CALGARY, Alberta, July 22, 2019 (GLOBE NEWSWIRE) — PrairieSky Royalty Ltd. (“PrairieSky” or the “Company“) (TSX: PSK) is pleased to announce its second quarter (“Q2 2019“) operating and financial results for the period ended June 30, 2019.
Second Quarter 2019 Highlights:
- Funds from Operations totaled $58.0 million ($0.25 per common share basic and $0.24 per common share diluted), consistent with Q1 2019 funds from operations of $57.8 million ($0.25 per common share basic and diluted).
- Revenues totaled $69.3 million, comprised of royalty production revenues of $63.1 million and other revenues of $6.2 million for the second quarter.
- Royalty production averaged 22,297 BOE per day (51% liquids), up 290 BOE per day from Q1 2019.
- Operating netback of $27.21 per BOE, down from $29.49 per BOE in Q1 2019.
- Dividends declared in the second quarter of $45.6 million ($0.1950 per share), representing a payout ratio of 79%, and common share repurchases of $5.7 million under the normal course issuer bid (“NCIB“).
PrairieSkyâs high margin, low cost royalty structure continued to deliver stable cash flow during Q2 2019 generating $58.0 million which was consistent with Q1 2019 cash flow of $57.8 million. Cash flow was used to pay $45.6 million in dividends, cancel 0.4 million common shares for $5.7 million, with the remaining $6.7 million being used for minor royalty acquisitions and to reduce our working capital deficiency by 66% from March 31, 2019, to $2.1 million as at June 30, 2019.
Spring break-up, a challenging commodity price environment and Alberta production curtailments contributed to lower capital expenditures than in the prior year across Western Canada. Royalty production volumes of 22,297 BOE per day increased by 290 BOE per day from Q1 2019 as total oil and NGL royalty production remained stable and natural gas production increased. Royalty production revenue totaled $63.1 million in the quarter. Average oil royalty production volumes of 8,740 bbls per day, down 164 bbls per day from Q1 2019, generated revenue of $52.1 million, an increase of 13% from Q1 2019 due to stronger average WTI pricing and narrowed average differentials for both light and heavy oil. Average NGL royalty production volumes of 2,690 bbls per day, up 104 bbls per day from Q1 2019, were offset by lower NGL benchmark pricing resulting in $6.5 million of royalty production revenue, a decline of 29% from Q1 2019. Average natural gas production volumes of 65.2 MMcf per day, up 2.1 MMcf per day from Q1 2019, generated $4.5 million of revenue, down 59% from Q1 2019 due to lower benchmark pricing.
Other revenue added $6.2 million of cash flow during the quarter with $1.5 million generated in lease rentals, $0.4 million generated from other income, and $4.3 million generated from bonus consideration. PrairieSky entered into 42 new leasing transactions with 37 different counterparties during the quarter, a substantial increase compared to Q1 2019. Leasing continued to be focused on crude oil targets across Alberta and Saskatchewan.
There were 112 wells (88% oil) spud on PrairieSky lands, down from 168 wells (96% oil) spud in Q2 2018. There were 50 wells spud on Fee Lands (Q2 2018 – 46 wells), 50 wells spud on GORR lands (Q2 2018 – 78 wells) and 12 wells spud on unitized lands (Q2 2018 – 44 wells).
The average net royalty rate of wells spud in the quarter was approximately 9.2%, up from Q1 2019 and Q2 2018 when the average net royalty rate was approximately 6%. This is primarily due to a higher percentage of activity on Fee Lands. Activity levels were focused on the Viking play in both Saskatchewan and Alberta with 75 wells being spud in Q2 2019. In addition, there were 4 Montney oil wells, 3 Duvernay oil wells, 1 Clearwater oil well and 16 other heavy and light oil wells spud in Q2 2019, targeting a number of different plays including the Mannville and Mississippian. There were 13 natural gas wells spud in the quarter, including 9 in the liquids rich Montney in the Pipestone area. After reviewing the budgets of our top drillers, we anticipate that over the next 12 months, close to 10% of drilling activity will be focused on the Clearwater oil play that was acquired less than two years ago.
