Vermilion Energy Inc. Announces Results for the Three and Nine Months Ended September 30, 2024

CALGARY, AB, Nov. 6, 2024 /PRNewswire/ - Vermilion Energy Inc. ("Vermilion", "We", "Our", "Us" or the "Company") (TSX:VET) (NYSE:VET) is pleased to report operating and condensed financial results for the three and nine months ended September 30, 2024.

The unaudited interim financial statements and management discussion and analysis for the three and nine months ended September 30, 2024 will be available on the System for Electronic Document Analysis and Retrieval Plus ("SEDAR+") at www.sedarplus.ca, on EDGAR at www.sec.gov/edgar.shtml, and on Vermilion's website at www.vermilionenergy.com. 

Highlights

Q3 2024 fund flows from operations ("FFO")(1) was $275 million ($1.76/basic share)(2), representing a 16% increase over the prior quarter, primarily due to stronger European gas prices. Benchmark TTF Day Ahead pricing increased 14% over the prior quarter, averaging $15.52/mmbtu in Q3 2024, and European gas was the only commodity in our portfolio that increased quarter-over-quarter and year-over-year. As a result of strong European gas prices, our corporate average realized natural gas price in Q3 2024 was $6.57/mcf, compared to $0.69/mcf for the AECO 5A benchmark.

Net earnings for Q3 2024 was $52 million ($0.33/basic share), an increase of $134 million over the prior quarter primarily due to a more normalized mark-to-market adjustment on our hedge book.

We invested $121 million in exploration and development ("E&D") capital expenditures(3), resulting in free cash flow ("FCF")(4) of $154 million ($0.98/basic share)(5), of which $59 million was returned to shareholders, including $19 million in dividends and $40 million of share buybacks, representing 45% of excess FCF ("EFCF")(4).

Year-to-date, we have returned $180 million ($1.13/basic share) to shareholders through dividends and share buybacks, representing 38% of EFCF, including the repurchase and cancellation of 8.0 million shares which has reduced our outstanding common shares to 155.3 million as at September 30, 2024. We continue to repurchase shares in Q4 2024 and are on track to return 10% of our market capitalization to shareholders in 2024 between our fixed dividend and variable share repurchase program, and expect to continue providing ratable dividend increases and repurchasing shares in future periods.

Net debt(6) decreased by $73 million in Q3 2024 to $833 million, representing a net debt to trailing FFO ratio(7) of 0.6 times, the lowest in 15 years.

Production during Q3 2024 averaged 84,173 boe/d(8) (56% natural gas and 44% crude oil and liquids), comprised of 53,936 boe/d(8) from our North American assets and 30,237 boe/d(8) from our International assets, and includes the impact from a planned turnaround in Australia and the partial shut-in of some Canadian gas production due to weak AECO pricing. Our Q3 2024 production represents an increase of 2% year-over-year, or 7% on a per share basis, reflecting the positive impact from our share repurchase program. Notably, production from our International assets has increased 16% over the prior year, including a 26% increase in natural gas production driven by new production from our SA-10 block in Croatia and higher runtime in Ireland.

In Germany, we successfully completed testing operations for our first deep gas exploration well drilled earlier this year. The well flow tested at a restricted rate of 17 mmcf/d(15) of natural gas with a wellhead pressure of 4,625 psi, which supports our expectation that deliverability would have been higher without testing equipment limitations. Tie-in operations are progressing to bring the well on production in the first half of 2025.

We commenced drilling on our second deep gas exploration well (0.3 net) in August 2024 and successfully completed drilling operations at the end of October 2024. We are pleased to report that we discovered gas within the reservoir and are now proceeding with completion and testing operations. Subsequent to the quarter, we commenced drilling on our third German deep gas exploration well (1.0 net) in October 2024. We anticipate results from the second well test and third well drilling operations in the first half of 2025.

In Croatia, we successfully increased production on the SA-10 block after commissioning the gas plant in late June 2024. Production in Q3 2024 averaged 1,855 boe/d (100% European natural gas) and currently exceeds 2,000 boe/d. On the SA-7 block, we completed testing on the third well of our four-well program, at a reservoir depth of 885 metres, which flow tested at 5.6 mmcf/d(16) of natural gas.

During Q3 2024 we achieved a major safety milestone in Ireland, where we celebrated two years and one million man-hours without a lost time incident, a testament to Vermilion's high standard for safety in our operations.

