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Perpetual Energy Third Quarter 2020 Results

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Capital Spending, Production and Operations:

• Third quarter production averaged 4,188 boe/d, down 50% from 8,383 boe/d in the comparative period of 2019, due primarily to the sale of a 50% working interest in the East Edson property in West Central Alberta to a third-party (the “Purchaser”) for consideration including a cash payment of $35 million and the carried interest funding of the drill, complete and tie-in costs for an eight-well drilling program (the “East Edson Transaction”).
• Compared to the second quarter of 2020, total production increased by 14% or 526 boe/d, due to the restart of heavy oil production which was suspended late in the first quarter in response to low oil prices. As Western Canadian Select (“WCS”) prices improved from their April lows, the Company began reactivating certain low-cost heavy oil production in mid-May 2020 and has continued to ramp up production as oil prices recover. As of September 30, 2020, Perpetual had restarted all heavy oil production with the exception of approximately 175 bbl/d of higher cost production in certain pools at Mannville. Additionally, production at East Edson was shut-in during the five-day scheduled turnaround at the West Wolf gas plant which is anticipated to support continued efficient and reliable operations going forward.
• Two wells (1.0 net) of the eight-well carried interest drilling commitment were drilled, completed and tied-in to production in mid-September by the operator at the 50% owned East Edson property. Three wells (1.5 net) are currently drilling and are expected to be tied-in to production later in the fourth quarter with a further two wells (1.0 net) scheduled to be drilled and tied-in to production during the first quarter of 2021. Capital cost reductions per well are exceeding Perpetual’s 25% cost reduction expectations. As production is tied-in from these new wells, unit production and operating costs are anticipated to decrease due to the largely fixed cost nature of the East Edson operations.
• Perpetual’s operated exploration and development spending in the third quarter of 2020 was nominal, consistent with guidance released on July 31, 2020 with the Company’s second quarter results.
• On an absolute dollar basis, production and operating costs were down by $1.6 million (39%) from the prior year period. This decrease reflects the impact of the East Edson Transaction, the elimination of variable costs related to the ongoing shut-in of 175 bbl/d of higher cost heavy oil production at Mannville, and other cost mitigation initiatives. Perpetual’s 50% share of the West Wolf plant turnaround costs during the third quarter were $0.3 million. Total production and operating expenses were up 23% on a unit-of-production basis to $6.79/boe for the third quarter of 2020, compared to $5.53/boe for the comparable period of 2019.

Financial Highlights:

