CALGARY, Alberta – Peyto Exploration & Development Corp. (“Peyto” or the “Company”) is pleased to report operating and financial results for the first quarter of 2023. A 71% operating margin1,2, combined with a 32% profit margin3 in the quarter delivered a return on capital employed (“ROCE”4) of 14% and return on equity (“ROE”4) of 17%, on a trailing 12-month basis. Additional highlights included:
- Strong Funds from Operations5 of $1.02/diluted share – Generated $180 million in funds from operations (“FFO”) in Q1 2023, despite lower realized commodity prices, and current income tax of $19 million ($nil in Q1 2022).
- Free Funds Flow6 of $58 million – Free funds flow totaled $58 million in Q1 2023, down from $60 million in Q1 2022 due to lower realized commodity prices and current income tax, partially offset by lower total capital expenditures.
- Total Cash Costs7 of $1.52/Mcfe (or $0.99/Mcfe before royalties) – Quarterly cash costs of $0.99/Mcfe, before royalties of $0.53/Mcfe, were 6% higher than Q1 2022 due to inflationary pressures on costs. Q1 operating costs of $0.50/Mcfe, transportation of $0.24/Mcfe, G&A of $0.03/Mcfe and interest expense of $0.22/Mcfe resulted in a 71% operating margin. Peyto continues to have the lowest cash costs in the Canadian natural gas industry.
- Total Capital Expenditures8 of $122 million – A total of 19 gross wells (17.6 net) were drilled in the first quarter, 14 gross wells (13.2 net) were completed, and 14 gross wells (13.3 net) were brought on production. Facilities and pipeline projects totaled $32 million in the quarter and included $13 million for the construction of the 23 km large diameter pipeline that directly connects Peyto’s Swanson gas plant to the Cascade power plant.
- Net debt9 down 18% – Net debt was reduced by $186 million from Q1 2022 to $878 million. Interest costs increased 5% from $0.21/Mcfe in Q1 2022 to $0.22/Mcfe in Q1 2023, while the average Bank of Canada rate increased from 0.33% in Q1 2022 to 4.33% in Q1 2023. Net debt has now fallen for 10 consecutive quarters.
- Earnings of $0.51/share, Dividends of $0.33/share ($0.11/month) – Earnings of $90 million were generated in the quarter while dividends of $58 million were paid to shareholders.
- Strong Track Record of Shareholder Returns – Over the past 10 quarters, Peyto has increased production from 78,200 boe/d to 102,900 boe/d, returned $183.5 million of dividends to shareholders, while reducing net debt by $300 million.
First Quarter 2023 in Review
Peyto was active with four drilling rigs operating in the first quarter, as well as pipeline and infrastructure projects including well optimization programs and the construction of a 23 km pipeline that directly connects Peyto’s Swanson gas plant to the Cascade power plant. Production volumes were 1% higher in the quarter compared to Q1 2022, however, FFO decreased to $179 million from $204 million in Q1 2022, due to a decline in realized commodity prices and a current tax provision in the quarter of $19 million ($nil in Q1 2022). Natural gas prices were particularly volatile in the quarter with many benchmarks decreasing sharply from the Q1 2022 averages. The average daily Henry Hub price was down 42% and the average daily AECO price was down 32% in the quarter compared to the first quarter of 2022. The average daily Malin price, however, was 235% higher as a result of supply shortages in California. So, while Peyto benefited from NYMEX hedging gains, the Company’s Malin hedges resulted in hedging losses. Going forward, Peyto has 40,000 MMBtu/d of unhedged exposure to Malin prices which are expected to remain volatile. Operating costs increased to $0.50/Mcfe in the quarter from $0.41/Mcfe in Q1 2022 due to increased plant and well maintenance, and inflationary pressures on insurance, power, trucking, fuels, and lubricants. The first quarter of each year typically represents the high-water mark for operating costs due to increased expenses in cold weather conditions, and operating costs are expected to taper down through 2023. Despite the significant and rapid drop in natural gas prices in the first quarter, Peyto’s profit margin of 32% remained strong and drove quarterly earnings of $90 million, allowing the Company to declare $58 million in dividends to shareholders.
