Adjusted funds flow (AFF)1 of $5.49/share
Record annual production of 22,587 boe / day (27% increase over 2022)
Return on average capital employed (ROACE)1 of 21%
Increased total proved plus probable Net Present Value by 9% year-over-year to $2.8 billion (NPV10)
2024 guidance reaffirmed
CALGARY, AB, March 6, 2024 /CNW/ – Kiwetinohk Energy Corp. (TSX:KEC) today reported its 2023 financial and operational results and year-end reserves evaluation. As companion documents to this news release, please review the Company’s year end 2023 management discussion and analysis (MD&A), consolidated financial statements and annual information form (available on kiwetinohk.com or www.sedarplus.ca) for additional financial and operational details.
Message to shareholders
“I am extremely pleased with the team’s performance throughout 2023. Kiwetinohk delivered robust financial and operational results, meeting or exceeding corporate expectations,” said Pat Carlson, Chief Executive Officer.
“This success is underscored by 27% annual production growth culminating in a record annual production level of 22,587 boe/d and year-end monthly exit production of approximately 30,150 boe/d. Equally important, our commitment to safety remained unwavering with the team executing a significant capital program with zero lost time incidents or reportable spills. The strength of the Company’s reserves continues to demonstrate the inherent value of our asset base. Our updated reserves report confirms a notable share price value gap. As of December 31, 2023, our proved developed producing (PDP) reserves alone are estimated to have a before tax net present value discounted at 10% (NPV10) of $15.70/share exceeding the year end trading price of $11.35/share by approximately 38%. Total proved (1P) and total proved plus probable (2P) NPV 10 values are estimated at $35.79/share and $63.10/share, respectively, reinforcing the underlying value of our upstream development program which is further bolstered by our current portfolio of gas fired and renewable power development projects which continue to progress.
“Kiwetinohk is executing on its 2024 budget priorities with a focus on financial discipline given anticipated ongoing volatility in commodity prices. Since year end, three Duvernay wells at the 8-23 pad have been brought on production and we have finished drilling our first two wells of our 2024 program at the 1-27 pad; one in the Duvernay and one in the Montney. Looking forward, the upstream development program is on track, production is substantially hedged at favourable prices over the balance of the year and our operating and financial outlook remains in-line with our guidance provided last December.
“We continue to make progress against project milestones across our power portfolio and are encouraged by the Alberta government’s February 28, 2024 announced new policy direction for renewable energy development which we believe brings clarity to solar developments going forward and which our projects are well positioned to address. We continue to pro-actively engage with federal and provincial governments to get better clarity on the broader evolving electricity policy and regulation and its potential impact on power development. In January 2024, extreme cold weather led to peak energy demand in Alberta, demonstrating electricity supply challenges that we believe will persist into the future. Kiwetinohk’s power development portfolio would provide a combination of power sources that would help Alberta address these supply challenges through clean, reliable, dispatchable and affordable power.”
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1 Non-GAAP and other financial measure that does not have any standardized meaning under IFRS and therefore may not be comparable to similar measures presented by other entities. See “Non-GAAP and Other Financial Measures” section of the Company’s MD&A for the year ended December 31, 2023.
