INNERGEX RENEWABLE ENERGY INC. RENEWABLE
Innergex Renewable Energy Inc. is a leading Canadian independent renewable power producer. Active since 1990, the Corporation develops, owns, and operates run-of-river hydroelectric facilities, wind farms, and solar photovoltaic farms and carries out its operations in Quebec, Ontario, British Columbia, Idaho, USA, and in France. The Corporation's shares are listed on the Toronto Stock Exchange ("TSX") under the symbols INE, INE.PR.A and INE.PR.C and its convertible debentures under the symbol INE.DB.A.
Innergex's mission is to increase its production of renewable energy by developing and operating high-quality facilities while respecting the environment and balancing the best interests of the host communities, its partners and its investors.
INTRODUCTIONThis Management's Discussion and Analysis ("MD&A") is a discussion of the operating results, cash flows and financial position of Innergex Renewable Energy Inc. ("Innergex" or the "Corporation") for the six-month period ended June 30, 2016, and reflects all material events up to August 4, 2016, the date on which this MD&A was approved by the Corporation's Board of Directors.
The MD&A should be read in conjunction with the unaudited consolidated financial statements and the accompanying notes for the three- and six-month periods ended June 30, 2016, and with the Corporation's Financial Review at December 31, 2015.
The unaudited condensed consolidated financial statements attached to this MD&A and the accompanying notes for the three- and six-month periods ended June 30, 2016, along with the 2015 comparative figures, have been prepared in accordance with International Financial Reporting Standards ("IFRS"). Some amounts included in this MD&A have been rounded to make reading easier, which may affect some calculations.
Q2 & HALF YEAR 2016 HIGHLIGHTSInnergex had a very good start of the year
Production was 115% of the long-term average ("LTA") for the first half of 2016 and 113% of the LTA for Q2
Q2 Revenues increased 25% to $87.8 million and Q2 Adjusted EBITDA rose 25% to $66.9 million compared with 2015
Construction of the Development Projects advanced very well
The Upper Lillooet and Boulder Creek hydroelectric projects are making up time lost to the 2015 forest fire
The commercial operation date ("COD") for the Big Silver Creek project is imminent, notice that all COD requirements have been satisfied was sent to British Columbia Hydro Power and Authority
The Corporation acquired a 87 MW wind farm portfolio in France and entered into an agreement to purchase another 44MW in France in Q1 2017 (the "French Acquisition")
Innergex finalized the investment by the Desjardins Group Pension Plan ("Desjardins") in the French Acquisition portfolio
The gross estimated LTA of the Mesgi'g Ugju's'n wind farm increased by 9%, resulting in an increase of $3.2 million in 2017 Projected Free Cash Flow allocated to Innergex.
The Corporation secured land rights for more than 100 MW of prospective wind farms projects in France
Establishment and Maintenance of DC&P and ICFR ...... Forward-Looking Information ..........................................
Non-IFRS Measures .......................................................
Additional Information and Updates ................................ Overview ........................................................................
Business Strategy ...........................................................
Second quarter update ...................................................
Development Projects ....................................................
Prospective Projects .......................................................
Operating Results ...........................................................
3 Liquidity and Capital Resources 20
3 Dividends 22
6 Outlook for 2017 27
11 Investments in Joint Ventures 34
Non-wholly owned subsidiaries Europe 36
Accounting Changes 39
Subsequent Events 39
ESTABLISHMENT AND MAINTENANCE OF DISCLOSURE CONTROLS AND PROCEDURES AND INTERNAL CONTROL OVER FINANCIAL REPORTINGThe President and Chief Executive Officer and the Chief Financial Officer of the Corporation have designed, or caused to be designed, under their supervision:
Disclosure controls and procedures ("DC&P") to provide reasonable assurance that: (i) material information relating to the Corporation is accumulated and communicated by others to the President and Chief Executive Officer and the Chief Financial Officer in a timely manner, particularly during the period in which the interim and annual filings are being prepared; and (ii) the information required to be disclosed by the Corporation in its annual filings, interim filings and other reports filed or submitted by it under applicable securities legislation is recorded, processed, summarized and reported within the time periods specified in securities legislation.
