BOSTON, MASSACHUSETTS – Atlantic Power Corporation (NYSE: AT) (TSX: ATP) (“Atlantic Power” or the “Company”) today announced its results for the quarter and year ended December 31, 2010. All amounts are in U.S. dollars unless otherwise indicated. Please see “Regulation G Disclosures” attached to this news release for an explanation and US GAAP reconciliation of the terms “EBITDA”, “Adjusted EBITDA” and “Cash Available for Distribution” as used in this news release.
Highlights
- 6% increase in Adjusted EBITDA in 2010 compared to the prior year
- $83 million of distributions from our projects exceeded 2010 guidance
- Maintaining our guidance that projected cash flows are sufficient to meet our current level of dividends into 2016 with no further acquisitions or organic growth
- Completed NYSE listing and subsequently raised $150 million in successful equity and convertible debenture offerings
- Completed project-level bank financing and commenced construction on our first greenfield biomass project to be completed in late 2012
- Construction completed in early 2011 on our first wind project investment
- Acquired Cadillac Renewable Energy, a 39.6 MW biomass facility in Cadillac, Michigan
“This year we had some significant milestones for the continued growth of Atlantic Power,” said Barry Welch, Atlantic Power’s President and CEO. “Our NYSE listing increased the liquidity of our shares as well as our access to capital in the United States, which we leveraged with a cross border public offering in the U.S. and Canada. The proceeds from that offering supported the diversification of our portfolio into the renewable space with the acquisition of Cadillac, the completed construction of Idaho Wind and the groundbreaking at Piedmont Green Power. With the one-year extension of the federal stimulus grant for renewable projects, we are excited about the prospects of additional opportunities in the wind and biomass space.”
Operating Performance
Project Adjusted EBITDA, including earnings from equity investments, increased by $0.7 million to $33.8 million for the quarter ended December 31, 2010 compared to $33.1 million for the quarter ended December 31, 2009. The increase was attributable to several factors, including:
- increased EBITDA of $2.9 million at Lake due to lower fuel expense attributable to lower price and volume of hedged gas;
- increased EBITDA of $0.7 million at Pasco primarily attributable to the maintenance outage during the fourth quarter of 2009; and
- decreased EBITDA of $2.6 million at Auburndale due primarily to higher maintenance costs and longer scheduled down-time during a planned fourth quarter 2010 outage.
Project Adjusted EBITDA, including earnings from equity investments, increased by $8.4 million to $152.6 million for the year ended December 31, 2010 compared to $144.2 million for the year ended December 31, 2009. The increase was attributable to several factors, including:
- increased EBITDA of $6.1 million at Lake due to earnings from favorable off-peak dispatch during the summer months and annually increased contractual capacity payments under the project’s PPA;
- increased EBITDA of $5.7 million at Chambers due to lower operations and maintenance costs in 2010 as compared to 2009 which had a planned major steam turbine generator outage, as well as higher generation due to better market prices;
- increased EBITDA of $1.4 million at Pasco primarily attributable to the maintenance outage during the year ended December 31, 2009; partially offset by
- decreased EBITDA of $1.0 million at Auburndale due to higher maintenance costs in 2010 and longer scheduled down-time during a planned outage, partially offset by higher contractual capacity payments under the project's PPA;
- the absence of Rumford EBITDA as the project was sold in the fourth quarter of 2010; and
- the absence of Stockton and Mid-Georgia’s EBITDA as both projects were sold in the fourth quarter of 2009.
Cash Available for Distribution
For the year ended December 31, 2010, Cash Available for Distribution was $65.5 million compared to $66.3 million for the year ended December 31, 2009.
Our payout ratio for 2010 was 100%, which was in line with our expectations and previous guidance.
From an overall cash flow perspective, cash flow from operating activities increased by $36.5 million for the year ended December 31, 2010 over the comparable period in 2009. The change from the prior year is primarily attributable to a significant decrease in cash interest expense as a result of our common share conversion in November of 2009, which eliminated Cdn$348 million ($328 million) of outstanding subordinated notes, as well as higher Project Adjusted EBITDA described above and $8 million in net cash tax refunds.