PrairieSky remains focused on cost control in its business. Cash administrative expenses totaled $2.41 per BOE in the quarter, lower by 37% compared to Q1 2019 and 15% compared to Q2 2018. PrairieSky anticipates cash administrative expenses for the year will be below $3.00 per BOE. PrairieSkyâs staff continued their focus on ensuring timely and accurate royalty payments, collecting compliance recoveries totaling $2.0 million in the quarter bringing year to date compliance recoveries to $3.8 million. During the quarter, the Alberta provincial government announced a reduction of the corporate tax rate to 11% effective July 1, 2019, and further reductions of 1% per year effective January 1, 2020, 2021 and 2022 to bring the rate to 8%. This change reduced the deferred tax liability by $24.4 million and will positively impact future cash flows.
I would like to thank our shareholders for your continued support and our dedicated staff for their continued efforts. Please contact Pam Kazeil, our Chief Financial Officer, at 587-293-4089 or myself at 587-293-4005 with any questions.
Andrew Phillips, President & CEO
FINANCIAL AND OPERATIONAL INFORMATION
The following table summarizes selected operational and financial information of the Company for the periods noted. All dollar amounts are stated in Canadian dollars unless otherwise noted.
A full version of PrairieSkyâs Managementâs Discussion and Analysis (“MD&A“) and unaudited interim condensed financial statements and notes thereto for the fiscal period ended June 30, 2019 is available on SEDAR at www.sedar.com and PrairieSkyâs website at www.prairiesky.com.
|Three months ended June 30,||Six months ended June 30 ,|
|(millions, except per share or as otherwise noted)||2019||2018||2019||2018|
|Funds from Operations||58.0||62.4||115.8||114.2|
|Per Share â basic(1)(2)||0.25||0.27||0.50||0.48|
|Per Share â diluted(1)(2)||0.24||0.26||0.49||0.48|
|Net Earnings and Comprehensive Income||44.0||25.1||70.4||44.9|
|Per Share â basic and diluted(2)||0.19||0.11||0.30||0.19|
|Working Capital (Deficiency) at period end||(2.1||)||21.1||(2.1||)||21.1|
|Shares Outstanding (millions)|
|Shares outstanding at period end||233.5||235.2||233.5||235.2|
|Weighted average â basic||233.7||235.4||233.9||235.5|
|Weighted average â diluted||234.0||235.7||234.1||235.8|
Royalty Production Volumes
|Crude Oil (bbls/d)||8,740||9,098||8,822||8,916|
|Natural Gas (MMcf/d)||65.2||69.4||64.2||71.9|
|Crude Oil ($/bbl)||$||65.48||$||68.92||$||61.60||$||62.80|
|Natural Gas ($/Mcf)||0.74||0.83||1.34||1.22|
|Operating Netback per BOE(1)||$||27.21||$||30.22||$||28.32||$||28.61|
|Funds from Operations per BOE||$||28.59||$||29.89||$||28.87||$||27.16|
|Natural Gas Price Benchmarks|
|AECO monthly index ($/Mcf)||$||1.17||$||1.03||$||1.56||$||1.44|
|AECO daily index ($/Mcf)||$||1.04||$||1.19||$||1.83||$||1.63|
|Foreign Exchange Rate (US$/CAD$)||0.7476||0.7717||0.7505||0.7811|
|Oil Price Benchmarks|
|Edmonton Light Sweet ($/bbl)||$||73.73||$||77.79||$||70.13||$||74.78|
|Western Canadian Select (WCS) crude oil differential to WTI (US$/bbl)||$||(10.67||)||$||(19.27||)||$||(11.48||)||$||(21.77||)|
(1) A non-GAAP measure which is defined under the Non-GAAP Measures section in the MD&A.
(2) Net Earnings and Comprehensive Income and Funds from Operations per Common Share are calculated using the weighted average number of common shares outstanding.
