ACQUISITIONS AND COMMISSIONING LEADING THE WAY
- Revenues up 30% to $140.8 million in Q3 2018 compared with the same period last year.
- Adjusted EBITDA rose 12% to $91.6 million in Q3 2018 compared with the same period last
year.
- Adjusted EBITDA Proportionate rose 42% to $117.6 million in Q3 2018 compared with the same
period last year.
|
All amounts are in Canadian dollars, except as noted.
|
LONGUEUIL, QC, Nov. 13, 2018 /CNW Telbec/ - Innergex Renewable Energy Inc.
(TSX: INE) ("Innergex" or the "Corporation") today released its operating and financial results for the third quarter and
nine-month period ended September 30, 2018. The improved performance stems mainly from acquisitions and commissioning
carried out over the last two years, softened by production levels below long-term averages.
"We are pleased with the contribution of our recent acquisitions as well as of the progress made at the Upper Lillooet River
and Mesgi'g Ugju's'n facilities. We were able to improve our results compared to last year and to grow our overall production",
said Michel Letellier, President and Chief Executive Officer of Innergex. "Innergex continues its
growth strategy with the acquisition of our partner's interest in the five Cartier wind farms
and operating entities, the acquisition of a potential solar project in Ohio, as well as the
advancement of potential opportunities including the two potential solar projects in Hawai'i. We believe we are in a good
position to continue seizing opportunities that can derive great value for our shareholders."
OPERATING RESULTS
|
|
Amounts shown are in thousands of Canadian dollars except as noted
otherwise.
|
Three months ended
September 30
|
Nine months ended
September 30
|
2018
|
2017
|
2018
|
2017
|
Power generated (MWh)
|
1,556,891
|
1,243,099
|
4,516,559
|
|
3,288,151
|
|
Long-term average (MWh) ("LTA")
|
1,702,028
|
1,374,068
|
4,712,157
|
|
3,631,564
|
|
Revenues
|
140,768
|
108,234
|
408,190
|
|
292,290
|
|
Adjusted EBITDA1
|
91,634
|
81,803
|
270,104
|
|
218,664
|
|
Adjusted EBITDA Proportionate1
|
117,632
|
83,131
|
313,651
|
|
225,139
|
|
Net earnings
|
9,431
|
4,251
|
11,629
|
|
15,748
|
|
Net earnings, $ per share - basic and diluted
|
0.07
|
0.04
|
0.10
|
|
0.17
|
|
|
|
|
|
|
|
|
|
|
|
Trailing twelve months ended
September 30
|
|
|
|
2018
|
2017
|
Free Cash Flow1
|
|
|
97,488
|
|
88,889
|
|
Payout Ratio1
|
|
|
88
|
%
|
80
|
%
|
1
|
Please refer to the Non-IFRS Measures Disclaimer for the definition of
Adjusted EBITDA, Adjusted EBITDA
Proportionate, Free Cash Flow and Payout Ratio.
|
Three-month period ended September 30, 2018
Production increased 25% compared to the same quarter last year. The Corporation's facilities produced
1,556,891 MWh of electricity or 91% of the LTA of 1,702,028 MWh. Overall, the hydroelectric facilities produced 88% of
their LTA, the wind farms produced 91% of their LTA , the geothermal facilities produced 103% of their LTA and the Stardale solar
farm produced 113% of its LTA .
The Corporation recorded revenues of $140.8 million, up 30%, and Adjusted EBITDA of $91.6 million, up 12%, mainly due to the contribution of the facilities acquired in 2018. The Adjusted EBITDA
Margin decreased from 75.6% to 65.1% for the three-month period due mainly to a larger increase in expenses as opposed to the
increase in revenues resulting from the integration of the HS Orka geothermal operations, which generate a lower margin due to
its higher maintenance, daily operating costs and power purchasing costs. The decrease is also attributable to challenging
post-commissioning activities that have now been mostly addressed at the Upper Lillooet River facility. The Adjusted EBITDA
Proportionate reached $117.6 million, up 42%, due mainly to higher Adjusted EBITDA and a higher
Innergex's share of Adjusted EBITDA of joint ventures and associates stemming from the addition of the facilities acquired from
Alterra and Energia Llaima in 2018.