Growth in 2010
Idaho Wind Commercially Operational
On July 2, 2010, we acquired a 27.6% interest in Idaho Wind Partners (“Idaho Wind”) for $38.9 million and approximately $3.1 million in transaction costs. In early 2011, Idaho Wind completed construction of its 183-MW wind power project located near Twin Falls, Idaho. The project’s 11 wind farms are powered by 122 of GE Energy’s 1.5 MW wind turbines, the most widely installed turbine in the world. Construction was completed and delivered on schedule by Fagen Inc. a leading engineering, procurement and construction firm. Idaho Wind has 20-year power purchase agreements with Idaho Power Company under which all electricity produced by the wind farms will be sold at fixed prices as scheduled in the projects’ PPAs.
Idaho Wind was funded, in conjunction with our partners, with a $221.7 million project-level credit facility. The facility is composed of two tranches, which includes a $138.5 million construction loan that will convert to a 17-year term loan following commercial operation and a $83.2 million cash grant bridge facility which will be repaid with federal stimulus grant proceeds expected in the second quarter of 2011.
In 2010, we made a short-term $22.8 million loan to Idaho Wind to provide temporary funding for construction of the project until a portion of the project-level construction financing is completed. The loan is expected to be repaid in 2011 with a combination of excess proceeds from the federal stimulus cash grant after repaying the cash grant loan facility, funds from a third closing for additional project debt, and project cash flow. The federal stimulus grant is expected in the second quarter of 2011 and a third closing is expected by the end of the year. As of March 18, 2011, $5.1 million of the loan has been repaid to us. The outstanding loan bears interest at a prime rate plus 10% (13.25% as of December 31, 2010).
Cadillac Renewable Energy Acquisition
On December 21, 2010, we acquired 100% of Cadillac Renewable Energy, LLC (“Cadillac”), which owns and operates a 39.6 MW wood fired facility located in Cadillac, Michigan.
The purchase price was $80.1 million, inclusive of customary working capital adjustments, and was funded by $37 million of cash on hand and $43.1 million of assumed non-recourse, project-level debt, which fully amortizes through the term of the power purchase agreement (“PPA”). Operations and maintenance will be managed by Rollcast Energy, Atlantic Power’s majority-owned affiliate. The Company expects to receive distributions from the project in the range of $3.5 million to $4.5 million per year, starting in 2011.
Piedmont Green Power Financing and Groundbreaking
In November 2010, we closed the construction and term financing for the Piedmont Green Power project, a 53.5 MW biomass project located in Barnesville, Georgia. Total project costs of approximately $207.4 million were financed in part with an $82.0 million construction loan which will convert to a term loan upon commercial operation, a $51.0 million bridge loan and approximately $75 million of equity to be contributed by Atlantic Power. The bridge loan will be repaid from the proceeds of a federal grant, which is expected to be received two months after achieving commercial operation. Construction of the project, headed by Zachry Industrial, commenced immediately following the financial closing. Piedmont has a 20-year PPA with Georgia Power Company which includes fixed capacity payments and variable energy payments with an adjustment related to the cost of biomass fuel for the plant. As of March 18, 2011 we have contributed $68.5 million in equity to the project. Cash distributions to the Company from the project are expected to average $8 million to $10 million for each full year of project operation after completion of construction in late 2012.
Expanded shareholder access and first cross-border capital raise
NYSE Listing
On July 23, 2010, our shares commenced trading on the NYSE, bringing many benefits including enhanced trading liquidity, increased shareholder access to our securities and additional access to competitively-priced public capital to finance our growth strategies.
Public Offerings
On October 20, 2010, we completed a public offering of 6,029,000 common shares, including 784,000 common shares issued pursuant to the exercise in full of the underwriters' over-allotment option, at a price of $13.35 per common share. We received net proceeds from the common share offering, after deducting the underwriting discounts and expenses, of approximately $75.3 million.
On October 20, 2010, we also completed a public offering of Cdn$80.5 million ($78.9 million) of convertible unsecured subordinated debentures, including Cdn$10.5 million ($10.3 million) aggregate principal amount of debentures pursuant to the exercise in full of the underwriters' over-allotment option. The debentures bear interest at a rate of 5.60% and will mature on June 30, 2017 unless earlier redeemed. We received net proceeds from the debenture offering, after deducting the underwriting discounts and expenses, of approximately Cdn$76.1 million ($74.6 million).
As of March 18, 2011, the net proceeds of approximately $150 million from the two public offerings had been used as follows:
- $20 million to partially fund the acquisition of Idaho Wind;
- $68.5 million to fund our equity contribution to the Piedmont Green Power biomass project, with an additional $6.5 million allocated for additional equity contributions;
- $37 million to fund our acquisition of Cadillac Renewable Energy, LLC; and
- The remaining net proceeds of approximately $18 million have been retained for general corporate purposes and continued execution of our growth strategy.
