PrairieSky Royalty Ltd. (" PrairieSky " or the " Company ") (TSX: PSK) is pleased to announce its third quarter (" Q3 2020 ") operating and financial results for the period ended September 30, 2020.

Third Quarter 2020 Highlights:
Revenues increased 54% to $43.5 million, comprised of royalty production revenues of $38.4 million and other revenues
of $5.1 million, compared to Q2 2020.
Funds from Operations increased 78% quarter over quarter to $37.9 million ($0.16 per common share basic and diluted).
Royalty production averaged 18,745 BOE per day (48% liquids) with oil production increasing 9% from Q2 2020.
Repurchased and cancelled 8.9 million common shares under the normal course issuer bid (" NCIB "), representing 4% of
the issued and outstanding shares.
Declared a third quarter dividend of $13.4 million ($0.06 per common share), representing a payout ratio of 35%.


PrairieSky's Q3 2020 results demonstrate the resiliency of our high margin, low cost royalty model with funds from operations of $37.9 million, an increase of 78% compared to Q2 2020. Our diversified portfolio of royalty assets, numerous ongoing secondary and tertiary recovery schemes, and the early stage nature of the Clearwater and Duvernay oil plays will provide PrairieSky owners with long-term growth as capital returns to Western Canada, without the need for future acquisitions or equity issuances. We continue to review only those acquisition opportunities that have the potential to improve our business per share and enhance our existing high-quality portfolio of royalty assets. In Q3 2020, PrairieSky accelerated the NCIB, acquiring and cancelling 8.9 million common shares for $81.8 million, representing approximately 4% of the outstanding common shares. Share purchases were funded from cash flows above the quarterly dividend, and by drawing down on PrairieSky's available credit facility, which PrairieSky expects to pay down in less than nine months. There are now 223.3 million common shares outstanding.

Exploration and development activity improved throughout the quarter, with 18 rigs working in Western Canada at the beginning of Q3 2020 and increasing to 73 rigs at September 30, 2020. There were 44 wells spud (93% oil) on PrairieSky lands during the quarter with a focus on Viking, Bakken and Leduc units (18 wells), as well as 12 new Viking wells and six new wells in the Clearwater oil play. In addition, three Spirit River natural gas wells were spud in Q3 2020. Rig counts have continued to increase in the early stages of Q4 2020, with approximately 85 rigs currently working in Western Canada.

PrairieSky's Q3 2020 total royalty production volumes increased modestly to 18,745 BOE per day, generating royalty production revenue of $38.4 million, an increase of 53% compared to Q2 2020. Oil royalty production volumes averaged 6,572 barrels per day, an increase of 9% over Q2 2020 oil royalty production volumes of 6,035 barrels per day as producers started to bring previously shut-in production back on throughout the quarter. Oil royalty revenue totaled $24.8 million, an 85% increase over Q2 2020 primarily due to improved production, more stable average West Texas Intermediate (" WTI ") benchmark pricing and narrowed Canadian light and heavy oil differentials. Natural gas royalty production volumes averaged 58.2 MMcf per day (Q2 2020 - 60.3 MMcf per day) and generated $8.7 million of royalty revenue, an increase of 14% compared to Q2 2020 due to stronger average AECO index benchmark pricing through the quarter. NGL royalty revenue totaled $4.9 million, an increase of 20% compared to Q2 2020 primarily as a result of improved pricing, partially offset by a modest 4% decrease in production volumes to 2,473 barrels per day in Q3 2020.

Other revenue improved in Q3 2020, totaling $5.1 million (Q2 2020 - $3.1 million) comprised of $1.2 million of lease rentals, $2.1 million in other income and $1.8 million in bonus consideration. During the quarter, PrairieSky entered into 15 new leases with 15 different counterparties on both oil and natural gas plays across Alberta and Saskatchewan.

Cash administrative expenses totaled $3.5 million or $2.03 per BOE in the quarter. We are committed to managing controllable costs in our business and expect cash administrative expenses to remain well below $3.00 per BOE in 2020. PrairieSky's staff continued their focus on ensuring timely and accurate royalty payments, collecting compliance recoveries totaling $1.0 million in the quarter bringing year to date compliance recoveries to $5.0 million.

