UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM 10-Q
☒ | QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
For the quarterly period ended April 30, 2022January 31, 2023
OR
☐ | TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
For the transition period from to
Commission file number: 1-14204
FUELCELL ENERGY, INC.
(Exact name of registrant as specified in its charter)
| | |
Delaware | | 06-0853042 |
(State or other jurisdiction of incorporation or organization) | | (I.R.S. Employer Identification No.) |
| | |
3 Great Pasture Road Danbury, Connecticut | | 06810 |
(Address of principal executive offices) | | (Zip Code) |
Registrant’s telephone number, including area code: (203) 825-6000
Securities registered pursuant to Section 12(b) of the Act:
| | |||
Title of each class | | Trading Symbol(s) | | Name of each exchange on which registered |
Common stock, par value $0.0001 per share | | FCEL | | The Nasdaq Stock Market LLC (Nasdaq Global Market) |
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ☒ No ☐
Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ☒ No ☐
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer”, “smaller reporting company” and “emerging growth company” in Rule 12b-2 of the Exchange Act.
Large accelerated filer | ☒ | Accelerated filer | ☐ |
Non-accelerated filer | ☐ | Smaller reporting company | ☐ |
Emerging growth company | ☐ | | |
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No ☒
Number of shares of common stock, par value $0.0001 per share, outstanding as of June 7, 2022: 386,609,395March 3, 2023: 405,732,053
FUELCELL ENERGY, INC.
FORM 10-Q
Table of Contents
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| Management’s Discussion and Analysis of Financial Condition and Results of Operations. | |
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2
PART I. FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
FUELCELL ENERGY, INC.
Consolidated Balance Sheets
(Unaudited)
(Amounts in thousands, except share and per share amounts)
| | | | | | |
| | April 30, | | October 31, | ||
|
| 2022 |
| 2021 | ||
ASSETS | | | | | | |
Current assets: | | | | | | |
Cash and cash equivalents, unrestricted | | $ | 467,774 | | $ | 432,213 |
Restricted cash and cash equivalents - short-term | | | 5,301 | | | 11,268 |
Accounts receivable, net | | | 15,466 | | | 14,730 |
Unbilled receivables | | | 10,205 | | | 8,924 |
Inventories | | | 82,878 | | | 67,074 |
Other current assets | | | 13,602 | | | 9,177 |
Total current assets | | | 595,226 | | | 543,386 |
Restricted cash and cash equivalents - long-term | | | 16,477 | | | 16,731 |
Inventories - long-term | | | 4,586 | | | 4,586 |
Project assets, net | | | 239,864 | | | 223,277 |
Property, plant and equipment, net | | | 44,767 | | | 39,416 |
Operating lease right-of-use assets, net | | | 7,658 | | | 8,109 |
Goodwill | | | 4,075 | | | 4,075 |
Intangible assets, net | | | 18,021 | | | 18,670 |
Other assets | | | 15,542 | | | 16,998 |
Total assets (1) | | $ | 946,216 | | $ | 875,248 |
LIABILITIES AND STOCKHOLDERS' EQUITY | | | | | | |
Current liabilities: | | | | | | |
Current portion of long-term debt | | $ | 9,919 | | $ | 10,085 |
Current portion of operating lease liabilities | | | 946 | | | 1,032 |
Accounts payable | | | 19,524 | | | 19,267 |
Accrued liabilities | | | 24,011 | | | 16,099 |
Deferred revenue | | | 25,902 | | | 6,287 |
Total current liabilities | | | 80,302 | | | 52,770 |
Long-term deferred revenue and customer deposits | | | 18,277 | | | 30,427 |
Long-term operating lease liabilities | | | 7,709 | | | 8,093 |
Long-term debt and other liabilities | | | 79,524 | | | 78,633 |
Total liabilities (1) | | | 185,812 | | | 169,923 |
Redeemable Series B preferred stock (liquidation preference of $64,020 as of | | | 59,857 | | | 59,857 |
Redeemable noncontrolling interest | | | 3,030 | | | 3,030 |
Total equity: | | | | | | |
Stockholders’ equity: | | | | | | |
Common stock ($0.0001 par value); 500,000,000 shares authorized as of April 30, 2022 and October 31, 2021; 386,608,869 and 366,618,693 shares issued and outstanding as of April 30, 2022 and October 31, 2021, respectively | | | 39 | | | 37 |
Additional paid-in capital | | | 2,028,206 | | | 1,908,471 |
Accumulated deficit | | | (1,336,092) | | | (1,265,251) |
Accumulated other comprehensive loss | | | (1,059) | | | (819) |
Treasury stock, Common, at cost (99,664 and 73,430 shares as of April 30, 2022 | | | (718) | | | (586) |
Deferred compensation | | | 718 | | | 586 |
Total stockholder's equity | | | 691,094 | | | 642,438 |
Noncontrolling interest | | | 6,423 | | | — |
Total equity | | | 697,517 | | | 642,438 |
Total liabilities, redeemable noncontrolling interests and stockholders' equity | | $ | 946,216 | | $ | 875,248 |
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| | January 31, | | October 31, | ||
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| 2023 |
| 2022 | ||
ASSETS | | | | | | |
Current assets: | | | | | | |
Cash and cash equivalents, unrestricted | | $ | 315,168 | | $ | 458,055 |
Restricted cash and cash equivalents - short-term | | | 4,456 | | | 4,423 |
Investments - short-term | | | 75,652 | | | - |
Accounts receivable, net | | | 3,213 | | | 4,885 |
Unbilled receivables | | | 13,711 | | | 11,019 |
Inventories | | | 101,176 | | | 90,909 |
Other current assets | | | 11,545 | | | 10,989 |
Total current assets | | | 524,921 | | | 580,280 |
Restricted cash and cash equivalents - long-term | | | 20,155 | | | 18,566 |
Inventories - long-term | | | 7,549 | | | 7,549 |
Project assets, net | | | 229,914 | | | 232,886 |
Property, plant and equipment, net | | | 63,338 | | | 58,137 |
Operating lease right-of-use assets, net | | | 8,997 | | | 7,189 |
Goodwill | | | 4,075 | | | 4,075 |
Intangible assets, net | | | 17,049 | | | 17,373 |
Other assets | | | 16,385 | | | 13,662 |
Total assets (1) | | $ | 892,383 | | $ | 939,717 |
LIABILITIES AND STOCKHOLDERS' EQUITY | | | | | | |
Current liabilities: | | | | | | |
Current portion of long-term debt | | $ | 13,249 | | $ | 13,198 |
Current portion of operating lease liabilities | | | 557 | | | 650 |
Accounts payable | | | 24,590 | | | 28,196 |
Accrued liabilities | | | 20,313 | | | 27,415 |
Deferred revenue | | | 7,366 | | | 16,341 |
Total current liabilities | | | 66,075 | | | 85,800 |
Long-term deferred revenue and customer deposits | | | - | | | 9,095 |
Long-term operating lease liabilities | | | 9,503 | | | 7,575 |
Long-term debt and other liabilities | | | 81,575 | | | 82,863 |
Total liabilities (1) | | | 157,153 | | | 185,333 |
Redeemable Series B preferred stock (liquidation preference of $64,020 as of | | | 59,857 | | | 59,857 |
Redeemable noncontrolling interest | | | - | | | 3,030 |
Total equity: | | | | | | |
Stockholders’ equity: | | | | | | |
Common stock ($0.0001 par value); 500,000,000 shares authorized as of January 31, 2023 and October 31, 2022; 405,732,053 and 405,562,988 shares issued and outstanding as of January 31, 2023 and October 31, 2022, respectively | | | 41 | | | 41 |
Additional paid-in capital | | | 2,095,667 | | | 2,094,076 |
Accumulated deficit | | | (1,426,595) | | | (1,407,973) |
Accumulated other comprehensive loss | | | (1,305) | | | (1,752) |
Treasury stock, Common, at cost (163,943 and 142,837 shares as of January 31, 2023 | | | (923) | | | (855) |
Deferred compensation | | | 923 | | | 855 |
Total stockholder's equity | | | 667,808 | | | 684,392 |
Noncontrolling interests | | | 7,565 | | | 7,105 |
Total equity | | | 675,373 | | | 691,497 |
Total liabilities, redeemable Series B preferred stock, redeemable noncontrolling interest and total equity | | $ | 892,383 | | $ | 939,717 |
(1) |
See accompanying notes to consolidated financial statements.
3
FUELCELL ENERGY, INC.
Consolidated Statements of Operations and Comprehensive Loss
(Unaudited)
(Amounts in thousands, except share and per share amounts)
| | | | | | | |
| | Three Months Ended April 30, | | ||||
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| 2022 |
| 2021 | | ||
Revenues: | | | | | | | |
Product | | $ | — | | $ | — | |
Service | | | 2,639 | | | 660 | |
Generation | | | 9,050 | | | 6,185 | |
Advanced Technologies | | | 4,695 | | | 7,108 | |
Total revenues | | | 16,384 | | | 13,953 | |
Costs of revenues: | | | | | | | |
Product | | | 3,033 | | | 1,921 | |
Service | | | 3,033 | | | 2,867 | |
Generation | | | 14,120 | | | 9,422 | |
Advanced Technologies | | | 3,508 | | | 4,499 | |
Total costs of revenues | | | 23,694 | | | 18,709 | |
Gross loss | | | (7,310) | | | (4,756) | |
Operating expenses: | | | | | | | |
Administrative and selling expenses | | | 13,234 | | | 9,670 | |
Research and development expenses | | | 7,673 | | | 2,964 | |
Total costs and expenses | | | 20,907 | | | 12,634 | |
Loss from operations | | | (28,217) | | | (17,390) | |
Interest expense | | | (1,707) | | | (1,563) | |
Other (expense) income, net | | | (202) | | | 32 | |
Loss before benefit for income taxes | | | (30,126) | | | (18,921) | |
Benefit for income taxes | | | — | | | 4 | |
Net loss | | | (30,126) | | | (18,917) | |
Net income attributable to noncontrolling interest | | | 91 | | | — | |
Net loss attributable to FuelCell Energy, Inc. | | | (30,217) | | | (18,917) | |
Series B preferred stock dividends | | | (800) | | | (800) | |
Net loss attributable to common stockholders | | $ | (31,017) | | $ | (19,717) | |
Loss per share basic and diluted: | | | | | | | |
Net loss per share attributable to common stockholders | | $ | (0.08) | | $ | (0.06) | |
Basic and diluted weighted average shares outstanding | | | 372,615,824 | | | 322,500,592 | |
| | | | | | | |
| | Three Months Ended April 30, | | ||||
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| 2022 |
| 2021 | | ||
Net loss | | $ | (30,126) | | $ | (18,917) | |
Other comprehensive loss: | | | | | | | |
Foreign currency translation adjustments | | | (149) | | | (60) | |
Total comprehensive loss | | $ | (30,275) | | $ | (18,977) | |
Comprehensive income attributable to noncontrolling interest | | | 91 | | | — | |
Comprehensive loss attributable to FuelCell Energy, Inc. | | $ | (30,366) | | $ | (18,977) | |
| | | | | | | |
See accompanying notes to consolidated financial statements.
4
FUELCELL ENERGY, INC.
Consolidated Statements of Operations and Comprehensive Loss
(Unaudited)
(Amounts in thousands, except share and per share amounts)
| | | | | | | | | | | | | |
| | Six Months Ended April 30, | | Three Months Ended January 31, | |||||||||
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| 2022 |
| 2021 |
| 2023 |
| 2022 |
| ||||
Revenues: | | | | | | | | | | | | | |
Product | | $ | 18,000 | | $ | — | | $ | 9,095 | | $ | 18,000 | |
Service | | | 4,806 | | | 5,573 | | | 13,882 | | | 2,167 | |
Generation | | | 16,546 | | | 11,076 | | | 9,557 | | | 7,496 | |
Advanced Technologies | | | 8,827 | | | 12,181 | | | 4,539 | | | 4,132 | |
Total revenues | | | 48,179 | | | 28,830 | | | 37,073 | | | 31,795 | |
Costs of revenues: | | | | | | | | | | | | | |
Product | | | 21,240 | | | 4,287 | | | 1,029 | | | 18,207 | |
Service | | | 5,405 | | | 7,966 | | | 10,945 | | | 2,372 | |
Generation | | | 24,842 | | | 16,537 | | | 16,602 | | | 10,722 | |
Advanced Technologies | | | 6,897 | | | 8,414 | | | 3,260 | | | 3,389 | |
Total costs of revenues | | | 58,384 | | | 37,204 | | | 31,836 | | | 34,690 | |
Gross loss | | | (10,205) | | | (8,374) | |||||||
Gross profit (loss) | | | 5,237 | | | (2,895) | | ||||||
Operating expenses: | | | | | | | | | | | | | |
Administrative and selling expenses | | | 50,199 | | | 18,602 | | | 15,009 | | | 36,965 | |
Research and development expenses | | | 12,657 | | | 4,787 | | | 12,683 | | | 4,984 | |
Total costs and expenses | | | 62,856 | | | 23,389 | | | 27,692 | | | 41,949 | |
Loss from operations | | | (73,061) | | | (31,763) | | | (22,455) | | | (44,844) | |
Interest expense | | | (3,135) | | | (4,108) | | | (1,512) | | | (1,428) | |
Loss on extinguishment of debt | | | — | | | (11,156) | |||||||
Loss on extinguishment of Series 1 preferred share obligation | | | — | | | (934) | |||||||
Change in fair value of common stock warrant liability | | | — | | | (15,974) | |||||||
Other expense, net | | | (50) | | | (946) | |||||||
Loss before benefit for income taxes | | | (76,246) | | | (64,881) | |||||||
Benefit for income taxes | | | — | | | 4 | |||||||
Interest income | | | 3,410 | | | 10 | | ||||||
Other income, net | | | 49 | | | 142 | | ||||||
Loss before provision for income taxes | | | (20,508) | | | (46,120) | | ||||||
Provision for income taxes | | | (578) | | | - | | ||||||
Net loss | | | (76,246) | | | (64,877) | | | (21,086) | | | (46,120) | |
Net loss attributable to noncontrolling interest | | | (5,405) | | | — | |||||||
Net loss attributable to noncontrolling interests | | | (2,464) | | | (5,496) | | ||||||
Net loss attributable to FuelCell Energy, Inc. | | | (70,841) | | | (64,877) | | | (18,622) | | | (40,624) | |
Series B preferred stock dividends | | | (1,600) | | | (1,600) | | | (800) | | | (800) | |
Net loss attributable to common stockholders | | $ | (72,441) | | $ | (66,477) | | $ | (19,422) | | $ | (41,424) | |
Loss per share basic and diluted: | | | | | | | | | | | | | |
Net loss per share attributable to common stockholders | | $ | (0.20) | | $ | (0.21) | | $ | (0.05) | | $ | (0.11) | |
Basic and diluted weighted average shares outstanding | | | 369,626,543 | | | 317,219,129 | | | 405,803,753 | | | 366,734,739 | |
| | | | | | | | | | | | | |
| | Six Months Ended April 30, | | Three Months Ended January 31, | |||||||||
|
| 2022 |
| 2021 |
| 2023 |
| 2022 |
| ||||
Net loss | | $ | (76,246) | | $ | (64,877) | | $ | (21,086) | | $ | (46,120) | |
Other comprehensive loss: | | | | | | | | | | | | | |
Foreign currency translation adjustments | | | (240) | | | (2) | | | 447 | | | (91) | |
Total comprehensive loss | | $ | (76,486) | | $ | (64,879) | | $ | (20,639) | | $ | (46,211) | |
Comprehensive loss attributable to noncontrolling interest | | | (5,405) | | | — | |||||||
Comprehensive loss attributable to noncontrolling interests | | | (2,464) | | | (5,496) | | ||||||
Comprehensive loss attributable to FuelCell Energy, Inc. | | $ | (71,081) | | $ | (64,879) | | $ | (18,175) | | $ | (40,715) | |
See accompanying notes to consolidated financial statements.
54
FUELCELL ENERGY, INC.
Consolidated Statements of Changes in Equity
(Unaudited)
(Amounts in thousands, except share amounts)
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| | Common Stock | | | | | | | | | | | | | | | | | | | | | | | | | | Common Stock | | | | | | | | | | | | | | | | | | | | | | | | | ||||||
|
| Shares |
| Amount |
| Additional |
| Accumulated |
| Accumulated |
| Treasury |
| Deferred | | | Total Stockholder's Equity | | | Noncontrolling Interests |
| Total |
| Shares |
| Amount |
| Additional |
| Accumulated |
| Accumulated |
| Treasury |
| Deferred | | | Total Stockholder's Equity | | | Noncontrolling Interests |
| Total | ||||||||||||||
Balance, October 31, 2021 | | 366,618,693 | | $ | 37 | | $ | 1,908,471 | | $ | (1,265,251) | | $ | (819) | | $ | (586) | | $ | 586 | | $ | 642,438 | | $ | — | | $ | 642,438 | |||||||||||||||||||||||||||||
Balance, October 31, 2022 | | 405,562,988 | | $ | 41 | | $ | 2,094,076 | | $ | (1,407,973) | | $ | (1,752) | | $ | (855) | | $ | 855 | | $ | 684,392 | | $ | 7,105 | | $ | 691,497 | |||||||||||||||||||||||||||||
Common stock issued, non-employee compensation | | 20,673 | | | — | | | 100 | | | — | | | — | | | — | | | — | | | 100 | | | — | | | 100 | | 21,106 | | | — | | | 68 | | | — | | | — | | | — | | | — | | | 68 | | | — | | | 68 |
Stock issued under benefit plans, net of taxes paid upon vesting of restricted stock awards | | 60,052 | | | — | | | (260) | | | — | | | — | | | — | | | — | | | (260) | | | — | | | (260) | | 169,065 | | | — | | | (314) | | | — | | | — | | | — | | | — | | | (314) | | | — | | | (314) |
Share based compensation | | — | | | — | | | 1,470 | | | — | | | — | | | — | | | — | | | 1,470 | | | — | | | 1,470 | | — | | | — | | | 2,637 | | | — | | | — | | | — | | | — | | | 2,637 | | | — | | | 2,637 |
Preferred dividends — Series B | | — | | | — | | | (800) | | | — | | | — | | | — | | | — | | | (800) | | | — | | | (800) | | — | | | — | | | (800) | | | — | | | — | | | — | | | — | | | (800) | | | — | | | (800) |
Effect of foreign currency translation | | — | | | — | | | — | | | — | | | (91) | | | — | | | — | | | (91) | | | — | | | (91) | | — | | | — | | | — | | | — | | | 447 | | | — | | | — | | | 447 | | | — | | | 447 |
Adjustment for deferred compensation | | (13,232) | | | — | | | — | | | — | | | — | | | (64) | | | 64 | | | — | | | — | | | — | | (21,106) | | | — | | | — | | | — | | | — | | | (68) | | | 68 | | | — | | | — | | | — |
Net loss attributable to noncontrolling interest | | — | | | — | | | — | | | 5,496 | | | — | | | — | | | — | | | 5,496 | | | (5,496) | | | — | |||||||||||||||||||||||||||||
Reclass of redeemable non-controlling interest | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | 3,030 | | | 3,030 | |||||||||||||||||||||||||||||
Distribution to non-controlling interest | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | (106) | | | (106) | |||||||||||||||||||||||||||||
Net loss attributable to noncontrolling interests | | — | | | — | | | — | | | 2,464 | | | — | | | — | | | — | | | 2,464 | | | (2,464) | | | — | |||||||||||||||||||||||||||||
Net Loss | | — | | | — | | | — | | | (46,120) | | | — | | | — | | | — | | | (46,120) | | | — | | | (46,120) | | — | | | — | | | — | | | (21,086) | | | — | | | — | | | — | | | (21,086) | | | — | | | (21,086) |
Balance, January 31, 2022 | | 366,686,186 | | $ | 37 | | $ | 1,908,981 | | $ | (1,305,875) | | $ | (910) | | $ | (650) | | $ | 650 | | $ | 602,233 | | $ | (5,496) | | $ | 596,737 | |||||||||||||||||||||||||||||
Sale of common stock, net of fees | | 19,896,904 | | | 2 | | | 118,262 | | | | | | | | | | | | | | | 118,264 | | | — | | | 118,264 | |||||||||||||||||||||||||||||
Common stock issued, non-employee compensation | | 13,002 | | | — | | | 68 | | | — | | | — | | | — | | | — | | | 68 | | | — | | | 68 | |||||||||||||||||||||||||||||
Stock issued under benefit plans, net of taxes paid upon vesting of restricted stock awards | | 25,779 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |||||||||||||||||||||||||||||
Share based compensation | | — | | | — | | | 1,695 | | | — | | | — | | | — | | | — | | | 1,695 | | | — | | | 1,695 | |||||||||||||||||||||||||||||
Preferred dividends — Series B | | — | | | — | | | (800) | | | — | | | — | | | — | | | — | | | (800) | | | — | | | (800) | |||||||||||||||||||||||||||||
Effect of foreign currency translation | | — | | | — | | | — | | | — | | | (149) | | | — | | | — | | | (149) | | | — | | | (149) | |||||||||||||||||||||||||||||
Adjustment for deferred compensation | | (13,002) | | | — | | | — | | | — | | | — | | | (68) | | | 68 | | | — | | | — | | | — | |||||||||||||||||||||||||||||
Reclassification of noncontrolling interest | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | 12,419 | | | 12,419 | |||||||||||||||||||||||||||||
Return of capital to noncontrolling interest | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | (496) | | | (496) | |||||||||||||||||||||||||||||
Distribution to noncontrolling interest | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | (95) | | | (95) | |||||||||||||||||||||||||||||
Net income attributable to noncontrolling interest | | — | | | — | | | — | | | (91) | | | — | | | — | | | — | | | (91) | | | 91 | | | — | |||||||||||||||||||||||||||||
Net Loss | | — | | | — | | | — | | | (30,126) | | | — | | | — | | | — | | | (30,126) | | | — | | | (30,126) | |||||||||||||||||||||||||||||
Balance, April 30, 2022 | | 386,608,869 | | $ | 39 | | $ | 2,028,206 | | $ | (1,336,092) | | $ | (1,059) | | $ | (718) | | $ | 718 | | $ | 691,094 | | $ | 6,423 | | $ | 697,517 | |||||||||||||||||||||||||||||
Balance, January 31, 2023 | | 405,732,053 | | $ | 41 | | $ | 2,095,667 | | $ | (1,426,595) | | $ | (1,305) | | $ | (923) | | $ | 923 | | $ | 667,808 | | $ | 7,565 | | $ | 675,373 |
See accompanying notes to consolidated financial statements.
6
FUELCELL ENERGY, INC.
Consolidated Statements of Changes in Equity
(Unaudited)
(Amounts in thousands, except share amounts)
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Common Stock | | | | | | | | | | | | | | | | | | | | Common Stock |
| | | | | | | | | | | | | | | | | | | | | | | | ||||||
|
| Shares |
| Amount |
| Additional |
| Accumulated |
| Accumulated |
| Treasury |
| Deferred | | | Total Equity |
| Shares |
| | Amount | | | Additional |
| Accumulated |
| Accumulated |
| Treasury |
| Deferred |
| | Total Stockholders' Equity |
| | Noncontrolling Interests |
| | Total Stockholders' Equity | ||||||||||
Balance, October 31, 2020 | | 294,706,758 | | $ | 29 | | $ | 1,359,454 | | $ | (1,164,196) | | $ | (739) | | $ | (432) | | $ | 432 | | $ | 194,548 | |||||||||||||||||||||||||||||
Sale of common stock, net of fees | | 25,000,000 | | | 3 | | | 156,363 | | | — | | | — | | | — | | | — | | | 156,366 | |||||||||||||||||||||||||||||
Orion warrant exercises | | 2,700,000 | | | — | | | 21,824 | | | — | | | — | | | — | | | — | | | 21,824 | |||||||||||||||||||||||||||||
Balance, October 31, 2021 | | 366,618,693 | | $ | 37 | | $ | 1,908,471 | | $ | (1,265,251) | | $ | (819) | | $ | (586) | | $ | 586 | | $ | 642,438 | | $ | — | | $ | 642,438 | |||||||||||||||||||||||
Common stock issued, non-employee compensation | | 2,734 | | | — | | | 45 | | | — | | | — | | | — | | | — | | | 45 | | 20,673 | | | — | | | 100 | | | — | | | — | | | — | | | — | | | 100 | | | — | | | 100 |
Stock issued under benefit plans, net of taxes paid upon vesting of restricted stock awards | | 4,521 | | | — | | | 8 | | | — | | | — | | | — | | | — | | | 8 | |||||||||||||||||||||||||||||
Stock issued under benefit plan, net of taxes paid upon vesting of restricted stock awards | | 60,052 | | | | | | (260) | | | — | | | — | | | — | | | — | | | (260) | | | — | | | (260) | |||||||||||||||||||||||
Share based compensation | | — | | | — | | | 1,417 | | | — | | | — | | | — | | | — | | | 1,417 | | — | | | — | | | 1,470 | | | — | | | — | | | — | | | — | | | 1,470 | | | — | | | 1,470 |
Preferred dividends — Series B | | — | | | — | | | (800) | | | — | | | — | | | — | | | — | | | (800) | | — | | | — | | | (800) | | | — | | | — | | | — | | | — | | | (800) | | | — | | | (800) |
Effect of foreign currency translation | | — | | | — | | | — | | | — | | | 58 | | | — | | | — | | | 58 | | — | | | — | | | — | | | — | | | (91) | | | — | | | — | | | (91) | | | — | | | (91) |
Adjustment for deferred compensation | | (1,669) | | | — | | | — | | | — | | | — | | | (30) | | | 30 | | | — | | (13,232) | | | — | | | — | | | — | | | — | | | (64) | | | 64 | | | — | | | — | | | — |
Release of a share reserve | | (48) | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |||||||||||||||||||||||||||||
Net Loss | | — | | | — | | | — | | | (45,960) | | | — | | | — | | | — | | | (45,960) | |||||||||||||||||||||||||||||
Balance, January 31, 2021 | | 322,412,296 | | $ | 32 | | $ | 1,538,311 | | $ | (1,210,156) | | $ | (681) | | $ | (462) | | $ | 462 | | $ | 327,506 | |||||||||||||||||||||||||||||
Sale of common stock, net of fees | | — | | | — | | | 5 | | | — | | | — | | | — | | | — | | | 5 | |||||||||||||||||||||||||||||
Warrant exercises | | 14,026 | | | — | | | 269 | | | — | | | — | | | — | | | — | | | 269 | |||||||||||||||||||||||||||||
Common stock issued, non-employee compensation | | 5,456 | | | — | | | 55 | | | — | | | — | | | — | | | — | | | 55 | |||||||||||||||||||||||||||||
Stock issued under benefit plans, net of taxes paid upon vesting of restricted stock awards | | 64,782 | | | — | | | (262) | | | — | | | — | | | — | | | — | | | (262) | |||||||||||||||||||||||||||||
Share based compensation | | — | | | — | | | 1,253 | | | — | | | — | | | — | | | — | | | 1,253 | |||||||||||||||||||||||||||||
Preferred dividends — Series B | | — | | | — | | | (800) | | | — | | | — | | | — | | | — | | | (800) | |||||||||||||||||||||||||||||
Effect of foreign currency translation | | — | | | — | | | — | | | — | | | (60) | | | — | | | — | | | (60) | |||||||||||||||||||||||||||||
Adjustment for deferred compensation | | (3,756) | | | — | | | — | | | — | | | — | | | (41) | | | 41 | | | — | |||||||||||||||||||||||||||||
Net Loss | | — | | | — | | | — | | | (18,917) | | | — | | | — | | | — | | | (18,917) | |||||||||||||||||||||||||||||
Balance, April 30, 2021 | | 322,492,804 | | $ | 32 | | $ | 1,538,831 | | $ | (1,229,073) | | $ | (741) | | $ | (503) | | $ | 503 | | $ | 309,049 | |||||||||||||||||||||||||||||
Net loss attributable to redeemable noncontrolling interest | | — | | | — | | | — | | | 5,496 | | | — | | | — | | | — | | | 5,496 | | | (5,496) | | | — | |||||||||||||||||||||||
Net loss attributable to FuelCell Energy, Inc. | | — | | | — | | | | | | (46,120) | | | — | | | — | | | — | | | (46,120) | | | — | | | (46,120) | |||||||||||||||||||||||
Balance, January 31, 2022 | | 366,686,186 | | $ | 37 | | $ | 1,908,981 | | $ | (1,305,875) | | $ | (910) | | $ | (650) | | $ | 650 | | $ | 602,233 | | $ | (5,496) | | $ | 596,737 |
See accompanying notes to consolidated financial statements.
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FUELCELL ENERGY, INC.
Consolidated Statements of Cash Flows
(Unaudited)
(Amounts in thousands)
| | | | | | | | | | | | | | |
| | Six Months Ended April 30, | | | Three Months Ended January 31, | |||||||||
|
| 2022 |
| 2021 | |
| 2023 |
| 2022 | | ||||
Cash flows from operating activities: | | | | | | | | | | | | | | |
Net loss | | $ | (76,246) | | $ | (64,877) | | | $ | (21,086) | | $ | (46,120) | |
Adjustments to reconcile net loss to net cash used in operating activities: | | | | | | | | | | | | | | |
Share-based compensation | | | 3,165 | | | 2,670 | | | | 2,637 | | | 1,470 | |
Depreciation and amortization | | | 11,103 | | | 10,412 | | | | 5,405 | | | 5,771 | |
Change in fair value of common stock warrant liability | | | — | | | 15,974 | | |||||||
Non-cash charge for extinguishment of preferred stock obligation of subsidiary | | | — | | | 934 | | |||||||
Non-cash interest expense on preferred stock and debt obligations | | | 2,099 | | | 2,475 | | |||||||
Non-cash charge for extinguishment of debt | | | — | | | 7,156 | | |||||||
Unrealized gain on derivative contract | | | (523) | | | (228) | | |||||||
Non-cash interest expense on finance obligations | | | 1,052 | | | 1,066 | | |||||||
Non-cash interest income on investments | | | (675) | | | - | | |||||||
Operating lease costs | | | 779 | | | 761 | | | | 323 | | | 395 | |
Operating lease payments | | | (730) | | | (586) | | | | (301) | | | (372) | |
Impairment of property, plant and equipment | | | 976 | | | — | | |||||||
Unrealized foreign currency losses | | | 578 | | | 873 | | |||||||
Other non-cash transactions | | | (134) | | | 372 | | |||||||
(Increase) decrease in operating assets: | | | | | | | | |||||||
Impairment of property, plant and equipment and project assets | | | - | | | 976 | | |||||||
Unrealized foreign currency losses (gains) | | | 5 | | | (82) | | |||||||
Other, net | | | 96 | | | (316) | | |||||||
Decrease (increase) in operating assets: | | | | | | | | |||||||
Accounts receivable | | | (1,382) | | | (2,584) | | | | 1,672 | | | (15,972) | |
Unbilled receivables | | | (242) | | | (645) | | | | (4,965) | | | (4,369) | |
Inventories | | | (20,021) | | | (13,617) | | | | (10,267) | | | (2,529) | |
Other assets | | | (6,154) | | | (2,930) | | | | (1,006) | | | (1,994) | |
Increase (decrease) in operating liabilities: | | | | | | | | |||||||
(Decrease) increase in operating liabilities: | | | | | | | | |||||||
Accounts payable | | | 2,568 | | | 3,280 | | | | (1,072) | | | 2,560 | |
Accrued liabilities | | | 8,057 | | | (2,864) | | | | (7,125) | | | 10,027 | |
Deferred revenue | | | 11,400 | | | 2,262 | | | | (18,070) | | | 1,735 | |
Net cash used in operating activities | | | (64,707) | | | (41,162) | | | | (53,377) | | | (47,754) | |
Cash flows from investing activities: | | | | | | | | | | | | | | |
Capital expenditures | | | (10,395) | | | (960) | | | | (7,765) | | | (5,331) | |
Project asset expenditures | | | (18,693) | | | (21,212) | | | | (2,080) | | | (10,435) | |
Purchases of held-to-maturity debt securities | | | (74,977) | | | - | | |||||||
Net cash used in investing activities | | | (29,088) | | | (22,172) | | | | (84,822) | | | (15,766) | |
Cash flows from financing activities: | | | | | | | | | | | | | | |
Repayment of debt | | | (4,857) | | | (91,669) | | | | (2,291) | | | (2,530) | |
Common stock issued for stock plans and related expenses | | | 26 | | | (15) | | |||||||
Expenses related to common stock issued for stock plans | | | 21 | | | 26 | | |||||||
Contributions received from sale of noncontrolling interest | | | 12,419 | | | — | | | | - | | | 12,419 | |
Return of capital to noncontrolling interest | | | (496) | | | — | | |||||||
Distribution to noncontrolling interest | | | (95) | | | — | | | | (106) | | | - | |
Payments for taxes related to net share settlement of equity awards | | | (286) | | | — | | | | (337) | | | (285) | |
Repayment of Series 1 Preferred Share Obligation | | | — | | | (21,541) | | |||||||
Common stock issuance, net of fees | | | 118,264 | | | 156,368 | | |||||||
Proceeds from warrant exercises, net | | | — | | | 923 | | |||||||
Payment of preferred dividends | | | (1,600) | | | (1,600) | | | | (800) | | | (800) | |
Net cash provided by financing activities | | | 123,375 | | | 42,466 | | |||||||
Net cash (used in) provided by financing activities | | | (3,513) | | | 8,830 | | |||||||
Effects on cash from changes in foreign currency rates | | | (240) | | | (2) | | | | 447 | | | (91) | |
Net increase (decrease) in cash, cash equivalents and restricted cash | | | 29,340 | | | (20,870) | | |||||||
Net decrease in cash, cash equivalents and restricted cash | | | (141,265) | | | (54,781) | | |||||||
Cash, cash equivalents and restricted cash-beginning of period | | | 460,212 | | | 192,052 | | | | 481,044 | | | 460,212 | |
Cash, cash equivalents and restricted cash-end of period | | $ | 489,552 | | $ | 171,182 | | | $ | 339,779 | | $ | 405,431 | |
| | | | | | | | |||||||
Supplemental cash flow disclosures: | | | | | | | | | | | | | | |
Cash interest paid and early prepayment charge | | $ | 815 | | $ | 8,790 | | |||||||
Cash interest paid | | $ | 343 | | $ | 329 | | |||||||
Noncash financing and investing activity: | | | | | | | | | | | | | | |
Operating lease liabilities | | | — | | | 1,459 | | | | 2,005 | | | - | |
Operating lease right-of-use assets | | | — | | | 1,459 | | | | 2,005 | | | - | |
Noncash reclassifications from inventory to project assets | | | 4,217 | | | 8,929 | | | | - | | | 4,217 | |
Noncash reclassifications from other assets to project assets | | | 2,375 | | | — | | |||||||
Warrant exercises | | | — | | | 21,170 | | |||||||
Accrued purchase of fixed assets, cash to be paid in subsequent period | | | 848 | | | 491 | | | | 3,055 | | | 1,077 | |
Accrued purchase of project assets, cash to be paid in subsequent period | | | 5,085 | | | 3,078 | | | | 5,250 | | | 7,640 | |
See accompanying notes to consolidated financial statements.
