fcel-10q_20190731.htm

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.

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 September 6, 2019: 125,914,240

	July 31,			October 31,
	2019			2018
ASSETS
Current assets:
Cash and cash equivalents, unrestricted	$	16,018		$	39,291
Restricted cash and cash equivalents - short-term		1,381			5,806
Accounts receivable, net		3,705			9,280
Unbilled receivables		8,186			13,759
Inventories		59,830			53,575
Other current assets		7,254			8,592
Total current assets		96,374			130,303
Restricted cash and cash equivalents - long-term		28,400			35,142
Inventories - long-term		2,179			—
Project assets		156,393			99,600
Property, plant and equipment, net		42,406			48,204
Goodwill		4,075			4,075
Intangible assets		21,588			9,592
Other assets		10,019			13,505
Total assets	$	361,434		$	340,421
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities:
Current portion of long-term debt	$	43,416		$	17,596
Accounts payable		30,250			22,594
Accrued liabilities		8,582			7,632
Deferred revenue		15,650			11,347
Preferred stock obligation of subsidiary		950			952
Total current liabilities		98,848			60,121
Long-term deferred revenue		22,190			16,793
Long-term preferred stock obligation of subsidiary		15,933			14,965
Long-term debt and other liabilities		79,696			71,619
Total liabilities		216,667			163,498
Redeemable Series B preferred stock (liquidation preference of $64,020 as of July 31, 2019 and October 31, 2018)		59,857			59,857
Redeemable Series C preferred stock (liquidation preference of $8,992 as of October 31, 2018)		—			7,480
Redeemable Series D preferred stock (liquidation preference of $25 and $30,680 as of July 31, 2019 and October 31, 2018, respectively)		27			27,392
Total equity:
Stockholders’ equity:
Common stock ($0.0001 par value); 225,000,000 shares authorized as of July 31, 2019 and October 31, 2018; 118,387,637 and 7,972,686 shares issued and outstanding as of July 31, 2019 and October 31, 2018, respectively		12			1
Additional paid-in capital		1,125,212			1,073,463
Accumulated deficit		(1,039,910	)		(990,867	)
Accumulated other comprehensive loss		(431	)		(403	)
Treasury stock, Common, at cost (42,496 and 13,042 shares as of July 31, 2019 and October 31, 2018, respectively)		(466	)		(363	)
Deferred compensation		466			363
Total stockholders’ equity		84,883			82,194
Total liabilities and stockholders' equity	$	361,434		$	340,421

	Three Months Ended July 31,
	2019			2018
Revenues:
Product	$	—		$	1,328
Service and license		11,496			5,549
Generation		5,448			1,695
Advanced Technologies		5,768			3,538
Total revenues		22,712			12,110
Costs of revenues:
Product		4,547			4,099
Service and license		1,102			5,997
Generation		5,726			1,375
Advanced Technologies		3,372			2,695
Total costs of revenues		14,747			14,166
Gross profit (loss)		7,965			(2,056	)
Operating expenses:
Administrative and selling expenses		7,058			6,100
Research and development expenses		1,977			6,318
Total costs and expenses		9,035			12,418
Loss from operations		(1,070	)		(14,474	)
Interest expense		(3,536	)		(2,434	)
Other (expense) income, net		(685	)		1,042
Loss before provision for income taxes		(5,291	)		(15,866	)
Provision for income taxes		(20	)		(15	)
Net loss		(5,311	)		(15,881	)
Series B preferred stock dividends		(810	)		(800	)
Series C preferred stock deemed contributions (dividends)		884			(939	)
Series D preferred stock deemed dividends		(3,091	)		—
Net loss attributable to common stockholders	$	(8,328	)	$	(17,620	)
Loss per share basic and diluted:
Net loss per share attributable to common stockholders	$	(0.18	)	$	(2.45	)
Basic and diluted weighted average shares outstanding		45,069,911			7,191,457

	Nine Months Ended July 31,
	2019			2018
Revenues:
Product	$	—		$	43,058
Service and license		25,866			12,859
Generation		8,560			5,329
Advanced Technologies		15,285			10,307
Total revenues		49,711			71,553
Costs of revenues:
Product		14,362			44,183
Service and license		15,166			11,934
Generation		9,047			5,020
Advanced Technologies		9,016			8,466
Total costs of revenues		47,591			69,603
Gross profit		2,120			1,950
Operating expenses:
Administrative and selling expenses		23,622			19,327
Research and development expenses		12,435			15,385
Total costs and expenses		36,057			34,712
Loss from operations		(33,937	)		(32,762	)
Interest expense		(7,807	)		(6,634	)
Other (expense) income, net		(556	)		3,138
Loss before (provision) benefit for income taxes		(42,300	)		(36,258	)
(Provision) benefit for income taxes		(89	)		3,020
Net loss		(42,389	)		(33,238	)
Series A warrant exchange		(3,169	)		—
Series B preferred stock dividends		(2,410	)		(2,400	)
Series C preferred stock deemed dividends and redemption value adjustment, net		(6,522	)		(8,601	)
Series D preferred stock deemed dividends and redemption accretion		(9,752	)		—
Net loss attributable to common stockholders	$	(64,242	)	$	(44,239	)
Loss per share basic and diluted:
Net loss per share attributable to common stockholders	$	(2.97	)	$	(6.70	)
Basic and diluted weighted average shares outstanding		21,608,427			6,607,687

	Common Stock
	Shares			Amount		Additional Paid-in Capital			Accumulated Deficit			Accumulated Other Comprehensive Income (Loss)			Treasury Stock			Deferred Compensation		Total Equity
Balance, October 31, 2018		7,972,686		$	1	$	1,073,463		$	(990,867	)	$	(403	)	$	(363	)	$	363	$	82,194
Share based compensation		—			—		987			—			—			—			—		987
Fee adjustment for common stock issuance		—			—		90			—			—			—			—		90
Common stock issued under benefit plans, net of taxes paid upon vesting of restricted stock awards		1,946			—		27			—			—			—			—		27
Series C convertible preferred stock conversions		127,829			—		1,974			—			—			—			—		1,974
Series C convertible preferred stock adjustment for beneficial conversion feature		—			—		6,586			—			—			—			—		6,586
Series C convertible stock redemption value adjustments		—			—		(8,550	)		—			—			—			—		(8,550	)
Series D convertible preferred stock conversions		932,144			—		4,334			—			—			—			—		4,334
Series D convertible preferred stock redemption accretion		—			—		(3,793	)		—			—			—			—		(3,793	)
Preferred dividends — Series B		—			—		(800	)		—			—			—			—		(800	)
Impact of the adoption of Topic 606		—			—		—			(6,654	)		—			—			—		(6,654	)
Effect of foreign currency translation		—			—		—			—			7			—			—		7
Net loss attributable to FuelCell Energy, Inc.		—			—		—			(17,548	)		—			—			—		(17,548	)
Balance, January 31, 2019		9,034,605		$	1	$	1,074,318		$	(1,015,069	)	$	(396	)	$	(363	)	$	363	$	58,854
Common stock issued, non-employee compensation		29,454			—		102			—			—			—			—		102
Share based compensation		—			—		955			—			—			—			—		955
Taxes paid upon vesting of restricted stock awards, net of stock issued under benefit plans		52,784			—		(219	)		—			—			—			—		(219	)
Series A warrant exchange		500,000			—		—			—			—			—			—		—
Series C convertible preferred stock conversions		2,127,528			—		10,355			—			—			—			—		10,355
Series C convertible preferred stock modification		—			—		(6,047	)		—			—			—			—		(6,047	)
Series D convertible preferred stock conversions		1,994,413			—		6,305			—			—			—			—		6,305
Preferred dividends — Series B		—			—		(800	)		—			—			—			—		(800	)
Effect of foreign currency translation		—			—		—			—			(140	)		—			—		(140	)
Adjustment for deferred compensation		(29,454	)		—		—			—			—			(103	)		103		—
Net loss attributable to FuelCell Energy, Inc.		—			—		—			(19,530	)		—			—			—		(19,530	)
Balance, April 30, 2019		13,709,330		$	1	$	1,084,969		$	(1,034,599	)	$	(536	)	$	(466	)	$	466	$	49,835
Sale of common stock, net of fees		43,997,807			3		16,196			—			—			—			—		16,199
Share based compensation		—			—		383			—			—			—			—		383
Taxes paid upon vesting of restricted stock awards, net of stock issued under benefit plans		437			—		(9	)		—			—			—			—		(9	)
Series C convertible preferred stock conversions		1,658,861			2		3,160			—			—			—			—		3,162
Series D convertible preferred stock conversions		59,021,202			6		20,513			—			—			—			—		20,519
Effect of foreign currency translation		—			—		—			—			105			—			—		105
Net loss attributable to FuelCell Energy, Inc.		—			—		—			(5,311	)		—			—			—		(5,311	)
Balance, July 31, 2019		118,387,637		$	12	$	1,125,212		$	(1,039,910	)	$	(431	)	$	(466	)	$	466	$	84,883

	Common Stock
	Shares			Amount		Additional Paid-in Capital			Accumulated Deficit			Accumulated Other Comprehensive Income (Loss)			Treasury Stock			Deferred Compensation		Total Equity
Balance, October 31, 2017		5,791,068		$	1	$	1,045,203		$	(943,533	)	$	(415	)	$	(280	)	$	280	$	101,256
Exercise of warrants		172,200			—		2,647			—			—			—			—		2,647
Share based compensation		—			—		617			—			—			—			—		617
Taxes paid upon vesting of restricted stock awards, net of stock issued under benefit plans		(8,912	)		—		(75	)		—			—			—			—		(75	)
Series C convertible preferred stock conversions		512,487			—		7,569			—			—			—			—		7,569
Preferred dividends — Series B		—			—		(800	)		—			—			—			—		(800	)
Effect of foreign currency translation		—			—		—			—			33			—			—		33
Net loss attributable to FuelCell Energy, Inc.		—			—		—			(4,183	)		—			—			—		(4,183	)
Balance, January 31, 2018		6,466,843		$	1	$	1,055,161		$	(947,716	)	$	(382	)	$	(280	)	$	280	$	107,064
Exercise of warrants		44,109			—		621			—			—			—			—		621
Common stock issued, non-employee compensation		10,066			—		282			—			—			—			—		282
Share based compensation		—			—		761			—			—			—			—		761
Taxes paid upon vesting of restricted stock awards, net of stock issued under benefit plans		(1,282	)		—		(546	)		—			—			—			—		(546	)
Series C convertible preferred stock conversions		559,844			—		8,029			—			—			—			—		8,029
Preferred dividends — Series B		—			—		(800	)		—			—			—			—		(800	)
Effect of foreign currency translation		—			—		—			—			54			—			—		54
Adjustment for deferred compensation		(4,683	)		—		—			—			—			(167	)		167		—
Net loss attributable to FuelCell Energy, Inc.		—			—		—			(13,174	)		—			—			—		(13,174	)
Balance, April 30, 2018		7,074,897		$	1	$	1,063,508		$	(960,890	)	$	(328	)	$	(447	)	$	447	$	102,291
Sale of common stock, net of fees		435,329			—		6,745			—			—			—			—		6,745
Share based compensation		—			—		931			—			—			—			—		931
Taxes paid upon vesting of restricted stock awards, net of stock issued under benefit plans		(1,403	)		—		(35	)		—			—			—			—		(35	)
Series C convertible preferred stock conversions		181,191			—		2,385			—			—			—			—		2,385
Preferred dividends — Series B		—			—		(800	)		—			—			—			—		(800	)
Effect of foreign currency translation		—			—		—			—			(128	)		—			—		(128	)
Net loss attributable to FuelCell Energy, Inc.		—			—		—			(15,881	)		—			—			—		(15,881	)
Balance, July 31, 2018		7,690,014		$	1	$	1,072,734		$	(976,771	)	$	(456	)	$	(447	)	$	447	$	95,508

	Nine Months Ended July 31,
	2019			2018
Cash flows from operating activities:
Net loss	$	(42,389	)	$	(33,238	)
Adjustments to reconcile net loss to net cash used in operating activities:
Share-based compensation		2,325			2,309
Loss from change in fair value of embedded derivatives		54			53
Depreciation		8,319			6,525
Non-cash interest expense on preferred stock and debt obligations		4,664			4,418
Unrealized foreign exchange gains		(23	)		(280	)
Deferred income taxes		—			(3,035	)
Impairment of property, plant and equipment		2,840			—
Project asset impairment		—			485
Unrealized loss on derivative contract		432			—
Other non-cash transactions, net		876			203
(Increase) decrease in operating assets:
Accounts receivable		4,309			17,683
Unbilled receivables		(5,603	)		15,426
Inventories		(8,434	)		22,138
Other assets		1,734			(2,511	)
Increase (decrease) in operating liabilities:
Accounts payable		9,350			3,563
Accrued liabilities		(464	)		(4,534	)
Deferred revenue		3,703			141
Net cash (used in) provided by operating activities		(18,307	)		29,346
Cash flows from investing activities:
Capital expenditures		(1,922	)		(7,625	)
Project asset expenditures		(21,877	)		(28,411	)
Asset acquisition		(35,474	)		—
Net cash used in investing activities		(59,273	)		(36,036	)
Cash flows from financing activities:
Repayment of debt		(23,030	)		(13,080	)
Proceeds from debt		55,096			13,091
Payment of deferred financing costs		(2,505	)		(352	)
Payment of preferred dividends and return of capital		(1,840	)		(3,134	)
Common stock issued for stock plans and related expenses		23			—
Proceeds from sale of common stock and warrant exercises, net		15,424			10,013
Net cash provided by financing activities		43,168			6,538
Effects on cash from changes in foreign currency rates		(28	)		(41	)
Net decrease in cash, cash equivalents and restricted cash		(34,440	)		(193	)
Cash, cash equivalents and restricted cash-beginning of period		80,239			87,448
Cash, cash equivalents and restricted cash-end of period	$	45,799		$	87,255
Supplemental cash flow disclosures:
Cash interest paid	$	2,688		$	1,960
Noncash financing and investing activity:
Series C preferred share conversions		15,491			17,983
Series C preferred share modification		(6,047	)		—
Series D preferred share conversions		31,158			—
Net noncash reclass of project assets to inventory		—			7,756
Accrued sale of common stock, cash received in a subsequent period		775			—
Accrued purchase of fixed assets, cash to be paid in subsequent period		281			798
Accrued purchase of project assets, cash to be paid in subsequent period		2,719			2,026

FuelCell Energy, Inc., together with its subsidiaries (the “Company”, “FuelCell Energy”, “we”, “us”, or “our”) is a leading integrated fuel cell company with a growing global presence. We design, manufacture, install, operate and service ultra-clean, efficient and reliable stationary fuel cell power plants. Our SureSource power plants generate electricity and usable high quality heat for commercial, industrial, government and utility customers. We have commercialized our stationary carbonate fuel cells and are also pursuing the complementary development of planar solid oxide fuel cells and other fuel cell technologies. Our operations are funded primarily through sales of equity instruments to strategic investors or in public markets, corporate and project level debt financing and local or state government loans or grants. In order to produce positive cash flow from operations, we need to be successful at increasing annual order volume and production and in our cost reduction efforts.

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 nine months ended July 31, 2019 and 2018 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, 2018 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, 2018, 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.

On May 8, 2019 at 5:00 p.m. Eastern time, the Company effected a 1-for-12 reverse stock split, reducing the number of the Company’s common shares outstanding on that date from 183,411,230 shares to 15,284,269 shares. The number of authorized shares of common stock remains unchanged at 225,000,000 shares and the number of authorized shares of preferred stock remains unchanged at 250,000 shares. Additionally, the conversion rate of our Series B Preferred Stock (as defined elsewhere herein), the conversion price of our Series C Preferred Stock and Series D Preferred Stock (each as defined elsewhere herein), the exchange price of our Series 1 Preferred Shares (as defined elsewhere herein), the exercise price of all then outstanding options and warrants, and the number of shares reserved for future issuance pursuant to our equity compensation plans were all adjusted proportionately in connection with the reverse stock split. All share and per share amounts and conversion prices presented herein have been adjusted retroactively to reflect these changes.

Certain reclassifications have been made to the prior year amounts to conform to the current year presentation. The Company adopted Accounting Standards Update (“ASU”) 2014-09, “Revenue from Contracts with Customers (Topic 606)” effective November 1, 2018 and applied the modified retrospective transition method. As a result of the adoption of this ASU, Unbilled receivables has been reclassified as a separate line item from Accounts receivable, net on the Consolidated Balance Sheets and Unbilled receivables has been classified as a separate item from Accounts receivable, net in the Consolidated Statement of Cash Flows for the prior year period.

The Company’s consolidated financial statements have been prepared on a going concern basis, which contemplates the realization of assets and satisfaction of liabilities and commitments in the normal course of business. The Company has significant short-term debt and other obligations currently due or maturing in less than one year, which are in excess of the Company’s cash and current asset balance. Due to the Company’s constrained liquidity, the Company has been delaying certain payments to third parties, including trade creditors, to conserve cash. Management has been actively working with trade creditors, and entering into forbearance agreements and payment arrangements. However, the Company may not be able to enter into forbearance agreements or make suitable payment arrangements with its trade creditors, or the terms of any forbearance agreements or payment arrangements may not be favorable to the Company. If the Company is unable to negotiate such forbearance agreements or payment arrangements, trade creditors whose payments have been delayed may take action against the Company, including, but not limited to, filing litigation, arbitration or other proceedings against the Company. Going forward, suppliers may require changes to payment terms and advance payments which may create an additional strain on liquidity.

The Company has entered into a series of amendments to its senior secured debt facility with its senior lender Hercules Capital, Inc. (“Hercules”) in order to, among other things, provide for a lower minimum cash covenant, obtain a waiver of the minimum cash covenant during certain amendment periods, and avoid events of default and acceleration of amounts due under the loan agreement. Most recently, Hercules provided an amendment through September 30, 2019, which would extend to October 22, 2019 if the outstanding loan balance is less than or equal to $5.0 million on or before September 30, 2019. As of September 4, 2019, the outstanding principal balance under the Hercules facility totaled approximately $5.6 million. In exchange for these amendments, the Company has paid down the principal balance under the Hercules facility and agreed to make additional principal payments equal to 30% of the net proceeds of stock sales under the Company’s at-the-market sales agreement, as further described in Note 17. “Debt and Financing Obligation” and Note 20. “Subsequent Events”.

As of July 31, 2019, the Company had an accumulated deficit from recurring net losses for the current and prior years. These factors as well as negative cash flows from operating and investing activities and negative working capital raise substantial doubt about the Company’s ability to continue as a going concern.

Management is working to address the Company’s current liquidity position through the exploration of various alternatives, including, but not limited to, refinancing the Company’s senior secured credit facility with Hercules; retaining existing project financing facilities and securing additional project financing facilities (including construction and term debt facilities and tax equity financing); potential sales of the Company’s assets, its intellectual property, or all or part of its business; potential licensing of certain of the Company’s technology and intellectual property; implementing cost reduction measures such as the reduction in force implemented in April; increasing sales activity related to the Company’s products; negotiating and entering into advanced technology research and development contracts; and sales of common stock or other equity securities directly to investors or through the Company’s at-the-market sales plan. Notwithstanding the Company’s efforts, the Company may not be able to refinance the Hercules credit facility on acceptable terms, or at all, retain existing project financing facilities or secure additional project financing facilities on acceptable terms, or at all, consummate any sale of its assets or all or part of its business, any sale or license of any of its intellectual property, or any sale of equity securities, implement further cost reduction measures, increase its sales activity, or successfully negotiate and enter into advanced technology contracts. Although the maturity date of the Hercules credit facility is April 1, 2020, the waiver by Hercules of certain covenants (including the minimum unrestricted cash covenant) expires by September 30, 2019 (or October 22, 2019 if the Hercules loan balance is less than or equal to $5.0 million on or before September 30, 2019). Accordingly, if the Company is not able to refinance the Hercules credit facility, and if Hercules is not willing to provide further accommodations, the Company may not meet certain covenant requirements and as a result may default on its obligations under its senior secured credit facility with Hercules. The occurrence of an event of default under the Hercules credit facility also constitutes or may result in an event of default under, and causes or may cause the acceleration of, a number of material financial obligations of the Company, including the loan from the State of Connecticut, the loan from Connecticut Green Bank, and the project finance facilities with Generate Lending, LLC (“Generate Lending”), PNC Energy Capital, LLC (“PNC”), and Fifth Third Bank (“Fifth Third”). The occurrence of an event of default under the Hercules credit facility also constitutes a triggering event under the Certificate of Designations, Preferences and Rights of the Series D Convertible Preferred Stock of the Company.