(3) A dividend of $0.065 per common share was declared on June 10, 2019. The dividend was paid on July 15, 2019 to shareholders of record as at June 28, 2019.
(4) See “Conversions of Natural Gas to BOE”.
CONFERENCE CALL DETAILS
A conference call to discuss the results will be held for the investment community on Tuesday, July 23, 2019 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)|
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 our expectations with respect to PrairieSky’s business and growth strategy, anticipated administrative expenses per BOE for 2019, future collections from compliance activities and future activity on PrairieSkyâs lands, including the percentage of total drilling activity in the Clearwater oil play.
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, 2018. 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, 2018 under the headings “Risk Management” and “Risk Factors”, respectively, each of which is available at www.sedar.com and PrairieSkyâs website at www.prairiesky.com.
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.
CONVERSIONS OF NATURAL GAS TO BOE
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 Companyâs liquidity and its ability to generate funds to conduct its business. Non-GAAP measures include operating netback, operating netback per BOE, funds from operations per share – basic and diluted, cash administrative expenses and cash administrative expenses per BOE. Managementâs use of these measures is discussed further below. Further information can be found in the Non-GAAP Measures section of PrairieSkyâs MD&A.
“Operating Netback” represents the cash margin for products sold. Operating netback is calculated as royalty production revenues less production and mineral taxes and administrative expenses. Operating netback provides a consistent measure of the cash generating and operating performance of PrairieSkyâs royalty properties to assess the comparability of the underlying performance between years.
“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 by the average production volumes for the period. Operating netback per BOE is used to assess the cash generating and operating performance per unit of product sold. Operating netback per BOE measures are commonly used in the crude oil and natural gas industry to assess performance comparability.
“Funds from Operations per Share” is calculated on a weighted average basis using basic and diluted common shares outstanding during the period. This measure, together with other measures, are used by the investment community to assess the source, sustainability and cash available for dividends and share repurchases.
“Cash Administrative Expenses” represents administrative expenses excluding the volatility and fluctuations in share-based compensation expense that was 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 plans as described in further detail in PrairieSkyâs MD&A. 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 production volumes for the period. Cash administrative expenses per BOE assists management and investors in evaluating operating performance on a comparable basis.
Funds from operations Per Share Calculations â Basic and Diluted
The following table presents the computation of Funds from Operations per Share:
|Three months ended
|Six months ended
|(millions, except per share data)||2019||2018||2019||2018|
|Funds from Operations||$||58.0||$||62.4||$||115.8||$||114.2|
|Number of Common Shares:|
|Weighted Average Common Shares Outstanding â Basic||233.7||235.4||233.9||235.5|
|Effect of Dilutive Securities||0.3||0.3||0.2||0.3|
|Weighted Average Common Shares Outstanding â Diluted||234.0||235.7||234.1||235.8|
|Funds from Operations per Share â Basic||$||0.25||$||0.27||$||0.50||$||0.48|
|Funds from Operations per Share â Diluted||$||0.24||$||0.26||$||0.49||$||0.48|
Cash Administrative Expenses
The following table presents the computation of Cash Administrative Expenses:
|Three months ended
|Six months ended
|Total Administrative Expenses||$||7.2||$||5.8||$||13.9||$||11.2|
|Share-Based Compensation Recovery (Expense)||(2.3||)||0.1||(3.6||)||0.5|
|Cash Payments made under RSU and PSU Plans(1)||–||–||2.2||5.1|
|Cash Administrative Expenses||$||4.9||$||5.9||$||12.5||$||16.8|
(1) See PrairieSkyâs MD&A for details on its share-based compensation plans.
ABOUT PRAIRIESKY ROYALTY LTD.
PrairieSky is a royalty-focused 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 free cash flow and that represent the largest and most concentrated independently-owned fee simple mineral title position in Canada. PrairieSky’s common shares trade on the Toronto Stock Exchange under the symbol PSK.
FOR FURTHER INFORMATION PLEASE
President & Chief Executive Officer
PrairieSky Royalty Ltd.