For the three-month period ended September 30, 2018, the Corporation recorded net earnings of $9.4
million (basic and diluted net earnings of $0.07 per share), compared with net earnings of
$4.3 million (basic and diluted net earnings of $0.04 per share) for
the corresponding period in 2017. The $5.2 million increase in net earnings can be explained by the
$14.9 million positive change in the share of earnings of joint ventures and associates, the
$9.8 million increase in Adjusted EBITDA and the $2.4 million
positive change in income taxes, partly offset by the $10.3 million increase in finance costs,
$7.9 million increase in depreciation and amortization, $2.0 million
change in unrealized net loss (gain) on financial instruments and $1.8 million negative change
in other net expenses (revenues).
Nine-month period ended September 30, 2018
Production increased 37% compared to the same period last year. The Corporation's facilities produced
4,516,559 MWh of electricity or 96% of the LTA of 4,712,157 MWh. Overall, the hydroelectric facilities produced 94% of
their LTA , the wind farms produced 95% of their LTA , the geothermal facilities produced 101% of their LTA and the Stardale
solar farm produced 109% of its LTA.
The Corporation recorded revenues of $408.2 million, up 40%, and Adjusted EBITDA of $270.1 million, up 24%, due mainly to the contribution of the geothermal facilities acquired from Alterra in
February 2018, to higher production at the Mesgi'g Ugju's'n and Upper Lillooet River facilities and
to the contribution of Rougemont-2, Plan Fleury and Les Renardières wind facilities commissioned
in 2017. The increase for the nine-month period is also due to the contribution of the wind facilities acquired in France in 2017 and to a revenue compensation received from a manufacturer for low-availability of equipment
at a wind farm. The Adjusted EBITDA Margin decreased from 74.8% to 66.2% for the nine-month period due mainly to the same factors
as for the three-month period. The Adjusted EBITDA Proportionate reached $313.7 million, up
39%, mainly due to the addition of the facilities acquired in 2018.
For the nine-month period ended September 30, 2018, the Corporation recorded net earnings of $11.6 million (basic and diluted net earnings of $0.10 per share), compared
with net earnings of $15.7 million (basic and diluted net earnings of $0.17 per share) for the corresponding period in 2017. The $4.1 million
decrease in net earnings can be explained by the $36.7 million increase in finance costs, the
$27.3 million increase in depreciation and amortization, the $6.2 million negative change in other net expenses (revenues) and the $5.9 million negative change in unrealized net loss (gain) on financial instruments, partly offset by the
$51.4 million increase in Adjusted EBITDA, $14.2 million
positive change in the share of earnings of joint ventures and associates and $6.3 million
positive change in income taxes.
Free Cash Flow and Payout Ratio
For the trailing twelve-month period ended September 30, 2018, the Corporation generated Free Cash Flow of
$97.5 million, compared with $88.9 million for the
corresponding period last year. The increase in Free Cash Flow is due mainly to higher cash flows from operating activities
before changes in non-cash working capital items and transaction costs related to realized acquisitions, partly offset by greater
scheduled debt principal payments, higher Free Cash Flow attributed to non-controlling interests and higher maintenance capital
expenditures net of proceeds from disposals.
For the trailing twelve-month ended September 30, 2018, the dividends on common shares declared by the Corporation
amounted to 88% of Free Cash Flow, compared with 80% for the corresponding period last year. This change results mainly from
higher scheduled debt repayment, higher dividend payments as a result of the issuance of 24,327,225 shares on
February 6, 2018, related to the Alterra acquisition, the increase in the quarterly dividend and to additional shares
following the exercise of stock options and issued under the Dividend Reinvestment Plan ("DRIP"), partly offset by the
acquisition of Alterra and the recent commissioning of the Mesgi'g Ugju's'n, Upper Lillooet River and Boulder Creek facilities
which generated higher Free Cash Flow.
OPERATIONAL HIGHLIGHTS
Acquisition of a solar project in Texas, United States
On July 2, 2018, the Corporation acquired the 250 MWAC/315 MWDC Phoebe photovoltaic solar
project located in Winkler County, Texas. Full notice to proceed with construction was also
issued on July 2, 2018, and commercial operation should be reached in the third quarter of 2019.