As we look towards 2021, our organization is working hard on the third PrairieSky Royalty Playbook ahead of our Investor Day in May, as well as our fourth annual ESG report. We expect both of these documents to highlight the unique attributes of our long duration, capital free, high margin business model, which was recently recognized by Sustainalytics as the #1 ranked company in their Oil and Gas ESG Risk Ratings.

The health and safety of our employees and community are our priority and we continue to monitor the situation related to COVID-19 and follow the advice of public health officials. While the majority of the staff have returned to the office environment under stringent health and safety protocols, we continue to support staff who are working remotely away from the office. Our investment in technology and systems over a number of years has allowed us to effectively manage a hybrid workforce through the COVID-19 pandemic without interruption while ensuring the safety and well-being of our staff. We appreciate the continued efforts of our team and we want to thank our shareholders for their ongoing support. Please contact Pam Kazeil, our Chief Financial Officer, at 587-293-4089 or myself at 587-293-4005 with any questions.

Andrew Phillips, President & CEO


The following table summarizes select operational and financial information of the Company for the periods noted. All dollar amounts are stated in Canadian dollars unless otherwise noted.

A full version of PrairieSky's MD&A and unaudited interim condensed Consolidated Financial Statements and notes thereto for the fiscal period ended September 30, 2020 is available on SEDAR at and PrairieSky's website at .

Three months ended
September 30
Nine months ended
September 30
(millions, except per share or as otherwise noted) 2020 2019 2020 2019
Revenues $ 43.5 $ 58.8 $ 124.4 $ 201.3
Funds from Operations 37.9 48.8 105.7 164.6
Per Share – basic and diluted (1) 0.16 0.21 0.46 0.70
Net Earnings 9.4 16.7 17.6 87.1
Per Share - basic and diluted (1) 0.04 0.07 0.08 0.37
Dividends declared (2) 13.4 45.5 72.7 136.7
Per Share 0.0600 0.1950 0.3150 0.5850
Common share repurchases 81.8 4.2 90.9 16.2
Acquisitions, including non-cash consideration - 5.2 6.7 7.8
Working Capital (Deficiency) at period end (66.2 ) (7.4 ) (66.2 ) (7.4 )
Shares Outstanding
Shares outstanding at period end 223.3 233.3 223.3 233.3
Weighted average – basic 229.8 233.4 231.7 233.7
Weighted average – diluted 230.2 233.8 232.2 234.1
Royalty Production Volumes
Crude Oil (bbls/d) 6,572 8,011 7,061 8,548
NGL (bbls/d) 2,473 2,334 2,667 2,536
Natural Gas (MMcf/d) 58.2 61.0 60.7 63.1
Royalty Production (BOE/d) (3) 18,745 20,512 19,845 21,601
Realized Pricing
Crude Oil ($/bbl) $ 41.11 $ 59.04 $ 36.82 $ 60.79
NGL ($/bbl) 21.43 20.23 21.92 28.81
Natural Gas ($/Mcf) 1.62 0.72 1.52 1.14
Total ($/BOE) (3) $ 22.27 $ 27.50 $ 20.71 $ 30.78
Operating Netback per BOE (4) $ 19.54 $ 23.31 $ 17.90 $ 26.73
Funds from Operations per BOE $ 21.98 $ 25.86 $ 19.44 $ 27.91
Oil Price Benchmarks
Western Texas Intermediate (WTI) (US$/bbl) $ 40.93 $ 56.50 $ 38.32 $ 57.07
Edmonton Light Sweet ($/bbl) $ 49.80 $ 68.48 $ 43.70 $ 69.62
Western Canadian Select (WCS) crude oil
differential to WTI (US$/bbl)
$ (9.09 ) $ (12.24 ) $ (13.69 ) $ (11.74 )
Foreign Exchange Rate (US$/CAD$) 0.7511 0.7564 0.7393 0.7525
Natural Gas Price Benchmarks
AECO monthly index ($/Mcf) $ 2.15 $ 1.05 $ 2.07 $ 1.39
AECO daily index ($/Mcf) $ 2.27 $ 0.89 $ 2.10 $ 1.52

(1) Net Earnings and Funds from Operations per Common Share are calculated using the weighted average number of basic and diluted common shares outstanding.

