SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
F O R M 6-K
REPORT OF FOREIGN PRIVATE ISSUER PURSUANT
TO RULE 13a-16 OR 15d-16 UNDER THE
SECURITIES EXCHANGE ACT OF 1934
For the month of
July 2024
Commission File Number 001-36258
Veren Inc.
(Name of Registrant)
Suite 2000,
585-8th Avenue S.W.
Calgary, Alberta, T2P 1G1
(Address of Principal Executive Office)
Indicate by check mark whether the registrant files or
will file annual reports under cover of Form 20-F or Form 40-F.
Form
20-F ☐ Form
40-F ☒
_______
DOCUMENTS FILED AS PART OF THIS FORM 6-K:
|
Exhibit No.
99.1 |
Description
News Release dated July 25, 2024 |
SIGNATURE
Pursuant to the requirements of the Securities Exchange Act
of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
| |
Veren Inc. |
|
| |
(Registrant) |
|
| |
|
|
|
| |
By: |
/s/ Ken Lamont |
|
| |
Name: |
Ken Lamont |
|
| |
Title: |
Chief Financial Officer |
Date: July 25, 2024
EXHIBITS
Exhibit 99.1
Veren Announces Q2 2024 Results
CALGARY, AB, July 25, 2024 /CNW/ - Veren Inc. ("Veren"
or the "Company") (TSX: VRN) (NYSE: VRN) is pleased to announce its operating and financial results for the quarter ended June
30, 2024.
KEY HIGHLIGHTS
- Continued operational execution in Alberta Montney and Kaybob
Duvernay with recent wells among the top in the WCSB.
- Generated $195 million of excess cash flow in second quarter,
with 60 percent returned to shareholders.
- Reduced net debt by $620 million in second quarter with proceeds
from non-core asset disposition and excess cash flow.
- Issued $1.0 billion of investment-grade senior notes, optimizing
the balance sheet.
- Expect significant excess cash flow of $825 million in 2024 based
on US$80/bbl WTI and $1.70/Mcf AECO for the full year.
"Our second quarter results demonstrate our continued
focus on operational execution and further strengthening and optimizing of our balance sheet," said Craig Bryksa, President and CEO
of Veren. "Continuing to build on our year-to-date momentum, we delivered additional efficiencies along with strong and consistent
results in our Alberta Montney and Kaybob Duvernay assets. We also received an investment-grade credit rating during the quarter, reflecting
our enhanced scale, sustainability and financial position, allowing us to access public debt markets and diversify our capital structure."
FINANCIAL HIGHLIGHTS
- Adjusted funds flow totaled $611.7 million during second quarter
2024, or $0.99 per share diluted, driven by a strong operating netback of $40.00 per boe.
- For the quarter ended June 30, 2024, development capital expenditures,
which included drilling and development, facilities and seismic costs, totaled $350.6 million.
- Veren's net debt as at June 30, 2024 was $3.0 billion, reflecting
a reduction of $620 million in the quarter. The Company reduced its net debt through a combination of proceeds received from its disposition
of certain non-core assets in Saskatchewan and excess cash flow generated in second quarter.
- During the quarter, Veren was assigned an issuer rating of BBB
(low), with a Stable trend, by DBRS Limited ("Morningstar DBRS"). This public investment-grade rating reflects the success of
the Company's strategic transformation over the last few years, building scalable premium inventory, increasing production and cash flows,
and strengthening and optimizing the balance sheet.
- In second quarter, Veren repaid senior note maturities totaling
$316 million. As previously announced, the Company also issued $1.0 billion aggregate principal amount of investment-grade senior unsecured
notes during the quarter, consisting of $550.0 million of 4.968% five-year notes priced at par and due June 2029, and $450 million of
5.503% 10-year notes priced at par and due June 2034. The net proceeds from the offering were used to repay existing indebtedness, including
fully retiring Veren's bank term loan. This issuance of investment-grade notes is an important step in diversifying the Company's capital
structure and improving its overall cost of capital.
- The Company has hedged 50 percent of its oil and liquids production
and 30 percent of its natural gas production for the second half of 2024, net of royalty interest. In the first half of 2025, Veren has
hedged 30 percent of its oil and liquids production and 30 percent of its natural gas production, net of royalty interest. The Company
has also diversified its pricing exposure for natural gas, with the majority of its production through 2025 receiving a combination of
fixed prices and pricing related to major U.S. markets.
- Veren reported net income of $261.0 million, or $0.42 per share
diluted, for the quarter ended June 30, 2024.
| Adjusted funds flow, adjusted funds flow per share diluted, excess cash flow, operating netback, development capital expenditures, total return of capital and net debt are specified financial measures - refer to the Specified Financial Measures section in this press release for further information. All financial figures are approximate and in Canadian dollars unless otherwise noted. This press release contains forward-looking information and references to specified financial measures. Significant related assumptions and risk factors, and reconciliations are described under the Specified Financial Measures, Forward-Looking Statements and Reserves and Drilling Data sections of this press release, respectively. Further information breaking down the production information contained in this press release by product type can be found in the "Product Type Production Information" section of this press release. |
RETURN OF CAPITAL HIGHLIGHTS
- During second quarter 2024, the Company's total return of capital
to shareholders, including the base dividend, was $114.1 million. Veren remains committed to returning 60 percent of its annual excess
cash flow to shareholders through a combination of dividends and share repurchases.
- The Company remained active on its normal course issuer bid ("NCIB")
in second quarter, repurchasing 3.6 million shares for $42.4 million. Year-to-date, Veren has repurchased 5.4 million shares under its
NCIB.
- Subsequent to the quarter, the Company's Board of Directors declared
a quarterly cash base dividend of $0.115 per share payable on October 1, 2024, to shareholders of record on September 15, 2024.
OPERATIONAL HIGHLIGHTS
- Average production in second quarter 2024 was 192,648 boe/d, comprised
of approximately 65 percent oil and liquids.
- The Company continued to demonstrate the strength of its operational
execution in the Alberta Montney, delivering the top four oil and liquids producing wells in the Western Canadian Sedimentary Basin ("WCSB")
based on recent monthly liquids volumes. During second quarter, Veren also drilled a new pacesetter well in its Gold Creek area of the
play. This well, which was a part of an eight-well pad, was drilled in 9.0 days with the overall pad averaging 11.3 days per well, an
improvement of 3.0 days compared to the Company's average drill time in the area since entering the play. Veren will continue to focus
on realizing further efficiencies through drilling optimization, consistent rig utilization and knowledge transfer across its assets.