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1 This press release contains certain non-GAAP and other financial measures to analyze financial performance, financial position, and cash flow including, but not limited to “operating margin”, “profit margin”, “return on capital”, “return on equity”, “netback”, “funds from operations”, “free funds flow”, “total cash costs”, and “net debt”. These non-GAAP and other financial measures do not have any standardized meaning prescribed under IFRS and therefore may not be comparable to similar measures presented by other entities. The non-GAAP and other financial measures should not be considered to be more meaningful than GAAP measures which are determined in accordance with IFRS, such as earnings, cash flow from operating activities, and cash flow used in investing activities, as indicators of Peyto’s performance. See “Non-GAAP and Other Financial Measures” included at the end of this press release and in Peyto’s most recently filed MD&A for an explanation of these financial measures and reconciliation to the most directly comparable financial measure under IFRS.
2 Operating Margin is a non-GAAP financial ratio. See “non-GAAP and Other Financial Measures” in this news release.
3 Profit Margin is a non-GAAP financial ratio. See “non-GAAP and Other Financial Measures” in this news release.
4 Return on capital employed and return on equity are non-GAAP financial ratios. See “non-GAAP and Other Financial Measures” in this news release and in the Q1 2023 MD&A.
5 Funds from operations is a non-GAAP financial measure. See “non-GAAP and Other Financial Measures” in this news release and in the Q1 2023 MD&A.
6 Free funds flow is a non-GAAP financial measure. See “non-GAAP and Other Financial Measures” in this news release and in the Q1 2023 MD&A.
7 Total cash costs is a non-GAAP financial ratio defined as the sum of royalties, operating expenses, transportation expenses, G&A and interest, on a per Mcfe basis. See “non-GAAP and Other Financial Measures” in this news release.
8 Total capital expenditures is a non-GAAP financial measure. See “non-GAAP and Other Financial Measures” in this news release and in the Q1 2023 MD&A.
9 Net debt is a non-GAAP financial measure. See “non-GAAP and Other Financial Measures” in this news release and in the Q1 2023 MD&A.
| Three Months Ended Mar 31 | % | |||||
| 2023 | 2022 | Change | ||||
| Operations | ||||||
| Production | ||||||
| Natural gas (Mcf/d) | 544,278 | 535,660 | 2 | % | ||
| NGLs (bbl/d) | 12,205 | 12,273 | -1 | % | ||
| Thousand cubic feet equivalent (Mcfe/d @ 1:6) | 617,509 | 609,295 | 1 | % | ||
| Barrels of oil equivalent (boe/d @ 6:1) | 102,918 | 101,549 | 1 | % | ||
| Production per million common shares (boe/d) | 589 | 601 | -2 | % | ||
| Product prices (after hedging) | ||||||
| Natural gas ($/Mcf) | 3.91 | 4.08 | -4 | % | ||
| NGLs ($/bbl) | 79.03 | 81.66 | -3 | % | ||
| Operating expenses ($/Mcfe) | 0.50 | 0.41 | 22 | % | ||
| Transportation ($/Mcfe) | 0.24 | 0.28 | -14 | % | ||
| Field netback(1) ($/Mcfe) | 3.82 | 3.96 | -4 | % | ||
| General & administrative expenses ($/Mcfe) | 0.03 | 0.03 | – | |||
| Interest expense ($/Mcfe) | 0.22 | 0.21 | 5 | % | ||
| Financial ($000, except per share) | ||||||
| Revenue and realized hedging losses (2) | 278,332 | 286,894 | -3 | % | ||
| Funds from operations(1) | 179,817 | 203,492 | -12 | % | ||