(2) A dividend of $0.06 per common share was declared on September 9, 2020. The dividend was paid on October 15, 2020 to shareholders of record as at September 30, 2020.

(3) See "Conversions of Natural Gas to BOE".

(4) Operating Netback per BOE is defined under the Non-GAAP Measures section in the MD&A.


A conference call to discuss the results will be held for the investment community on Tuesday, October 27, 2020 beginning at 6:30 a.m. MDT (8:30 a.m. EDT). To participate in the conference call, approximately 10 minutes prior to the conference call, please dial:

(844) 657-2668 (toll free in North America)
(612) 979-9882 (International)
Conference ID: 3539308


This press release includes certain statements regarding PrairieSky's future plans and operations and contains forward-looking statements that we believe allow readers to better understand our business and prospects. The use of any of the words "expect", "anticipate", "continue", "estimate", "objective", "ongoing", "may", "will", "project", "should", "believe", "plans", "intends", "strategy" and similar expressions are intended to identify forward-looking information or statements. Forward-looking statements contained in this press release include estimates regarding our expectations with respect to PrairieSky's business and growth strategy, future growth from PrairieSky's existing royalty asset portfolio, the quality of PrairieSky's existing royalty asset portfolio, the timing of repaying amounts drawn under PrairieSky's existing credit facility, the amount of royalty production shut-in and the timing of when that production will resume, improvement in the business in the near, medium and long term, expectations regarding cash administrative expenses per BOE through the balance of 2020, future collections from compliance activities and future activity on PrairieSky's lands.

With respect to forward-looking statements contained in this press release, we have made several assumptions including those described in detail in our MD&A and the Annual Information Form for the period ended December 31, 2019. Readers and investors are cautioned that the assumptions used in the preparation of such forward-looking information and statements, although considered reasonable at the time of preparation, may prove to be imprecise and, as such, undue reliance should not be placed on forward-looking statements. Our actual results, performance, or achievements could differ materially from those expressed in, or implied by, these forward-looking statements. We can give no assurance that any of the events anticipated will transpire or occur, or if any of them do, what benefits we will derive from them.

By their nature, forward-looking statements are subject to numerous risks and uncertainties, some of which are beyond our control, including the impact of general economic conditions, industry conditions, volatility of commodity prices, lack of pipeline capacity, currency fluctuations, imprecision of reserve estimates, competitive factors impacting royalty rates, environmental risks, taxation, regulation, changes in tax or other legislation, competition from other industry participants, the lack of availability of qualified personnel or management, stock market volatility, political and geopolitical instability and our ability to access sufficient capital from internal and external sources. In addition, PrairieSky is subject to numerous risks and uncertainties in relation to acquisitions. These risks and uncertainties include risks relating to the potential for disputes to arise with counterparties, and limited ability to recover indemnification under certain agreements. The foregoing and other risks are described in more detail in PrairieSky's MD&A, and the Annual Information Form for the year ended December 31, 2019 under the headings "Risk Management" and "Risk Factors", respectively, each of which is available at and PrairieSky's website at .

Further, any forward-looking statement is made only as of the date of this press release, and PrairieSky undertakes no obligation to update or revise any forward-looking statement or statements to reflect events or circumstances after the date on which such statement is made or to reflect the occurrence of unanticipated events, except as required by applicable securities laws. New factors emerge from time to time, and it is not possible for PrairieSky to predict all of these factors or to assess in advance the impact of each such factor on PrairieSky's business or the extent to which any factor, or combination of factors, may cause actual results to differ materially from those contained in any forward-looking statements.

The forward-looking information contained in this document is expressly qualified by this cautionary statement.