The project is expecting a projected Adjusted EBITDA of approximately US$20.2 million ($26.7 million) for 12 months of operation. Following cash distributions to the tax equity investor, the
distributions receivable by Innergex prior to debt service would be approximately US$13.8 million
($18.2 million). The project is also eligible for a U.S. federal Investment Tax Credit (ITC) equal
to approximately 30% of the project's capital costs. The ITC will be allocated mostly to the Tax Equity Investor. After the
seventh year of operation, it is expected that approximately 95% of the projected Adjusted EBITDA, corresponding to about
US$19.6 million ($25.9 million), would be realized.
Partnership and acquisition in Chile
On July 3, 2018, Innergex acquired a 50% ownership in Energia Llaima, which owns
interests in the Guyacán hydro facility (12 MW) and Pampa Elvira solar facility (34 MW),
which should generate projected Adjusted EBITDA of approximately US$6.5 million ($8.5 million). Energia Llaima also owns interest in two hydro facilities in development (125 MW) and
other early development stage projects. Innergex invested an initial US$10 million ($13.2 million) using funds available under its corporate revolving credit facilities and has agreed to invest
an additional US$100 million ($131.5 million) over a 12-month
period, US$90 million of which was invested in the acquisition of the Duqueco hydro
project.
On July 5, 2018, Energia Llaima completed the previously announced acquisition of the 140 MW
Duqueco hydro project in Chile. The Duqueco hydro project includes two hydro facilities
commissioned in 2001, Peuchén (85 MW) and Mampil (55 MW). Innergex expects an Adjusted EBITDA of approximately US$21 million ($27.6 million) annually for the Duqueco project. The purchase
price, net of an estimated US$10 million ($13.2 million) of cash, is
approximately US$210 million ($276.2 million), subject to
certain adjustments.
Acquisition of our partner's interest in the five Cartier wind farms
On August 2, 2018, the Corporation announced that it had signed a final agreement to
acquire TransCanada's 62% interest in five wind farms in Quebec's Gaspé peninsula, known as
Baie-des-Sables, Carleton, Gros-Morne, L'Anse-à-Valleau and
Montagne Sèche (the "Cartier Wind Farms"), and its 50% interest in the operating entities of the Cartier Wind Farms (the "Cartier
Operating Entities"). Innergex already owned the remaining interests in both the Cartier Wind Farms and Cartier Operating
Entities. This acquisition was completed on October 24, 2018, for a total consideration of
approximately $620 million after adjustment for distributions received by TransCanada since
July 1, 2018.
The Cartier Wind Farms are located in the Gaspésie region of Quebec. With an aggregated gross
installed capacity of 590 MW, the expected long-term average annual power generation is approximately 1,780 GWh, enough to
power about 80,900 Quebec households. All the electricity produced by these wind farms is sold
to Hydro-Québec under existing PPAs at fixed prices, a portion of which is adjusted according to inflation indexes, for initial
terms of 20 years, ending between 2026 and 2032.
Innergex expects the 62% acquired interest in the Cartier Wind Farms to generate revenues of approximately $82.9 million and projected Adjusted EBITDA of approximately $68.4 million annually.
Concurrent with the closing of the acquisition, Innergex obtained two short-term credit facilities to cover the purchase price
and transaction costs in their entirety.
Innergex has obtained a $400 million one-year non-recourse credit facility, which the
Corporation intends to repay using the proceeds of a non-recourse long-term project level financing based on the useful life of
the assets. Discussions with long-term lenders are at an advanced stage and the closing of the non-recourse long-term financing
of the projects is expected in the coming months.
Innergex has also obtained a one-year term credit facility of $228 million to be reimbursed
through the strategic divestment of selected assets that would be optimal for the long-term performance and outlook of the
Corporation. Management believes there are a number of attractive, actionable opportunities to monetize selected assets or
portions of existing assets in a manner that supports Innergex's long-term strategy. The Corporation will diligently investigate
these options to derive maximum value from its portfolio of assets. The timing is subject to prevailing market conditions, any
such sales are expected to be completed within a year.
