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Perpetual Energy Inc. reports first quarter 2019 financial and operating results

CALGARYMay 8, 2019 /CNW/ – (TSX:PMT) – Perpetual Energy Inc. (“Perpetual”, the “Corporation” or the “Company”) is pleased to release its first quarter 2019 financial and operating results. Highlights from the quarter include:

  • Heavy oil production in Eastern Alberta grew 30% relative to the prior year first quarter, driven by positive results from heavy oil focused drilling and waterflood investment during the second half of 2018.
  • Perpetual’s market diversification strategy delivered strong natural gas pricing of $3.54/Mcf.
  • Perpetual’s realized operating netback increased 4% to $13.36/boe (Q1 2018 – $12.87/boe), reflecting continued top quartile operating costs at the East Edson liquids-rich gas property in West Central Alberta.
  • Cash flow from operating activities in the first quarter of 2019 was $9.3 million ($0.15/share) and adjusted funds flow was $6.4 million ($0.11/share).
  • On March 27, 2019, the Company’s reserve-based credit facility was extended for an additional 1.5 years to November 30, 2020 and the borrowing limit was maintained at $55 million.
  • Net debt declined 9% ($10.2 million) from December 31, 2018 to $102.4 million.
  • On May 7, 2019, Perpetual announced it will early redeem the $14.6 million 2019 Senior Notes due July 23, 2019, effective June 11, 2019. The redemption will be funded by the issuance of $15.7 million 2022 Senior Notes.

A complete copy of Perpetual’s unaudited condensed interim consolidated financial statements and related Management’s Discussion and Analysis (“MD&A”) for the three months ended March 31, 2019 can be obtained through the Company’s website at and SEDAR at

Perpetual adopted IFRS 16 “Leases” effective January 1, 2019 using the modified retrospective approach, therefore comparative information has not been restated. The adoption of IFRS 16 had a minimal impact on net loss, and increased cash flow from operating activities and adjusted funds flow by $0.1 million compared to what would have occurred had the new accounting policy not been adopted. Refer to the “recently adopted accounting pronouncements” section of the Q1 2019 MD&A for details.


Capital Spending, Production and Operations

  • Perpetual’s 2019 budgeted capital spending program funded by adjusted funds flow, is largely planned for the second half of 2019 with approximately 50% of expenditures targeting heavy oil drilling in Eastern Alberta, and 50% targeting continued development of liquids-rich natural gas at the Company’s East Edsonproperty.
  • Exploration and development spending in the first quarter of 2019 was just $1.2 million, 92% lower than the comparative period in 2018, and consistent with guidance released with its 2018 year-end results on March 27, 2019.
    • Spending at the East Edson property in West Central Alberta was $0.7 million, and was directed towards the installation of field compression and a sweetening tower to enable reactivation of several higher liquids ratio wells back to production. The installation of the field compression and sweetening tower was completed in January, resulting in incremental production in Q1 2019 of approximately 300 boe/d.
    • Spending in Eastern Alberta was $0.5 million, 91% lower than the comparative period in 2018. Spending included the installation of automated leak detection monitoring equipment at several well pads.
  • Perpetual also spent $0.3 million (Q1 2018 – $0.6 million) on abandonment and reclamation projects. As part of Perpetual’s focus on well and pipeline abandonment and reclamation, four reclamation certificates were received from the Alberta Energy Regulator (“AER”) during the first quarter of 2019 (Q1 2018 – eight reclamation certificates) which will result in the cessation of associated property tax and surface lease expenses. The Company’s ratio of deemed assets to deemed liabilities as per the AER’s Licensee Liability Rating was 4.7 at the end of the first quarter.
  • Production averaged 10,240 boe/d in the first quarter of 2019, down 20% from the comparable period in 2018. The decrease was driven by natural declines resulting from limited capital investment on the Company’s natural gas assets during 2018, to preserve value during this period of depressed natural gas pricing in Alberta. Production was 8% higher than the fourth quarter of 2018, as there were no voluntary market related shut-ins of natural gas during the quarter, and the four well pad that was shut-in by the AER until December 2018 was back on production for the entire first quarter.
  • Heavy oil production in Eastern Alberta was up 30% to 1,113 bbl/d (11% of production) relative to the comparative 2018 period (Q1 2018 – 7% of production), as capital spending in the second half of 2018 was focused on heavy oil waterflood and development drilling in the Mannville area where return on capital is anticipated to be significantly higher than expected natural gas focused investment returns that sell into current AECO hub forward market prices. Heavy oil exploration and development activities will recommence once weather permits after spring break-up.
  • Production and operating expenses were up by $0.5 million relative to the 2018 first quarter, attributable to the increase in Eastern Alberta heavy oil production. West Central production and operating expenses were essentially flat relative to the first quarter of 2018 at $2.0 million, but up on a unit-of-production basis to $2.60/boe (Q1 2018 – $2.05/boe), illustrating the largely fixed cost nature of the East Edson property.

