk factors, limitations and qualifications, including those set forth in the above paragraphs. The actual results of operations of the Company and the resulting financial results will vary from the amounts set forth in this press release and such variations may be material. This information has been provided for illustration only and with respect to future periods are based on budgets and forecasts that are speculative and are subject to a variety of contingencies and may not be appropriate for other purposes. Accordingly, these estimates are not to be relied upon as indicative of future results. Except as required by applicable securities laws, the Company undertakes no obligation to update such financial outlook. The financial outlook contained in this press release was made as of the date of this press release and was provided for the purpose of providing further information about the Company’s potential future business operations. Readers are cautioned that the financial outlook contained in this press release is not conclusive and is subject to change.
The following abbreviations used in this press release have the meanings set forth below:
| bbl |
one barrel |
| bbls |
barrels |
| bbl/d |
barrels per day |
| boe |
barrels of oil equivalent of natural gas; one barrel of oil or natural gas liquids for six thousand cubic feet of natural gas |
| boe/d |
barrels of oil equivalent of natural gas per day |
| mcf |
thousand cubic feet |
| mcf/d |
thousand cubic feet per day |
| W.I. |
working interest |
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