| Funds from operations per share – basic(1) | 1.03 | 1.20 | -14 | % | ||
| Funds from operations per share – diluted(1) | 1.02 | 1.17 | -13 | % | ||
| Total dividends declared | 57,677 | 25,358 | 127 | % | ||
| Total dividends declared per share | 0.33 | 0.15 | 120 | % | ||
| Earnings | 89,937 | 97,816 | -8 | % | ||
| Earnings per share – basic | 0.51 | 0.58 | -12 | % | ||
| Earnings per share – diluted | 0.51 | 0.56 | -9 | % | ||
| Total capital expenditures(1) | 121,802 | 143,331 | -15 | % | ||
| Corporate acquisition | – | 22,220 | -100 | % | ||
| Total payout ratio(1) | 100% | 83% | 20 | % | ||
| Weighted average common shares outstanding – basic | 174,778,048 | 169,058,178 | 3 | % | ||
| Weighted average common shares outstanding – diluted | 176,570,311 | 173,320,559 | 2 | % | ||
| Net debt(1) | 877,827 | 1,064,086 | -18 | % | ||
| Shareholders’ equity | 2,305,076 | 1,633,557 | 41 | % | ||
| Total assets | 4,119,135 | 3,852,410 | 7 | % | ||
(1) This is a Non-GAAP financial measure or ratio. See “non-GAAP and Other Financial Measures” in this news release and in the Q1 2023 MD&A
(2) Excludes revenue from sale of third-party volumes
Exploration & Development
The bulk of first quarter 2023 activity was spread out amongst the existing core areas of Greater Sundance and Greater Brazeau. Additionally, three wells were drilled in the Minehead/Whitehorse region as part of a delineation and farm-in program to earn certain offsetting lands. Target formations were also widespread, as summarized in the following table.
| Zone | |||||||
| Area | Cardium | Dunvegan | Notikewin | Falher | Wilrich | Bluesky | Total |
| Greater Sundance Area | – | – | 2 | 5 | – | – | 7 |
| Greater Brazeau Area | 1 | – | 5 | – | 3 | – | 9 |
| Minehead/Whitehorse | – | – | – | – | 3 | – | 3 |
| Total | 1 | – | 7 | 5 | 6 | – | 19 |
Average measured depth drilled increased 11% in the quarter compared to fourth quarter of 2022 as Peyto drilled the longest average wells in the Company’s history. The pursuit of extended reach horizontal (“ERH”) wells resulted in lower costs per meter drilled as compared to the previous quarter. Although inflationary pressures have eased on drilling operations, completion costs per meter and per stage were up 5% and 13%, respectively, due to service rate increases as compared to the previous quarter.
| 2015 | 2016 | 2017 | 2018 | 2019 | 2020 | 2021 | 2022 | 2022 Q1 |
2022 Q2 |
2022 Q3 |
2022 Q4 |
2023 Q1 |
|
| Gross Hz Spuds | 140 | 126 | 135 | 70 | 61 | 64 | 95 | 95 | 29 | 23 | 23 | 20 | 19 |
| Measured Depth (m) | 4,309 | 4,197 | 4,229 | 4,020 | 3,848 | 4,247 | 4,453 | 4,611 | 4,291 | 4,571 | 4,994 | 4692 | 5,198 |
| Drilling ($MM/well) | $2.16 | $1.82 | $1.90 | $1.71 | $1.62 | $1.68 | $1.89 | $2.56 | $2.13 | $2.56 | $2.90 | $2.80 | $3.05 |
| $ per meter | $501 | $433 | $450 | $425 | $420 | $396 | $424 | $555 | $496 | $560 | $580 | $596 | $587 |
| Completion ($MM/well) | $1.21 | $0.86 | $1.00 | $1.13 | $1.01* | $0.94 | $1.00 | $1.35 | $1.22 | $1.16 | $1.49 | 1.58 | $1.73 |
| Hz Length (m) | 1,531 | 1,460 | 1,241 | 1,348 | 1,484 | 1,682 | 1,612 | 1,661 | 1,529 | 1,602 | 1,654 | 1870 | 1,947 |
| $ per Hz Length (m) | $792 | $587 | $803 | $751 | $679 | $560 | $620 | $813 | $801 | $727 | $902 | $845 | $888 |
| $ ‘000 per Stage | $115 | $79 | $81 | $51 | $38 | $36 | $37 | $47 | $44 | $40 | $51 | $52 | $59 |
*Peyto’s Montney well is excluded from drilling and completion cost comparison.