- During the quarter, the Company brought on stream its first fully-operated
pad in its Karr West area of the Alberta Montney, utilizing Veren's optimized drilling and completions design. This pad generated an average
peak 30-day rate of 1,300 boe/d per well (65% liquids). The Company is in the process of bringing 11 wells on stream in its Gold Creek
area which were completed in late second quarter and expects to bring an additional 22 wells on stream in the Alberta Montney through
the remainder of 2024.
- In the Kaybob Duvernay, the Company continues to realize strong
and consistent well results, with three of its recent wells ranking within the top five oil and liquids producing wells in the Duvernay
based on monthly liquids volumes. Veren brought three pads on stream in the Volatile Oil window during second quarter, one of which has
been on stream for over 30 days with an average peak 30-day rate of 1,300 boe/d per well (75% liquids). Veren plans to bring an additional
22 wells on stream in the Kaybob Duvernay through the remainder of 2024.
- In its Saskatchewan operations, the Company continues to advance
its decline mitigation projects to further enhance its long-term sustainability and excess cash flow generation. Veren remains on track
to convert approximately 70 producing wells to water injection wells in 2024, further supporting its current base decline rate of approximately
15 percent in Saskatchewan.
OUTLOOK
Veren remains on track to meet its 2024 annual average
production guidance of 191,000 to 199,000 boe/d with development capital expenditures of $1.4 to $1.5 billion.
The Company expects to generate approximately $825
million of excess cash flow in 2024, based on US$80/bbl WTI and $1.70/Mcf AECO for the full year. Given the timing of its development
program and expected production growth through the remainder of the year, 60 percent of Veren's full year excess cash flow is expected
to be realized in the second half of 2024.
The Company will continue to return 60 percent of
its excess cash flow to shareholders through its base dividend and share repurchases. The balance of Veren's excess cash flow remains
directed toward debt reduction, with the Company expected to reduce its net debt to $2.8 billion by year-end 2024 at US$80/bbl WTI, or
1.1 times adjusted funds flow.
Veren is in the initial stages of its annual budgeting
process and plans to provide its 2025 outlook along with an updated five-year plan later this year. Similar to prior years, the Company's
2025 budget will remain disciplined and flexible with a focus on allocating capital to its highest return assets with attractive payback
periods. The Kaybob Duvernay and Alberta Montney assets, which rank in the top quartile in Veren's portfolio, are expected to garner the
majority of its capital, alongside continued investment in decline mitigation programs throughout Saskatchewan to further enhance Veren's
excess cash flow profile.
The Company will continue to focus on its strategic
priorities of operational execution, further strengthening its balance sheet and increasing its return of capital to shareholders.
| Net debt to adjusted funds flow is a specified financial measure - refer to the Specified Financial Measures section in this press release for further information. |
CONFERENCE CALL DETAILS
Veren's management will host a conference call on
Thursday, July 25, 2024 at 10:00 a.m. MT (12:00 p.m. ET) to discuss the Company's results and outlook. A slide deck will accompany the
conference call and can be found on Veren's website.
Participants can listen to this event online via webcast.
To join the call without operator assistance, participants may register online by entering their phone number to receive an instant automated
call back. Alternatively, the conference call can be accessed with operated assistance by dialing 1-888-390-0605. Participants will be
able to take part in a question and answer session following management's opening remarks through both the webcast dashboard and the conference
line.
The webcast will be archived for replay and can be
accessed online. The replay will be available shortly after the completion of the call.
Shareholders and investors can also find the Company's
most recent investor presentation on Veren's website.
2024 GUIDANCE
The Company's guidance for 2024 is as follows:
| Total Annual Average Production (boe/d) (1) |
191,000 - 199,000 |
| |
|
| Capital Expenditures |
|
| Development capital expenditures ($ millions) (2) |
$1,400 - $1,500 |
| Capitalized administration ($ millions) |
$40 |
| Total ($ million) (3) |
$1,440 - $1,540 |
| |
| Other Information for 2024 Guidance |
|
| Reclamation activities ($ millions) (4) |
$40 |
| Capital lease payments ($ millions) |
$20 |
| Annual operating expenses ($/boe) |
$12.50 - $13.50 |
| Royalties |
10.00% - 11.00% |
| 1) |
Total annual average production (boe/d) is comprised of approximately 65% Oil, Condensate & NGLs and 35% Natural Gas |
| 2) |
Specified financial measure that does not have any standardized meaning prescribed by IFRS and, therefore may not be comparable with the calculation of similar measures presented by other entities. Refer to the Specified Financial Measures section for further information |
| 3) |
Land expenditures and net property acquisitions and dispositions are not included. Development capital expenditures spend is allocated on an approximate basis as follows: 90% drilling & development and 10% facilities & seismic |
| 4) |
Reflects Veren's portion of its expected total budget |
RETURN OF CAPITAL OUTLOOK
| Base Dividend |
|
| Current quarterly base dividend per share |
$0.115 |
| Total Return of Capital |
|
| % of excess cash flow (1) |
60 % |
| 1) |
Total return of capital is based on a framework that targets to return to shareholders 60% of excess cash flow on an annual basis |
The Company's unaudited consolidated financial statements
and management's discussion and analysis for the quarter ended June 30, 2024, will be available on the System for Electronic Document
Analysis and Retrieval ("SEDAR+") at www.sedarplus.ca, on EDGAR at www.sec.gov and on Veren's website at www.vrn.com.