To provide a single unit of production for analytical purposes, natural gas production and reserves volumes are converted mathematically to equivalent barrels of oil (BOE). PrairieSky uses the industry-accepted standard conversion of six thousand cubic feet of natural gas to one barrel of oil (6 Mcf = 1 bbl). The 6:1 BOE ratio is based on an energy equivalency conversion method primarily applicable at the burner tip. It does not represent a value equivalency at the wellhead and is not based on either energy content or current prices. While the BOE ratio is useful for comparative measures and observing trends, it does not accurately reflect individual product values and might be misleading, particularly if used in isolation. As well, given that the value ratio, based on the current price of crude oil to natural gas, is significantly different from the 6:1 energy equivalency ratio, using a 6:1 conversion ratio may be misleading as an indication of value.


Certain measures in this document do not have any standardized meaning as prescribed by International Financial Reporting Standards ("IFRS") and, therefore, are considered non-GAAP measures. These measures may not be comparable to similar measures presented by other issuers. These measures are commonly used in the crude oil and natural gas industry and by PrairieSky to provide potential investors with additional information regarding the Company's liquidity and its ability to generate funds to conduct its business. Non-GAAP measures include operating netback per BOE, payout ratio and cash administrative expenses per BOE. Management's use of these measures is discussed further below. Further information can be found in the Non-GAAP Measures section of PrairieSky's MD&A.

"Operating Netback per BOE" represents the cash margin for products sold on a BOE basis. Operating netback per BOE is calculated by dividing the operating netback (royalty production revenues less production and mineral taxes and administrative expenses) by the average daily production volumes for the period. Operating netback per BOE is used to assess the cash generating and operating performance per unit of product sold and the comparability of the underlying performance between years. Operating netback per BOE measures are commonly used in the crude oil and natural gas industry to assess performance comparability.

"Payout Ratio" is calculated as dividends declared as a percentage of funds from operations. Payout ratio is used by dividend paying companies to assess dividend levels in relation to the funds generated and used in operating activities.

"Cash Administrative Expenses" represents administrative expenses excluding the volatility and fluctuations in share-based compensation expense for RSUs, PSUs, ODSUs and DSUs and stock options that were not settled in cash in the current period. Cash administrative expenses are calculated as total administrative expenses, adjusting for share-based compensation expense (recovery) in the period, plus any actual cash payments made under the RSU, PSU, ODSU or DSU plans. Management believes cash administrative expenses are a common benchmark used by investors when comparing companies to evaluate operating performance.

"Cash Administrative Expenses per BOE" represents cash administrative expenses on a BOE basis. Cash administrative expenses per BOE is calculated by dividing cash administrative expenses by the average daily production volumes for the period. Cash administrative expenses per BOE assists management and investors in evaluating operating performance on a comparable basis.

Cash Administrative Expenses

The following table presents the computation of Cash Administrative Expenses:

T hree months ended
September 30
Nine months ended
September 30
(millions) 202 0 2 019 202 0 2 019
Total Administrative Expenses $ 4.1 $ 6.7 $ 13.7 $ 20.6
Share-Based Compensation Expense (0.6 ) (2.0 ) (0.9 ) (5.6 )
Cash Payments made under RSU and PSU Plans (1) - - 1.7 2.2
Cash Administrative Expenses $ 3.5 $ 4.7 $ 14.5 $ 17.2

(1) See PrairieSky's MD&A for details on its share-based compensation plans.


PrairieSky is a royalty company, generating royalty production revenues as petroleum and natural gas are produced from its properties. PrairieSky has a diverse portfolio of properties that have a long history of generating funds from operations and that represent the largest and most consolidated independently-owned fee simple mineral title position in Canada. PrairieSky's common shares trade on the Toronto Stock Exchange under the symbol PSK.


Andrew Phillips
President & Chief Executive Officer
PrairieSky Royalty Ltd.

Pamela Kazeil
Vice President, Finance & Chief Financial Officer
PrairieSky Royalty Ltd.

Investor Relations
(587) 293-4000

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Tourmaline Oil Corp. (TSX: TOU) ("Tourmaline" or the "Company") is pleased to announce the completion of its previously announced acquisition of Rising Star Resources Ltd. (the "Transaction"). The purchase price for the Transaction included 6,000,000 common shares ("Topaz Shares") of Topaz Energy Corp. ("Topaz") currently owned by Tourmaline and $67,770,000 . In connection with this disposition of Topaz Shares, Tourmaline has filed an Early Warning Report as required by applicable securities laws.