Internal control over financial reporting ("ICFR") to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with IFRS applicable to the Corporation.
In accordance with Regulation 52-109 - Certification of Disclosure in Issuers' Annual and Interim Filings, the President and Chief Executive Officer and the Chief Financial Officer of the Corporation have certified that : (a) there were no material weaknesses relating to the DC&P and ICFR for the three-month period ended June 30, 2016; (b) they have limited the scope of the Corporation's design of DC&P and ICFR to exclude the controls policies and procedures of Energie Antoigné S.A.S., Energie du Porcien S.A.S, Eoles Beaumont S.A.S., Energie des Cholletz S.A.S., Eoliennes de Longueval S.A.S., Energie Des Valottes S.A.S. et Société d'Exploitation du Parc Éolien du Bois d'Anchat (the "Seven French Entities") and (c) there was no change to the ICFR that has materially affected, or is reasonably likely to materially affect, the Corporation's ICFR during the three-month period ended June 30, 2016. The design and evaluation of the operating effectiveness of the DC&P and ICFR for the Seven French Entities will be completed in the 12 months following the date of acquisition. Summary unaudited financial information about the Seven French Entities is presented in the Innergex Europe L.P. and its Subsidiaries section of this MD&A.
FORWARD-LOOKING INFORMATIONTo inform readers of the Corporation's future prospects, this MD&A contains forward-looking information within the meaning of applicable securities laws ("Forward-Looking Information"). Forward-Looking Information can generally be identified by the use of words such as "approximately", "may", "will", "could", "believes", "expects", "intends", "should", "plans", "potential", "project", "anticipates", "estimates", "scheduled" or "forecasts", or other comparable terminology that state that certain events will or will not occur. It represents the projections and expectations of the Corporation relating to future events or results as of the date of this MD&A.
Future-oriented financial information: Forward-Looking Information includes future-oriented financial information or financial outlook within the meaning of securities laws, such as expected production, projected revenues, projected Adjusted EBITDA , projected Free Cash Flow, estimated project costs and expected project financing, to inform readers of the potential financial impact of expected results, of the expected commissioning of Development Projects, of the potential financial impact of the French Acquisition, of the Corporation's ability to sustain current dividends and dividend increases and of its ability to fund its growth. Such information may not be appropriate for other purposes. Assumptions: Forward-Looking Information is based on certain key assumptions made by the Corporation, including those concerning hydrology, wind regimes and solar irradiation, performance of operating facilities, financial market conditions and the Corporation's success in developing new facilities.Risks and uncertainties: Forward-Looking Information involves risks and uncertainties that may cause actual results or performance to be materially different from those expressed, implied or presented by the Forward-Looking Information. These are referred to in the Corporation's Annual Information Form in the "Risk Factors" section and include, without limitation: the ability of the Corporation to execute its strategy for building shareholder value; its ability to raise additional capital and the state of capital markets; liquidity risks related to derivative financial instruments; variability in hydrology, wind regimes and solar irradiation; delays and cost overruns in the design and construction of projects; health, safety and environmental risks; uncertainties surrounding the development of new facilities; obtainment of permits; variability of installation performance and related penalties; equipment failure or unexpected operations and maintenance activity; interest rate fluctuations and refinancing risk; financial leverage and restrictive covenants governing current and future indebtedness; the possibility that the Corporation may not declare or pay a dividend; the ability to secure new power purchase agreements or to renew any power purchase agreement; changes in governmental support to increase electricity to be generated from renewable sources by independent power producers; the ability to attract new talent or to retain officers or key employees; litigation; performance of major counterparties; social acceptance of renewable energy projects; relationships with stakeholders; equipment supply; changes in general economic conditions; regulatory and political risks; the ability to secure appropriate land; reliance on power purchase
agreements; availability and reliability of transmission systems; increases in water rental cost or changes to regulations applicable to water use; assessment of water, wind and sun resources and associated electricity production; dam failure; natural disasters and force majeure; foreign exchange fluctuations; foreign market growth and development risks; cybersecurity; sufficiency of insurance coverage limits and exclusions; a credit rating that may not reflect actual performance of the Corporation or a lowering (downgrade) of the credit rating; potential undisclosed liabilities associated with acquisitions; integration of the facilities and projects acquired and to be acquired; failure to realize the anticipated benefits of acquisitions, including those of the French Acquisition; reliance on shared transmission and interconnection infrastructure; and the fact that revenues from the Miller Creek facility will vary based on the spot price of electricity.