DIVIDEND DECLARATION
The following dividends will be paid by the Corporation on January 15, 2019:
|
|
|
|
|
|
Date of
announcement
|
Record date
|
Payment date
|
Dividend per
common share
|
Dividend per
Series A
Preferred Share
|
Dividend per
Series C
Preferred Share
|
November 13, 2018
|
December 31, 2018
|
January 15, 2019
|
$0.1700
|
$0.2255
|
$0.359375
|
ADDITIONAL INFORMATION
Innergex's third quarter of 2018 unaudited condensed consolidated interim financial statements, the notes thereto and
the Management's Discussion and Analysis can be obtained on SEDAR at www.sedar.com and in the "Investors" section of the Corporation's website at www.innergex.com.
CONFERENCE CALL
The Corporation will hold a conference call on Wednesday November 14, 2018, at
9 AM (EST). Investors and financial analysts are invited to access the conference call by dialing
1 888 231-8191 or 647 427-7450. Journalists as well as the public may access this conference call via a listen
mode only. A replay of the conference call will be available after the event on the Corporation's website.
About Innergex Renewable Energy Inc.
The Corporation is an independent renewable power producer which develops, acquires, owns and operates hydroelectric
facilities, wind farms, solar farms and geothermal power generation plants. As a global corporation, Innergex conducts operations
in Canada, the United States, France, Chile and Iceland. Innergex
manages a large portfolio of assets currently consisting of interests in 68 operating facilities with an aggregate net installed
capacity of 2,091 MW (gross 3,072 MW), including 37 hydroelectric facilities, 25 wind farms, four solar farms and two
geothermal facilities. Innergex also holds interests in five projects under development with a net installed capacity of 719 MW
(gross 800 MW), two of which are currently under construction and prospective projects at different stages of development
with an aggregate net capacity totaling 8,382 MW (gross 9,246 MW). Respecting the environment and balancing the best interests of
the host communities, its partners, and its investors are at the heart of the Corporation's development strategy. Its approach
for building shareholder value is to generate sustainable cash flows, provide an attractive risk-adjusted return on invested
capital and to distribute a stable dividend. Innergex Renewable Energy Inc. is rated BBB- by S&P.
Non-IFRS measures disclaimer
The unaudited condensed consolidated interim financial statements for the three- and nine-month period ended
September 30, 2018, have been prepared in accordance with International Financial Reporting Standards ("IFRS"). However,
some measures referred to in this press release are not recognized measures under IFRS and therefore may not be comparable to
those presented by other issuers. Innergex believes that these indicators are important, as they provide management and the
reader with additional information about the Corporation's production and cash generation capabilities, its ability to sustain
current dividends and dividend increases and its ability to fund its growth. These indicators also facilitate the comparison of
results over different periods. Adjusted EBITDA, Adjusted EBITDA Margin, Adjusted EBITDA Proportionate, Free Cash Flow and Payout
Ratio are not measures recognized by IFRS and have no standardized meaning prescribed by IFRS.
References in this document to "Adjusted EBITDA" are to revenues less operating expenses, general and administrative expenses
and prospective project expenses. Innergex believes that the presentation of this measure enhances the understanding of the
Corporation's operating performance. Readers are cautioned that Adjusted EBITDA should not be construed as an alternative to net
earnings, as determined in accordance with IFRS.
References in this document to "Adjusted EBITDA Margin" are to Adjusted EBITDA divided by revenues. Innergex believes that the
presentation of this measure enhances the understanding of the Corporation's operating performance.
References in this document to "Innergex's share of Adjusted EBITDA of the joint ventures and associates" are to Innergex's
ownership interest in the equity or in the sponsors' equity when applicable of the Adjusted EBITDA of the joint ventures and
associates.
References in this document to "Adjusted EBITDA Proportionate" are to Adjusted EBITDA plus Innergex's share of Adjusted EBITDA
of the joint ventures and associates. Innergex believes that the presentation of this measure enhances the understanding of the
Corporation's operating performance. Readers are cautioned that Adjusted EBITDA Proportionate should not be construed as an
alternative to net earnings, as determined in accordance with IFRS.