• Realized revenue was $17.93/boe in the third quarter of 2020, 26% lower than the comparative period of 2019 ($24.34/boe).
  • Perpetual’s realized natural gas price, including derivatives, decreased 98% to $0.06/Mcf for the third quarter of 2020 from $3.13/Mcf in the comparative period of 2019, and represented only 3% of the AECO Daily Index price compared to 344% in the prior year period. Compared to the AECO Daily Index, lower realized natural gas prices were the result of AECO-NYMEX basis hedging losses of $2.6 million ($1.75/Mcf) which occurred as Western Canadian gas storage filled rapidly. The basis positions were put in place prior to the implementation of the Temporary Service Protocol by TC Energy which established access for storage operators. The Company has closed out its remaining AECO-NYMEX basis hedge positions by entering into offsetting hedge arrangements for the remainder of 2020 ($2.4 million unrealized loss) and 2021 ($3.4 million unrealized loss). Realized losses on financial and physical gas derivatives decreased the realized price in the third quarter of 2020 by $2.42/Mcf compared to the AECO Daily Index (Q3 2019 – increased the realized price by $1.20/Mcf).
  • In the third quarter of 2020, the Company reduced its fixed volume obligations under the market diversification contract by 30,000 MMBtu/d to 10,000 MMBtu/d for the period commencing November 1, 2020 and ending on October 31, 2021 to align natural gas sales obligations with lower forecast production volumes following the East Edson Transaction. The modification resulted in a realized loss on derivatives of $1.0 million ($2.53/boe) and reduced the Company’s realized natural gas price by $0.65/Mcf in the third quarter of 2020. Subsequent to September 30, 2020, the Company reduced its fixed volume obligations under the market diversification contract by 14,600 MMBtu/d to 25,400 MMBtu/d for the period commencing November 1, 2021 to October 31, 2022, realizing a gain of $0.5 million. Market diversification contract pricing is based on daily index natural gas prices at pricing hubs outside of Alberta that generally track North American NYMEX prices.
  • Perpetual’s realized oil price of $55.71/bbl was 26% higher than the third quarter of 2019, and included realized hedging gains on crude oil derivative contracts of $2.2 million or $19.83/bbl (Q3 2019 – realized hedging losses of $1.1 million or $8.83/bbl). Excluding realized hedging gains, Perpetual’s realized oil price was $35.88/bbl in the third quarter of 2020, down 32% from $53.14/bbl in the prior year period. Compared to the second quarter of 2020, Perpetual’s realized oil price excluding hedging gains increased by 54% ($12.64/bbl), attributable to a similar increase in WTI prices. WTI fixed price hedges have been substantially offset for the remainder of 2020 by similar arrangements having unrealized gains of $3.3 million. WTI-WCS differential hedges remain in place for the remainder of 2020 on an average of 200 bbl/d at a fixed differential of US$19.75/bbl. For 2021, the Company has fixed the WTI-WCS differential on 300 bbl/d at US$13.25/bbl.
  • Perpetual’s realized NGL price for the third quarter of 2020 was $28.09/bbl, down 25% from the third quarter of 2019, reflecting a decrease in all NGL component prices which moved lower commensurate with lower WTI light oil prices.
• Royalty expenses for the third quarter of 2020 were $1.6 million, 30% lower than the comparative period of 2019 due to both lower production and oil and natural gas revenue, partially offset by higher Alberta Gas Reference prices and AECO Daily Index prices which are used to calculate crown and freehold natural gas royalties, respectively.
• Transportation costs in the third quarter of 2020 were $0.8 million, down 51% from the prior year period of $1.5 million. On a unit-of-production basis, company-wide transportation costs were largely unchanged, decreasing from $2.00/boe in the third quarter of 2019 to $1.98/boe in the same period of 2020. Effective July 31, 2020, Perpetual’s natural gas firm transportation capacity was reduced from 25.5 MMcf/d to 15.4 MMcf/d, reducing unutilized demand charges at East Edson.
• Cash costs were down 34% to $8.6 million (Q3 2019 – $13.0 million), but up 32% on a unit-of-production basis to $22.21/boe (Q3 2019 – $16.84/boe). Cash costs decreased by $4.4 million from the prior year period due to the East Edson Transaction, the continued shut-in of approximately 175 bbl/d of higher cost heavy oil production, the reduction in work hours and corresponding compensation to 80% effective April 1, 2020, and payments received from the Canada Emergency Wage Subsidy (“CEWS”) program. Cash costs on a unit-of-production basis increased by 32%, due to the 50% decrease in production.
• Net loss for the third quarter of 2020 was $7.5 million ($0.12/share), compared to a net loss of $20.3 million ($0.34/share) in the comparative period of 2019.
• Cash flow used in operating activities in the third quarter of 2020 was $2.5 million ($0.04/share), down $8.0 million from the prior year period (Q3 2019 – cash flow from operating activities of $5.5 million and $0.09/share).
• Adjusted funds flow in the third quarter of 2020 was negative $2.1 million (negative $0.03/share), down $6.3 million (150%) from the prior year period of $4.2 million ($0.07/share) due primarily to the 50% decrease in production in the third quarter of 2020 caused by the sale of East Edson production and natural gas hedging losses. Compared to the second quarter of 2020, adjusted funds flow improved by $1.2 million, due to higher third quarter oil production following the restart of production in mid-May and higher selling prices for all commodities.
• At September 30, 2020, Perpetual had total net debt of $102.1 million, down $16.0 million (14%) from December 31, 2019. The improvement reflected the $34.8 million of net cash consideration received from the East Edson Transaction. Compared to June 30, 2020, net debt increased by $3.5 million (4%) due to increased draws on the reserve-based Credit Facility to fund net working capital payments and cash flows used in operating activities.
• Perpetual had available liquidity at September 30, 2020 of $3.6 million, comprised of the $20 million Credit Facility Borrowing Limit, less current borrowings and letters of credit of $15.1 million and $1.3 million, respectively. Subsequent to quarter end, Perpetual has reduced its outstanding letters of credit to $0.9 million. On October 30, 2020, the $20 million Borrowing Limit was confirmed and the revolving credit period was extended until November 30, 2020. If not extended by November 30, 2020, the credit facility will cease to revolve, and all outstanding advances will be repayable.