As of March 18, 2011, we had outstanding 68,108,042 common shares (NYSE: AT; TSX: ATP), Cdn$49.6 million principal amount of 6.50% convertible secured debentures due October 31, 2014 (TSX: ATP.DB), Cdn$76.7 million principal amount of 6.25% convertible debentures due March 15, 2017 (TSX: ATP.DB.A) and Cdn$80.5 million principal amount of 5.60% convertible debentures due June 30, 2017 (TSX: ATP.DB.B).
Recent Developments
Impairment of Topsham and Badger Creek/Topsham PSA
During the three months ended December 31, 2010, we reviewed the recoverability of our 50.0% equity investments in the Topsham and Badger Creek projects. These two projects combined have historically represented approximately 3% of our Project Adjusted EBITDA.
The review at Topsham was undertaken as a result of sale negotiations relating to our lessor interest in the project. At Badger Creek, the review was undertaken as a result of the project’s recent discussions with utilities in California, the current status of the regulatory proceedings related to contract pricing for qualified facilities in California and recent comparable market transactions in the region.
Based on these reviews we determined that the carrying value of the Topsham and Badger Creek projects were impaired and recorded a pre-tax long-lived asset impairment of $2.0 million and $1.2 million, respectively, during the fourth quarter of 2010. The Topsham and Badger Creek projects are accounted for under the equity method of accounting and the impairment charges are included in equity in earnings of unconsolidated affiliates in the consolidated statements of operations.
On February 28, 2011, we entered into a purchase and sale agreement with a third party for the purchase of our lessor interest in Topsham. Closing of the transaction is expected to occur in the second quarter of 2011.
Guidance
Based on actual performance to date and projections for the remainder of the year, we expect to receive distributions from our projects in the range of $80 million to $90 million for the full year 2011 compared to $83 million in 2010. We expect overall levels of operating cash flows in 2011 to be improved over actual 2010 levels. Higher distributions from existing projects, initial distributions from our recent investments in Idaho Wind and Cadillac, and a slightly lower payment under the management termination agreement are expected to be partially offset by the non-recurrence of the cash tax refunds in 2010. These increased cash flows in 2011, combined with the impact of our recent public offering, are expected to result in a payout ratio of approximately 100% to 105% in 2011. In 2012, additional increases in distributions from projects are expected to further increase operating cash flow compared to 2011. The most significant factor in the expected higher operating cash flow in 2012 is increased distributions from Selkirk following the final payment of its non-recourse project level debt in 2012.
Based on management’s cash flow projections, we believe the current level of dividends is sustainable into 2016 before considering any positive impact from potential future acquisitions or organic growth opportunities.
The calculation of Cash Available for Distribution and a summary of Adjusted EBITDA by individual project for the quarter and year ended December 31, 2010 are attached to this news release.
Investor Conference Call and Webcast
A telephone conference call hosted by Atlantic Power's management team will be held on Monday, March 21, 2011 at 10:00 AM ET. The telephone numbers for the conference call are: Local/International: (416) 849-2698, North American Toll Free: (866) 400-2270. The Conference Call will also be broadcast over Atlantic Power's website at www.atlanticpower.com. Please call or log in 10 minutes prior to the call. The telephone numbers to listen to the conference call after it is completed (Instant Replay) are Local/International: (416) 915-1035, North American Toll Free (866) 245-6755. Please enter the passcode 48946# when instructed. The conference call will also be archived on Atlantic Power's web site.
About Atlantic Power
Atlantic Power Corporation owns and operates a diverse fleet of power generation and infrastructure assets in the United States. Our power generation projects sell electricity to utilities and other large commercial customers under long-term power purchase agreements, which seek to minimize exposure to changes in commodity prices. Our power generation projects in operation have an aggregate gross electric generation capacity of approximately 1,962 megawatts in which our ownership interest is approximately 878 MW. Our corporate strategy is to generate stable cash flows from our existing assets and to make accretive acquisitions to sustain our dividend payout to shareholders, which is currently paid monthly at an annual rate of Cdn$1.094 per share. Our current portfolio consists of interests in 13 operational power generation projects across ten states, one biomass project under construction in Georgia, and a 500 kilovolt 84-mile electric transmission line located in California. Atlantic Power also owns a majority interest in Rollcast Energy, a biomass power plant developer with several projects under development.