Financial Highlights

  • Realized revenue was $24.24/boe in the first quarter of 2019, 16% higher than the comparative period of 2018 ($20.96/boe). The increase was due largely to the 34% increase in Perpetual’s realized natural gas price to $3.54/Mcf and a higher proportion of oil and NGL in the production mix (Q1 2019 – 19%; Q1 2018 – 14%), which more than offset the decline in realized crude oil and NGL prices.
    • Natural gas revenue decreased 4% from $15.5 million in the first quarter of 2018, reflecting the impact of the 24% decrease in natural gas production volumes driven by natural declines following limited capital investment in East Edson during 2018. Higher realized natural gas prices were the result of a 26% increase in the AECO Daily Index, combined with the positive impact of the Company’s market diversification contract, which contributed $3.5 million of incremental revenue ($0.77/Mcf) over the AECO Daily Index price in the quarter (Q1 2018 – $2.4 million and $0.41/Mcf). Perpetual’s market diversification contract enabled the Company to sell approximately 72% of its natural gas production (adjusted for heat content) to markets priced at five pricing hubs outside of Alberta, and provided a 29% uplift over average AECO Daily Index prices during the first quarter (Q1 2018 – 20%).
    • Oil revenue was 44% higher than the same period in 2018, due to the 25% increase in crude oil production which more than offset a 15% decrease in the realized oil price. Compared to the first quarter of 2018, the Western Canadian Select (“WCS”) average price of $56.67/bbl increased by 17%, mainly due to the tightening of the WCS differential by US$11.99/bbl in response to the Albertagovernment’s introduction of production quotas effective January 1, 2019. Perpetual did not fully participate in the improved WCS differential, as hedges were in place protecting a WCS differential of US$25.22/bbl on 750 bbl/d for 2019.
    • NGL revenue decreased by 48% over the prior year period while NGL production decreased only 7%, reflecting the 44% decrease in Perpetual’s realized NGL price compared to the prior year period. Propane and butane prices have become disconnected from WTI light oil prices in recent months, reflecting excess supply produced from Western Canada and the United States. This oversupply condition is expected to continue.
  • Perpetual’s operating netback of $12.3 million in the first quarter of 2019 decreased 17% from $14.8 millionin the comparative period of 2018. This decrease was due to the 20% decrease in production caused by natural declines at East Edson, combined with increased higher cost Eastern Alberta heavy oil production and increased royalties due to higher natural gas prices. On a unit-of-production basis, the operating netback per boe increased 4% to $13.36/boe (Q1 2018 – $12.87/boe), reflecting a 16% increase in realized revenue per boe due to improved natural gas pricing, which more than offset the lower realized crude oil and NGL prices, offset by higher cash costs.
  • Net loss for the first quarter of 2019 was $4.9 million ($0.08/share), compared to a net loss of $6.5 million($0.11/share) in the comparative period of 2018. The decrease in net loss from the prior year period was due to the change in fair value of the TOU share investment, which increased by $6.1 million in the first quarter of 2019 compared to a decrease of $1.6 million in the comparative period of 2018. This was partially offset by a $5.8 million reduction in the fair value of derivatives compared to the prior year period, attributable to the reduction in future NYMEX natural gas prices and an increase in future oil prices during the first quarter of 2019.
  • Cash flow from operating activities in the first quarter of 2019 was $9.3 million ($0.15/share), down $1.9 million from the prior year period of $11.2 million ($0.19/share) due to the impact of a 20% decrease in production, as the changes in fair value of the TOU share investment and derivatives that impacted net loss did not impact cash flow from operating activities.
  • Adjusted funds flow in the first quarter of 2019 was $6.4 million ($0.11/share), down $2.7 million (30%) from the prior year period of $9.1 million ($0.15/share) due to lower cash flow from operating activities and a $0.4 million change in non-cash working capital. Adjusted funds flow was $6.90/boe in the first quarter of 2019, down 13% from the prior year period of $7.94/boe as the impact of higher production and operating costs, combined with lower production, was only partially offset by a 16% increase in realized revenue per boe.
  • At March 31, 2019, Perpetual had total net debt of $102.4 million, down $10.2 million (9%) from December 31, 2018. The decrease in net debt was mainly attributable to the $6.1 million increase in the fair value of TOU shares during the first quarter of 2019, combined with net cash flow from operations which exceeded capital expenditures during the period.
  • On March 27, 2019, the $55 million reserve-based credit facility borrowing limit (the “Borrowing Limit”) was confirmed by the Company’s lenders and the maturity was extended to November 30, 2020. The Credit Facility will revolve until May 31, 2020 and may be extended for a further 364-day period subject to approval by the Company’s lenders.
  • As at March 31, 2019, 61% of net debt outstanding was repayable in 2021 or later. During the three months ended March 31, 2019, Perpetual’s net debt to trailing twelve-months adjusted funds flow was unchanged at 3.7 times (December 31, 2018 – 3.7 times).
  • Perpetual had available liquidity at March 31, 2019 of $31.8 million, comprised of an unutilized revolving bank debt Borrowing Limit of $11.7 million and the market value of its Tourmaline Oil Corp. (“TOU”) share investment, net of the principal amount of the associated TOU share margin demand loan, of $20.1 million.
  • Perpetual’s Application for Summary Dismissal of the Sequoia litigation was heard during the fourth quarter of 2018. There were no developments during the first quarter of 2019 concerning this litigation. The Court’s decision is anticipated to be received in the second quarter of 2019.