Capital Expenditures
During the first quarter of 2023, Peyto drilled 19 gross (17.6 net) wells, completed 14 gross (13.2 net) wells, and brought 14 gross (13.3 net) wells on production for drilling, completions, equipping and tie-in capital of $89 million. Facilities and major pipeline projects included $12.9 million for the construction of the 23 km large diameter pipeline that directly connects the Company’s Swanson gas plant to the Cascade power plant near the town of Edson, Alberta, and $18.8 million for other infrastructure projects, including debottlenecking pipeline projects in the Sundance and Brazeau areas. Land and seismic investments totaled $1.3 million in the quarter.
Commodity Prices
Peyto’s natural gas was sold in Q1 2023 at various hubs including AECO, Empress, Malin, Dawn, Ventura, Emerson 2 and Henry Hub using both physical fixed price and basis transactions to access those locations (diversification activities). Natural gas prices were left to float on daily or monthly pricing or locked in using fixed price financial and physical swaps at those hubs. In Q1 2023, net of diversification activities of $0.62/Mcf, Peyto realized a natural gas price of $5.35/Mcf before natural gas hedging losses reduced this price to $3.91/Mcf. Peyto’s natural gas hedging activity resulted in a realized loss of $1.44/Mcf, due mainly to high Malin prices in the quarter, averaging US$18.98/MMBtu, partially offset by realized gains on NYMEX hedges. Peyto’s Malin hedges ended on March 31, 2023 and the Company has floating price exposure on its Malin contract through to October 31, 2024 as noted below in the “Marketing Update” section of this news release.
Condensate and pentanes volumes were sold in Q1 2023 for an average price of $103.06/bbl, which is down 18% from $125.81/bbl in Q1 2022 and Peyto realized a marginal premium over the Q1 2023 Canadian WTI oil price of $102.90/bbl. Butane and propane volumes were sold in combination at an average price of $39.20/bbl, or 38% of light oil price, down 26% from $52.68/bbl in Q1 2022, due to increased NGL supplies. NGL hedging gains increased the combined realized NGL price of $76.15/bbl by $2.88/bbl to $79.03 in Q1 2023.
Peyto’s realized prices for the three months ended March 31, 2023 and 2022 and are shown in the following table.
| Peyto Realized Commodity Prices | Three Months Ended March 31 |
|||
| 2023 | 2022 | |||
| Natural gas ($/Mcf) | 5.97 | 5.52 | ||
| Diversification activities ($/Mcf) | (0.62) | (0.66) | ||
| Realized natural gas price – before hedging ($/Mcf) | 5.35 | 4.86 | ||
| Gas hedging loss ($/Mcf) | (1.44) | (0.78) | ||
| Realized natural gas price – after hedging and diversification ($/Mcf) | 3.91 | 4.08 | ||
| Condensate and Pentanes Plus(1) ($/bbl) | 103.06 | 125.81 | ||
| Other Natural gas liquids(1) ($/bbl) | 39.20 | 52.68 | ||
| NGL price – before hedging ($/bbl) | 76.15 | 95.90 | ||
| NGL hedging gain (loss) ($/bbl) | 2.88 | (14.24) | ||
| Realized NGL price – after hedging ($/bbl) | 79.03 | 81.66 | ||
Peyto gas has an average heating value of approx. 1.15GJ/Mcf.
1Liquids prices are Peyto realized prices in Canadian dollars adjusted for fractionation, transportation, and market differentials.