Atlantic Power trades on the New York Stock Exchange under the symbol AT, on the Toronto Stock Exchange under the symbol ATP and has a market capitalization of approximately $1.0 billion. For more information, please visit the Company’s website at www.atlanticpower.com or contact:
Atlantic Power Corporation
Patrick Welch, Chief Financial Officer
(617) 977-2700
info@atlanticpower.com
Forward-looking Statements
Certain statements in this news release may constitute “forward-looking statements”, which reflect the expectations of management regarding the future growth, results of operations, performance and business prospects and opportunities of our Company and our projects. These statements, which are based on certain assumptions and describe our future plans, strategies and expectations, can generally be identified by the use of the words "may," "will," "project," "continue," "believe," "intend," "anticipate," "expect" or similar expressions that are predictions of or indicate future events or trends and which do not relate solely to present or historical matters. Examples of such statements in this press release include, but are not limited, to statements with respect to the following:
- The belief that, based on management’s cash flow projections, the current level of dividends is sustainable into 2016 without additional acquisitions or organic growth opportunities;
- The expectation that distributions from our projects will be in the range of $80 million to $90 million for the full year 2011;
- The expectation that overall levels of operating cash flows in 2011 will be improved over actual 2010 levels;
- The expectation that the payout ratio in 2011 will be approximately 100%-105% and that improvements in cash flow and payout ratio are expected in 2012;
- The expectation that we will receive distributions from Cadillac in the range of $3.5 million to $4.5 million per year beginning in 2011;
- The expectation that cash distributions from Piedmont are expected to average $8 million to $10 million for each full year of project operation;
- The expectation that the total project costs for Piedmont will be $207.4 million; and
- The expectation that Piedmont will complete construction in late 2012.
Forward-looking statements involve significant risks and uncertainties, should not be read as guarantees of future performance or results, and will not necessarily be accurate indications of whether or not or the times at or by which such performance or results will be achieved. Please refer to the factors discussed under "Risk Factors" in the Company's periodic reports as filed with the Securities and Exchange Commission from time to time for a detailed discussion of the risks and uncertainties affecting our Company. Although the forward-looking statements contained in this news release are based upon what are believed to be reasonable assumptions, investors cannot be assured that actual results will be consistent with these forward-looking statements, and the differences may be material. These forward-looking statements are made as of the date of this news release and, except as expressly required by applicable law, the Company assumes no obligation to update or revise them to reflect new events or circumstances. The financial outlook information contained in this news release is presented to provide readers with guidance on the cash distributions expected to be received by the Company and to give readers a better understanding of the Company’s ability to pay its current level of distributions into the future. Readers are cautioned that such information may not be appropriate for other purposes.
Atlantic Power Corporation
Consolidated Balance Sheets (in thousands of U.S. dollars)
| Cash and cash equivalents | $ 45,497 | $ 49,850 | |
| Restricted cash | 15,744 | 14,859 | |
| Accounts receivable | 19,362 | 17,480 | |
| Note receivable - related party (Note 17) | 22,781 | - | |
| Current portion of derivative instruments asset (Notes 11 and 12) | 8,865 | 5,619 | |
| Prepayments, supplies, and other | 4,889 | 3,019 | |
| Deferred income taxes (Note 13) | - | 17,887 | |
| Refundable income taxes (Note 13) | 1,593 | 10,552 | |