At the project finance level, as further described in Note 17. “Debt and Financing Obligation” and Note 20. “Subsequent Events”, the Company has outstanding construction loans from NRG Energy, Inc. (“NRG”), Generate Lending and Fifth Third. Under the most recent amendment to the loan agreement with NRG, the maturity date of each note payable to NRG is now the date that is the earliest of (a) September 30, 2019, (b) the commercial operation date or substantial completion date, as applicable, with respect to the fuel cell project owned by the co-borrower under such note, and (c) the repayment in full or the closing of a refinancing of the Company’s indebtedness with Hercules. NRG may also accelerate the maturity dates if it determines, in its sole discretion, that the Company is not making sufficient progress towards the completion of the construction of the 2.8 MW Tulare BioMAT project in California. If the Company is unable to make sufficient progress toward the completion of such project or to obtain another amendment, extension or refinancing, the Company may default on the NRG loan. The occurrence of an event of default under the NRG loan agreement may result in the principal and all accrued interest becoming immediately due and payable.

Under the most recent amendment to the loan agreement with Generate Lending, Generate Lending has a call right, which may be exercised during the period beginning on September 1, 2019 and ending on (and including) September 30, 2019 (which period may be further extended by mutual agreement of the parties), and which, if exercised, would require payment of all outstanding loans from Generate Lending (which are further described in Note 17. “Debt and Financing Obligations”) and all accrued and unpaid interest thereon on September 30, 2019. If Generate Lending calls the loan or determines to cease lending under its construction loan facility, the Company will be required to pursue alternative financing for the Company’s generation backlog. If the Company is unable to obtain such financing, it may result in delays in project execution and potential termination or events of default under certain power purchase agreements.

Finally, under the most recent amendment to the construction loan agreement with Fifth Third, the Company has agreed (among other things) that, no later than September 28, 2019, it will deliver to Fifth Third a binding loan agreement for permanent financing from another lender and one or more binding letters of intent from tax equity investors in an amount of at least $18.0 million, provided that such date will be automatically extended to October 21, 2019 in the event that the Hercules credit facility is repaid or extended beyond October 21, 2019, and further provided that both dates could be extended by an additional 60 days due to delays outside of the control of the Company or if Fifth Third is reasonably satisfied that the Company is negotiating diligently and in good faith with potential take-out lenders or tax equity investors. If the Company is unable to obtain a binding loan agreement for permanent financing from another lender and one or more binding letters of intent from tax equity investors in an amount of at least $18.0 million, and if Fifth Third does not provide further accommodation, the Company may default on the Fifth Third loan. The occurrence of an event of default under the Fifth Third loan may result in the principal and all accrued interest becoming immediately due and payable.

Should these obligations to NRG, Generate Lending and Fifth Third mature as described above without further extension or amendment, the Company may not have the liquidity to repay such obligations. The occurrence of an event of default under any of these project finance agreements also constitutes or may result in an event of default under, and causes or may cause the acceleration of amounts due under these agreements and a number of other material financial obligations of the Company, including the Hercules facility, the loan from the State of Connecticut, the financing agreements with PNC and the loan from the Connecticut Green Bank.

The terms of any financing and other measures to obtain funds that may be undertaken by the Company may adversely affect the holdings or the rights of the Company’s stockholders. If the Company is unable to obtain and retain funding, the Company could be forced to delay, reduce or eliminate some or all of its research and development efforts and commercialization efforts and accelerate its exploration of potential sales of its intellectual property, other assets, and business, any of which could adversely affect its business prospects, or the Company may be unable to continue operations. Although management continues to pursue its business plans, there is no assurance that the Company will be successful in obtaining and retaining sufficient funding on terms acceptable to the Company to fund continuing operations, if at all. If the Company is unable to obtain external financing and/or increase liquidity through sales of its assets, its intellectual property or all or part of its business or through licensing of its technology and intellectual property, it may not be able to sustain future operations. As a result, the Company may be required to delay, reduce and/or cease its operations and/or seek bankruptcy protection. Based on its recurring losses from operations, expectation of continuing operating losses for the foreseeable future, negative working capital, and need to raise additional capital to finance its future operations, the Company has concluded that there is substantial doubt about its ability to continue as a going concern for a period of one year after the date of filing of this Quarterly Report on Form 10-Q.

The Company’s financial statements do not include any adjustments that might result from the outcome of this uncertainty. Accordingly, the financial statements have been prepared on a basis that assumes the Company will continue as a going concern and which contemplates the realization of assets and satisfaction of liabilities and commitments in the ordinary course of business.

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 of contingent liabilities. Estimates are used in accounting for, among other things, revenue recognition, 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), income taxes, contingencies and valuing assets acquired and pre-existing contractual arrangements settled in the acquisition of Bridgeport Fuel Cell, LLC. 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.

In May 2014, the Financial Accounting Standards Board (the “FASB”) issued ASU 2014-09, “Revenue from Contracts with Customers (Topic 606)”. The objective of this ASU is to remove inconsistent practices with regard to revenue recognition in and between GAAP and International Financial Reporting Standards. ASU 2014-09 intends to improve comparability of revenue recognition practices across entities, industries, jurisdictions and capital markets. The adoption of this ASU by the Company on November 1, 2018 resulted in a cumulative effect adjustment that increased Accumulated deficit by $6.7 million.

In January 2017, the FASB issued ASU 2017-04, “Intangibles-Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment” which provides for a one-step quantitative impairment test, whereby a goodwill impairment loss will be measured as the excess of a reporting unit’s carrying amount over its fair value (not to exceed the total goodwill allocated to that reporting unit). It eliminates Step 2 of the current two-step goodwill impairment test, under which a goodwill impairment loss is measured by comparing the implied fair value of a reporting unit’s goodwill with the carrying amount of that goodwill. The standard is effective, on a prospective basis for interim and annual periods beginning after December 15, 2019, with early adoption permitted. The Company adopted this ASU effective November 1, 2018. The adoption of this ASU did not have an impact on the Company’s consolidated financial statements.

In February 2016, the FASB issued ASU 2016-02, “Leases” that amends the accounting and disclosure requirements for leases. The new guidance requires that a lessee shall recognize a right-of-use (“ROU”) asset and a corresponding lease liability, initially measured at the present value of the lease payments, in its balance sheet. Leases will be classified as either finance or operating, with classification affecting the pattern of expense recognition in the Consolidated Statements of Operations. The new standard required a modified retrospective transition approach that the Company is required to adopt on November 1, 2019. In July 2018, the FASB issued an amendment to the new leasing standard which provides an alternative transition method that allows companies to recognize a cumulative effect adjustment to the opening balance sheet upon adoption. The Company intends to elect this alternative transition method and forgo the adjustments to comparative-period financial information.

The Company has both operating and capital leases (refer to Note 19. “Commitments and Contingencies”) as well as sale-leaseback transactions that are accounted for under the finance method. The new standard provides entities with several practical expedient elections. Among them, the Company intends to elect the package of practical expedients that permits the Company to not reassess prior conclusions related to its leasing arrangements, lease classifications and initial direct costs. In addition, the Company plans to elect the practical expedients to not separate lease and non-lease components, to use hindsight in determining the lease terms and impairment of ROU assets, and to not apply the new standard’s recognition requirements to short-term leases or use the portfolio approach to a group of leases with similar characteristics. Upon adoption of this ASU, the Company will record ROU assets and the present value of its lease liabilities which are currently not recognized on its consolidated balance sheet. The Company is in the process of implementing changes to its business processes, systems and controls to support the new lease standard and its disclosure requirements. The Company is still in the process of reviewing its contractual arrangements and the impact that adoption of ASU 2016-02 will have on the Company’s consolidated financial statements.

Under Accounting Standards Codification (“ASC”) Topic 606: Revenue from Contracts with Customer (“Topic 606”), the amount of revenue recognized for any goods or services reflects the consideration that the Company expects to be entitled to receive in exchange for those goods or services. To achieve this core principle, the Company applies the following five-step approach: (1) identify the contract with a customer; (2) identify the performance obligations in the contract; (3) determine the transaction price; (4) allocate the transaction price to performance obligations in the contract; and (5) recognize revenue when or as a performance obligation is satisfied.

A contract is accounted for when there has been approval and commitment from both parties, the rights of the parties are identified, payment terms are identified, the contract has commercial substance and collectability of consideration is probable. Performance obligations under a contract are identified based on the goods or services that will be transferred to the customer that are both capable of being distinct and are distinct in the context of the contract. In certain instances, the Company has concluded distinct goods or services should be accounted for as a single performance obligation that is a series of distinct goods or services that have the same pattern of transfer to the customer. To the extent a contract includes multiple promised goods or services, the Company must apply judgment to determine whether the customer can benefit from the goods or services either on their own or together with other resources that are readily available to the customer (the goods or services are distinct) and if the promise to transfer the goods or services to the customer is separately identifiable from other promises in the contract (the goods or services are distinct in the context of the contract). If these criteria are not met, the promised services are accounted for as a single performance obligation. The transaction price is determined based on the consideration that the Company will be entitled to in exchange for transferring goods or services to the customer. To the extent the transaction price includes variable consideration, the Company estimates the amount of variable consideration that should be included in the transaction price, generally utilizing the expected value method. Determining the transaction price requires judgment. If the contract contains a single performance obligation, the entire transaction price is allocated to the single performance obligation. Contracts that contain multiple performance obligations require an allocation of the transaction price to each performance obligation based on a relative standalone selling price basis. Standalone selling price is determined by the price at which the performance obligation is sold separately. If the standalone selling price is not observable through past transactions, the Company estimates the standalone selling price by taking into account available information such as market conditions and internally approved pricing guidelines related to the performance obligations. Performance obligations are satisfied either over time or at a point in time as discussed in further detail below. In addition, the Company’s contracts with customers generally do not include significant financing components or non-cash consideration.

Product. Includes the sale of completed project assets, sale and installation of fuel cell power plants including site engineering and construction services, and the sale of modules, balance of plant (“BOP”) components and spare parts to customers.

Service. Includes performance under long-term service agreements for power plants owned by third parties.

License and royalty. Includes license fees and royalty income from manufacturing and technology transfer agreements.

Generation. Includes the sale of electricity under power purchase agreements (“PPAs”) and utility tariffs from project assets retained by the Company. This also includes revenue received from the sale of other value streams from these assets including the sale of heat, steam, capacity and renewable energy credits.

Advanced Technologies. Includes revenue from customer-sponsored and government-sponsored Advanced Technologies projects.

See below for discussion of revenue recognition under Topic 606 by disaggregated revenue stream, including a comparison to revenue recognition treatment under ASC 605, Revenue Recognition (“ASC 605”).

Contracts for the sale of completed project assets includes the sale of the project asset, the assignment of the service agreement, and the assignment of the PPA. The relative stand-alone selling price is estimated and is used as the basis for allocation of the contract consideration. Revenue is recognized upon the satisfaction of the performance obligations, which includes the transfer of control of the project asset to the customer, which is when the contract is signed and the PPA is assigned to the customer. See below for further discussion regarding revenue recognition for service agreements. The revenue recognition for completed project assets under Topic 606 is consistent with treatment under ASC 605.

Contractual payments related to the sale of the project asset and assignment of the PPA are generally received up-front. Payment terms for service agreements are generally ratable over the term of the agreement.

Service agreements represent a single performance obligation whereby the Company performs all required maintenance and monitoring functions, including replacement of modules, to ensure the power plant(s) under the service agreement generate a minimum power output. To the extent the power plant(s) under service agreements do not achieve the minimum power output, certain service agreements include a performance guarantee penalty. Performance guarantee penalties represent variable consideration, which is estimated for each service agreement based on past experience, using the expected value method. The net consideration for each service agreement is recognized using costs incurred to date relative to total estimated costs at completion to measure progress. Under ASC 605, revenue for service agreements was generally recorded ratably over the term of the service agreement, as the performance of routine monitoring and maintenance under the service agreements was expected to be incurred on a straight-line basis. If there was an estimated module exchange during the term, the costs of performance were not expected to be incurred on a straight-line basis, and therefore a portion of the initial contract value relating to the module exchange was deferred and recognized upon such module replacement event. Prior to the implementation of Topic 606, an estimate for a performance guarantee was not recorded until a performance issue occurred at a particular power plant. At that point, the actual power plant’s output was compared against the minimum output guarantee and an accrual was recorded. Furthermore, under ASC 605, performance guarantee accruals were recorded based on actual performance and the related expense was recorded to service and license cost of revenues. The review of power plant performance was updated for each reporting period to incorporate the most recent performance of the power plant and minimum output guarantee payments made to customers, if applicable.

The Company reviews its cost estimates on service agreements on a quarterly basis and records any changes in estimates on a cumulative catch-up basis.

Loss accruals for service agreements are recognized to the extent that the estimated remaining costs to satisfy the performance obligation exceed the estimated remaining unrecognized net consideration. Estimated losses are recognized in the period in which losses are identified.

The Company records any amounts that are billed to customers in excess of revenue recognized as deferred revenue and revenue recognized in excess of amounts billed to customers as unbilled receivables. Payment terms for service agreements are generally ratable over the term of the agreement.

Advanced Technologies contracts include the promise to perform research and development services and as such this represents one performance obligation. Revenue from most government sponsored Advanced Technologies projects is recognized as direct costs are incurred plus allowable overhead less cost share requirements, if any. Revenue is only recognized to the extent the contracts are funded. Revenue from fixed price Advanced Technologies projects is recognized using the cost to cost input method. There was no impact of adoption of Topic 606 on revenue recognition for Advanced Technologies contracts.

The Company records any amounts that are billed to customers in excess of revenue recognized as deferred revenue and revenue recognized in excess of amounts billed to customers as unbilled receivables. Payments are based on costs incurred for government sponsored Advanced Technologies projects and upon completion of milestones for all other projects.

The Company entered into manufacturing and technology transfer agreements (the “license agreements”) with POSCO Energy Co., Ltd. (“POSCO Energy”) in 2007, 2009 and 2012. Revenue from the license fees received from POSCO Energy were previously recognized over the term of the associated agreements. In connection with the adoption of Topic 606, several performance obligations were identified including previously satisfied performance obligations for the transfer of licensed intellectual property, two performance obligations for specified upgrades of the previously licensed intellectual property, a performance obligation to deliver unspecified upgrades to the previously licensed intellectual property on a when and if available basis, and a performance obligation to provide technical support for previously delivered intellectual property. The performance obligations related to the specified upgrades will be satisfied and related consideration recognized as revenue upon the delivery of the specified upgrades. The performance obligations for unspecified upgrades and technical support are being recognized on a straight-line basis over the license term on the basis this represents the method that best depicts the progress towards completion of the related performance obligations. All fixed consideration for the license agreements was previously collected.

Effective as of June 11, 2019, the Company entered into a License Agreement (the “EMRE License Agreement”) with ExxonMobil Research and Engineering Company (“EMRE”), pursuant to which the Company agreed, subject to the terms of the EMRE License Agreement, to grant EMRE and its affiliates a non-exclusive, worldwide, fully paid, perpetual, irrevocable, non-transferrable license and right to use the Company’s patents, data, know-how, improvements, equipment designs, methods, processes and the like to the extent it is useful to research, develop, and commercially exploit carbonate fuel cells in applications in which the fuel cells concentrate carbon dioxide from industrial and power sources and for any other purpose attendant thereto or associated therewith. Such right and license is sublicensable to third parties performing work for or with EMRE or its affiliates, but shall not otherwise be sublicensable. Upon the payment by EMRE to the Company of $10.0 million, which was received by the Company on June 14, 2019, EMRE and its affiliates were fully vested in the rights and licenses granted in the EMRE License Agreement, and any further obligations under the license agreement are considered by the Company to be minimal. As a result, the total amount received of $10.0 million was recorded as revenue for the three and nine months ended July 31, 2019.

For project assets where customers purchase electricity from the Company under PPAs, the Company has determined that these agreements should be accounted for as operating leases pursuant to ASC 840, Leases. Revenue is recognized based on the amount of electricity delivered at rates specified under the contracts, assuming all other revenue recognition criteria are met.

The cumulative effect of the changes made to the Company’s Consolidated Balance Sheets as of November 1, 2018 as a result of the adoption of Topic 606 was as follows:

The increase in long-term deferred revenue primarily pertains to license arrangement consideration previously recognized as revenue under ASC 605 that will be recognized when the specified upgrade performance obligations are satisfied.

The following tables summarize the impacts of Topic 606 on the Company’s consolidated financial statements.

For the three and nine month periods ended July 31, 2019, the only adjustment to comprehensive loss when comparing the balances with Topic 606 and the balances without Topic 606 included the adjustment to net loss.

For the nine month period ended July 31, 2019, the impact of adoption of Topic 606 on the Consolidated Statement of Cash Flows included an adjustment to net loss of $1.9 million and adjustments to changes in operating assets and liabilities consistent with the impact of adoption of Topic 606 on the July 31, 2019 Consolidated Balance Sheet as reflected above.

Contract assets as of July 31, 2019 and October 31, 2018 were $12.3 million and $23.2 million, respectively. The contract assets relate to the Company’s rights to consideration for work completed but not billed. These amounts are included on a separate line item as Unbilled receivables 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 recorded as revenue offset by customer billings. A total of $6.6 million was transferred to accounts receivable from contract assets recognized at the beginning of the period.

Contract liabilities as of July 31, 2019 and October 31, 2018 were $37.8 million and $28.1 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. These amounts are included within Deferred revenue and Long-term deferred revenue on the accompanying consolidated balance sheets. The net change in contract liabilities represents customer billings offset by revenue recorded.

Remaining performance obligations are the aggregate amount of total contract transaction price that is unsatisfied or partially unsatisfied. As of July 31, 2019, the Company’s total remaining performance obligations for service agreements, license agreements and Advanced Technologies contracts were $284.1 million. License revenue recognized over time will be recognized over the remaining term of the license agreement. License revenue recognized at a point in time will be recognized when the first specified upgrade that has been developed is delivered and when the second specified upgrade is developed and delivered. Service revenue in periods where there are no module replacements is expected to be relatively consistent from period to period whereas module replacements will result in an increase in revenue. Advanced Technologies revenue will be recognized as costs are incurred.

On October 31, 2018, FuelCell Energy Finance, LLC (“FuelCell Finance”) entered into a membership interest purchase agreement (the “Purchase Agreement”) with Dominion Generation, Inc., amended on January 15, 2019 and May 9, 2019, pursuant to which FuelCell Finance purchased (on May 9, 2019) all of the outstanding membership interests in Dominion Bridgeport Fuel Cell, LLC (which is now known as Bridgeport Fuel Cell, LLC) (“BFC”). BFC owns a 14.9 MW fuel cell park in Bridgeport, Connecticut (the “Bridgeport Fuel Cell Project”), which the Company originally developed and constructed and has been operating, for Dominion Generation, Inc. since December 2013 under a service agreement.

On May 9, 2019, FuelCell Finance closed on the purchase of BFC for a total purchase price of approximately $35.5 million, subject to a dollar-for-dollar post-closing adjustment to the extent that the closing working capital is greater or less than $1.0 million (the “BFC Purchase Price”). The Company has estimated a working capital adjustment of $0.4 million, which has been included in the BFC Purchase Price. Certain balance sheet accounts as of the transaction date, May 9, 2019, relating to the Bridgeport Fuel Cell Project service agreement (accounts receivable of $2.7 million, unbilled receivables of $15.3 million and accrued performance guarantees of $1.3 million) were settled in connection with the acquisition and accordingly were included in the consideration for the acquisition.

The acquisition was funded by loans from Fifth Third, Liberty Bank and Connecticut Green Bank (refer to Note 17. “Debt and Financing Obligation” for more information). The balance of the financing for the acquisition was funded by the $15 million of restricted cash on hand that was tied to the Bridgeport Fuel Cell Project and released at closing.