| Net debt to adjusted funds flow is a specified financial measure - refer to the Specified Financial Measures section in this press release for further information. |
CONSOLIDATED FINANCIAL AND OPERATING HIGHLIGHTS
| |
Three months ended June 30 |
Six months ended June 30 |
|
| (Cdn$ millions except per share and per boe amounts) |
2024 |
2023 |
2024 |
2023 |
|
| Financial |
|
|
|
|
|
| Cash flow from operating activities |
625.8 |
462.1 |
1,037.0 |
935.5 |
|
| Adjusted funds flow from operations (1) |
611.7 |
552.6 |
1,179.9 |
1,077.5 |
|
| Per share (1) (2) |
0.99 |
1.01 |
1.90 |
1.96 |
|
| Net income (loss) |
261.0 |
212.3 |
(150.7) |
429.0 |
|
| Per share (2) |
0.42 |
0.39 |
(0.24) |
0.78 |
|
| Adjusted net earnings from operations (1) |
237.8 |
205.4 |
424.8 |
424.3 |
|
| Per share (1) (2) |
0.38 |
0.38 |
0.68 |
0.77 |
|
| Dividends declared |
71.7 |
54.8 |
143.0 |
71.9 |
|
| Per share (2) |
0.115 |
0.100 |
0.230 |
0.132 |
|
| Net debt (1) |
2,962.7 |
3,000.7 |
2,962.7 |
3,000.7 |
|
| Net debt to adjusted funds flow from operations (1) (3) |
1.2 |
1.4 |
1.2 |
1.4 |
|
| Weighted average shares outstanding |
|
|
|
|
|
| Basic |
618.7 |
543.0 |
619.3 |
545.9 |
|
| Diluted |
620.3 |
545.3 |
621.4 |
549.0 |
|
| Operating |
|
|
|
|
|
| Average daily production |
|
|
|
|
|
| Crude oil and condensate (bbls/d) |
110,399 |
101,347 |
112,003 |
97,045 |
|
| NGLs (bbls/d) |
17,041 |
18,911 |
18,059 |
18,443 |
|
| Natural gas (mcf/d) |
391,249 |
208,640 |
393,228 |
190,268 |
|
| Total (boe/d) |
192,648 |
155,031 |
195,600 |
147,199 |
|
| Average selling prices (4) |
|
|
|
|
|
| Crude oil and condensate ($/bbl) |
101.81 |
92.26 |
95.93 |
93.18 |
|
| NGLs ($/bbl) |
35.78 |
26.45 |
36.62 |
32.16 |
|
| Natural gas ($/mcf) |
1.64 |
2.81 |
2.35 |
3.46 |
|
| Total ($/boe) |
64.82 |
67.31 |
63.04 |
69.93 |
|
| Netback ($/boe) |
|
|
|
|
|
| Oil and gas sales |
64.82 |
67.31 |
63.04 |
69.93 |
|
| Royalties |
(6.61) |
(8.79) |
(6.46) |
(9.33) |
|
| Operating expenses |
(13.66) |
(14.40) |
(13.78) |
(14.85) |
|
| Transportation expenses |
(4.55) |
(3.10) |
(4.54) |
(2.97) |
|
| Operating netback |
40.00 |
41.02 |
38.26 |
42.78 |
|
| Realized gain (loss) on commodity derivatives |
(0.19) |
1.79 |
0.03 |
0.67 |
|
| Other (5) |
(4.92) |
(3.64) |
(5.15) |
(3.01) |
|
| Adjusted funds flow from operations netback (1) |
34.89 |
39.17 |
33.14 |
40.44 |
|
| Capital Expenditures |
|
|
|
|
|
| Capital acquisitions (6) |
— |
1,702.7 |
— |
2,074.7 |
|
| Capital dispositions (6) |
(541.1) |
(8.4) |
(646.9) |
(11.0) |
|
| Development capital expenditures (1) |
|
|
|
|
|
| Drilling and development |
318.2 |
212.2 |
668.7 |
492.7 |
|
| Facilities and seismic |
32.4 |
17.9 |
80.5 |
51.6 |
|
| Total |
350.6 |
230.1 |
749.2 |
544.3 |
|
| Land expenditures |
27.4 |
7.1 |
35.1 |
8.4 |
|
| (1) |
Specified financial measure that does not have any standardized meaning prescribed by IFRS and, therefore, may not be comparable with the calculation of similar measures presented by other entities. Refer to the Specified Financial Measures section for further information. |
| (2) |
The per share amounts (with the exception of dividends per share) are the per share – diluted amounts. |
| (3) |
Net debt to adjusted funds flow from operations is calculated as the period end net debt divided by the sum of adjusted funds flow from operations for the trailing four quarters. |
| (4) |
The average selling prices reported are before realized derivatives and transportation. |
| (5) |
Other includes net purchased products, general and administrative expenses, interest on long-term debt, foreign exchange, cash-settled share-based compensation and certain cash items and excludes transaction costs, foreign exchange on US dollar long-term debt and certain non-cash items. |
| (6) |
Capital acquisitions and dispositions, net represent total consideration for the transactions, including long-term debt and working capital assumed, and exclude transaction costs. |
FINANCIAL AND OPERATING HIGHLIGHTS FROM CONTINUING
OPERATIONS
| |
Three months ended June 30 |
Six months ended June 30 |
| (Cdn$ millions except per share and per boe amounts) |
2024 |
2023 |
2024 |
2023 |
| Financial |
|
|
|
|
| Cash flow from operating activities from continuing operations |
625.8 |
365.9 |
1,037.0 |
735.7 |
| Adjusted funds flow from continuing operations (1) |
611.7 |
453.4 |
1,179.9 |
892.0 |
| Per share (1) (2) |
0.99 |
0.83 |
1.90 |
1.62 |
| Net income (loss) from continuing operations |
260.9 |
178.4 |
(138.0) |
363.2 |
| Per share (2) |
0.42 |
0.33 |
(0.22) |
0.66 |
| Adjusted net earnings from continuing operations (1) |
237.8 |
171.6 |
424.8 |
359.3 |
| Per share (1) (2) |
0.38 |
0.32 |
0.68 |
0.65 |
| Weighted average shares outstanding |
|
|
|
|
| Basic |
618.7 |
543.0 |
619.3 |
545.9 |
| Diluted |
620.3 |
545.3 |
621.4 |
549.0 |
| Operating |
|
|
|
|
| Average daily production from continuing operations |
|
|
|
|
| Crude oil and condensate (bbls/d) |
110,399 |
84,944 |
112,003 |
81,586 |
| NGLs (bbls/d) |
17,041 |
14,360 |
18,059 |
13,963 |
| Natural gas (mcf/d) |
391,249 |
192,964 |
393,228 |
175,425 |
| Production from continuing operations (boe/d) |
192,648 |
131,465 |
195,600 |
124,787 |
| Average selling prices from continuing operations (3) |
|
|
|
|
| Crude oil and condensate ($/bbl) |
101.81 |
91.08 |
95.93 |
91.83 |
| NGLs ($/bbl) |
35.78 |
29.64 |
36.62 |
35.43 |
| Natural gas ($/mcf) |
1.64 |
2.78 |
2.35 |
3.40 |
| Total ($/boe) |
64.82 |
66.17 |
63.04 |
68.78 |
| Netback from Continuing Operations ($/boe) |
|
|
|
|
| Oil and gas sales |
64.82 |
66.17 |
63.04 |
68.78 |
| Royalties |
(6.61) |
(7.00) |
(6.46) |
(7.52) |
| Operating expenses |
(13.66) |
(15.28) |
(13.78) |
(15.58) |
| Transportation expenses |
(4.55) |
(3.32) |
(4.54) |
(3.21) |
| Operating netback |
40.00 |
40.57 |
38.26 |
42.47 |
| Realized gain (loss) on commodity derivatives |
(0.19) |
2.11 |
0.03 |
0.79 |
| Other (4) |
(4.92) |
(4.78) |
(5.15) |
(3.77) |
| Adjusted funds flow from continuing operations netback (1) |
34.89 |
37.90 |
33.14 |
39.49 |
| Capital Expenditures |
|
|
|
|
| Development capital expenditures from continuing operations (1) |