| Total current assets | 118,731 | 119,266 | |
| Property, plant, and equipment, net (Note 5) | 275,421 | 193,822 | |
| Transmission system rights (Note 6) | 188,134 | 195,984 | |
| Equity investments in unconsolidated affiliates (Note 4) | 294,805 | 259,230 | |
| Other intangible assets, net (Note 6) | 88,462 | 71,770 | |
| Goodwill (Note 3) | 12,453 | 8,918 | |
| Derivative instruments asset (Notes 11 and 12) | 17,884 | 14,289 | |
| Other assets | 17,122 | 6,297 | |
| Total assets | $ 1,013,012 | $ 869,576 | |
| Liabilities | |||
| Current Liabilities: | |||
| Accounts payable and accrued liabilities | $ 20,530 | $ 21,661 | |
| Current portion of long-term debt (Note 8) | 21,587 | 18,280 | |
| Current portion of derivative instruments liability (Notes 11 and 12) | 10,009 | 6,512 | |
| Interest payable on convertible debentures (Note 10) | 3,078 | 800 | |
| Dividends payable | 6,154 | 5,242 | |
| Other current liabilities | 5 | 752 | |
| Total current liabilities | 61,363 | 53,247 | |
| Long-term debt (Note 8) | 244,299 | 224,081 | |
| Convertible debentures (Note 10) | 220,616 | 139,153 | |
| Derivative instruments liability (Notes 11 and 12) | 21,543 | 5,513 | |
| Deferred income taxes (Note 13) | 29,439 | 28,619 | |
| Other non-current liabilities | 2,376 | 4,846 | |
| Commitments and contingencies (Note 19) | |||
| Equity | |||
| Common shares, no par value, unlimited authorized shares; 67,118,154 and 60,404,093 issued and outstanding at December 31, 2010 and 2009, respectively | 626,108 | 541,917 | |
| Accumulated other comprehensive loss (Note 12) | 255 | (859) | |
| Retained deficit | (196,494) | (126,941) | |
| Total Atlantic Power Corporation shareholders' equity | 429,869 | 414,117 | |
| Noncontrolling interest (Note 3) | 3,507 | - | |
| Total equity | 433,376 | 414,117 | |
| Total liabilities and equity | $ 1,013,012 | $ 869,576 |
Atlantic Power Corporation
Consolidated Statements of Operations (in thousands of U.S. dollars)
| Years ended December 31, | |||||
| 2010 | 2009 | 2008 | |||
| Project revenue: | |||||
| Energy sales | $ 69,116 | $ 58,953 | $ 64,237 | ||
| Energy capacity revenue | 93,567 | 88,449 | 77,691 | ||
| Transmission services | 31,000 | 31,000 | 31,528 | ||
| Other | 1,573 | 1,115 | 356 | ||
| 195,256 | 179,517 | 173,812 | |||
| Project expenses: | |||||
| Fuel | 65,553 | 59,522 | 55,366 | ||
| Operations and maintenance | 26,506 | 24,038 | 17,711 | ||
| Project operator fees and expenses | 4,731 | 4,115 | 3,727 | ||
| Depreciation and amortization | 40,387 | 41,374 | 29,528 | ||
| 137,177 | 129,049 | 106,332 | |||
| Project other income (expense): | |||||
| Change in fair value of derivative instruments (Notes 11 and 12) | (14,047) | (6,813) | (16,026) | ||
| Equity in earnings of unconsolidated affiliates (Note 4) | 15,348 | 8,514 | 1,895 | ||
| Gain on sales of equity investments, net (Note 3) | 1,511 | 13,780 | - | ||
| Interest expense, net | (17,660) | (18,800) | (17,709) | ||
| Other income, net | 219 | 1,266 | 5,366 | ||
| (14,629) | (2,053) | (26,474) | |||
| Project income | 43,450 | 48,415 | 41,006 | ||
| Administrative and other expenses (income): | |||||
| Management fees and administration | 16,149 | 26,028 | 10,012 | ||
| Interest, net | 11,701 | 55,698 | 43,275 | ||
| Foreign exchange (gain) loss (Note 12) | (1,014) | 20,506 | (47,247) | ||
| Other (income) expense, net | (26) | 362 | 425 | ||
| 26,810 | 102,594 | 6,465 | |||
| Income (loss) from operations before income taxes | 16,640 | (54,179) | 34,541 | ||
| Income tax expense (benefit) (Note 13) | 18,924 | (15,693) | (13,560) | ||
| Net income (loss) | (2,284) | (38,486) | 48,101 | ||
| Net loss attributable to noncontrolling interest | (103) | - | - | ||
| Net income (loss) attributable to Atlantic Power Corporation | $ (2,181) | $ (38,486) | $ 48,101 | ||
| Net income (loss) per share attributable to Atlantic Power Corporation | |||||
| shareholders: (Note 15) | |||||
| Basic | $ (0.04) | $ (0.63) | $ 0.78 | ||
| Diluted | $ (0.04) | $ (0.63) | $ 0.73 | ||
Atlantic Power Corporation
Consolidated Statements of Cash Flows (in thousands of U.S. dollars)