On May 7, 2019, Perpetual announced it will early redeem the $14.6 million 8.75% senior unsecured notes due July 23, 2019 (the “2019 Senior Notes”), effective June 11, 2019 for $1,000 for each $1,000 principal amount of 2019 Senior Notes (the “Cash Consideration”), or $1,075 principal amount of 8.75% senior unsecured notes due January 23, 2022 (the “2022 Senior Notes”). A significant shareholder will backstop the Cash Consideration such that the redemption of the $14.6 million 2019 Senior Notes will be fully funded, and result in the issuance of $15.7 million 2022 Senior Notes.


Perpetual’s 2019 capital expenditure and adjusted funds flow guidance remains unchanged from guidance released with its 2018 year-end results on March 27, 2019.

The Company’s Board of Directors has approved a total capital spending program of $21 to $25 million for 2019 to be funded from adjusted funds flow. At least 50% will be spent in Eastern Alberta, primarily targeting heavy oil development at Mannville along with abandonment and reclamation work of up to $2 million to prudently address decommissioning obligations associated with non-producing wells. The remaining expenditures will be concentrated in East Edson, developing liquids-rich natural gas reserves in the Wilrich formation if AECO forward gas prices support investment in the second half of 2019, or alternatively, will be deployed in an expanded heavy oil drilling program.

