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Peyto Exploration & Development Corp. Announces Q1 2019 Results

CALGARY, Alberta, May 07, 2019 (GLOBE NEWSWIRE) — Peyto Exploration & Development Corp. (“Peyto” or the “Company”) is pleased to present its operating and financial results for the first quarter of the 2019 fiscal year. A 68% Operating Margin(1) and a 16% Profit Margin(2) in the quarter delivered a 6% return on capital employed (ROCE) and a 6% return on equity (ROE), on a trailing twelve month basis. Additional highlights included:

  • Liquids yield increases 31%. Condensate and NGL yields increased from 17.7 bbl/mmcf in Q1 2018 to 23.2 bbl/mmcf in Q1 2019, due to continued deployment of capital in Peyto’s liquids rich Cardium play. Total liquids production of 10,703 bbl/d in Q1 2019 was up 7% year over year, despite suspended deep cut operations during February and March. Natural gas production was down 19% to 462 mmcf/d as Peyto replaced declining dry gas with significantly higher liquids-rich gas. Total Q1 2019 production of 87,703 boe/d was up slightly from Q4 2018 of 86,738 boe/d and Q3 2018 of 85,242 boe/d.
  • Funds from operations of $0.63/share. Generated $103 million in Funds from operations (“FFO”) in Q1 2019 down from $149 million in Q1 2018 due to lower commodity prices and lower production levels. FFO exceeded both capital expenditures ($62 million) and dividend payments ($10 million) by $31 million resulting in reduced net debt levels.
  • Total cash costs of $1.02/Mcfe (or $0.88/Mcfe ($5.30/boe) excluding royalties). Industry leading total cash costs, included $0.14/Mcfe royalties, $0.35/Mcfe operating costs, $0.19/Mcfe transportation, $0.06/Mcfe G&A and $0.28/Mcfe interest, combined with a realized price of $3.20/Mcfe, resulted in a $2.18/Mcfe ($13.06/boe) cash netback, down 17% from $2.63/Mcfe in Q1 2018.
  • Capital investment of $62 million. A total of 15 gross wells (13.5 net) were drilled in the first quarter, 15 gross wells (14 net) were completed, and 15 gross wells (14 net) were brought on production. Over the last 12 months the 69 gross (64.8 net) wells brought on production accounted for 17,500 boe/d at the end of the quarter, which, when combined with a trailing twelve month capital investment of $259 million, equates to an annualized capital efficiency of $14,800/boe/d. Peyto anticipates the 2019 full year capital efficiency will be $10,000/boe/d.
  • Earnings of $0.15/share, dividends of $0.06/share. Earnings of $25 million were generated in the quarter while dividends of $10 million were paid to shareholders. The Company has never incurred a write down nor recorded an impairment of its assets and this quarter represents Peyto’s 57th consecutive quarter of earnings.

First Quarter 2019 in Review

Peyto spent the majority of the first quarter advancing its Greater Sundance, liquids-rich, Cardium play with all drilling and completions focused on the Cardium. Success with this program was evidenced by some of the strongest initial production and most consistent well results in the Company’s 20 year history in this play. As well, Peyto added 49 sections of new Cardium lands in the quarter, all with multiple identified drilling locations, for an average cost of $52/acre. This brings total Cardium land additions to 157 gross (123 net) sections since 2017. Cardium production, with a minimum 50 bbl/mmcf of NGLs (67% pentanes and condensate), now represents 22% of total corporate production and has increased Peyto’s proportion of oil and NGL production to 13%. It is anticipated that Cardium production will represent approximately 40% of total production by year end. The added liquids production and Peyto’s gas market diversification efforts in the quarter helped strengthen Peyto’s revenues and contributed to stronger netbacks despite consistently weak AECO monthly gas prices. In total, 78% of Peyto’s natural gas had been hedged for the quarter, and 8% was exported to markets outside of Alberta, leaving just 14% exposed to the domestic Alberta market. Cost control remained a consistent focus, and despite higher methanol costs and usage due to an extremely cold February, cash costs continued to be industry leading. Significant free cashflow generated in the quarter was utilized to reduce net debt levels and improve Peyto’s balance sheet. Also in the quarter, the Company extended its four year revolving credit facility which included a revised, peer equivalent, covenant package.