Tourmaline Oil Corp. (CNW Group/Tourmaline Oil Corp.) (CNW Group/Tourmaline Oil Corp.)

Required Early Warning Disclosure

This disclosure is being provided pursuant to National Instrument 62-103 – The Early Warning System and Related Take-Over Bid and Insider Reporting Issues , which also requires a report to be filed by Tourmaline with the regulatory authorities in each jurisdiction in which the Company is a reporting issuer containing information with respect to the foregoing matters (the "Early Warning Report").

Prior to the Transaction, the Company held 51,149,494 Topaz Shares, representing approximately 35.5% of the issued and outstanding Topaz Shares. Following the closing of the Transaction, the Company holds 45,149,494 Topaz Shares, representing approximately 31.3% of the issued and outstanding Topaz Shares.

Tourmaline disposed of the Topaz Shares as part of a long-term plan to reduce its equity position as Topaz develops and continues to succeed as an independent royalty and infrastructure company. Tourmaline's reduction in Topaz equity is also consistent with its commitment to continue to reduce overall debt levels of Tourmaline and accelerate shareholder returns. The disposition will expand Topaz's free-trading share float and provide new and existing shareholders with enhanced trading liquidity which is in-line with Topaz's strategic objectives.

Tourmaline intends to hold its Topaz Shares for investment purposes. Tourmaline may from time to time, depending on market and other conditions, acquire additional Topaz Shares or dispose of Topaz Shares through market transactions, public offerings, private agreement or otherwise.

The Early Warning Report with additional information in respect of the foregoing matters will be filed and made available on the System for Electronic Document Analysis and Review (SEDAR) at under Topaz's issuer profile. A copy of such report may also be obtained by contacting the secretary of Topaz, on behalf of Tourmaline, at telephone number (587) 747-4830.

Tourmaline's head office is located at Suite 2900, 250 6th Avenue SW, Calgary, Alberta T2P 3H7 and Topaz's head office is located at Suite 2900, 250 6th Avenue SW, Calgary, Alberta T2P 3H7.

Reader Advisories


All amounts in this news release are stated in Canadian dollars unless otherwise specified.


This news release contains forward-looking information and statements (collectively, "forward-looking information") within the meaning of applicable securities laws. The use of any of the words "forecast", "expect", "anticipate", "continue", "estimate", "objective", "ongoing", "on track", "may", "will", "project", "should", "believe", "plans", "intends" and similar expressions are intended to identify forward-looking information. More particularly and without limitation, this news release contains forward-looking information concerning Tourmaline's plans relating to the Common Shares The forward-looking information is based on certain key expectations and assumptions made by Tourmaline.

Although Tourmaline believes that the expectations and assumptions on which such forward-looking information is based are reasonable, undue reliance should not be placed on the forward-looking information because Tourmaline can give no assurances that it will prove to be correct. Since forward-looking information addresses future events and conditions, by its very nature it involves inherent risks and uncertainties. Actual results could differ materially from those currently anticipated due to a number of factors and risks.

Additional information on these and other factors that could affect Tourmaline, or its operations or financial results, are included in the Company's most recently filed Management's Discussion and Analysis (See "Forward-Looking Statements" therein), Annual Information Form (See "Risk Factors" and "Forward-Looking Statements" therein) and other reports on file with applicable securities regulatory authorities and may be accessed through the SEDAR website ( ) or Tourmaline's website ( ).

The forward-looking information contained in this news release is made as of the date hereof and Tourmaline undertakes no obligation to update publicly or revise any forward-looking information, whether as a result of new information, future events or otherwise, unless expressly required by applicable securities laws.


Tourmaline is Canada's largest and most active natural gas producer dedicated to producing the lowest-emission and lowest-cost natural gas in North America . We are an investment grade exploration and production company providing strong and predictable operating and financial performance through the development of our three core areas in the Western Canadian Sedimentary Basin. With our existing large reserve base, decades-long drilling inventory, relentless focus on execution and cost management, and industry-leading environmental performance, we are excited to provide shareholders an excellent return on capital, and an attractive source of income through our base dividend and surplus free cash flow distribution strategies.

