Peyto Exploration (PEY) — Stock Analysis 2026 [3.9]

Analysis as of 26 August 2026. Price deck: base Henry Hub US$3.00/MMBtu — the representative trailing average on the fixed US$2.00–4.00 grid — with every grid price run as a scenario (deep bear US$2.00, US$2.50, base US$3.00, US$3.50, deep bull US$4.00), WTI held at US$80/bbl, and the reserve evaluator’s escalating 2025 forecast as a 0% cross-check — no spot price. Shares at CA$24.95 (TSX close); the market-implied deck is ~US$4.80/MMBtu Henry Hub. Canadian dollars at US$1.00 = CA$1.3876. Refreshed on each annual report and each quarterly report. Rating: ★★★★ Solid / Overvalued (wide band).

Peyto Exploration is an E&P producer in the natural-gas sector: an Alberta Deep Basin company that produced 134,055 boe/d in 2025, 88% of it natural gas, through gas plants it owns. The thesis in one line: the lowest-cost operator in its peer set, priced at about twice the value its booked reserves support at a US$3.00 Henry Hub deck. It is worth a look now because first-half 2026 gas output ran at 767,813 Mcf/d, 8% above the 2025 average, and a 50,000 MMBtu/d supply agreement priced off European TTF gas starts in 2029. To screen Peyto against every North American upstream name on the same fields, go to Metal Pilot’s upstream oil & gas stock screener.

1. Snapshot & thesis

Figure 1. Peyto in numbers, as of 26 August 2026

Figure data: Table 1, this analysis.

Table 1. Peyto in numbers

Source: Peyto reports and filings — AIF 2025 p.12 (reserves), 2025 reserves release p.1 (reserve life), Annual report 2025 pp.2–4 (production, netback, dividend), Q2 2026 report pp.2, 35 (shares, net debt, covenants); price from Yahoo Finance (PEY.TO, 26 Aug 2026); NAV/share, blend and return from the model in Section 7.

How to read this analysis: the statcards and Section 9 carry the verdict; Sections 2–7 carry the evidence, Section 7 the valuation.

Identity. Peyto Exploration & Development Corp. (TSX: PEY) is a Calgary-based E&P producer in the natural-gas sector with one producing area, the Alberta Deep Basin, where it holds 517,000 net acres, owns seven gas plants outright and three joint plants at a 72% average interest, and carries 1,636 future drilling locations in its reserve report. It reports in Canadian dollars, its reserves evaluated under NI 51-101 by GLJ Ltd.

Thesis in brief. The bull case is cost: a FY2025 field netback of CA$21.66/boe, the highest in the peer set, reserves replaced 172% on a producing basis and 270% on proved plus probable in 2025, and a dividend covered 1.42× by free funds flow while net debt fell CA$171.0 m. The bear case is price: at US$3.00 Henry Hub the shares trade at 2.19× the risked NAV/share of CA$11.42, so the market is paying for a gas price the trailing averages do not show — ~US$4.80/MMBtu Henry Hub. What tips it is the gas price — the read moves up a band only above ~US$3.81/MMBtu Henry Hub.

2. Assets & operations

Peyto sells gas priced off AECO, Alberta’s landlocked hub, which averaged CA$1.76/GJ in 2025 while NYMEX Henry Hub averaged US$3.43/MMBtu; the Natural Gas — A Complete Market Guide explains the gap. Peyto’s 2025 realized gas price before hedging was CA$2.90/Mcf.

2.1 Portfolio overview

Table 2. Portfolio at 31 December 2025

Source: Peyto reports and filings — AIF 2025 pp.9, 12, 20; 2025 reserves release p.1; Annual report 2025 p.2; Q2 2026 report p.3.

One basin carries the whole company: every well, plant and booked barrel sits in the Deep Basin, and 2025 volume was 88% natural gas and 12% NGLs. That concentration is the source of the low cost — dense, owned infrastructure — and of the main risk, one regional gas price. There is no second basin or international acreage to average that price against; the hedge book in Section 3 and a marketing portfolio do that work — Q2 2026 gas sold CA$0.93/Mcf above AECO, and from 2028 over 400 MMcf/d is exposed to non-AECO markets, the 2029 TTF agreement the newest leg.

2.2 Revenue split

Figure 2. Net revenue by product, base deck

Figure data: the model in Section 7, base case (Table 12 revenue mix).

Figure 3. Revenue by asset

Figure data: Table 2; Peyto reports one producing area.