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FUELCELL ENERGY, INC.
Notes to Consolidated Financial Statements
(Unaudited)
(Tabular amounts in thousands, except share and per share amounts)
Note 1. Nature of Business and Basis of Presentation
Headquartered in Danbury, Connecticut, FuelCell Energy, Inc. (together with its subsidiaries, the “Company,” “FuelCell Energy,” “we,” “us,” or “our”) has leveraged five decades of research and development to become a global leader in delivering environmentally responsible distributed baseload power platform solutions through our proprietary fuel cell technology. As an innovator and an American manufacturer of clean fuel cell power platforms, ourOur current commercial technology delivers clean, distributed generationproduces electricity, heat, hydrogen, and distributed hydrogen, as well as heat,water while separating carbon separation andfor utilization and water.and/or sequestration. We plancontinue to increase our investmentinvest in developing and commercializing future technologies expected to add new capabilities to our platforms’ abilities to deliver hydrogen and long duration hydrogen-based energy storage through our solid oxide technologies, as well as further enhance our existing platforms’ carbon capture solutions.
FuelCell Energy is a global leader in sustainable clean energy technologies that address some of the world’s most critical challenges around energy access, security, safety and environmental stewardship. As a leading global manufacturer of proprietary fuel cell technology platforms, we areFuelCell Energy is uniquely positioned to serve customers worldwide with sustainable products and solutions for industrial and commercial businesses, utilities, governments, and municipalities. Our solutions are designed to enable a world empowered by clean energy, enhancing the quality of life for people around the globe. We target large-scale power users with our megawatt-class installations globally, and currently offer sub-megawatt solutions for smaller power consumers in Europe. To provide a frame of reference, one megawatt is adequate to continually power approximately 1,000 average sized U.S. homes. Our customer base includes utility companies, municipalities, universities, hospitals, government entities/military bases and a variety of industrial and commercial enterprises. Our leading geographic markets are currently the United States and Korea, and we are pursuing opportunities in other countries around the world. Our product offerings drive our mission to help our customers realize their environmental goals, strengthen resiliency, manage energy and other commodity costs, and deliver valuable goods and services to their customers.
Basis of Presentation
The accompanying unaudited consolidated financial statements have been prepared in accordance with the rules and regulations of the Securities and Exchange Commission (“SEC”) regarding interim financial information. Accordingly, they do not contain all of the information and footnotes required by accounting principles generally accepted in the United States of America (“GAAP”) for complete financial statements. In the opinion of management, all normal and recurring adjustments necessary to fairly present the Company’s financial position and results of operations as of and for the three and six months ended April 30,January 31, 2023 and 2022 and 2021 have been included. All intercompany accounts and transactions have been eliminated.
Certain information and footnote disclosures normally included in financial statements prepared in accordance with GAAP have been condensed or omitted. The balance sheet as of October 31, 20212022 has been derived from the audited financial statements at that date, but it does not include all of the information and footnotes required by GAAP for complete financial statements. These financial statements should be read in conjunction with the Company’s financial statements and notes thereto for the fiscal year ended October 31, 2021,2022, which are contained in the Company’s Annual Report on Form 10-K previously filed with the SEC. The results of operations for the interim periods presented are not necessarily indicative of results that may be expected for any other interim period or for the full fiscal year.
Certain reclassifications have been made to the prior year amounts to conform to the presentation for the three months ended January 31, 2023. Interest income for the three months ended January 31, 2022, which was previously included within Other income, net has been reclassified to Interest income in the Consolidated Statement of Operations and Comprehensive Loss.
Principles of Consolidation
The unaudited consolidated financial statements reflect our accounts and operations and those of our subsidiaries in which we have a controlling financial interest. We use a qualitative approach in assessing the consolidation requirement for each of our variable interest entities ("VIEs"), which are tax equity partnerships further described in Note 3. “Tax Equity Financings.” This approach focuses on determining whether we have the power to direct those activities of the tax equity partnerships that most significantly affect their economic performance and whether we have the obligation to absorb losses, or the right to receive benefits, that could potentially be significant to the tax equity partnerships. For all periods presented, we have determined that we are the primary beneficiary in all of our tax equity partnerships. We evaluate our tax equity partnerships on an ongoing basis to ensure that we continue to be the primary beneficiary.
9
Use of Estimates
The preparation of financial statements and related disclosures in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the disclosure
7
of contingent assets and liabilities. Estimates are used in accounting for, among other things, revenue recognition, lease right-of-use assets and liabilities, contract loss accruals, excess, slow-moving and obsolete inventories, product warranty accruals, loss accruals on service agreements, share-based compensation expense, allowance for doubtful accounts, depreciation and amortization, impairment of goodwill and in-process research and development intangible assets, impairment of long-lived assets (including project assets), lease liabilities and right-of-use (“ROU”) assets, and contingencies. Estimates and assumptions are reviewed periodically, and the effects of revisions are reflected in the consolidated financial statements in the period they are determined to be necessary. Due to the inherent uncertainty involved in making estimates, actual results in future periods may differ from those estimates.
Liquidity
Our principal sources of cash have been proceeds from the sale of our products and projects, electricity generation revenues, research and development and service agreements with third parties, sales of our common stock through public equity offerings, and proceeds from debt, project financing and tax monetization transactions, proceeds from the sale of our projects, as well as research and development and service agreements with third parties.transactions. We have utilized this cash to accelerate the commercialization of our solid oxide platforms, develop new capabilities to separate and capture carbon, develop and construct project assets, invest in capital improvements and expansion of our operations, perform research and development on Advanced Technologies, pay down existing outstanding indebtedness, and meet our other cash and liquidity needs.
As of April 30, 2022,January 31, 2023, unrestricted cash and cash equivalents totaled $467.8$315.2 million compared to $432.2$458.1 million as of October 31, 2021.2022. During the three months ended January 31, 2023, the Company invested $75.0 million in United States (U.S.) Treasury Securities which have maturity dates ranging from February 9, 2023 to May 15, 2023. The amortized cost of these U.S. Treasury Securities totaled $75.7 million as of January 31, 2023 compared to $0 as of October 31, 2022 and are classified as Investments - short-term on the Consolidated Balance Sheets.
On June 11, 2021,July 12, 2022, the Company entered into an Open Market Sale Agreement with Jefferies LLC, andB. Riley Securities, Inc., Barclays Capital Inc., BMO Capital Markets Corp., BofA Securities, Inc., Canaccord Genuity LLC, Citigroup Global Markets Inc., J.P. Morgan Securities LLC and Loop Capital Markets LLC (the “Open Market Sale Agreement”) with respect to an at the market offering program under which the Company may, from time to time, offer and sell up to 95.0 million shares of the Company’s common stock having an aggregate offering price of up to $500 million.stock. From the date of the Open Market Sale Agreement through April 30, 2022, approximately 64.0 million shares were sold, resulting in cumulative gross proceeds toJanuary 31, 2023, the Company totalingsold approximately $498.118.5 million before deducting expenses and sales commissions. Cumulative net proceeds to the Company totaled approximately $488.1 million after deducting commissions and offering expenses totaling approximately $10.0 million. During the three and six months ended April 30, 2022 (which periods are included in the broader period described in the preceding two sentences), approximately 19.9 million shares were sold under the Open Market Sale Agreement at an average salessale price of $6.07$3.63 per share, resulting in gross proceeds of $120.8approximately $67.2 million before deducting expenses and sales commissions. For the three and six months ended April 30, 2022, net proceeds to the Company totaled approximately $118.3 million after deducting commissions and offering expenses totalingfees. During the quarter ended January 31, 2023, no sales were made under the Open Market Sale Agreement. As of January 31, 2023, approximately $2.4 million.76.5 million shares were available for issuance under the Open Market Sale Agreement. The Company planscurrently intends to use the net proceeds from this offering to accelerate the development and commercialization of our Advanced Technologies products, including ourits product platforms (including, but not limited to, its solid oxide platform,and carbon capture platforms), for project development, formarket development, and internal research and development, to invest in capacity expansion for solid oxide and carbonate fuel cell manufacturing, and for project financing, working capital support, and general corporate purposes. The remaining availability underCompany may also use the Open Market Sale Agreement as of the date of filing ofnet proceeds from this report is approximately $1.9 million.offering to invest in joint ventures, acquisitions, and strategic growth investments and to acquire, license or invest in products, technologies or businesses that complement its business. See Note 13.11. “Stockholders’ Equity and Warrant Liabilities”Equity” for additional information regarding the Open Market Sale Agreement.
We believe that our unrestricted cash and cash equivalents, expected receipts from our contracted backlog, and release of short-term restricted cash less expected disbursements over the next twelve months will be sufficient to allow the Company to meet its obligations for at least one year from the date of issuance of these financial statements.
To date, we have not achieved profitable operations or sustained positive cash flow from operations. The Company’s future liquidity, infor fiscal year 20222023 and in the long-term, will depend on its ability to (i) timely complete current projects in process within budget, (ii) increase cash flows from its generation operating portfolio, including by meeting conditions required to timely commence operation of new projects, operating its generation operating portfolio in compliance with minimum performance guarantees and operating its generation operating portfolio in accordance with revenue expectations, (iii) obtain financing for project construction and manufacturing expansion, (iv) obtain permanent financing for its projects once constructed, (v) increase order and contract volumes, which would lead to additional product sales, service agreements and generation revenues, (vi) obtain funding for and receive payment for research and development under current and future Advanced Technologies contracts, (vii) successfully commercialize its Advanced Technologies platforms, including its solid oxide, hydrogen and carbon capture platforms, (viii) implement capacity expansion for solid oxide product manufacturing, (ix) implement the product cost reductions necessary to achieve profitable operations,
108
profitable operations, (ix)(x) manage working capital and the Company’s unrestricted cash balance and (x)(xi) access the capital markets to raise funds through the sale of debt and equity securities, convertible notes, and other equity-linked instruments.
We are continually assessing different means by which to accelerate the Company’s growth, enter new markets, commercialize new products, and enable capacity expansion. Therefore, from time to time, the Company may consider and enter into agreements for one or more of the following: negotiated financial transactions, minority investments, collaborative ventures, technology sharing, transfer or other technology license arrangements, joint ventures, partnerships, acquisitions or other business transactions for the purpose(s) of geographic or manufacturing expansion and/or new product or technology development and commercialization, including hydrogen production through our carbonate and solid oxide platforms and storage and carbon capture, sequestration and utilization technologies.
Our business model requires substantial outside financing arrangements and satisfaction of the conditions of such arrangements to construct and deploy our projects andto facilitate the growth of our business. The Company has invested capital raised from sales of its common stock to build out its project portfolio. The Company has also utilized and expects to continue to utilize a combination of long-term debt and tax equity financing (e.g., sale-leaseback transactions, partnership flip transactions and partnership transactions)the monetization and/or transfer of eligible investment and production tax credits) to finance its project asset portfolio as these projects commence commercial operations.operations, particularly in light of the passage of the Inflation Reduction Act in August 2022. The Company may also seek to undertake private placements of debt securities of a portfolio of assets to finance its project asset portfolio. The proceeds of any such financing, if obtained, may allow the Company to reinvest capital back into the business and to fund other projects. We may also seek to obtain additional financing in both the debt and equity markets in the future. If financing is not available to us on acceptable terms if and when needed, or on terms acceptable to us or our lenders, if we do not satisfy the conditions of our financing arrangements, if we spend more than the financing approved for projects, if project costs exceed an amount that the Company can finance, or if we do not generate sufficient revenues or obtain capital sufficient for our corporate needs, we may be required to reduce or slow planned spending, reduce staffing, sell assets, seek alternative financing and take other measures, any of which could have a material adverse effect on our financial condition and operations.
Note 2. Recent Accounting Pronouncements
Recently Adopted Accounting Guidance
There is no recently adopted accounting guidance.
Recent Accounting Guidance Not Yet Effective
There is no recent accounting guidance that is not yet effective that is expected to have a material impact on the Company’s financial statements when adopted.effective.
Note 3. Tax Equity Financings
Groton Tax Equity Financing Transaction
The Company closed on a tax equity financing transaction in August 2021 with East West Bancorp, Inc. (“East West Bank”) for the 7.4 MW fuel cell project (the “Groton Project”) located on the U.S. Navy Submarine Base in Groton, CT, also known as the Submarine Force.CT. East West Bank’s tax equity commitment totals $15 million.
This transaction was structured as a “partnership flip”, which is a structure commonly used by tax equity investors in the financing of renewable energy projects. Under this partnership flip structure, a partnership, in this case Groton Station Fuel Cell Holdco, LLC (the “Groton Partnership”), was organized to acquire from FuelCell Energy Finance II, LLC, a wholly-owned subsidiary of the Company, all outstanding equity interests in Groton Station Fuel Cell, LLC (the “Groton Project Company”) which in turn owns the Groton Project and is the party to the power purchase agreement and all project agreements. At the closing of the transaction, the Groton Partnership is owned by East West Bank, holdsholding Class A Units, in the Groton Partnership and Fuel Cell Energy Finance Holdco, LLC, a subsidiary of the Company holds theFuelCell Energy Finance, LLC, holding Class B Units. The acquisition of the Groton Project Company by the Groton Partnership was funded in part by an initial draw from East West Bank and funds contributed downstream to the Groton Partnership by the Company. The initial closing occurred on August 4, 2021, upon the satisfaction of certain conditions precedent (including the receipt of an appraisal and confirmation that the Groton Project would be eligible for the investment tax credit under Section 48 of the Internal Revenue Code of 1986, as amended). In connection with the initial closing, the Company was able to drawdrew down $3.0 million, of which approximately $0.8 million was used to pay closing costs including appraisal fees, title insurance expenses and legal and consulting fees. The Company is eligible to draw the remaining amount of the commitment,
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Under the original terms of the Company’s agreement with East West Bank, the Company would have been eligible to draw the remaining amount of the commitment, approximately $12 million, once the Groton Project achieves commercial operation. In addition, under the original terms of the Company’s agreement with East West Bank, the Groton Project had a required commercial operations deadline of October 18, 2021. The significance of the commercial operations deadline is that, if commercial operations were not achieved by such deadline, East West Bank would have the option to require an amount equal to 101% of its investment to be returned. East West Bank granted several extensions of the commercial operations deadline, which collectively extended the deadline to May 15, 2022, in exchange for the Company’s agreement to pay fees of $0.4 million in the aggregate.
On July 7, 2022, the Company and East West Bank amended their tax equity financing agreement and extended the commercial operations deadline to September 30, 2022. In addition, in the July 7, 2022 amendment to the tax equity financing agreement, the terms of East West Bank’s remaining investment commitment of $12.0 million were modified such that East West Bank will contribute $4.0 million on each of the first, second and third anniversaries of the Groton Project achieving commercial operations, rather than contributing the full $12.0 million when the Groton Project achieves commercial operations. Such contributions are subject to certain customer conditions precedent, including a third-party certification by an independent engineer that the plant is operating in conformance with the amended and restated power purchase agreement. When such fundscontributions are drawn down,made by East West Bank, the funds will be distributed upstream to the Company, as a reimbursement of prior construction costs incurred by the Company. In conjunction with this amendment, the Company agreed to pay aggregate fees of $0.5 million (which are inclusive of the fees from the previous extensions described above), which were payable by the Company upon commencement of commercial operations of the plant.
On October 4, 2022, the Company and East West Bank further amended their tax equity financing agreement to extend the deadline by which commercial operations were to be achieved at the Groton Project from September 30, 2022 to November 30, 2022. In addition, modifications to the Groton Project documents between Connecticut Municipal Electric Energy Cooperative (“CMEEC”) and the Company as a result of the agreement between those parties to commence operations at less than 7.4 MW required the approval of East West Bank as part of East West Bank’s rights under the agreement between East West Bank and the Company. On December 16, 2022, the Company and CMEEC agreed that, for all purposes, the commercial operations date had occurred, and, accordingly, East West Bank no longer had a right to have its investment returned as a result of the Company’s failure to achieve commercial operations in a timely fashion, and this investment became a non-redeemable noncontrolling interest as of December 16, 2022. In addition, on December 16, 2022, the Company paid the aggregate fees of $0.5 million described above to East West Bank.
On December 16, 2022, the Company declared and, per the terms of the Amended and Restated Power Purchase Agreement between the Company and CMEEC entered into on that date (the “Amended and Restated PPA”), CMEEC agreed that the Groton Project is commercially operational at 6 MW. As of December 16, 2022, the Groton Project is reported as a part of the Company’s generation operating portfolio. The Amended and Restated PPA allows the Company to operate the plants at a reduced output of approximately 6 MW while a Technical Improvement Plan (“TIP”) is implemented over the next year with the goal of bringing the platform to its rated capacity of 7.4 MW by December 31, 2023. In conjunction with entering into the Amended and Restated PPA, the Navy also provided its authorization to proceed with commercial operations at 6 MW. The Company paid CMEEC an amendment fee of $1.2 million and is incurring and will continue to incur performance guarantee fees under the Amended and Restated PPA as a result of operating at an output below 7.4 MW during implementation of the TIP. Although the Company believes it will successfully implement the TIP and bring the plants up to their nominal output of 7.4 MW by December 31, 2023, no assurance can be provided that such work will be successful. In the event that the plants do not reach an output of 7.4 MW by December 31, 2023, the Amended and Restated PPA will continue in effect, and the Company will be subject to ongoing performance guarantee fees as set forth in the Amended and Restated PPA.
With the declaration of commercial operations, East West Bank’s investment in the project was reclassified, as of December 16, 2022, from a redeemable noncontrolling interest to non-redeemable noncontrolling interests within the Total equity section of the Consolidated Balance Sheet.
Under most partnership flip structures, tax equity investors agree to receive a minimum target rate of return, typically on an after-tax basis. Prior to receiving a contractual rate of return or a date specified in the contractual arrangements, East West Bank will receive substantially all of the non-cash value attributable to the Groton Project, which includes accelerated depreciation and Section 48(a) investment tax credits; however, the Company will receive a majority of the cash distributions (based on the operating income of the Groton Project), which are paid quarterly. After East West Bank receives its contractual rate of return, the Company will receive approximately 95% of the cash and tax allocations. The
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Company (through a separate wholly owned entity) may enter into a back leverage debt financing transaction and use the cash distributions from the Groton Partnership to service the debt.
We have determined we are the primary beneficiary in the Groton Partnership for accounting purposes as a Variable Interest Entity (“VIE”) under GAAP. We have considered the provisions within the financing-related agreements (including the limited liability company agreement for the Groton Partnership) which grant us power to manage and make decisions affecting the operations of the Groton Partnership. We consider the rights granted to East West Bank under the agreements to be more protective in nature than participatory. Therefore, we have determined under the power and benefits criterion of Accounting Standards Codification (“ASC”) 810, Consolidations that we are the primary beneficiary of the Groton Partnership. As the primary beneficiary, we consolidate the financial position, results of operations and cash flows of the Groton Partnership in our consolidated financial statements, and all intercompany balances and transactions between us and the Groton Partnership are eliminated. We recognized East West Bank’s share of the net assets of the Groton Partnership as redeemable noncontrolling interests in our Consolidated Balance Sheets. East West Bank’s share of the net assets is considered as a redeemable noncontrolling interest due to the conditional withdrawal right under which, if events outside the control of the Company occur, (such as the failure to meet the commercial operation deadline for the Groton Project, which failure occurred on May 15, 2022), East West Bank has the ability to force the Company to redeem its interest in the Groton Partnership. East West Bank has not confirmed its intent to redeem its interest. The income or loss allocations reflected in our Consolidated Statements of Operations and Comprehensive Loss may create volatility in our reported results of operations, including potentially changing net loss attributable to stockholders to net income attributable to stockholders, or vice versa, from quarter to quarter. OnceSince the Groton Project isbecame operational during the three months ended January 31, 2023, we willhave begun to allocate profits and losses to noncontrolling interests under the hypothetical liquidation at book value ("HLBV") method. HLBV is a balance sheet-oriented approach for applying the equity method of accounting when there is a complex structure, such as the partnership flip structure. For the three months ended January 31, 2023, the net loss attributable to noncontrolling interests totaled $2.9 million. There were no amounts allocated to noncontrolling interest for the three months and six months ended April 30,January 31, 2022 for the Groton Partnership.
Yaphank Tax Equity Financing Transaction
The Company closed on a tax equity financing transaction in November 2021 with Renewable Energy Investors, LLC (“REI”), a subsidiary of Franklin Park Infrastructure, LLC, for the 7.4 MW fuel cell project (the “LIPA Yaphank Project”) located in Yaphank Long Island. REI’s tax equity commitment totaled $12.4 million.
This transaction was structured as a “partnership flip,” which is a structure commonly used by tax equity investors in the financing of renewable energy projects. Under this partnership flip structure, a partnership, in this case YTBFC Holdco, LLC (the “Yaphank Partnership”), was organized to acquire from FuelCell Energy Finance II, LLC, a wholly-owned subsidiary of the Company, all outstanding equity interests in Yaphank Fuel Cell Park, LLC which in turn owns the LIPA Yaphank Project and is the party to the power purchase agreement and all project agreements. REI holds Class A Units in the Yaphank Partnership and a subsidiary of the Company holds the Class B Units. The initial funding occurred on December 13, 2021, upon the satisfaction of certain conditions precedent (including the receipt of an appraisal and confirmation that the LIPA Yaphank Project would be eligible for the investment tax credit (“ITC”) under Section 48 of the Internal Revenue Code of 1986, as amended).2021. In connection with the initial closing, the Company was able to draw down approximately $3.2 million, of which approximately $0.4 million was used to pay closing costs, including title insurance expenses and legal and consulting fees. The Company drew down the remaining amount of the commitment, approximately $9.2 million, in December 2021 and January 2022, after the LIPA Yaphank Project achieved commercial operation. These proceeds were partially offset by legal and advisory fees of approximately $0.4 million.
The Company determined during the second quarter of fiscal year 2022 that there was an overpayment by REI of the Class A Member Capital Contribution of $0.5 million and as such the Company refunded this amount back to REI, reducing the
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REI tax equity commitment to $11.9 million. During the three and six months ended April 30, 2022,January 31, 2023, the Company made a priority return distributiondistributions to REI of $0.1 million which waswere calculated at a 2.73% annual interest rate ofon invested tax equity capital. There were no priority return distributions to REI during the three months ended January 31, 2022.
Under a partnership flip structure, tax equity investors agree to receive a minimum target rate of return, typically on an after-tax basis. Prior to receiving a contractual rate of return or a date specified in the contractual arrangements, REI will receive substantially all of the non-cash value attributable to the LIPA Yaphank Project, which includes accelerated depreciation and Section 48(a) investment tax credits; however, the Company will receive a majority of the cash distributions (based on the operating income of the LIPA Yaphank Project), which are paid quarterly. After REI receives its contractual rate of return, the Company will receive approximately 95% of the cash and tax allocations. The Company may enter into a back leverage debt financing transaction and use the cash distributions from the Yaphank Partnership to service the debt.
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Under this partnership flip structure, after the fifth anniversary following achievement of commercial operations, we have an option to acquire all of the equity interests that REI holds in the Yaphank Partnership starting after REI receives its contractual rate of return (the anticipated “flip” date) after the LIPA Yaphank Project is operational. If we exercise this option, we will be required to pay the greater of the following: (i) the fair market value of REI's equity interest at the time the option is exercised or (ii) an amount equal to 10.3% of REI’s capital contributions. This option payment is to be grossed up for federal taxes if it exceeds the tax basis of the Yaphank Partnership Class A Units.
We are the primary beneficiary in the Yaphank Partnership for accounting purposes as a VIE under GAAP. We have considered the provisions within the financing-related agreements (including the limited liability company agreement for the Yaphank Partnership) which grant us power to manage and make decisions affecting the operations of the Yaphank Partnership. We consider that the rights granted to REI under the agreements to be more protective in nature rather than participatory. Therefore, we have determined under the power and benefits criterion of ASC 810, Consolidations that we are the primary beneficiary of the Yaphank Partnership. As the primary beneficiary, we consolidate the financial position, results of operations and cash flows of the Yaphank Partnership in our consolidated financial statements, and all intercompany balances and transactions between us and the Yaphank Partnership are eliminated. We recognized REI’s share of the net assets of the Yaphank Partnership as noncontrolling interests in our Consolidated Balance Sheets. The income or loss allocations reflected in our Consolidated Statements of Operations and Comprehensive Loss may create volatility in our reported results of operations, including potentially changing net loss attributable to stockholders to net income attributable to stockholders, or vice versa, from quarter to quarter. We allocate profits and losses to REI’s noncontrolling interest under the HLBV method. HLBV is a balance sheet-oriented approach for applying the equity method of accounting when there is a complex structure, such as the partnership flip structure. For the three months and six months ended April 30,January 31, 2023 and 2022, net income (loss) attributable to noncontrolling interestsinterest for the Yaphank Partnership totaled $0.1$0.4 million and $(5.4)$(5.5) million, respectively.
During the preparation of the financial statements for the quarterly period ended April 30, 2022, the Company identified a misstatement in the Consolidated Balance Sheet as of January 31, 2022 related to the tax equity financing transaction for the LIPA Yaphank Project. In the financial statements issued for the quarterly period ended January 31, 2022, the REI tax equity commitment was incorrectly categorized as a Redeemable noncontrolling interest which totaled $12.4 million. The amount should have been classified as a Noncontrolling interest within Equity since the conditional withdrawal period expired upon the LIPA Yaphank Project achieving commercial operation in December 2021. The Company evaluated this misstatement based on the guidance provided by the SEC’s Staff Accounting Bulletin99, Materiality, and determined that its impact was not material to the Company’s previously issued interim financial statements, and accordingly, no prior period financial statements have been restated. The Company corrected the classification prospectively in the Consolidated Balance Sheet as of April 30, 2022 and the Consolidated Statement of Changes in Equity as of April 30, 2022.
Note 4. Revenue Recognition
Contract Balances
Contract assets as of April 30, 2022January 31, 2023 and October 31, 20212022 were $25.7 million ($12.0 million long-term) and $20.7 million and $20.5($9.7 million long-term), respectively. The contract assets relate to the Company’s rights to consideration for work performedcompleted but not yet billed. These amounts are included on a separate line item as Unbilled receivables, for amounts expected to be billed within one year from the balance sheet date, and balances expected to be billed later than one year from the balance sheet date are included within Other assets on the accompanying Consolidated Balance Sheets. The net change in contract assets represents amounts recognized as revenue offset by customer billings.
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Contract liabilities as of April 30, 2022 and October 31, 2021 were $44.2 million and $36.7 million, respectively. The contract liabilities relate to the advance billings to customers for services that will be recognized over time and in some instances for deferred revenue relating to license performance obligations that will be recognized at a future point in time. The Company discontinued revenue recognition of the deferred license revenue related to the POSCO Energy License Agreements in July 2020 given the then pending arbitrations. During the first quarter of fiscal year 2022, $22.2 million related to the POSCO Energy License Agreements was recharacterized from deferred revenue to customer deposits within Long-term deferred revenue and customer deposits on the accompanying Consolidated Balance Sheets.
The net change in contract liabilities represents customer billings offset by revenue recognized.
Contract modification
As a result of the settlement reached with POSCO Energy Co., Ltd. (“POSCO Energy”) (see Note 19. “Commitments and Contingencies” for further background), the Company evaluated the license agreements with POSCO Energy as well as all of the terms of the settlement agreement with POSCO Energy, which was effective December 20, 2021 (the “Settlement Agreement”). As part of this analysis, the Company considered the accounting surrounding the execution of the Settlement Agreement, reviewed all elements related to the license agreements with POSCO Energy and the Settlement Agreement and considered any potential contingencies in the license agreements and whether any proceeds were related to the litigation settlement.
Under the terms of the Settlement Agreement, the Company agreed that the license agreements are not terminated, but instead are deemed to be amended such that POSCO Energy and its subsidiary, Korea Fuel Cell Co., Ltd. (“KFC”, and with POSCO Energy, collectively, “PE Group”), only have the right (i) to provide maintenance and repair services to PE Group’s existing customers on existing molten carbonate power generation and thermal projects under long-term service agreements currently in force as well as long-term service agreements that have expired and are pending renewal as of the settlement date (collectively, “Existing LTSAs”), (ii) to supply replacement modules purchased from the Company only for their existing customers for existing molten carbonate power generation and thermal projects under Existing LTSAs and (iii) to own, operate and maintain all facilities and factories solely for the purposes set forth in (i) and (ii) above (collectively, the “Right to Service License”) and further agreed to sell modules with a service warranty pursuant to a module sales agreement to be negotiated by the parties after execution of the Settlement Agreement. As such, the Company has considered the execution of the Settlement Agreement to be a contract modification as it results in a change in both the scope and price of a contract with a customer. Therefore, the Company will account for such modification under the contract modification guidance included within ASC 606 (Revenue from Contracts with Customers). Further, the Company noted that none of the parties to the Settlement Agreement specifically acknowledged any payment of damages or reimbursement of any costs related to the matters settled under the Settlement Agreement, which supports the conclusion that the overall settlement is a form of contract modification. Additionally, the transaction price allocated to the modified contract does not exceed the stand-alone selling prices (“SSP”) of the performance obligations under the modified contract (i.e., there is no indication of a premium that would indicate that a portion of the transaction price relates to something other than the promised goods or services).