ASC Topic 805, “Business Combinations” states that a business is an integrated set of activities and assets that is capable of being conducted and managed for the purpose of providing a return in the form of dividends, lower costs, or other economic benefits directly to investors or other owners, members, or participants. As the acquisition did not meet the definition of a business combination under ASC 805, the Company accounted for the transaction as an asset acquisition. In an asset acquisition, goodwill is not recognized, but rather any excess consideration transferred over the fair value of the net assets acquired is allocated on a relative fair value basis to the identifiable net assets. The Company determined the estimated fair values using Level 3 inputs after review and consideration of relevant information, including discounted cash flows, quoted market prices and estimates made by management. The acquisition of BFC also

included a PPA with Connecticut Light and Power, a land lease with the City of Bridgeport, and working capital. The pre-existing service agreement was determined to be priced similar to current market rates and no gain or loss was recorded. A total of $38.8 million of consideration was allocated to the fuel cell power plants installation which is recorded in Project Assets, a total of $12.3 million of consideration was allocated to the PPA which is recorded as an intangible asset, and the remaining consideration was allocated to the acquired working capital. The project asset and PPA intangible asset will be depreciated and amortized over their respective useful lives. Additionally, the land lease with the City of Bridgeport was not assigned any consideration due to its insignificant value.

As of July 31, 2019, the total value of the acquired project asset was $37.4 million. The major depreciable assets of the Bridgeport Fuel Cell Project are the fuel cell modules, which will be depreciated over their estimated remaining useful lives of approximately one to seven years, and balance of plant assets, which will be depreciated over its estimated remaining useful life of approximately fifteen years. As of July 31, 2019, the total value of the intangible assets was $12.0 million and amortization expense recorded since the acquisition date of May 9, 2019 was $0.3 million. The intangible assets will be amortized over their remaining useful life of approximately ten years.

On April 12, 2019, the Company undertook a reorganization, which included a reduction in force of 135 employees, which represented 30% of the Company’s global workforce. The workforce was reduced at the North American production facility in Torrington, Connecticut, as well as at corporate offices in Danbury, Connecticut and at remote locations. There was no restructuring expense recorded because no severance was provided in connection with the reduction in force. The Company has also reduced its procurement of inventory and is implementing various cost control initiatives.

In connection with the reorganization, the Company also reviewed certain construction in process projects and identified a construction in process asset related to automation equipment for use in manufacturing which has been determined to be impaired due to uncertainty as to whether the asset will be completed as a result of the Company’s liquidity position and continued low level of production rates. The Company recorded a charge of $2.8 million which is included in Product cost of revenues on the Consolidated Statements of Operations for the nine months ended July 31, 2019.

Accounts receivable, net and Unbilled receivables as of July 31, 2019 and October 31, 2018 consisted of the following:

Accounts receivable are presented net of an allowance for doubtful accounts of $0.2 million as of October 31, 2018. There was no allowance for doubtful accounts as of July 31, 2019. Uncollectible accounts receivable are charged against the allowance for doubtful accounts when all collection efforts have failed and it is deemed unlikely that the amount will be recovered.

Inventories as of July 31, 2019 and October 31, 2018 consisted of the following:

Additional long-term inventory of $2.2 million as of July 31, 2019 includes a module that is contractually required to be segregated for use as a replacement at the Bridgeport Fuel Cell Project which is expected to be utilized beyond twelve months from July 31, 2019. There was no long-term inventory as of October 31, 2018.

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 balance of plant components, fuel cell stacks and modules, which are all subcomponents of a power plant.

The Company incurred excess plant capacity and manufacturing variances of $4.4 million and $3.0 million for the three months ended July 31, 2019 and 2018, respectively, and $11.0 million and $8.5 million for the nine months ended July 31, 2019 and 2018, respectively, which were included within product cost of revenues on the consolidated statements of operations.

Project assets as of July 31, 2019 and October 31, 2018 were $156.4 million and $99.6 million, respectively. Project assets as of July 31, 2019 and October 31, 2018 included six and five, respectively, completed, commissioned installations generating power with respect to which the Company has a PPA with an aggregate carrying value of $62.3 million and $28.6 million as of July 31, 2019 and October 31, 2018, respectively. Certain of these assets are the subject of sale-leaseback arrangements with PNC, which are accounted for under the financing method. The increase in project assets between October 31, 2018 and July 31, 2019 is primarily a result of the acquisition of the Bridgeport Fuel Cell Project. Project asset depreciation was approximately $2.4 million and $1.1 million for the three months ended July 31, 2019 and 2018, respectively, and was approximately $4.4 million and $3.1 million for the nine months ended July 31, 2019 and 2018, respectively.

The Project assets balance as of July 31, 2019 and October 31, 2018 also includes installations with an aggregate value of $94.1 million and $71.0 million, respectively, which are being developed and constructed by the Company under existing PPAs that have not been placed in service.

Project construction costs incurred for the 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 a financing obligation within “Current portion of long-term debt” and “Long-term debt and other liabilities” on the Consolidated Balance Sheets (refer to Note 17. “Debt and Financing Obligation” for more information).

As of July 31, 2019 and October 31, 2018, the Company had goodwill of $4.1 million and intangible assets of $9.6 million that were recorded in connection with the acquisition in fiscal year 2012 of Versa Power Systems, Inc. The intangible asset represents indefinite lived in-process research and development for cumulative research and development efforts associated with the development of solid oxide fuel cells stationary power generation.

The Company completed its annual impairment analysis of goodwill and in-process research and development assets as of July 31, 2019. A quantitative analysis was completed for fiscal year 2019 and the Company determined there was no impairment of goodwill or the indefinite lived intangible asset.

Other current assets as of July 31, 2019 and October 31, 2018 consisted of the following:

Other assets as of July 31, 2019 and October 31, 2018 consisted of the following:

Accrued liabilities as of July 31, 2019 and October 31, 2018 consisted of the following:

On June 13, 2018, the Company entered into an At Market Issuance Sales Agreement (the “Sales Agreement”) with B. Riley FBR, Inc. and Oppenheimer & Co. Inc. (together, the “Agents”) to create an at the market equity program under which the Company from time to time may offer and sell shares of its common stock having an aggregate offering price of up to $50.0 million through the Agents. Under the Sales Agreement, the Agent making the sales will be entitled to a commission in an amount equal to 3.0% of the gross proceeds from such sales. During the three and nine months ended July 31, 2019, the Company sold approximately 44.0 million shares under the Sales Agreement at an average sale price of $0.38 per share and raised aggregate gross proceeds of approximately $16.7 million before deducting expenses and commissions. Commissions of $0.5 million were paid to the Agent making the sales during the three and nine months ended July 31, 2019, resulting in net proceeds of approximately $16.2 million. As the Company had sold an aggregate of approximately $24.7 million of shares of common stock under the Sales Agreement as of July 31, 2019, the Company could sell, as of July 31, 2019, up to approximately $25.3 million of shares of its common stock in the future under the Sales Agreement, subject to contractual requirements, trading windows and market conditions (refer to Note 20. “Subsequent Events” for information on common stock sales under the Sales Agreement subsequent to July 31, 2019).

On May 3, 2017, the Company completed an underwritten public offering of (i) 1,000,000 shares of its common stock, (ii) Series C warrants to purchase 1,000,000 shares of its common stock and (iii) Series D warrants to purchase 1,000,000 shares of its common stock. The Series C warrants have an exercise price of $19.20 per share and a term of five years. The Series D warrants were all exercised prior to October 31, 2018. No Series C warrants were exercised during the nine months ended July 31, 2019.

On July 12, 2016, the Company closed on a registered public offering of securities to a single institutional investor pursuant to a placement agent agreement with J.P. Morgan Securities LLC. In conjunction with the offering, the Company issued a Series A warrant to purchase 640,000 shares of the Company’s common stock (the “Series A Warrant”) with an exercise price of $69.96 per share.

On February 21, 2019, the Company entered into an Exchange Agreement (the “Exchange Agreement”) with the holder (the “Warrant Holder”) of the Series A Warrant. Pursuant to the Exchange Agreement, the Company agreed to issue to the Warrant Holder 500,000 shares of the Company’s common stock (subject to adjustment for stock dividends, stock splits, stock combinations, and other reclassifications) in exchange for the transfer of the Series A Warrant back to the Company, in reliance on an exemption from registration provided by Section 3(a)(9) of the Securities Act of 1933, as amended. Following the transfer of the Series A Warrant back to the Company, the Series A Warrant was cancelled and no further shares were issuable pursuant to the Series A Warrant. For the nine months ended July 31, 2019, the Company recorded a charge to common stockholders for the difference between the fair value of the Series A Warrant prior to the modification of $0.3 million and the fair value of the common shares issuable at the date of the Exchange Agreement of $3.5 million.

The following table summarizes outstanding warrant activity during the nine months ended July 31, 2019:

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, as of July 31, 2019, shares were issued and designated as Series D Convertible Preferred Stock (referred to herein as “Series D Preferred Stock”) and 5% Series B Cumulative Convertible Perpetual Preferred Stock (referred to herein as “Series B Preferred Stock”). The Series C Convertible Preferred Stock (referred to herein as “Series C Preferred Stock”) previously issued by the Company were fully converted prior to July 31, 2019.

On August 27, 2018, the Company entered into an underwriting agreement (the “Underwriting Agreement”) with Oppenheimer & Co. Inc. (the “Underwriter”), relating to an underwritten offering (the “Offering”) of the Company’s Series D Preferred Stock with a par value of $0.01 per share. Subject to the terms and conditions contained in the Underwriting Agreement, the Underwriter agreed to purchase, and the Company agreed to sell, 30,680 shares of Series D Preferred Stock, which were initially convertible into 1,852,657 shares of the Company’s common stock (without regard to any limitation on conversion set forth in the Certificate of Designations, Preferences and Rights of the Series D Preferred Stock of the Company (the “Series D Certificate of Designation”)), at an initial conversion price of $16.56 per share, subject to certain adjustments (“Series D Conversion Price”).

The Offering closed on August 29, 2018. The net proceeds to the Company from the sale of the Series D Preferred Stock, after deducting the underwriting discounts and commissions and the offering expenses payable by the Company, were approximately $25.3 million.

In conjunction with the closing of the Offering, on August 29, 2018, the Company filed the Series D Certificate of Designation with the Secretary of State of the State of Delaware, designating 30,680 shares of the Company’s preferred stock as Series D Convertible Preferred Stock (such shares, the “Series D Preferred Shares”).

As of July 31, 2019 and October 31, 2018, there were 25 and 30,680 shares, respectively, of Series D Preferred Stock issued and outstanding with a carrying value of $27.0 thousand and $27.4 million, respectively.

During the three and nine months ended July 31, 2019, holders of the Series D Preferred Stock converted 18,932 and 30,655 Series D Preferred Shares into 59,021,202 and 61,947,759 shares of common stock, respectively, through installment and optional conversions, triggering event conversions and acceleration of future installment amounts, resulting in a reduction of $20.5 million and $31.1 million, respectively, to the carrying value being recorded to equity. Conversions in which the conversion price was below $16.56 (the conversion price of the Series D Preferred Stock as of July 31, 2019 and during the three and nine months ended July 31, 2019) resulted in a variable number of shares being issued to settle the conversion amounts and are treated as a partial redemption of the Series D Preferred Shares. Conversions during the three and nine months ended July 31, 2019 that were settled in a variable number of shares and treated as redemptions resulted in deemed dividends of $3.1 million and $6.0 million, respectively. The deemed dividends represent the difference between the fair value of the shares of common stock issued to settle the conversion amounts and the carrying value of the Series D Preferred Shares.

The Series D Preferred Stock redemption accretion of $3.8 million for the nine months ended July 31, 2019 reflects the accretion of the difference between the carrying value and the amount that would have been redeemed if stockholder approval had not been obtained for the issuance of common stock equal to 20.0% or more of the Company’s outstanding voting stock prior to the issuance of the Series D Preferred Stock. Additionally, prior to receiving stockholder approval of the issuance of 20.0% or more of the Company’s outstanding voting stock immediately preceding the issuance of the Series D Preferred Stock, the holders were prohibited from converting Series D Preferred Shares into shares of common stock if such conversion would have caused the Company to issue pursuant to the terms of the Series D Preferred Stock a number of shares in excess of the maximum number of shares permitted to be issued thereunder without breaching the Company’s obligations under the rules or regulations of the Nasdaq Global Market. The Company received stockholder approval of such issuance at the annual meeting of the Company’s stockholders on April 4, 2019.

Any failure to pay any amounts due to the holders of the Series D Preferred Shares, as well as certain other “triggering events,” including, without limitation, the Company’s failure to timely deliver shares, the suspension of trading of the Company’s common stock, the Company’s failure to keep reserved for issuance an adequate number of shares of common stock to cover conversion of the Series D Preferred Shares, breaches of certain agreements that permit the other party to such agreement to declare a default or accelerate amounts due, the existence of a circumstance or event that would result in a default under another agreement that would or is reasonably expected to have a material adverse effect, and breaches of certain covenants that are not timely cured, where a cure period is permitted, would permit the holders of the Series D Preferred Shares to require the Company to redeem such Series D Preferred Shares in cash at a price equal to the greater of (i) 125% of the stated value of the Series D Preferred Shares being redeemed plus accrued dividends, if any, and (ii) the market value of the number of shares issuable on conversion of the Series D Preferred Shares valued at the greatest closing sales price during the period from the date immediately before the triggering event through the date the Company makes the redemption payment.

Alternatively, in the event of such a triggering event, the holders of Series D Preferred Shares may elect to convert such shares (subject to the beneficial ownership limitations provided in the Series D Certificate of Designation) into shares of common stock at a conversion price equal to the lower of the Series D Conversion Price in effect on the trading day (as such term is defined in the Series D Certificate of Designation) immediately preceding the delivery of the conversion notice and 85% of the lowest dollar volume weighted average price (“VWAP”) of the common stock on any of the five consecutive trading days ending on the trading day immediately prior to delivery of the applicable conversion notice.

During the week of June 10, 2019, the holders of the Series D Preferred Stock asserted that certain triggering events had occurred under the Series D Certificate of Designation and indicated their intent to exercise their rights to convert certain of their shares at a reduced conversion price. While the Company did not agree with the basis for their assertions or their characterization of such events, there are provisions under the Series D Certificate of Designation which could be interpreted as giving them the right to demand such conversion at a reduced conversion price. Accordingly, during the period beginning on June 11, 2019 and ending on July 3, 2019, the Company effected conversions at reduced conversion prices ranging from $0.14 to $0.61, resulting in the issuance of 52,702,282 shares of common stock.

The Company issued an aggregate of 33,500 shares of its Series C Convertible Preferred Stock (“Series C Preferred Stock” and such shares, the “Series C Preferred Shares”), $0.01 par value and $1,000 stated value per share, during the fiscal year ended October 31, 2017. As of July 31, 2019 and October 31, 2018, there were 0 and 8,992 shares, respectively, of Series C Preferred Stock issued and outstanding with a carrying value of $0 and $7.5 million, respectively.

On February 21, 2019, the Company entered into a waiver agreement (the “Waiver Agreement”) with the holder of the Series C Preferred Stock (such holder, the “Series C Holder”). Under the Waiver Agreement, the Series C Holder waived any equity conditions failures that may have occurred under the Certificate of Designations, Preferences and Rights of the Series C Preferred Stock (the “Series C Certificate of Designations”). The Series C Holder further waived any triggering event occurring after the date of the Waiver Agreement, as well as its right to demand, require or otherwise receive cash payments under the Series C Certificate of Designations, which waiver would have terminated upon the occurrence of certain key triggering events (failure to provide freely tradable shares, suspension from trading on the Nasdaq Global Market or another eligible market, or failure to convert or deliver shares under certain circumstances), the occurrence of a fundamental transaction, a breach of the Waiver Agreement, or the occurrence of a bankruptcy triggering event. In addition, the Company agreed in the Waiver Agreement, pursuant to Section 8(d) of the Series C Certificate of Designations, to adjust the conversion price of the Series C Preferred Stock in connection with future conversions, such that, when the Series C Holder converted its Series C Preferred Stock into common stock, it would receive approximately 25% more shares than it would have received upon conversion prior to the execution of the Waiver Agreement. Under the Waiver Agreement, the conversion price of the Series C Preferred Stock is stated to be the lowest of (i) $4.45, (ii) 85% of the lowest closing bid price of the Company’s common stock during the period beginning on and including the fifth trading day prior to the date on which the applicable conversion notice is delivered to the Company and ending on and including the date on which the applicable conversion notice is delivered to the Company, and (iii) 85% of the quotient of (A) the sum of the five lowest VWAPs of the Company’s common stock during the twenty consecutive trading day period ending and including the trading day immediately preceding the applicable conversion date divided by (B) five. To determine the number of shares of common stock to be issued upon conversion, 125% of the value of the Series C Preferred Shares being converted is divided by the applicable conversion price. The parties further agreed to waive the installment payment/conversion provisions in Section 9 of the Series C Certificate of Designations, which required installment conversions or payments to be made on the 1^st and 16^th of each month (as described in additional detail below). Under the Waiver Agreement, conversions of Series C Preferred Stock were permitted to occur and did occur after the original March 1, 2019 maturity date, and the Company further agreed to reserve specific numbers of shares for issuance to the Series C Holder and the holders of the Series D Preferred Stock until the Company effected a reverse stock split, which occurred on May 8, 2019, or increased its authorized shares of common stock.

The Waiver Agreement was treated for accounting purposes to be an extinguishment of the Series C Preferred Stock instrument as of February 21, 2019. The Series C Preferred Stock remained classified in mezzanine equity, however, the carrying value was adjusted to reflect the estimated fair value of the post-modification Series C Preferred Shares which incorporated the new terms outlined in the Waiver Agreement. The valuation utilized a Binomial Lattice Model (“Lattice Model”) which is a commonly used methodology to value path-dependent options or stock units in order to capture their potential early conversion. The Lattice Model produces an estimated fair value based on changes in the underlying stock price over successive periods of time. The assumptions used in the model such as stock price, conversion price and conversion ratio were consistent with date of execution and terms in the Waiver Agreement. Other assumptions included the volatility of the Company’s stock which was assumed to be 75% and a discount rate of 20% which was estimated based on various indices consistent with the Company’s profile, venture capital rates of return and the Company’s borrowing rate. The Lattice Model resulted in an estimated fair value as of February 21, 2019 of $13.5 million whereby the Series C Preferred Stock carrying value was adjusted to this amount. As discussed above, a beneficial conversion feature was recorded during the three months ended January 31, 2019 due to reductions in the conversion price. Upon extinguishment during the three months ended April 30, 2019, the Company first allocated $6.6 million to the reacquisition of the embedded conversion option equal to the intrinsic value that was previously recognized during the three months ended January 31, 2019 for the embedded conversion option. Because the remaining estimated fair value of the instrument on February 21, 2019 was less than the carrying amount of the Series C Preferred Stock, the amount of the shortfall resulted in a decrease in loss available to common stockholders for purposes of computing loss per share of $0.5 million.

In order to resolve different interpretations of the provisions of the Series C Certificate of Designations that governed adjustments to the conversion price in connection with sales of common stock under the Company’s at-the-market stock sales plan below the initial conversion price $22.08 and whether such sales constituted sales of variable priced securities under the Series C Certificate of Designations, the Company’s Board of Directors (the “Board”) agreed to reduce the conversion price of the Series C Preferred Shares from $22.08 to $18.00 effective August 27, 2018 in exchange for a waiver of certain anti-dilution and price adjustment rights under the Series C Certificate of Designations for future at-the-market sales of common stock. The conversion price of the Series C Preferred Shares was adjusted again on December 3, 2018 to $6.96, on December 17, 2018 to $6.00 and on January 2, 2019 to $5.16. During the period from February 1, 2019 to May 23, 2019, the conversion price was further adjusted to prices ranging from $4.45 to $1.27, the conversion price as of the last conversion, which occurred on May 23, 2019. Conversions occurring during the three and nine months ended July 31, 2019 resulted in a variable number of shares being issued to settle the conversion amounts and were treated as a partial redemption of the Series C Preferred Shares. Conversions during the three and nine months ended July 31, 2019 that were settled in a variable number of shares and treated as partial redemptions resulted in deemed contributions of $0.9 million and $1.5 million,

respectively. The deemed contributions represent the difference between the fair value of the common shares issued to settle the conversion amounts and the carrying value of the Series C Preferred Shares. Additionally, as discussed in more detail below, the net loss attributable to common stockholders for the nine months ended July 31, 2019 was impacted by a $0.5 million decrease in the loss resulting from accounting for the Waiver Agreement in February 2019 which was recorded during the three months ended April 30, 2019. The net loss attributable to common stockholders for the nine months ended July 31, 2019 also includes the $8.6 million redemption value adjustment recorded during the three months ended January 31, 2019.