Financial Results
The Company’s realized price for natural gas in Q1 2023 was $5.97/Mcf, prior to $0.62/Mcf of market diversification activities and a $1.44/Mcf hedging loss, while its realized liquids price was $76.15/bbl, before a $2.88/bbl hedging gain, which yielded a combined revenue stream of $5.10/Mcfe (including $0.09/Mcfe of other income). This net sales price was 3% lower than the $5.25/Mcfe realized in Q1 2022. Total cash costs of $1.52/Mcfe were consistent with the $1.53/Mcfe in Q1 2022 as increased operating costs were offset by royalties. Peyto’s cash netback (net sales price plus other income plus realized gain on foreign exchange less total cash costs), was $3.58/Mcfe driving a 71% operating margin. Historical cash costs and operating margins are shown in the following table:
| 2020 | 2021 | 2022 | 2023 | ||||||||||
| ($/Mcfe) | Q1 | Q2 | Q3 | Q4 | Q1 | Q2 | Q3 | Q4 | Q1 | Q2 | Q3 | Q4 | Q1 |
| Revenue (1) | 2.30 | 1.73 | 2.15 | 2.71 | 3.70 | 2.92 | 3.33 | 4.42 | 5.25 | 5.48 | 5.01 | 5.74 | 5.10 |
| Royalties | 0.12 | 0.06 | 0.14 | 0.18 | 0.29 | 0.26 | 0.36 | 0.53 | 0.60 | 0.95 | 0.70 | 0.72 | 0.53 |
| Op Costs | 0.39 | 0.36 | 0.32 | 0.31 | 0.36 | 0.35 | 0.35 | 0.32 | 0.41 | 0.39 | 0.38 | 0.41 | 0.50 |
| Transportation | 0.19 | 0.17 | 0.16 | 0.15 | 0.17 | 0.22 | 0.23 | 0.23 | 0.28 | 0.27 | 0.26 | 0.22 | 0.24 |
| G&A | 0.04 | 0.04 | 0.04 | 0.04 | 0.04 | 0.05 | 0.02 | 0.02 | 0.03 | 0.02 | 0.02 | 0.02 | 0.03 |
| Interest | 0.29 | 0.33 | 0.35 | 0.38 | 0.38 | 0.33 | 0.26 | 0.22 | 0.21 | 0.20 | 0.21 | 0.21 | 0.22 |
| Cash cost pre-royalty | 0.91 | 0.90 | 0.87 | 0.88 | 0.95 | 0.95 | 0.86 | 0.79 | 0.93 | 0.88 | 0.87 | 0.86 | 0.99 |
| Total Cash Costs | 1.03 | 0.96 | 1.01 | 1.06 | 1.24 | 1.21 | 1.22 | 1.32 | 1.53 | 1.83 | 1.57 | 1.58 | 1.52 |
| Netback | 1.27 | 0.77 | 1.14 | 1.65 | 2.46 | 1.71 | 2.11 | 3.10 | 3.72 | 3.65 | 3.44 | 4.16 | 3.58 |
| Operating Margin | 55% | 45% | 53% | 61% | 67% | 59% | 63% | 70% | 71% | 67% | 69% | 72% | 71% |
(1) Revenue includes other income, net third party sales and realized gains on foreign exchange.
Depletion, depreciation, and amortization charges of $1.39/Mcfe, along with provisions for current tax, deferred tax and stock-based compensation payments resulted in earnings of $1.62/Mcfe, or a 32% profit margin. Dividends to shareholders totaled $1.04/Mcfe.
Marketing Update
Hedging
In general, Peyto’s commodity risk management program is designed to smooth out the short-term fluctuations in the price of natural gas and natural gas liquids through future sales. This smoothing gives greater predictability of cashflows for the purposes of capital planning and dividend payments. The future sales are meant to be methodical and consistent to avoid speculation. In general, this approach will show hedging losses when short term prices climb and hedging gains when short term prices fall.