The Company has identified 2 revenue elements of the Settlement Agreement related to module sales which include the sale of the module and a performance guarantee. The Company assessed the SSP of the modules utilizing a cost-plus margin approach to arrive at $3.0 million per module which will be recognized upon title transfer consistent with the Company’s established revenue recognition policies. The Company is also providing a performance guarantee for up to seven years with each module to cover any annual output penalty that would need to be paid by PE Group to a customer. The Company evaluated this performance guarantee, determined that $0.67 million per module is considered to be variable consideration and recorded $3.9 million as variable consideration based upon the sale of 6 modules during the three and six months ended April 30, 2022. This variable consideration will be recognized as revenue if it is determined that there are no amounts due under the performance guarantee. In its analysis, the Company determined that it is probable that PE Group will exercise its option to purchase an additional 14 modules (with a performance guarantee) beyond the firm order of 20 modules, to which it is contractually committed. Given that the license rights for which the Company was previously recognizing revenue are no longer in place and the Company now has a new revenue stream from the enhanced warranty, the $22.2 million of deferred license revenue has been recharacterized as a customer deposit, of which $3.9 million was recorded as variable consideration within Long-term debt and other liabilities on the accompanying Consolidated Balance Sheets. The Company will monitor the variable consideration based on the performance of the modules and make adjustments as necessary.
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EMTEC Joint Development Agreement
Effective as of October 31, 2019, the Company entered into a Joint Development Agreement (as amended, the “EMTEC Joint Development Agreement”) with ExxonMobil Technology and Engineering Company (formerly known as ExxonMobil Research and Engineering Company) (“EMTEC”), pursuant to which the Company has engaged in exclusive research and development efforts with EMTEC to evaluate and develop new and/or improved carbonate fuel cells to reduce carbon dioxide emissions from industrial and power sources, in exchange for (i) payment by EMTEC of certain fees and costs (including research costs of up to $45 million) as well as certain milestone-based payments, and (ii) certain licenses.
In Amendment No. 1 to the EMTEC Joint Development Agreement (“Amendment No. 1”), which was executed on October 29, 2021 and effective as of October 31, 2021, the Company and EMTEC agreed, among other things, to extend the term of the EMTEC Joint Development Agreement for an additional six months, ending on April 30, 2022. Amendment No. 1 allowed for the continuation of research intended to enable incorporation of design improvements to Company fuel cell design in order to support a decision to use the improvements in a potential future demonstration of the technology for capturing carbon at ExxonMobil’s Rotterdam refinery in The Netherlands (such demonstration, the “Rotterdam Project”) and provided additional time to achieve the first milestone under the EMTEC Joint Development Agreement.
In a related letter agreement between the Company and EMTEC dated as of October 28, 2021 and executed on October 29, 2021 (the “Letter Agreement”), the Company agreed to invest with EMTEC in the Rotterdam Project, should EMTEC move forward with the Rotterdam Project. In the Letter Agreement, the Company agreed that, if (i) the Company achieves the first milestone under the EMTEC Joint Development Agreement (which the Company achieved in the first quarter of fiscal year 2022, resulting in a $5.0 million payment to the Company which the Company received in the second quarter of fiscal year 2022) and (ii) EMTEC and the Company execute a contractual agreement to proceed with the Rotterdam Project (which has not occurred), then at EMTEC’s option, the Company will either make an investment in the amount of $5.0 million in the Rotterdam Project or discount EMTEC’s purchase of the Company’s fuel cell module and detailed engineering design, as agreed to by the parties, required for the Rotterdam Project by said amount.
On April 29, 2022, the Company and EMTEC entered into Amendment No. 2 (“Amendment No. 2”) to the EMTEC Joint Development Agreement which was effective as of April 30, 2022 and which increased the maximum amount of research costs to be reimbursed by EMTEC from $45.0 million to $50.0 million and extended the term an additional eight months, ending December 31, 2022 (unless terminated earlier).
During the six months ended April 30, 2022, the Company achieved the first technical milestone under the EMTEC Joint Development Agreement and received payment of $5.0 million. The Company has not recognized revenue in connection with this milestone achievement as a result of its agreement, in the Letter Agreement described above, to either make a $5.0 million investment in the Rotterdam Project or discount EMTEC’s purchase of the Company’s fuel cell module and detailed engineering design for the Rotterdam Project by $5.0 million, should the Company enter into a contract with EMTEC to proceed with the Rotterdam Project. The Company will continue to evaluate revenue recognition of this milestone achievement as project negotiations with ExxonMobil (or a subsidiary thereof) evolve.
Remaining Performance Obligations
Remaining performance obligations are the aggregate amount of total contract transaction price that is unsatisfied or partially unsatisfied. As of April 30, 2022, the Company’s total remaining performance obligations were: $60.2 million for product revenue, $121.3 million for service agreements, and $35.4 million for Advanced Technologies contracts in the aggregate. Service revenue in periods in which there are no module exchanges is expected to be relatively consistent from period to period, whereas module exchanges will result in an increase in revenue when exchanges occur.
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Note 5. Accounts Receivable, Net and Unbilled Receivables
Accounts receivable, net and Unbilled receivables as of April 30, 2022 and October 31, 2021 consisted of the following (in thousands):
| | | | | | |
| | April 30, | | October 31, | ||
|
| 2022 |
| 2021 | ||
Commercial Customers: | | | | | | |
Amount billed | | $ | 10,881 | | $ | 13,854 |
Unbilled receivables (1) | | | 8,591 | | | 7,175 |
| | | 19,472 | | | 21,029 |
Advanced Technologies (including U.S. government(2)): | | | | | | |
Amount billed | | | 4,585 | | | 876 |
Unbilled receivables | | | 1,614 | | | 1,749 |
| | | 6,199 | | | 2,625 |
Accounts receivable, net and unbilled receivables | | $ | 25,671 | | $ | 23,654 |
We bill customers for power platform and power platform component sales based on certain contractual milestones being reached. We bill service agreements based on the contract price and billing terms of the contracts. Generally, our Advanced Technologies contracts are billed based on actual revenues recorded, typically in the subsequent month. Some Advanced Technologies contracts are billed based on contractual milestones or costs incurred. Unbilled receivables relate toThe net change in contract assets represents amounts recognized as revenue recognized onoffset by customer contracts that have not been billed.billings.
The Company had 0 allowance for doubtful accountsContract liabilities as of April 30, 2022January 31, 2023 and October 31, 2021. Uncollectible accounts receivable, including unbilled receivables, are charged against2022 were $7.4 million and $25.4 million, respectively. The contract liabilities relate to the allowanceadvance billings to customers for doubtful accounts when all collection efforts have failed and it is deemed unlikelyservices that the amount will be recovered or ifrecognized over time.
The net change in contract liabilities represents customer billings offset by revenue recognized.
Contract modification
As previously disclosed, the Company calculatesentered into a Settlement Agreement (the “Settlement Agreement”) with POSCO Energy Co., Ltd. (“POSCO Energy”) and its subsidiary, Korea Fuel Cell Co., Ltd. (“KFC”) in fiscal year 2022. The Settlement Agreement included an option to purchase an additional 14 modules (in addition to the 20 modules which were purchased by KFC during fiscal year 2022). The option was not exercised as of the expiration date of December 31, 2022 and as a result, the Company recognized $9.1 million of product revenue during the three months ended January 31, 2023 which represents the consideration allocated to the material right had the option been exercised.
Advanced Technologies Revenue - EMTEC Joint Development Agreement
On December 19, 2022, the Company and ExxonMobil Technology and Engineering Company (formerly known as ExxonMobil Research and Engineering Company) (“EMTEC”) entered into Amendment No. 3 to the Joint Development
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Agreement between the Company and EMTEC, effective as of December 1, 2022 (such amendment, “Amendment No. 3” and such agreement, as amended, the “EMTEC Joint Development Agreement”). In Amendment No. 3, the Company and EMTEC agreed to further extend the term of the EMTEC Joint Development Agreement such that it will end on August 31, 2023 (unless terminated earlier) and to further increase the maximum amount of contract consideration to be reimbursed by EMTEC from $50.0 million to $60.0 million. Amendment No. 3 is intended to (i) allow for continuation of research that would enable the parties to finalize data collection in support of the project gate decision to use the developed technology in a Company fuel cell module demonstration for capturing carbon at ExxonMobil’s Rotterdam facility, (ii) allow for the continuation of the development, engineering and mechanical derisking of the Generation 2 Technology fuel cell module prototype, and (iii) allow for studying the manufacturing scale-up and cost reduction of a commercial Generation 2 Technology fuel cell carbon capture facility.
Remaining Performance Obligations
Remaining performance obligations are the aggregate amount of total contract transaction price that is unsatisfied or partially unsatisfied. As of January 31, 2023, the Company’s total remaining performance obligations were: $99.9 million for service agreements and $26.8 million for Advanced Technologies contracts in the aggregate. Service revenue in periods in which there are no module exchanges is expected credit loss estimates based upon forward-looking information.to be relatively consistent from period to period, whereas module exchanges will result in an increase in revenue when exchanges occur.
Note 5. Investments – Short-Term
On November 14, 2022, the Company invested $75.0 million to purchase U.S. Treasury Securities. The U.S. Treasury Securities have maturity dates ranging from February 9, 2023 to May 15, 2023. We have classified the U.S. Treasury Securities as held-to-maturity and recorded them at amortized cost. The following table summarizes the amortized cost basis and fair value (based on quoted market prices) at January 31, 2023.
| | | | | | | | | |
| | Amortized | | Gross unrealized | | Gross unrealized | | ||
|
| cost |
| gains | | losses | Fair value | ||
U.S. Treasury Securities | | | | | | | | | |
As of January 31, 2023 | | $ | 75,652 | $ | — | $ | (24) | $ | 75,628 |
The contractual maturities of investments are within one year and the weighted average yield to maturity is 4.36%.
Note 6. Inventories
Inventories (short(current and long-term) as of April 30, 2022January 31, 2023 and October 31, 20212022 consisted of the following (in thousands):
| | | | | | | | | | | | |
| | April 30, | | October 31, | | January 31, | | October 31, | ||||
|
| 2022 |
| 2021 |
| 2023 |
| 2022 | ||||
Raw materials | | $ | 28,215 | | $ | 25,968 | | $ | 39,395 | | $ | 30,624 |
Work-in-process (1) | | | 59,249 | | | 45,692 | | | 69,330 | | | 67,834 |
Inventories | | | 87,464 | | | 71,660 | | | 108,725 | | | 98,458 |
Inventories – short-term | | | (82,878) | | | (67,074) | ||||||
Inventories – current | | | (101,176) | | | (90,909) | ||||||
Inventories – long-term (2) | | $ | 4,586 | | $ | 4,586 | | $ | 7,549 | | $ | 7,549 |
(1) | Work-in-process includes the standard components of inventory used to build the typical modules or module components that are intended to be used in future project asset construction or power plant orders or for use under the Company’s service agreements. Included in work-in-process as of |
(2) | Long-term inventory includes modules that are contractually required to be segregated for use as exchange modules for specific project assets. |
Raw materials consist mainly of various nickel powders and steels, various other components used in producing cell stacks and purchased components for balance of plant. Work-in-process inventory is comprised of material, labor, and overhead costs incurred to build fuel cell stacks and modules, which are subcomponents of a power platform.
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The Company incurred costs associated with excess plant capacity and manufacturing variances of $2.5 million and $1.3 million for the three months ended April 30, 2022 and 2021, respectively, and $4.7 million and $3.4 million for the six months ended April 30, 2022 and 2021, respectively, which were included within product cost of revenues on the Consolidated Statements of Operations and Comprehensive Loss.
Note 7. Project Assets
Project assets as of April 30, 2022January 31, 2023 and October 31, 20212022 consisted of the following (in thousands):
| | | | | | | | | | | | | | | | |
| | April 30, | | October 31, | | Estimated | | January 31, | | October 31, | | Estimated | ||||
|
| 2022 |
| 2021 |
| Useful Life |
| 2023 |
| 2022 |
| Useful Life | ||||
Project Assets – Operating | | $ | 165,362 | | $ | 116,286 | | 4-20 years | | $ | 211,384 | | $ | 154,736 | | 4-20 years |
Accumulated depreciation | | | (24,268) | | | (19,844) | | | | | (33,403) | | | (29,546) | | |
Project Assets – Operating, net | | | 141,094 | | | 96,442 | | | | | 177,981 | | | 125,190 | | |
Project Assets – Construction in progress | | | 98,770 | | | 126,835 | | 7-20 years | | | 51,933 | | | 107,696 | | 7-20 years |
Project Assets, net | | $ | 239,864 | | $ | 223,277 | | | | $ | 229,914 | | $ | 232,886 | | |
The estimated useful lives of these project assets are 20 years from commencement date for balance of plant (“BOP”) and site construction, and four to seven years for modules. Project assets as of April 30, 2022January 31, 2023 and October 31, 20212022 included 10nine and 9,eight, respectively, completed, commissioned installations generating power with respect to which the Company has a power purchase agreement (“PPA”) with the end-user of power and site host with a net aggregate value of $141.1$178.0 million and $96.4$125.2 million as of April 30, 2022January 31, 2023 and October 31, 2021,2022, respectively. Certain of these assets are the subject of sale-leaseback arrangements with PNC Energy Capital, LLC (“PNC”) and Crestmark Equipment Finance (“Crestmark”). The increase in operating project assets at January 31, 2023 is a result of the inclusion of the Groton Project which became operational during the three months ended January 31, 2023.
Project assets as of April 30, 2022January 31, 2023 and October 31, 20212022 also include installations with carrying values of $98.8$51.9 million and $126.8$107.7 million, respectively, which are being developed and constructed by the Company in connection with projects for which we have entered into PPAs or projects for which we expect to secure PPAs or otherwise recover the asset value and which have not yet been placed in service.
Included in “Construction in progress” is the 2.3 MW Toyota project. It was determined in the fourth quarter of fiscal year 2021 that a potential source of renewable natural gas (“RNG”) at favorable pricing was no longer sufficiently probable and that market pricing for RNG had significantly increased, resulting in the determination that the carrying value of the project asset iswas no longer recoverable. Refer to Note 19.17. “Commitments and Contingencies” for more information regarding fuel risk exposure. While the Company is pursuing alternative sources of RNG, a $2.8 million charge was recorded for the fiscal year ended October 31, 2021 which represents the carrying value of the project asset less the carrying value of inventory components that could be redeployed for alternative use. Charges for the three month and six month periods ended April 30, 2022 were $4.4 million and $7.2 million, respectively. As this project is being constructed, only inventory components that can be redeployed for alternative use are being capitalized. The balance of costs incurred are being expensed as generation cost of revenues.
Project construction costs incurred for long-term project assets are reported as investing activities in the Consolidated Statements of Cash Flows. The proceeds received from the sale and subsequent leaseback of project assets are classified as “Cash flows from financing activities” within the Consolidated Statements of Cash Flows and are classified as a financingfinance obligation within “Current portion of long-term debt” and “Long-term debt and other liabilities” on the Consolidated Balance Sheets (refer to Note 17.15. “Debt” for more information).
Note 8. Goodwill and Intangible Assets
As of April 30, 2022January 31, 2023 and October 31, 2021,2022, the Company had goodwill of $4.1 million and intangible assets of $18.0$17.0 million and $18.7$17.4 million, respectively, that were recorded in connection with the Company’s 2012 acquisition of Versa Power Systems, Inc. (“Versa”) and the 2019 Bridgeport Fuel Cell Project acquisition.
The Versa acquisition intangible asset represents an indefinite-lived in-process research and development intangible asset (“IPR&D”) for cumulative research and development efforts associated with the development of solid oxide fuel cell stationary power generation. Amortization expense for the Bridgeport Fuel Cell Project-related intangible asset for each of the three months ended April 30,January 31, 2023 and 2022 and 2021 was $0.3 million and for each of the six months ended April 30, 2022 and 2021 was $0.6 million.
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The following tables summarize the carrying value of the Company’s intangible assets as of April 30, 2022January 31, 2023 and October 31, 20212022 (in thousands):
| | | | | | | | | | | | | | | | | | |
As of April 30, 2022 |
| Gross Amount |
| Accumulated |
| Net Amount | ||||||||||||
As of January 31, 2023 |
| Gross Amount |
| Accumulated |
| Net Amount | ||||||||||||
In-Process Research and Development | | $ | 9,592 | | $ | — | | $ | 9,592 | | $ | 9,592 | | $ | — | | $ | 9,592 |
Bridgeport PPA | | | 12,320 | | | (3,891) | | | 8,429 | | | 12,320 | | | (4,863) | | | 7,457 |
Total | | $ | 21,912 | | $ | (3,891) | | $ | 18,021 | | $ | 21,912 | | $ | (4,863) | | $ | 17,049 |
| | | | | | | | | | | | | | | | | | |
As of October 31, 2021 |
| Gross Amount |
| Accumulated |
| Net Amount | ||||||||||||
As of October 31, 2022 |
| Gross Amount |
| Accumulated |
| Net Amount | ||||||||||||
In-Process Research and Development | | $ | 9,592 | | $ | — | | $ | 9,592 | | $ | 9,592 | | $ | — | | $ | 9,592 |
Bridgeport PPA | | | 12,320 | | | (3,242) | | | 9,078 | | | 12,320 | | | (4,539) | | | 7,781 |
Total | | $ | 21,912 | | $ | (3,242) | | $ | 18,670 | | $ | 21,912 | | $ | (4,539) | | $ | 17,373 |
Note 9. Other Current Assets
Other current assets as of April 30, 2022 and October 31, 2021 consisted of the following (in thousands):
| | | | | | |
| | April 30, | | October 31, | ||
|
| 2022 |
| 2021 | ||
Advance payments to vendors (1) | | $ | 7,097 | | $ | 4,005 |
Prepaid expenses and other (2) | | | 6,505 | | | 5,172 |
Other current assets | | $ | 13,602 | | $ | 9,177 |
Note 10. Other Assets
Other assets as of April 30, 2022 and October 31, 2021 consisted of the following (in thousands):
| | | | | | |
| | April 30, | | October 31, | ||
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| 2022 |
| 2021 | ||
Long-term stack residual value (1) | | $ | — | | $ | 263 |
Long-term unbilled receivables (2) | | | 10,542 | | | 11,581 |
Other (3) | | | 5,000 | | | 5,154 |
Other assets | | $ | 15,542 | | $ | 16,998 |
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Note 11.9. Accrued Liabilities
Accrued liabilities as of April 30, 2022January 31, 2023 and October 31, 20212022 consisted of the following (in thousands):
| | | | | | | | | | | | |
| | April 30, | | October 31, | | January 31, | | October 31, | ||||
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| 2022 |
| 2021 |
| 2023 |
| 2022 | ||||
Accrued payroll and employee benefits | | $ | 5,035 | | $ | 2,544 | | $ | 4,784 | | $ | 8,534 |
Accrued product warranty cost | | | 247 | | | 72 | | | 426 | | | 537 |
Accrued service agreement and PPA costs | | | 8,934 | | | 9,112 | | | 12,087 | | | 11,340 |
Accrued legal, taxes, professional and other | | | 9,795 | | | 4,371 | | | 3,016 | | | 7,004 |
Accrued liabilities | | $ | 24,011 | | $ | 16,099 | | $ | 20,313 | | $ | 27,415 |
(1) | The |
(2) | The decrease in accrued product warranty cost reflects an adjustment for the removal of 3 months of warranty costs associated with the |
Accrued service agreement costs include loss accruals on service agreements of |
Note 12.10. Leases
The Company enters into operating and finance lease agreements for the use of real estate, vehicles, information technology equipment, and certain other equipment. We determine if an arrangement contains a lease at inception, which is the date on which the terms of the contract are agreed to and the agreement creates enforceable rights and obligations. Operating leases are included in Operating lease right-of-use assets, net, Operating lease liabilities, and Long-term operating lease liabilities in the Company’s Consolidated Balance Sheets. Finance leases are not considered significant to the Company’s Consolidated Balance Sheets or Consolidated Statements of Operations and Comprehensive Loss.
Right-of-use Finance lease right-of-use (“ROU”) assets representof $0.1 million at January 31, 2023 and October 31, 2022 are included in Property, plant and equipment, net in the Company’s rightConsolidated Balance Sheets. Finance lease liabilities of $0.1 million at January 2023 and October 31, 2022 are included in Current portion of long-term debt and Long-term debt and other liabilities in the Company’s Consolidated Balance Sheets.
On January 5, 2023, the Company’s wholly-owned subsidiary, Versa Power Systems Ltd. (“Versa Ltd.”), entered in to usea lease expansion, extension and amending agreement to an underlying asset forexisting building lease that was originally entered into on May 20, 2005. The lease expansion, extension and amending agreement extended the term of the lease termthrough September 30, 2028 and lease liabilities representexpanded the present valuespace to be leased by Versa Ltd. in Calgary, Alberta, Canada to include approximately 48,000 square feet of the Company’s obligation to make lease payments arising from the lease over the lease term at the commencement date of the lease. As most of the Company’s leases do not provide an implicit rate, the Company estimated the incremental borrowing rate based on the information available in determining the present value of lease paymentsadditional space. A ROU asset and used the implicit rate when readily determinable. The Company determined incremental borrowing rates through market sources for secured borrowings including relevant industry rates. The Company’s operating lease ROU assets also include anyliability was recorded for this lease pre-payments and exclude lease incentives. Certainas of the Company’s leases include variable payments, which may vary based upon changes in facts or circumstances after the start of the lease. The Company excludes variable payments from lease ROU assets and lease liabilities, to the extent not considered in-substance fixed, and instead, expenses variable payments as incurred. Variable lease expense and lease expenseJanuary 31, 2023 for short-term contracts are not material components of lease expense. The Company’s leases generally have remaining lease terms of 1 to 26 years, some of which include options to extend leases. The exercise of lease renewal options is at the Company’s sole discretion and the Company’s lease ROU assets and liabilities reflect only the options the Company is reasonably certain that it will exercise. The Company does not have leases with residual value guarantees or similar covenants.
Operating lease expense for each of the three months ended April 30, 2022 and 2021 was $0.4CAD $2.7 million and for each of the six months ended April 30, 2022 and 2021 was $0.8 million. As of April 30, 2022, the weighted average remaining lease term (in years) was approximately 20 years and the weighted average discount rate was 8.3%. Lease payments made during each of the three months ended April 30, 2022 and 2021 were $0.3($2.0 million and during the six months ended April 30, 2022 and 2021 were $0.7 million and $0.6 million, respectively.USD).
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Operating lease expense for each of the three months ended January 31, 2023 and 2022 was $0.3 million and $0.4 million, respectively. As of January 31, 2023, the weighted average remaining lease term (in years) was approximately 17 years and the weighted average discount rate was 6.9%. Lease payments made during the three months ended January 31, 2023 and 2022 were $0.3 million and $0.4 million, respectively.
Undiscounted maturities of operating lease and finance lease liabilities as of April 30, 2022January 31, 2023 were as follows:
| | | | | | | | | | | | |
|
| Operating |
| Finance |
| Operating |
| Finance | ||||
Due Year 1 | | $ | 1,426 | | $ | 51 | | $ | 1,126 | | $ | 49 |
Due Year 2 | | | 914 | | | 37 | | | 1,278 | | | 4 |
Due Year 3 | | | 841 | | | — | | | 1,268 | | | — |
Due Year 4 | | | 765 | | | — | | | 1,295 | | | — |
Due Year 5 | | | 780 | | | — | | | 1,316 | | | — |
Thereafter | | | 13,803 | | | — | | | 13,261 | | | — |
Total undiscounted lease payments | | | 18,529 | | | 88 | | | 19,544 | | | 53 |
Less imputed interest | | | (9,874) | | | (8) | | | (9,484) | | | (7) |
Total discounted lease payments | | $ | 8,655 | | $ | 80 | | $ | 10,060 | | $ | 46 |
Note 13.11. Stockholders’ Equity and Warrant Liabilities
2022 Open Market Sale Agreement
On June 11, 2021,July 12, 2022, the Company entered into an Open Market Sale Agreement with Jefferies LLC, andB. Riley Securities, Inc., Barclays Capital Inc., BMO Capital Markets Corp., BofA Securities, Inc., Canaccord Genuity LLC, Citigroup Global Markets Inc., J.P. Morgan Securities LLC and Loop Capital Markets LLC (the “Agents”“Open Market Sale Agreement”) with respect to an at the market offering program under which the Company may, from time to time, offer and sell up to 95.0 million shares of the Company’s common stock having an aggregate offering price of up to $500 million. stock. Pursuant to the Open Market Sale Agreement, the Company paid the Agent makingpays each saleagent a commission equal to 2.0% of the aggregate gross proceeds it received from sucheach sale of shares made by such Agent of sharesagent under the Open Market Sale Agreement. From the date of the Open Market Sale Agreement through April 30, 2022,January 31, 2023, the Company sold approximately 64.018.5 million shares were sold under the Open Market Sale Agreement at an average salessale price of $7.79 per share, resulting in cumulative gross proceeds of $498.1 million, before deducting expenses and sales commissions. Cumulative net proceeds to the Company totaled approximately $488.1 million after deducting commissions and offering expenses totaling approximately $10.0 million. During the three and six months ended April 30, 2022 (which periods are included in the broader period described in the preceding two sentences), approximately 19.9 million shares were sold under the Open Market Sale Agreement at an average sales price of $6.07$3.63 per share, resulting in gross proceeds of $120.8approximately $67.2 million, before deducting expensessales commissions and sales commissions. For the threefees, and six months ended April 30, 2022, net proceeds to the Company totaledof approximately $118.3$65.4 million after deducting commissions and offering expensesfees totaling approximately $2.4$1.8 million. ThereNo sales were 0 salesmade under the Open Market Sale Agreement during the three monthsquarter ended January 31, 2022.2023.
As of April 30, 2022, the remaining availabilityJanuary 31, 2023, approximately 76.5 million shares were available for issuance under the Open Market Sale Agreement totaled $1.9 million.
Outstanding Warrants
The following table summarizes outstanding warrant activity during the six months ended April 30, 2022:
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The Series C warrants, which were issued in May 2017, had an exercise price of $19.20 per share and a term of five years (expiring in May 2022). The Series C warrants contained provisions regarding adjustments to their exercise price and the number of shares of common stock issuable upon exercise.Agreement.
Note 14.12. Redeemable Preferred Stock
The Company is authorized to issue up to 250,000 shares of preferred stock, par value $0.01 per share, in one or more series, of which 105,875 shares were designated as 5% Series B Cumulative Convertible Perpetual Preferred Stock (“Series B Preferred Stock”) in March 2005.
20
Series B Preferred Stock
As of April 30, 2022,January 31, 2023, the Company had 105,875 shares of Series B Preferred Stock, with a liquidation preference of $1,000.00 per share, authorized for issuance. As of April 30, 2022January 31, 2023 and October 31, 2021,2022, there were 64,020 shares of Series B Preferred Stock issued and outstanding, with a carrying value of $59.9 million. Dividends of $0.8 million were paid in cash during each of the three month periods ended April 30, 2022January 31, 2023 and 2021 and dividends2022.
16
Note 15.13. Loss Per Share
The calculation of basic and diluted loss per share was as follows:
| | | | | | | | | | | | | | | | | | | | |
| | Three Months Ended April 30, | | Six Months Ended April 30, | | Three months ended January 31, | | |||||||||||||
|
| 2022 |
| 2021 |
| 2022 |
| 2021 |
| 2023 | | 2022 | |
| ||||||
Numerator | | | | | | | | | | | | | | | | | | | | |
Net loss attributable to FuelCell Energy, Inc. | | $ | (30,217) | | $ | (18,917) | | $ | (70,841) | | $ | (64,877) | | $ | (18,622) | | $ | (40,624) | | |
Series B preferred stock dividends | | | (800) | | | (800) | | | (1,600) | | | (1,600) | | | (800) | | | (800) | | |
Net loss attributable to common stockholders | | $ | (31,017) | | $ | (19,717) | | $ | (72,441) | | $ | (66,477) | | $ | (19,422) | | $ | (41,424) | | |
Denominator | | | | | | | | | | | | | | | | | | | | |
Weighted average common shares outstanding – basic | | | 372,615,824 | | | 322,500,592 | | | 369,626,543 | | | 317,219,129 | | | 405,803,753 | | | 366,734,739 | | |
Effect of dilutive securities (1) | | | — | | | — | | | — | | | — | | | — | | | — | | |
Weighted average common shares outstanding – diluted | | | 372,615,824 | | | 322,500,592 | | | 369,626,543 | | | 317,219,129 | | | 405,803,753 | | | 366,734,739 | | |
Net loss to common stockholders per share – basic | | $ | (0.08) | | $ | (0.06) | | $ | (0.20) | | $ | (0.21) | | $ | (0.05) | | $ | (0.11) | | |
Net loss to common stockholders per share – diluted (1) | | $ | (0.08) | | $ | (0.06) | | $ | (0.20) | | $ | (0.21) | | $ | (0.05) | | $ | (0.11) | | |
(1) | Due to the net loss to common stockholders in each of the periods presented above, diluted loss per share was computed without consideration to potentially dilutive instruments as their inclusion would have been anti-dilutive. As of |
| | | | | | | | | | | | | | |
| | April 30, | | April 30, | | | January 31, | | January 31, | | ||||
|
| 2022 |
| 2021 | |
| 2023 |
| 2022 | | ||||
May 2017 Offering – Series C Warrants | | | 950,102 | | | 950,102 | | | | - | | | 950,102 | |
Outstanding options to purchase common stock | | | 20,231 | | | 22,388 | | | | 20,231 | | | 22,432 | |
Unvested Restricted Stock Units | | | 3,315,557 | | | 2,817,137 | | | | 7,102,089 | | | 3,276,776 | |
5% Series B Cumulative Convertible Preferred Stock | | | 37,837 | | | 37,837 | | |||||||
5% Series B Cumulative Convertible Perpetual Preferred Stock | | | 37,837 | | | 37,837 | | |||||||
Total potentially dilutive securities | | | 4,323,727 | | | 3,827,464 | | | | 7,160,157 | | | 4,287,147 | |
Note 16.14. Restricted Cash
As of April 30, 2022January 31, 2023 and October 31, 2021,2022, there was $21.8$24.6 million and $28.0$23.0 million, respectively, of restricted cash and cash equivalents pledged as performance security, reserved for future debt service requirements, and reserved for letters of credit for certain banking requirements and contracts. The allocation of restricted cash is as follows (in thousands):
| | | | | | | | | | | | |
| | April 30, | | October 31, | | January 31, | | October 31, | ||||
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| 2022 |
| 2021 |
| 2023 |
| 2022 | ||||
Cash Restricted for Outstanding Letters of Credit (1) | | $ | 4,844 | | $ | 6,478 | | $ | 4,993 | | $ | 4,993 |
Cash Restricted for PNC Sale-Leaseback Transactions (2) | | | 4,191 | | | 5,514 | | | 5,424 | | | 5,010 |
Cash Restricted for Crestmark Sale-Leaseback Transactions (3) | | | 2,891 | | | 2,887 | | | 2,896 | | | 2,894 |
Bridgeport Fuel Cell Park Project Debt Service and Performance Reserves (4) | | | 8,836 | | | 11,937 | | | 9,441 | | | 8,746 |
Other | | | 1,016 | | | 1,183 | | | 1,857 | | | 1,346 |
Total Restricted Cash | | | 21,778 | | | 27,999 | | | 24,611 | | | 22,989 |
Restricted Cash and Cash Equivalents – Short-Term (5) | | | (5,301) | | | (11,268) | | | (4,456) | | | (4,423) |
Restricted Cash and Cash Equivalents – Long-Term | | $ | 16,477 | | $ | 16,731 | | $ | 20,155 | | $ | 18,566 |
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(1) | Letters of credit outstanding as of |
(2) | Long and short-term reserve that is to be used primarily to fund future module exchanges for operating projects falling under the PNC sale leaseback obligations. |
(3) | Long and short-term reserve that is to be used primarily to fund future module exchanges and other performance obligations. |
(4) | Long and short-term reserves for the Bridgeport Fuel Cell Park Project to fund future module exchanges and other performance requirements. |
(5) | Short-term restricted cash and cash equivalents are amounts expected to be released and |
17
Note 17.15. Debt
Debt as of April 30, 2022January 31, 2023 and October 31, 20212022 consisted of the following (in thousands):
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| | April 30, | | October 31, | | January 31, | | October 31, | ||||
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| 2022 |
| 2021 |
| 2023 |
| 2022 | ||||
Connecticut Green Bank Loan | | | 4,800 | | | 4,800 | | $ | 4,800 | | $ | 4,800 |
Connecticut Green Bank Loan (Bridgeport Fuel Cell Project) | | | 3,921 | | | 4,318 | | | 3,294 | | | 3,507 |
Liberty Bank Term Loan Agreement (Bridgeport Fuel Cell Project) | | | 6,424 | | | 7,465 | | | 4,861 | | | 5,382 |
Fifth Third Bank Term Loan Agreement (Bridgeport Fuel Cell Project) | | | 6,424 | | | 7,465 | | | 4,861 | | | 5,382 |
Finance obligation for sale-leaseback transactions | | | 56,446 | | | 56,492 | | | 56,777 | | | 56,625 |
State of Connecticut Loan | | | 8,200 | | | 8,622 | | | 7,559 | | | 7,774 |
Finance lease obligations | | | 80 | | | 102 | | | 46 | | | 57 |
Deferred finance costs | | | (1,346) | | | (1,556) | | | (1,063) | | | (1,152) |
Total debt and financing obligations | | $ | 84,949 | | $ | 87,708 | ||||||
Current portion of long-term debt and financing obligations | | | (9,919) | | | (10,085) | ||||||
Long-term debt and financing obligations | | $ | 75,030 | | $ | 77,623 | ||||||
Total debt and finance obligations | | | 81,135 | | | 82,375 | ||||||
Current portion of long-term debt and finance obligations | | | (13,249) | | | (13,198) | ||||||
Long-term debt and finance obligations | | $ | 67,886 | | $ | 69,177 |
Note 18.16. Benefit Plans
We have stockholder approved equity incentive plans, a stockholder approved Employee Stock Purchase Plan and an employee tax-deferred savings plan. During the six months ended April 30, 2022, the Company’s Board of Directors approved a sub-plan to its 2018 Omnibus Incentive Plan, as amended and restated,plan which isare described in more detail below.