SOURCE Tourmaline Oil Corp.

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Gran Tierra Energy Inc. Announces Second Quarter 2022 Results

Gran Tierra Energy Inc. Announces Second Quarter 2022 Results

Gran Tierra Energy Inc.. (“Gran Tierra” or the “Company”) (NYSE American:GTE) (TSX:GTE) (LSE:GTE) today announced the Company’s financial and operating results for the quarter ended June 30, 2022 (“the Quarter”). All dollar amounts are in United States dollars, and production amounts are on an average working interest (“WI”) before royalties basis unless otherwise indicated. Per barrel (“bbl”) and bbl per day (“BOPD”) amounts are based on WI sales before royalties. For per bbl amounts based on net after royalty (“NAR”) production, see Gran Tierra’s Quarterly Report on Form 10-Q filed August 8, 2022.
  • Average Total Production of 30,607 BOPD, Highest since Fourth Quarter 2019
  • Total Average Production Up 4% from First Quarter 2022 and 33% from Second Quarter 2021
  • Generated Net Income of $53 Million
  • Increased Adjusted EBITDA(1) to $140 Million, Up 286% Year-on-Year
  • Grew Net Cash Provided by Operating Activities to $143 Million, Up 285% Year-on-Year
  • Increased Funds Flow from Operations(1) to $104 Million, Up 345% Year-on-Year, Highest since First Quarter 2013
  • Generated Free Cash Flow(1)of $38 Million
  • Credit Facility Repaid in Full
  • As of June 30, 2022, Cash Balance of $109 Million and Net Debt(1) of $491 Million

Key Highlights of the Quarter:

  • Net Income: Gran Tierra generated net income of $53 million, up 275% from first quarter 2022 (“the Prior Quarter”), and versus a net loss of $18 million in second quarter 2021.
  • Diluted Earnings Per Share: Gran Tierra generated earnings of $0.14 per share, up from $0.04 per share in the Prior Quarter and compared to a net loss of $0.05 per share in second quarter 2021.
  • Significant Growth in Net Cash Provided by Operating Activities: The Company realized net cash provided by operating activities of $143 million, up 285% from second quarter 2021.
  • Highest Funds Flow from Operations(1) since First Quarter 2013: Funds flow from operations(1) increased to $104 million, the highest since first quarter 2013, which was up 19% from the Prior Quarter and up 345% from second quarter 2021. On a diluted per share basis funds flow from operations was $0.28, which was up from $0.06 per share in second quarter 2021 and up from $0.23 per share in the Prior Quarter.
  • Strong Free Cash Flow(1): Gran Tierra generated free cash flow(1) of $38 million while completing the majority of the Company’s development programs in Acordionero and Costayaco.
  • Rapid Debt Reduction: Gran Tierra has repaid its credit facility. In only two years, Gran Tierra fully paid down its credit facility balance from $207 million to zero, which demonstrates the Company’s commitment to rapidly reduce debt with its free cash flow(1). As of June 30, 2022, the Company had a cash balance of $109 million and net debt(1) of $491 million. The Quarter’s net debt to annualized EBITDA(1) ratio was below 1.0 times and the Company is targeting a long-term net debt to EBITDA ratio of under 1.0 times at an assumed $60/bbl Brent oil price.
  • Annual Production Growth: Production was in-line with the budget and averaged 30,607 BOPD, up 4% compared to the Prior Quarter and 33% from second quarter 2021.
  • Additional Key Financial Metrics:
    • Capital Expenditures: Capital expenditures of approximately $65 million were higher than the Prior Quarter’s level of $41 million, as the majority of Gran Tierra’s capital programs in both Costayaco and Acordionero were completed during the Quarter.
    • Increased Oil Sales: The Brent oil price averaged $111.98/bbl, up 14% from the Prior Quarter and up 62% year-on-year. Gran Tierra generated oil sales of $206 million, up 18% from the Prior Quarter and 113% from the second quarter of 2021. The significant annual increase in oil sales was driven by the Company’s 33% increase in quarterly production year-on-year, combined with the increase in the Brent oil price over the same period.
    • Strong Operating Netback(1)(2): The Company’s operating netback(1)(2) of $59.62/bbl was the highest netback since third quarter 2014, and was up 14% from the Prior Quarter and up 81% year-on-year. This strong annual increase was driven by Gran Tierra’s 33% rise in quarterly production year-on-year and the strong growth in the Brent oil price.
    • Operating Expenses: Compared to the Prior Quarter, Gran Tierra’s operating expenses increased 8% to $14.38/bbl, up from $13.34/bbl, due to higher workover and power generation costs. Compared to the second quarter of 2021, operating expenses increased by 12% on a per bbl basis, primarily as a result of workover costs.
    • Other Expenses:
      • The quality and transportation discount increased 3% to $13.00 per bbl, compared to $12.57 per bbl in the Prior Quarter, because of widening Castilla and Vasconia oil price differentials to Brent.
      • General and administrative (“G&A”) expenses before stock-based compensation were $2.86 per bbl, down from $2.97 per bbl in the Prior Quarter and $3.49 per bbl in second quarter 2021. This decrease was driven by the Company’s higher sales volumes in the Quarter.