Based on review of pertinent accounting literature including ASC 470 – Debt, ASC 480 - Distinguishing Liabilities from Equity and ASC 815 - Derivative and Hedging, the Series C Preferred Shares are classified outside of permanent equity on the Consolidated Balance Sheets and were recorded at fair value on the issuance date (proceeds from the issuance, net of direct issuance cost). The decline in the Company’s stock price during the three months ended January 31, 2019 and between January 31, 2019 and the execution of the Waiver Agreement in February 2019 resulted in equity conditions failures under the Series C Certificate of Designations, which were waived by the Series C Holder in the Waiver Agreement, as described above. Prior to the execution of such Waiver Agreement, the conversion price was adjusted in December 2018 and January 2019 as described in the paragraph above. This contingent beneficial conversion feature resulted in a $6.6 million reduction in the Series C Preferred Shares carrying value. Because the equity conditions failures were continuing as of January 31, 2019 (prior to the execution of the Waiver Agreement), the Series C Preferred Shares were adjusted to 108% of stated redemption value as of January 31, 2019 with a corresponding charge to common stockholders of $8.6 million.

During the three and nine months ended July 31, 2019, holders of the Series C Preferred Stock converted 1,618 and 8,992 Series C Preferred Shares into 1,658,861 and 3,914,218 shares of common stock, respectively, resulting in a reduction in carrying value of $3.2 million and $15.5 million, respectively. Upon the conversion of the last outstanding Series C Preferred Shares on May 23, 2019, there were no further Series C Preferred Shares outstanding.

As of July 31, 2019, the Company had 105,875 shares of 5% Series B Cumulative Convertible Perpetual Preferred Stock with a liquidation preference of $1,000.00 per share (referred to herein as “Series B Preferred Stock”) authorized for issuance. As of July 31, 2019 and October 31, 2018, there were 64,020 shares of Series B Preferred Stock issued and outstanding, with a carrying value of $59.9 million. Dividends of $1.6 million and $2.4 million were paid in cash during the nine month periods ended July 31, 2019 and 2018, respectively. Dividends of $0 and $0.8 million were paid during the three month periods ended July 31, 2019 and 2018, respectively.

No dividends were declared or paid by the Company on the Series B Preferred Stock in connection with the May 15, 2019 dividend payment date. Based on the dividend rate in effect on May 15, 2019, the aggregate amount of such dividend payment would have been $0.8 million. Because such dividends were not paid on May 15, under the terms of the Amended Certificate of Designation with respect to the Series B Preferred Stock, the holders of shares of Series B Preferred Stock will be entitled to receive, when, as and if, declared by the Board, dividends at a dividend rate per annum equal to the normal dividend rate of 5% plus an amount equal to the number of dividend periods for which the Company failed to pay or set apart funds to pay dividends multiplied by 0.0625%, for each subsequent dividend period until the Company has paid or provided for the payment of all dividends on the shares of Series B Preferred Stock for all prior dividend periods. As of July 31, 2019, a total of $0.81 million will be payable with respect to the May 15 dividend period, if and when declared by the Board.

As of July 31, 2019, FCE FuelCell Energy, Ltd. had 1,000,000 Class A Cumulative Redeemable Exchangeable Preferred Shares (the “Series 1 Preferred Shares”) issued and outstanding, which are held by Enbridge, Inc. (“Enbridge”), which is a related party. Dividends and return of capital payments are due quarterly based on calendar quarters. The Company made payments of Cdn. $0.3 million and Cdn. $0.9 million during the three month period ended December 31, 2018 and the nine month period ended July 31, 2018, respectively, under the terms of the Company’s agreement with Enbridge. However, the Company’s return of capital payments were not made for the calendar quarters ended on March 31, 2019 and June 30, 2019. The Company recorded interest expense, which reflects the amortization of the fair value discount of approximately Cdn. $1.4 million and Cdn. $0.7 million for the three months ended July 31, 2019 and 2018, respectively, and Cdn. $2.2 million and Cdn. $2.1 million for the nine months ended July 31, 2019 and 2018, respectively. As of July 31, 2019 and October 31, 2018, the carrying value of the Series 1 Preferred Shares was Cdn. $22.2 million (U.S. $16.9 million) and Cdn. $20.9 million (U.S. $15.9 million), respectively, and is classified as a preferred stock obligation of subsidiary on the Consolidated Balance Sheets.

	Three Months Ended July 31,						Nine Months Ended July 31,
	2019			2018			2019			2018
Numerator
Net loss	$	(5,311	)	$	(15,881	)	$	(42,389	)	$	(33,238	)
Series A warrant exchange		—			—			(3,169	)		—
Series B preferred stock dividends		(810	)		(800	)		(2,410	)		(2,400	)
Series C preferred stock deemed contributions (dividends) and redemption value adjustment, net		884			(939	)		(6,522	)		(8,601	)
Series D Preferred stock deemed dividends and redemption accretion		(3,091	)		—			(9,752	)		—
Net loss attributable to common stockholders	$	(8,328	)	$	(17,620	)	$	(64,242	)	$	(44,239	)
Denominator
Weighted average basic common shares		45,069,911			7,191,457			21,608,427			6,607,687
Effect of dilutive securities ⁽¹⁾		—			—			—			—
Weighted average diluted common shares		45,069,911			7,191,457			21,608,427			6,607,687
Basic loss per share	$	(0.18	)	$	(2.45	)	$	(2.97	)	$	(6.70	)
Diluted loss per share ⁽¹⁾	$	(0.18	)	$	(2.45	)	$	(2.97	)	$	(6.70	)

As of July 31, 2019 and October 31, 2018, there was $29.8 million and $40.9 million, respectively, of restricted cash and cash equivalents pledged as collateral for letters of credit for certain banking requirements and contractual commitments. The restricted cash balance as of October 31, 2018 included $15.0 million, which was placed in a Grantor’s Trust account to secure certain obligations under a 15-year service agreement and has been classified as long-term. In connection with the acquisition of the Bridgeport Fuel Cell Project, $15.0 million of restricted cash was released on May 9, 2019. The restricted cash balance as of July 31, 2019 and October 31, 2018 also includes $17.8 million and $17.7 million, respectively, to support obligations related to the PNC sale-leaseback transactions. As of July 31, 2019, an additional amount of $6.9 million was classified as restricted cash to support future obligations under the loan agreements with Fifth Third and Liberty Bank. As of July 31, 2019 and October 31, 2018, outstanding letters of credit totaled $5.2 million and $3.8 million, respectively. These expire on various dates through August 2028.

As of July 31, 2019, the Company had a long-term loan agreement with the Connecticut Green Bank, providing a total of $5.9 million in support of the Bridgeport Fuel Cell Project. During the three months ended July 31, 2019, this loan was partially repaid with a new project level loan from Connecticut Green Bank in connection with the Company’s acquisition of all of the membership interests in BFC. The balance as of July 31, 2019 was $1.8 million.

On May 9, 2019, in connection with the closing of the purchase of BFC, BFC 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”). 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 balance under the Subordinated Credit Agreement as of July 31, 2019 was $5.9 million.

Also on May 9, 2019, in connection with the purchase of BFC, FuelCell Finance (a subsidiary of the Company) entered into a Credit Agreement with Liberty Bank, as administrative agent and co-lead arranger, and Fifth Third as co-lead arranger (the “BFC Credit Agreement”), whereby (i) Fifth Third provided financing to BFC in the amount of $12.5 million towards the BFC Purchase Price; and (ii) Liberty Bank provided financing to BFC in the amount of $12.5 million towards the BFC Purchase Price. As security for the BFC Credit Agreement, Liberty Bank and Fifth Third 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 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 Finance’s ownership interest in BFC. Principal and interest are due monthly in amounts sufficient to fully amortize the loans over an 84 month period. The maturity date of each loan under the BFC Credit Agreement is May 9, 2025. The interest rate under the BFC Credit Agreement fluctuates monthly at the 30-day LIBOR rate plus 275 basis points on a total notional value which is equivalent to the outstanding principal.

On May 16, 2019, an interest rate swap agreement (the “Swap Agreement”) was entered into with Fifth Third 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 totals a fixed rate of 5.09%. The interest rate swap will be marked-to-market on a quarterly basis. The mark-to-market adjustment is based on Level 2 inputs including primarily the forward LIBOR curve available to swap dealers. The mark-to-market methodology involves comparison of (i) the sum of the present value of all monthly variable rate payments during the term at the notional amount of the loan outstanding based on a reset rate using the forward LIBOR curve and (ii) the sum of the present value of all monthly fixed rate payments during the term of the loan at the notional amount which is equivalent to the outstanding principal. The mark-to-market adjustment for the three and nine months ended July 31, 2019 was $0.4 million.

The BFC Credit Agreement also requires BFC to maintain a debt service reserve at each of Liberty Bank and Fifth Third of $1.25 million, which debt service reserves were funded on May 10, 2019, to be held in deposit accounts at each respective bank, with funds to be disbursed with the consent of or at the request of the required lenders in their sole discretion. Each of Liberty Bank and Fifth Third also has an operation and module replacement reserve (“O&M Reserve”) of $250.0 thousand, both of which were funded at closing, to be held in deposit accounts at each respective bank, and thereafter BFC is required to deposit $100.0 thousand 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, as applicable. BFC is also required to maintain excess cash flow reserve accounts at each of Liberty Bank and Fifth Third and to deposit 50% of the excess cash flows from the Bridgeport Fuel Cell Project into these accounts. Excess cash flow consists of cash generated by BFC from the Bridgeport Fuel Cell Project after payment of all expenses (including after payment of service fees to the Company), debt service to Liberty Bank and Fifth Third, 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 annually based on fiscal quarters beginning with the quarter ended July 31, 2020. The BFC Credit Agreement contains other representations, warranties and covenants and includes a material adverse effect clause related to the operations, business, properties, liabilities or prospects of Bridgeport Fuel Cell, LLC.

Several of the Company’s project finance subsidiaries previously entered into sale-leaseback agreements with PNC for commissioned projects where the Company had entered into a PPA with the site host/end-user of produced power. Under the financing method of accounting for a sale-leaseback, the Company did not recognize as income any of the sale proceeds received from the lessor that contractually constitute payments to acquire the assets subject to these arrangements. Instead, the sale proceeds received were accounted for as financing obligations. The outstanding financing obligation balance as of July 31, 2019 was $45.2 million and the decrease from $46.1 million on October 31, 2018 includes lease payments offset by the recognition of interest expense. The outstanding financing obligation includes an embedded gain which will be recognized at the end of the lease term.

In November 2015, the Company entered into a definitive Assistance Agreement with the State of Connecticut 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 percent, repayable over 15 years. Principal payments were deferred for four years from disbursement and begin on December 1, 2019. Under the Assistance Agreement, the Company was eligible for forgiveness of up to 50 percent of the loan principal 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 extends the Target Date to October 31, 2022 and amends the Employment Obligation to require the Company to maintain a minimum of 538 full-time positions for 24 consecutive months. If the Company meets the Employment Obligation, as modified by the Second Amendment, and creates an additional 91 full-time positions, the Company may receive a credit in the amount of $2.0 million to be applied against the outstanding balance of the loan. The Second Amendment deletes and cancels the provisions of the Assistance Agreement related to the second phase of the expansion project and the loans related thereto, but the Company had not drawn any funds or received any disbursements under those provisions. A job audit will be performed within ninety days of the Target Date. If the Company does not meet the Employment Obligation, then a penalty shall be assessed at a rate of $18,587.36 times the number of employees below the Employment Obligation. Such penalty, which accelerates the payment, is immediately payable and will be first applied against any outstanding fees or interest due and then against outstanding principal.

In April 2016, the Company entered into a loan and security agreement (as amended from time to time, the “Hercules Agreement”) with Hercules for an aggregate principal amount of up to $25.0 million. The loan was a 30 month secured facility.

The Hercules Agreement was subsequently amended on September 5, 2017, October 27, 2017, March 28, 2018, August 29, 2018, December 19, 2018, February 28, 2019, March 29, 2019, May 8, 2019, June 11, 2019 and July 24, 2019. Principal payments under the Hercules Agreement began on April 1, 2019 and were expected to total approximately $1.8 million per month, however, the Company has been prepaying principal as a result of the recent amendments to the Hercules Agreement, resulting in a loan balance of $7.4 million as of July 31, 2019. The term loan interest rate as of July 31, 2019 was 10.65%. The term loan interest rate is the greater of (i) 9.90% plus the prime rate minus 4.50%, and (ii) 9.90%. The initial end of term charge of $1.7 million was paid on October 1, 2018. An additional end of term charge of $0.9 million will be due on April 1, 2020 or upon repayment of the principal balance. The additional end of term charge is being accreted over a 30-month term.

On June 11, 2019, the Company and each of its qualified subsidiaries, as “Borrower”, certain banks and other financial institutions, as “Lender”, and Hercules, as administrative agent for itself and Lender, entered into the ninth amendment to the Hercules Agreement (the “Ninth Hercules Amendment”). Under the Ninth Hercules Amendment, Borrower agreed, among other things, to: (a) no later than June 11, 2019, pay Lender $1.4 million to be applied towards the outstanding balance of the loan; (b) no later than June 26, 2019, direct EMRE to pay Lender $6.0 million of the $10.0 million payable under the EMRE License Agreement to be applied towards the outstanding balance of the loan; and (c) on each of July 1, 2019 and August 1, 2019, pay Lender interest-only payments on the outstanding principal balance of the loan. In the Ninth Hercules Amendment, the term “Amendment Period” is defined as the period from and after June 11, 2019 through the earlier of (i) August 9, 2019 and (ii) the occurrence of any event of default under the Ninth Hercules Amendment. The Hercules Agreement was further modified by the Tenth Hercules Amendment described below.

On July 24, 2019, the Company and each of its qualified subsidiaries, as Borrower, certain banks and other financial institutions, as Lender, and Hercules, as administrative agent for itself and Lender, entered into the tenth amendment to the Hercules Agreement (the “Tenth Hercules Amendment”). In the Tenth Hercules Amendment, the “Amendment Period” is defined as the period from and after July 24, 2019 through the earlier of (i) September 30, 2019 and (ii) the occurrence of any event of default under the Tenth Hercules Amendment; provided, however, that in the event that the outstanding balance of the secured obligations (including accrued interest, fees, costs, and charges) has been paid down to an amount that is less than or equal to $5.0 million on or before September 30, 2019, the Amendment Period shall be extended automatically through the earlier of (i) October 22, 2019 and (ii) the occurrence of any event of default under the Tenth Hercules Amendment.

Under the Tenth Hercules Amendment, Borrower has agreed, among other things, to: (a) no later than July 25, 2019, pay Lender $4.0 million to be applied towards the outstanding balance of the loan; (b) from and after July 24, 2019 through the end of the Amendment Period under the Tenth Hercules Amendment, pay Lender, on the third trading day of each week (each, an “ATM Payment Date”) following a week in which the Company issues shares of its common stock under the Sales Agreement or any similar or replacement agreement (each such week, an “ATM Issuance Period”), an amount equal to 30% of the net proceeds, after deducting commissions and any offering-related expenses, of such issuances (“Net ATM Proceeds”), if any, received in cash by Borrower from such issuances, if any, during the ATM Issuance Period completed immediately prior to such ATM Payment Date, which amount shall be applied towards the outstanding balance of the loan; and (c) pay to Lender an interest-only payment on the outstanding principal balance of the loan at the term loan interest rate, which payment shall be due and payable on September 1, 2019; provided, however, that in the event the Amendment Period under the Tenth Hercules Amendment is extended to October 22, 2019 (as described above), Borrower shall pay to Lender an interest and amortization payment on the outstanding principal balance of the secured obligations at the term loan interest rate, which payment shall be due and payable on October 1, 2019. Borrower has further agreed that interest at the default rate (which

is an additional 5% per annum against outstanding obligations), which has been accruing from June 3, 2019, will continue to accrue and be due and payable, subject to the terms of the Tenth Hercules Amendment; provided, however, that in the event that all of the secured obligations are paid in full on or prior to the last day of the Amendment Period under the Tenth Hercules Amendment (as such may be extended as described above), Lender will fully and unconditionally waive its right to payment of accrued and unpaid default rate interest. The accrued and unpaid default rate interest totaled $0.1 million as of July 31, 2019.

In addition, Hercules has waived Borrower’s compliance with certain financial reporting covenants and the minimum unrestricted cash balance covenant set forth in the Hercules Agreement, in each case from June 11, 2019 through the end of the Amendment Period under the Tenth Hercules Amendment.

The Hercules Agreement contains certain representations and warranties, affirmative and negative covenants, and events of default, including the occurrence of a circumstance that would reasonably be expected to have a material adverse effect, that entitle Hercules to cause the indebtedness under the agreement to become immediately due and payable. The occurrence of an event of default under the Hercules Agreement also constitutes or may result in an event of default under, and causes or may cause the acceleration of, a number of material financial obligations of the Company, including the loan from the State of Connecticut, the loan from Connecticut Green Bank, and the project finance facilities with Generate Lending, PNC and Fifth Third. The occurrence of an event of default under the Hercules Agreement also constitutes a triggering event under the Series D Certificate of Designations.

As collateral for obligations under the Hercules Agreement, the Company granted Hercules a security interest in FuelCell Energy, Inc.’s existing and thereafter-acquired assets except for intellectual property and certain other excluded assets. The collateral does not include assets held by FuelCell Finance or any project subsidiary thereof. The Company may continue to collateralize and finance its project subsidiaries through other lenders and partners.

On December 13, 2018, FuelCell Finance’s wholly owned subsidiary, Central CA Fuel Cell 2, LLC, drew a construction loan advance of $5.8 million under the NRG loan facility. This advance was used to support the completion of construction of the 2.8 MW Tulare BioMAT project in California. In conjunction with the December 13, 2018 draw, FuelCell Finance and NRG entered into an amendment to the NRG loan agreement to revise the definitions of the terms “Maturity Date” and “Project Draw Period” under the NRG loan agreement and to make other related revisions. Pursuant to this amendment, FuelCell Finance and its subsidiaries could only request draws through December 31, 2018 and the Maturity Date of each note was the earlier of (a) March 31, 2019 and (b) the commercial operation date or substantial completion date, as applicable, with respect to the fuel cell project owned by the borrower under such note. As of July 31, 2019, there have been no other drawdowns under the NRG loan facility.

Prior to July 31, 2019, the Maturity Date was subsequently extended through amendments to the NRG loan agreement on March 29, 2019 (the “Third Amendment”), June 13, 2019 and July 11, 2019 (the “Fifth Amendment”). In connection with the Third Amendment, the Company agreed to make an additional payment of $750 thousand at the Maturity Date, which is recorded in interest expense on the Consolidated Statement of Operations. In addition, the Fifth Amendment, which was in effect as of the end of the quarter, extended the Maturity Date of each note to the earlier of (a) August 9, 2019, (b) the commercial operation date or substantial completion date, as applicable, with respect to the fuel cell project owned by Central CA Fuel Cell 2, LLC, and (c) closing of a refinancing of indebtedness; provided, however, in the event NRG determines, in its sole discretion, that the Company is not making sufficient progress toward the completion of the construction of the 2.8 MW Tulare BioMAT project in California, including but not limited to delivery of a mutually agreed plan of completion by no later than July 19, 2019, NRG may accelerate the Maturity Date on the date of such determination. Refer to Note 20. “Subsequent Events” for information regarding an additional amendment to the terms of the NRG loan agreement, including a further extension of the Maturity Date.

On December 21, 2018, the Company, through its indirect wholly-owned subsidiary FuelCell Energy Finance II, LLC (“FCEF II”), entered into a Construction Loan Agreement (as amended from time to time, the “Generate Agreement”) with Generate Lending pursuant to which Generate Lending agreed (the “Commitment”) to make available to FCEF II a credit facility in an aggregate principal amount of up to $100.0 million (the “Generate Facility”) to fund the manufacture, construction, installation, commissioning and start-up of stationary fuel cell projects to be developed by the Company on behalf of FCEF II during the Availability Period (as defined below). Fuel cell projects must meet certain conditions to be determined to be “Approved Projects” under the Generate Facility. If approved by Generate Lending at its sole discretion, the Generate Facility may be comprised of multiple loans to individual Approved Projects (each, a “Working Capital Loan”). Each Working Capital Loan will be sized to the lesser of (i) 100% of the construction budget and (ii) the invested amount that allows Generate Lending to achieve a 10% unlevered, after-tax inefficient internal rate of return. Approved Projects will be funded at milestones on a cost incurred basis. FCEF II and the Company will contribute any additional equity required to

construct an Approved Project on a pari-passu basis with the Working Capital Loans. The Commitment to provide Working Capital Loans will remain in place for thirty-six months from the date of the Generate Agreement (the “Availability Period”). Interest will accrue at 9.5% per annum, calculated on a 30/360 basis, on all outstanding principal, paid on the first business day of each month. The initial draw amount under the Generate Facility, funded at closing, was $10.0 million. The initial draw reflects loan advances for the first Approved Project under the Generate Facility, the Bolthouse Farms 5 MW project in California.