2018 Omnibus Incentive Plan
The Company’s 2018 Omnibus Incentive Plan (as amended and restated from time to time, the “2018 Incentive Plan”) authorizes grants of stock options, stock appreciation rights (“SARs”), restricted stock awards (“RSAs”), restricted stock units (“RSUs”), performance shares, performance units and incentive awards to employees, directors, consultants and advisors. Stock options, RSAs, RSUs and SARs have restrictions as to transferability. Stock option exercise prices are fixed by the Company’s Board of Directors but shall not be less than the fair market value of our common stock on the date of the grant. SARs may be granted in conjunction with stock options. Of the 12,333,333 shares of the Company’s common stock currently authorized to be issued under the 2018 Incentive Plan, 3,556,070 remained available for grant as of January 31, 2023. Of the shares remaining available for grant, the Company has reserved, for potential future grant, up to 2,036,257 performance stock units if maximum performance is achieved.
Long-Term Incentive Plans
The Company’s Board of Directors periodically approves Long Term Incentive Plans which include performance-based awards tied to the Company’s common stock price as well as time-vesting awards. None of the awards granted as part of Long-Term Incentive Plans include any dividend equivalent or other stockholder rights. To the extent the awards are earned, they may be settled in shares or cash of an equivalent value at the Company’s option.
Fiscal Year 2023 Long Term Incentive Plan:
On December 10, 2021,5, 2022, the Company’s Board of Directors approved a Long TermLong-Term Incentive Plan for fiscal year 2023 (the “LTI“FY 2023 LTI Plan”) as a sub-plan consisting of awards made under the 2018 Incentive Plan. The participants in the FY 2023 LTI Plan includeare members of senior management and the Company’s named executive officers (as identified in the definitive proxy statement filed by the Company on February 22, 2022).management. The FY 2023 LTI Plan consists of two award components: (1) relative total shareholder return (“TSR”) performance units, and (2) time-vesting restricted stock units. The performance units granted during the six months ended April 30, 2022 will be earned over the performance period ending on October 31, 2024, but will remain subject to a continued service-based vesting requirement until the third anniversary of the date of grant. The performance measure for the relative TSR performance units is the TSR of the Company relative to the TSR of the Russell 2000 from November 1, 2021 through October 31, 2024. In addition to senior management, the Board of Directors also approved time-based awards to certain salaried employees to promote ownership of the Company’s equity and retention. The time-vesting RSUs granted during the six months ended April 30, 2022 will vest at a rate of one-third of the total number of RSUs on each of the first three anniversaries of the date of grant. None of the awards granted as part of the LTI Plan
1) | Relative Total Shareholder Return (“TSR”) Performance Share Units (“PSU”) awards. The PSUs granted during the three months ended January 31, 2023 will be earned over the performance period ending on October 31, 2025, but will remain subject to a continued service-based vesting requirement until the third anniversary of the date of grant. The performance measure for the relative TSR PSUs is the TSR of the Company relative to the TSR of the Russell 2000 from November 1, 2022 through October 31, 2025. The Compensation Committee established the performance assessment criteria for the relative TSR PSUs as the TSR of the Company relative to the TSR of the Russell 2000, with the award calibration being 100% plus or minus 0.5x the difference between the Company’s TSR and the Russell 2000 Index composite TSR. The award is capped at 200% of the target number of PSUs, and the award is further capped at 100% of the target number of PSUs if the Company’s absolute TSR over the performance period is negative. The Company’s TSR is calculated by subtracting the Company’s beginning |
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stock price (defined as the average closing price of the Company’s common stock over the 60 consecutive trading days ending on October 31, 2022) from the ending stock price (defined as the average closing price of the Company’s common stock over the 60 consecutive trading days ending on October 31, 2025), adding any dividends during the period, and then dividing the result by the Company’s beginning stock price. Given that the performance period is still open, the Company has reserved shares equal to 200% of the target number of PSUs, subject to performance during the remaining performance period as well as vesting based on continued service until December 5, 2025 (the third anniversary of the grant date). |
2) | Time-vesting RSUs. The time-vesting RSUs granted during the three months ended January 31, 2023 will vest at a rate of one-third of the total number of RSUs on each of the first three anniversaries of the date of grant. |
include any dividend equivalent or other stockholder rights. ToOther Equity Incentive Plans
The Company’s 2006 and 2010 Equity Incentive Plans remain in effect only to the extent theof awards are earned, they may be settled in shares or cash of an equivalent value at the Company’s option.
On December 10, 2021, 642,464 time-vesting restricted stock units and 169,026 performance units were awardedoutstanding under the LTI Plan. Should the Company’s share price achieve the 200% performance level, awardees will receive up to 169,026 additional performance units. The performance units were valued based on a Monte-Carlo Simulation, and the estimated fair valueplans as of the 169,026 relative TSR performance units was $11.70 per share. The performance units and time-vesting restricted stock units are expensed over the three-year service period.January 31, 2023.
Share-Based Compensation
Share-based compensation was reflected in the Consolidated Statements of Operations and Comprehensive Loss as follows (in thousands):
| | | | | | | | | | | | | | | | | | | |
| | Three months Ended April 30, | | Six months Ended April 30, | | Three Months Ended January 31, | |||||||||||||
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| 2022 |
| 2021 | | 2022 |
| 2021 |
| 2023 |
| 2022 | | ||||||
Cost of revenues | | $ | 185 | | $ | 141 | | $ | 338 | | $ | 318 | | $ | 331 | | $ | 153 | |
General and administrative expense | | | 1,350 | | | 1,054 | | | 2,528 | | | 2,237 | |||||||
Administrative and selling expense | | | 1,942 | | | 1,178 | | ||||||||||||
Research and development expense | | | 106 | | | 31 | | | 184 | | | 63 | | | 291 | | | 78 | |
| | $ | 1,641 | | $ | 1,226 | | $ | 3,050 | | $ | 2,618 | | $ | 2,564 | | $ | 1,409 | |
Restricted Stock Awards and Restricted Stock Units Including Performance Based AwardsShare Units
The following table summarizes our RSA and RSU activity for the sixthree months ended April 30, 2022:January 31, 2023:
| | | | | | |
Restricted Stock Awards and Units |
| | Shares |
| Weighted-Average Fair Value | |
Outstanding as of October 31, 2021 | | | 2,543,541 | | $ | 5.08 |
Granted – performance units | | | 169,026 | | | 11.70 |
Granted – time-vesting restricted stock units | | | 652,597 | | | 9.20 |
Vested | | | (88,388) | | | 3.54 |
Outstanding as of January 31, 2022 | | | 3,276,776 | | $ | 6.27 |
Granted – time-vesting restricted stock units | | | 85,804 | | | 5.52 |
Vested | | | (25,464) | | | 9.57 |
Forfeited | | | (21,559) | | | 9.05 |
Outstanding as of April 30, 2022 | | | 3,315,557 | | $ | 6.21 |
| | | | | | |
Restricted Stock Units |
| | Shares |
| Weighted-Average Fair Value | |
Outstanding as of October 31, 2022 | | | 2,520,881 | | $ | 7.93 |
Granted - PSUs | | | 1,124,953 | | | 5.50 |
Granted - time-vesting RSUs | | | 3,781,370 | | | 3.41 |
Vested | | | (261,059) | | | 7.03 |
Forfeited | | | (64,056) | | | 7.55 |
Outstanding as of January 31, 2023 | | | 7,102,089 | | $ | 5.18 |
On December 5, 2022, 2,249,890 RSUs were awarded to senior management under the FY 2023 LTI Plan, which included 1,124,953 PSUs and 1,124,937 time-based vesting RSUs. The PSUs were valued based on a Monte-Carlo Simulation, and the estimated fair value of the relative TSR PSUs was $5.50 per share. The PSUs and time-based vesting RSUs are expensed over the three-year performance period.
In addition to the awards granted to senior management, during the first quarter of fiscal year 2023, the Board of Directors also granted a total of 2,656,433 time-based vesting RSUs to certain salaried employees to promote ownership of the Company’s equity and retention. The time-based vesting RSUs granted during the first quarter of fiscal year 2023 vest at a rate of one-third of the total number of RSUs granted on each of the first three anniversaries of the date of grant.
PSUs are issued assuming participants achieve 100% target performance. The Company also reserves additional shares assuming the maximum performance targets are met.
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Note 19.17. Commitments and Contingencies
Service Agreements
Under the provisions of its service agreements, the Company provides services to maintain, monitor, and repair customer power plants to meet minimum operating levels. Under the terms of such service agreements, the particular power plant must meet a minimum operating output during defined periods of the term. If minimum output falls below the contract requirement, the Company may be subject to performance penalties and/or may be required to repair or replace the customer’s fuel cell module(s).
Power Purchase Agreements
Under the terms of the Company’s PPAs, customers agree to purchase power or other values streams delivered such as hydrogen, steam, water, and/or carbon from the Company’s fuel cell power plantsplatforms at negotiated rates. Electricity rates are generally a function of the customers’ current and estimated future electricity pricing available from the grid. As owner or lessee of the power plants,platforms, the Company is responsible for all operating costs necessary to maintain, monitor and repair the power plants.platforms. Under certain agreements, the Company is also responsible for procuring fuel, generally natural gas or biogas, to run the power plants.platforms. In addition, under the terms of some of the PPAs, the Company may be subject to a performance penalty if the Company does not meet certain performance requirements.
Project Fuel Exposure
Certain of our PPAs for project assets in our generation operating portfolio and project assets under construction expose us to fluctuating fuel price risks as well as the risk of being unable to procure the required amounts of fuel and the lack of
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alternative available fuel sources. We seek to mitigate our fuel risk using strategies including: (i) fuel cost reimbursement mechanisms in our PPAs to allow for pass through of fuel costs (full or partial) where possible, which we have done with our 14.9 MW operating project in Bridgeport, CT and our 7.4 MW project under construction in Hartford, CT; (ii) procuring fuel under fixed price physical contracts with investment grade counterparties, which we have done for twenty years for our Tulare BioMAT project and the initial seven years of the eighteen year PPA for our LIPA Yaphank NY project;Project; and (iii) potentially entering into future financial hedges with investment grade counterparties to offset potential negative market fluctuations. The Company does not take a fundamental view on natural gas or other commodity pricing and seeks commercially available means to reduce commodity exposure.
WeThere are currently have 3three projects in development with fuel sourcing risk, which are the Toyota project, which requires procurement of RNG, and our Derby, CT 14.0 MW and 2.8 MW projects, both of which require natural gas for which there is no pass throughpass-through mechanism. Fuel sourcing and risk mitigation strategies for all 3three projects are being assessed and will be implemented as project operational dates become firm. Such strategies may require cash collateral or reserves to secure fuel or related contracts for these 3three projects. If the Company is unable to secure fuel on favorable economic terms, it may result in impairment charges to thesethe Derby project assets.assets and further charges for the Toyota project asset.
While the Company is pursuing alternative sources of RNG for the Toyota project, charges are being recorded to generation cost of salesgeneration revenues for any project expenditure which mayexpenditures currently expected to be unrecoverable. To date, $10.0$32.0 million in charges have been recorded, which includes $7.1 million and $2.8 million in charges for the fiscal year ended October 31, 2021 and $7.2 million in charges for the sixthree months ended April 30, 2022.January 31, 2023 and 2022, respectively. As of April 30, 2022,January 31, 2023, the carrying value of the Toyota project on the Consolidated Balance Sheet totaled $20.7$22.0 million which represents the carrying value of inventory components that could be redeployed for alternative use.
GivenSince the risewar in Ukraine began in February of 2022, there has been significant volatility in the global natural gas prices as of April 30,markets. As a result, in fiscal year 2022, the Company performed an impairmenta recoverability analysis with respect to the Derby 14.0 MW and 2.8 MW projects and concluded that the assets are recoverable and therefore an impairment hashad not occurred. Should natural gas prices continue to rise, there could be an impairment in future periods. No triggering events occurred during the first quarter of fiscal year 2023. The Company has risk mitigation strategies that it may implement in an effort to mitigate potential impacts including the ability to extend commercial operations dates. As of April 30, 2022,January 31, 2023, the carrying value of the 14.0 MW project in Derby, CT totaled $18.3$29.4 million and the carrying value of the 2.8 MW project in Derby, CT totaled $0.2$0.4 million.
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ImpactTable of the COVID-19 PandemicContents
During fiscal year 2020, the Company launched a proactive response to the escalating COVID-19 outbreak and temporarily suspended operations at its Torrington, CT manufacturing facility in March 2020. The Company also commenced remote work protocol for those employees worldwide that were capable of working from home. The Company took these actions to secure the safety of the Company’s employees, our corporate community as a whole, and the communities in which our team members live, and to adhere to Centers for Disease Control and Prevention (“CDC”) recommendations of social distancing and limited public exposure in connection with the COVID-19 pandemic. All employees that were not able to work from home during the manufacturing facility shutdown due to their job function received full wages and benefits during such time. We did not implement any furlough, layoff or shared work program during such time. The Company resumed manufacturing in June 2020 and the Torrington, Connecticut manufacturing facility employees returned to work. We established a phased-in return to work schedule commencing March 15, 2021 for those employees working from home, which was completed in April 2021. In December of 2021, we instructed certain employees to work from home as a result of a rise in cases in the northeastern United States. We lifted this mandate at the end of January 2022. We will continue to evaluate our ability to operate in the event of a resurgence of COVID-19 and the advisability of continuing operations based on federal, state and local guidance, evolving data concerning the pandemic and the best interests of our employees, customers and stockholders. In addition, given the then-elevated number of COVID-19 cases throughout the U.S. as a result of the highly transmissible Delta and Omicron variants, the Company instituted policies to protect its employees and customers, including implementing a mandatory vaccination policy which required all U.S. employees to be fully vaccinated by November 1, 2021 or to seek a qualified religious and/or medical exemption with weekly testing protocols. Our weekly testing protocol for unvaccinated employees has been suspended due to the relatively low incidence of COVID-19 infections. However, we will continue to monitor any COVID-19 related data that affects the interests of the Company and its stakeholders and will take appropriate action as necessary.
Other
As of April 30, 2022,January 31, 2023, the Company had unconditional purchase commitments aggregating $95.8$77.1 million for materials, supplies and services in the normal course of business.
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Legal Proceedings
POSCO Energy Matters
Background and Description of Proceedings
From approximately 2007 through 2015, the Company relied on POSCO Energy to develop and grow the Korean and Asian markets for its products and services. The Company received upfront license payments and was entitled to receive royalty income from POSCO Energy pursuant to certain manufacturing and technology transfer agreements, including the Alliance Agreement dated February 7, 2007 (and the amendments thereto), the Technology Transfer, License and Distribution Agreement dated February 7, 2007 (and the amendments thereto), the Stack Technology Transfer and License Agreement dated October 27, 2009 (and the amendments thereto), and the Cell Technology Transfer and License Agreement dated October 31, 2012 (and the amendments thereto) (collectively, the “License Agreements”). The License Agreements provided POSCO Energy with the exclusive technology rights to manufacture, sell, distribute and service the Company’s SureSource 300, SureSource 1500 and SureSource 3000 fuel cell technology in the Korean and broader Asian markets.
In November 2019, POSCO Energy spun-off its fuel cell business into a new entity, KFC, without the Company’s consent. As part of the spin-off, POSCO Energy transferred manufacturing and service rights under the License Agreements to KFC, but retained distribution rights and severed its own liability under the License Agreements. The Company formally objected to POSCO Energy’s spin-off, and POSCO Energy posted a bond to secure any liabilities to the Company arising out of the spin-off. In September 2020, the Korean Electricity Regulatory Committee found that POSCO Energy’s spin-off of the fuel cell business to KFC may have been done in violation of Korean law.
On February 19, 2020, the Company notified POSCO Energy in writing that it was in material breach of the License Agreements by (i) its actions in connection with the spin-off of the fuel cell business to KFC, (ii) its suspension of performance through its cessation of all sales activities since late 2015 and its abandonment of its fuel cell business in Asia, and (iii) its disclosure of material nonpublic information to third parties and its public pronouncements about the fuel cell business on television and in print media that have caused reputational damage to the fuel cell business, the Company and its products. The Company also notified POSCO Energy that, under the terms of the License Agreements, it had 60 days to fully cure its breaches to the Company’s satisfaction and that failure to so cure would lead to termination of the License Agreements. Further, on March 27, 2020, the Company notified POSCO Energy of additional instances of its material breach of the License Agreements based on POSCO Energy’s failure to pay royalties required to be paid in connection with certain module exchanges.
On April 27, 2020, POSCO Energy initiated a series of three arbitration demands against the Company at the International Court of Arbitration of the International Chamber of Commerce seated in Singapore, in which it alleged certain warranty defects in a sub-megawatt conditioning facility at its facility in Pohang, Korea and sought combined damages of approximately $3.3 million. Prior to filing the arbitrations, POSCO Energy obtained provisional attachments from the Seoul Central District Court attaching certain revenues owed to the Company by Korea Southern Power Company (“KOSPO”) as part of such warranty claims, which delayed receipt of certain payments owed to the Company. POSCO Energy subsequently sought additional provisional attachments on KOSPO revenues from the Seoul Central District Court based on unspecified warranty claims in an additional amount of approximately $7 million, and additional provisional attachments on KOSPO revenues from the Seoul Central District Court based on its alleged counterclaims in the license termination arbitration described below in an additional amount of approximately $110 million. POSCO Energy posted a bond in the amount of $46 million to secure any damages to the Company resulting from the attachments. The Company had outstanding accounts receivable due from KOSPO of $11.2 million, which amount was recovered from the Seoul Central District Court during the second quarter of fiscal year 2022 as discussed in additional detail below.
On June 28, 2020, the Company terminated the License Agreements with POSCO Energy and filed a demand for arbitration against POSCO Energy and KFC in the International Court of Arbitration of the International Chamber of Commerce based on POSCO Energy’s (i) failure to exercise commercially reasonable efforts to sell the Company’s technology in the Korean and Asian markets, (ii) disclosure of the Company’s proprietary information to third parties, (iii) attack on the Company’s stock price and (iv) spin-off of POSCO Energy’s fuel cell business into KFC without the Company’s consent. The Company requested that the arbitral tribunal (a) confirm through declaration that POSCO Energy’s exclusive license to market the Company’s technology and products in Korea and Asia is null and void as a result of the breaches of the License Agreements and that the Company had the right to pursue direct sales in these markets, (b) order POSCO Energy and KFC to compensate the Company for losses and damages suffered in the amount of more
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than $200 million, and (c) order POSCO Energy and KFC to pay the Company’s arbitration costs, including counsel fees and expenses. The Company retained outside counsel on a contingency basis to pursue its claims, and outside counsel entered into an agreement with a litigation finance provider to fund the legal fees and expenses of the arbitration. In October 2020, POSCO Energy filed a counterclaim in the arbitration (x) seeking approximately $880 million in damages based on allegations that the Company misrepresented the capabilities of its fuel cell technology to induce POSCO Energy to enter into the License Agreements and failed to turn over know-how sufficient for POSCO Energy to successfully operate its business; (y) seeking a declaration that the License Agreements remained in full force and effect and requesting the arbitral tribunal enjoin the Company from interfering in POSCO Energy’s exclusive rights under the License Agreements and (z) seeking an order that the Company pay POSCO Energy’s arbitration costs, including counsel fees and expenses.
The Company discontinued revenue recognition of the deferred license revenue related to the License Agreements in July 2020 given the then-pending arbitrations.
On August 28, 2020, POSCO Energy filed a complaint in the Court of Chancery of the State of Delaware (the “Court”) purportedly seeking to enforce its rights as a stockholder of the Company to inspect and make copies and extracts of certain books and records of the Company and/or the Company’s subsidiaries pursuant to Section 220 of the Delaware General Corporation Law and/or Delaware common law. POSCO Energy alleged that it was seeking to inspect these documents for a proper purpose reasonably related to its interests as a stockholder of the Company, including investigating whether the Company’s Board of Directors and its management breached their fiduciary duties of loyalty, due care, and good faith. POSCO Energy sought an order of the Court permitting POSCO Energy to inspect and copy the demanded books and records, awarding POSCO Energy reasonable costs and expenses, including reasonable attorney’s fees incurred in connection with the matter, and granting such other and further relief as the Court deemed just and proper. On July 9, 2021, the Court issued a post-trial ruling denying POSCO Energy’s demand to inspect the Company’s books and records because POSCO Energy lacked a proper purpose. The Court held that the totality of the circumstances, including the fact that this complaint was the seventh legal action POSCO Energy initiated against the Company within the span of nine months, confirmed that POSCO Energy’s purpose in initiating the books and records demand and filing the complaint was not proper. As this dispute was resolved by the Court as described above, it did not require resolution pursuant to, and was not part of, the Settlement Agreement described below.
On September 14, 2020, POSCO Energy filed a complaint in the United States District Court for the Southern District of New York (the “SD Court”) alleging that the Company delayed the removal of restrictive legends on certain share certificates held by POSCO Energy in 2018, thus precluding POSCO Energy from selling the shares and resulting in claimed losses in excess of $1 million. On September 16, 2021, the SD Court ruled in the Company’s favor on a motion for summary judgement dismissing all 4 counts of POSCO Energy’s complaint regarding share certificates held by POSCO Energy in 2018, but granted POSCO Energy leave to file an amended complaint.
Settlement Agreement
In order to resolve the disputes described above (other than the books and records dispute which was previously resolved by the Court), on December 20, 2021, the Company entered into the Settlement Agreement with PE Group. The Settlement Agreement provides, among other things, that the parties will cooperate in good faith to effect a market transition to the Company of the molten carbonate fuel cell business in Korea in accordance with the terms and conditions of the Settlement Agreement. To that end, the Settlement Agreement provides that any and all past, current, or potential disputes and claims between the Company, on the one hand, and POSCO Energy and KFC, on the other, of any nature whatsoever, whether known or unknown, asserted or not asserted, based on actions or omissions of any party on or before the date of Settlement Agreement are fully and finally settled, including such disputes and claims, directly or indirectly, in connection with the legal disputes (other than the books and records dispute which was previously resolved by the Court) and License Agreements described above, with the exception of (i) an unfiled claim by the Company in the amount of approximately $1.8 million with respect to certain royalties the Company believes are owed by POSCO Energy with respect to replacement modules deployed by POSCO Energy at Gyenonggi Green Energy and other sites for which POSCO Energy has not paid royalties, and (ii) an unfiled claim by POSCO Energy in an unknown amount with respect to a series of purchase orders for materials and components which began in 2014 under a supply chain contract, both of which claims remain unsettled. The Company does not believe the claim by POSCO Energy with respect to purchase orders for materials and components under the supply chain contract has merit and the Company retains the right to file a counterclaim for damages it believes it has incurred with respect to such supply chain contract. With respect to the attachments obtained by POSCO Energy from the Seoul Central District Court (as described above), the Settlement Agreement provides that, within five days of the date of the Settlement Agreement, POSCO Energy would file an application with the Seoul Central District
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Court to revoke the attachments. The application was filed with the Seoul Central District Court and during the second quarter of fiscal year 2022, the Company recovered the outstanding KOSPO accounts receivable of approximately $11.2 million from the Seoul Central District Court.
Under the Settlement Agreement, the parties also agreed that, within five days of the date thereof, the Company would withdraw its objection to the spin-off of KFC from POSCO Energy, and that the License Agreements are not terminated, but instead are deemed to be amended such that PE Group only has the Right to Service License (as defined above). POSCO Energy and KFC further agreed that, as of the date of the Settlement Agreement, the License Agreements are deemed to be amended such that the Company exclusively enjoys all rights as to its technology in Korea and Asia, other than the Right to Service License. The Settlement Agreement further provides that the License Agreements will terminate automatically upon sixty days prior written notice to PE Group if (i) the Company enters into a business collaboration agreement with a Korean company to construct, assemble, manufacture, market, sell, distribute, import, export, install, commission, service, maintain, or repair products incorporating the Company’s technology, or otherwise conduct the Company’s business, in the Korean market; or (ii) the Company expands the capacity of its existing Korean entity such as to perform such activities itself. In the event of the termination of the License Agreements, the license granted to PE Group under the Right to Service License will continue notwithstanding the termination of the License Agreements, except that PE Group’s right to own, operate, and maintain all facilities and factories for the purpose of servicing any orders or requests made by the Company will terminate. For the avoidance of doubt, pursuant to the terms of the Settlement Agreement, PE Group has no right to manufacture modules or any other product incorporating the Company’s technology under the License Agreements as amended, the Right to Service License or otherwise unless requested and authorized by the Company to do so.
The Settlement Agreement further provides that, in order to service its existing customers under the Existing LTSAs, KFC would place a firm, non-cancelable order for 12 SureSource 3000 modules within 2 weeks after the date of the Settlement Agreement and will place an additional firm, non-cancelable order for 8 SureSource 3000 modules on or before June 30, 2022, all at a price of $3.0 million per module. In addition, KFC has agreed to use commercially reasonable efforts to order 14 additional SureSource 3000 modules by December 31, 2022, at a price of $3.0 million per module if ordered by such date. If KFC materially breaches the Settlement Agreement by failing to make timely and full payment for the modules for which KFC is required to place orders under the Settlement Agreement and does not cure such material breach within fifteen days of notice of such breach by the Company, the License Agreements and the Right to Service License granted to PE Group will be terminated. If the Company materially breaches the Settlement Agreement by failing to supply the modules for which KFC is required to place orders under the Settlement Agreement, as long as KFC has made the payment for such modules and has otherwise satisfied its contractual obligations for those modules and such material breach is not cured within sixty days after notice from PE Group, PE Group will have the right to terminate the Settlement Agreement. With respect to any other alleged breach, material or otherwise, of the Settlement Agreement, the parties’ exclusive remedy consists solely of general damages.
The Company received a firm, non-cancelable order from KFC for 12 SureSource 3000 modules. NaN of these modules were delivered Ex Works from the Company’s facility in Torrington, Connecticut in January 2022.
Pursuant to the Settlement Agreement, with respect to new modules to be supplied by the Company and deployed by PE Group to its existing customers, the Company will provide its standard warranty against module defects until the earlier of eighteen months from the date of shipment or twelve months from the date of installation. As part of the global settlement of the disputes among the parties and subject to the qualifications set forth in the Settlement Agreement, the Company will reimburse PE Group for any annual output penalty amount paid by PE Group to its customers pursuant to Existing LTSAs (whether such Existing LTSA is extended or renewed), caused by a shortfall or defect in the new modules for a period of up to seven years. The maximum annual reimbursement obligation with regard to any PE Group customer for any new module provided by the Company will not exceed an amount equal to 7.5% per year of the module purchase price. The Company will not be required to reimburse PE Group for any penalty paid by PE Group under the Existing LTSAs that is not caused by a shortfall or defect in the modules to be supplied by the Company including, without limitation, any shortfall or defect caused by a site-related problem, a problem with the balance of plant, or other components of the project.
Although the Company has the exclusive and unrestricted right under the Settlement Agreement to perform, pursue, and otherwise conduct its business in relation to new fuel cell projects (including new projects with PE Group’s existing customers) in Korea and Asia, the parties have agreed that, except as further provided in the Settlement Agreement with respect to PE Group’s existing customers Noeul Green Energy and Godeok Green Energy, the Company will not engage in discussions with PE Group’s existing customers regarding Existing LTSAs without PE Group’s consent. The parties have further agreed that if PE Group cannot enter into an agreement with its existing customers to extend or renew Existing
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LTSAs by December 31, 2022, PE Group will cooperate with the Company so that the Company may discuss and, at the Company’s sole discretion, enter into an extension of an Existing LTSA, a new long-term service agreement to replace an Existing LTSA, or a module sales agreement with PE Group’s existing customers; provided that (i) should the Company enter into such an arrangement with a PE Group existing customer, (ii) the Company is required to provide replacement modules to such existing customer under such arrangement, and (iii) PE Group has not already deployed all or some the modules that PE Group ordered under Settlement Agreement, the Company will purchase the number of required replacement modules from PE Group at a price of $3.0 million per module (to the extent such modules are available and have not yet been deployed). The purchase of such replacement modules by the Company is contingent upon the modules being in proper condition as determined by inspection process to be agreed by the parties. Any modules purchased by the Company from PE Group under these terms will be included as part of the firm orders KFC is required to make pursuant to the Settlement Agreement.
With respect to operations and maintenance agreements, the Settlement Agreement provides that KFC will have the right of first refusal on providing operation and maintenance services on commercially reasonable terms for new long-term service agreements entered into by the Company in Korea for a period of the first to occur of either twenty-four months after the date of the Settlement Agreement or until such time as the Company engages a third party capable of providing such services in Korea. If KFC and the Company agree that KFC should provide operation and maintenance services pursuant to the right of first refusal, KFC and the Company will enter into one or more operation and maintenance agreements that reflect commercially reasonable terms and conditions as agreed by KFC and the Company at that time.
With respect to BOP, KFC currently has 8 units of BOP available, and the Settlement Agreement provides that the Company has the option to purchase such units of BOP for any new molten carbonate fuel cell projects within Korea at a price of KRW 2,550,000,000 (or USD $2,116,500 as of April 30, 2022) per unit. The Company will also have a non-exclusive, non-transferrable, non-sublicensable license to use the intellectual property embedded in the BOP units in Korea in consideration for a reasonable license fee to be separately agreed by the parties. Detailed terms and conditions of BOP and related software and firmware supply will be discussed and agreed to in good faith in separate BOP supply agreements in the event the Company exercises its option to purchase any of such BOP.
As described above, the Company retained outside counsel on a contingency basis to pursue its claims against POSCO Energy and KFC, and outside counsel entered into an agreement with a litigation finance provider to fund the legal fees and expenses of the arbitration proceedings brought by the Company against POSCO Energy and KFC. As the Company has entered into the Settlement Agreement, it is required to remit fees to its counsel, Wiley Rein, LLP (“Wiley”), subject to the terms of its engagement letter with Wiley. On December 23, 2021, the Company agreed that it would pay Wiley a total of $24.0 million to satisfy all obligations to Wiley under the Company’s engagement letter (which is included in Administrative and selling expenses on the Consolidated Statements of Operations and Comprehensive Loss for the six months ended April 30, 2022). Of this amount, $19.0 million was paid during the six months ended April 30, 2022, and the remaining $5.0 million will be paid on or before June 30, 2022.