Gas is 88% of production but 54.0% of net revenue at the base deck, because a barrel of NGLs realized CA$56.52 in 2025 against CA$17.40 for the six Mcf of gas that make one boe. In FY2025 terms the 16,048 bbl/d of NGLs were 12% of the boe but, at CA$56.52/bbl against CA$2.90/Mcf, earned close to a third (31%) of pre-hedge sales. Liquids pricing is the second lever on the value, which is why Section 7 runs WTI as its own deck.

2.3 Deep Basin

The Deep Basin of west-central Alberta is Peyto’s only asset, held 100% and operated through the company’s own gathering and processing; no stream, royalty financing or offtake encumbers it. It produced 708,046 Mcf/d of gas and 16,048 bbl/d of NGLs in 2025, and 758,165 Mcf/d of gas in Q2 2026 (767,813 Mcf/d over the first half). The 2026 capital budget is CA$450–500 m; no 2026 production guidance is published. The booked inventory of 1,636 gross locations needs CA$5.9 bn of capital, CA$1.22/Mcfe. From 2029 a 10-year agreement with Centrica prices 50,000 MMBtu/d, delivered at NIT (AECO), on European TTF.

Owning the plumbing is what keeps the unit cost down: gas runs through seven plants Peyto owns outright and three joint plants in which it averages 72%, so a new well needs a tie-in rather than a new facility. The 2025 program replaced 172% of production on a producing basis at a 2025 PDP recycle ratio of 3.8× including hedges (2.9× excluding) — the netback earned against the cost of finding and developing the reserves — and the booked inventory, at CA$5.9 bn, is about twelve years of the 2026 budget.

Table 3. Reserves and NPV, 31 December 2025 (NI 51-101, GLJ forecast prices)

Source: Peyto reports and filings — AIF 2025 p.12, Summary of Oil and Gas Reserves and Net Present Values of Future Net Revenue, evaluated by GLJ Ltd. effective 31 December 2025. Notes: (1) the developed non-producing after-tax value is derived as total proved less producing and undeveloped; (2) values are struck on the evaluator’s escalating forecast, not this analysis’s deck.

Total proved holds 4,730,177 MMcf of gas and 137,591 Mbbl of NGLs. Producing reserves carry CA$4,031.1 m of the CA$7,259.8 m after-tax P+P value (56%), so most of the evaluator’s value sits in wells already flowing. Those values rest on the evaluator’s escalating forecast; rebuilt at the US$3.00 deck in Section 7, the same P+P reserves are worth CA$3,724.0 m after tax before risking. The asset’s one risk is its price: everything here is sold into Western Canadian gas markets.

2.4 Production, reserves & costs

Table 4. Unit costs and reserve performance

Source: Peyto reports and filings — Annual report 2025 pp.2, 12; Q2 2026 report p.3; 2025 reserves release p.1. Per-unit operating cost = CA$152.8 m ÷ (134,055 boe/d × 365 × 6).

Figure 4. Natural gas production, Mcf/d

Figure data: Annual report 2025 p.2 (708,046 Mcf/d) and Q2 2026 report p.2 (767,813 and 758,165 Mcf/d), Peyto reports and filings.

FY2025 production of 134,055 boe/d is 48.9 mmboe/yr annualized, of which gas was 258.4 bcf/yr. The CA$3.61/Mcfe netback, after royalties, transportation and operating costs, is the margin Dimension 2 rests on; royalties, the price-linked line, rose to CA$0.28/Mcfe in Q2 2026. Producing reserves are 55% of total proved, and the 2025 replacement ratios mean the drill bit added more reserves than the year produced in every category.

2.5 Peer positioning

Peer set: Advantage Energy (TSX: AAV), Birchcliff Energy (TSX: BIR) and Tourmaline Oil (TSX: TOU) — gas-weighted Western Canadian producers on FY2025 filings, none in a pending deal; every star in Section 9 uses this set.

Table 5. Quality metrics against the peer set, FY2025

Source: Peyto per Tables 2–4; peers as filed in their FY2025 reports on SEDAR+, per the Birchcliff Energy analysis Table 5. Life is P+P over FY2025 production. Netbacks are each company’s own basis (Peyto’s field netback; the peers’ operating netback), so the column is indicative.

Peyto is second by scale and reserves, second on life, and first on netback by CA$5.67/boe over Advantage. Tourmaline is the scale reference at almost five times Peyto’s output; Birchcliff holds the longest life but earned CA$7.00/boe less netback in 2025. Peyto’s edge over the set is cost, not size or life.