In Canada, we completed and brought on production five (5.0 net) Montney liquids-rich shale gas wells during the third quarter. These wells have produced at an average IP90 rate of over 1,000 boe/d(17) per well (43% liquids)(17), which is in line with expectations. The total drill, complete, equip and tie-in ("DCET") cost for the 9-21 pad was approximately $9.6 million per well as we continue to make progress towards our normalized targeted cost range of $9.0 to $9.5 million per well. The new battery and water infrastructure have achieved 99% run time since starting up and are contributing to these cost savings.

In conjunction with our Q3 2024 release, we announced a quarterly cash dividend of $0.12 per common share, payable on January 15, 2025 to shareholders of record on December 31, 2024.

We have tightened our 2024 production guidance range to 84,000 to 85,000 boe/d to reflect increased certainty on annual production levels, and our capital budget of $600 to $625 million remains unchanged. We are in the process of finalizing our 2025 budget which will target modest production growth on a similar capital spending level as 2024, while maintaining our return of capital payout target at 50% of EFCF.

($M except as indicated)

Q3 2024

Q2 2024

Q3 2023

YTD 2024

YTD 2023

Financial

Petroleum and natural gas sales

490,095

478,925

475,532

1,477,055

1,499,586

Cash flows from operating activities

134,547

266,322

118,436

755,164

680,697

Fund flows from operations (1)

275,024

236,703

270,218

943,085

770,494

    Fund flows from operations ($/basic share) (2)

1.76

1.48

1.65

5.93

4.70

    Fund flows from operations ($/diluted share) (2)

1.75

1.47

1.62

5.87

4.61

Net earnings (loss)

51,697

(82,425)

57,309

(28,423)

565,549

    Net earnings (loss) ($/basic share)

0.33

(0.52)

0.35

(0.18)

3.45

Cash flows used in investing activities

145,828

153,025

170,404

480,196

443,503

Capital expenditures (3)

121,269

110,610

125,639

422,321

447,304

Acquisitions (9)

1,642

5,450

5,238

16,844

247,294

Dispositions









182,152

Asset retirement obligations settled

15,332

11,745

13,582

32,052

28,029

Repurchase of shares

40,106

46,555

11,645

123,070

66,102

Cash dividends ($/share)

0.12

0.12

0.10

0.36

0.30

Dividends declared

18,642

18,981

16,367

56,806

49,023

    % of fund flows from operations (10)

7 %

8 %

6 %

6 %

6 %

Payout (12)

155,243

141,336

155,588

511,179

524,356

    % of fund flows from operations (11)

56 %

60 %

58 %

54 %

68 %

Free cash flow (4)

153,755

126,093

144,579

520,764

323,190

Long-term debt

903,354

915,364

966,505

903,354

966,505

Net debt (6)

833,331

906,715

1,242,522

833,331

1,242,522

Net debt to four quarter trailing fund flows from operations (7)

0.6

0.7

1.2

0.6

1.2

Operational

Production (8)

    Crude oil and condensate (bbls/d)

29,837

32,879

31,417

31,797

31,407

    NGLs (bbls/d)

7,547

7,196

7,344

7,264

7,261

    Natural gas (mmcf/d)

280.73

269.39

263.80

274.93

265.09

    Total (boe/d)

84,173

84,974

82,727

84,881

82,849

Average realized prices

    Crude oil and condensate ($/bbl)

103.55

108.93

106.94

105.54

100.64

    NGLs ($/bbl)

27.49

31.61

27.77

30.99

30.89

    Natural gas ($/mcf)

6.57

5.69

6.32

6.13

8.08

Production mix (% of production)

    % priced with reference to WTI

32 %

32 %

34 %

32 %

35 %

    % priced with reference to Dated Brent

13 %

15 %

13 %

14 %

12 %

    % priced with reference to AECO

33 %

33 %

34 %

33 %

34 %

    % priced with reference to TTF and NBP

22 %

20 %

19 %

21 %

19 %

Netbacks ($/boe)

    Operating netback (12)

41.89

40.32

49.30

48.23

46.42

    Fund flows from operations ($/boe) (13)

34.78

30.87

35.76

39.99

34.19

Average reference prices

    WTI (US $/bbl)

75.10

80.57

82.26

77.54

77.40

    Dated Brent (US $/bbl)