Financial and operating results for the quarter
Q4 2023
Q4 2022
2023
2022
Production
Oil & condensate (bbl/d)
8,407
8,423
7,183
6,197
NGLs (bbl/d)
3,507
2,664
2,769
2,012
Natural gas (Mcf/d)
76,756
81,949
75,810
57,859
Total (boe/d)
24,707
24,745
22,587
17,852
Oil and condensate % of production
34 %
34 %
32 %
35 %
NGL % of production
14 %
11 %
12 %
11 %
Natural gas % of production
52 %
55 %
56 %
54 %
Realized prices
Oil & condensate ($/bbl)
95.66
104.96
96.90
115.82
NGLs ($/bbl)
51.44
68.82
53.07
74.06
Natural gas ($/Mcf)
3.32
8.12
3.76
8.69
Total ($/boe)
50.17
70.04
49.95
76.72
Royalty expense ($/boe)
(4.84)
(5.72)
(4.72)
(6.78)
Operating expenses ($/boe)
(8.55)
(7.20)
(8.52)
(9.70)
Transportation expenses ($/boe)
(5.49)
(5.27)
(5.61)
(5.31)
Operating netback 1 ($/boe)
31.29
51.85
31.10
54.93
Realized gain (loss) on risk management ($/boe) 2
0.23
(6.58)
1.50
(13.33)
Realized gain (loss) on risk management – purchases ($/boe) 2
1.20
(2.36)
1.69
(5.23)
Net commodity sales from purchases (loss) ($/boe) 1
(0.51)
3.16
(0.80)
7.07
Adjusted operating netback 1
32.21
46.07
33.49
43.44
Financial results ($000s, except per share amounts)
Commodity sales from production
114,038
159,457
411,826
499,898
Net commodity sales from purchases (loss) 1
(1,152)
7,174
(6,642)
46,069
Cash flow from operating activities
58,946
87,028
240,760
242,850
Adjusted funds flow from operations 1
63,697
101,506
241,311
264,082
Per share basic
1.46
2.30
5.49
6.00
Per share diluted
1.44
2.26
5.43
5.92
Net debt to annualized adjusted funds flow from operations 1
0.77
0.46
0.77
0.46
Free funds flow deficiency from operations (excluding acquisitions/dispositions) 1
(12,713)
(1,202)
(65,674)
(5,647)
Net income (loss)
48,302
115,308
111,896
190,989
Per share basic
1.11
2.61
2.54
4.34
Per share diluted
1.09
2.57
2.52
4.28
Capital expenditures prior to (dispositions) acquisitions 1
76,410
102,708
306,985
269,729
Net (dispositions) acquisitions
(18,000)
—
(19,995)
57,323
Capital expenditures and net (dispositions) acquisitions 1
58,410
102,708
286,990
327,052
Balance sheet ($000s, except share amounts)
Total assets
1,085,615
932,650
1,085,615
932,650
Long-term liabilities
305,735
221,731
305,735
221,731
Net debt 1
186,523
122,304
186,523
122,304
Adjusted working capital surplus (deficit) 1
7,565
(3,105)
7,565
(3,105)
Weighted average shares outstanding
Basic
43,710,734
44,168,157
43,971,108
44,045,613
Diluted
44,172,101
44,887,920
44,467,348
44,593,528
Shares outstanding end of period
43,662,644
44,176,710
43,662,644
44,176,710
Return on average capital employed (“ROACE”) 1
21 %
30 %
Reserves
Proved reserves (MMboe) 3
123.2
125.5
Proved reserves per share (boe) 3
2.8
2.9
Proved plus probable reserves (MMboe) 3
224.5
214.5
Proved plus probable reserves per share (boe) 3
5.1
4.9
1 – Non-GAAP and other financial measure that does not have any standardized meaning under IFRS and therefore may not be comparable to similar measures presented by other entities. See “Non-GAAP and Other Financial Measures” section of the Company’s MD&A.
2 – Realized gain (loss) on risk management contracts includes settlement of financial hedges on production and foreign exchange, with gains on contracts associated with purchases presented separately.
3 – Oil and natural gas reserves are as determined by the Company’s independent qualified reserve evaluator with an effective date of December 31 for the years shown in accordance with the Canadian Oil and Gas Evaluation Handbook and are shown as net working interest reserves before royalties.
Fourth quarter highlights
Record annual production of 22,587 boe/d, a 27% increase year-over-year. Fourth quarter production of 24,707 boe/d, grew 16.4% over the third quarter of 2023; year-end exit production for the month of December 2023 was approximately 30,150 boe/d.
Strong quarterly operating netback2 of $31.29/boe drove adjusted funds from operations during the fourth quarter of $63.7 million, or $1.46/share. This represents a 14% increase over the third quarter of 2023 and results in annual adjusted funds from operations2 of