References to "Free Cash Flow" are to cash flows from operating activities before changes in non-cash operating working
capital items, less maintenance capital expenditures net of proceeds from disposals, scheduled debt principal payments, preferred
share dividends declared and the portion of Free Cash Flow attributed to non-controlling interests, plus or minus other elements
that are not representative of the Corporation's long-term cash generating capacity, such as transaction costs related to
realized acquisitions (which are financed at the time of the acquisition), realized losses or gains on derivative financial
instruments used to hedge the interest rate on project-level debt or the exchange rate on equipment purchases. Innergex believes
that presentation of this measure enhances the understanding of the Corporation's cash generation capabilities, its ability to
sustain current dividends and dividend increases and its ability to fund its growth. Readers are cautioned that Free Cash Flow
should not be construed as an alternative to cash flows from operating activities, as determined in accordance with IFRS.
References to "Payout Ratio" are to dividends declared on common shares divided by Free Cash Flow. Innergex believes that this
is a measure of its ability to sustain current dividends and dividend increases as well as its ability to fund its growth.
Forward-Looking Information
To inform readers of the Corporation's future prospects, this press release 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",
"would", "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 press release.
Forward-Looking Information includes future-oriented financial information or financial outlook within the meaning of
securities laws, such as expected production and projected Adjusted EBITDA, 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
acquisitions, of the Corporation's ability to sustain current dividends and of its ability to fund its growth. Such information
may not be appropriate for other purposes.
Forward-looking statements are based on certain key expectations and assumptions made by Innergex, including expectations and
assumptions concerning availability of capital resources; economic and financial conditions; project performance and the timing
of receipt of the requisite shareholder, court, regulatory and other third-party approvals. Although Innergex believes that the
expectations and assumptions on which such forward-looking statements are based are reasonable, undue reliance should not be
placed on the forward-looking statements because Innergex can give no assurance that they will prove to be correct.
Since forward-looking statements address future events and conditions, they are by their very nature subject to inherent risks
and uncertainties. Actual results could differ materially from those currently anticipated due to a number of factors and risks.
These include, but are not limited to, the risks associated with the renewable energy industry in general such as execution of
strategy; ability to develop Innergex's projects on time and within budget; capital resources; derivative financial instruments;
current economic and financial conditions; hydrology and wind regimes; geothermal resources and solar irradiation; construction,
design and development of new facilities; performance of existing projects; equipment failure; interest rate and refinancing
risk; currency exchange rates, variation in merchant price of electricity, financial leverage and restrictive covenants; and
relationships with public utilities.
There are also risks inherent to the acquisition of TransCanada's stake in the five Cartier
wind farms, including incorrect assessments of the value of the entity and our ability to secure non-recourse long term project
level financing (including the timing and amount thereof). There can also be no assurance that the strategic, operational or
financial benefits expected to result from the Transaction will be realized. In addition, the potential divestiture of selected
assets are also subject to inherent risks and uncertainties including the outcomes of Innergex's exploration to find interested
purchaser(s) and partner(s), the ability to correctly assess the value of the assets, the consummation and timing of any such
transaction(s) and the terms of such transaction(s), if any, and if consummated, the ability of Innergex to realize the expected
benefits of such transaction(s).
Forward-Looking Information in this press release is based on certain key expectations and assumptions made by the
Corporation. The following table outlines Forward-Looking Information contained in this press release, 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; for solar energy, the historical solar irradiation conditions,
panel technology and expected solar panel degradation; and for geothermal power, the historical geothermal resources,
natural depletion of geothermal resources over time, the technology used and the potential of energy loss to occur before
delivery. 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 Dokie, East Toba, Flat
Top, Guyacán, Jimmie Creek, Kokomo, Mampil, Montrose Creek, Pampa Elvira, Peuchén, Shannon, Spartan, Umbata Falls and
Viger-Denonville, which are accounted for using the equity method).