80.18

84.94

86.76

82.79

82.14

    AECO ($/mcf)

0.69

1.18

2.61

1.45

2.76

    TTF ($/mcf)

15.52

13.62

14.11

13.62

17.39

Share information ('000s)

Shares outstanding - basic

155,348

158,174

163,666

155,348

163,666

Shares outstanding - diluted (14)

158,912

161,672

167,904

158,912

167,904

Weighted average shares outstanding - basic

156,624

159,525

163,946

159,114

163,848

Weighted average shares outstanding - diluted (14)

157,502

161,069

166,392

160,743

167,167

(1)

Fund flows from operations (FFO) is a total of segments measure comparable to net earnings (loss) that is comprised of sales less royalties, transportation, operating, G&A, corporate income tax, PRRT, windfall taxes, interest expense, equity based compensation settled in cash, realized gain (loss) on derivatives, realized foreign exchange gain (loss), and realized other income (expense). The measure is used to assess the contribution of each business unit to Vermilion's ability to generate income necessary to pay dividends, repay debt, fund asset retirement obligations, and make capital investments. FFO does not have a standardized meaning under IFRS and therefore may not be comparable to similar measures provided by other issuers. More information and a reconciliation to primary financial statement measures can be found in the "Non-GAAP and Other Specified Financial Measures" section of this document.

(2)

Fund flows from operations per share (basic and diluted) are supplementary financial measures and are not standardized financial measures under IFRS, and therefore may not be comparable to similar measures disclosed by other issuers. They are calculated using FFO (a total of segments measure) and basic/diluted shares outstanding. The measure is used to assess the contribution per share of each business unit. More information and a reconciliation to primary financial statement measures can be found in the "Non-GAAP and Other Specified Financial Measures" section of this document.

(3)

Capital expenditures is a non-GAAP financial measure that is the sum of drilling and development costs and exploration and evaluation costs from the Consolidated Statements of Cash Flows. More information and a reconciliation to primary financial statement measures can be found in the "Non-GAAP and Other Specified Financial Measures" section of this document.

(4)

Free cash flow (FCF) and excess free cash flow (EFCF) are non-GAAP financial measures comparable to cash flows from operating activities. FCF is comprised of FFO less drilling and development and exploration and evaluation expenditures and EFCF is FCF less payments on lease obligations and asset retirement obligations settled. More information and a reconciliation to primary financial statement measures can be found in the "Non-GAAP and Other Specified Financial Measures" section of this document.

(5)

Free cash flow per basic share is a non-GAAP supplementary financial measure and is not a standardized financial measure under IFRS and may not be comparable to similar measures disclosed by other issuers. It is calculated using FCF and basic shares outstanding.

(6)

Net debt is a capital management measure most directly comparable to long-term debt and is comprised of long-term debt (excluding unrealized foreign exchange on swapped USD borrowings) plus adjusted working capital (defined as current assets less current liabilities, excluding current derivatives and current lease liabilities). More information and a reconciliation to primary financial statement measures can be found in the "Non-GAAP and Other Specified Financial Measures" section of this document.

(7)

Net debt to four quarter trailing fund flows from operations is a supplementary financial measure and is not a standardized financial measure under IFRS. It may not be comparable to similar measures disclosed by other issuers and is calculated using net debt (capital management measure) and FFO (total of segment measure). The measure is used to assess the ability to repay debt. Information in this document is included by reference; refer to the "Non-GAAP and Other Specified Financial Measures" section of this document.

(8)

Please refer to Supplemental Table 4 "Production" of the accompanying Management's Discussion and Analysis for disclosure by product type.

(9)

Acquisitions is a non-GAAP financial measure that is calculated as the sum of acquisitions, net of cash acquired, and acquisitions of securities from the Consolidated Statements of Cash Flows, Vermilion common shares issued as consideration, the estimated value of contingent consideration, the amount of acquiree's outstanding long-term debt assumed, and net acquired working capital. More information and a reconciliation to primary financial statement measures can be found in the "Non-GAAP and Other Specified Financial Measures" section of this document.

(10)

Dividends % of FFO is a supplementary financial measure that is not standardized under IFRS and may not be comparable to similar measures disclosed by other issuers. Dividends % of FFO is calculated as dividends declared divided by FFO. The ratio is used by management as a metric to assess the cash distributed to shareholders.