1. Operating Margin is defined as funds from operations divided by revenue before royalties but including realized hedging gains/losses. 
2. Profit Margin is defined as net earnings for the quarter divided by revenue before royalties but including realized hedging gains/losses.
Natural gas volumes recorded in thousand cubic feet (mcf) are converted to barrels of oil equivalent (boe) using the ratio of six (6) thousand cubic feet to one (1) barrel of oil (bbl). Natural gas liquids and oil volumes in barrel of oil (bbl) are converted to thousand cubic feet equivalent (Mcfe) using a ratio of one (1) barrel of oil to six (6) thousand cubic feet. This could be misleading, particularly if used in isolation as it is based on an energy equivalency conversion method primarily applied at the burner tip and does not represent a value equivalency at the wellhead.


  Three Months Ended March 31 %
2019 2018 Change
Natural gas (mcf/d) 462,003 568,496 -19%
Oil & NGLs (bbl/d) 10,703 10,043 7%
Liquid to Gas Ratio (bbl/mmcf) 23.2 17.7 31%
Barrels of oil equivalent (boe/d @ 6:1) 87,703 104,793 -16%
Production per million common shares (boe/d)* 532 636 -16%
Product prices
Natural gas ($/mcf) 2.48 2.86 -13%
Oil & NGLs ($/bbl) 50.37 59.67 -16%
Operating expenses ($/mcfe) 0.35 0.29 21%
Transportation ($/mcfe) 0.19 0.13 46%
Field netback ($/mcfe) 2.52 2.95 -15%
General & administrative expenses ($/mcfe) 0.06 0.08 -25%
Interest expense ($/mcfe) 0.28 0.24 17%
Financial ($000, except  per share*)
Revenue 151,660 200,397 -24%
Royalties 6,673 9,543 -30%
Funds from operations 103,078 148,986 -31%
Funds from operations per share 0.63 0.90 -31%
Total  dividends 9,893 29,677 -67%
Total dividends per share 0.06 0.18 -67%
Payout ratio (%) 10 20 -50%
Earnings 24,970 47,749 -48%
Earnings per diluted share 0.15 0.29 -48%
Capital expenditures 62,395 35,454 76%
Weighted average common shares outstanding 164,874,175 164,874,175
As at March 31
End of period shares outstanding (includes shares to be issued) 164,874,175 164,874,175
Net debt 1,189,849 1,243,291 -4%
Shareholders’ equity 1,654,076 1,725,131 -4%
Total assets 3,6534,039 3,762,835 -3%
*all per share amounts using weighted average common shares outstanding


Three Months Ended March 31
($000 except per share) 2019 2018
Cash flows from operating activities 91,511 143,995
Change in non-cash working capital 9,061 3,913
Change in provision for performance based compensation 215 1,078
Performance based compensation 2,291
Funds from operations 103,078 148,986
Funds from operations per share 0.63 0.90

(1) Funds from operations (“FFO”) – Management uses FFO to analyze the operating performance of its energy assets. In order to facilitate comparative analysis, FFO is defined throughout this report as earnings before performance based compensation, non‑cash and non‑recurring expenses. Management believes that FFO is an important parameter to measure the value of an asset when combined with reserve life. FFO is not a measure recognized by Canadian generally accepted accounting principles (“GAAP”) and does not have a standardized meaning prescribed by GAAP. Therefore, FFO, as defined by Peyto, may not be comparable to similar measures presented by other issuers, and investors are cautioned that FFO should not be construed as an alternative to net earnings, cash flow from operating activities or other measures of financial performance calculated in accordance with GAAP. FFO cannot be assured and future dividends may vary.