| Years ended December 31, | |||||
| 2010 | 2009 | 2008 | |||
| Cash flows from operating activities: | |||||
| Net loss | $ (2,284) | $ (38,486) | $ 48,101 | ||
| Adjustments to reconcile to net cash provided by operating activities: | |||||
| Depreciation and amortization | 40,387 | 41,374 | 29,528 | ||
| Common share conversions recorded in interest expense | - | 4,508 | - | ||
| Subordinated note redemption premium recorded in interest expense | - | 1,935 | - | ||
| Long-term incentive plan expense | 4,497 | - | - | ||
| (Gain) loss on sale of assets | (1,511) | (12,847) | (5,163) | ||
| Earnings from unconsolidated affiliates | (18,484) | (14,213) | (1,895) | ||
| Impairment of equity investments | 3,136 | 5,500 | - | ||
| Distributions from unconsolidated affiliates | 16,843 | 27,884 | 41,031 | ||
| Unrealized foreign exchange loss | 5,611 | 24,370 | (39,203) | ||
| Change in fair value of derivative instruments | 14,047 | 6,813 | 16,026 | ||
| Change in deferred income taxes | 17,964 | (6,436) | (14,009) | ||
| Other | (210) | 106 | 27 | ||
| Change in other operating balances | |||||
| Accounts receivable | 1,729 | 10,520 | 216 | ||
| Prepayments, refundable income taxes and other assets | 9,311 | (3,454) | 12,229 | ||
| Accounts payable and accrued liabilities | (6,551) | 2,959 | (20) | ||
| Other liabilities | 2,468 | (84) | (9,080) | ||
| Net cash provided by operating activities | 86,953 | 50,449 | 77,788 | ||
| Cash flows (used in) provided by investing activities: | |||||
| Acquisitions and investments, net of cash acquired | (78,180) | (3,068) | (141,688) | ||
| Short-term loan to Idaho Wind | (22,781) | - | - | ||
| Change in restricted cash | 945 | 575 | 6,335 | ||
| Biomass development costs | (2,286) | - | - | ||
| Proceeds from sale of assets | 2,000 | 29,467 | 7,889 | ||
| Purchase of property, plant and equipment | (46,695) | (2,016) | (1,102) | ||
| Purchases of auction rate securities | - | - | (75,518) | ||
| Sales of auction rate securities | - | - | 75,518 | ||
| Net cash (used in) provided by investing activities | (146,997) | 24,958 | (128,566) | ||
| Cash flows (used in) provided by financing activities: | |||||
| Proceeds from issuance of convertible debenture, net of offering costs | 74,575 | - | - | ||
| Proceeds from issuance of equity, net of offering costs | 72,767 | - | - | ||
| Deferred financing costs | (7,941) | - | |||
| Repayment of project-level debt | (18,882) | (12,744) | (22,275) | ||
| Proceeds from revolving credit facility borrowings | 20,000 | - | 55,000 | ||
| Repayments of revolving credit facility borrowings | (20,000) | (55,000) | - | ||
| Dividends paid | (65,028) | (24,955) | (24,612) | ||
| Equity contribution from noncontrolling interest | 200 | - | - | ||
| Proceeds from issuance of project level debt | - | 78,330 | 35,000 | ||
| Redemption of IPSs under normal course issuer bid | - | (3,369) | (1,612) | ||
| Redemption of subordinated notes | - | (40,638) | (3,064) | ||
| Costs associated with common share conversion | - | (4,508) | - | ||
| Net cash provided by (used in) financing activities | 55,691 | (62,884) | 38,437 | ||
| Net (decrease) increase in cash and cash equivalents | (4,353) | 12,523 | (12,341) | ||
| Cash and cash equivalents at beginning of period | 49,850 | 37,327 | 49,668 | ||
| Cash and cash equivalents at end of period | $ 45,497 | $ 49,850 | $ 37,327 | ||
| Supplemental cash flow information | |||||
| Interest paid | $ 26,687 | $ 69,186 | $ 72,129 | ||
| Income taxes paid (refunded), net | $ (8,000) | $ (216) | $ 2,418 | ||
Regulation G Disclosures
Cash Available for Distribution is not a measure recognized under U.S. generally accepted accounting principles (“GAAP”) and does not have a standardized meaning prescribed by GAAP. Management believes Cash Available for Distribution is a relevant supplemental measure of the Company’s ability to earn and distribute cash returns to investors. A reconciliation of Cash Flows from Operating Activities to Cash Available for Distributions is provided below. Investors are cautioned that the Company may calculate this measure in a manner that is different from other companies.