Other Legal Proceedings
From time to time, the Company is involved in other legal proceedings, including, but not limited to, regulatory proceedings, claims, mediations, arbitrations and litigation, arising out of the ordinary course of its business (“Other Legal Proceedings”). Although the Company cannot assure the outcome of such Other Legal Proceedings, management presently believes that the result of such Other Legal Proceedings, either individually, or in the aggregate, will not have a material adverse effect on the Company’s consolidated financial statements, and no material amounts have been accrued in the Company’s consolidated financial statements with respect to these matters.
Note 18. Subsequent Events
On February 20, 2023, Versa Ltd. entered into a Lease Expansion and Amending Agreement – Short Term (the “Lease Expansion and Amendment”) to the existing lease for the Calgary manufacturing facility, which was originally entered into on May 20, 2005 and was amended and extended several times, including on January 5, 2023 (refer to Note 10. “Leases” for more information regarding the January 5, 2023 amendment). Under the Lease Expansion and Amendment, the space leased by Versa Ltd. is to be further expanded to include, on a short-term basis, an additional space located at the same address as the original Calgary manufacturing facility (4800 – 52nd Street SE, Calgary, Alberta, Canada) and consisting of approximately 18,627 square feet (the “Temporary Premises”). Subject to certain conditions, the term of the lease with respect to the Temporary Premises will commence on April 1, 2023 and expire on July 31, 2024. The Temporary Premises is expected to be used for short term expansion of solid oxide fuel cell and stack production and commissioning of newly purchased production equipment.
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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
FORWARD-LOOKING STATEMENTS
This Quarterly Report on Form 10-Q contains both historical statements and forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995 that involve risks, uncertainties and assumptions. The statements contained in this report that are not purely historical are forward-looking statements that are subject to the safe harbors created under the Securities Act of 1933, as amended, and the Securities Exchange Act of 1934, as amended, including statements regarding our expectations, beliefs, intentions and strategies for the future. When used in this report, the words “expects,” “anticipates,” “estimates,” “goals,” “projects,” “intends,” “plans,” “believes,” “predicts,” “should,” “seeks,” “will,” “could,” “would,” “may,” “forecast,” and similar expressions and variations of such words are intended to identify forward-looking statements. Such statements relate to, among other things, the following: (i) the development and commercialization by FuelCell Energy, Inc. and its subsidiaries of fuel cell technology and products and the market for such products; (ii) expected operating results such as revenue growth and earnings; (iii) the expected timing of completion of our ongoing projects; (iv) our business plans and strategies; (v) the markets in which we expect to operate; (vi) our belief that we have sufficient liquidity to fund our business operations for the next 12 months; (iv)(vii) future funding under Advanced Technologies contracts; (v)(viii) future financing for projects, including equity and debt investments by investors and commercial bank financing, as well as overall financial market conditions; (vi)(ix) the expected cost competitiveness of our technology; and (vii)(x) our ability to achieve our sales plans, market access and market expansion goals, and cost reduction targets.
The forward-looking statements contained in this report are subject to risks and uncertainties, known and unknown, that could cause actual results and future events to differ materially from those set forth in or contemplated by the forward-looking statements, including, without limitation, the risks described in our Annual Report on Form 10-K for the fiscal year ended October 31, 20212022 and in the section below entitled “Item 1A. Risk Factors,” and the following risks and uncertainties: general risks associated with product development and manufacturing; general economic conditions; changes in interest rates, which may impact project financing; supply chain disruptions; changes in the utility regulatory environment; changes in the utility industry and the markets for distributed generation, distributed hydrogen, and fuel cell power plants configured for carbon capture or carbon separation; potential volatility of commodity and energy prices that may adversely affect our projects; availability of government subsidies and economic incentives for alternative energy technologies; our ability to remain in compliance with U.S. federal and state and foreign government laws and regulations and the listing rules of The Nasdaq Stock Market (“Nasdaq”); rapid technological change; competition; the risk that our bid awards will not convert to contracts or that our contracts will not convert to revenue; market acceptance of our products; changes in accounting policies or practices adopted voluntarily or as required by accounting principles generally accepted in the United States; factors affecting our liquidity position and financial condition; government appropriations; the ability of the government and third parties to terminate their development contracts at any time; the ability of the government to exercise “march-in” rights with respect to certain of our patents; our ability to successfully market and sell our products internationally; our ability to develop new products to achieve our long-term revenue targets; our ability to implement our strategy; our ability to reduce our levelized cost of energy and deliver on our cost reduction strategy generally; our ability to protect our intellectual property; litigation and other proceedings; the risk that commercialization of our new products will not occur when anticipated or, if it does, that we will not have adequate capacity to satisfy demand; our need for and the availability of additional financing; our ability to generate positive cash flow from operations; our ability to service our long-term debt; our ability to increase the output and longevity of our platforms and to meet the performance requirements of our contracts; our ability to expand our customer base and maintain relationships with our largest customers and strategic business allies; changes by the U.S. Small Business Administration or other governmental authorities to, or with respect to the implementation or interpretation of, the Coronavirus Aid, Relief, and Economic Security Act, the Paycheck Protection Program or related administrative matters; and concerns with, threats of, or the consequences of, pandemics, contagious diseases or health epidemics, including the novel coronavirus (“COVID-19”), and resulting supply chain disruptions, shifts in clean energy demand, impacts to our customers’ capital budgets and investment plans, impacts to our project schedules, impacts to our ability to service existing projects, and impacts on the demand for our products.
We cannot assure you that: we will be able to meet any of our development or commercialization schedules; any of our new products or technologies, once developed, will be commercially successful; our SureSource power plants will be commercially successful; we will be able to obtain financing or raise capital to achieve our business plans; the government will appropriate the funds anticipated by us under our government contracts; the government will not exercise its right to terminate any or all of our government contracts; or we will be able to achieve any other result anticipated in any other forward-looking statement contained herein.
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Investors are cautioned that forward-looking statements are not guarantees of future performance and involve risks and uncertainties, many of which are beyond our ability to control, and that actual results may differ materially from those projected in the forward-looking statements as a result of various factors discussed herein. Any forward-looking statement made by us in this report is based only on information currently available to us and speaks only as of the date on which it is made. We undertake no obligation to publicly update any forward-looking statement, whether written or oral, that may be made from time to time, whether as a result of new information, future developments or otherwise.
Management’s Discussion and Analysis of Financial Condition and Results of Operations is provided as a supplement to the accompanying financial statements and footnotes to help provide an understanding of our financial condition, changes in our financial condition and results of operations. The preparation of financial statements and related disclosures requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the disclosure of contingent assets and liabilities, as well as management’s assessment of the Company’s ability to meet its obligations as they come due over the next twelve months. Actual results could differ from those estimates. Estimates are used in accounting for, among other things, revenue recognition, excess, slow-moving and obsolete inventories, product warranty accruals, loss accruals on service agreements, share-based compensation expense, allowance for doubtful accounts, depreciation and amortization, impairment of goodwill and in-process research and development intangible assets, impairment of long-lived assets (including project assets), lease liabilities and right-of-use (“ROU”) assets, and contingencies, and in management’s assessment of the Company’s ability to meet its obligations as they come due over the next twelve months. Estimates and assumptions are reviewed periodically, and the effects of revisions are reflected in the consolidated financial statements in the period they are determined to be necessary. Due to the inherent uncertainty involved in making estimates, actual results in future periods may differ from those estimates. The following discussion should be read in conjunction with information included in our Annual Report on Form 10-K for the fiscal year ended October 31, 20212022 filed with the Securities and Exchange Commission (“SEC”). Unless otherwise indicated, the terms “Company”, “FuelCell Energy”, “we”, “us”, and “our” refer to FuelCell Energy, Inc. and its subsidiaries. All tabular dollar amounts are in thousands.
OVERVIEW
Headquartered in Danbury, Connecticut, FuelCell Energy has leveraged five decades of research and development to become a global leader in delivering environmentally responsible distributed baseload energy platform solutions through our proprietary fuel cell technology. Our current commercial technology produces electricity, heat, hydrogen, and water while separating carbon for utilization and/or sequestration. We continue to invest in developing and commercializing future technologies expected to add new capabilities to our platforms’ abilities to deliver hydrogen and long duration hydrogen-based energy storage through our solid oxide technologies, as well as further enhance our existing platforms’ carbon capture solutions.
FuelCell Energy is a global leader in sustainable clean energy technologies that address some of the world’s most critical challenges around energy access, security, safety and global urbanization.environmental stewardship. As a leading global manufacturer of proprietary fuel cell technology platforms, we areFuelCell Energy is uniquely positioned to serve customers worldwide with sustainable products and solutions for industrial and commercial businesses, utilities, governments, and municipalities. Our solutions are designed to enable a world empowered by clean energy, enhancing the quality of life for people around the globe. We target large-scale power users with our megawatt-class installations globally, and currently offer sub-megawatt solutions for smaller power consumers in Europe. To provide a frame of reference, one megawatt is adequate to continually power approximately 1,000 average sized U.S. homes. Our customer base includes utility companies, municipalities, universities, hospitals, government entities/military bases and a variety of industrial and commercial enterprises. Our leading geographic markets are currently the United States and Korea, and we are pursuing opportunities in other countries around the world.
FuelCell Energy, based in Connecticut, was founded in 1969 as a New York corporation to provide applied research and development services on a contract basis. We completed our initial public offering in 1992 and reincorporated in Delaware in 1999. We began selling stationary fuel cell power plants commercially in 2003.
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RECENT DEVELOPMENTS
On February 20, 2023, Versa Power Systems Ltd. (“Versa Ltd.”), a wholly owned subsidiary of FuelCell Energy, entered into a Lease Expansion and Amending Agreement – Short Term (the “Lease Expansion and Amendment”) to the existing lease for the Calgary manufacturing facility, which was originally entered into on May 20, 2005 and was amended and extended several times, including on January 5, 2023 (refer to Note 10. “Leases” for more information regarding the January 5, 2023 amendment). Under the Lease Expansion and Amendment, the space leased by Versa Ltd. is to be further expanded to include, on a short-term basis, an additional space located at the same address as the original Calgary manufacturing facility (4800 – 52nd Street SE, Calgary, Alberta, Canada) and consisting of approximately 18,627 square feet (the “Temporary Premises”). Subject to the landlord’s ability to obtain vacant possession of the Temporary Premises on March 31, 2023, the term of the lease with respect to the Temporary Premises will commence on April 1, 2023 and expire on July 31, 2024. The Temporary Premises is expected to be used for short term expansion of solid oxide fuel cell and stack production and commissioning of newly purchased production equipment.
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RESULTS OF OPERATIONS
Management evaluates our results of operations and cash flows using a variety of key performance indicators, including revenues compared to prior periods and internal forecasts, costs of our products and results of our cost reduction initiatives, and operating cash use. These are discussed throughout the “Results of Operations” and “Liquidity and Capital Resources” sections. Results of Operations are presented in accordance with accounting principles generally accepted in the United States (“GAAP”).
Comparison of Three Months Ended April 30,January 31, 2023 and 2022 and 2021
Revenues and Costs of revenues
Our revenues and cost of revenues for the three months ended April 30,January 31, 2023 and 2022 and 2021 were as follows:
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| | Three Months Ended April 30, | | Change | | Three Months Ended January 31, | | Change | ||||||||||||||
(dollars in thousands) |
| 2022 |
| 2021 |
| $ |
| % |
| 2023 |
| 2022 |
| $ |
| % | ||||||
Total revenues | | $ | 16,384 | | $ | 13,953 | | $ | 2,431 | | 17% | | $ | 37,073 | | $ | 31,795 | | $ | 5,278 | | 17% |
Total costs of revenues | | | 23,694 | | | 18,709 | | | 4,985 | | 27% | | | 31,836 | | | 34,690 | | | (2,854) | | (8)% |
Gross loss | | $ | (7,310) | | $ | (4,756) | | $ | (2,554) | | 54% | |||||||||||
Gross profit (loss) | | $ | 5,237 | | $ | (2,895) | | $ | 8,132 | | 281% | |||||||||||
Gross margin | | | (44.6)% | | | (34.1)% | | | | | | | | 14.1% | | | (9.1)% | | | | | |
Total revenues for the three months ended April 30, 2022January 31, 2023 of $16.4$37.1 million reflects an increase of $2.4$5.3 million from $14.0$31.8 million for the same period in the prior year. Cost of revenues for the three months ended April 30, 2022January 31, 2023 of $23.7$31.8 million increased $5.0reflects a decrease of $2.9 million from $18.7$34.7 million for the same period in the prior year. A discussion of the changes in product revenues, service agreements revenues, generation revenues and Advanced Technologies contract revenues follows.
Product revenues
Our product revenues and related costs for the three months ended April 30,January 31, 2023 and 2022 and 2021 were as follows:
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| | Three Months Ended April 30, | | Change | | Three Months Ended January 31, | | Change | ||||||||||||||
(dollars in thousands) |
| 2022 |
| 2021 |
| $ |
| % |
| 2023 |
| 2022 |
| $ |
| % | ||||||
Product revenues | | $ | — | | $ | — | | $ | — | | N/A | | $ | 9,095 | | $ | 18,000 | | $ | (8,905) | | (49)% |
Cost of product revenues | | | 3,033 | | | 1,921 | | | 1,112 | | 58% | | | 1,029 | | | 18,207 | | | (17,178) | | (94)% |
Gross loss from product revenues | | $ | (3,033) | | $ | (1,921) | | $ | (1,112) | | (58)% | |||||||||||
Product gross margin | | | N/A | | | N/A | | | | | | |||||||||||
Gross profit (loss) from product revenues | | $ | 8,066 | | $ | (207) | | $ | 8,273 | | 3997% | |||||||||||
Product revenues gross margin | | | 88.7% | | | (1.2)% | | | | | |
There were no productProduct revenues for the three months ended April 30, 2022 and April 30, 2021. ThereJanuary 31, 2023 were no product revenues$9.1 million compared to $18.0 million for the three months ended April 30, 2022 because there were no modules delivered during that period. We expect product revenues to increase during the quarter ending JulyJanuary 31, 2022 as we have built inventory2022. Our December 2021 Settlement Agreement (the “Settlement Agreement”) with POSCO Energy Co., Ltd. (“POSCO Energy”) and expect to deliver additional modules from the initial twelve module order we received fromits subsidiary, Korea Fuel Cell Co., Ltd. (“KFC”) (a subsidiary, included an option to purchase an additional 14 modules (in addition to the 20 modules that were purchased by KFC during fiscal year 2022). This option included a material right related to an extended warranty obligation for the modules. The option was not exercised by KFC as of POSCO Energy Co., Ltd. (“POSCO Energy”))the expiration date of December 31, 2022 and, as a result, the Company recognized $9.1 million of product revenues, which represents the consideration allocated to the material right if the option had been exercised. Product revenues for the three months ended January 31, 2022 were a result of module sales to KFC under the Settlement Agreement for which the Company recognized $18.0 million on the Ex Works delivery of six modules from the Company’s facility in the first fiscal quarter ofTorrington, CT in January 2022.
Cost of product revenues increased $1.1decreased $17.2 million for the three months ended April 30, 2022January 31, 2023 to $3.0$1.0 million, compared to $1.9$18.2 million in the same period in the prior year. The decrease is primarily due to the lack of module sales during the three months ended January 31, 2023. Manufacturing variances, primarily related to production volumes and unabsorbed overhead costs, totaled approximately $2.5$1.1 million for the three months ended April 30, 2022January 31, 2023 compared to approximately $1.3$2.2 million for the three months ended April 30, 2021.
For the three months ended April 30, 2022, we operated at an annualized production rate of approximately 40.8 MW, which is an increase from the annualized production rate of 32 MWJanuary 31, 2022. The reduction in manufacturing variances for the three months ended April 30, 2021.January 31, 2023 included an increase in capitalized costs as a result of an increase in product standard costs. Cost of product revenues for the three months ended January 31, 2022 included an impairment charge of
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approximately $1.0 million related to the cessation of use of conditioning equipment in Danbury, CT, which has been replaced by new equipment at our production facility in Torrington, CT.
Product revenues for the three months ended January 31, 2023 generated a gross profit of $8.1 million compared to a gross loss of $0.2 million for the three months ended January 31, 2022. The gross profit is a direct result of the product revenues recognized in the three months ended January 31, 2023 related to the expiration of KFC’s module purchase option, particularly as there were no corresponding costs associated with the recognition of these revenues.
For the three months ended January 31, 2023, we operated at an annualized production rate of approximately 38.2 megawatts (“MW”), which is comparable to the annualized production rate of 38.3 MW for the three months ended January 31, 2022.
Service agreements revenues
Service agreements revenues and related costs for the three months ended April 30,January 31, 2023 and 2022 and 2021 were as follows:
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| | Three Months Ended April 30, | | Change | | Three Months Ended January 31, | | Change | ||||||||||||||
(dollars in thousands) |
| 2022 |
| 2021 |
| $ |
| % |
| 2023 |
| 2022 |
| $ |
| % | ||||||
Service agreements revenues | | $ | 2,639 | | $ | 660 | | $ | 1,979 | | 300% | | $ | 13,882 | | $ | 2,167 | | $ | 11,715 | | 541% |
Cost of service agreements revenues | | | 3,033 | | | 2,867 | | | 166 | | 6% | | | 10,945 | | | 2,372 | | | 8,573 | | 361% |
Gross loss from service agreements revenues | | $ | (394) | | $ | (2,207) | | $ | 1,813 | | (82)% | |||||||||||
Gross profit (loss) from service agreements revenues | | $ | 2,937 | | $ | (205) | | $ | 3,142 | | 1533% | |||||||||||
Service agreements revenues gross margin | | | (14.9)% | | | (334.4)% | | | | | | | | 21.2% | | | (9.5)% | | | | | |
RevenuesService agreements revenues for the three months ended April 30, 2022 from service agreementsJanuary 31, 2023 increased $2.0$11.7 million to $2.6$13.9 million from $0.7$2.2 million for the three months ended April 30, 2021. The serviceJanuary 31, 2022. Service agreements revenues forrecognized during the three months ended April 30, 2022 include revenues recorded for a refurbishedJanuary 31, 2023 were primarily driven by new module exchangeexchanges at the plant in Woodbridge, CT, which originally achieved commercial operations in fiscal year 2017, and routine and non-routine maintenance activities.at the plants owned by Korea Southern Power Company in Korea, which achieved commercial operations in fiscal year 2018. The increase in revenues for the three months ended April 30, 2022January 31, 2023 is primarily due to the fact that new module exchanges occurred during the quarter, while there was a refurbishedwere no new module exchange and non-routine maintenance activitiesexchanges during the three months ended April 30January 31, 2022.
Cost of service agreements revenues increased $0.2$8.6 million to $3.0$10.9 million for the three months ended April 30, 2022January 31, 2023 from $2.4 million for the three months ended January 31, 2022. Cost of service agreements revenues includes maintenance and operating costs and costs of module exchanges and the increase is primarily due to the fact that new module exchanges occurred during the three months ended January 31, 2023, while there were no new module exchanges during the three months ended January 31, 2022.
Overall gross profit from service agreements revenues was $2.9 million for the three months ended April 30, 2021. Cost of service agreements includes maintenance and operating costs and module exchanges.
OverallJanuary 31, 2023 which increased from a gross loss from service agreements revenues was $0.4 million and $2.2of $0.2 million for the three months ended April 30, 2022 and April 30, 2021, respectively.January 31, 2022. The overall gross margin was (14.9)%21.2% for the three months ended April 30, 2022January 31, 2023 compared to a gross margin loss of (334.4)%9.5% in the comparable prior year period. Gross margin was higher during the three months ended April 30, 2022January 31, 2023 primarily due to the fact that the comparable prior year period included additional performance guarantees recorded and adjustments to the loss accrual to account for changes in the expected timing of futurenew module exchanges based onwere completed during the Company’s then currentthree months ended January 31, 2023 (compared to no new module exchanges during the three months ended January 31, 2022) and that such module exchanges were performed pursuant to service schedule in order to improve fleet performance.agreements with higher margins.
Generation revenues
Generation revenues and related costs for the three months ended April 30,January 31, 2023 and 2022 and 2021 were as follows:
| | | | | | | | | | | | | | | | | | | | | | |
| | Three Months Ended April 30, | | Change | | Three Months Ended January 31, | | Change | ||||||||||||||
(dollars in thousands) |
| 2022 |
| 2021 |
| $ |
| % |
| 2023 |
| 2022 |
| $ |
| % | ||||||
Generation revenues | | $ | 9,050 | | $ | 6,185 | | $ | 2,865 | | 46% | | $ | 9,557 | | $ | 7,496 | | $ | 2,061 | | 27% |
Cost of generation revenues | | | 14,120 | | | 9,422 | | | 4,698 | | 50% | | | 16,602 | | | 10,722 | | | 5,880 | | 55% |
Gross loss from generation revenues | | $ | (5,070) | | $ | (3,237) | | $ | (1,833) | | 57% | | $ | (7,045) | | $ | (3,226) | | $ | (3,819) | | (118)% |
Generation revenues gross margin | | | (56.0)% | | | (52.3)% | | | | | | | | (73.7)% | | | (43.0)% | | | | | |
Revenues from generation for the three months ended April 30, 2022January 31, 2023 totaled $9.1$9.6 million, which represents an increase of $2.9$2.1 million from revenue recognized of $6.2$7.5 million for the three months ended April 30, 2021.January 31, 2022. Generation revenues
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for the three months ended April 30,January 31, 2023 and 2022 and 2021 reflect revenue from electricity generated under our power purchase agreements (“PPAs”). and renewable energy credits. The increase in generation revenues in the three months ended April 30, 2022January 31, 2023 is primarily due to the completionfact that we recorded a full quarter of generation revenues associated with the Long Island Power Authority (“LIPA”) project in Yaphank, New York (which achieved commercial operations in December 2021) and that fact that the project duringat the three months ended January 31, 2022U.S. Navy Submarine Base in Groton, Connecticut (the “Groton Project”) achieved commercial operations and began generating revenues in the higher operating output of the generation fleet portfolio as a result of module replacements during the last six monthsfirst quarter of fiscal year 2021.2023.
Cost of generation revenues totaled $14.1$16.6 million in the three months ended April 30, 2022.January 31, 2023. The increase from the comparable prior year period was primarily due to expensed construction costs of approximately $4.8$7.1 million related to the Toyota project (while construction costs for the comparable prior year period were $2.8 million) and costs of approximately $2.4$0.8 million related to the increased size of the installed fleet with the San Bernardino and LIPA Yaphank projectsGroton Project achieving commercial operation,operations, offset by lower operating costs for existing plants due to efficiencies resulting from plant maintenance activities and module replacements. exchanges.
As further background on the costs related to the Toyota project, it was determined in the fourth quarter of fiscal year 2021 that a potential source of renewable natural gas (“RNG”) at favorable pricing was no longer sufficiently probable for the Toyota project.project, resulting in impairment of the asset. Thus, as the Toyota project is being constructed, only amounts associated with inventory components that can be redeployed for alternative use are being capitalized. The balance of costs incurred (i.e., the construction costs mentioned above in an amount equal to $4.8 million) are being expensed as cost of generation revenues.
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We currently have three projects in development with fuel sourcing risk, which are the Toyota project, which requires procurement of RNG, and our Derby, CT 14.0 MW and 2.8 MW projects, which require natural gas. Fuel sourcing and risk mitigation strategies for all three projects are being assessed and will be implemented as project operational dates become firm. Such strategies may require cash collateral or reserves to secure fuel or related contracts for these three projects. If the Company is unable to secure fuel on favorable economic terms, it may result in impairment charges to thesethe Derby project assets may result.and further charges for the Toyota project asset.
Cost of generation revenues included depreciation and amortization of approximately $4.1$4.2 million and $3.6 million for the three months ended April 30,January 31, 2023 and 2022, and 2021, respectively.
The decrease in generation revenues gross margin is primarily related to the $4.8$7.1 million of costs being expensed related to the Toyota project, partially offset by higher margins from the operating fleet (due in part to the higher operating output of the generation fleet portfolio) compared to the three months ended April 30, 2021.January 31, 2022.
We had 41.443.7 MW of operating power plants in our generation operating portfolio as of April 30, 2022,January 31, 2023, which increased from 32.641.4 MW as of April 30, 2021.January 31, 2022 and which includes 7.4 MW attributed to the design rated output of the Groton Project although the Groton Project is, and was as of January 31, 2023 and at the commencement of commercial operations in December 2022, operating at approximately 6.0 MW. The increase relates to the 1.4 MW platform at the City of San Bernardino Municipal Water Department in San Bernardino, California,Groton Project, which commenced commercial operations in June 2021, and the 7.4below its rated capacity at an output of approximately 6.0 MW platform for LIPA in Yaphank Long Island, New York, which commenced commercial operations during the three months ended January 31, 2022.2023 (and continues to operate at an output of approximately 6.0 MW), offset by the removal of the 3.7 MW Triangle Street Project which is no longer in operation and the 1.4 MW UCI Medical Center Project which has been decommissioned.
Advanced Technologies contract revenues
Advanced Technologies contract revenues and related costs for the three months ended April 30,January 31, 2023 and 2022 and 2021 were as follows:
| | | | | | | | | | | | | | | | | | | | | | |
| | Three Months Ended April 30, | | Change | | Three Months Ended January 31, | | Change | ||||||||||||||
(dollars in thousands) |
| 2022 |
| 2021 |
| $ |
| % |
| 2023 |
| 2022 |
| $ |
| % | ||||||
Advanced Technologies contract revenues | | $ | 4,695 | | $ | 7,108 | | $ | (2,413) | | (34)% | | $ | 4,539 | | $ | 4,132 | | $ | 407 | | 10% |
Cost of Advanced Technologies contract revenues | | | 3,508 | | | 4,499 | | | (991) | | (22)% | | | 3,260 | | | 3,389 | | | (129) | | (4)% |
Gross profit from Advanced Technologies contracts | | $ | 1,187 | | $ | 2,609 | | $ | (1,422) | | (55)% | | $ | 1,279 | | $ | 743 | | $ | 536 | | 72% |
Advanced Technologies contract gross margin | | | 25.3% | | | 36.7% | | | | | | | | 28.2% | | | 18.0% | | | | | |
Advanced Technologies contract revenues decreasedincreased to $4.7$4.5 million for the three months ended April 30, 2022January 31, 2023 from $7.1$4.1 million for the three months ended April 30, 2021.January 31, 2022. Compared to the three months ended April 30, 2021,January 31, 2022, Advanced Technologies contract revenues recognized under the Joint Development Agreement entered into with
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ExxonMobil Technology and Engineering Company f/k/a ExxonMobil Research and Engineering Company (“EMTEC”), on November 5, 2019 (as amended effective as of October 31, 2021, and April 30, 2022 theand December 1, 2022 (the “EMTEC Joint Development Agreement”)) were approximately $3.2$0.1 million lowerhigher during the three months ended April 30, 2022 due to the scope of work performed during this period compared to the scope of work performed in the comparable prior year period, offset by an increase inJanuary 31, 2023 and revenue recognized under government contracts and other contracts of $0.9were approximately $0.3 million higher for the three months ended April 30, 2022.January 31, 2023.
Cost of Advanced Technologies contract revenues were $3.5$3.3 million for the three months ended April 30, 2022,January 31, 2023, compared to $4.5$3.4 million for the same period in the prior year based on the level of activity and the scope of work performed under the EMTEC Joint Development Agreement in the period.year.
Advanced Technologies contracts for the three months ended April 30, 2022January 31, 2023 generated a gross marginprofit of $1.2$1.3 million compared to a gross marginprofit of $2.6$0.7 million for the three months ended April 30, 2021.January 31, 2022. The lowerhigher gross marginprofit was due to lower revenueshigher gross profit recognized under the EMTEC Joint Development Agreement during the three months ended April 30,January 31, 2023 as a result of lower costs incurred under the EMTEC Joint Development Agreement compared to the three months ended January 31 2022.
Administrative and selling expenses
Administrative and selling expenses were $13.2$15.0 million and $9.7$37.0 million for the three months ended April 30,January 31, 2023 and 2022, and 2021, respectively. The increase is relatedthree months ended January 31, 2022 included non-recurring legal expenses of $24.0 million associated with the settlement of the Company’s disputes with POSCO Energy and KFC. Excluding the $24.0 million in legal fees, administrative and selling expenses were higher during the three months ended January 31, 2023 than during the three months ended January 31, 2022 primarily due to higher sales, marketing and consulting costs, as the Company is investing in rebranding and accelerating its sales and commercialization efforts including increasing the size of its sales and marketing teams, which resulted in an increase in compensation expense resulting from an increase in headcount.
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Research and development expenses
Research and development expenses increased to $7.7$12.7 million for the three months ended April 30, 2022January 31, 2023 compared to $3.0$5.0 million for the three months ended April 30, 2021.January 31, 2022. The increase relatesis primarily due to an increase in spending on the Company’s hydrogen commercialization initiativesongoing commercial development efforts related to our solid oxide platform and carbon capture solutions compared to the comparable prior year period.
Loss from operations
Loss from operations for the three months ended April 30, 2022January 31, 2023 was $28.2$22.5 million compared to $17.4$44.8 million for the three months ended April 30, 2021.January 31, 2022. This increasedecrease was driven by an $8.3a $14.3 million increasedecrease in operating expenses for the three months ended April 30, 2022January 31, 2023 as a result of (a) higher sales, marketingdecreased administrative and consulting costsselling expenses compared to the three months ended January 31, 2022 and an increase in compensation expense resulting from an increase in headcount and (b) higher research and development expenses, which were higher due to an increase in spending on the Company’s hydrogen commercialization initiativesongoing commercial development efforts related to our solid oxide platform and carbon capture solutions compared to the comparable prior year period.three months ended January 31, 2022. The increasedecrease in loss from operations was also due, in part, to highera gross lossprofit of $7.3$5.2 million in the three months ended April 30, 2022January 31, 2023, compared to gross loss of $4.8$2.9 million in the three months ended April 30, 2021.January 31, 2022. The increase intransition from gross loss to gross profit was driven by higherlower manufacturing variances $4.8and higher Advanced Technologies contract margin, partially offset by $7.1 million of non-recoverablenon-capitalizable costs related to construction of the Toyota project, increased gross profit from service agreements and lower Advanced Technologies contract margin, partially offset by reduced generation gross loss (excluding the impact of non-recoverablenon-capitalizable costs related to construction of the Toyota project) and reduced service gross loss..
Interest expense
Interest expense for the three months ended April 30,January 31, 2023 and 2022 and 2021 was $1.7$1.5 million and $1.6$1.4 million, respectively. Interest expense for both periods includes interest related to financingassociated with finance obligations related tofor failed sale-leaseback transactions and interest on the outstanding loans associated with the Bridgeport Fuel Cell Project.
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Interest income
Interest income was $3.4 million and $10.0 thousand for the three months ended January 31, 2023 and 2022, respectively. Interest income for the three months ended January 31, 2023 represents $2.7 million of interest earned on money market investments and $0.7 million of unrealized interest income on U.S. Treasury Securities purchased in November 2022.
Other (expense) income, net
Other (expense) income, net was $(0.2) million$49.0 thousand and $0.03$0.1 million for the three months ended April 30,January 31, 2023 and 2022, respectively, and 2021, respectively.primarily represents foreign currency exchange gains for each of the three month periods ended January 31, 2023 and 2022.
BenefitProvision for income taxes
We have not paid federal or state income taxes in several years due to our history of net operating losses, although we have paid foreign income and withholding taxes in Korea. BenefitProvision for income tax recorded for the three months ended April 30,January 31, 2023 and 2022 was $0.6 million and 2021 was $0 and $4 thousand,$0.0 million, respectively. The provision for income tax recorded for the three months ended January 31, 2023 reflects the realization of withholding taxes on customer deposits.
Series B preferred stock dividends
Dividends recorded on our 5% Series B Cumulative Convertible Perpetual Preferred Stock (“Series B Preferred Stock”) were $0.8 million for each of the three month periods ended April 30, 2022January 31, 2023 and 2021.2022.