3. Financials & balance sheet

Table 6. Five-year financial summary (CA$ millions except per-share)

Source: Peyto reports and filings — Annual report 2025 pp.2, 4, 23, 27; Annual report 2023 pp.2, 20, 23, 24; Annual report 2022 pp.2, 4, 19, 22. Notes: (1) FY2021–FY2022 sales as the Annual report 2022 prints them, FY2021 growth on its FY2020 column; (2) cash margin, growth and FCF are derived from the rows shown, FCF on unrounded thousands.

Funds from operations reached a record CA$860.5 m in 2025, above the 2022 peak of CA$827.6 m, and operating cash flow of CA$857.6 m was twice net income of CA$418.6 m. No sustaining-capital line is filed, so free cash flow is struck on total capital. Capital of CA$475.2 m in 2025 sits inside the CA$450–500 m 2026 budget, so spending is held about flat, and net debt fell a further CA$161.7 m in the first half of 2026.

Cost deck. No unit-cost guidance is published; Q2 2026 cash costs were CA$1.32/Mcfe, of which royalties — the price-linked line — were CA$0.28 against CA$0.16 in FY2025. Federal tax pools of CA$1,197.4 m (CDE CA$622.0 m, UCC CA$372.3 m) shelter part of the income, but Peyto is a cash taxpayer: CA$95.2 m paid in 2025 and CA$87.3 m in the first half of 2026.

Net debt and liquidity. Company net debt was CA$1,015.9 m at 30 June 2026, leases (CA$7.1 m) outside it. The CA$1.05 bn revolver was CA$570.5 m drawn, leaving CA$479.5 m; senior secured notes are CA$100 m and US$40 m due 2028, CA$160 m due 2030, CA$100 m due 2033 and CA$75 m due 2034. Covenants read 1.06× total debt/EBITDA (limit 4.0×) and 17.45× interest coverage (limit 3.0×). At US$3.00 Henry Hub, net debt is 1.74× the model’s unhedged forward funds flow of CA$582.7 m. The decommissioning provision is CA$329.6 m against an escalated undiscounted CA$1,049.4 m.

Table 7. Hedge book at 30 June 2026

Source: Peyto reports and filings — Q2 2026 report p.5, Commodity price risk management; covered calls p.29; derivative assets p.49.

The H2 2026 gas hedge covers 66% of first-half output at a price above the base-deck realization; derivative assets stood at CA$144.1 m on the 30 June balance sheet.

Capital returns. The CA$1.32 dividend, CA$264.9 m in 2025, was covered 1.42× by free funds flow of CA$375.2 m, and basic shares rose 2.8% to 203,343,491 over 2025. The ratios follow the Financial Metrics for Commodity Investing guide.

4. Management, strategy & structure

4.1 Management & governance

Jean-Paul Lachance has been Chief Executive Officer since 1 January 2023, with Tavis Carlson as Vice-President Finance and Chief Financial Officer. The Chair, founder Donald Gray, has been a director since 1998. Seven of the eight directors are independent, on four committees: Audit; Compensation; Nominating and Board Governance; and Reserves, Environmental, Social and Governance and Health and Safety. Directors and officers hold about 6.5 m shares, 3.2% of the outstanding. Related-party transactions are disclosed in note 15 of the 2025 financial statements; none is material to this read.

4.2 Strategy

The strategy is low-cost Deep Basin gas through owned gathering and processing, funded from cash flow, the revolver and senior notes. The 2026 capital budget is CA$450–500 m, set in February 2026, and the TTF-linked supply agreement of 50,000 MMBtu/d from 2029 extends a portfolio already tied to Dawn, Chicago, Henry Hub and other non-AECO markets. No production target is published. In 2025 the cash went to CA$475.2 m of capital, CA$264.9 m of dividends and a CA$171.0 m cut in net debt — growth into owned capacity, a held dividend and a falling balance.

4.3 Ownership & structure

The last material deal was the purchase of Repsol’s Canadian assets under a partnership interest purchase agreement dated 6 September 2023; the consideration is not among the figures read. The three joint plants (72% average interest) are the only shared assets; there is no strategic investor, offtake partner, stream or royalty, and no holder above 10%. A Total Shareholder Return Rights Plan, approved in May 2025, had 5.7 m Rights outstanding at 30 June 2026 (2.8% of shares). Basic shares were 203,343,491 at 31 December 2025; the Q2 2026 weighted averages were 205.2 m basic and 208.6 m diluted.