Exploration & Development

First quarter 2019 activity was focused exclusively in the Greater Sundance area on the Cardium play as shown in the following table:

  Field Total Wells
Zone Sundance Nosehill Wildhay Ansell Whitehorse Kisku/
Belly River
Cardium 6 9 15
Total 6 9 15

The Company continues to drive down costs with its preferred Cardium drilling and completion design. As illustrated in the following table, drilling cost per meter have continued to drop as have completion costs per frac stage.

2010 2011 2012 2013 2014 2015 2016 2017 2018 2019
Gross Hz Spuds 52 70 86 99 123 140 126 135 70 15
Measured Depth (m) 3,762 3,903 4,017 4,179 4,251 4,309 4,197 4,229 4,020 3,853
Drilling ($MM/well) $2.76 $2.82 $2.79 $2.72 $2.66 $2.16 $1.82 $1.90 $1.71 $1.54
$ per meter $734 $723 $694 $651 $626 $501 $433 $450 $425 $400
Completion ($MM/well) $1.36 $1.68 $1.67 $1.63 $1.70 $1.21 $0.86 $1.00 $1.13 $1.15
Hz Length (m) 1,335 1,303 1,358 1,409 1,460 1,531 1,460 1,241 1,348 1,528
$ per Hz Length (m) $1,017 $1,286 $1,231 $1,153 $1,166 $792 $587 $803 $835 $751
$ ‘000 per Stage $231 $246 $257 $188 $168 $115 $79 $81 $51 $46

Capital Expenditures

During the first quarter of 2019, Peyto spent $24.2 million on drilling, $20.2 million on completions, $5.1 million on wellsite equipment and tie-ins, $8.9 million on facilities and major pipeline projects, and $4.0 million acquiring new lands and seismic, for total capital investments of $62.4 million.

The $8.9 million on new facilities and major pipeline projects included two pipeline looping projects in Sundance and liquid handling modifications to our Wildhay, Oldman and Oldman North gas plants.

Commodity Prices

Average Monthly AECO natural gas prices were $1.84/GJ in Q1 2019, up from $1.80/GJ in the previous quarter and $1.76/GJ in the prior year. This is in contrast to the average Daily AECO gas price of $2.49/GJ in Q1 2019. Historically, monthly prices have outperformed daily prices, however, this was not the case in the first quarter. Peyto typically hedges the majority of the AECO exposed production using fixed price swaps settled against the monthly price which is why such a large portion of Peyto’s unhedged gas received the monthly price.

On average for Q1 2019, Peyto realized a natural gas price of $2.48/Mcf ($2.16/GJ) or 135% of the AECO monthly average price. This was the result of a combination of approximately 14% of natural gas production being sold into the daily or monthly spot market at an average of $1.94/GJ, approximately 78% having been pre-sold at an average hedged price of $2.04/GJ, and approximately 8% being sold to export markets in Eastern Canada at $3.69/GJ.

In the first quarter of 2019, NGL prices, relative to natural gas prices, justified the operation of Peyto’s Oldman deep cut plant only during the month of January. As a result, Peyto realized a blended oil and natural gas liquids price of $50.37/bbl, which represented 69% of the $72.98/bbl average Canadian WTI price. Details of realized commodity prices by component are shown in the following table:

Commodity Prices by Component

Three Months ended Mar 31
   2019  2018
AECO monthly ($/GJ) 1.84 1.76
AECO daily ($/GJ) 2.49 1.97
Henry Hub spot ($US/MMBTU) 2.92 3.08
Peyto natural gas – prior to hedging ($/GJ) 2.05 1.72
($/mcf) 2.36 1.98
Peyto natural gas – after hedging ($/GJ) 2.16 2.49
($/mcf) 2.48 2.86
Condensate ($/bbl)   71.23 72.56
Propane ($/bbl)   16.99 26.04
Butane ($/bbl)   26.69 40.83
Pentane ($/bbl)   64.16 79.26
Total Oil and natural gas liquids ($/bbl)   50.37 59.67
Canadian WTI ($/bbl)   72.98 79.54
Peyto Realized liquids price/Canadian WTI   69% 75%

Liquids prices are Peyto realized prices in Canadian dollars adjusted for fractionation and transportation.