Peyto currently has 317,977 Mcf/d fixed with financial hedges for April 1, 2023 to December 31, 2023 at $4.49/Mcf. The Company’s current financial commodity hedges and foreign exchange forward contracts are summarized below:
| Natural gas(1) | Units | Q2 2023 | Q3 2023 | Q4 2023 | 2024 | 2025 |
| AECO (7A & 5A) | GJ/d | 247,500 | 247,500 | 134,783 | 82,288 | 63,534 |
| NYMEX | MMBtu/d | 130,000 | 130,000 | 183,043 | 119,454 | – |
| Total volume(2) | Mcf/d | 334,487 | 334,487 | 285,137 | 181,148 | 55,247 |
| Average Price(3) | $/Mcf | 4.19 | 4.19 | 5.20 | 5.33 | 4.47 |
| (1) | Includes financial hedges only. Fixed-price physical and basis contracts are excluded. See the “Marketing” section in Peyto’s Q1 2023 MD&A for additional information on hedge contracts and prices. |
| (2) | 1MMBtu = 1.0551GJ and Peyto’s gas has an average heating value of approx. 1.15GJ/Mcf. |
| (3) | Average price is calculated using a weighted average of notional volumes and prices, converted to $/Mcf. USD contracts are converted at 1.335 CAD/USD FX rate. |
| NGLs | Units | Q2 2023 | Q3 2023 | Q4 2023 | 2024 | 2025 |
| WTI CAD | ||||||
| Fixed price swaps | Bbl/d | 3,700 | 2,700 | 1,500 | 199 | – |
| Average Price | $/Bbl | 108.47 | 105.46 | 103.37 | 100.74 | – |
| WTI CAD | ||||||
| Collars | Bbl/d | – | 500 | 500 | 124 | – |
| Put | $/Bbl | – | 95.00 | 90.00 | 90.00 | – |
| Call | $/Bbl | – | 115.25 | 116.25 | 110.20 | – |
| Foreign Exchange Forwards | Units | Q2 2023 | Q3 2023 | Q4 2023 | H1 2024 | H2 2024 | ||
| Amount | USD | $30 million | $30 million | $30 million | $60 million | – | ||
| Exchange Rate | CAD/USD | 1.3601 | 1.3601 | 1.3601 | 1.350 | – | ||
Diversification
The Company’s natural gas sales are diversified with exposure to hubs other than AECO, including Henry Hub, Ventura, Emerson 2, Empress, Malin, Dawn and Chicago. On April 1, 2023, Peyto’s firm delivery service to the Empress hub increased by 150,000 GJ per day upon completion of the NGTL 2021 expansion program. Empress service provides Peyto access to the TC Energy Canadian Mainline and the option to sell gas outside of the AECO market. As a result, Peyto has no exposure to AECO prices for the rest of 2023 and, accounting for projected volume growth, limited exposure in 2024. Peyto anticipates that AECO prices will remain weak due to elevated gas supply in western Canada coupled with substantial NGTL system maintenance planned during summer.
Peyto’s construction of the 23 km Cascade pipeline is now finished with just connection work remaining at both ends of the line. The Cascade power plant is a highly efficient 900-megawatt combined cycle power plant and is expected to start operations in late 2023. Peyto will supply 60,000 GJ/d (approximately 10% of current gas production) under a 15-year gas supply agreement to this plant.
Details of Peyto’s ongoing marketing and diversification efforts are available on Peyto’s website at: https://www.peyto.com/Files/Operations/Marketing/Marketing_May_2023.pdf
Activity Update
Since the end of the quarter Peyto has reduced activity to three rigs as part of the current breakup plan. Activity will remain focused in the Chambers area of Brazeau as well as Greater Sundance where road and lease conditions are suitable, and a high level of operational efficiency can be maintained. Since the end of the quarter, 5 gross (4.4 net) wells have been drilled, 8 gross (7.4 net) wells have been brought on production, and 7 gross (6.7 net) wells are waiting on completion and/or tie-in. Peyto’s efforts to maximize value by extending lateral length has continued through the first part of the year with average lateral lengths approaching 2,000 meters. Results from these wells continue to meet or exceed expectations, particularly in the underdeveloped Falher channels that Peyto has been targeting recently. Development continues for the assets acquired in 2022 in Brazeau with Peyto drilling 8 gross (8 net) wells since acquiring these lands and growing production from 500 to 6,000 boe/d. This activity, in conjunction with the sales line and gathering line modifications made at the Aurora plant earlier this year, has allowed for maximum utilization of the Aurora facility. The remainder of this year’s drilling program focuses on a species mix that generates the best overall returns, however, this program will remain flexible and could pivot toward a higher liquids rich content, such as the Cardium, where the Company could deploy the ERH design to improve efficiencies. Peyto’s projections of returns continue to be strong, with a forecasted full-cycle internal rate of return of approximately 40% for 2023 based on current strip pricing, year-to-date results, and current drilling plans for the remainder of the year.