5. ESG & sustainability

No sustainability report is among the documents read: the AIF lists the Canadian Sustainability Disclosure Standards (CSDS 1 and 2) as pending, and no recordable-injury or lost-time rate is filed. Tailings do not apply to a gas producer. The disclosed environmental obligation is the decommissioning liability, CA$1,049.4 m escalated and undiscounted, carried at CA$329.6 m. The combined Reserves, ESG and Health and Safety committee oversees it. Dimension 9 is scored on that thin disclosure, not on an inferred problem; it is the one dimension where Peyto sits below the peer median.

6. Risks

Table 8. Risk register

Source: Peyto reports and filings — Q2 2026 report pp.5, 35, 49, 56; Q2 2026 release p.2; the sensitivities from the model in Section 7.

Figure 5. Risk matrix

Figure data: Table 8, this analysis.

The gas price is the risk that breaks the thesis: at US$2.00 Henry Hub the blend falls to CA$2.46, and free cash flow turns negative below ~US$2.69/MMBtu. Section 7 prices it on the Henry Hub grid, with WTI, the rate, the Canadian dollar and the probable risking as sensitivities; the gas hedges soften 2026 but step down to 123 MMcf/d in 2028.

7. Valuation

Valuation as of 26 August 2026, in Canadian dollars at US$1.00 = CA$1.3876 (Bank of Canada, 26 August 2026). Horizon: spot fair value. Gas deck: Henry Hub US$2.00, 2.50, 3.00, 3.50 and 4.00/MMBtu, base US$3.00/MMBtu — the trailing averages of the monthly Henry Hub price (3-month US$2.99, 6-month US$3.07, 12-month US$3.60, EIA, to July 2026) snapped to the nearest grid price, leaning on the two shorter windows because the 12-month carries January’s spike. Second deck: WTI US$80/bbl (3-month US$89.13, 6-month US$87.27, 12-month US$74.28, EIA monthly WTI, to July 2026), held in every scenario. Realized gas is Henry Hub less the FY2025 gap between Peyto’s realized price and Henry Hub, held at US$1.36/MMBtu. Discount rate 10% real after-tax, the E&P rate for a single-basin producer; grid rows at 8%, 10% and 12%. Price: CA$24.95, the TSX close on 26 August 2026.

Peyto is valued as a gas-weighted exploration and production company with the method set of the commodity stock valuation guide: a net asset value on its booked reserves at the target P/NAV (50%), a forward EV/DACF (30%) and a forward P/CF (20%). The base Henry Hub price sits 20.2% below the US$3.76 five-year average, so both the deck and the target multiples move across the scenarios.

Three choices shape the numbers. First, the reserve report’s net present values are struck on the evaluator’s own escalating price forecast, which this valuation does not carry: the total-proved and proved-plus-probable totals are each rebuilt at this deck from their filed volume, royalty share and development capital over the life their own discounted and undiscounted totals imply, the producing reserves over the life of a decline set by their filed reserve life index, and the categories are read off by difference. Second, oil and NGLs are 46.0% of net revenue at the base deck although gas is 88% of production, so WTI is a second deck in its own right: it is held at US$80 in every scenario, and the model’s out file prints the Henry Hub × WTI grid. Third, Peyto’s fixed-price gas hedges run through 2028 well above the AECO price this deck implies, so the hedge book is marked from its volumes and strikes in the bridge rather than carried inside the cash flow.

Table 9. Load-bearing inputs — the filed figures the valuation moves on

Source: the filings named in each row; the full source register is Table 23 in Section 10.1. Peyto reports and filings.

8. Near-term catalysts (1–3 years)

Table 21. Near-term catalysts

Source: Peyto reports and filings — 2025 reserves release p.2; Q2 2026 report pp.5, 35; Q2 2026 release p.2. Timing is company disclosure, not a guarantee.

The hedges and the budget are contracted or set, so 2026 cash flow is largely visible. The reserve report tests the inventory, and the TTF agreement adds a European price — 50,000 MMBtu/d, about 6% of first-half gas output, beside the non-AECO volumes already contracted.

9. Rating & verdict

Table 22. The Metal Pilot Company Scorecard — Peyto Exploration

Source: this analysis; every score cites its home section. Scored as an E&P producer — all nine dimensions apply — against the peer set in §2.5.

Σ(weight × stars) = 0.15 × (4 + 5 + 4 + 3 + 4) + 0.0625 × (4 + 4 + 4 + 2) = 3.00 + 0.88 = 3.88/5 → ★★★★ Solid.