Adjusted EBITDA, earnings before interest, taxes, depreciation and amortization (including non-cash impairment charges), is not a measure recognized under GAAP and is therefore unlikely to be comparable to similar measures presented by other issuers and does not have a standardized meaning prescribed by GAAP. Management uses Adjusted EBITDA at the Project-level to provide comparative information about project performance. A reconciliation of Project Adjusted EBITDA to project income is provided on the following page. Investors are cautioned that the Company may calculate this measure in a manner that is different from other issuers.
Atlantic Power Corporation
Cash Available for Distribution
(In thousands of U.S. dollars, except as otherwise stated)
| (unaudited) | Year ended December 31, | ||||||
| (in thousands of U.S. dollars, except as otherwise stated) | 2010 | 2009 | 2008 | ||||
| Cash flows from operating activities | $ 86,953 | $ 50,449 | $ 77,788 | ||||
| Project-level debt repayments | (18,882) | (12,744) | (22,275) | ||||
| Interest on IPS portion of subordinated notes(1) | - | 30,639 | 36,560 | ||||
| Purchases of property, plant and equipment(2) | (2,549) | (2,016) | (1,102) | ||||
| Cash Available for Distribution | 65,522 | 66,328 | 90,971 | ||||
| Interest on subordinated notes | - | 30,639 | 36,560 | ||||
| Dividends on common shares | 65,648 | 27,988 | 24,692 | ||||
| Total distributions to shareholders | $ 65,648 | $ 58,627 | $ 61,252 | ||||
| Payout ratio | 100% | 88% | 67% | ||||
| Expressed in Cdn$ | |||||||
| Cash Available for Distribution | 67,540 | 75,673 | 97,102 | ||||
| Total common share distributions | 67,914 | 66,325 | 65,143 | ||||
(1) Prior to the common share conversion in November 2009, a portion of our monthly distribution to IPS holders was paid in the form of interest on the subordinated notes compromising a part of the IPSs. Subsequent to the conversion, the entire monthly cash distribution is paid in the form of a dividend on our common shares.
(2) Excludes construction-in-progress costs related to our Piedmont biomass project.
Atlantic Power Corporation
Project Adjusted EBITDA (in thousands of U.S. dollars)
| Year ended December 31, | ||||||
| 2010 | 2009 | 2008 | ||||
| Project Adjusted EBITDA by individual segment | ||||||
| Auburndale | $ 34,232 | $ 35,221 | $ 4,461 | |||
| Lake | 31,428 | 25,378 | 32,892 | |||
| Pasco | 4,712 | 3,299 | 21,953 | |||
| Path 15 | 28,639 | 27,691 | 28,872 | |||
| Chambers | 19,344 | 13,595 | 27,603 | |||
| Total | 118,355 | 105,184 | 115,781 | |||
| Other Project Assets segment | ||||||
| Mid-Georgia | - | 2,509 | 4,206 | |||
| Stockton | - | (675) | 1,780 | |||
| Badger Creek | 3,062 | 3,245 | 3,762 | |||
| Koma Kulshan | 812 | 822 | 912 | |||
| Onondaga | - | 7,865 | ||||
| Orlando | 7,883 | 8,858 | 8,206 | |||
| Topsham | 1,890 | 1,879 | 2,629 | |||
| Delta-Person | 1,849 | 894 | 2,012 | |||
| Gregory | 4,822 | 4,482 | 5,236 | |||
| Rumford | (7) | 2,590 | 2,395 | |||
| Selkirk | 14,931 | 15,059 | 19,104 | |||
| Rollcast | (987) | (234) | - | |||
| Other | (26) | (434) | 801 | |||
| Total adjusted EBITDA from Other Project Assets segment | 34,229 | 38,995 | 58,908 | |||
| Project income | ||||||
| Total adjusted EBITDA from all Projects | 152,584 | 144,179 | 174,689 | |||
| Depreciation and amortization | 65,791 | 67,643 | 60,125 | |||
| Interest expense, net | 23,628 | 31,511 | 30,316 | |||
| Change in the fair value of derivative instruments | 16,072 | 5,047 | 29,914 | |||
| Other (income) expense | 3,643 | (8,437) | 13,328 | |||
| Project income as reported in the statement of operations | $ 43,450 | $ 48,415 | $ 41,006 | |||