350.6 |
123.5 |
749.2 |
308.5 |
| (1) |
Specified financial measure that does not have any standardized meaning prescribed by IFRS and, therefore, may not be comparable with the calculation of similar measures presented by other entities. Refer to the Specified Financial Measures section for further information. |
| (2) |
The per share amounts (with the exception of dividends per share) are the per share – diluted amounts. |
| (3) |
The average selling prices reported are before realized derivatives and transportation. |
| (4) |
Other includes net purchased products, general and administrative expenses, interest on long-term debt, foreign exchange, cash-settled share-based compensation and certain cash items and excludes transaction costs, foreign exchange on US dollar long-term debt and certain non-cash items. |
Specified Financial Measures
Throughout this press release, the Company uses the
terms "total operating netback", "total operating netback from continuing operations", "total netback",
"total netback from continuing operations", "operating netback", "netback", "adjusted funds flow from
operations" (or "adjusted FFO"), "adjusted funds flow from operations per share - diluted", "adjusted funds
flow from continuing operations", "adjusted funds flow from continuing operations per share - diluted", "adjusted
funds flow from discontinued operations", "adjusted funds flow from operations netback", "adjusted funds flow
from continuing operations netback" "excess cash flow", "base dividends", "total return of capital",
"adjusted working capital deficiency", "net debt", "net debt to adjusted funds flow from operations", "adjusted
net earnings from operations", "adjusted net earnings from operations per share - diluted", "adjusted net earnings
from continuing operations", "adjusted net earnings from continuing operations per share – diluted", "adjusted
net earnings from discontinued operations", "development capital expenditures", "development capital expenditures
from continuing operations", and "development capital expenditures from discontinued operations". These terms do not have
any standardized meaning as prescribed by IFRS and, therefore, may not be comparable with the calculation of similar measures presented
by other issuers. For information on the composition of these measures and how the Company uses these measures, refer to the Specified
Financial Measures section of the Company's MD&A for the quarter ended June 30, 2024, which section is incorporated herein by reference,
and available on SEDAR+ at www.sedarplus.ca and on EDGAR at www.sec.gov/edgar.
Adjusted funds flow from operations netback is a non-GAAP
financial ratio and is calculated as adjusted funds flow from operations divided by total production. Adjusted funds flow from operations
netback is a common metric used in the oil and gas industry and is used to measure operating results on a per boe basis.
The following table reconciles oil and gas sales to
total operating netback from continuing operations, total netback from continuing operations and total adjusted funds flow from continuing
operations netback:
| |
Three months ended June 30 |
Six months ended June 30 |
| ($ millions) |
2024 |
2023 |
% Change |
2024 |
2023 |
% Change |
| Oil and gas sales |
1,136.4 |
791.6 |
44 |
2,244.3 |
1,553.6 |
44 |
| Royalties |
(115.9) |
(83.8) |
38 |
(229.8) |
(169.8) |
35 |
| Operating expenses |
(239.5) |
(182.8) |
31 |
(490.5) |
(351.8) |
39 |
| Transportation expenses |
(79.7) |
(39.7) |
101 |
(161.5) |
(72.5) |
123 |
| Total operating netback from continuing operations |
701.3 |
485.3 |
45 |
1,362.5 |
959.5 |
42 |
| Realized gain (loss) on commodity derivatives |
(3.4) |
25.3 |
(113) |
1.1 |
17.9 |
(94) |
| Total netback from continuing operations |
697.9 |
510.6 |
37 |
1,363.6 |
977.4 |
40 |
| Other (1) |
(86.2) |
(57.2) |
51 |
(183.7) |
(85.4) |
115 |
| Total adjusted funds flow from continuing operations netback |
611.7 |
453.4 |
35 |
1,179.9 |
892.0 |
32 |
| (1) |
Other includes net purchased products, general and administrative expenses, interest on long-term debt, foreign exchange, cash-settled share-based compensation and certain cash items and excludes transaction costs, foreign exchange on US dollar long-term debt and certain non-cash items. |
The following table reconciles cash flow from operating
activities to adjusted funds flow from operations and excess cash flow:
| |
Three months ended June 30 |
Six months ended June 30 |
| ($ millions) |
2024 |
2023 (1) |
% Change |
2024 |
2023 (1) |
% Change |
| Cash flow from operating activities |
625.8 |
462.1 |
35 |
1,037.0 |
935.5 |
11 |
| Changes in non-cash working capital |
(34.3) |
70.0 |
(149) |
114.1 |
109.8 |
4 |
| Transaction costs |
12.9 |
14.6 |
(12) |
14.2 |
16.4 |
(13) |
| Decommissioning expenditures (2) |
7.3 |
5.9 |
24 |
14.6 |
15.8 |
(8) |
| Adjusted funds flow from operations |
611.7 |
552.6 |
11 |
1,179.9 |
1,077.5 |
10 |
| Development capital and other expenditures |
(387.7) |
(249.1) |
56 |
(805.6) |
(576.5) |
40 |
| Payments on lease liability |
(8.8) |
(5.3) |
66 |
(17.4) |
(10.6) |
64 |
| Decommissioning expenditures |
(7.3) |
(5.9) |
24 |
(14.6) |
(15.8) |
(8) |
| Unrealized gain (loss) on equity derivative contracts |
(0.7) |
(2.5) |
(72) |
(0.6) |
(30.0) |
(98) |
| Transaction costs |
(12.9) |
(14.6) |
(12) |
(14.2) |
(16.4) |
(13) |
| Other items (3) |
(0.9) |
2.6 |
(135) |
(3.3) |
3.0 |
(210) |
| Excess cash flow |
193.4 |
277.8 |
(30) |
324.2 |
431.2 |
(25) |
| (1) |
Comparative period revised to reflect current period presentation. |
| (2) |
Excludes amounts received from government grant programs. |
| (3) |
Other items exclude net acquisitions and dispositions. |
The following table reconciles cash flow from operating
activities from discontinued operations to adjusted funds flow from discontinued operations:
| |
Three months ended June 30 |
Six months ended June 30 |
| ($ millions) |
2024 |
2023 |
% Change |
2024 |
2023 |
% Change |
| Cash flow from operating activities from discontinued operations |
— |
96.2 |
(100) |
— |
199.8 |
(100) |
| Changes in non-cash working capital |
— |
3.0 |