The maturity date for the outstanding principal amount of each Working Capital Loan will be the earlier of (a) the achievement of the Commercial Operation Date under the Engineering, Procurement and Construction (“EPC”) Agreement for such Approved Project, (b) ninety days prior to the required Commercial Operation Date under the Revenue Contract (as defined in the Generate Agreement), or (c) upon certain defaults by FCEF II.

As of September 1, 2019, Generate Lending has the right to issue a notice to FCEF II that all Working Capital Loans shall be due and payable on September 30, 2019. If Generate Lending delivers such notice, all of the Working Capital Loans, together with all accrued and unpaid interest thereon, shall be due and payable in their entirety, without penalty or premium. Further, if Generate Lending delivers such notice, FCEF II may prepay all then outstanding Working Capital Loans at any time prior to September 30, 2019. Mandatory prepayments are required in the event of (i) material damage or destruction to an Approved Project, (ii) termination or default under an Approved Project’s Revenue Contract, (iii) a change of control, or (iv) failure to achieve Substantial Completion as defined under the EPC Agreement for such Approved Project by the required dates. Refer to Note 20. “Subsequent Events” for information regarding recent amendments to the terms of the Generate Agreement.

On January 9, 2019, the Company, through its indirect wholly-owned subsidiary TRS Fuel Cell, LLC, entered into a Loan and Security Agreement (the “Enhanced Capital Loan Agreement”) with Enhanced Capital Connecticut Fund V, LLC in the amount of $1.5 million. Interest will accrue at a rate of 6.0% per annum, calculated on a 30/360 basis, on all outstanding principal, paid on the first business day of each month. The loan maturity date is three years from the date of the Enhanced Capital Loan Agreement upon which the outstanding principal and accrued interest will be payable.

On February 28, 2019, the Company, through its indirect wholly-owned subsidiary, Groton Station Fuel Cell, LLC (“Groton Borrower”), entered into a Construction Loan Agreement (the “Groton Agreement”) with Fifth Third pursuant to which Fifth Third agreed to make available to Groton Borrower a construction loan facility in an aggregate principal amount of up to $23.0 million (the “Groton Facility”) to fund the manufacture, construction, installation, commissioning and start-up of the 7.4 MW fuel cell power plant for the Connecticut Municipal Electric Energy Cooperative located on the U.S. Navy submarine base in Groton, Connecticut (the “Groton Project”). Groton Borrower made an initial draw under the Groton Facility on the date of closing of $9.7 million and made a draw of $1.4 million in April 2019. The total outstanding balance as of July 31, 2019 was $11.1 million.

Amounts borrowed under the Groton Facility bear interest at a rate equal to the sum of the one-month LIBOR Rate plus 2.25%. Regular monthly payments are interest-only. Amounts borrowed under the Groton Facility may be prepaid at any time without penalty. The maturity date of the Groton Facility will be the earlier of (a) October 31, 2019, (b) the commercial operation date of the Groton Project, or (c) one business day after receipt of proceeds of debt financing (i.e., take out financing) in an amount sufficient to repay the outstanding indebtedness under the Groton Facility. Mandatory prepayments are required in the event of material damage or destruction to the Groton Project or a change of control of Groton Borrower.

The Company has agreed to guarantee Groton Borrower’s obligations under the Groton Agreement. In addition, Groton Borrower’s obligations under the Groton Agreement are secured by a first mortgage lien on Groton Borrower’s leasehold interest in the Groton Project site, a security interest in the Groton Project assets, including material Groton Project related contracts such as the power purchase agreement and engineering, procurement and construction agreement, and the Company’s equity interest in the Groton Borrower. The Groton Agreement contains customary representations and warranties, affirmative and negative covenants, and events of default that entitle Fifth Third to cause the indebtedness under the Groton Facility to become immediately due and payable. Refer to Note 20. “Subsequent Events” for information regarding an amendment to the terms of the Groton Agreement.

Deferred finance costs relate primarily to (i) sale-leaseback transactions entered into with PNC which are being amortized over the ten-year term, (ii) payments under the Hercules Agreement, which are being amortized over the term of the loan and (iii) payments under the loans obtained to purchase BFC which are being amortized over the term of the loans.

The Company recorded income tax expense of $0.1 million for the nine months ended July 31, 2019 compared to an income tax benefit totaling $3.0 million for the nine months ended July 31, 2018. The Company recorded income tax expense of $0.02 million for the three months ended July 31, 2019 and 2018. The income tax benefit for the nine months ended July 31, 2018 primarily related to the Tax Cuts and Jobs Act (the “Act”) that was enacted on December 22, 2017. The Act reduced the U.S. federal corporate tax rate from 34% to 21% effective January 1, 2018 which resulted in a deferred tax benefit of $1.0 million primarily related to a reduction of the Company’s deferred tax liability for an in process research and development asset (“IPR&D”). The Act also established an unlimited carryforward period for the net operating loss (“NOL”) the Company generated in fiscal year 2018. This provision of the Act resulted in a reduction of the valuation allowance attributable to deferred tax assets at the enactment date by $2.0 million based on the indefinite life of the resulting NOL as well as the deferred tax liability for its IPR&D asset.

The Company leases certain computer and office equipment in Torrington and Danbury, Connecticut and manufacturing facilities in Torrington, Connecticut under operating leases expiring on various dates through 2030.

Non-cancelable minimum payments applicable to operating and capital leases as of July 31, 2019 were as follows:

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).

Under the terms of the Company’s PPAs, customers agree to purchase power from the Company’s fuel cell power plants 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, the Company is responsible for all operating costs necessary to maintain, monitor and repair the power plants. Under certain agreements, the Company is also responsible for procuring fuel, generally natural gas or biogas, to run the power plants.

As of July 31, 2019, the Company had unconditional purchase commitments aggregating $44.8 million, for materials, supplies and services in the normal course of business.

The Company is involved in legal proceedings, claims and litigation arising out of the ordinary conduct of its business. Although the Company cannot assure the outcome, management presently believes that the result of such 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.

On August 8, 2019, FuelCell Finance, Central CA Fuel Cell 2, LLC, and NRG entered into the sixth amendment to the NRG loan agreement, which amends the definition of “Maturity Date” under the NRG loan agreement. Pursuant to the sixth amendment, the Maturity Date of each note is now the date that is the earliest of (a) September 30, 2019, (b) the commercial operation date or substantial completion date, as applicable, with respect to the fuel cell project owned by the co-borrower under such note, and (c) the repayment in full or the closing of a refinancing of the Company’s indebtedness with Hercules; provided, however, in the event NRG determines, in its sole discretion, that the Company is not making sufficient progress toward the completion of the construction of the 2.8 MW Tulare BioMAT project in California, NRG may accelerate the Maturity Date on the date of such determination. In conjunction with the sixth amendment, Central CA Fuel Cell 2, LLC prepaid interest (which would otherwise be paid at maturity) that had been accrued through the date of the sixth amendment totaling approximately $0.3 million.

On December 21, 2018, the Company, through its indirect wholly-owned subsidiary FCEF II, entered into the Generate Agreement with Generate Lending. In connection with the execution of the Generate Agreement and concurrently therewith, Generate Lending, FCEF II and the Company entered into a Right to Finance Agreement, which gave the Generate Lending an exclusive right, subject to certain exclusions and exceptions, to provide construction financing through the Generate facility to all of the Company’s stationary fuel cell projects and provided that, upon a breach of such exclusivity provision, FCEF II would pay to Generate Lending a cash amount equal to $650,000 (the “Liquidated Damages Amount”).

Pursuant to the terms of the Generate Agreement, Generate Lending had an optional call right which, if exercised, was required to be noticed during the ten day period beginning on June 20, 2019 and ending on (and including) June 30, 2019 (as amended or modified from time to time, the “Call Right”). If Generate Lending had exercised its Call Right during that period, all of the Working Capital Loans (as described elsewhere herein) (in an amount equal to $10,000,000), together with all accrued and unpaid interest thereon, would have been due and payable in their entirety, without penalty or premium, prior to September 30, 2019.

On June 28, 2019, FCEF II, Generate Lending, and various project company guarantors entered into the First Amendment to the Generate Agreement (the “First Generate Amendment”). Under the First Generate Amendment, the Call Right was modified to give Generate Lending the right to exercise the Call Right, requiring payment of all Working Capital Loans and all accrued and unpaid interest thereon on September 30, 2019, during the ten day period beginning on August 1, 2019 and ending on (and including) August 11, 2019. Concurrently with the execution of the First Generate Amendment, the Company, FCEF II and Generate Lending entered into the First Amendment to the Right to Finance Agreement, which provided that, if Generate Lending exercised its Call Right, the Right to Finance Agreement (as amended) would terminate. In addition, in the First Amendment to the Right to Finance Agreement, the provision requiring the payment of the Liquidated Damages Amount (as described above) was deleted in its entirety.

On August 7, 2019, Generate Lending exercised the Call Right. On August 13, 2019, FCEF II, Generate Lending and various project company guarantors entered into the Second Amendment to the Generate Agreement (the “Second Generate Amendment”). Under the Second Generate Amendment, the Call Right was further amended to provide Generate Lending the right to exercise the Call Right, requiring payment of all Working Capital Loans and all accrued and unpaid interest thereon on September 30, 2019, any time between September 1, 2019 and September 30, 2019, subject to further extension upon mutual agreement of FCEF II and Generate Lending. Pursuant to the Second Generate Amendment, FCEF II and various project company guarantors agreed to (i) use all commercially reasonable efforts to provide Generate Lending with a consent to assignment of the power purchase agreement for the 7.4 MW project in Brookhaven, New York currently under development, (ii) provide daily reports to Generate Lending in form and substance satisfactory to Generate Lending, (iii) use all commercially reasonable efforts to provide information to Generate Lending within three business days of Generate Lending’s request therefor, and (iv) by September 1, 2019, at FCEF II’s cost and Generate Lending’s option to either (x) provide executed bailee letters for all collateral under the Generate Agreement or (y) move all collateral currently held at the Company’s Danbury and/or Torrington facilities, or any other facility owned or leased by FCEF II or the Company to a mutually agreeable separate location only accessible with the consent of Generate Lending. Failure to timely comply with any of the foregoing shall constitute a Facility Event of Default (as defined in the Generate Agreement). With the execution of the Second Generate Amendment, Generate Lending withdrew its August 7, 2019 notice exercising the Call Right. Concurrently with the execution of the Second Generate Amendment, the Company, FCEF II and Generate Lending entered into the Second Amendment to the Right to Finance Agreement, which provides that if Generate Lending exercises its Call Right (as amended by the Second Generate Amendment), the Right to Finance Agreement will terminate as of September 30, 2019.

On August 13, 2019, Groton Borrower and Fifth Third entered into Amendment No. 1 to the Groton Agreement (the “Groton Amendment”). Under the Groton Amendment, the definition of “Commitment” was amended to reduce the aggregate principal amount of the facility available to Groton Borrower from $23.0 million to $18.0 million. Pursuant to the Groton Amendment, Groton Borrower has agreed to (i) no later than August 16, 2019, deliver executed bailee letters for certain collateral, (ii) no later than August 21, 2019, provide Fifth Third with a plan to fund the remaining project costs needed to complete the construction of the Groton Project, (iii) complete the conditioning of the first of the remaining two fuel cells units for the Groton Project no later than September 19, 2019 and the final fuel cell unit for the Groton Project by October 25, 2019, and (iv) no later than September 28, 2019, deliver to Fifth Third a binding loan agreement for permanent financing with another lender and one or more binding letters of intent from tax equity investors, such date to be automatically extended to October 21, 2019 in the event that the Company’s credit facility with Hercules is repaid or extended beyond October 21, 2019; and further provided that such dates shall be extended by an additional 60 days due to delays outside of the control of Groton Borrower or if Fifth Third is reasonably satisfied that Groton Borrower is negotiating diligently and in good faith with potential take-out lenders or tax equity investors.

No dividends were declared or paid by the Company on the Series B Preferred Stock in connection with the August 15, 2019 dividend payment date. Based on the dividend rate in effect on August 15, 2019, the aggregate amount of such dividend payment would have been $0.8 million. Because such dividends were not paid on August 15, under the terms of the Amended Certificate of Designation with respect to the Series B Preferred Stock, the holders of shares of Series B Preferred Stock will be entitled to receive, when, as and if, declared by the Board, dividends at a dividend rate per annum equal to the normal dividend rate of 5% plus an amount equal to the number of dividend periods for which the Company failed to pay or set apart funds to pay dividends multiplied by 0.0625% for each subsequent dividend period until the Company has paid or provided for the payment of all dividends on the shares of Series B Preferred Stock for all prior dividend periods. A total of $0.83 million will be payable with respect to the August 15 dividend period, if and when declared by the Board.

During the period beginning on August 1, 2019 and ending on (and including) August 8, 2019, the Company sold approximately 7.5 million shares of its common stock under the Sales Agreement at an average sale price of $0.31 per share and raised aggregate gross proceeds of approximately $2.4 million, before deducting expenses and commissions. Commissions of $0.07 million were paid to the Agent making the sales during the period beginning on August 1, 2019 and ending on (and including) August 8, 2019, resulting in net proceeds of approximately $2.3 million.

As the Company had sold an aggregate of approximately $27.1 million of shares of common stock under the Sales Agreement as of September 4, 2019, the Company may sell up to approximately $22.9 million of common stock in the future under the Sales Agreement, subject to contractual requirements, trading windows and market conditions.

This Quarterly Report on Form 10-Q (including exhibits and any information incorporated by reference herein) contains both historical and forward-looking statements 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,” “projects,” “intends,” “plans,” “believes,” “predicts,” “should,” “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) future funding under Advanced Technologies contracts; (iv) future financing for projects including publicly issued bonds, equity and debt investments by investors and commercial bank financing; (v) the expected cost competitiveness of our technology; and (vi) our ability to achieve our sales plans and cost reduction targets and execute on our backlog.

The forward-looking statements contained in this report are subject to risks and uncertainties, known and unknown, that could cause actual results to differ materially from those forward-looking statements, including the risks contained in Part II, Item 1A, “Risk Factors” of this Quarterly Report on Form 10-Q and the following risks and uncertainties: general risks associated with product development and manufacturing; general economic conditions; changes in the utility regulatory environment; changes in the utility industry and the markets for distributed generation, distributed hydrogen, and carbon capture configured fuel cell power plants; potential volatility of energy prices; 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; rapid technological change; competition; our dependence on strategic relationships; 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; our ability to address our current liquidity position; government appropriations; the ability of the government to terminate its 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 reduce our levelized cost of energy and our cost reduction strategy generally; our ability to protect our intellectual property; litigation and other proceedings; the risk that commercialization of our products will not occur when anticipated; our need for and the availability of additional financing and/or refinancing alternatives for our senior secured credit facility and for project 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 power plants; our ability to execute on our backlog; and our ability to expand our customer base and maintain relationships with our largest customers and strategic business allies.

We cannot assure you that: we will be able to meet any of our development or commercialization schedules; any of our new products or technology, once developed, will be commercially successful; our existing SureSource power plants will remain commercially successful; 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; we will be able to obtain refinancing for our senior secured credit facility or other financing to fund our operations; we will be able to address our current liquidity position; we will be able to execute on our backlog; or we will be able to achieve any other result anticipated in any other forward-looking statement contained herein.

Investors are cautioned that any such 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.

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. Actual results could differ from those estimates. Estimates are used in accounting for, among other things, revenue recognition, 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), income taxes 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. 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, 2018 filed with the 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.

FuelCell Energy develops and delivers efficient, affordable and clean solutions for the supply, recovery and storage of energy. We design, manufacture, undertake project development of, install, operate and maintain megawatt-scale and sub-megawatt fuel cell systems, serving utilities and industrial and large municipal power users with solutions that include both utility-scale and on-site power generation, as well as advancing development of solutions for carbon capture, local hydrogen production for transportation and industrial users, and long duration energy storage. Fuel cell power plants utilizing our technology are operating in more than 50 locations on three continents and have generated more than 9.0 million megawatt hours (MWh) of electricity.

We provide comprehensive turn-key power generation solutions to our customers, including multi-year power purchase agreements (“PPAs”), power plant installation, and operations and maintenance under multi-year service agreements. We both develop projects as well as sell equipment directly to customers, providing either a complete solution of engineering, installing and servicing the fuel cell power plant, or selling the power plant equipment and providing long-term maintenance only. We offer to arrange financing structures that enable power users to benefit from the multitude of advantages of clean onsite power while avoiding an up-front capital investment. Utilizing long-term PPAs or lease structures, the end-user of the power hosts the installation and only pays for power as it is delivered. For projects that we develop, the end user of the power typically enters into a PPA, and we have the option to either identify a project investor to purchase the power plant and assume the PPA, or retain the project and recognize electricity revenue over the term of the PPA. We target large-scale power users with our megawatt-class installations. To provide a frame of reference, one megawatt (“MW”) is adequate to continually power approximately 1,000 average sized U.S. homes. Our customer base includes utility companies, municipalities, universities, hospitals, government entities and a variety of industrial and commercial enterprises. Our leading geographic markets are the United States and South Korea, and we are pursuing expanding opportunities in other countries around the world.

Our value proposition is to enable economic returns with clean, affordable, reliable and resilient fuel cell power plants that supply power where consumed. Our products can also be configured for carbon capture, energy recovery and storage applications. Our solutions are easy-to-site in populated areas as they are clean, operate quietly and without vibrations, and have only modest space requirements. Fuel cells use an electrochemical process to convert a fuel source into electricity and heat in a highly efficient process that emits virtually no pollutants as the fuel is not burned, generating power that is almost wholly absent of criteria pollutants such as nitrogen oxide that causes smog, sulfur oxide that contributes to acid rain, and particulate matter that can aggravate asthma. Locating power generation near the point of use reduces reliance on the transmission grid, leading to enhanced energy security and power reliability. Utilities can minimize or even avoid the cost of transmission or other infrastructure by adopting distributed generation, which saves their customers the cost of installing and maintaining transmission and also avoids the losses associated with transmitting electricity over great distances. Our power plants provide electricity priced competitively to grid-delivered electricity in certain high cost regions, and our strategy is to continue to reduce costs, which we believe will lead to wider adoption.

On August 19, 2019, the Board of Directors (the “Board”) of the Company appointed Jason B. Few as the Company’s President and Chief Executive Officer, effective as of August 26, 2019. Mr. Few will also continue to serve as a director of the Company. Beginning on August 26, 2019, Mr. Few, in his capacity as President, will assume the responsibilities previously undertaken by Jennifer D. Arasimowicz in her role as Interim President of the Company and, accordingly, her term and service as Interim President will cease as of such date. Ms. Arasimowicz will remain in her role as General Counsel, Corporate Secretary, Executive Vice President, and Chief Commercial Officer.

On July 30, 2014, FuelCell Energy Finance, LLC (“FuelCell Finance”), a wholly owned subsidiary of the Company, entered into a Loan Agreement (as amended from time to time, the “NRG Loan Agreement”) with NRG Energy, Inc. (“NRG”), pursuant to which NRG extended a $40 million revolving construction and term financing facility (the “NRG Facility”) to FuelCell Finance for the purpose of accelerating project development by the Company and its subsidiaries. On December 13, 2018, FuelCell Finance’s wholly owned subsidiary, Central CA Fuel Cell 2, LLC (“Co-Borrower”, and, together with FuelCell Finance, the “Credit Parties”), drew a construction loan advance of approximately $5.8 million under the NRG Facility. In conjunction with this advance, the NRG Loan Agreement was amended on December 13, 2018, and this advance became the last advance under the NRG Facility. The NRG Loan Agreement was also subsequently amended on March 29, 2019, June 13, 2019, and July 11, 2019.