The two-axis verdict (26 August 2026). ★★★★ Solid × Overvalued (wide band) — Full: at CA$24.95 the blend of CA$11.38 implies −54.4%, and the price assumes ~US$4.80/MMBtu Henry Hub (the market-implied deck), 28% above the five-year average. Peyto is the best operator in its peer set, priced well beyond what its reserves are worth at a US$3.00 deck. The target multiples carry Dimension 2 (+0.04), Dimensions 1 and 3 (+0.02 each) and Dimensions 6 and 8 (+0.01 each), with Dimension 5 neutral — a ×1.10 driver line. The quality band is held below High quality by the balance sheet and the ESG disclosure, not by the operation.

A reader paying CA$24.95 is paying for the operator and for a gas price above every trailing average; the 5.3% dividend yield is the carry while waiting.

The bull case is the netback: CA$21.66/boe in 2025, a dividend covered by free funds flow, and a hedge book that holds the 2026 realization above the deck. The bear case is the price: the blend of CA$11.38 sits 54.4% below the share price, and even the US$4.00 deep-bull blend of CA$21.57 is below it. What tips it is Henry Hub — above ~US$3.81/MMBtu the read moves up to Modestly overvalued — and the TTF volume from 2029.

To rank Peyto against every North American gas producer on these fields, screen the sector on Metal Pilot’s upstream oil & gas stock screener.

10. Sources, methodology & disclaimer

10.1 Sources, methodology & data vintage

Company filings (Peyto reports and filings; SEDAR+): the Annual Information Form for 2025 (31 March 2026, with the GLJ Ltd. reserve evaluation effective 31 December 2025); the 2022–2025 annual reports; the Q1 and Q2 2026 reports; the releases of 5 January, 19 February, 10 March, 2 June and 11 August 2026; the 2026 management information circular; and the AGM presentation of 21 May 2026.

Market data: the TSX close from Yahoo Finance (PEY.TO, 26 August 2026); the Bank of Canada USD/CAD rate; EIA monthly Henry Hub and WTI prices to July 2026; the Alberta Economic Dashboard AECO series. Peer figures as filed, per the Birchcliff Energy analysis.

Methodology. The valuation runs a base Henry Hub deck of US$3.00/MMBtu on the fixed US$2.00–4.00 grid, WTI held at US$80/bbl, realized gas at Henry Hub less US$1.36/MMBtu, a 10% real after-tax rate, and weights of 50% NAV, 30% EV/DACF and 20% P/CF. The scorecard uses the E&P weights against the three peers in §2.5. Refreshed on each annual report and each quarterly report. The model’s out file, claude/valuation-models/peyto-exploration-pey.out.md, holds the deck sensitivity, the P/NAV map, the cross-checks, the FX and stage-risk cases and the Henry Hub × WTI grid. The load-bearing inputs open Section 7 as Table 9; the full register is Table 23 below.

Re-run log. 26 August 2026 (run 18 October 2026): rebuilt from the 26 August 2026 post (CA$25.26, read Fairly valued) as a standalone valuation — price CA$24.95, NAV/share CA$12.04, blend CA$11.84, implied −52.6%, Overvalued (wide band); composite 4.09 → 3.88. 26 August 2026 (re-run 18 October 2026, gate fixes): the hedge book completed with the WTI collars, sold calls and US$ forward sales, and taxed at 23% at the column rate in both methods; income tax payable split from working capital — NAV/share CA$12.04 → CA$11.42, blend CA$11.84 → CA$11.38, implied −52.6% → −54.4%; read unchanged, Overvalued (wide band). 26 August 2026 (re-run 18 October 2026, second fix round): the risk-register sensitivities, the Figure 7 checksum and Section 6’s stress case moved to the fixed model; sector references added to Dims 7 and 9 — no figure moves, read unchanged.

Omitted figures and data gaps. The asset map is not built; Peyto reports one producing area, so Figure 3 has one bar. Not in the files read (n/d): sustaining capital, unit-cost and production guidance, a quantified FX sensitivity, the option table, safety rates and ESG programs, analyst consensus, the development-capital schedule by year, the Repsol consideration, management’s prior roles, and Tourmaline’s netback.

Table 23. Full source register for the valuation

Source: the filings named in each row; Peyto documents from Peyto reports and filings; market data as dated in each row.

10.2 Disclaimer & disclosure

This analysis is for informational purposes only and is not investment advice; do your own research or consult a licensed advisor. It is a point-in-time snapshot as of 26 August 2026: the share price, the multiples and the valuation read move, and reserve and net-asset-value figures are estimates as of the dates stated. The scorecard and the two-axis verdict are an analytical read of quality and price, not a buy or sell instruction. This report was prepared with AI assistance from the company’s filings and dated market data; verify before acting. The author holds no position in Peyto or any company named.