Although the Corporation believes that the expectations and assumptions on which Forward-Looking Information is based are reasonable under the current circumstances, readers are cautioned not to rely unduly on this Forward-Looking Information as no assurance can be given that it will prove to be correct. Forward-Looking Information contained herein is made as at the date of this MD&A and the Corporation does not undertake any obligation to update or revise any Forward-Looking Information, whether as a result of events or circumstances occurring after the date hereof, unless so required by law.
Forward-Looking Information in this MD&AThe following table outlines the Forward-Looking Information contained in this MD&A, which the Corporation considers important to better inform readers about its potential financial performance, together with the principal assumptions used to derive this information and the principal risks and uncertainties that could cause actual results to differ materially from this information.
Principal Assumptions Principal Risks and Uncertainties | |
Expected production For each facility, the Corporation determines a long-term average annual level of electricity production ("LTA") over the expected life of the facility, based on engineers' studies that take into consideration a number of important factors: for hydroelectricity, the historically observed flows of the river, the operating head, the technology employed and the reserved aesthetic and ecological flows; for wind energy, the historical wind and meteorological conditions and turbine technology; and for solar energy, the historical solar irradiation conditions, panel technology and expected solar panel degradation. Other factors taken into account include, without limitation, site topography, installed capacity, energy losses, operational features and maintenance. Although production will fluctuate from year to year, over an extended period it should approach the estimated long-term average. On a consolidated basis, the Corporation estimates the LTA by adding together the expected LTA of all the facilities in operation that it consolidates (excludes Umbata Falls and Viger-Denonville, which are accounted for using the equity method). | Improper assessment of water, wind and sun resources and associated electricity production Variability in hydrology, wind regimes and solar irradiation Equipment failure or unexpected operations and maintenance activity Natural disaster |
Projected revenues For each facility, expected annual revenues are estimated by multiplying the LTA by a price for electricity stipulated in the power purchase agreement secured with a public utility or other creditworthy counterparty. These agreements stipulate a base price and, in some cases, a price adjustment depending on the month, day and hour of delivery, except for the Miller Creek hydroelectric facility, which receives a price based on a formula using the Platts Mid- C pricing indices, and the Horseshoe Bend hydroelectric facility, for which 85% of the price is fixed and 15% is adjusted annually as determined by the Idaho Public Utility Commission. In most cases, power purchase agreements also contain an annual inflation adjustment based on a portion of the Consumer Price Index. On a consolidated basis, the Corporation estimates annual revenues by adding together the projected revenues of all the facilities in operation that it consolidates (excludes Umbata Falls and Viger-Denonville, which are accounted for using the equity method). | Production levels below the LTA caused mainly by the risks and uncertainties mentioned above Unexpected seasonal variability in the production and delivery of electricity Lower-than-expected inflation rate |
Projected Adjusted EBITDA For each facility, the Corporation estimates annual operating earnings by subtracting from the estimated revenues the budgeted annual operating costs, which consist primarily of operators' salaries, insurance premiums, operations and maintenance expenditures, property taxes and royalties; these are predictable and relatively fixed, varying mainly with inflation (except for maintenance expenditures). On a consolidated basis, the Company estimates annual Adjusted EBITDA by adding together the projected operating earnings of all the facilities in operation that it consolidates (excludes Umbata Falls and Viger-Denonville, which are accounted for using the equity method), from which it subtracts budgeted general and administrative expenses, comprised essentially of salaries and office expenses, and budgeted prospective project expenses, which are determined based on the number of prospective projects the Corporation chooses to develop and the resources required to do so. | Variability of facility performance and related penalties Changes to water and land rental expenses Unexpected maintenance expenditures Changes in the purchase price of electricity upon renewal of a PPA |
Innergex Renewable Energy Inc. published this content on 04 August 2016 and is solely responsible for the information contained herein.
Distributed by Public, unedited and unaltered, on 04 August 2016 15:45:02 UTC.
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