Net incomeloss attributable to noncontrolling interestinterests
Net loss attributable to noncontrolling interestinterests is the result of allocating profits and losses to noncontrolling interestinterests under the hypothetical liquidation at book value ("HLBV"(“HLBV”) method. HLBV is a balance sheet-oriented approach for applying the equity method of accounting when there is a complex structure, such as the flip structure of our tax equity financings with East West Bancorp, Inc. (“East West Bank”) and Renewable Energy Investors, LLC (“REI”).
For the three months ended April 30, 2022,January 31, 2023, net income attributable to noncontrolling interest totaled $0.1$0.4 million for the LIPA Yaphank project tax equity financing transaction with REI. For the three months ended January 31, 2022, net loss allocated to noncontrolling interest totaled $5.5 million for the LIPA Yaphank tax equity financing transaction with REI. The net loss for the three months ended January 31, 2022 was primarily driven by the Investment Tax Credit (“ITC”) attributable to the noncontrolling interest for the 2021 tax year. The ITC reduces the noncontrolling interests’ claim on hypothetical liquidation proceeds in the HLBV waterfall. This reduction in liquidation proceeds drove the loss in the three months ended January 31, 2022.
For the three months ended January 31, 2023, net loss attributable to noncontrolling interests totaled $2.9 million for the Groton Project tax equity financing transaction with East West Bank. There was no comparable net loss for the prior yearthree months ended January 31, 2022, as the LIPA YaphankGroton Project tax equity transaction closed and the LIPA Yaphank projectGroton Project began operatingoperations in the first quarter of fiscal year 2022.2023. The net loss for the three months ended January 31, 2023 is primarily driven by the ITC attributable to the noncontrolling interest for the 2022 tax year. The ITC reduces the noncontrolling interests’ claim on hypothetical liquidation proceeds in the HLBV waterfall. This reduction in liquidation proceeds drove the loss in the three months ended January 31, 2023.
Net loss attributable to common stockholders and loss per common share
Net loss attributable to common stockholders represents the net loss for the period less the preferred stock dividends on the Series B Preferred Stock. For the three month periods ended April 30,January 31, 2023 and 2022, and 2021, net loss attributable to common stockholders was $31.0$19.4 million and $19.7$41.4 million, respectively, and loss per common share was $0.08$0.05 and $0.06,
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$0.11, respectively. The increasedecrease in the net loss attributable to common stockholders for the three months ended April 30, 2022January 31, 2023 is primarily due to higherthe gross profit for the three months ended January 31, 2023 compared to gross loss for the three months ended April 30,January 31, 2022, compared to the corresponding period in fiscal year 2021, as well as higher interest expense and higherlower operating expenses during the three months ended April 30, 2022.January 31, 2023. The higherlower net loss per common share for the three months ended April 30, 2022January 31, 2023 as compared to the three months ended April 30, 2021January 31, 2022 is primarily due to due to the higherlower net loss attributable to common stockholders partially offset byand the higher number of weighted average shares outstanding due to share issuances since April 30, 2021.January 31, 2022.
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Comparison of Six Months Ended April 30, 2022 and 2021
Revenues and Costs of revenues
Our revenues and cost of revenues for the six months ended April 30, 2022 and 2021 were as follows:
| | | | | | | | | | | |
| | Six Months Ended April 30, | | Change | |||||||
(dollars in thousands) |
| 2022 |
| 2021 |
| $ |
| % | |||
Total revenues | | $ | 48,179 | | $ | 28,830 | | $ | 19,349 | | 67% |
Total costs of revenues | | | 58,384 | | | 37,204 | | | 21,180 | | 57% |
Gross loss | | $ | (10,205) | | $ | (8,374) | | $ | (1,831) | | 22% |
Gross margin | | | (21.2)% | | | (29.0)% | | | | | |
Total revenues for the six months ended April 30, 2022 of $48.2 million reflects an increase of $19.3 million from $28.8 million during the same period in the prior year. Cost of revenues for the six months ended April 30, 2022 of $58.4 million reflects a $21.2 million increase from $37.2 million during the same period in the prior year. A discussion of the changes in product revenues, service agreements revenues, generation revenues and Advanced Technologies contract revenues follows.
Product revenues
Our product revenues and related costs from product revenues for the six months ended April 30, 2022 and 2021 were as follows:
| | | | | | | | | | | |
| | Six Months Ended April 30, | | Change | |||||||
(dollars in thousands) |
| 2022 |
| 2021 |
| $ |
| % | |||
Product revenues | | $ | 18,000 | | $ | — | | $ | 18,000 | | N/A |
Cost of product revenues | | | 21,240 | | | 4,287 | | | 16,953 | | 395% |
Gross loss from product revenues | | $ | (3,240) | | $ | (4,287) | | $ | 1,047 | | (24)% |
Product revenues gross loss | | | (18.0)% | | | N/A | | | | | |
Product revenues for the six months ended April 30, 2022 were $18.0 million compared to $0 for the six months ended April 30, 2021. The increase in product revenues is a result of module sales to KFC for which the Company recognized $18.0 million on the delivery Ex Works of 6 modules from the Company’s facility in Torrington, Connecticut in January 2022.
Cost of product revenues increased $17.0 million for the six months ended April 30, 2022 to $21.2 million, compared to $4.3 million in the same period in the prior year. The increase is primarily due to the module sales to KFC. The increase also relates to a fixed asset impairment charge of approximately $1.0 million for the six months ended April 30, 2022 (related to the cessation of operations at a conditioning facility in Danbury, CT, which is being replaced by a new facility in Torrington, CT as a part of our fiscal year 2022 capital investments) and accrued warranty cost of approximately $0.2 million associated with the module sales to KFC discussed above. Manufacturing variances, primarily related to production volumes and unabsorbed overhead costs, totaled approximately $4.7 million for the six months ended April 30, 2022 compared to approximately $3.4 million for the six months ended April 30, 2021.
For the six months ended April 30, 2022, we operated at an annualized production rate of approximately 39.6 MW, which is an increase from the annualized production rate of 27 MW for the six months ended April 30, 2021.
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Service agreements revenues
Service agreements revenues and related costs for the six months ended April 30, 2022 and 2021 were as follows:
| | | | | | | | | | | |
| | Six Months Ended April 30, | | Change | |||||||
(dollars in thousands) |
| 2022 |
| 2021 |
| $ |
| % | |||
Service agreements revenues | | $ | 4,806 | | $ | 5,573 | | $ | (767) | | (14)% |
Cost of service agreements revenues | | | 5,405 | | | 7,966 | | | (2,561) | | (32)% |
Gross loss from service agreements revenues | | $ | (599) | | $ | (2,393) | | $ | 1,794 | | (75)% |
Service agreements revenues gross margin | | | (12.5)% | | | (42.9)% | | | | | |
Revenues for the six months ended April 30, 2022 from service agreements decreased $0.8 million to $4.8 million from $5.6 million for the six months ended April 30, 2021. The decline in service and license revenues for the six months ended April 30, 2022 is primarily due to fewer refurbished module exchanges.
Cost of service and license revenues decreased $2.6 million to $5.4 million for the six months ended April 30, 2022 from $8.0 million for the six months ended April 30, 2021. Cost of service and license revenues were lower for the six months ended April 30, 2022 than for the six months ended April 30, 2021 primarily due to the fact that less planned module exchanges in the service fleet occurred during the six months ended April 30, 2022 than during the six months ended April 30, 2021. Cost of service agreements includes maintenance and operating costs and module exchanges.
Overall gross loss from service agreements and license revenues was $0.6 million for the six months ended April 30, 2022, which represents a decrease of $1.8 million from a gross loss of $2.4 million for the six months ended April 30, 2021. The overall gross margin was (12.5)% for the six months ended April 30, 2022 compared to a gross margin of (42.9)% in the comparable prior year period. Gross margin decreased during the six months ended April 30, 2022, primarily due to the fact that there were fewer refurbished module exchanges for projects during the period.
Generation revenues
Generation revenues and related costs for the six months ended April 30, 2022 and 2021 were as follows:
| | | | | | | | | | | |
| | Six Months Ended April 30, | | Change | |||||||
(dollars in thousands) |
| 2022 |
| 2021 |
| $ |
| % | |||
Generation revenues | | $ | 16,546 | | $ | 11,076 | | $ | 5,470 | | 49% |
Cost of generation revenues | | | 24,842 | | | 16,537 | | | 8,305 | | 50% |
Gross loss from generation revenues | | $ | (8,296) | | $ | (5,461) | | $ | (2,835) | | 52% |
Generation revenues gross margin | | | (50.1)% | | | (49.3)% | | | | | |
Revenues from generation for the six months ended April 30, 2022 totaled $16.5 million, which represents an increase of $5.5 million from revenue recognized of $11.1 million for the six months ended April 30, 2021. Generation revenues for the six months ended April 30, 2022 and 2021 reflect revenue from electricity generated under our PPAs. The increase in generation revenues in the six months ended April 30, 2022 is primarily due to the higher operating output of the generation fleet portfolio as a result of investments in maintenance activities and an increase in the size of the fleet.
Cost of generation revenues totaled $24.8 million in the six months ended April 30, 2022. The increase from the comparable prior year period was primarily due to construction costs of approximately $7.8 million related to the Toyota project and costs of approximately $3.3 million related to the increased size of the installed fleet with the San Bernardino and LIPA Yaphank projects achieving commercial operations, offset by lower operating costs for existing plants due to efficiencies from plant maintenance activities and module replacements. As further background on the costs related to the Toyota project, it was determined in the fourth quarter of fiscal year 2021 that a potential source of RNG at favorable pricing was no longer sufficiently probable for the Toyota project. Thus, as the Toyota project is being constructed, only amounts that can be redeployed for alternative use are being capitalized. The balance of costs incurred (i.e., the construction costs mentioned above in an amount equal to $7.8 million) are being expensed as cost of generation revenues.
We currently have three projects in development with fuel sourcing risk, which are the Toyota project, which requires procurement of RNG, and our Derby, CT 14.0 MW and 2.8 MW projects, which require natural gas. Fuel sourcing and risk mitigation strategies for all three projects are being assessed and will be implemented as project operational dates become firm. Such strategies may require cash collateral or reserves to secure fuel or related contracts for these three
37
projects. If the Company is unable to secure fuel on favorable economic terms, impairment charges to these project assets may result.
Cost of generation revenues included depreciation and amortization of approximately $7.7 million and $8.0 million for the six months ended April 30, 2022 and 2021, respectively.
The increase in generation revenues gross margin loss is primarily related to the $7.8 million of construction costs being expensed related to the Toyota project, partially offset by higher margins from the operating fleet (due in part to the higher operating output of the generation fleet portfolio) compared to the six months ended April 30, 2021.
Advanced Technologies contract revenues
Advanced Technologies contract revenues and related costs for the six months ended April 30, 2022 and 2021 were as follows:
| | | | | | | | | | | |
| | Six Months Ended April 30, | | Change | |||||||
(dollars in thousands) |
| 2022 |
| 2021 |
| $ |
| % | |||
Advanced Technologies contract revenues | | $ | 8,827 | | $ | 12,181 | | $ | (3,354) | | (28)% |
Cost of Advanced Technologies contract revenues | | | 6,897 | | | 8,414 | | | (1,517) | | (18)% |
Gross profit from Advanced Technologies contracts | | $ | 1,930 | | $ | 3,767 | | $ | (1,837) | | (49)% |
Advanced Technologies contract gross margin | | | 21.9% | | | 30.9% | | | | | |
Advanced Technologies contract revenues decreased to $8.8 million for the six months ended April 30, 2022 from $12.2 million for the six months ended April 30, 2021. Compared to the six months ended April 30, 2021, Advanced Technologies contract revenues recognized under the EMTEC Joint Development Agreement were approximately $4.6 million lower during the six months ended April 30, 2022, partially offset by an increase in revenue recognized under government contracts and other contracts of $1.3 million for the six months ended April 30, 2022.
Cost of Advanced Technologies contract revenues decreased $1.5 million to $6.9 million for the six months ended April 30, 2022, compared to $8.4 million for the same period in the prior year based on the level of activity and the scope of work performed under the EMTEC Joint Development Agreement in the period. Advanced Technologies contracts for the six months ended April 30, 2022 generated a gross margin of $1.9 million compared to a gross margin of $3.8 million for the six months ended April 30, 2021 primarily due to the decrease in revenue recognized under the EMTEC Joint Development Agreement during the period, which resulted in a lower gross margin recognized during the period.
Administrative and selling expenses
Administrative and selling expenses were $50.2 million and $18.6 million for the six months ended April 30, 2022 and 2021, respectively. The six months ended April 30, 2022 included higher legal expenses associated with the settlement of the Company’s disputes with POSCO Energy and KFC (as described in additional detail in Note 19. “Commitments and Contingencies” to our Consolidated Financial Statements for the six months ended April 30, 2022 included in this Quarterly Report on Form 10-Q). The Company retained outside counsel on a contingency basis to pursue its claims against POSCO Energy and KFC, and outside counsel entered into an agreement with a litigation finance provider to fund the legal fees and expenses of the arbitration proceedings brought by the Company against POSCO Energy and KFC. In conjunction with the Settlement Agreement, dated December 20, 2021, among the Company, POSCO Energy and KFC (the “Settlement Agreement”), the Company is required to remit fees to its counsel, Wiley Rein, LLP (“Wiley”), subject to the terms of its engagement letter with Wiley. On December 23, 2021, the Company agreed that it would pay Wiley a total of $24.0 million to satisfy all obligations to Wiley under the Company’s engagement letter, of which $19.0 million was paid during the six months ended April 30, 2022, and $5.0 million will be paid on or before June 30, 2022. The increase is also related to higher sales, marketing and consulting costs, as the Company is investing in rebranding and accelerating its sales and commercialization efforts, including increasing the size of its sales and marketing teams which resulted in an increase in compensation expense resulting from an increase in headcount.
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Research and development expenses
Research and development expenses increased to $12.7 million for the six months ended April 30, 2022 compared to $4.8 million for the six months ended April 30, 2021. The increase relates to an increase in spending on the Company’s hydrogen commercialization initiatives compared to the comparable prior year period.
Loss from operations
Loss from operations for the six months ended April 30, 2022 was $73.1 million compared to $31.8 million for the six months ended April 30, 2021. This increase was primarily driven by a $39.5 million increase in operating expenses for the six months ended April 30, 2022 as a result of (a) administrative and selling expenses for the six months ended April 30, 2022, which included higher legal expenses associated with the settlement of the Company’s disputes with POSCO Energy and KFC as well as higher sales, marketing and consulting costs and an increase in compensation expense resulting from an increase in headcount and (b) research and development expenses, which were higher due to an increase in spending on the Company’s hydrogen commercialization initiatives compared to the comparable prior year period. The increase was also due to higher gross loss of $10.5 million during the six months ended April 30, 2022. Impacting gross loss for the six months ended April 30, 2022 were higher manufacturing variances and non-recoverable costs related to construction of the Toyota project which were partially offset by lower product gross loss primarily due to module sales to KFC.
Interest expense
Interest expense for the six months ended April 30, 2022 and 2021 was $3.1 million and $4.1 million, respectively. Interest expense for both periods presented includes interest related to financing obligations for failed sale-leaseback transactions and interest on the outstanding loans associated with the Bridgeport Fuel Cell Project.
Change in fair value of common stock warrant liability
The $16.0 million expense for the six months ended April 30, 2021 represents an adjustment to the estimated fair value of the outstanding unexercised warrants to purchase common stock held by the lenders under the Orion Credit Agreement (as defined below), which were exercised, in full, during the year ended October 31, 2021. The expense was primarily a result of an increase in the price of the Company’s common stock during the six months ended April 30, 2021.
Loss on extinguishment of debt
The loss on extinguishment of debt for the six months ended April 30, 2021 represents costs associated with the repayment of the $80.0 million principal balance outstanding under the Credit Agreement among the Company, certain of its affiliates as guarantors, Orion Energy Partners Investment Agent, LLC, and certain lenders affiliated therewith (as amended, the “Orion Credit Agreement”). The amount includes an early prepayment penalty of $4.0 million and the write-off of debt discounts and deferred finance costs of $7.2 million.
Extinguishment of preferred stock obligation of subsidiary
For the six months ended April 30, 2021, a charge of $0.9 million was recorded for the extinguishment of preferred stock obligation of subsidiary to adjust for the difference between the amount of the payoff of the obligation and the carrying amount of the obligation under the terms of the Class A Preferred Shares issued by FCE FuelCell Energy Ltd. (which are referred to elsewhere herein as the “Series 1 Preferred Shares”), which obligation was guaranteed by the Company.
Other expense, net
Other expense, net was $0.05 million and $(0.9) million for the six months ended April 30, 2022 and 2021, respectively. Other expense, net for the six months ended April 30, 2021 primarily relates to a foreign exchange loss of $0.8 million related to the remeasurement of the Canadian Dollar denominated preferred stock obligation (the Series 1 Preferred Share obligation) of our U.S. Dollar functional currency Canadian subsidiary (FCE FuelCell Energy Ltd.) prior to the payoff of the preferred share obligation in December 2020.
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Benefit for income taxes, net
We have not paid federal or state income taxes in several years due to our history of net operating losses, although we have paid foreign income and withholding taxes in Korea. There was no income tax provision recorded for the six months ended April 30, 2022 compared to an income tax benefit of $4 thousand for the six months ended April 30, 2021.
Series B preferred stock dividends
Dividends recorded on our Series B Preferred Stock were $1.6 million for each of the six month periods ended April 30, 2022 and 2021.
Net loss attributable to noncontrolling interest
For the six months ended April 30, 2022, net loss attributable to noncontrolling interest totaled $5.4 million for the LIPA Yaphank tax equity financing transaction with REI. There was no comparable net loss for the prior year as the LIPA Yaphank tax equity transaction closed and the LIPA Yaphank project began operating in the first quarter of fiscal year 2022. The loss is primarily driven by the Investment Tax Credit (“ITC”) attributable to the noncontrolling interest for the 2021 tax year (which is consistent with the calendar year). The ITC reduces the noncontrolling interest’s hypothetical liquidation proceeds. This reduction in hypothetical liquidation proceeds drove the net loss attributable to the noncontrolling interest in the period.
Net loss attributable to common stockholders and loss per common share
Net loss attributable to common stockholders represents the net loss for the period less the preferred stock dividends on the Series B Preferred Stock. For the six-month periods ended April 30, 2022 and 2021, net loss attributable to common stockholders was $72.4 million and $66.5 million, respectively, and loss per common share was $0.20 and $0.21, respectively. The increase in the net loss attributable to common stockholders for the six months ended April 30, 2022 is primarily due to higher gross loss and higher operating expenses for the six months ended April 30, 2022 compared to the corresponding period in fiscal year 2021, partially offset by (i) lower interest expense during the quarter, (ii) the fact that there was no loss on extinguishment of debt in the quarter, no loss on extinguishment of preferred stock obligation during the quarter, and no charge for the change in fair value of common stock warrant liability during the quarter and (iii) a net loss attributable to noncontrolling interest totaling $5.4 million (or approximately $0.01 per share) for the LIPA Yaphank tax equity financing transaction. The lower loss per common share for the six months ended April 30, 2022, as compared to the six months ended April 30, 2021, is primarily due to the higher weighted average shares outstanding as of April 30, 2022 as a result of share issuances since April 30, 2021.
LIQUIDITY AND CAPITAL RESOURCES
Overview, Cash Position, Sources and Uses
Our principal sources of cash have been proceeds from the sale of our products and projects, electricity generation revenues, research and development and service agreements with third parties, sales of our common stock through public equity offerings, and proceeds from debt, project financing and tax monetization transactions, proceeds from the sale of our projects, as well as research and development and service agreements with third parties.transactions. We have utilized this cash to accelerate the commercialization of our solid oxide platforms, develop new capabilities to separate and capture carbon, develop and construct project assets, invest in capital improvements and expansion of our operations, perform research and development on Advanced Technologies, pay down existing outstanding indebtedness, and meet our other cash and liquidity needs.
As of April 30, 2022,January 31, 2023, unrestricted cash and cash equivalents totaled $467.8$315.2 million compared to $432.2$458.1 million as of October 31, 2021.2022. During the three months ended January 31, 2023, the Company invested $75.0 million in United States (U.S.) Treasury Securities which have maturity dates ranging from February 9, 2023 to May 15, 2023. The amortized cost of these U.S. Treasury Securities totaled $75.7 million as of January 31, 2023 compared to $0 as of October 31, 2022 and are classified as Investments - short term on the Consolidated Balance Sheets.
On June 11, 2021,July 12, 2022, the Company entered into an Open Market Sale Agreement with Jefferies LLC, andB. Riley Securities, Inc., Barclays Capital Inc., BMO Capital Markets Corp., BofA Securities, Inc., Canaccord Genuity LLC, Citigroup Global Markets Inc., J.P. Morgan Securities LLC and Loop Capital Markets LLC (the “Open Market Sale Agreement”) with respect to an at the market offering program under which the Company may, from time to time, offer and sell up to 95.0 million shares of the Company’s common stock having an aggregate offering price of up to $500 million.stock. From the date of the Open Market Sale Agreement through April 30, 2022,January 31, 2023, the Company sold approximately 64.018.5 million shares were sold, resulting in cumulative gross proceeds to the Company totaling approximately $498.1 million before deducting expenses and sales commissions. Cumulative net proceeds to the Company totaled approximately $488.1 million after deducting commissions and offering expenses totaling approximately $10.0 million. During the three months ended April 30, 2022 (which is included in the broader period described in the preceding two sentences), approximately 19.9 million shares were sold under the Open
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Market Sale Agreement at an average salessale price of $6.07$3.63 per share, resulting in gross proceeds of $120.8approximately $67.2 million before deducting expensessales commissions and sales commissions. During the three months ended April 30, 2022,fees, and net proceeds to the Company totaledof approximately $118.3$65.4 million after deducting commissions and offering expensesfees totaling approximately $2.4$1.8 million. The remaining availabilityDuring the quarter ended January 31, 2023, no sales were made under the Open Market Sale Agreement asAgreement. As of April 30, 2022 wasJanuary 31, 2023, approximately $1.9 million.76.5 million shares were available for issuance under the Open Market Sale Agreement. The Company planscurrently intends to use the net proceeds from this offering to accelerate the development and commercialization of our Advanced Technologies products, including ourits product platforms (including, but not limited to, its solid oxide platform,and carbon capture platforms), for project development, formarket development, and internal research and development, to invest in capacity expansion for solid oxide and carbonate fuel cell manufacturing, and for project financing, working capital support, and general corporate purposes. The Company may also use the net proceeds from this offering to invest in joint ventures, acquisitions, and strategic growth investments and to acquire, license or invest in products, technologies or businesses that complement its business.
We believe that our unrestricted cash and cash equivalents, expected receipts from our contracted backlog, and release of short-term restricted cash less expected disbursements over the next twelve months will be sufficient to allow the Company to meet its obligations for at least one year from the date of issuance of thesethe financial statements.statements included in this Quarterly Report on Form 10-Q.
To date, we have not achieved profitable operations or sustained positive cash flow from operations. The Company’s future liquidity, infor fiscal year 20222023 and in the long-term, will depend on its ability to (i) timely complete current projects in process within budget, (ii) increase cash flows from its generation operating portfolio, including by meeting conditions required to timely commence operation of new projects, operating its generation operating portfolio in compliance with minimum performance guarantees and operating its generation operating portfolio in accordance with revenue expectations, (iii) obtain financing for project construction and manufacturing expansion, (iv) obtain permanent financing for its projects once constructed, (v) increase order and contract volumes, which would lead to additional product sales, service agreements and generation revenues, (vi) obtain funding for and receive payment for research and development under current and future Advanced Technologies contracts, (vii) successfully commercialize its Advanced Technologies platforms, including its solid oxide, hydrogen and carbon capture platforms, (viii) implement capacity expansion for solid oxide product manufacturing, (ix) implement the product cost reductions necessary to achieve profitable operations, (ix)(x) manage working capital and the Company’s unrestricted cash balance and (x)(xi) access the capital markets to raise funds through the sale of debt and equity securities, convertible notes, and other equity-linked instruments.
We are continually assessing different means by which to accelerate the Company’s growth, enter new markets, commercialize new products, and enable capacity expansion. Therefore, from time to time, the Company may consider
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and enter into agreements for one or more of the following: negotiated financial transactions, minority investments, collaborative ventures, technology sharing, transfer or other technology license arrangements, joint ventures, partnerships, acquisitions or other business transactions for the purpose(s) of geographic or manufacturing expansion and/or new product or technology development and commercialization, including hydrogen production through our carbonate and solid oxide platforms and storage and carbon capture, sequestration and utilization technologies.
Our business model requires substantial outside financing arrangements and satisfaction of the conditions of such arrangements to construct and deploy our projects andto facilitate the growth of our business. The Company has invested capital raised from sales of its common stock to build out its project portfolio. The Company has also utilized and expects to continue to utilize a combination of long-term debt and tax equity financing (e.g., sale-leaseback transactions, partnership flip transactions and partnership transactions)the monetization and/or transfer of eligible investment and production tax credits) to finance its project asset portfolio as these projects commence commercial operations.operations, particularly in light of the passage of the Inflation Reduction Act in August 2022. The Company may also seek to undertake private placements of debt securities of a portfolio of assets to finance its project asset portfolio. The proceeds of any such financing, if obtained, may allow the Company to reinvest capital back into the business and to fund other projects. We may also seek to obtain additional financing in both the debt and equity markets in the future. If financing is not available to us on acceptable terms if and when needed, or on terms acceptable to us or our lenders, if we do not satisfy the conditions of our financing arrangements, if we spend more than the financing approved for projects, if project costs exceed an amount that the Company can finance, or if we do not generate sufficient revenues or obtain capital sufficient for our corporate needs, we may be required to reduce or slow planned spending, reduce staffing, sell assets, seek alternative financing and take other measures, any of which could have a material adverse effect on our financial condition and operations.
Generation Operating Portfolio, Project Assets, and Backlog
To grow our generation operating portfolio, the Company will invest in developing and building turn-key fuel cell projects, which will be owned by the Company and classified as project assets on the balance sheet.Consolidated Balance Sheets. This strategy requires liquidity and the Company expects to continue to have increasing liquidity requirements as project sizes increase and more projects are added to backlog. We may commence building project assets upon the award of a project or execution of a multi-year PPA with an end-user that has a strong credit profile. Project development and construction cycles, which span the time between securing a PPA and commercial operation of the platform, vary substantially and can take years. As a result of these project cycles and strategic decisions to finance the construction of certain projects, we may need to make significant
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up-front investments of resources in advance of the receipt of any cash from the sale or long-term financing of such projects. To make these up-front investments, we may use our working capital, seek to raise funds through the sale of equity or debt securities, or seek other financing arrangements. Delays in construction progress and completing current projects in process within budget, or in completing financing or the sale of our projects may impact our liquidity in a material way.
Our generation operating portfolio (41.4(43.7 MW as of April 30, 2022)January 31, 2023, which includes 7.4 MW attributed to the design rated output of the Groton Project although the Groton Project is, and was as of January 31, 2023 and at the commencement of commercial operations in December 2022, operating at approximately 6.0 MW) contributes higher long-term cash flows to the Company than if these projects had been sold. In fiscal year 2021, our operating portfolio generated approximately $24.0 million of revenue. We expect thisgeneration revenue amount to continue to grow as additional projects achieve commercial operation, but this revenue amount may also fluctuate from year to year depending on platform output, operational performance and management and site conditions. The Company plans to continue to grow this portfolio while also selling projects to investors. As of April 30, 2022,January 31, 2023, the Company had projects representing an additional 34.919.4 MW in various stages of development and construction, which projects are expected to generate operating cash flows in future periods, if completed. Retaining long-term cash flow positive projects, combined with our service fleet, is expected to result in reduced reliance on new project sales to achieve cash flow positive operations, however, operations and performance issues could impact results. We have worked with and are continuing to work with lenders and financial institutions to secure construction financing, long-term debt, tax equity and sale-leasebacks for our project asset portfolio, but there can be no assurance that such financing can be attained, or that, if attained, it will be retained and sufficient.
As of April 30, 2022,January 31, 2023, net debt outstanding related to project assets was $71.9$68.7 million. Future required payments totaled $38.3$30.9 million as of April 30, 2022.January 31, 2023. The outstanding financingfinance obligations under our sale-leaseback transactions, which totaled $56.4$56.8 million as of April 30, 2022,January 31, 2023, include an embedded gain of $35.8$37.8 million representing the current carrying value of finance obligations less future required payments, which will be recognized at the end of the applicable lease terms.
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Our generation operating portfolio provides us with the full benefit of future cash flows, net of any debt service requirements.
The following table summarizes our generation operating portfolio as of April 30, 2022:January 31, 2023:
| | | | | | | | | | | | | | | | | | | | |
Project Name |
| Location |
| Power Off - Taker |
| Rated |
| Actual |
| PPA Term |
| Location |
| Power Off - Taker |
| Rated |
| Actual |
| PPA Term |
Central CT State University | | New Britain, CT | | CCSU (CT University) | | 1.4 | | Q2 ‘12 | | 10 | | New Britain, CT | | CCSU (CT University) | | 1.4 | | Q2 ‘12 | | 15 |
UCI Medical Center (“UCI”) | | Orange, CA | | UCI (CA University Hospital) | | 1.4 | | Q1 '16 | | 19 | ||||||||||
Riverside Regional Water | | Riverside, CA | | City of Riverside (CA Municipality) | | 1.4 | | Q4 '16 | | 20 | | Riverside, CA | | City of Riverside (CA Municipality) | | 1.4 | | Q4 '16 | | 20 |
Pfizer, Inc. | | Groton, CT | | Pfizer, Inc. | | 5.6 | | Q4 '16 | | 20 | | Groton, CT | | Pfizer, Inc. | | 5.6 | | Q4 '16 | | 20 |
Santa Rita Jail | | Dublin, CA | | Alameda County, California | | 1.4 | | Q1 '17 | | 20 | | Dublin, CA | | Alameda County, California | | 1.4 | | Q1 '17 | | 20 |
Bridgeport Fuel Cell Project | | Bridgeport, CT | | Connecticut Light and Power Company (CT Utility) | | 14.9 | | Q1 '13 | | 15 | | Bridgeport, CT | | Connecticut Light and Power Company (CT Utility) | | 14.9 | | Q1 '13 | | 15 |
Tulare BioMAT | | Tulare, CA | | Southern California Edison (CA Utility) | | 2.8 | | Q1 '20 | | 20 | | Tulare, CA | | Southern California Edison (CA Utility) | | 2.8 | | Q1 '20 | | 20 |
Triangle Street | | Danbury, CT | | Tariff - Eversource (CT Utility) | | 3.7 | | Q2 '20 | | Tariff | ||||||||||
San Bernardino | | San Bernardino, CA | | City of San Bernardino Municipal Water Department | | 1.4 | | Q3'21 | | 20 | | San Bernardino, CA | | City of San Bernardino Municipal Water Department | | 1.4 | | Q3'21 | | 20 |
LIPA Yaphank Project | | Long Island, NY | | PSEG / LIPA, LI NY (Utility) | | 7.4 | | Q1'22 | | 18 | | Long Island, NY | | PSEG / LIPA, LI NY (Utility) | | 7.4 | | Q1'22 | | 18 |
Groton Project | | Groton, CT | | CMEEC (CT Electric Co-op) | | 7.4 | (2) | Q1'23 | | 20 | ||||||||||
| | | | Total MW Operating: | | 41.4 | | | | | | | | Total MW Operating: | | 43.7 | | | | |
(1) | Rated capacity is the platform’s design rated output as of the date of initiation of commercial |
(2) | As previously disclosed, the Groton Project achieved commercial operations on December 16, 2022. On December 16, 2022, the Company entered into an amended and restated power purchase agreement (“Amended and Restated PPA”) which modified and replaced the existing power purchase agreement with Connecticut Municipal Electric Energy Cooperative (“CMEEC”) to allow the Groton Project to operate at a reduced output of approximately 6 MW while a Technical Improvement Plan (“TIP”) is implemented with the goal of bringing the platform to its rated capacity of 7.4 MW by December 31, 2023. In conjunction with entering into the Amended and Restated PPA, on December 16, 2022, the Company and CMEEC declared that the plants are commercially operational at 6 MW and CMEEC and the Company agreed that, for all purposes, the commercial operations date had been achieved. The Navy also provided its authorization to proceed with commercial operations at 6 MW. The Company is incurring and will continue to incur performance guarantee fees under the Amended and Restated PPA as a result of operating at an output below 7.4 MW during implementation of the TIP. Although the Company believes it will successfully implement the TIP and bring the plant up to its design rated output of 7.4 MW by December 31, 2023, no assurance can be provided that such work will be successful. In the event that the plants do not reach an output of 7.4 MW by December 31, 2023, the Amended and Restated PPA will continue in effect, and the Company will be subject to ongoing performance guarantee fees. |
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The following table summarizes projects in process, all of which are in backlog, as of April 30, 2022:January 31, 2023:
| | | | | | | | | | | | | | | | |
Project Name |
| Location |
| Power Off-Taker |
| Rated |
| PPA |
| Location |
| Power Off-Taker |
| Rated |
| PPA |
Groton Sub Base | | Groton, CT | | CMEEC (CT Electric Co-op) | | 7.4 | | 20 | ||||||||
Toyota | | Los Angeles, CA | | Southern California Edison; Toyota | | 2.3 | | 20 | | Los Angeles, CA | | Southern California Edison; Toyota | | 2.3 | | 20 |
CT RFP-1 | | Hartford, CT | | Eversource/United Illuminating (CT Utilities) | | 7.4 | | 20 | ||||||||
CT RFP-2 | | Derby, CT | | Eversource/United Illuminating (CT Utilities) | | 14.0 | | 20 | | Derby, CT | | Eversource/United Illuminating (CT Utilities) | | 14.0 | | 20 |
SCEF - Derby | | Derby, CT | | Eversource/United Illuminating (CT Utilities) | | 2.8 | | 20 | | Derby, CT | | Eversource/United Illuminating (CT Utilities) | | 2.8 | | 20 |
SCEF - Hartford | | Hartford, CT | | Eversource/United Illuminating (CT Utilities) | | 1.0 | | 20 | ||||||||
Trinity College | | Hartford, CT | | Trinity College | | 0.3 | | 15 | ||||||||
| | | | Total MW in Process: | | 34.9 | | | | | | Total MW in Process: | | 19.4 | | |
(1) | Rated capacity is the platform’s design rated output as of the date of initiation of commercial operations. |
The projects listed in the above table are in various stages of development or on-site construction and installation. Current project updates are as follows:
In addition, as previously disclosed, in August 2021, the Company closed on a tax equity financing transaction with East West Bancorp, Inc. (“East West Bank”) for the Groton Project. East West Bank’s tax equity commitment totals $15 million. In connection with the initial closing, the Company was able to draw down $3.0 million. The Company is eligible to draw the remaining amount of the commitment, approximately $12 million, once the Groton Project achieves commercial operation. Under the terms of the Company’s agreement with East West Bank, the project had a required commercial operation deadline of October 18, 2021. East West Bank granted several extensions of the commercial operation deadline, most recently to May 15, 2022, in exchange for fees of $0.4 million in the aggregate. Because commercial operations are delayed beyond May 15, 2022 and no further extensions have been granted by East West Bank, East West Bank has a conditional withdrawal right to request the return of their investment at an amount equal to 101% of the amount of the investment. East West Bank has not exercised this right as of the date of this report.