On August 8, 2019, FuelCell Finance, Co-Borrower, and NRG entered into the sixth amendment to the NRG Loan Agreement, which amends the definition of “Maturity Date” under the NRG Loan Agreement. Pursuant to the sixth amendment, the Maturity Date of each note is now the date that is the earliest of (a) September 30, 2019, (b) the commercial operation date or substantial completion date, as applicable, with respect to the fuel cell project owned by the co-borrower under such note, and (c) the repayment in full or the closing of a refinancing of the Company’s indebtedness with Hercules Capital, Inc. (“Hercules”); provided, however, in the event NRG determines, in its sole discretion, that the Credit Parties are not making sufficient progress toward the completion of the construction of the 2.8 MW Tulare BioMAT project in California, NRG may accelerate the Maturity Date on the date of such determination. In conjunction with the sixth amendment, the Co-Borrower prepaid interest (which would otherwise be paid at maturity) that has been accrued through the date of the sixth amendment totaling approximately $0.3 million.

Pursuant to the terms of the Generate Agreement, Generate Lending had an optional call right which, if exercised, was required to be noticed during the ten day period beginning on June 20, 2019 and ending on (and including) June 30, 2019 (as amended or modified from time to time, the “Call Right”). If Generate Lending had exercised its Call Right during that period, all of the Working Capital Loans (as defined elsewhere herein) (in an amount equal to $10,000,000), together with all accrued and unpaid interest thereon, would have been due and payable in their entirety, without penalty or premium, prior to September 30, 2019.

On June 28, 2019, FCEF II, Generate Lending, and various project company guarantors entered into the First Amendment to the Generate Agreement (the “First Generate Amendment”). Under the First Generate Amendment, the Call Right was modified to give Generate Lending the right to exercise the Call Right, requiring payment of all Working Capital Loans and all accrued and unpaid interest thereon on September 30, 2019, during the ten day period beginning on August 1, 2019 and ending on (and including) August 11, 2019. Concurrently with the execution of the First Generate Amendment, the Company, FCEF II and Generate Lending entered into the First Amendment to the Right to Finance Agreement, which provided that, if Generate Lending exercised its Call Right, the Right to Finance Agreement (as amended) would terminate as of August 11, 2019. In addition, in the First Amendment to the Right to Finance Agreement, the provision requiring the payment of the Liquidated Damages Amount (as described above) was deleted in its entirety.

On August 13, 2019, FCEF II, Generate Lending and various project company guarantors entered into the Second Amendment to the Generate Agreement (the “Second Generate Amendment”). Under the Second Generate Amendment, the Call Right was further amended to provide Generate Lending the right to exercise the Call Right, requiring payment of all Working Capital Loans and all accrued and unpaid interest thereon on September 30, 2019, any time between September 1, 2019 and September 30, 2019, subject to further extension upon mutual agreement of FCEF II and Generate Lending. Pursuant to the Second Generate Amendment, FCEF II and various project company guarantors agreed to (i) use all commercially reasonable efforts to provide Generate Lending with a consent to assignment of the power purchase agreement for the 7.4 MW project in Brookhaven, New York currently under development, (ii) provide daily reports to Generate Lending in form and substance satisfactory to Generate Lending, (iii) use all commercially reasonable efforts to provide information to Generate Lending within three business days of Generate Lending’s request therefor, and (iv) by September 1, 2019, at FCEF II’s cost and Generate Lending’s option to either (x) provide executed bailee letters for all collateral under the Generate Agreement or (y) move all collateral currently held at the Company’s Danbury and/or Torrington facilities, or any other facility owned or leased by FCEF II or the Company to a mutually agreeable separate location only accessible with the consent of Generate Lending. Failure to timely comply with any of the foregoing shall constitute a Facility Event of Default (as defined in the Generate Agreement). With the execution of the Second Generate Amendment, Generate Lending withdrew its August 7, 2019 notice exercising the Call Right. Concurrently with the execution of the Second Generate Amendment, the Company, FCEF II and Generate Lending entered into the Second Amendment to the Right to Finance Agreement, which provides that if Generate Lending exercises its Call Right (as amended by the Second Generate Amendment), the Right to Finance Agreement will terminate as of September 30, 2019.

On February 28, 2019, the Company, through its indirect wholly-owned subsidiary, Groton Station Fuel Cell, LLC (“Groton Borrower”), entered into a Construction Loan Agreement (the “Groton Agreement”) with Fifth Third Bank (“Fifth Third”), pursuant to which Fifth Third agreed to make available to Groton Borrower a construction loan facility in an aggregate principal amount of up to $23.0 million (the “Groton Facility”) to fund the manufacture, construction, installation, commissioning and start-up of the 7.4 MW fuel cell power plant for the Connecticut Municipal Electric Energy Cooperative located on the U.S. Navy submarine base in Groton, Connecticut (the “Groton Project”).

On June 13, 2018, the Company entered into an At Market Issuance Sales Agreement (the “Sales Agreement”) with B. Riley FBR, Inc. and Oppenheimer & Co. Inc. (together, the “Agents”) to create an at the market equity program under which the Company from time to time may offer and sell shares of its common stock having an aggregate offering price of up to $50.0 million through the Agents. Under the Sales Agreement, the Agent making the sales will be entitled to a commission in an amount equal to 3.0% of the gross proceeds from such sales. During the period beginning on July 15, 2019 and ending on (and including) August 8, 2019, the Company sold approximately 51.5 million shares under the Sales Agreement at an average sale price of $0.37 per share and raised aggregate gross proceeds of approximately $19.1 million before deducting expenses and commissions. Commissions of $0.6 million were paid to the Agent making the sales during the period beginning on July 15, 2019 and ending on (and including) August 8, 2019, resulting in net proceeds of approximately $18.5 million.

Net proceeds of such sales totaling approximately $5.9 million have been used to pay down the outstanding balance of the Company’s senior secured credit facility with Hercules, leaving an outstanding balance under that facility of approximately $5.6 million as of September 4, 2019.

Management evaluates the 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”).

Our revenues and cost of revenues for the three months ended July 31, 2019 and 2018 were as follows:

Total revenues for the three months ended July 31, 2019 of $22.7 million reflects an increase of $10.6 million from $12.1 million for the same period in the prior year. Total cost of revenues for the three months ended July 31, 2019 increased by $0.6 million to $14.7 million from $14.1 million during the same period in the prior year. A discussion of the changes in product revenues, service and license revenues, generation revenues and Advanced Technologies contract revenues follows.

Our product revenues, cost of product revenues and gross loss from product revenues for the three months ended July 31, 2019 and 2018 were as follows:

There was no product revenue during the three months ended July 31, 2019, whereas product revenue for the three months ended July 31, 2018 was $1.3 million. Product revenues for the three months ended July 31, 2018 related primarily to the 20 MW order from Hanyang Industrial Development Co., Ltd (“HYD”), pursuant to which we provided equipment to HYD for a fuel cell project with Korea Southern Power Co., Ltd. (“KOSPO”). Shipments began in the fourth quarter of fiscal 2017 and were completed in the first quarter of fiscal 2018. The Company completed commissioning the plant in the third quarter of fiscal 2018.

Cost of product revenues increased $0.4 million for the three months ended July 31, 2019 to $4.5 million, compared to $4.1 million in the same period in the prior year. Overall gross loss from product revenues was $4.5 million for the three months ended July 31, 2019 compared to gross loss of $2.8 million in the comparable prior year period. Both periods were impacted by the under-absorption of fixed overhead costs due to low production volumes. Manufacturing variances, primarily related to low production volumes and other charges, totaled approximately $4.4 million for the three months ended July 31, 2019 compared to approximately $3.0 million for the three months ended July 31, 2018. For the three months ended July 31, 2019, we operated at an annualized production rate of approximately 2 MW which is a reduction from the prior year annual production rate of 25 MW.

As of July 31, 2019, product sales backlog totaled approximately $1.0 thousand, compared to $9.5 thousand as of July 31, 2018.

Service and license revenues and related costs for the three months ended July 31, 2019 and 2018 were as follows:

Revenues for the three months ended July 31, 2019 from service agreements and license fee and royalty agreements increased $6.0 million to $11.5 million from $5.5 million for the three months ended July 31, 2018. Service and license revenue increased from the three months ended July 31, 2018 primarily due to revenues of $10.0 million recorded for a License Agreement that was entered into with ExxonMobil Research and Engineering Company (“EMRE”). The increase in revenue for the three months ended July 31, 2019 was offset by lower revenue from module replacements during the three months ended July 31, 2019 compared to the same period in the prior year. The prior year also included revenue recorded for the Bridgeport Fuel Cell Project service agreement. As a result of the purchase of the Bridgeport Fuel Cell Project on May 9, 2019, revenue under this service agreement is no longer being recognized.

We adopted Accounting Standards Update (ASU) 2014-09, “Revenue from Contracts with Customers” (“Topic 606”) as of November 1, 2018 which impacted service and license revenues recognition. Service revenues are now recorded based on a cost-to-cost input method whereas previously service revenues for maintenance and monitoring were recorded ratably over the term of the service agreement and revenue from module exchanges was recognized upon the module replacement event. Performance guarantees, which were previously recorded as a cost of service and license revenues, are now accounted for as variable consideration with a reduction to service and license revenues. License revenues were previously recorded over the contract term on a straight-line basis, however, upon adoption of Topic 606, we assessed the performance obligations within an existing license contract and allocated consideration between performance obligations that are satisfied at a point in time and performance obligations that are recognized over time. Revenue from the license performance obligation that is satisfied over time was $0.3 million for the three month period ended July 31, 2019 compared to $0.6 million for the three month period ended July 31, 2018 and the decrease is a result of the adoption of Topic 606.

Cost of service and license revenues decreased $4.9 million to $1.1 million for the three months ended July 31, 2019 from $6.0 million for the three months ended July 31, 2018. Cost of service agreements includes maintenance and operating costs and module exchanges. As further discussed above, cost of service agreements for the prior year period included charges for performance guarantees.

Overall gross profit from service and license revenues was $10.4 million for the three months ended July 31, 2019 which represents an increase of $10.8 million from a gross loss of $0.4 million for the three months ended July 31, 2018. The overall gross margin percentage was 90.4% for the three months ended July 31, 2019 compared to a gross loss of 8.1% in the prior year period.

As of July 31, 2019, service and license backlog totaled approximately $256.9 million, compared to $317.8 million as of July 31, 2018. Service and license backlog does not include future variable royalties. This backlog relates to service agreements of up to twenty years and is expected to generate positive margins and cash flows based on current estimates.

Generation revenues and related costs for the three months ended July 31, 2019 and 2018 were as follows:

Revenues from generation for the three months ended July 31, 2019 totaled $5.4 million which represents an increase of $3.8 million from revenue recognized of $1.7 million for the three months ended July 31, 2018. Generation revenues for the three months ended July 31, 2019 and 2018 reflect revenue from electricity generated under our PPAs. Generation revenues increased for the three months ended July 31, 2019 compared to the prior year period due to additional revenue recorded for the Bridgeport Fuel Cell Project, which is now recognized under a PPA. Cost of generation revenues totaled $5.7 million in the three months ended July 31, 2019, which represents an increase from the comparable prior year period. Cost of generation revenues included depreciation of approximately $2.7 million and $1.1 million for the three months ended July 31, 2019 and 2018, respectively. We had 26.1 MW of operating power plants in our portfolio as of July 31, 2019, compared to 11.2 MW as of July 31, 2018. This increase is primarily a result of the acquisition of the Bridgeport Fuel Cell Project.

As of July 31, 2019, generation backlog totaled approximately $1.2 billion, compared to $430.0 million as of July 31, 2018.

Advanced Technologies contract revenues and related costs for the three months ended July 31, 2019 and 2018 were as follows:

Advanced Technologies contract revenues for the three months ended July 31, 2019 were $5.8 million, which reflects an increase of $2.2 million when compared to $3.6 million of revenues for the three months ended July 31, 2018. Advanced Technologies contract revenues were higher for the three months ended July 31, 2019 primarily due to the timing of activity under existing contracts. Cost of Advanced Technologies contract revenues increased $0.7 million to $3.4 million for the three months ended July 31, 2019, compared to $2.7 million for the same period in the prior year. Advanced Technologies contracts for the three months ended July 31, 2019 generated a gross profit of $2.4 million compared to a gross profit of $0.8 million for the three months ended July 31, 2018. The increase in Advanced Technologies contract gross margin is related to the timing and mix of contracts being performed during the three months ended July 31, 2019.

As of July 31, 2019, Advanced Technologies backlog totaled approximately $27.2 million compared to $35.8 million as of July 31, 2018.

Administrative and selling expenses were $7.1 million and $6.1 million for the three months ended July 31, 2019 and 2018, respectively. The increase from the prior year period primarily relates to legal and consulting costs related to our restructuring and refinancing initiatives. Total legal and professional fees incurred in the three months ended July 31, 2019 were $3.3 million compared to $1.1 million in the prior year period offset by lower expenses due to restructuring initiatives.

Research and development expenses decreased to $2.0 million for the three months ended July 31, 2019 compared to $6.3 million during the three months ended July 31, 2018. The decrease related to the reduction in spending resulting from the restructuring initiatives and resources being allocated to funded Advanced Technologies projects.

Loss from operations for the three months ended July 31, 2019 was $1.1 million compared to $14.5 million for the three months ended July 31, 2018. The decrease in the loss from operations was primarily a result of higher gross profit primarily due to revenues recorded for the EMRE License Agreement and lower operating expenses for the three months ended July 31, 2019.

Interest expense for the three months ended July 31, 2019 and 2018 was $3.5 million and $2.4 million, respectively. Interest expense for both periods presented includes interest on the loan and security agreement with Hercules, interest expense related to sale-leaseback transactions and interest for the amortization of the redeemable preferred stock of subsidiary fair value discount. The increase in interest expense represents additional interest on the loans made by Fifth Third and Liberty Bank in connection with the acquisition of the Bridgeport Fuel Cell Project and an end of term fee of $0.8 million that was recorded for the NRG Facility.

Other expense, net, was expense of $0.7 million and income of $1.0 million for the three months ended July 31, 2019 and 2018, respectively. Other expense, net for the three months ended July 31, 2018 includes expense of $0.4 million for the fair value adjustment of an interest rate swap and foreign exchanges losses related to the remeasurement of the Canadian Dollar denominated preferred stock obligation of our U.S. Dollar functional currency Canadian subsidiary, offset by income from refundable research and development tax credits. The income for the three months ended July 31, 2018 includes foreign exchange gains related to the remeasurement of the Canadian Dollar denominated preferred stock obligation and income from refundable research and development tax credits.

Dividends recorded on our 5% Series B Cumulative Convertible Perpetual Preferred Stock (“Series B Preferred Stock”) were $0.8 million for the three month periods ended July 31, 2019 and 2018. The dividends for the three month period ended July 31, 2019, which would have been paid on or before May 15, 2019, were not declared and paid. Because such dividends were not paid, under the terms of the Amended Certificate of Designation with respect to the Series B Preferred Stock, the holders of shares of Series B Preferred Stock will be entitled to receive, when, as and if, declared by the Board, dividends at a dividend rate per annum equal to: the normal dividend rate of 5%, plus an amount equal to the number of dividend periods for which the Company failed to pay or set apart funds to pay dividends multiplied by 0.0625%, for each subsequent dividend period until the Company has paid or provided for the payment of all dividends on the shares of Series B Preferred Stock for all prior dividend periods.

Conversions resulted in a variable number of shares being issued to settle the conversion amounts and were treated as a partial redemption of our Series C Convertible Preferred Stock (“Series C Preferred Stock” and such shares, the “Series C Preferred Shares”). Conversions during the three months ended July 31, 2019 and 2018 that were settled in a variable number of shares and treated as partial redemptions resulted in deemed contributions of $0.9 million and deemed dividends of $0.9 million, respectively. The deemed contributions and dividends represent the difference between the fair value of the common shares issued to settle the conversion amounts and the carrying value of the Series C Preferred Shares.

Conversions where the conversion price was below the initial conversion price (as adjusted for the reverse stock split) of $16.56 per share resulted in a variable number of shares being issued to settle the conversion amounts and are treated as a partial redemption of the shares of the Company’s Series D Convertible Preferred Stock (“Series D Preferred Stock” and such shares, the “Series D Preferred Shares”). Conversions during the three months ended July 31, 2019 that were settled in a variable number of shares and treated as redemptions resulted in deemed dividends of $3.1 million. The deemed dividends represent the difference between the fair value of the common shares issued to settle the conversion amounts and the carrying value of the Series D Preferred Shares.

Net loss attributable to common stockholders represents the net loss for the period less the preferred stock dividends on the Series B Preferred Stock, the preferred stock deemed contributions (dividends) on the Series C Preferred Stock and the Series D Preferred Stock deemed dividends. For the three month periods ended July 31, 2019 and 2018, net loss attributable to common stockholders was $8.3 million and $17.6 million, respectively, and loss per common share was $0.18 and $2.45, respectively.

Our revenues and cost of revenues for the nine months ended July 31, 2019 and 2018 were as follows:

Total revenues for the nine months ended July 31, 2019 of $49.7 million reflects a decrease of $21.8 million from $71.5 million for the same period in the prior year. Total cost of revenues for the nine months ended July 31, 2019 decreased by $22.0 million to $47.6 million from $69.6 million during the same period in the prior year. A discussion of the changes in product revenues, service and license revenues, generation revenues and Advanced Technologies contract revenues follows.

Our product revenues, cost of product revenues and gross loss for the nine months ended July 31, 2019 and 2018 were as follows:

Product revenues for the nine months ended July 31, 2018 included $39.9 million of power plant revenue and $3.2 million of revenue related to engineering and construction services. There was no product revenue recorded for the nine months ended July 31, 2019. Product revenue for the nine months ended July 31, 2018 included revenues from the 20 MW order from HYD, pursuant to which we provided equipment to HYD for a fuel cell project with KOSPO. Shipments began in the fourth quarter of fiscal 2017 and were completed in the first quarter of fiscal 2018. During the nine months ended July 31, 2018, we also recorded product revenues for the sale of a 2.8 MW fuel cell power plant project located at the waste water treatment facility in Tulare, California to Clearway Energy.

Cost of product revenues decreased $29.8 million for the nine months ended July 31, 2019 to $14.4 million, compared to $44.2 million in the same period in the prior year. Overall gross loss from product revenues was $14.4 million for the nine months ended July 31, 2019 compared to a gross loss of $1.1 million in the comparable prior year period. Both periods were impacted by the under-absorption of fixed overhead costs due to low production volumes. Manufacturing variances, primarily related to low production volumes and other charges, totaled approximately $11.0 million for the nine months ended July 31, 2019 compared to approximately $8.5 million for the nine months ended July 31, 2018. Cost of revenues for the nine months ended July 31, 2019 also includes a charge for a specific construction in process asset related to automation equipment for use in manufacturing with a carrying value of $2.8 million, which was impaired due to uncertainty as to whether the asset will be completed as a result of the Company’s liquidity position and continued low level of production rates. For the nine months ended July 31, 2019, we operated at an annualized production rate of approximately 17.5 MW compared to a 25 MW annualized production rate in the same period in the prior year. The annualized production rate as of July 31, 2019 was 2 MW.

Service and license revenues and related costs for the nine months ended July 31, 2019 and 2018 were as follows:

Revenues for the nine months ended July 31, 2019 from service agreements and license fee and royalty agreements increased $13.0 million to $25.9 million from $12.9 million for the nine months ended July 31, 2018. Service agreement and license revenue increased from the nine months ended July 31, 2018 primarily due to revenue of $10.0 million recorded for the EMRE License Agreement during the nine months ended July 31, 2019 and higher revenue from module replacements during the nine months ended July 31, 2019 compared to the same period in the prior year. Revenue from a license performance obligation that is satisfied over time was $1.3 million for the nine month period ended July 31, 2019 compared to $1.7 million for the nine month period ended July 31, 2018.

Cost of service and license revenues increased $3.2 million to $15.1 million for the nine months ended July 31, 2019 from $11.9 million for the nine months ended July 31, 2018. Cost of service agreements includes maintenance and operating costs and module exchanges. As discussed previously, cost of service agreements for the prior year period included charges for performance guarantees.