Seqouia Litigation Update

On January 13, 2020, the Court of Queen’s Bench issued its written decision related to the Statement of Claim filed on August 3, 2018 against Perpetual and its President and CEO with respect to the Company’s disposition of shallow gas assets in Eastern Alberta to an unrelated third party on October 1, 2016. The decision dismissed and struck all claims against the Company’s CEO and all but one of the claims filed by PricewaterhouseCoopers Inc. (PwC) LIT in its capacity as trustee in bankruptcy against Perpetual. The Court did not find that the test for summary dismissal relating to whether the asset transaction was an arm’s length transfer for purposes of section 96(1) of the Bankruptcy and Insolvency Act (the “BIA”) was met, on the balance of probabilities. Accordingly, the BIA claim was not dismissed or struck and only that part of the claim can continue against Perpetual.

The Trustee filed a notice of appeal with the Court of Appeal of Alberta, challenging the entire decision, and Perpetual filed a similar notice of appeal contesting the BIA claim portion of the decision. The appeal proceedings are scheduled to be heard in December 2020. On September 24, 2019, Perpetual filed an application for security for costs of the appeal. On January 28, 2020, the Court of Appeal issued its decision, requiring the Trustee to post security with the Court of Appeal in the amount of $0.2 million. Applications filed by the Trustee to appeal the security for costs decision and alter the reasons for the decision were dismissed at a hearing held on June 18, 2020. Costs of $0.1 million were awarded by the Court of Appeal against the Trustee on July 21, 2020.

On August 26, 2020, costs of $0.6 million were awarded by the Court against PwC in their personal capacity, related to the claims against Perpetual’s CEO which were dismissed and struck in the January 13, 2020 decision. Additionally, the Court ordered PwC to post security of $1.7 million as a condition to continuing the Trustee’s Statement of Claim action. PwC has since posted the required security with the Court and has filed a notice of appeal with the Court of Appeal of Alberta with respect to the cost award decision.

On February 25, 2020, Perpetual filed a second application to strike and summarily dismiss the BIA claim on the basis that there was no transfer at undervalue, and Sequoia was not insolvent at the time of the asset transaction nor caused to be insolvent by the asset transaction. In July 2020, the Orphan Well Association (“OWA”), certain oil and gas companies, and six municipalities applied to intervene in the second BIA dismissal application proceedings. The OWA and certain oil and gas companies were permitted to intervene (the “Intervenors”) in the proceedings which took place on October 1^st and 2^nd, 2020. The Court’s decision is pending. In late October, the Intervenors also filed applications with the Court of Appeal of Alberta to be permitted to intervene in the Trustee’s appeal of the January 13, 2020 Court decision scheduled for December 2020.

Management expects that the Company is more likely than not to be completely successful in defending against the Sequoia Litigation such that no damages will be awarded against it, and therefore, no amounts have been accrued as a liability in Perpetual’s financial statements.

Outlook

Perpetual currently anticipates that five of the eight carried interest wells at the 50% owned East Edson property will be drilled, completed and tied-in before the end of the fourth quarter of 2020. Two horizontal Wilrich wells were tied-in to production in mid-September, with drilling operations underway on the next three well pad which is scheduled to be on production in the fourth quarter. A two well pad is planned for the first quarter of 2021 and the final carried interest well is scheduled to be drilled, completed and tied-in during the second half of 2021. While oil prices have begun to recover from their second quarter lows, capital expenditures for the remainder of 2020 in Eastern Alberta have been deferred, pending a sustained recovery of WTI oil prices to the US$45.00/bbl level.

With the reactivation of shut-in heavy oil production and the contribution from the first two carried interest wells at East Edson in late-September, production is forecast to increase 24% in the fourth quarter to 5,100 to 5,300 boe/d (29% liquids). First quarter 2021 production is anticipated to increase a further 12% to 5,700 to 6,000 boe/d (26% liquids) with the full impact of the first five carried interest East Edson wells. An additional 175 bbl/d of heavy oil production could be re-started if WTI oil prices increase above the US$45.00/bbl level.

The Company has been approved for funding of $1.5 million from the Alberta Site Rehabilitation program. Work on these funded abandonment and reclamation projects will be ongoing throughout the fourth quarter of 2020 and into 2021.

Minimization of operating and corporate costs will remain a priority, as will ensuring employees remain safe and healthy amid the COVID-19 pandemic.