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● | Toyota - Port of Long Beach, CA – The Toyota Project. This |
● | Derby, |
Backlog by revenue category is as follows:
● | Service agreements backlog totaled |
● | Generation backlog totaled $0.9 billion as of January 31, 2023 compared to $1.1 billion as of |
● | There was no product sales backlog as of January 31, 2023. Product sales backlog totaled $60.2 million as of |
● | Advanced Technologies contract backlog totaled |
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Backlog increaseddecreased by approximately 0.2%19% to $1.33$1.06 billion as of April 30, 2022January 31, 2023, compared to $1.32$1.30 billion as of April 30, 2021,January 31, 2022, primarily as a result of the addition of product sales backlog, partially offset by a reduction in service agreementsgeneration backlog and Advanced Technologies contract backlog, and reflectingdue to the continued executiondecision to not move forward with certain generation projects during the fourth quarter of backlog and adjustmentsfiscal year 2022. The reduction was also due, in part, to generation backlog. Specifically, changes to backlog reflect: (i) the addition of product sales backlog from the module order received from KFC, and (ii) module exchanges in our generation operating portfolio that are expected to contribute to higher future output and revenues. Advanced Technologies contract backlog reflects new contracts from the U.S. Department of Energy partially offset by work performed under the EMTEC Joint Development Agreement.revenue recognition since January 31, 2022.
Backlog represents definitive agreements executed by the Company and our customers. Projects for which we have an executed PPA are included in generation backlog, which represents future revenue under long-term PPAs. The Company’s ability to recognize revenue in the future under a PPA is subject to the Company’s completion of construction of the project covered by such PPA. Should the Company not complete the construction of the project covered by a PPA, it will forgo future revenues with respect to the project and may incur penalties and/or impairment charges related to the project. Projects sold to customers (and not retained by the Company) are included in product sales and service agreements backlog, and the related generation backlog is removed upon sale. Together, the service and generation portion of backlog had a weighted average term of approximately 1817 years, with weighting based on the dollar amount of backlog and utility service contracts of up to 20 years in duration at inception.inception.
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Factors that may impact our liquidity
Factors that may impact our liquidity both in fiscal year 20222023 and in periods beyond fiscal year 2022 include:
● | The Company’s cash on hand and access to additional liquidity. As of |
● | We bid on large projects in diverse markets that can have long decision cycles and uncertain outcomes. |
● | We manage production rate based on expected demand and project schedules. Changes to production rate take time to implement. |
● | As project sizes and the number of projects evolve, project cycle times may increase. We may need to make significant up-front investments of resources in advance of the receipt of any cash from the financing or sale of our projects. These amounts include development costs, interconnection costs, costs associated with posting of letters of credit, bonding or other forms of security, and engineering, permitting, legal, and other expenses. |
● | The amount of accounts receivable and unbilled receivables as of |
● | The amount of total inventory as of |
● | The amount of total project assets as of |
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operating project assets (which includes 7.4 MW attributed to the design rated output of the Groton Project although the Groton Project is, and was as of January 31, 2023 and at the commencement of commercial operations in December 2022, operating at approximately 6.0 MW) that generated |
● | As of |
● | Certain of our PPAs for project assets in our generation operating portfolio and project assets under construction expose us to fluctuating fuel price risks as well as the risk of being unable to procure the required amounts of fuel and the lack of alternative available fuel sources. We seek to mitigate our fuel risk using strategies including: (i) fuel |
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cost reimbursement mechanisms in our PPAs to allow for pass through of fuel costs (full or partial) where possible, which we have done with our 14.9 MW operating project in Bridgeport, |
We currently have three projects in development with fuel sourcing risk, which are the Toyota project, which requires procurement of RNG,renewable natural gas (“RNG”), and our Derby, CT 14.0 MW and 2.8 MW projects, both of which require natural gas for which there is no pass through mechanism.mechanism in the related PPAs. Fuel sourcing and risk mitigation strategies for all three projects are being assessed and will be implemented as project operational dates become firm. Such strategies may require cash collateral or reserves to secure fuel or related contracts for these three projects.
● | Capital expenditures are expected to range between |
We have made progress in advancing our carbonate and solid oxide platform capacity expansion plans.
Carbonate Platform:At this time, the maximum annualized capacity (module manufacturing, final assembly, testing and conditioning) is 100 MW per year under the Torrington facility’s current configuration when fully utilized. The Torrington facility is sized to accommodate the eventual annualized production capacity of up to 200 MW per year with additional capital investment in machinery, equipment, tooling, labor and inventory.
The Company continues to invest in capability with the goal of reducing production bottlenecks and driving productivity, including investments in automation, laser welding, and the construction of additional integrated conditioning capacity. The Company also constructed a SureSource 1500 in Torrington during fiscal year 2022, which operates as a testing facility for qualifying new supplier components and performance testing and validation of continued platform innovations. During fiscal year 2023, the Company expects to invest in adding the engineered carbon separation capability to the onsite SureSource 1500, which will allow potential customers to observe the operating plant and, given the targeted market of food and beverage companies, will allow for the sampling and testing of separated CO2 to verify quantity, quality or purity requirements.
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Solid Oxide Platform: During the three months ended January 31, 2023, Versa Ltd., a subsidiary of FuelCell Energy, entered into a lease expansion, extension and amending agreement which expanded the space to be leased by Versa Ltd. in Calgary, Alberta, Canada to include an additional approximately 48,000 square feet, for a total of approximately 80,000 square feet of space. Additionally, long-lead process equipment has been ordered to facilitate the expansion of manufacturing capacity for the solid oxide platforms in Calgary. Upon the completion of the Calgary capacity expansion, the Company expects that it will be able to increase annual production capacity and that it will be capable of delivering up to 40 MWs of annualized electrolysis production per year.
During calendar year 2023, our Calgary manufacturing operation is expected to build and deliver four units: two units that will run internally for advanced testing and two first article production units for delivery externally. Of these commercial units for external delivery, one will be our electrolysis platform for delivery to Idaho National Laboratory, and the other will be our distributed power platform for delivery to Trinity College in Hartford, Connecticut for use under a long-term power purchase agreement.
The expansion of the Calgary manufacturing facility is phase 1 of the Company’s planned operational expansion of production capability. While this expansion is expected to increase our production capacity from 4 MWs per year to 40 MWs per year of solid oxide electrolyzers, the Company has plans to add an additional 400 MW of solid oxide manufacturing capacity in the United States. While the location of the facility has not yet been determined, early facility design and engineering requirements have been developed. We anticipate announcing more details regarding our plans for solid oxide production expansion into the United States later this fiscal year.
● |
● | Under the terms of certain contracts, the Company will provide performance security for future contractual obligations. As of |
● | On August 16, 2022, the U.S. Inflation Reduction Act (“IRA” or the "Act") was signed into law. The provisions of the IRA are intended to, among other things, incentivize domestic clean energy investment, manufacturing and production. The IRA includes provisions that provide incentives for clean energy through enhancement of the Investment Tax Credit (“ITC”) program, Production Tax Credits for clean energy component sourcing and production in the United States, enhancements to Section 45Q of the Internal Revenue Code which provides credits for carbon oxide sequestration intended to incentivize investment in carbon capture and sequestration, and certain incentives for clean energy projects that use environmental brownfield sites and/or are located in economically challenged areas. In addition, the Act would provide a 10-year Production Tax Credit (“PTC”) for the production of clean hydrogen at a qualified facility that begins construction prior to January 1, 2033, with the option to elect the ITC in lieu of the PTC. The Company views the enactment of the IRA as favorable for the overall business climate for fuel cell manufacturers, however, the Company is continuing to evaluate the overall impact and applicability of the IRA to the Company’s current and planned products and the markets in which the Company seeks to sell its products. |
● | As global policies evolve, there may be incentives available to the Company and potential customers that may help to accelerate the growth of projects utilizing FuelCell Energy’s platform. We continue to see broad support for the energy transition through legislation and economic incentives globally. For example, the European Union recently proposed an approximately $270 billion program that would offer tax breaks for businesses investing in net-zero |
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technology, and in Korea, the Korean Hydrogen Economy Roadmap aims to produce 6.2 million fuel cell electric vehicles and deploy at least 1,200 hydrogen refueling stations by 2040. Additionally, Japan’s Sixth Strategy Energy Plan would target decarbonizing power sources through increased hydrogen production as well as the broad deployment of carbon capture utilization and sequestration technology. |
Depreciation and Amortization
As the Company builds project assets and makes capital expenditures, depreciation and amortization expenses are expected to increase. For the three months ended April 30,January 31, 2023 and 2022, and 2021, depreciation and amortization totaled $5.3$5.4 million and $4.8$5.8 million, respectively (of these totals, approximately $4.1$4.2 million and $3.6 million for the three months ended April 30,January 31, 2023 and 2022, and 2021, respectively, relate to depreciation and amortization of project assets in our generation operating portfolio). For the six months ended April 30, 2022 and 2021, depreciation and amortization totaled $11.1 million and $10.4 million, respectively (of these totals, approximately $7.7 million and $8.0 million for the six months ended April 30, 2022 and 2021, respectively, relate to depreciation of project assets in our generation operating portfolio).
Cash Flows
Cash and cash equivalents and restricted cash and cash equivalents totaled $489.6$339.8 million as of April 30, 2022January 31, 2023 compared to $460.2$481.0 million as of October 31, 2021.2022. As of April 30, 2022,January 31, 2023, unrestricted cash and cash equivalents was $467.8$315.2 million compared to $432.2$458.1 million of unrestricted cash and cash equivalents as of October 31, 2021.2022. As of April 30, 2022,January 31, 2023, restricted cash and cash equivalents was $21.8$24.6 million, of which $5.3$4.5 million was classified as current and $16.5$20.2 million was classified as non-current, compared to $28.0$23.0 million of restricted cash and cash equivalents as of October 31, 2021,2022, of which $11.3$4.4 million was classified as current and $16.7$18.6 million was classified as non-current.
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The following table summarizes our consolidated cash flows:
| | | | | | | | | | | | ||
| | Six months ended April 30, | | Three Months Ended January 31, | |||||||||
(dollars in thousands) |
| 2022 | | 2021 |
| 2023 | | 2022 |
| ||||
Consolidated Cash Flow Data: | | | | | | | | | | | | ||
Net cash used in operating activities | | $ | (64,707) | | $ | (41,162) | | $ | (53,377) | | $ | (47,754) | |
Net cash used in investing activities | | | (29,088) | | | (22,172) | | | (84,822) | | | (15,766) | |
Net cash provided by financing activities | | | 123,375 | | | 42,466 | |||||||
Net cash (used in) provided by financing activities | | | (3,513) | | | 8,830 | | ||||||
Effects on cash from changes in foreign currency rates | | | (240) | | | (2) | | | 447 | | | (91) | |
Net increase (decrease) in cash, cash equivalents and restricted cash | | $ | 29,340 | | $ | (20,870) | |||||||
Net decrease in cash, cash equivalents and restricted cash | | $ | (141,265) | | $ | (54,781) | |
The key components of our cash inflows and outflows were as follows:
Operating Activities – Net cash used in operating activities was $64.7$53.4 million during the sixthree months ended April 30, 2022,January 31, 2023, compared to $41.2$47.8 million of net cash used in operating activities during the sixthree months ended April 30, 2021.January 31, 2022.
Net cash used in operating activities for the sixthree months ended April 30,January 31, 2023 was primarily a result of the net loss of $21.1 million, increases in inventories of $10.3 million, unbilled receivables of $5.0 million and other assets of $1.0 million and decreases in deferred revenue of $18.1 million, accrued liabilities of $7.1 million and accounts payable of $1.1 million partially offset by decreases in accounts receivable of $1.7 million and non-cash adjustments of $8.8 million.
Net cash used in operating activities for the three months ended January 31, 2022 was primarily a result of the net loss of $76.2$46.1 million, increases in inventories of $20.0$2.5 million, unbilled receivables of $4.4 million, accounts receivable of $1.4$16.0 million, and other assets of $6.2$2.0 million, and unbilled receivables of $0.2 million, partially offset by increases in deferred revenue of $11.4$1.7 million, accrued liabilities of $8.1$10.0 million, and accounts payable of $2.6 million and non-cash adjustments of $18.0$9.3 million.
Net cash used in operating activities for the six months ended April 30, 2021 was primarily a result of the net loss of $64.9 million, increases in inventories of $13.6 million, unbilled receivables of $0.6 million, other assets of $2.9 million, and accounts receivable of $2.6 million, and decreases in accrued liabilities of $2.9 million partially offset by increases in accounts payable of $3.3 million and deferred revenue of $2.3 million and non-cash adjustments of $41.4 million.
Investing Activities – Net cash used in investing activities was $29.1$84.8 million for the sixthree months ended April 30, 2022,January 31, 2023, compared to net cash used in investing activities of $22.2$15.8 million during the sixthree months ended April 30, 2021.January 31, 2022.
Net cash used in investing activities for the sixthree months ended April 30, 2022January 31, 2023 included $18.7$75.0 million for the purchase of U.S. Treasury Securities, $7.8 million of capital expenditures and $2.1 million of project asset expenditures and $10.4 million of capital expenditures.
Net cash used in investing activities for the sixthree months ended April 30, 2021January 31, 2022 included $21.2$10.4 million of project asset expenditures and $1.0$5.3 million of capital expenditures.
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Financing Activities – Net cash provided byused in financing activities was $123.4$3.5 million during the sixthree months ended April 30, 2022,January 31, 2023, compared to net cash provided by financing activities of $42.5$8.8 million during the sixthree months ended April 30, 2021.January 31, 2022.
Net cash used in financing activities during the three months ended January 31, 2023 resulted from debt repayments of $2.3 million, payments for taxes related to net share settlement of equity awards of $0.3 million, payment of $0.8 million in preferred dividends and distribution to noncontrolling interest of $0.1 million.
Net cash provided by financing activities during the sixthree months ended April 30,January 31, 2022 resulted from $118.3 million of net proceeds from sales of common stock and $12.4 million of contributions received from the sale of a noncontrolling interest in our tax equity partnership for the LIPA Yaphank Project, partially offset by debt repayments of $4.9 million, return of capital to noncontrolling interest of $0.5$2.5 million, payment for taxes related to net share settlement of equity awards of $0.3 million, payment of $1.6 million for preferred dividends and distribution to noncontrolling interest of $0.1 million.
Net cash provided by financing activities during the six months ended April 30, 2021 resulted from $156.4 million of net proceeds from sales of common stock and $0.9 million of proceeds received from warrant conversions, offset by debt repayments of $91.7 million primarily relating to the payoff of amounts owed under the Orion Credit Agreement and the April 2020 Paycheck Protection Program Promissory Note, payment of preferred dividends and return of capital of $1.6 million under the terms of the Series 1 Preferred Shares, and payment of $21.5$0.8 million to satisfy our obligations under the terms of the Series 1 Preferred Shares.
in preferred dividends.
Sources and Uses of Cash and Investments
In order to consistently produce positive cash flow from operations, we need to increase order flow to support higher production levels, leading to lower costs on a per unit basis. We also continue to invest in new product and market
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development and, as a result, we are not generating positive cash flow from our operations. Our operations are funded primarily through cash generated from product sales, service contracts, generation assets and Advanced Technologies contracts, as well as sales of equity and equity linked securities, issuances of corporate and project level debt, and monetization of technology through licenses.
Commitments and Significant Contractual Obligations
A summary of our significant commitments and contractual obligations as of April 30, 2022January 31, 2023 and the related payments by fiscal year are as follows:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Payments Due by Period | | Payments Due by Period | ||||||||||||||||||||||||||
(dollars in thousands) |
| Total |
| Less than |
| 1 – 3 |
| 3 – 5 |
| More than |
| Total |
| Less than |
| 1 – 3 |
| 3 – 5 |
| More than | ||||||||||
Purchase commitments (1) | | $ | 95,787 | | $ | 95,164 | | $ | 623 | | $ | — | | $ | — | | $ | 77,107 | | $ | 76,283 | | $ | 710 | | $ | 114 | | $ | — |
Term loans (principal and interest) | | | 32,286 | | | 8,139 | | | 15,471 | | | 4,791 | | | 3,885 | | | 27,270 | | | 7,880 | | | 12,099 | | | 4,166 | | | 3,125 |
Capital and operating lease commitments (2) | | | 18,617 | | | 1,477 | | | 1,792 | | | 1,545 | | | 13,803 | | | 19,599 | | | 1,176 | | | 2,550 | | | 2,612 | | | 13,261 |
Sale-leaseback financing obligation (3) | | | 19,735 | | | 3,304 | | | 6,550 | | | 5,191 | | | 4,690 | |||||||||||||||
Sale-leaseback finance obligations (3) | | | 17,236 | | | 3,259 | | | 6,487 | | | 3,742 | | | 3,748 | |||||||||||||||
Natural gas supply contract (4) | | | 12,634 | | | 1,969 | | | 3,938 | | | 3,938 | | | 2,789 | | | 11,158 | | | 1,969 | | | 3,938 | | | 3,938 | | | 1,313 |
Series B Preferred dividends payable (5) | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — |
Totals | | $ | 179,059 | | $ | 110,053 | | $ | 28,374 | | $ | 15,465 | | $ | 25,167 | | $ | 152,370 | | $ | 90,567 | | $ | 25,784 | | $ | 14,572 | | $ | 21,447 |
(1) | Purchase commitments with suppliers for materials, supplies and services incurred in the normal course of business. |
(2) | Future minimum lease payments on finance and operating leases. |
(3) | Represents payments due under sale-leaseback transactions and related financing agreements between certain of our wholly-owned subsidiaries and PNC Energy Capital, LLC (“PNC”) and/or Crestmark Equipment Finance (“Crestmark”) (as applicable). Lease payments for each lease under these financing agreements are generally payable in fixed quarterly installments over a 10-year period. |
(4) | During fiscal year 2020, the Company entered into a 7-year natural gas contract with an estimated annual cost per year of $2.0 million |
(5) | We pay $3.2 million in annual dividends on our Series B Preferred Stock, if and when declared. The $3.2 million annual dividend payment, if dividends are declared, has not been included in this table as we cannot reasonably determine when or if we will be able to convert the Series B Preferred Stock into shares of our common stock. We may, at our option, convert these shares into the number of shares of our common stock that are issuable at the then prevailing conversion rate if the closing price of our common stock exceeds 150% of the then prevailing conversion price ($1,692 per share at |
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Outstanding Loans
Connecticut Green Bank Loans
As of October 31, 2019, the Company had a long-term loan agreement with the Connecticut Green Bank, providing the Company with a loan of $1.8 million (the “Green Bank Loan Agreement”). On and effective as of December 19, 2019, the Company and Connecticut Green Bank entered into an amendment to the Green Bank Loan Agreement (the “Green Bank Amendment”). Upon the execution of the Green Bank Amendment on December 19, 2019, Connecticut Green Bank made an additional loan to the Company in the aggregate principal amount of $3.0 million (the “December 2019 Loan”), which was to be used (i) first, to pay closing fees related to the May 9, 2019 acquisition of the Bridgeport Fuel Cell Project and the Subordinated Credit Agreement (as defined below), other fees and interest, and (ii) thereafter, for general corporate purposes.
The Green Bank Amendment provides that, until such time as the loan (which includes both the outstanding principal balance of the original loan under the Green Bank Loan Agreement and the outstanding principal amount of the December 2019 Loan) has been repaid in its entirety, interest on the outstanding balance of the loan shall accrue at a rate of 8% per annum, payable by the Company on a monthly basis in arrears. Interest payments made by the Company after the date of the Green Bank Amendment are to be applied first to interest that has accrued on the outstanding principal balance of the original loan under the Green Bank Loan Agreement and then to interest that has accrued on the December 2019 Loan.
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The Green Bank Amendment also modifies the repayment and mandatory prepayment terms and extends the maturity date set forth in the original Green Bank Loan Agreement. Under the Green Bank Amendment, to the extent that excess cash flow reserve funds under the BFC Credit Agreement (as defined below) are eligible for disbursement to Bridgeport Fuel Cell, LLC pursuant to Section 6.23(c) of the BFC Credit Agreement, such funds are to be paid to Connecticut Green Bank until the loans are repaid in full. The Green Bank Amendment further provides that any unpaid balance of the loan and all other obligations due under the Green Bank Loan Agreement will be due and payable on May 9, 2026. Finally, with respect to mandatory prepayments, the Green Bank Amendment provides that, when the Company has closed on the subordinated project term loan pursuant to the Commitment Letter, dated February 6, 2019, issued by Connecticut Green Bank to Groton Station Fuel Cell, LLC (“Groton Fuel Cell”) to provide a subordinated project term loan to Groton Fuel Cell in the amount of $5.0 million, the Company will be required to prepay to Connecticut Green Bank the lesser of any then outstanding amount of the December 2019 Loan and the amount of the subordinated project term loan actually advanced by Connecticut Green Bank. The balance under the original Green Bank Loan Agreement and the December 2019 Loan as of April 30, 2022January 31, 2023 was $4.8 million.
Bridgeport Fuel Cell Project Loans
On May 9, 2019, in connection with the closing of the purchase of the membership interests of Bridgeport Fuel Cell, LLC (“BFC”) (and the 14.9 MW Bridgeport Fuel Cell Project), BFC (a subsidiary of the Company following the closing) entered into a subordinated credit agreement with the Connecticut Green Bank whereby Connecticut Green Bank provided financing in the amount of $6.0 million (the “Subordinated Credit Agreement”). This $6.0 million consisted of $1.8 million in incremental funding that was received by BFC and $4.2 million of funding previously received by FuelCell Energy, Inc. with respect to which BFC became the primary obligor. As security for the Subordinated Credit Agreement, Connecticut Green Bank received a perfected lien, subordinated and second in priority to the liens securing the $25.0 million loaned under the BFC Credit Agreement (as defined below), in all of the same collateral securing the BFC Credit Agreement. The interest rate under the Subordinated Credit Agreement is 8% per annum. Principal and interest are due monthly in amounts sufficient to fully amortize the loan over an 84-month period ending in May 2026. The Subordinated Credit Agreement contains customary representations, warranties and covenants. The Subordinated Credit Agreement contains a debt coverage ratio which is required to be maintained and may not be less than 1.10 as of the end of each fiscal quarter, beginning with the quarter ended July 31, 2020. The balance under the Subordinated Credit Agreement as of April 30, 2022January 31, 2023 was $3.9$3.3 million.
On May 9, 2019, in connection with the closing of the purchase of the Bridgeport Fuel Cell Project, BFC entered into a Credit Agreement with Liberty Bank, as administrative agent and co-lead arranger, and Fifth Third Bank as co-lead arranger and interest rate swap hedger (the “BFC Credit Agreement”), whereby (i) Fifth Third Bank provided financing in the amount of $12.5 million towards the purchase price for the BFC acquisition; and (ii) Liberty Bank provided financing in the amount of $12.5 million towards the purchase price for the BFC acquisition. As security for the BFC Credit Agreement, Liberty Bank and Fifth Third Bank were granted a first priority lien in (i) all assets of BFC, including BFC’s cash accounts, fuel cells, and all other personal property, as well as third party contracts including the Energy Purchase
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Agreement between BFC and Connecticut Light and Power Company dated July 10, 2009, as amended; (ii) certain fuel cell modules that are intended to be used to replace the Bridgeport Fuel Cell Project’s fuel cell modules as part of routine operation and maintenance; and (iii) FuelCell Energy Finance, LLC’s (a wholly-owned subsidiary of the Company and the direct parent of BFC) ownership interest in BFC. The maturity date under the BFC Credit Agreement is May 9, 2025. Monthly principal and interest are to be paid in arrears in an amount sufficient to fully amortize the term loan over a 72-month period. BFC has the right to make additional principal payments or pay the balance due under the BFC Credit Agreement in full, provided that it pays any associated breakage fees with regard to the interest rate swap agreements fixing the interest rate. The interest rate under the BFC Credit Agreement fluctuates monthly at the 30-day LIBOR rate plus 275 basis points.
An interest rate swap agreement was required to be entered into with Fifth Third Bank in connection with the BFC Credit Agreement to protect against movements in the floating LIBOR index. Accordingly, on May 16, 2019, an interest rate swap agreement (the “Swap Agreement”) was entered into with Fifth Third Bank in connection with the BFC Credit Agreement for the term of the loan. The net interest rate across the BFC Credit Agreement and the swap transaction results in a fixed rate of 5.09%. The interest rate swap is adjusted to fair value on a quarterly basis. The estimated fair value is based on Level 2 inputs including primarily the forward LIBOR curve available to swap dealers. The valuation methodology involves comparison of (i) the sum of the present value of all monthly variable rate payments based on a reset rate using the forward LIBOR curve and (ii) the sum of the present value of all monthly fixed rate payments on the notional amount, which is equivalent to the outstanding principal amount of the loan. The fair value adjustments for the three months ended April 30,January 31, 2023 and 2022 and 2021 resulted in a $0.3 million gain and a $0.1 million gain, respectively, and for the six months ended April 30, 2022 and 2021 resulted in a $0.5 million gainloss and a $0.2 million gain, respectively. The
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fair value of the interest rate swap asset at April 30,as of January 31, 2023 and October 31, 2022 was $0.1$0.2 million and $0.3 million, respectively. On August 1, 2022, the fair value of theCompany entered into an amendment to its interest rate swap liability at October 31, 2021 $0.5 million.agreement that replaced LIBOR with Term Secured Overnight Financing Rate (“SOFR”) effective as of June 2023.
The BFC Credit Agreement requires BFC to maintain a debt service reserve. Each of Liberty Bank and Fifth Third Bank also has an operation and module exchangereplacement reserve (“O&M Reserve”) under the BFC Credit Agreement. BFC is required to deposit $100,000$0.1 million per month into each O&M Reserve for the first five years of the BFC Credit Agreement, with such funds to be released at the sole discretion of Liberty Bank and Fifth Third Bank, as applicable. BFC is also required to maintain excess cash flow reserve accounts at each of Liberty Bank and Fifth Third Bank. Excess cash flow consists of cash generated by BFC from the Bridgeport Fuel Cell Project after payment of all expenses (including after payment of intercompany service fees to the Company), debt service to Liberty Bank and Fifth Third Bank, the funding of all required reserves, and payments to Connecticut Green Bank for the subordinated facility. BFC is also required to maintain a debt service coverage ratio of not less than 1.20, measured for the trailing year based on fiscal quarters beginning with the quarter ended July 31, 2020. The Company was in compliance with the debt service coverage ratio as of January 31, 2023. The Company has certain quarterly and annual financial reporting requirements under the BFC Credit Agreement. The annual financial statements to be provided pursuant to such requirements are to be audited and accompanied by a report of an independent certified public accountant, which report shall not include a “going concern” matter of emphasis or any qualification as to the scope of such audit.
State of Connecticut Loan
In October 2015, the Company closed on a definitive Assistance Agreement with the State of Connecticut (the “Assistance Agreement”) and received a disbursement of $10.0 million, which was used for the first phase of the expansion of the Company’s Torrington, Connecticut manufacturing facility. In conjunction with this financing, the Company entered into a $10.0 million promissory note and related security agreements securing the loan with equipment liens and a mortgage on its Danbury, Connecticut location. Interest accrues at a fixed interest rate of 2.0%, and the loan is repayable over 15 years from the date of the first advance, which occurred in October of 2015. Principal payments were deferred for four years from disbursement and began on December 1, 2019. Under the Assistance Agreement, the Company was eligible for up to $5.0 million in loan forgiveness if the Company created 165 full-time positions and retained 538 full-time positions for two consecutive years (the “Employment Obligation”) as measured on October 28, 2017 (the “Target Date”). The Assistance Agreement was subsequently amended in April 2017 to extend the Target Date by two years to October 28, 2019.
In January 2019, the Company and the State of Connecticut entered into a Second Amendment to the Assistance Agreement (the “Second Amendment”). The Second Amendment extended the Target Date to October 31, 2022 and amended the Employment Obligation to require the Company to continuously maintain a minimum of 538 full-time positions for 24 consecutive months. If the Company meetsmet the Employment Obligation, as modified by the Second Amendment, and createscreated an additional 91 full-time positions, the Company may receivewould have received a credit in the amount of $2.0
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$2.0 million to be applied against the outstanding balance of the loan. However, based on the Company’s current headcount and plans for fiscal yearas of October 31, 2022, and beyond, it maydid not meet this requirement orand will not receive this credit. A job audit will be performed within 90 days of the Target Date. IfBecause the Company doesdid not meet the Employment Obligation, then an accelerated payment penalty will be assessed at a rate of $18,587.36 multiplied by the number of employees below the number of employees required by the Employment Obligation. Such penalty is immediately payable and will be applied first to accelerate the payment of any outstanding fees or interest due and then to accelerate the payment of outstanding principal. The Company estimates that it had an average of 359 employees over the 24 consecutive month period. As a result, $3.3 million of the loan has been reclassified to current, which represents the accelerated payment penalty amount. The Company has not been formally assessed a penalty but since there are no fees or interest due, any penalty assessed would be applied to the outstanding principal and not result in any charges to the Statement of Operations. The Company is currently in dialogue with the State of Connecticut regarding an extension to the Employment Obligation, but there can be no assurance that an extension will be granted.