(100) |
— |
(14.3) |
(100) |
| Adjusted funds flow from discontinued operations |
— |
99.2 |
(100) |
— |
185.5 |
(100) |
The following tables reconcile cash flow from operating
activities and adjusted funds flow from operations from continuing and discontinued operations:
| |
Three months ended June 30 |
Six months ended June 30 |
| ($ millions) |
2024 |
2023 |
% Change |
2024 |
2023 |
% Change |
| Cash flow from operating activities from continuing operations |
625.8 |
365.9 |
71 |
1,037.0 |
735.7 |
41 |
| Cash flow from operating activities from discontinued operations |
— |
96.2 |
(100) |
— |
199.8 |
(100) |
| Cash flow from operating activities |
625.8 |
462.1 |
35 |
1,037.0 |
935.5 |
11 |
| |
Three months ended June 30 |
Six months ended June 30 |
| ($ millions) |
2024 |
2023 |
% Change |
2024 |
2023 |
% Change |
| Adjusted funds flow from continuing operations |
611.7 |
453.4 |
35 |
1,179.9 |
892.0 |
32 |
| Adjusted funds flow from discontinued operations |
— |
99.2 |
(100) |
— |
185.5 |
(100) |
| Adjusted funds flow from operations |
611.7 |
552.6 |
11 |
1,179.9 |
1,077.5 |
10 |
Adjusted funds flow from operations per share - diluted
is a supplementary financial measure and is calculated as adjusted funds flow from operations divided by the number of weighted average
diluted shares outstanding.
The following table reconciles adjusted working capital
deficiency:
| ($ millions) |
June 30, 2024 |
December 31, 2023 |
% Change |
| Accounts payable and accrued liabilities |
571.4 |
634.9 |
(10) |
| Dividends payable |
71.2 |
56.8 |
25 |
| Long-term compensation liability (1) |
51.2 |
66.8 |
(23) |
| Cash |
(5.8) |
(17.3) |
(66) |
| Accounts receivable |
(379.5) |
(377.9) |
— |
| Prepaids and deposits |
(105.0) |
(87.8) |
20 |
| Deferred consideration receivable (2) |
(63.1) |
(79.2) |
(20) |
| Adjusted working capital deficiency |
140.4 |
196.3 |
(28) |
| (1) |
Includes current portion of long-term compensation liability and is net of equity derivative contracts. |
| (2) |
Deferred consideration receivable is comprised of $50.1 million included in other current assets and $13.0 million included in other long-term assets (December 31, 2023 - $79.2 million in other current assets and nil in other long-term assets). |
The following table reconciles long-term debt to net
debt:
| ($ millions) |
June 30, 2024 |
December 31, 2023 |
% Change |
| Long-term debt (1) |
2,844.9 |
3,566.3 |
(20) |
| Adjusted working capital deficiency |
140.4 |
196.3 |
(28) |
| Unrealized foreign exchange on translation of hedged US dollar long-term debt |
(22.6) |
(24.5) |
(8) |
| Net debt |
2,962.7 |
3,738.1 |
(21) |
| (1) |
Includes current portion of long-term debt. |
The following table reconciles net income (loss) to
adjusted net earnings from operations:
| |
Three months ended June 30 |
Six months ended June 30 |
| ($ millions) |
2024 |
2023 |
% Change |
2024 |
2023 |
% Change |
| Net income (loss) |
261.0 |
212.3 |
23 |
(150.7) |
429.0 |
(135) |
| Amortization of E&E undeveloped land |
29.8 |
5.3 |
462 |
59.4 |
7.9 |
652 |
| Impairment |
— |
— |
— |
512.3 |
— |
100 |
| Unrealized derivative losses |
4.8 |
116.2 |
(96) |
157.7 |
120.1 |
31 |
| Unrealized foreign exchange (gain) loss on translation of hedged US dollar long-term debt |
(66.6) |
(128.5) |
(48) |
1.6 |
(129.1) |
(101) |
| Net (gain) loss on capital dispositions |
(1.3) |
(2.1) |
(38) |
10.7 |
(4.1) |
(361) |
| Deferred tax adjustments |
10.1 |
2.2 |
359 |
(166.2) |
0.5 |
(33,340) |
| Adjusted net earnings from operations |
237.8 |
205.4 |
16 |
424.8 |
424.3 |
— |
The following table reconciles net income (loss) from
discontinued operations to adjusted net earnings from discontinued operations:
| |
Three months ended June 30 |
Six months ended June 30 |
| ($ millions) |
2024 |
2023 |
% Change |
2024 |
2023 |
% Change |
| Net income (loss) from discontinued operations |
0.1 |
33.9 |
(100) |
(12.7) |
65.8 |
(119) |
| Net (gain) loss on capital dispositions |
(0.1) |
— |
(100) |
12.7 |
— |
100 |
| Deferred tax adjustments |
— |
(0.1) |
(100) |
— |
(0.8) |
(100) |
| Adjusted net earnings from discontinued operations |
— |
33.8 |
(100) |
— |
65.0 |
(100) |
The following table reconciles adjusted net earnings
from continuing and discontinued operations:
| |
Three months ended June 30 |
Six months ended June 30 |
| ($ millions) |
2024 |
2023 |
% Change |
2024 |
2023 |
% Change |
| Adjusted net earnings from continuing operations |
237.8 |
171.6 |
39 |
424.8 |
359.3 |
18 |
| Adjusted net earnings from discontinued operations |
— |
33.8 |
(100) |
— |
65.0 |
(100) |
| Adjusted net earnings from operations |
237.8 |
205.4 |
16 |
424.8 |
424.3 |
— |
The following table reconciles development capital
and other expenditures to development capital expenditures:
| |
Three months ended June 30 |
Six months ended June 30 |
| ($ millions) |
2024 |
2023 |
% Change |
2024 |
2023 |
% Change |
| Development capital and other expenditures |
387.7 |
249.1 |
56 |
805.6 |
576.5 |
40 |
| Payments on drilling rig lease liabilities |
3.2 |
— |
100 |
6.3 |
— |
100 |
| Land expenditures |
(27.4) |
(7.1) |
286 |
(35.1) |
(8.4) |
318 |
| Capitalized administration (1) |
(11.4) |
(10.1) |
13 |
(25.0) |
(21.5) |
16 |
| Corporate assets |
(1.5) |
(1.8) |
(17) |
(2.6) |
(2.3) |
13 |
| Development capital expenditures |
350.6 |
230.1 |
52 |
749.2 |
544.3 |
38 |
| (1) |
Capitalized administration excludes capitalized equity-settled SBC. |
The following table reconciles development capital
expenditures from continuing and discontinued operations:
| |
Three months ended June 30 |
Six months ended June 30 |
| ($ millions) |
2024 |
2023 |
% Change |
2024 |
2023 |
% Change |
| Development capital expenditures from continuing operations |
350.6 |
123.5 |
184 |
749.2 |
308.5 |
143 |
| Development capital expenditures from discontinued operations |
— |
106.6 |
(100) |
— |
235.8 |
(100) |
| Development capital expenditures |
350.6 |
230.1 |
52 |
749.2 |
544.3 |
38 |
Total return of capital is a supplementary financial
measure and is comprised of base dividends, special dividends and share repurchases, adjusted for the timing of special dividend payments.