Financial Results

Approximately 34%, or $1.02/Mcfe, of Peyto’s unhedged revenue came from its associated natural gas liquids sales while 66%, or $2.00/Mcfe, came from natural gas. Natural gas hedging activity contributed $0.18/Mcfe for total revenue of $3.20/Mcfe. Liquids production represented 12% of total production but 34% of revenue which covered all cash costs. Cash costs of $1.02/Mcfe, included royalties of $0.14/Mcfe, operating costs of $0.35/Mcfe, transportation costs of $0.19/Mcfe, G&A of $0.06/Mcfe and interest costs of $0.28/Mcfe. Cash costs per unit of production were higher than the previous quarter and previous year due to increased royalties, related to higher liquids pricing, higher operating and transportation costs, reduced production levels, and increased interest rates. For the balance of the year, Peyto expects to lower per unit operating and interest costs as chemical requirements diminish in summer months and as debt is reduced.

Total cash costs, when deducted from realized revenues of $3.20/Mcfe, resulted in a cash netback of $2.18/Mcfe or a 68% operating margin. Historical cash costs and operating margins are shown in the following table.

2016 2017 2018 2019
($/Mcfe) Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1
Revenue 3.24 2.92 3.16 3.38 3.44 3.36 3.24 3.50 3.54 3.20 3.27 3.03 3.20
Royalties 0.13 0.10 0.12 0.18 0.19 0.17 0.09 0.15 0.17 0.10 0.14 0.12 0.14
Op Costs 0.23 0.26 0.25 0.26 0.29 0.24 0.26 0.28 0.29 0.30 0.31 0.33 0.35
Transportation 0.16 0.17 0.16 0.16 0.17 0.18 0.17 0.16 0.13 0.18 0.19 0.19 0.19
G&A 0.03 0.06 0.04 0.03 0.04 0.05 0.03 0.03 0.08 0.05 0.03 0.04 0.06
Interest 0.17 0.21 0.19 0.18 0.20 0.21 0.21 0.21 0.24 0.26 0.27 0.27 0.28
Cash Costs 0.72 0.80 0.76 0.81 0.89 0.85 0.76 0.83 0.91 0.89 0.94 0.95 1.02
Netback 2.52 2.12 2.40 2.57 2.55 2.51 2.48 2.67 2.63 2.31 2.33 2.08 2.18
Operating Margin 78% 73% 76% 76% 74% 75% 76% 76% 74% 72% 71% 69% 68%

Depletion, depreciation and amortization charges of $1.38/Mcfe, along with a provision for deferred tax and market based bonus payments reduced the cash netback to earnings of $0.53/Mcfe, or a 16% profit margin. Dividends of $0.21/Mcfe were paid to shareholders.

Natural Gas Marketing

Peyto continues to make meaningful progress on its market diversification strategy. This thoughtful plan is designed to complement the Company’s highly successful hedging strategy and endeavors to achieve, over the long term, a balanced marketing approach whereby 40% of natural gas sales are linked to AECO based pricing, 40% are linked to US-based pricing and 20% are sold directly to intra-Alberta industrial markets. The Company has been actively securing both synthetic and physical transportation arrangements to link gas sales to US-based markets and Eastern Canadian markets that are more closely tied to NYMEX price.

For 2019, Peyto has 25% of forecast natural gas volumes linked to NYMEX prices with 84% of this volume already hedged, 12% linked to Eastern Canadian markets in Dawn and Ventura where 13% is hedged (100% of Ventura volumes are hedged for this summer), and 63% to the AECO market where 72% is hedged. The result of these arrangements means less than 5% of annual revenue is exposed to the AECO spot market.