Overall gross profit from service and license revenues was $10.7 million for the nine months ended July 31, 2019. The adoption of Topic 606 resulted in a reduction of service and license margins of $1.9 million primarily due to the treatment of performance guarantees as variable consideration. The overall gross margin percentage was 41.4% for the nine months ended July 31, 2019 compared to a gross margin of 7.2% in the prior year period.

Generation revenues and related costs for the nine months ended July 31, 2019 and 2018 were as follows:

Revenues from generation for the nine months ended July 31, 2019 totaled $8.6 million which represents an increase of $3.2 million from revenue recognized of $5.3 million for the nine months ended July 31, 2018. Generation revenues for the nine months ended July 31, 2019 and 2018 reflect revenue from electricity generated under our PPAs. Revenues increased for the nine months ended July 31, 2019 compared to the prior year period due to additional revenue recorded for the Bridgeport Fuel Cell Project, which is now recognized under a PPA, partially offset by a decrease for maintenance activities causing a decrease in power output at a specific project asset. Cost of generation revenues totaled $9.0 million in the nine months ended July 31, 2019, which represents an increase of $4.0 million from $5.0 million for the nine months ended July 31, 2018. Cost of generation revenues included depreciation of approximately $4.7 million and $3.1 million for the nine months ended July 31, 2019 and 2018, respectively. We had 26.1 MW of operating power plants in our portfolio as of July 31, 2019, compared to 11.2 MW as of July 31, 2018. This increase is primarily a result of the acquisition of the Bridgeport Fuel Cell Project.

Advanced Technologies contract revenues and related costs for the nine months ended July 31, 2019 and 2018 were as follows:

Advanced Technologies contract revenues for the nine months ended July 31, 2019 were $15.3 million, which reflects an increase of $5.0 million when compared to $10.3 million of revenues for the nine months ended July 31, 2018. Advanced Technologies contract revenues were higher for the nine months ended July 31, 2019 primarily due to the timing of activity under existing contracts. Cost of Advanced Technologies contract revenues increased $0.6 million to $9.0 million for the nine months ended July 31, 2019, compared to $8.4 million for the same period in the prior year. Advanced Technologies contracts for the nine months ended July 31, 2019 generated a gross profit of $6.3 million compared to a gross profit of $1.8 million for the nine months ended July 31, 2018. The increase in Advanced Technologies contract gross margin is related to the timing and mix of contracts being performed during the nine months ended July 31, 2019.

Administrative and selling expenses were $23.6 million and $19.3 million for the nine months ended July 31, 2019 and 2018, respectively. The increase from the prior year period primarily relates to legal and consulting costs related to the Company’s restructuring and refinancing initiatives. Total legal and professional fees incurred in the nine months ended July 31, 2019 was $9.3 million compared to $4.0 million in the prior year period.

Research and development expenses decreased to $12.4 million for the nine months ended July 31, 2019 compared to $15.4 million during the nine months ended July 31, 2018. The decrease related to the reduction in spending resulting from the restructuring initiative and resources being allocated to funded Advanced Technologies projects.

Loss from operations for the nine months ended July 31, 2019 was $33.9 million compared to $32.8 million for the nine months ended July 31, 2018. The increase in the loss from operations was primarily a result of higher operating expenses for the nine months ended July 31, 2019 offset by higher margins primarily due to the revenue recorded for the EMRE License Agreement.

Interest expense for the nine months ended July 31, 2019 and 2018 was $7.8 million and $6.6 million, respectively. Interest expense for both periods presented includes interest on the loan and security agreement with Hercules, interest expense related to sale-leaseback transactions and interest for the amortization of the redeemable preferred stock of subsidiary fair value discount. The increase in interest expense represents additional interest on the loans made by Fifth Third and Liberty Bank in connection with the acquisition of the Bridgeport Fuel Cell Project and an end of term fee of $0.8 million that was recorded for the NRG Facility.

Other (expense) income, net, was expense of $0.6 million and income of $3.1 million for the nine months ended July 31, 2019 and 2018, respectively. The expense for the nine months ended July 31, 2019 includes expense of $0.4 million for the fair value adjustment of an interest rate swap. The income for the nine months ended July 31, 2018 includes foreign exchange gains related to the remeasurement of the Canadian Dollar denominated preferred stock obligation of our U.S. Dollar functional currency Canadian subsidiary, a foreign exchange gain realized on payments and unbilled receivable balances denominated in South Korean Won for the HYD contract, and income from refundable research and development tax credits.

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 South Korea. Income tax expense of $0.1 million was recorded for the nine months ended July 31, 2019 compared to an income tax benefit totaling $3.1 million for the nine months ended July 31, 2018. The income tax benefit for the nine months ended July 31, 2018 related to the Tax Cuts and Jobs Act (the “Act”) that was enacted on December 22, 2017. The Act reduced the U.S. federal corporate tax rate from 34% to 21% effective January 1, 2018, which resulted in a deferred tax benefit of $1.0 million related to a reduction of our deferred tax liability for an in process research and development (“IPR&D”) asset. The Act also established an unlimited carryforward period for the net operating loss (“NOL”) we generated in fiscal year 2018. This provision of the Act resulted in a reduction of the valuation allowance attributable to deferred tax assets at the enactment date by $2.0 million based on the indefinite life of the resulting NOL and the deferred tax liability for our IPR&D asset.

We recorded a charge to common stockholders for the difference between the fair value of the Series A Warrant prior to the modification of $0.3 million and the fair value of the common shares issuable at the date of the Exchange Agreement of $3.5 million.

Dividends recorded on our Series B Preferred Stock were $2.4 million for the nine month periods ended July 31, 2019 and 2018.

As discussed in more detail in Note 14. “Redeemable Preferred Stock” of the Notes to Consolidated Financial Statements, conversions during the nine months ended July 31, 2019 resulted in a net deemed contribution of $1.6 million. The deemed contributions represent the difference between the fair value of the common shares issued to settle the conversion amounts and the carrying value of the Series C Preferred Shares. Additionally, net loss to common stockholders was impacted by a $0.5 million deemed contribution resulting from accounting for the Waiver Agreement (as defined elsewhere herein) in February 2019 and the $8.6 million redemption value adjustment recorded during the three months ended January 31, 2019.

Conversions where the conversion price was below the initial conversion price (as adjusted for the reverse stock split) of $16.56 per share resulted in a variable number of shares being issued to settle the conversion amounts and are treated as a partial redemption of the Series D Preferred Shares. Conversions during the nine months ended July 31, 2019 that were settled in a variable number of shares and treated as redemptions resulted in deemed dividends of $6.0 million. The deemed dividends represent the difference between the fair value of the common shares issued to settle the conversion amounts and the carrying value of the Series D Preferred Shares.

The Series D Preferred Stock redemption accretion of $3.8 million for the three months ended January 31, 2019 reflects the accretion of the difference between the carrying value and the amount that would have been redeemed if stockholder approval had not been obtained for the issuance of common stock equal to 20% or more of our outstanding voting stock prior to the issuance of the Series D Preferred Stock. If we had been unable to obtain such stockholder approval and were therefore prohibited from issuing shares of common stock as a result of this limitation (the “Exchange Cap Shares”) to a holder of Series D Preferred Stock at any time after April 30, 2019, we would have been required to pay cash to such holder in exchange for the redemption of such number of Series D Preferred Shares held by such holder that would not have been convertible into such Exchange Cap Shares. Stockholder approval was obtained at the annual meeting of the Company’s stockholders on April 4, 2019 and no further accretion was required.

Net loss attributable to common stockholders represents the net loss for the period, the Series A Warrant exchange, the Series B preferred stock dividends, the Series C preferred stock deemed dividends and redemption value adjustment, net and the Series D Preferred Stock deemed dividends and redemption accretion. For the nine month periods ended July 31, 2019 and 2018, net loss attributable to common stockholders was $64.2 million and $44.2 million, respectively, and loss per common share was $2.97 and $6.70, respectively.

The Company has entered into a series of amendments to its senior secured debt facility with its senior lender Hercules in order to, among other things, provide for a lower minimum cash covenant, obtain a waiver of the minimum cash covenant during certain amendment periods, and avoid events of default and acceleration of amounts due under the loan agreement. Most recently, Hercules provided an amendment through September 30, 2019, which would extend to October 22, 2019 if the outstanding loan balance is less than or equal to $5.0 million on or before September 30, 2019. As of September 4, 2019, the outstanding principal balance under the Hercules facility totaled approximately $5.6 million. In exchange for these amendments, the Company has paid down the principal balance under the Hercules facility and agreed to make additional principal payments equal to 30% of the net proceeds of stock sales under the Company’s at-the-market sales agreement, as further described in Note 17. “Debt and Financing Obligation” and Note 20. “Subsequent Events”.

Management is working to address the Company’s current liquidity position through the exploration of various alternatives, including, but not limited to, refinancing the Company’s senior secured credit facility with Hercules; retaining existing project financing facilities and securing additional project financing facilities (including construction and term debt facilities and tax equity financing); potential sales of the Company’s assets, its intellectual property, or all or part of its business; potential licensing of certain of the Company’s technology and intellectual property; implementing cost reduction measures such as the reduction in force implemented in April; increasing sales activity related to the Company’s products; negotiating and entering into advanced technology research and development contracts; and sales of common stock or other equity securities directly to investors or through the Company’s at-the-market sales plan. Notwithstanding the Company’s efforts, the Company may not be able to refinance the Hercules credit facility on acceptable terms, or at all, retain existing project financing facilities or secure additional project financing facilities on acceptable terms, or at all, consummate any sale of its assets or all or part of its business, any sale or license of any of its intellectual property, or any sale of equity securities, implement further cost reduction measures, increase its sales activity, or successfully negotiate and enter into advanced technology contracts. Although the maturity date of the Hercules credit facility is April 1, 2020, the waiver by Hercules of certain covenants (including the minimum unrestricted cash covenant) expires by September 30, 2019 (or October 22, 2019 if the Hercules loan balance is less than or equal to $5.0 million on or before September 30, 2019). Accordingly, if the Company is not able to refinance the Hercules credit facility, and if Hercules is not willing to provide further accommodations, the Company may not meet certain covenant requirements and as a result may default on its obligations under its senior secured credit facility with Hercules. The occurrence of an event of default under the Hercules credit facility also constitutes or may result in an event of default under, and causes or may cause the acceleration of, a number of material financial obligations of the Company, including the loan from the State of Connecticut, the loan from Connecticut Green Bank, and the project finance facilities with Generate Lending, PNC Energy Capital, LLC (“PNC”), and Fifth Third. The occurrence of an event of default under the Hercules credit facility also constitutes a triggering event under the Certificate of Designations, Preferences and Rights of the Series D Convertible Preferred Stock of the Company.

towards the completion of the construction of the 2.8 MW Tulare BioMAT project in California. If the Company is unable to make sufficient progress toward the completion of such project or to obtain another amendment, extension or refinancing, the Company may default on the NRG loan. The occurrence of an event of default under the NRG loan agreement may result in the principal and all accrued interest becoming immediately due and payable.

Cash and cash equivalents including restricted cash totaled $45.8 million as of July 31, 2019 compared to $80.2 million as of October 31, 2018.

On June 13, 2018, the Company entered into the Sales Agreement with the Agents to create an at the market equity program under which the Company from time to time may offer and sell shares of its common stock having an aggregate offering price of up to $50.0 million through the Agents. Under the Sales Agreement, the Agent making the sales will be entitled to a commission in an amount equal to 3.0% of the gross proceeds from such sales. During the three and nine months ended July 31, 2019, the Company sold approximately 44.0 million shares under the Sales Agreement at an average sale price of $0.38 per share and raised aggregate gross proceeds of approximately $16.7 million before deducting expenses and commissions. Commissions of $0.5 million were paid to the Agent making the sales during the three and nine months ended July 31, 2019, resulting in net proceeds of approximately $16.2 million. In addition, after July 31, 2019 (the end of the quarter), the Company sold approximately 7.5 million shares under the Sales Agreement at an average sale price of $0.31 per share and raised aggregate gross proceeds of approximately $2.4 million before deducting expenses and commissions. Commissions of $0.07 million were paid to the Agent making the sales after July 31, 2019, resulting in net proceeds of approximately $2.3 million. As the Company had sold an aggregate of approximately $27.1 million of common stock under the Sales Agreement as of September 4, 2019, the Company may sell up to approximately $22.9 million of common stock in the future under the Sales Agreement, subject to contractual requirements, trading windows and market conditions.

The Company also has an effective shelf registration statement on file with the SEC for issuance of additional equity and debt securities.

Our future liquidity will be dependent on obtaining a combination of increased order and contract volumes, increased cash flows from our generation and service portfolios, cost reductions necessary to achieve profitable operations, debt and equity from the capital markets, and additional sources of outside financing. To grow our generation portfolio, we will invest in developing and building turn-key fuel cell projects which we will own and classify as project assets on the balance sheet. This strategy requires liquidity, and we expect to have increasing liquidity requirements to the extent that project sizes and the number of projects increase. 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 plant, 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 up-front investments of resources in advance of the receipt of any cash from the sale or long-term financing of such projects. These up-front investments may include using our working capital, availability under our construction

financing facilities or other financing arrangements. Delays in construction progress, in completing financing, in obtaining new financing, or the sale of our projects may impact our liquidity in a material way.

Our operating portfolio (26.1 MW as of July 31, 2019) contributes higher long-term cash flows to us than if these projects had been sold. These projects currently generate approximately $22 million per year in annual revenue depending on plant output and site conditions. We plan to continue to grow this portfolio while also selling certain projects to investors. As of July 31, 2019, we had projects representing an additional 52.1 MW under development and construction, which projects are expected to generate operating cash flows in future periods. These totals do not include the 32.4 MW Long Island Power Authority (“LIPA”) project awards, which are not yet in backlog. Including the LIPA awards, the projects in process totaled 84.5 MW as of July 31, 2019. We expect these projects in process, including the LIPA awards, to generate an additional $70 - $80 million of annual recurring revenue if and when they become operational. 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. We have worked with and are continuing to work with lenders and financial institutions to secure long-term debt and sale-leasebacks for our project asset portfolio as well as for construction period financing. The Company does not currently have committed financing for this portfolio. There can be no assurance that such financing can be attained. As of July 31, 2019, we have financed four projects through sale-leaseback transactions. As of July 31, 2019, total financing obligations and debt outstanding related to project assets was $102.0 million. Future required payments total $86.4 million as of July 31, 2019. The outstanding financing obligation under the sale-leaseback transactions includes an embedded gain, which will be recognized at the end of the lease term.

Our operating portfolio provides us with the full benefit of future cash flows, net of any debt service requirements.

In May 2019, we closed on the acquisition of the 14.9 MW Bridgeport Fuel Cell Project in Bridgeport, Connecticut from Dominion Generation, Inc. We own and operate the Bridgeport Fuel Cell Project as part of our generation portfolio, which is included in the table above. The Bridgeport Fuel Cell Project is expected to produce annual revenue in excess of $15 million per year and is expected to deliver EBITDA margins in excess of 50%. The total cash consideration paid was $35.5 million. We funded the acquisition with a combination of third party financing and $15 million of restricted cash on hand that was tied to the project and released at closing. Liberty Bank and Fifth Third jointly provided the senior project-level debt facility of $25 million, while the Connecticut Green Bank provided additional subordinated capital. The PPA term runs through December 2028.

The following table summarizes projects in process, including those in backlog and awards, as of July 31, 2019:

* Projects are “awards” and not in contracted backlog. Refer to additional disclosure below.

We had contract backlog totaling approximately $1.4 billion as of July 31, 2019. We also had project awards with respect to 32.4 MW of LIPA projects totaling an additional $636.3 million, resulting in total backlog and awards of approximately $2.1 billion as of July 31, 2019.

Backlog represents definitive agreements executed by us and our customers. Projects for which we have a PPA are included in generation backlog, which represents future revenue under long-term PPAs. Projects sold to customers (and not retained by us) are included in product sales and service backlog and the related generation backlog is removed upon the sale. Project awards referenced by us are notifications that we have been selected, typically through a competitive bidding process, to enter into definitive agreements. These awards have been publicly disclosed but are still subject to negotiation and execution with the off-taker and are not yet definitive. We are working to enter into definitive agreements with respect to these project awards and, upon execution of a definitive agreement with respect to a project award, that project award will become backlog. Project awards that were not included in backlog as of July 31, 2019 include the 32.4 MW LIPA project awards (which are expected to become generation backlog). These awards in total represent approximately $636.3 million of future revenue potential over the life of the projects, assuming we retain ownership of the projects. If we were to sell such projects, the backlog amount would be decreased (in an amount determined by the negotiated sales price at the time of sale) and would consist of product sales to be recognized over a one to two-year period and service revenue to be recognized over a twenty-year term.

Cash and cash equivalents and restricted cash and cash equivalents totaled $45.8 million as of July 31, 2019 compared to $80.2 million as of October 31, 2018. As of July 31, 2019, restricted cash and cash equivalents was $29.8 million, of which $1.4 million was classified as current and $28.4 million was classified as non-current, compared to $40.9 million total restricted cash and cash equivalents as of October 31, 2018, of which $5.8 million was classified as current and $35.1 million was classified as non-current.

Operating Activities – Net cash used in operating activities was $18.3 million during the nine months ended July 31, 2019, compared to $29.3 million of net cash provided by operating activities during the nine months ended July 31, 2018.

Net cash used in operating activities for the nine months ended July 31, 2019 was primarily the result of the net loss of $42.4 million and increases in inventory of $8.4 million and unbilled receivables of $5.6 million, offset by increases in accounts payable of $9.4 million, deferred revenue of $3.7 million and a decrease in accounts receivable of $4.3 million and net non-cash adjustments of $19.5 million.

Net cash provided by operating activities for the nine months ended July 31, 2018 was primarily the result of decreases in accounts receivable of $33.1 million and inventories of $22.1 million, increases in accounts payable of $3.6 million and deferred revenue of $0.1 million and net non-cash adjustments of $10.7 million. Accounts receivable and inventory decreased primarily as a result of cash received and inventory delivered under the HYD contract. The amounts were offset by the net loss of $33.2 million for the nine months ended July 31, 2018, a decrease in accrued liabilities of $4.5 million, and an increase in other assets of $2.5 million.

Investing Activities – Net cash used in investing activities was $59.3 million for the nine months ended July 31, 2019, compared to net cash used in investing activities of $36.0 million during the nine months ended July 31, 2018.

Net cash used in investing activities for the nine months ended July 31, 2019 included the purchase of all the outstanding membership interests in Bridgeport Fuel Cell, LLC (“BFC”) for $35.5 million, a $21.9 million investment in project assets to expand our operating portfolio and $1.9 million for capital expenditures.

Net cash used in investing activities for the nine months ended July 31, 2018 included a $28.4 million investment in project assets to expand our operating portfolio and $7.6 million for capital expenditures.

Financing Activities – Net cash provided by financing activities was $43.2 million during the nine months ended July 31, 2019, compared to net cash provided by financing activities of $6.5 million during the nine months ended July 31, 2018.

Net cash provided by financing activities during the nine months ended July 31, 2019 resulted from the receipt of $55.1 million of debt proceeds, which included $26.7 million of loans from various lenders used for the purchase of all of the outstanding membership interests in BFC, $11.1 million from Fifth Third, $10.0 million from Generate Lending, $5.8 million from NRG, and $1.5 million under the Enhanced Capital Loan Agreement (as defined below) offset by debt repayment of $23.0 million, the payment of deferred financing costs of $2.5 million and the payment of preferred dividends and return of capital of $1.8 million.

Net cash provided by financing activities during the nine months ended July 31, 2018 included the receipt of $13.1 million under the amended Hercules loan and security agreement and net proceeds of $10.0 million from warrant exercises and sales of our common stock under the Sales Agreement offset by cash payments of $13.1 million primarily relating to repayments under the Hercules loan and the payment of preferred dividends and the return of capital of $3.1 million.

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 development and, as a result, we are not consistently 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 and issuances of corporate and project debt and monetization of technology through licenses. During the second quarter of fiscal year 2019, we implemented a series of restructuring activities aimed at reducing operating costs and streamlining operations while targeting cash generation and long-term financial stability.