In April of 2020, as a result of the COVID-19 pandemic, the State of Connecticut agreed to defer three months of principal and interest payments under the Assistance Agreement, beginning with the May 2020 payment. These deferred payments werewill be added at the end of the loan, thus extending out the maturity date by three months.
Restricted Cash
We have pledged approximately $21.8$24.6 million of our cash and cash equivalents as performance security and for letters of credit for certain banking requirements and contracts. As of April 30, 2022,January 31, 2023, outstanding letters of credit totaled $4.8$5.0 million. These expire on various dates through DecemberAugust 2028. Under the terms of certain contracts, we will provide performance security for future contractual obligations. The restricted cash balance as of April 30, 2022January 31, 2023 also included $4.2$5.4 million and $2.9 million primarily to support obligations under the power purchase and service agreements related to the PNC sale-leaseback transactions and the Crestmark sale-leaseback transactions, respectively, and $8.8$9.4 million relating to future obligations associated with the Bridgeport Fuel Cell Project. Refer to Note 16. “Restricted Cash” to our
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Consolidated Financial Statements for the sixthree months ended April 30, 2022January 31, 2023 included in this Quarterly Report on Form 10-Q for a more detailed discussion of the Company’s restricted cash balance.
Power purchase agreements
Under the terms of our PPAs, customers agree to purchase power or other value streams delivered such as hydrogen, steam, water, and/or carbon from ourthe Company’s fuel cell power plantsplatforms at negotiated rates. Electricity rates are generally a function of the customers’ current and estimated future electricity pricing available from the grid. We are responsible for all operating costs necessary to maintain, monitor and repair our fuel cell power plants.platforms. Under certain agreements, we are also responsible for procuring fuel, generally natural gas or biogas, to run our fuel cell power platforms. In addition, under certain agreements, we are required to produce minimum amounts of power under our PPAs and we have the right to terminate PPAs by giving written notice to the customer, subject to certain exit costs. As of April 30, 2022,January 31, 2023, our generation operating portfolio was 41.4 MW.43.7 MW (which includes 7.4 MW attributed to the design rated output of the Groton Project although the Groton Project is, and was as of January 31, 2023 and at the commencement of commercial operations in December 2022, operating at approximately 6.0 MW).
Service and warranty agreements
We warranty our products for a specific period of time against manufacturing or performance defects. Our standard U.S. warranty period is generally 15 months after shipment or 12 months after acceptance of the product. In addition to the standard product warranty, we have contracted with certain customers to provide services to ensure the power plants meet minimum operating levels for terms of up to 20 years. Pricing for service contracts is based upon estimates of future costs, which could be materially different from actual expenses. Refer to “Critical Accounting Policies and Estimates” for additional details.
Advanced Technologies contracts
We have contracted with various government agencies and certain companies from private industry to conduct research and development as either a prime contractor or sub-contractor under multi-year, cost-reimbursement and/or cost-share type contracts or cooperative agreements. Cost-share terms require that participating contractors share the total cost of the project based on an agreed upon ratio. In many cases, we are reimbursed only a portion of the costs incurred or to be incurred on the contract. While government research and development contracts may extend for many years, funding is
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often provided incrementally on a year-by-year basis if contract terms are met and Congress authorizes the funds. As of April 30, 2022,January 31, 2023, Advanced Technologies contract backlog totaled $35.4$26.8 million, of which $14.6$14.2 million is non-U.S. Government-funded, $19.6$11.4 million is U.S. Government-funded and $1.2 million is U.S. Government-unfunded.
Off-Balance Sheet Arrangements
We have no off-balance sheet debt or similar obligations, which are not classified as debt. We do not guarantee any third-party debt. See Note 19.17. “Commitments and Contingencies” to our Consolidated Financial Statements for the sixthree months ended April 30, 2022January 31, 2023 included in this Quarterly Report on Form 10-Q for further information.
CRITICAL ACCOUNTING POLICIES AND ESTIMATES
The preparation of financial statements and related disclosures in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the disclosure of contingent assets and liabilities. Estimates are used in accounting for, among other things, revenue recognition, loss accruals on service agreements, excess, slow-moving and obsolete inventories, product warranty accruals, loss accruals on service agreements, share-based compensation expense, allowance for doubtful accounts, depreciation and amortization, impairment of goodwill and in-process research and development intangible assets, impairment of long-lived assets (including project assets), lease liabilities and right-of-use (“ROU”) assets, and contingencies. Estimates and assumptions are reviewed periodically, and the effects of revisions are reflected in the consolidated financial statements in the period they are determined to be necessary. Due to the inherent uncertainty involved in making estimates, actual results in future periods may differ from those estimates.
Our critical accounting policies are those that are both most important to our financial condition and results of operations and require the most difficult, subjective or complex judgments on the part of management in their application, often as a result of the need to make estimates about the effect of matters that are inherently uncertain. For a complete description of our critical accounting policies that affect our more significant judgments and estimates used in the preparation of our condensed consolidated financial statements, refer to our Annual Report on Form 10-K for the year ended October 31, 20212022 filed with the SEC.
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ACCOUNTING GUIDANCE UPDATE
See Note 2. “Recent Accounting Pronouncements,” to our Consolidated Financial Statements included in this Quarterly Report on Form 10-Q for a summary of recently adopted accounting guidance.
Item 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Interest Rate Exposure Risk
We have invested in U.S. Treasury Securities with maturities ranging from more than three months to less than one year. We expect to hold these investments until maturity and accordingly, these investments are carried at cost and not subject to mark-to-market accounting. At January 31, 2023, our U.S. Treasury Securities had a carrying value of $75.7 million, which approximated fair value. These investments have maturity dates ranging from February 2023 to May 2023 and a weighted average yield to maturity of 4.36%. Cash is invested overnight with high credit quality financial institutions and therefore we are not exposed to market risk on our cash holdings from changing interest rates. Based on our overall interest rate exposure as of April 30, 2022,January 31, 2023, including all interest rate sensitive instruments, a change in interest rates of 1% would not have a material impact on our results of operations.
Foreign Currency Exchange Risk
As of April 30, 2022,January 31, 2023, approximately 0.3%0.5% of our total cash and cash equivalents were in currencies other than U.S. dollars (primarily the Euro, Canadian dollars and Korean Won) and we have no plans of repatriation. We make purchases from certain vendors and receive payment from certain customers in currencies other than U.S. dollars. Although we have not experienced significant foreign exchange rate losses to date, we may in the future, especially to the extent that we do not engage in currency hedging activities. The economic impact of currency exchange rate movements on our operating results is complex because such changes are often linked to variability in real growth, inflation, interest rates, governmental actions and other factors. These changes, if material, may cause us to adjust our financing and operating strategies.
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Derivative Fair Value Exposure Risk
Interest Rate Swap
On May 16, 2019, an interest rate swap agreement (the “Swap Agreement”) was entered into with Fifth Third Bank in connection with the BFC Credit Agreement for the term of the loan. The net interest rate across the BFC Credit Agreement and the swap transaction results in a fixed rate of 5.09%. The interest rate swap is adjusted to fair value on a quarterly basis. The estimated fair value is based on Level 2 inputs including primarily the forward LIBOR curve available to swap dealers. The valuation methodology involves comparison of (i) the sum of the present value of all monthly variable rate payments based on a reset rate using the forward LIBOR curve and (ii) the sum of the present value of all monthly fixed rate payments on the notional amount, which is equivalent to the outstanding principal amount of the loan. On August 1, 2022, the Company entered into an amendment to its interest rate swap agreement that replaced LIBOR with Term Secured Overnight Financing Rate (“SOFR”) effective as of June 2023. The fair value adjustments for the three months ended April 30,January 31, 2023 and 2022 and 2021 resulted in a gainloss of $0.3 million and a gain of $0.1 million, respectively, and for the six months ended April 30, 2022 and 2021 resulted in a gain of $0.5 million and a gain of $0.2 million, respectively.
Project Fuel Price Exposure Risk
Certain of our PPAs for project assets in our generation operating portfolio and project assets under construction expose us to fluctuating fuel price risks as well as the risk of being unable to procure the required amounts of fuel and the lack of alternative available fuel sources. We seek to mitigate our fuel risk using strategies including: (i) fuel cost reimbursement mechanisms in our PPAs to allow for pass through of fuel costs (full or partial) where possible, which we have done with our 14.9 MW operating project in Bridgeport, CT and our 7.4 MW project under construction in Hartford, CT; (ii) procuring fuel under fixed price physical contracts with investment grade counterparties, which we have done for twenty years for our Tulare BioMAT project and the initial seven years of the 18 year PPA for our LIPA Yaphank, NY project; and (iii) potentially entering into future financial hedges with investment grade counterparties to offset potential negative market fluctuations.
We currently have three projects in development with fuel sourcing risk, which arenamely, the Toyota project, which requires procurement of renewable natural gas (“RNG”), and our Derby, CT 14.0 MW and 2.8 MW projects, both of which require natural gas for which there is no pass though mechanism.mechanism in the related PPAs. Fuel sourcing and risk mitigation strategies for all three projects are being assessed and will be implemented as project operational dates become firm.
Historically, this risk has not been material to our financial statements as our operating projects prior to April 30, 2022January 31, 2023 either did not have fuel price risk exposure, had fuel cost reimbursement mechanisms in our related PPAs to allow for pass through of fuel costs (full or partial), or had established long term fixed price fuel physical contracts. To provide a
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meaningful assessment of the fuel price risk arising from price movements of natural gas, the Company performed a sensitivity analysis to determine the impact a change in natural gas commodity pricing would have on our Consolidated Statements of Operations and Comprehensive Loss (assuming that all projects with fuel price risk were operating). A $1/Metric Million British Thermal Unit (“MMBTu”) increase in market pricing compared to our underlying project models would result in a cost impact of approximately $1.4$1.1 million to our Consolidated Statements of Operations and Comprehensive Loss on an annual basis. We have also conducted a sensitivity analysis on the impact of RNG pricing and a $10/MMBTu increase in market pricing compared to our underlying project models would result in an impact of approximately $2.0 million to our Consolidated Statements of Operations and Comprehensive Loss on an annual basis.
Item 4. CONTROLS AND PROCEDURES
The Company maintains disclosure controls and procedures, which are designed to provide reasonable assurance that information required to be disclosed in the Company’s periodic SEC reports is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms, and that such information is accumulated and communicated to its principal executive officer and principal financial officer, as appropriate, to allow timely decisions regarding required disclosure.
We carried out an evaluation, under the supervision and with the participation of our principal executive officer and principal financial officer, of the effectiveness of the design and operation of our disclosure controls and procedures as of the end of the period covered by this report. Based on that evaluation, the Company’s principal executive officer and principal financial officer have concluded that the Company’s disclosure controls and procedures were effective as of the end of the period covered by this report to provide reasonable assurance that information required to be disclosed in the Company’s periodic SEC reports is recorded, processed, summarized, and reported within the time periods specified in
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the SEC’s rules and forms, and that such information is accumulated and communicated to its principal executive officer and principal financial officer, as appropriate, to allow timely decisions regarding required disclosure.
There has been no change in our internal controls over financial reporting that occurred during the last fiscal quarter that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.
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PART II. OTHER INFORMATION
Item 1. LEGAL PROCEEDINGS
POSCO Energy Matters
Background and Description of Proceedings
From approximately 2007 through 2015, the Company relied on POSCO Energy Co., Ltd. (“POSCO Energy”) to develop and grow the Korean and Asian markets for its products and services. The Company received upfront license payments and was entitled to receive royalty income from POSCO Energy pursuant to certain manufacturing and technology transfer agreements, including the Alliance Agreement dated February 7, 2007 (and the amendments thereto), the Technology Transfer, License and Distribution Agreement dated February 7, 2007 (and the amendments thereto), the Stack Technology Transfer and License Agreement dated October 27, 2009 (and the amendments thereto), and the Cell Technology Transfer and License Agreement dated October 31, 2012 (and the amendments thereto) (collectively, the “License Agreements”). The License Agreements provided POSCO Energy with the exclusive technology rights to manufacture, sell, distribute and service the Company’s SureSource 300, SureSource 1500 and SureSource 3000 fuel cell technology in the Korean and broader Asian markets.
In November 2019, POSCO Energy spun-off its fuel cell business into a new entity, Korea Fuel Cell Co., Ltd. (“KFC”), without the Company’s consent. As part of the spin-off, POSCO Energy transferred manufacturing and service rights under the License Agreements to KFC, but retained distribution rights and severed its own liability under the License Agreements. The Company formally objected to POSCO Energy’s spin-off, and POSCO Energy posted a bond to secure any liabilities to the Company arising out of the spin-off. In September 2020, the Korean Electricity Regulatory Committee found that POSCO Energy’s spin-off of the fuel cell business to KFC may have been done in violation of Korean law.
On February 19, 2020, the Company notified POSCO Energy in writing that it was in material breach of the License Agreements by (i) its actions in connection with the spin-off of the fuel cell business to KFC, (ii) its suspension of performance through its cessation of all sales activities since late 2015 and its abandonment of its fuel cell business in Asia, and (iii) its disclosure of material nonpublic information to third parties and its public pronouncements about the fuel cell business on television and in print media that have caused reputational damage to the fuel cell business, the Company and its products. The Company also notified POSCO Energy that, under the terms of the License Agreements, it had 60 days to fully cure its breaches to the Company’s satisfaction and that failure to so cure would lead to termination of the License Agreements. Further, on March 27, 2020, the Company notified POSCO Energy of additional instances of its material breach of the License Agreements based on POSCO Energy’s failure to pay royalties required to be paid in connection with certain module exchanges.
On April 27, 2020, POSCO Energy initiated a series of three arbitration demands against the Company at the International Court of Arbitration of the International Chamber of Commerce seated in Singapore, in which it alleged certain warranty defects in a sub-megawatt conditioning facility at its facility in Pohang, Korea and sought combined damages of approximately $3.3 million. Prior to filing the arbitrations, POSCO Energy obtained provisional attachments from the Seoul Central District Court attaching certain revenues owed to the Company by Korea Southern Power Company (“KOSPO”) as part of such warranty claims, which delayed receipt of certain payments owed to the Company. POSCO Energy subsequently sought additional provisional attachments on KOSPO revenues from the Seoul Central District Court based on unspecified warranty claims in an additional amount of approximately $7 million, and additional provisional attachments on KOSPO revenues from the Seoul Central District Court based on its alleged counterclaims in the license termination arbitration described below in an additional amount of approximately $110 million. POSCO Energy posted a bond in the amount of $46 million to secure any damages to the Company resulting from the attachments. The Company had outstanding accounts receivable due from KOSPO of $11.2 million, which amount was recovered from the Seoul Central District Court during the second quarter of fiscal year 2022 as discussed in additional detail below.
On June 28, 2020, the Company terminated the License Agreements with POSCO Energy and filed a demand for arbitration against POSCO Energy and KFC in the International Court of Arbitration of the International Chamber of Commerce based on POSCO Energy’s (i) failure to exercise commercially reasonable efforts to sell the Company’s technology in the Korean and Asian markets, (ii) disclosure of the Company’s proprietary information to third parties, (iii) attack on the Company’s stock price and (iv) spin-off of POSCO Energy’s fuel cell business into KFC without the
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Company’s consent. The Company requested that the arbitral tribunal (a) confirm through declaration that POSCO Energy’s exclusive license to market the Company’s technology and products in Korea and Asia is null and void as a result of the breaches of the License Agreements and that the Company had the right to pursue direct sales in these markets, (b) order POSCO Energy and KFC to compensate the Company for losses and damages suffered in the amount of more than $200 million, and (c) order POSCO Energy and KFC to pay the Company’s arbitration costs, including counsel fees and expenses. The Company retained outside counsel on a contingency basis to pursue its claims, and outside counsel entered into an agreement with a litigation finance provider to fund the legal fees and expenses of the arbitration. In October 2020, POSCO Energy filed a counterclaim in the arbitration (x) seeking approximately $880 million in damages based on allegations that the Company misrepresented the capabilities of its fuel cell technology to induce POSCO Energy to enter into the License Agreements and failed to turn over know-how sufficient for POSCO Energy to successfully operate its business; (y) seeking a declaration that the License Agreements remained in full force and effect and requesting the arbitral tribunal enjoin the Company from interfering in POSCO Energy’s exclusive rights under the License Agreements and (z) seeking an order that the Company pay POSCO Energy’s arbitration costs, including counsel fees and expenses.
The Company discontinued revenue recognition of the deferred license revenue related to the License Agreements in July 2020 given the then-pending arbitrations.
On August 28, 2020, POSCO Energy filed a complaint in the Court of Chancery of the State of Delaware (the “Court”) purportedly seeking to enforce its rights as a stockholder of the Company to inspect and make copies and extracts of certain books and records of the Company and/or the Company’s subsidiaries pursuant to Section 220 of the Delaware General Corporation Law and/or Delaware common law. POSCO Energy alleged that it was seeking to inspect these documents for a proper purpose reasonably related to its interests as a stockholder of the Company, including investigating whether the Company’s Board of Directors and its management breached their fiduciary duties of loyalty, due care, and good faith. POSCO Energy sought an order of the Court permitting POSCO Energy to inspect and copy the demanded books and records, awarding POSCO Energy reasonable costs and expenses, including reasonable attorney’s fees incurred in connection with the matter, and granting such other and further relief as the Court deemed just and proper. On July 9, 2021, the Court issued a post-trial ruling denying POSCO Energy’s demand to inspect the Company’s books and records because POSCO Energy lacked a proper purpose. The Court held that the totality of the circumstances, including the fact that this complaint was the seventh legal action POSCO Energy initiated against the Company within the span of nine months, confirmed that POSCO Energy’s purpose in initiating the books and records demand and filing the complaint was not proper. As this dispute was resolved by the Court as described above, it did not require resolution pursuant to, and was not part of, the Settlement Agreement described below.
On September 14, 2020, POSCO Energy filed a complaint in the United States District Court for the Southern District of New York (the “SD Court”) alleging that the Company delayed the removal of restrictive legends on certain share certificates held by POSCO Energy in 2018, thus precluding POSCO Energy from selling the shares and resulting in claimed losses in excess of $1 million. On September 16, 2021, the SD Court ruled in the Company’s favor on a motion for summary judgement dismissing all four counts of POSCO Energy’s complaint regarding share certificates held by POSCO Energy in 2018, but granted POSCO Energy leave to file an amended complaint.
Settlement Agreement
In order to resolve the disputes described above (other than the books and records dispute which was previously resolved by the Court), on December 20, 2021, the Company entered into a Settlement Agreement (the “Settlement Agreement”) with POSCO Energy and KFC (POSCO Energy and KFC may be collectively referred to herein as “PE Group”). The Settlement Agreement provides, among other things, that the parties will cooperate in good faith to effect a market transition to the Company of the molten carbonate fuel cell business in Korea in accordance with the terms and conditions of the Settlement Agreement. To that end, the Settlement Agreement provides that any and all past, current, or potential disputes and claims between the Company, on the one hand, and POSCO Energy and KFC, on the other, of any nature whatsoever, whether known or unknown, asserted or not asserted, based on actions or omissions of any party on or before the date of Settlement Agreement are fully and finally settled, including such disputes and claims, directly or indirectly, in connection with the legal disputes (other than the books and records dispute which was previously resolved by the Court) and License Agreements described above, with the exception of (i) an unfiled claim by the Company in the amount of approximately $1.8 million with respect to certain royalties the Company believes are owed by POSCO Energy with respect to replacement modules deployed by POSCO Energy at Gyenonggi Green Energy and other sites for which POSCO Energy has not paid royalties, and (ii) an unfiled claim by POSCO Energy in an unknown amount with respect to a series of purchase orders for materials and components which began in 2014 under a supply chain contract, both of which claims
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remain unsettled. The Company does not believe the claim by POSCO Energy with respect to purchase orders for materials and components under the supply chain contract has merit and the Company retains the right to file a counterclaim for damages it believes it has incurred with respect to such supply chain contract. With respect to the attachments obtained by POSCO Energy from the Seoul Central District Court (as described above), the Settlement Agreement provides that, within five days of the date of the Settlement Agreement, POSCO Energy would file an application with the Seoul Central District Court to revoke the attachments. The application was filed with the Seoul Central District Court, and, during the second quarter of fiscal year 2022, the Company recovered the outstanding KOSPO accounts receivable of approximately $11.2 million from the Seoul Central District Court.
Under the Settlement Agreement, the parties also agreed that, within five days of the date thereof, the Company would withdraw its objection to the spin-off of KFC from POSCO Energy, and that the License Agreements are not terminated, but instead are deemed to be amended such that POSCO Energy and KFC only have the right (i) to provide maintenance and repair services to PE Group’s existing customers on existing molten carbonate power generation and thermal projects under long-term service agreements currently in force as well as long-term service agreements that have expired and are pending renewal as of the settlement date (collectively, “Existing LTSAs”), (ii) to supply replacement modules purchased from the Company only for their existing customers for existing molten carbonate power generation and thermal projects under Existing LTSAs and (iii) to own, operate and maintain all facilities and factories solely for the purposes set forth in (i) and (ii) above (collectively, the “Right to Service License”). POSCO Energy and KFC further agreed that, as of the date of the Settlement Agreement, the License Agreements are deemed to be amended such that the Company exclusively enjoys all rights as to its technology in Korea and Asia, other than the Right to Service License. The Settlement Agreement further provides that the License Agreements will terminate automatically upon sixty days prior written notice to PE Group if (i) the Company enters into a business collaboration agreement with a Korean company to construct, assemble, manufacture, market, sell, distribute, import, export, install, commission, service, maintain, or repair products incorporating the Company’s technology, or otherwise conduct the Company’s business, in the Korean market; or (ii) the Company expands the capacity of its existing Korean entity such as to perform such activities itself. In the event of the termination of the License Agreements, the license granted to PE Group under the Right to Service License will continue notwithstanding the termination of the License Agreements, except that PE Group’s right to own, operate, and maintain all facilities and factories for the purpose of servicing any orders or requests made by the Company will terminate. For the avoidance of doubt, pursuant to the terms of the Settlement Agreement, PE Group has no right to manufacture modules or any other product incorporating the Company’s technology under the License Agreements as amended, the Right to Service License or otherwise unless requested and authorized by the Company to do so.
The Settlement Agreement further provides that, in order to service its existing customers under the Existing LTSAs, KFC would place a firm, non-cancelable order for twelve SureSource 3000 modules within two weeks after the date of the Settlement Agreement and will place an additional firm, non-cancelable order for eight SureSource 3000 modules on or before June 30, 2022, all at a price of $3.0 million per module. In addition, KFC has agreed to use commercially reasonable efforts to order fourteen additional SureSource 3000 modules by December 31, 2022, at a price of $3.0 million per module if ordered by such date. If KFC materially breaches the Settlement Agreement by failing to make timely and full payment for the modules for which KFC is required to place orders under the Settlement Agreement and does not cure such material breach within fifteen days of notice of such breach by the Company, the License Agreements and the Right to Service License granted to PE Group will be terminated. If the Company materially breaches the Settlement Agreement by failing to supply the modules for which KFC is required to place orders under the Settlement Agreement, as long as KFC has made the payment for such modules and has otherwise satisfied its contractual obligations for those modules and such material breach is not cured within sixty days after notice from PE Group, PE Group will have the right to terminate the Settlement Agreement. With respect to any other alleged breach, material or otherwise, of the Settlement Agreement, the parties’ exclusive remedy consists solely of general damages.
The Company received a firm, non-cancelable order from KFC for twelve SureSource 3000 modules. Six of these modules were delivered Ex Works from the Company’s facility in Torrington, Connecticut in January 2022.
Pursuant to the Settlement Agreement, with respect to new modules to be supplied by the Company and deployed by PE Group to its existing customers, the Company will provide its standard warranty against module defects until the earlier of eighteen months from the date of shipment or twelve months from the date of installation. As part of the global settlement of the disputes among the parties and subject to the qualifications set forth in the Settlement Agreement, the Company will reimburse PE Group for any annual output penalty amount paid by PE Group to its customers pursuant to Existing LTSAs (whether such Existing LTSA is extended or renewed), caused by a shortfall or defect in the new modules for a period of up to seven years. The maximum annual reimbursement obligation with regard to any PE Group customer for any new module provided by the Company will not exceed an amount equal to 7.5% per year of the module purchase price. The Company will not be required to reimburse PE Group for any penalty paid by PE Group under the Existing
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LTSAs that is not caused by a shortfall or defect in the modules to be supplied by the Company including, without limitation, any shortfall or defect caused by a site-related problem, a problem with the balance of plant, or other components of the project.
Although the Company has the exclusive and unrestricted right under the Settlement Agreement to perform, pursue, and otherwise conduct its business in relation to new fuel cell projects (including new projects with PE Group’s existing customers) in Korea and Asia, the parties have agreed that, except as further provided in the Settlement Agreement with respect to PE Group’s existing customers Noeul Green Energy and Godeok Green Energy, the Company will not engage in discussions with PE Group’s existing customers regarding Existing LTSAs without PE Group’s consent. The parties have further agreed that if PE Group cannot enter into an agreement with its existing customers to extend or renew Existing LTSAs by December 31, 2022, PE Group will cooperate with the Company so that the Company may discuss and, at the Company’s sole discretion, enter into an extension of an Existing LTSA, a new long-term service agreement to replace an Existing LTSA, or a module sales agreement with PE Group’s existing customers; provided that (i) should the Company enter into such an arrangement with a PE Group existing customer, (ii) the Company is required to provide replacement modules to such existing customer under such arrangement, and (iii) PE Group has not already deployed all or some the modules that PE Group ordered under Settlement Agreement, the Company will purchase the number of required replacement modules from PE Group at a price of $3.0 million per module (to the extent such modules are available and have not yet been deployed). The purchase of such replacement modules by the Company is contingent upon the modules being in proper condition as determined by inspection process to be agreed by the parties. Any modules purchased by the Company from PE Group under these terms will be included as part of the firm orders KFC is required to make pursuant to the Settlement Agreement.
With respect to operations and maintenance agreements, the Settlement Agreement provides that KFC will have the right of first refusal on providing operation and maintenance services on commercially reasonable terms for new long-term service agreements entered into by the Company in Korea for a period of the first to occur of either twenty-four months after the date of the Settlement Agreement or until such time as the Company engages a third party capable of providing such services in Korea. If KFC and the Company agree that KFC should provide operation and maintenance services pursuant to the right of first refusal, KFC and the Company will enter into one or more operation and maintenance agreements that reflect commercially reasonable terms and conditions as agreed by KFC and the Company at that time.
With respect to balance of plant (“BOP”), KFC currently has eight units of BOP available, and the Settlement Agreement provides that the Company has the option to purchase such units of BOP for any new molten carbonate fuel cell projects within Korea at a price of KRW 2,550,000,000 (or USD $2,116,500 as of April 30, 2022) per unit. The Company will also have a non-exclusive, non-transferrable, non-sublicensable license to use the intellectual property embedded in the BOP units in Korea in consideration for a reasonable license fee to be separately agreed by the parties. Detailed terms and conditions of BOP and related software and firmware supply will be discussed and agreed to in good faith in separate BOP supply agreements in the event the Company exercises its option to purchase any of such BOP.
As described above, the Company retained outside counsel on a contingency basis to pursue its claims against POSCO Energy and KFC, and outside counsel entered into an agreement with a litigation finance provider to fund the legal fees and expenses of the arbitration proceedings brought by the Company against POSCO Energy and KFC. As the Company has entered into the Settlement Agreement, it is required to remit fees to its counsel, Wiley Rein, LLP (“Wiley”), subject to the terms of its engagement letter with Wiley. On December 23, 2021, the Company agreed that it would pay Wiley a total of $24.0 million to satisfy all obligations to Wiley under the Company’s engagement letter (which is included in Administrative and selling expenses on the Consolidated Statements of Operations and Comprehensive Loss for the six months ended April 30, 2022). Of this amount, $19.0 million was paid during the six months ended April 30, 2022, and the remaining $5.0 million will be paid on or before June 30, 2022.
Other Legal Proceedings
From time to time, the Company is involved in other legal proceedings, including, but not limited to, regulatory proceedings, claims, mediations, arbitrations and litigation, arising out of the ordinary course of its business (“Other Legal Proceedings”). Although the Company cannot assure the outcome of such Other Legal Proceedings, management presently believes that the result of such Other Legal Proceedings, either individually, or in the aggregate, will not have a material adverse effect on the Company’s consolidated financial statements, and no material amounts have been accrued in the Company’s consolidated financial statements with respect to these matters.
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Item 1A. RISK FACTORS
Part I, Item 1A, “Risk Factors” of our most recently filed Annual Report on Form 10-K for the fiscal year ended October 31, 2021,2022, filed with the Securities and Exchange Commission on December 29, 202120, 2022 (the “2021“2022 Annual Report”), sets forth information relating to important risks and uncertainties that could materially adversely affect our business, financial condition and operating results. Those risk factors continue to be relevant to an understanding of our business, financial condition and operating results and, accordingly, you should review and consider such risk factors in making any investment decision with respect to our securities. There have been no material changes to the risk factors previously disclosed in the 20212022 Annual Report.
Item 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS
(a) | None. |
(b) | Not applicable. |
(c) | Stock Repurchases |
The following table sets forth information with respect to purchases made by us or on our behalf of our common stock during the periods indicated:
| | | | | | | | | | | | | | | | | | |
Period |
| Total |
| Average |
| Total Number |
| Maximum |
| Total |
| Average |
| Total Number |
| Maximum | ||
February 1, 2022 – February 28, 2022 | | 470 | | $ | 6.00 | | — | | — | |||||||||
March 1, 2022 – March 31, 2022 | | — | | | — | | — | | — | |||||||||
April 1, 2022 – April 30, 2022 | | — | | | — | | — | | — | |||||||||
November 1, 2022 - November 30, 2022 | | 32,582 | | $ | 3.48 | | — | | — | |||||||||
December 1, 2022 - December 31, 2022 | | 68,381 | | | 3.47 | | — | | — | |||||||||
January 1, 2023 - January 31, 2023 | | — | | | — | | — | | — | |||||||||
Total | | 470 | | $ | 6.00 | | — | | — | | 100,963 | | $ | 3.47 | | — | | — |
(1) | Includes only shares that were surrendered by employees to satisfy statutory tax withholding obligations in connection with the vesting of stock-based compensation awards. |
Item 3. DEFAULT UPON SENIOR SECURITIES
None.
Item 4. MINE SAFETY DISCLOSURES
None.
45
Item 6. EXHIBITS
Exhibit No. |
| Description |
---|---|---|
3.1 | | |
3.2 | | |
3.3 | | |
3.4 | | |
3.5 | | |
3.6 | | |
3.7 | | |
3.8 | | |
3.9 | | |
3.10 | | |
3.11 | | |
3.12 | | |
3.13 | | |
3.14 | | |
3.15 | | |
3.16 | | |
3.17 | | |
4.1 | | |
| | |
|
| |
10.2 | | Lease, dated May 20, 2005, between Westpen Properties Ltd. and Versa Power Systems Ltd. |
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Exhibit No. |
| Description |
---|---|---|
| | |
| | |
10.5 | | |
10.6 | | |
10.7 | | |
10.8 | | |
10.9 | | |
31.1 | | Certification of Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 |
31.2 | | Certification of Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 |
32.1 | | Certification of Chief Executive Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 |
32.2 | | Certification of Chief Financial Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 |
101.INS | | Inline XBRL Instance Document – the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document. |
101.SCH | | Inline XBRL Schema Document |
101.CAL | | Inline XBRL Calculation Linkbase Document |
101.LAB | | Inline XBRL Labels Linkbase Document |
101.PRE | | Inline XBRL Presentation Linkbase Document |
104 | | Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101). |
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SIGNATURE
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
| | FUELCELL ENERGY, INC. |
| | (Registrant) |
| | |
| | /s/ Michael S. Bishop |
Date | | Michael S. Bishop |
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