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Cenovus Acquiring Outstanding 50% Interest in Toledo Refinery from bp, Will Assume Operatorship

Cenovus Energy Inc. (TSX: CVE) (NYSE: CVE), through its U.S. operating business, has reached an agreement to purchase bp's 50% interest in the bp-Husky Toledo Refinery in Ohio. Cenovus has owned the other 50% of the refinery since its combination with Husky Energy in 2021. Cenovus's U.S. operating business will assume operatorship from bp upon closing of the transaction, which is expected before the end of 2022, dependent on the satisfaction of closing conditions. Total consideration includes US$300 million in cash, subject to customary closing adjustments, plus the value of inventory. In addition, the parties have signed a multi-year product supply agreement.

"Fully owning the Toledo Refinery provides a unique opportunity to further integrate our heavy oil production and refining capabilities," said Alex Pourbaix, Cenovus President & Chief Executive Officer. "Operating the refinery will open up additional synergies and capital efficiency opportunities, including connectivity with our nearby Lima Refinery. This transaction solidifies our refining footprint in the U.S. Midwest and increases our ability to capture margin throughout the value chain."

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Suncor Energy Reports Second Quarter 2022 Results

Unless otherwise noted, all financial figures are unaudited, presented in Canadian dollars (Cdn$), and have been prepared in accordance with International Financial Reporting Standards (IFRS), specifically International Accounting Standard (IAS) 34 Interim Financial Reporting as issued by the International Accounting Standards Board. Production volumes are presented on a working-interest basis, before royalties, except for production values from the company's Libya operations, which are presented on an economic basis. Certain financial measures referred to in this news release (adjusted funds from operations, adjusted operating earnings, net debt and free funds flow) are not prescribed by Canadian generally accepted accounting principles (GAAP). See the Non-GAAP Financial Measures section of this news release. References to Oil Sands operations exclude Suncor Energy Inc.'s interest in Fort Hills and Syncrude.

"Driven by a strong business environment, Suncor (TSX: SU) (NYSE: SU) generated record adjusted funds from operations of approximately $5.3 billion, or $3.80 per common share, in the second quarter of 2022, as we executed planned maintenance across our asset base," said Kris Smith, interim president and chief executive officer. "Our confidence in our business and expected annual cash flows enabled us to return approximately $3.2 billion of value to our shareholders, which includes both the highest dividend per share and highest rate of share repurchases in the company's history."

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AltaGas Ltd. ("AltaGas" or the "Company") (TSX: ALA) today announced that it has priced an offering of $250 million of 7.35% Fixed-to-Fixed Rate Subordinated Notes, Series 2 due August 17, 2082 (the " Offering ").

The Offering is expected to close on or about August 17, 2022 . The Company intends to use the net proceeds of the offering to redeem or repurchase its outstanding cumulative redeemable five-year rate reset preferred shares, series C (TSX: ALA.PR.U).

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