|
Improper assessment of water, wind, sun and geothermal resources and
associated electricity production
Variability in hydrology, wind regimes, solar irradiation and geothermal
resources
Natural depletion of geothermal resources
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 PPA secured with a public utility or other creditworthy counterparty
mainly. These PPAs 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, 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. Revenues at the HS Orka facilities also fluctuates with
the price of aluminum, as certain of those PPAs are linked to such price. 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 Dokie, East Toba, Flat Top, Guyacán, Jimmie Creek, Kokomo, Mampil, Montrose Creek, Pampa
Elvira, Peuchén, Shannon, Spartan, 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
Changes in the purchase price of electricity upon renewal of a
PPA
|
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, royalties and cost of power (if
applicable); these are predictable and relatively fixed, varying mainly with inflation (except for maintenance
expenditures and cost of power). 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 Dokie, East Toba, Flat
Top, Guyacán, Jimmie Creek, Kokomo, Mampil, Montrose Creek, Pampa Elvira, Peuchén, Shannon, Spartan, 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.
|
Lower revenues caused mainly by the risks and uncertainties mentioned
above
Variability of facility performance and related penalties
Unexpected maintenance expenditures
|
Estimated project costs, expected obtainment of permits, start of
construction, work conducted and start of commercial operation for Development Projects or Prospective
Projects
For each development project, the Corporation provides an estimate of
project costs based on its extensive experience as a developer, directly related incremental internal costs, site
acquisition costs and financing costs, which are eventually adjusted for the projected costs provided by the engineering,
procurement and construction ("EPC") contractor retained for the project.
The Corporation provides indications regarding scheduling and construction
progress for its Development Projects and indications regarding its Prospective Projects, based on its extensive
experience as a developer.
|
Performance of counterparties, such as the EPC contractors
Delays and cost overruns in the design and construction of
projects
Obtainment of permits
Equipment supply
Interest rate fluctuations and financing risk
Relationships with stakeholders
Regulatory and political risks
Higher-than-expected inflation
Natural disaster
Outcome of insurance claims
|
Intention to submit projects under requests for proposals
The Corporation provides indications of its intention to submit projects
under requests for proposals based on the state of readiness of some of its Prospective Projects and their compatibility
with the announced terms of these requests for proposals.
|
Regulatory and political risks
Ability of the Corporation to execute its strategy for building shareholder
value
Ability to secure new PPAs
|
Qualification for PTCs and ITC
For certain Development Projects in the United States, the Corporation has
conducted on and off-site activities expected to qualify its Development Projects for PTCs or ITC at the full rate and to
obtain tax equity financing on such basis. To assess the potential qualification of a project, the Corporation takes into
account the construction work performed and the timing of such work.
|
Risks related to U.S. Production Tax Credit, Investment Tax Credit, changes
in U.S. Corporate Tax
Risks related to the project qualification to be eligible to PTCs and
ITC
Rates and availability of Tax Equity Financing
Regulatory and political risks
Delays and cost overruns in the design and construction of
projects
Obtainment of permits
|
Expected closing of the non-recourse project financing
That the Corporation is able to successfully secure, on the timeline and in
the amount expected, project level non-recourse financing to support the acquisition of the Cartier Wind Farms. That the
value of such acquired assets is sufficient to support such financing.
|
Availability of the capital
Regulatory and political risks
Market conditions, and other risks inherent in project financing
Assessment of the value of the acquired assets, and performance
thereof
Performance of counterparties
|
Potential divestiture of selected assets
The Corporation ability to successfully identify potential purchases,
assess and realize the value of such assess in a successful divestiture, and the timing thereof. That the Corporation's
strategy of divesting certain assets successfully advances the Corporation's long-term strategy and enhances the
Corporation's value.
|
Accurate assessment of the value of any divested assets and of the value
Innergex will receive in return
That the Corporation's long-term strategy improves the Corporation's
value
That the divestiture of assets closing within a timeframe that allows the
Corporation to use such divestiture to support the acquisition of the Cartier Wind Farms.
Market conditions, and other risk inherent in closing of such
transactions
Regulatory and political risks
Performance of counterparties
|
Although the Corporation believes that the expectations and assumptions on which Forward-Looking Information is based are
reasonable, readers of this press release are cautioned not to rely unduly on this Forward-Looking Information since no assurance
can be given that they will prove to be correct. The forward-looking statements contained in this press release are made as of
the date hereof and Innergex undertakes no obligation to publicly update or revise any forward-looking statements, whether as a
result of new information, future events or otherwise, unless so required by applicable securities laws.
SOURCE Innergex Renewable Energy Inc.
View original content: http://www.newswire.ca/en/releases/archive/November2018/13/c1798.html