Excess cash flow for 2024 is a forward-looking non-GAAP
measures and is calculated consistently with the measures disclosed in the Company's MD&A. Refer to the Specified Financial Measures
section of the Company's MD&A for the three and six months ended June 30, 2024.
Management believes the presentation of the specified
financial measures above provide useful information to investors and shareholders as the measures provide increased transparency and the
ability to better analyze performance against prior periods on a comparable basis.
Notice to US Readers
The oil and natural gas reserves contained in this
press release have generally been prepared in accordance with Canadian disclosure standards, which are not comparable in all respects
of United States or other foreign disclosure standards. For example, the United States Securities and Exchange Commission (the "SEC")
generally permits oil and gas issuers, in their filings with the SEC, to disclose only proved reserves (as defined in SEC rules), but
permits the optional disclosure of "probable reserves" and "possible reserves" (each as defined in SEC rules). Canadian
securities laws require oil and gas issuers, in their filings with Canadian securities regulators, to disclose not only proved reserves
(which are defined differently from the SEC rules) but also probable reserves and permits optional disclosure of "possible reserves",
each as defined in NI 51-101. Accordingly, "proved reserves", "probable reserves" and "possible reserves"
disclosed in this news release may not be comparable to US standards, and in this news release, Veren has disclosed reserves designated
as "proved plus probable reserves". Probable reserves are higher-risk and are generally believed to be less likely to be accurately
estimated or recovered than proved reserves. "Possible reserves" are higher risk than "probable reserves" and are
generally believed to be less likely to be accurately estimated or recovered than "probable reserves". In addition, under
Canadian disclosure requirements and industry practice, reserves and production are reported using gross volumes, which are volumes prior
to deduction of royalties and similar payments. The SEC rules require reserves and production to be presented using net volumes, after
deduction of applicable royalties and similar payments. Moreover, Veren has determined and disclosed estimated future net revenue from
its reserves using forecast prices and costs, whereas the SEC rules require that reserves be estimated using a 12-month average price,
calculated as the arithmetic average of the first-day-of-the-month price for each month within the 12-month period prior to the end of
the reporting period. Consequently, Veren's reserve estimates and production volumes in this news release may not be comparable
to those made by companies using United States reporting and disclosure standards. Further, the SEC rules are based on unescalated costs
and forecasts.
All amounts in the news release are stated in Canadian
dollars unless otherwise specified.
Forward-Looking Statements
Any "financial outlook" or "future
oriented financial information" in this press release, as defined by applicable securities legislation has been approved by management
of Veren. Such financial outlook or future oriented financial information is provided for the purpose of providing information about management's
current expectations and plans relating to the future. Readers are cautioned that reliance on such information may not be appropriate
for other purposes.
Certain statements contained in this press release
constitute "forward-looking statements" within the meaning of section 27A of the Securities Act of 1933 and section 21E of the
Securities Exchange Act of 1934 and "forward-looking information" for the purposes of Canadian securities regulation (collectively,
"forward-looking statements"). The Company has tried to identify such forward-looking statements by use of such words as "could",
"should", "can", "anticipate", "expect", "believe", "will", "may",
"intend", "projected", "sustain", "continues", "strategy", "potential", "projects",
"grow", "take advantage", "estimate", "well-positioned" and other similar expressions, but these
words are not the exclusive means of identifying such statements.
In particular, this press release contains forward-looking
statements pertaining, among other things, to the following: optimized diversified balance sheet; diversified capital structure, significant
excess cash flow of $825 million in 2024 based on US$80/bbl WTI and $1.70/Mcf AECO for the full year; focus on operational execution and
further strengthening and optimizing of balance sheet; enhanced scale, sustainability and financial position; premium inventory; credit
ratings and trends; improving overall cost of capital; the extent of hedges, timing, benefits and expectations; return of capital outlook,
percentage of annual excess cash flow to be returned to shareholders and methods thereof; further efficiencies through continued drilling
optimization, consistent rig utilization and knowledge transfer across assets; plans to bring additional wells on stream in the Alberta
Montney and Kaybob Duvernay through the remainder of 2024; Saskatchewan decline mitigation projects to further enhance long-term sustainability
and excess cash flow generation and timing to convert producing wells to water injection wells in 2024; base decline rate of approximately
15 percent in Saskatchewan; Veren's 2024 production and development capital expenditures guidance; and other information for Veren's 2024
guidance, including capitalized administration, reclamation activities, capital lease payments, annual operating expenses and royalties;
and return of capital outlook, including base dividend, and the additional return of capital targeted as a percentage of excess cash flow;
timing to to realize full year excess cash flow; direction of balance of excess cash flow beyond return of capital toward debt reduction,
with the Company expected to reduce its net debt to $2.8 billion by year-end 2024 at US$80/bbl WTI, or 1.1 times adjusted funds flow;
timing to release 2025 outlook along with an updated five-year plan; the Company's 2025 budget will remain disciplined and flexible with
a focus on allocating capital to its highest return assets with attractive payback periods; allocation of 2025 capital budgeted and benefits
thereof; and strategic priorities of operational execution, further strengthening its balance sheet and increasing its return of capital
to shareholders.