For 2020, Peyto has 47% of forecast natural gas volumes linked to NYMEX prices, 13% to Dawn and Ventura, and 40% to AECO. At those markets, 6% of the NYMEX and 38% of the AECO volume has already been hedged.

For a real time summary of Peyto’s market diversification portfolio and future hedges refer to Peyto’s website at:

Activity Update

Drilling activity was shut down in mid-April for the annual spring breakup period while completion activity continued with the completion of four standing Cardium wells. Four additional wells remain standing, awaiting completion which is expected to occur in June.

No new wells were brought on production in April, however, 5 gross (4.5 net) Cardium wells have recently been equipped and tied in during the first week of May. Production in April was impacted by extremely volatile AECO natural gas prices, where at times Peyto had approximately 10% of its dry gas production shut in due to low prices. This reduced April average production by approximately 1,000 boe/d. The new, liquids-rich wells added in May, all with NGL yields in excess of 75 bbl/mmcf, have grown current liquid production to 12,500 bbl/d. This added liquid volume has created high gathering system pressures which has backed out approximately 1,500 boe/d of existing production. Pipeline looping and plant liquid handling projects are ready to be installed immediately following spring breakup to recover this production.

Also, since the end of the first quarter, Peyto has acquired 7 net sections of Cardium rights at an average cost of $55/acre, increasing total crown purchases this year to 67 sections.

Peyto’s first Montney well, which was drilled in the fourth quarter of 2018, will also be completed in June. The Company plans to complete the well using a slick-water fracture stimulation which will incorporate approximately 3,400 tonnes of sand pumped along the 1,935m horizontal lateral.

New Ventures

Peyto continues to work on design attributes for its Big Sunny storage scheme. Reservoir simulation work has been completed and a pilot project utilizing existing vertical wells is currently being contemplated. The Company is also awaiting the imminent market impact to local propane prices by a new West Coast export terminal before making a final investment decision on the Swanson Deep Cut facility installation, as this facility will primarily extract liquid propane from the sales gas stream. In addition, Peyto continues to evaluate opportunities to vertically integrate its energy business to extract maximum value from existing and future reserves and infrastructure assets.


The current capital program for 2019 remains unchanged with an expected range of $150 to $200 million, involving the drilling of approximately 50 Cardium liquids-rich gas wells, the testing of Peyto’s new Montney play, the continued accumulation of new lands which add profitable drilling inventory, and continued debt reduction. The rapidly growing liquids revenue, particularly from free wellhead condensate, is expected to help offset weak summer spot gas prices. By replacing declining dry gas production with more liquids rich gas, Peyto will be able to increase its sales revenue on a unit of production basis while continuing to drive down total supply cost resulting in increasing cash netbacks.

Peyto’s continues to pursue its long term strategy of becoming a more fully integrated energy business. Opportunities to invest in new infrastructure to extend the value chain will continue to be investigated, as will additional opportunities for market diversification for all of its produced products.

Conference Call and Webcast

A conference call will be held with the senior management of Peyto to answer questions with respect to the 2019 first quarter financial results on Wednesday, May 8th, 2019, at 9:00 a.m. Mountain Daylight Time (MDT), or 11:00 a.m. Eastern Daylight Time (EDT). To participate, please call 1-844-492-6041 (North America) or 1-478-219-0837 (International). Shareholders and interested investors are encouraged to ask questions about Peyto and its most recent results. Questions can be submitted prior to the call at The conference call can also be accessed through the internet: The conference call will be archived on the Peyto Exploration & Development website at

Management’s Discussion and Analysis/Financial Statements

A copy of the first quarter report to shareholders, including the MD&A, unaudited financial statements and related notes, is available at and at and will be filed at SEDAR, at a later date.

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