Peyto recently installed and commissioned its first waste heat recovery (“WHR”) system at Chambers which will reduce fuel usage and emissions. The project is currently in the evaluation phase but economic success of the WHR system in Chambers will drive additional application across Peyto’s vast plant processing capacity, further reducing Peyto’s fuel usage and emissions.
Alberta Wildfires
Peyto has been fortunate that although many of the wildfires have been proximal, they have not directly impacted the Company’s major infrastructure. However, on May 5th, Peyto shut down two gas plants in the Brazeau area as a precautionary measure. The Company was able to mitigate the temporary production losses by redirecting some volumes to other plants through Peyto’s integrated gathering system. Peyto also adjusted refrigeration processes to minimize liquid production while third party trucking and pipeline services were suspended. Start-up of the Brazeau plant has already begun, however, sustained production will depend on continued access into the area and the ability to truck and transfer out liquids. At this time, the Company believes the production impact for the second quarter will be a reduction between 1,000 to 2,000 boe/d, however, the situation continues to be dynamic.
Peyto’s drilling and completion operations have continued throughout most of this period, however, they will remain flexible providing access into areas, oilfield services, and safe work conditions remain. The Peyto team remains ready to respond to changing conditions to keep the Company’s personnel and equipment safe.
Outlook
The long-term outlook for natural gas remains positive with increasing demand in North America and around the world. Future build out of LNG export projects in Canada and the US should play a major role in supplying clean, reliable natural gas to many nations currently limited to dirtier fuels. Peyto’s low cost, long reserve life, low emission assets are well-positioned in the Deep Basin and the Company can react quickly to increasing market demand. Peyto’s strategic diversification to gas markets across North America provides excellent exposure to premium seasonal markets such as Malin in California and Ventura in Chicago while reducing the risk of selling into potential dislocated markets like AECO.
The Company’s capital plan to spend $425-$475 million in 2023 is specifically designed to be flexible in the back half of the year to adjust to changing commodity prices and economic conditions. In the meantime, Peyto will target the lower range of the capital guidance while the Company’s systematic hedging and market diversification programs help secure revenues for future dividends and continued strengthening of the balance sheet.
Conference Call and Webcast
A conference call will be held with senior management of Peyto to answer questions with respect to the Company’s Q1 2023 results on Thursday, May 11, 2023, at 9:00 a.m. Mountain Time (MT), or 11:00 a.m. Eastern Time (ET).
Access to the webcast can be found at: https://edge.media-server.com/mmc/gco3uorv.To participate in the call, please register for the event at: https://register.vevent.com/register/BId0d75796da4a4f139ddf7bc23372835a. Participants will be issued a dial in number and PIN to join the conference call and ask questions. Alternatively, questions can be submitted prior to the call at info@peyto.com. The conference call will be archived on the Peyto Exploration & Development website at www.peyto.com.
Annual General Meeting
Peyto’s Annual General Meeting of Shareholders is scheduled for 3:00 p.m. on Wednesday, May 17, 2023, at the Eau Claire Tower, +15 level, 600 – 3rd Avenue SW, Calgary, Alberta. Shareholders who do not wish to attend are encouraged to visit the Peyto website at www.peyto.com where there is a wealth of information designed to inform and educate investors and where a copy of the AGM presentation will be posted.
Management’s Discussion and Analysis and Financial Statements
A copy of the first quarter report to shareholders, including the MD&A, unaudited consolidated financial statements and related notes, is available at https://www.peyto.com/Files/Financials/2023/Q12023FS.pdf and at https://www.peyto.com/Files/Financials/2023/Q12023MDA.pdf and will be filed at SEDAR, www.sedar.com at a later date.
Jean-Paul Lachance
President & Chief Executive Officer
May 10, 2023
Phone: (403) 261-6081