Forecast capital activity in Eastern Alberta for 2019 includes the drilling of up to 10 (10.0 net) horizontal wells, including several multi-lateral wells, targeting a mix of step outs, exploratory wells, and infill wells in waterflooded pools. Timing for start-up of the 2019 program is dependent on surface lease conditions, but is expected to be in June or early July to take advantage of lower drilling, completion, and equipping costs generally realized in the summer in Eastern Alberta. Decommissioning expenditures will continue to be focused in the Mannville area and are expected to provide future surface lease rental and property tax expense reductions while maintaining regulatory compliance. In Eastern Alberta, production is forecast to increase by 20% to 30% from 2018, to a range of 2,200 to 2,400 boe/d (61% oil) in 2019.

At East Edson, the Company has budgeted a two (2.0 net) well drilling program to come onstream during the fourth quarter of 2019. The two wells will be extended reach horizontal (“ERH”) wells, as the performance of the ERH wells drilled in late 2017 and early 2018 indicate improved capital efficiencies over the wells drilled with less than 2,500 meters of lateral length. If AECO forward gas prices normalize above $2.00/Mcf, drilling activities are expected to continue into 2020. Processing capacity at the Company’s 100% working interest and operated West Wolf Lake facility is 65 MMcf/d, with an additional 13 MMcf/d of working interest capacity at the non-operated Rosevear plant, plus associated liquids. The planned drilling will not have a material impact on production in 2019, as new wells are forecast to come on stream late in the year. Natural declines and capital spending deferrals to late 2019 result in lower anticipated 2019 production in East Edson with an average of 7,000 to 7,200 boe/d (10% oil and NGL). Despite reduced production in East Edson and a substantially fixed operating cost base, operating costs are forecast to remain low in 2019, at less than $3.25/boe.

The table below summarizes anticipated capital spending and drilling activities for the first and second half of 2019.

2019 Exploration and Development Forecast Capital Expenditures

Q1 2019

($ millions)

# of wells


Q2 – Q4 2019

($ millions)

# of wells


West Central liquids-rich gas





Eastern Alberta











Excludes budgeted abandonment and reclamation spending of $1.5 to $2.0 million in 2019 (Q1 2019 – $0.3 million).

Perpetual expects the 2019 capital program will be funded by adjusted funds flow. Perpetual forecasts average production of 9,200 to 9,600 boe/d, with oil and NGL production growing to represent approximately 20% to 24% of the production mix. This represents an expected reduction in average daily production in 2019 of approximately 11% relative to 2018, but includes a 16% increase in oil and NGL production. The Company expects to exit the year at over 11,500 boe/d as natural gas and NGL production ramps up again driven by the second half capital spending program targeting seasonal natural gas price optimization.

Cash costs of $17.00 to $18.00/boe are forecast for 2019, up approximately 13% to 16% from 2018 due to the impact of lower forecast 2019 production on a substantially fixed operating cost base. Increased oil production in 2019, which is higher cost compared to natural gas cash costs, is also expected to contribute to the increase in 2019 cash costs per boe.

Perpetual has diversified its commodity and natural gas pricing point exposure (net of royalties) away from AECO as detailed below:

Market/Pricing Point

Natural gas

Estimated 2019 Exposure


AECO – fixed price(2)












Total natural gas


Natural gas liquids – Condensate(1)


Natural gas liquids – Other(1)


Crude oil(1)(2)


Total forecast production, net of royalties



Net of royalties.


See “Commodity price risk management and sales obligations” section of the Q1 2019 MD&A for details.

The market diversification contract is expected to continue to provide higher natural gas pricing and enhanced risk management through future periods of volatile natural gas prices in Western Canada related to market access constraints.