Statements relating to "reserves" are also
deemed to be forward-looking statements, as they involve the implied assessment, based on certain estimates and assumptions, that the
reserves described exist in the quantities predicted or estimated and that the reserves can be profitably produced in the future. Actual
reserve values may be greater than or less than the estimates provided herein.
Unless otherwise noted, reserves referenced herein
are given as at December 31, 2023. Also, estimates of reserves and future net revenue for individual properties may not reflect the same
confidence level as estimates and future net revenue for all properties due to the effect of aggregation. All required reserve information
for the Company is contained in its Annual Information Form for the year ended December 31, 2023, which is accessible at www.sedarplus.ca.
With respect to disclosure contained herein regarding
resources other than reserves, there is uncertainty that it will be commercially viable to produce any portion of the resources and there
is significant uncertainty regarding the ultimate recoverability of such resources.
All forward-looking statements are based on Veren's
beliefs and assumptions based on information available at the time the assumption was made. Veren believes that the expectations reflected
in these forward-looking statements are reasonable but no assurance can be given that these expectations will prove to be correct and
such forward-looking statements included in this report should not be unduly relied upon. By their nature, such forward-looking statements
are subject to a number of risks, uncertainties and assumptions, which could cause actual results or other expectations to differ materially
from those anticipated, expressed or implied by such statements, including those material risks discussed in the Company's Annual Information
Form for the year ended December 31, 2023 under "Risk Factors" and our Management's Discussion and Analysis for the year ended
December 31, 2023, under the headings "Risk Factors" and "Forward-Looking Information" and for the three and six months
ended June 30, 2024, under the headings "Risk Factors" and "Forward-Looking Information". The material assumptions
are disclosed in the Management's Discussion and Analysis for the year ended December 31, 2023, under the headings "Capital Expenditures",
"Liquidity and Capital Resources", "Critical Accounting Estimates", "Risk Factors" and "Changes in
Accounting Policies" and in the Management's Discussion and Analysis for the three and six months ended June 30, 2024, under the
headings "Overview", "Commodity Derivatives", "Liquidity and Capital Resources", "Guidance", "Royalties"
and "Operating Expenses". In addition, risk factors include: financial risk of marketing reserves at an acceptable price given
market conditions; volatility in market prices for oil and natural gas, decisions or actions of OPEC and non-OPEC countries in respect
of supplies of oil and gas; delays in business operations or delivery of services due to pipeline restrictions, rail blockades, outbreaks,
pandemics, and blowouts; the risk of carrying out operations with minimal environmental impact; industry conditions including changes
in laws and regulations including the adoption of new environmental laws and regulations and changes in how they are interpreted and enforced;
uncertainties associated with estimating oil and natural gas reserves; risks and uncertainties related to oil and gas interests and operations
on Indigenous lands; economic risk of finding and producing reserves at a reasonable cost; uncertainties associated with partner plans
and approvals; operational matters related to non-operated properties; increased competition for, among other things, capital, acquisitions
of reserves and undeveloped lands; competition for and availability of qualified personnel or management; incorrect assessments of the
value and likelihood of acquisitions and dispositions, and exploration and development programs; unexpected geological, technical, drilling,
construction, processing and transportation problems; the impacts of drought, wildfires and severe weather events; availability of insurance;
fluctuations in foreign exchange and interest rates; stock market volatility; general economic, market and business conditions, including
uncertainty in the demand for oil and gas and economic activity in general; changes in interest rates and inflation; uncertainties associated
with regulatory approvals; geopolitical conflicts, including the Russian invasion of Ukraine and the conflict between Israel and Hamas;
uncertainty of government policy changes; the impact of the implementation of the Canada-United States-Mexico Agreement; uncertainty regarding
the benefits and costs of dispositions; failure to complete acquisitions and dispositions; uncertainties associated with credit facilities
and counterparty credit risk; and changes in income tax laws, tax laws, crown royalty rates and incentive programs relating to the oil
and gas industry; and other factors, many of which are outside the control of the Company. The impact of any one risk, uncertainty or
factor on a particular forward-looking statement is not determinable with certainty as these are interdependent and Veren's future course
of action depends on management's assessment of all information available at the relevant time.
Included in this press release are Veren's 2024 guidance
in respect of capital expenditures and average annual production which is based on various assumptions as to production levels, commodity
prices and other assumptions and are provided for illustration only and are based on budgets and forecasts that have not been finalized
and are subject to a variety of contingencies including prior years' results. The Company's return of capital framework is based on certain
facts, expectations and assumptions that may change and, therefore, this framework may be amended as circumstances necessitate or require.
To the extent such estimates constitute a "financial outlook" or "future oriented financial information" in this press
release, as defined by applicable securities legislation, such information has been approved by management of Veren. Such financial outlook
or future oriented financial information is provided for the purpose of providing information about management's current expectations
and plans relating to the future. Readers are cautioned that reliance on such information may not be appropriate for other purposes.
Additional information on these and other factors
that could affect Veren's operations or financial results are included in Veren's reports on file with Canadian and U.S. securities regulatory
authorities. Readers are cautioned not to place undue reliance on this forward-looking information, which is given as of the date it is
expressed herein. Veren undertakes no obligation to update publicly or revise any forward-looking statements, whether as a result of new
information, future events or otherwise, unless required to do so pursuant to applicable law. All subsequent forward-looking statements,
whether written or oral, attributable to Veren or persons acting on the Company's behalf are expressly qualified in their entirety by
these cautionary statements.
Credit ratings are intended to provide investors with
an independent measure of credit quality of an issue of securities. Credit ratings are not recommendations to purchase, hold or sell securities
and do not address the market price or suitability of a specific security for a particular investor. There is no assurance that any rating
will remain in effect for any given period of time or that any rating will not be revised or withdrawn entirely by a rating agency in
the future if, in its judgement, circumstances so warrant.
Product Type Production Information
The Company's annual aggregate production for the
three and six months ended June 30, 2024 and June 30, 2023 and the references to "natural gas", "crude oil"
and "condensate" reported in this Press Release consist of the following product types, as defined in NI 51-101 and using a
conversion ratio of 6 mcf : 1 bbl where applicable:
| |
Three months ended June 30 |
Six months ended June 30 |
| |
2024 |
2023 |
2024 |
2023 |
| Light & Medium Crude Oil (bbl/d) |
9,653 |
13,188 |
10,543 |
13,034 |
| Heavy Crude Oil (bbl/d) |
2,866 |
3,857 |
3,243 |
3,933 |
| Tight Oil (bbl/d) |
72,546 |
48,151 |
72,698 |
43,831 |
| Total Crude Oil (bbl/d) |
85,065 |
65,196 |
86,484 |
60,798 |
| |
|
|
|
|
| NGLs (bbl/d) |
42,375 |
34,108 |
43,578 |
34,751 |
| |
|
|
|
|
| Shale Gas (mcf/d) |
387,893 |
184,105 |
388,162 |
165,883 |
| Conventional Natural Gas (mcf/d) |
3,357 |
8,859 |
5,066 |
9,542 |
| Total Natural Gas (mcf/d) |
391,250 |
192,964 |
393,228 |
175,425 |
| |
|
|
|
|
| Total production from continuing operations (boe/d) |
192,648 |
131,465 |
195,600 |
124,787 |
| |
Three months ended June 30 |
Six months ended June 30 |
| |
2024 |
2023 |
2024 |
2023 |
| Light & Medium Crude Oil (bbl/d) |
9,653 |
13,190 |
10,543 |
13,035 |
| Heavy Crude Oil (bbl/d) |
2,866 |
3,857 |
3,243 |
3,933 |
| Tight Oil (bbl/d) |
72,546 |
63,812 |
72,698 |
58,528 |
| Total Crude Oil (bbl/d) |
85,065 |
80,859 |
86,484 |
75,496 |
| |
|
|
|
|
| NGLs (bbl/d) |
42,375 |
39,399 |
43,578 |
39,992 |
| |
|
|
|
|
| Shale Gas (mcf/d) |
387,893 |
199,781 |
388,162 |
180,726 |
| Conventional Natural Gas (mcf/d) |
3,357 |
8,859 |
5,066 |
9,542 |
| Total Natural Gas (mcf/d) |
391,250 |
208,640 |
393,228 |
190,268 |
| |
|
|
|
|
| Total average daily production (boe/d) |
192,648 |
155,031 |
195,600 |
147,199 |
NI 51-101 includes condensate within the natural gas
liquids (NGLs) product type. The Company has disclosed condensate as combined with crude oil and/or separately from other natural gas
liquids in this press release since the price of condensate as compared to other natural gas liquids is currently significantly higher
and the Company believes that this crude oil and condensate presentation provides a more accurate description of its operations and results
therefore.
The Karr West pad's average peak 30-day rate, referred
to herein, of 1,300 boe/d per well consisted of the following product types: 60% light oil, 7% NGLs and 33% shale gas.
In the Kaybob Duvernay, one pad brought on stream
in the Volatile Oil window during second quarter, referred to above, that has been on stream for over 30 days generating an average peak
30-day rate of 1,300 boe/d per well had the following product types: 66% condensate, 11% NGL and 23% shale gas.
Reserves and Drilling Data
The reserves information contained in this press
release has been prepared in accordance with NI 51-101.
Where applicable, a barrels of oil equivalent ("boe")
conversion rate of six thousand cubic feet of natural gas to one barrel of oil equivalent (6mcf:1bbl) has been used based on an energy
equivalent conversion method primarily applicable at the burner tip. Given that the value ratio based on the current price of crude oil
as compared to natural gas is significantly different than the energy equivalency of the 6:1 conversion ratio, utilizing the 6:1 conversion
ratio may be misleading as an indication of value.
This press release contains metrics commonly used
in the oil and natural gas industry, including "netbacks" and "decline rate". 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.
Readers are cautioned as to the reliability of oil and gas metrics used in this press release.
Netback is calculated on a per boe basis as oil and
gas sales, less royalties, operating and transportation expenses and realized derivative gains and losses. Netback is used by management
to measure operating results on a per boe basis to better analyze performance against prior periods on a comparable basis.
Decline rate is the reduction in the rate of production
from one period to the next. This rate is usually expressed on an annual basis. Management uses decline rate to assess future productivity
of the Company's assets.
There are numerous uncertainties inherent in estimating
quantities of crude oil, natural gas and NGLs reserves and the future cash flows attributed to such reserves. The reserve and associated
cash flow information set forth above are estimates only. In general, estimates of economically recoverable crude oil, natural gas and
NGLs reserves and the future net cash flows therefrom are based upon a number of variable factors and assumptions, such as historical
production from the properties, production rates, ultimate reserve recovery, timing and amount of capital expenditures, marketability
of oil and natural gas, royalty rates, the assumed effects of regulation by governmental agencies and future operating costs, all of which
may vary materially. For these reasons, estimates of the economically recoverable crude oil, NGLs and natural gas reserves attributable
to any particular group of properties, classification of such reserves based on risk of recovery and estimates of future net revenues
associated with reserves prepared by different engineers, or by the same engineers at different times, may vary. The Company's actual
production, revenues, taxes and development and operating expenditures with respect to its reserves will vary from estimates thereof and
such variations could be material.
Individual properties may not reflect the same confidence
level as estimates of reserves for all properties due to the effects of aggregation. This press release contains estimates of the net
present value of the Company's future net revenue from our reserves. Such amounts do not represent the fair market value of our reserves.
The recovery and reserve estimates of the Company's reserves provided herein are estimates only and there is no guarantee that the estimated
reserves will be recovered.
The reserve data provided in this news release presents
only a portion of the disclosure required under National Instrument 51-101. All of the required information is contained in the Company's
Annual Information Form for the year ended December 31, 2023, on SEDAR+ (accessible at www.sedarplus.ca and EDGAR (accessible at www.sec.gov/edgar.shtml)
and further supplemented by Material Change Reports as applicable.
FOR MORE INFORMATION ON VEREN, PLEASE CONTACT:
Sarfraz Somani, Manager, Investor Relations
Telephone: (403) 693-0020 Toll-free (US and Canada):
888-693-0020
Address: Veren Inc. Suite 2000, 585 - 8th Avenue S.W.
Calgary AB T2P 1G1
www.vrn.com
Veren shares are traded on the Toronto Stock Exchange
and New York Stock Exchange under the symbol VRN.
View original content:https://www.prnewswire.com/news-releases/veren-announces-q2-2024-results-302205898.html
SOURCE Veren Inc.
View original content: http://www.newswire.ca/en/releases/archive/July2024/25/c5214.html
%CIK: 0001545851
CO: Veren Inc.
CNW 06:30e 25-JUL-24
Crescent Point Energy (NYSE:CPG)
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Crescent Point Energy (NYSE:CPG)
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