Guidance assumptions are as follows:

2019 Annual Guidance

2019 exploration and development expenditures ($ millions)

$21 – $25

2019 cash costs ($/boe)

$17.00 – $18.00

2019 average daily production (boe/d)

9,200 – 9,600

2019 average production mix (%)

20% – 24% oil and NGL

2019 adjusted funds flow ($ millions)

$22 – $27

2019 adjusted funds flow ($/share)

$0.36 – $0.44

Commodity price assumptions reflect forward market price levels as follows:

Market Prices(1)

Current Guidance

Prior Guidance

2019 average NYMEX natural gas price (US$/MMBtu)



2019 average West Texas Intermediate (“WTI”) oil price (US$/bbl)



2019 average Western Canadian Select (“WCS”) differential (US$/bbl)



2019 average exchange rate (US$1.00 = Cdn$)




Reflects settled and forward market prices.

Year-end 2019 net debt (net of the estimated market value of the Company’s TOU share investment of approximately $35 million), is forecast at $107 – $113 million, consistent with prior 2019 guidance issued on March 27, 2019. Current guidance is based on the following assumptions:

  • Net debt at March 31, 2019 of $102.4 million;
  • Forecast adjusted funds flow for the remainder of 2019 of $16 to $21 million;
  • Forecast capital spending for the remainder of 2019 of $20 to $24 million; and
  • Forecast decommissioning expenditures for the remainder of 2019 of $1.2 to $1.7 million.

The following sensitivities can be applied to estimate changes to annualized cash flow from operating activities and adjusted funds flow, assuming no change in differentials to Perpetual’s market pricing points:

  • For every US$0.25/MMBtu increase or decrease in the NYMEX Daily Index price, annualized adjusted funds flow increases or decreases by $4.8 million;
  • For every US$2.50/bbl increase or decrease in the WTI light oil price, annualized adjusted funds flow increases or decreases by $1.5 million;
  • For every 2.5 MMcf/d increase or decrease in average natural gas production, annualized adjusted funds flow increases or decreases by $1.6 million;
  • For every 100 bbl/d increase or decrease in average crude oil and NGL production, annualized adjusted funds flow increases or decreases by $1.8 million; and
  • For every $0.05 increase or decrease in the Cdn$/US$ exchange rate, annualized adjusted funds flow increases or decreases by $1.5 million.

Financial and Operating Highlights

Three months ended March 31,

($Cdn thousands except volume and per share amounts)





Oil and natural gas revenue




Net loss




Per share – basic and diluted(2)




Cash flow from operating activities




Adjusted funds flow(1)




Per share – basic and diluted(1)(2)




Total assets




Revolving bank debt




Term loan, principal amount



TOU share margin demand loan, principal amount




Senior Notes, principal amount



TOU share investment




Adjusted working capital deficiency (surplus)(1)




Net debt(1)




Capital expenditures




Net payments on acquisitions and dispositions



Net capital expenditures




Common shares (thousands)(3)

End of period



Weighted average – basic and diluted





Daily average production

Natural gas (MMcf/d)




Oil (bbl/d)




NGL (bbl/d)




Total (boe/d)




Average prices

Realized natural gas price ($/Mcf)




Realized oil price ($/bbl)




Realized NGL price ($/bbl)




Wells drilled – gross (net)

Natural gas

– (-)

1 (1.0)


– (-)

3 (3.0)


– (-)

4 (4.0)


These are non-GAAP measures. Please refer to “Non-GAAP Measures” below.


Based on weighted average basic common shares outstanding for the period.


All common shares are net of shares held in trust (Q1 2019 – 0.9 million; Q1 2018 – 0.3 million). See “Note 15 to the condensed interim consolidated financial statements”.


About Perpetual

Perpetual is an oil and natural gas exploration, production and marketing company headquartered in Calgary, Alberta. Perpetual operates a diversified asset portfolio, including liquids-rich natural gas assets in the deep basin of west central Alberta, heavy oil and shallow natural gas in eastern Alberta, with longer term opportunities through undeveloped oil sands leases in northern Alberta. Additional information on Perpetual can be accessed at or from the Corporation’s website at

The Toronto Stock Exchange has neither approved nor disapproved the information contained herein.

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