A summary of our significant commitments and contractual obligations as of July 31, 2019 and the related payments by fiscal year are as follows:

Webster Bank Loan. In November 2016, our wholly-owned subsidiary, FuelCell Finance, entered into a membership interest purchase agreement with GW Power LLC (“GWP”) whereby FuelCell Finance purchased all of the outstanding membership interests in New Britain Renewable Energy, LLC (“NBRE”) from GWP. GWP assigned the NBRE interest to FuelCell Finance free and clear of all liens other than a pledge in favor of Webster Bank, National Association (“Webster Bank”). FuelCell Finance assumed the debt outstanding with Webster Bank in the amount of $2.3 million. The term loan interest rate is 5.0% per annum and payments due on a quarterly basis commenced in January 2017. The balance outstanding as of July 31, 2019 was $0.6 million.

Hercules Loan. In April 2016, the Company entered into a loan and security agreement (as amended from time to time, the “Hercules Agreement”) with Hercules for an aggregate principal amount of up to $25.0 million, subject to certain terms and conditions. The loan was a 30 month secured facility.

On June 11, 2019, the Company and Hercules entered into the ninth amendment to the Hercules Agreement (the “Ninth Hercules Amendment”). Under the Ninth Hercules Amendment, the Company agreed, among other things, to: (a) no later than June 11, 2019, pay Hercules $1.4 million to be applied towards the outstanding balance of the loan; (b) no later than June 26, 2019, direct EMRE to pay Hercules $6.0 million of the $10.0 million payable under the EMRE License Agreement to be applied towards the outstanding balance of the loan; and (c) on each of July 1, 2019 and August 1, 2019, pay Hercules interest-only payments on the outstanding principal balance of the loan. In the Ninth Hercules Amendment, the term “Amendment Period” is defined as the period from and after June 11, 2019 through the earlier of (i) August 9, 2019 and (ii) the occurrence of any event of default under the Ninth Hercules Amendment. The Hercules Agreement was further modified by the Tenth Hercules Amendment described below.

On July 24, 2019, the Company and Hercules entered into the tenth amendment to the Hercules Agreement (the “Tenth Hercules Amendment”). In the Tenth Hercules Amendment, the “Amendment Period” is defined as the period from and after July 24, 2019 through the earlier of (i) September 30, 2019 and (ii) the occurrence of any event of default under the Tenth Hercules Amendment; provided, however, that in the event that the outstanding balance of the secured obligations (including accrued interest, fees, costs, and charges) has been paid down to an amount that is less than or equal to $5.0 million on or before September 30, 2019, the Amendment Period shall be extended automatically through the earlier of (i) October 22, 2019 and (ii) the occurrence of any event of default under the Tenth Hercules Amendment.

Under the Tenth Hercules Amendment, the Company has agreed, among other things, to: (a) no later than July 25, 2019, pay Hercules $4.0 million to be applied towards the outstanding balance of the loan; (b) from and after June 24, 2019 through the end of the Amendment Period under the Tenth Hercules Amendment, pay Hercules, on the third trading day of each week (each, an “ATM Payment Date”) following a week in which the Company issues shares of its common stock under the Sales Agreement or any similar or replacement agreement (each such week, an “ATM Issuance Period”), an amount equal to 30% of the net proceeds, after deducting commissions and any offering-related expenses, of such issuances (“Net ATM Proceeds”), if any, received in cash by the Company from such issuances, if any, during the ATM Issuance Period completed immediately prior to such ATM Payment Date, which amount shall be applied towards the outstanding balance of the loan; and (c) pay to Hercules an interest-only payment on the outstanding principal balance of the loan at the term loan interest rate, which payment shall be due and payable on September 1, 2019; provided, however, that in the event the Amendment Period under the Tenth Hercules Amendment is extended to October 22, 2019 (as described

above), the Company shall pay to Hercules an interest and amortization payment on the outstanding principal balance of the secured obligations at the term loan interest rate, which payment shall be due and payable on October 1, 2019. The Company has further agreed that interest at the default rate (which is an additional 5% per annum against outstanding obligations), which has been accruing from June 3, 2019, will continue to accrue and be due and payable, subject to the terms of the Tenth Hercules Amendment; provided, however, that in the event that all of the secured obligations are paid in full on or prior to the last day of the Amendment Period under the Tenth Hercules Amendment (as such may be extended as described above), Hercules will fully and unconditionally waive its right to payment of accrued and unpaid default interest. The accrued and unpaid default interest totaled $0.1 million as of July 31, 2019. The total outstanding balance under the Hercules Agreement as of July 31, 2019 was $7.4 million.

In addition, Hercules has waived the Company’s compliance with certain financial reporting covenants and the minimum unrestricted cash balance covenant set forth in the Hercules Agreement, in each case from June 11, 2019 through the end of the Amendment Period under the Tenth Hercules Amendment.

State of Connecticut Loan. In November 2015, the Company entered into a definitive Assistance Agreement with the State of Connecticut 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 percent, repayable over 15 years. Principal payments were deferred for four years from disbursement and begin on December 1, 2019. Under the Assistance Agreement, the Company was eligible for forgiveness of up to 50 percent of the loan principal 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 extends the Target Date to October 31, 2022 and amends the Employment Obligation to require the Company to maintain 538 full-time positions for 24 consecutive months. If the Company meets the Employment Obligation, as modified by the Second Amendment, and creates an additional 91 full-time positions, the Company may receive a credit in the amount of $2.0 million to be applied against the outstanding balance of the loan. The Second Amendment deletes and cancels the provisions of the Assistance Agreement related to the second phase of the expansion project and the loans related thereto, but the Company had not drawn any funds or received any disbursements under those provisions. A job audit will be performed within ninety days of the Target Date. If the Company does not meet the Employment Obligation, then a penalty shall be assessed at a rate of $18,587.36 times the number of employees below the Employment Obligation. Such penalty, which accelerates the payment, is immediately payable and will be first applied against any outstanding fees or interest due and then against outstanding principal.

NRG Loan. In July 2014, the Company, through its wholly-owned subsidiary, FuelCell Finance, entered into the NRG Loan Agreement. Pursuant to the NRG Loan Agreement, NRG extended a $40.0 million loan facility to FuelCell Finance for the purpose of accelerating project development by the Company and its subsidiaries. Under the NRG Loan Agreement, FuelCell Finance and its subsidiaries were permitted to draw on the loan facility to finance the construction of projects through the commercial operating date of the power plants. Additionally, FuelCell Finance had the option to continue the financing term for each project after the commercial operating date for a minimum term of five years per project. The interest rate is 8.5% per annum for construction-period financing and 8.0% per annum thereafter.

On December 13, 2018, FuelCell Finance’s wholly owned subsidiary, Central CA Fuel Cell 2, LLC, drew a construction loan advance of $5.8 million under the NRG loan facility. This advance was used to support the completion of construction of the 2.8 MW Tulare BioMAT project in California. In conjunction with the December 13, 2018 draw, FuelCell Finance and NRG entered into an amendment to the NRG Loan Agreement to revise the definitions of the terms “Maturity Date” and “Project Draw Period” under the NRG Loan Agreement and to make other related revisions. Pursuant to this amendment, FuelCell Finance and its subsidiaries could only request draws through December 31, 2018 and the Maturity Date of each note was the earlier of (a) March 31, 2019 and (b) the commercial operation date or substantial completion date, as applicable, with respect to the fuel cell project owned by the borrower under such note. As of July 31, 2019, there have been no other drawdowns under the NRG loan facility.

Prior to July 31, 2019, the Maturity Date was subsequently extended through amendments to the NRG Loan Agreement on March 29, 2019 (the “third amendment”), June 13, 2019 and July 11, 2019 (the “fifth amendment”). In connection with the third amendment, the Company agreed to make an additional payment of $750,000 at the Maturity Date, which is recorded in interest expense on the Consolidated Statement of Operations. In addition, the fifth amendment, which was in effect as of the end of the quarter, extended the Maturity Date of each note to the earlier of (a) August 9, 2019, (b) the commercial operation date or substantial completion date, as applicable, with respect to the fuel cell project owned by Central CA Fuel Cell 2, LLC, and (c) closing of a refinancing of indebtedness; provided, however, in the event NRG determines, in its sole discretion, that the Company is not making sufficient progress toward the completion of the construction of the 2.8 MW Tulare BioMAT project in California, including but not limited to delivery of a mutually agreed plan of completion by no later than July 19, 2019, NRG may accelerate the Maturity Date on the date of such determination.

On August 8, 2019, FuelCell Finance, Central CA Fuel Cell 2, LLC, and NRG entered into the sixth amendment to the NRG Loan Agreement, which amends the definition of “Maturity Date” under the NRG Loan Agreement. Pursuant to the sixth amendment, the Maturity Date of each note is now the date that is the earliest of (a) September 30, 2019, (b) the commercial operation date or substantial completion date, as applicable, with respect to the fuel cell project owned by the co-borrower under such note, and (c) the repayment in full or the closing of a refinancing of the Company’s indebtedness with Hercules; provided, however, in the event NRG determines, in its sole discretion, that FuelCell Finance and Central CA Fuel Cell 2, LLC are not making sufficient progress toward the completion of the construction of the 2.8 MW Tulare BioMAT project in California, NRG may accelerate the Maturity Date on the date of such determination. In conjunction with the sixth amendment, Central CA Fuel Cell 2, LLC prepaid interest (which would otherwise be paid at maturity) that had been accrued through the date of the sixth amendment totaling approximately $0.3 million.

Connecticut Green Bank Loans. As of July 31, 2019, we had a long-term loan agreement with the Connecticut Green Bank, providing a total of $5.9 million in support of the Bridgeport Fuel Cell Project. During the three months ended July 31, 2019, this loan was partially repaid with a new project level loan from Connecticut Green Bank in connection with the Company’s acquisition of all of the membership interests in BFC. The balance as of July 31, 2019 was $1.8 million.

On May 9, 2019, in connection with the closing of the purchase of BFC, BFC 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”). 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 (as described below). 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. The Subordinated Credit Agreement contains customary representations, warranties and covenants. The balance under the Subordinated Credit Agreement as of July 31, 2019 was $5.9 million.

Enhanced Capital Loan. On January 9, 2019, we, through our indirect wholly-owned subsidiary TRS Fuel Cell, LLC, entered into a Loan and Security Agreement (the “Enhanced Capital Loan Agreement”) with Enhanced Capital Connecticut Fund V LLC in the amount of $1.5 million. Interest will accrue at a rate of 6.0% per annum, calculated on a 30/360 basis, on all outstanding principal, paid on the first business day of each month. The loan maturity date is three years from the date of the Enhanced Capital Loan Agreement upon which the outstanding principal and accrued interest will be payable.

Fifth Third Bank Groton Loan. On February 28, 2019, the Groton Borrower entered into the Groton Agreement with Fifth Third pursuant to which Fifth Third agreed to make available to Groton Borrower a construction loan facility in an aggregate principal amount of up to $23.0 million to fund the manufacture, construction, installation, commissioning and start-up of the Groton Project. Groton Borrower made an initial draw under this facility on the date of closing of $9.7 million and made an additional draw of $1.4 million in April 2019.

On August 13, 2019, Groton Borrower and Fifth Third entered into Amendment No. 1 to the Groton Agreement (the “Groton Amendment”). Under the Groton Amendment, the definition of “Commitment” was amended to reduce the aggregate principal amount of the facility available to Groton Borrower from $23.0 million to $18.0 million. Pursuant to the Groton Amendment, Groton Borrower has agreed to (i) no later than August 16, 2019, deliver executed bailee letters for certain collateral, (ii) no later than August 21, 2019, provide Fifth Third with a plan to fund the remaining project costs needed to complete the construction of the Groton Project, (iii) complete the conditioning of the first of the remaining two fuel cells units for the Groton Project no later than September 19, 2019 and the final fuel cell unit for the Groton Project by October 25, 2019, and (iv) no later than September 28, 2019, deliver to Fifth Third a binding loan agreement for permanent financing and one or more binding letters of intent from tax equity investors, such date to be automatically extended to October 21, 2019 in the event that the Company’s credit facility with Hercules is repaid or extended beyond October 21, 2019; and further provided that such dates shall be extended by an additional 60 days due to delays outside of control of Groton Borrower or if Fifth Third is reasonably satisfied that Groton Borrower is negotiating diligently and in good faith with potential take-out lenders or tax equity investors.

Bridgeport Loans. On May 9, 2019, in connection with the purchase of the membership interests of BFC, FuelCell Finance entered into a Credit Agreement with Liberty Bank, as administrative agent and co-lead arranger, and Fifth Third, as co-lead arranger and swap hedger (the “BFC Credit Agreement”), whereby (i) Fifth Third provided financing to BFC in the amount of $12.5 million towards the purchase price for the BFC acquisition; and (ii) Liberty Bank provided financing to BFC 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 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 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 Finance’s ownership interest in BFC.

BFC has the right to make additional principal payments or pay the balance due under the 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 maturity date is May 9, 2025. The interest rate under the BFC Credit Agreement fluctuates monthly at the 30-day LIBOR rate plus 275 basis points on a total notional value of $25.0 million. An interest rate swap agreement was required to be entered into with Fifth Third in connection with the BFC Credit Agreement to protect against movements in the floating LIBOR index. Accordingly, on May 16, 2019, BFC entered into the 1992 ISDA Master Agreement, along with the Schedule to such Agreement, with Fifth Third, and executed the related trade confirmations on May 17, 2019. The net interest rate across the BFC Credit Agreement and the swap transaction totals a fixed rate of 5.09%.

The obligations of BFC to Fifth Third under the swap agreement are treated as obligations under the BFC Credit Agreement and, accordingly, are secured by the same collateral securing the obligations of BFC under the BFC Credit Agreement.

The BFC Credit Agreement also requires BFC to maintain a debt service reserve at each of Liberty Bank and Fifth Third of $1.25 million, which debt service reserves were funded on May 10, 2019, to be held in deposit accounts at each respective bank, with funds to be disbursed with the consent of or at the request of the required lenders in their sole discretion. Each of Liberty Bank and Fifth Third also has an operation and module replacement reserve (“O&M Reserve”) of $250.0 thousand, both of which were funded at closing, to be held in deposit accounts at each respective bank, and thereafter BFC is required to deposit $100.0 thousand 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, as applicable. BFC is also required to maintain excess cash flow reserve accounts at each of Liberty Bank and Fifth Third and to deposit 50% of the excess cash flows from the Bridgeport Fuel Cell Project into these accounts. Excess cash flow consists of cash generated by BFC from the Bridgeport Fuel Cell Project after payment of all expenses (including after payment of service fees to the Company), debt service to Liberty Bank and Fifth Third, 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 annually based on fiscal quarters beginning with the quarter ended July 31, 2020. The BFC Credit Agreement contains customary representations, warranties and covenants and includes a material adverse effect clause related to the operations, business, properties, liabilities or prospects of Bridgeport Fuel Cell, LLC.

In addition to the commitments listed in the table under the heading “Commitments and Significant Contractual Obligations,” we have the following outstanding obligations:

We have pledged approximately $29.8 million of our cash and cash equivalents as performance security and for letters of credit for certain banking requirements and contracts. As of July 31, 2019, outstanding letters of credit totaled $5.2 million. These expire on various dates through August 2028. Under the terms of certain contracts, we will provide performance security for future contractual obligations. The restricted cash balance as of July 31, 2019 also included $17.8 million primarily to support obligations under the power purchase and service agreements related to the PNC sale-leaseback transactions and $6.9 million relating to future obligations associated with the Bridgeport Fuel Cell Project.

As of October 31, 2018, we had uncertain tax positions aggregating $15.7 million and have reduced our NOL carryforwards by this amount. Because of the level of NOLs and valuation allowances, unrecognized tax benefits, even if not resolved in our favor, would not result in any cash payment or obligation and therefore have not been included in the contractual obligation table under the heading “Commitments and Significant Contractual Obligations.”

Under the terms of our PPAs, customers agree to purchase power from our fuel cell power plants 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. Under certain agreements, we are also responsible for procuring fuel, generally natural gas or biogas, to run our fuel cell power plants. 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 July 31, 2019, our PPA operating portfolio was 26.1 MW.

We warranty our products for a specific period of time against manufacturing or performance defects. Our standard U.S. warranty period is generally fifteen months after shipment or twelve 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 twenty 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.

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 often provided incrementally on a year-by-year basis if contract terms are met and Congress authorizes the funds. As of July 31, 2019, Advanced Technologies contracts backlog totaled $27.2 million, of which $15.8 million is funded and $11.4 million is unfunded. Should funding be terminated or delayed or if business initiatives change, we may choose to devote resources to other activities, including internally funded research and development.

We have no off-balance sheet debt or similar obligations, other than operating leases, which are not classified as debt. We do not guarantee any third-party debt. See Note 19. “Commitments and Contingencies” to our consolidated financial statements for the nine months ended July 31, 2019 included in this Quarterly Report on Form 10-Q for further information.

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 liabilities. Actual results could differ from those estimates. Estimates are used in accounting for, among other things, revenue recognition, 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), income taxes, contingencies and valuing assets acquired and pre-existing contractual arrangements settled in the acquisition of Bridgeport Fuel Cell, LLC. 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.

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, 2018 filed with the Securities and Exchange Commission.

Effective November 1, 2018, we adopted Topic 606. See “Note 3 – Revenue Recognition” included in our Notes to Consolidated Financial Statements for changes to our critical accounting policies as a result of adopting Topic 606. Other than changes to our revenue recognition policy as a result of adopting Topic 606, there have been no significant changes to the critical accounting policies disclosed in “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in our 2018 Annual Report on Form 10-K.

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, as well as recent accounting guidance that is not yet effective.

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. The Company has an interest rate swap that will be marked-to-market on a quarterly basis. The mark-to-market adjustment is based on Level 2 inputs including primarily the forward LIBOR curve available to swap dealers. The mark-to-market methodology involves comparison of (i) the sum of the present value of all monthly variable rate payments during the term at the notional amount of the loan outstanding based on a reset rate using the forward LIBOR curve and (ii) the sum of the present value of all monthly fixed rate payments during the term of the loan at the notional amount which is equivalent to the outstanding principal. Based on our overall interest rate exposure as of July 31, 2019, including all interest rate sensitive instruments, a change in interest rates of 1% would not have a material impact on our results of operations.

As of July 31, 2019, approximately 1% of our total cash and cash equivalents were in currencies other than U.S. dollars (primarily the Euro, Canadian dollar and South Korean Won) and we have no plans of repatriation. The Company had sales and accounts receivable denominated in foreign currencies and had outstanding accounts receivable denominated in foreign currencies as of July 31, 2019. We make purchases from certain vendors 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.

The conversion feature and the variable dividend obligation of FCE FuelCell Energy Ltd.’s (“FCE Ltd.”) Class A Cumulative Redeemable Exchangeable Preferred Shares (“Series 1 Preferred Shares”) are embedded derivatives that require bifurcation from the host contract. The aggregate fair value of these derivatives included within long-term debt and other liabilities as of July 31, 2019 and October 31, 2018 was $0.9 million and $0.8 million, respectively. The fair value was based on valuation models using various assumptions, including historical stock price volatility, risk-free interest rate and a credit spread based on the yield indexes of technology high yield bonds, foreign exchange volatility as the Series 1 Preferred Shares are denominated in Canadian dollars, and the closing price of our common stock. Changes in any of these assumptions would change the underlying fair value with a corresponding charge or credit to operations.

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 due to the material weakness described below, the Company’s disclosure controls and procedures were ineffective 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.

Notwithstanding the material weakness described below, management has concluded that our consolidated financial statements included in this Form 10-Q for the quarter ended July 31, 2019 are fairly stated in all material respects in accordance with generally accepted accounting principles in the United States of America for each of the periods presented and that they may be relied upon.

Previously identified material weakness in internal control over financial reporting

A material weakness is a deficiency, or combination of deficiencies, in internal control over financial reporting, such that there is a reasonable possibility that a material misstatement of our annual or interim financial statements will not be prevented or detected on a timely basis.

We previously disclosed in our Form 10-Q for the quarter ended April 30, 2019 that the Company did not have resources to sufficiently address asset impairments on a timely basis as a result of the Company’s reorganization activities or the accounting considerations and disclosures related to the Company’s amended credit facilities. As a result, we concluded that there was a material weakness in internal control over financial reporting, as we did not maintain effective controls over the accounting for and disclosures in the consolidated financial statements related to asset impairments and credit facilities. This control deficiency partially led to the delayed filing of our Form 10-Q for the quarter ended April 30, 2019 to properly reflect adjustments and disclosures in our financial statements for the quarter ended April 30, 2019.

Subsequent to the evaluation made in connection with filing our Form 10-Q for the three and six months ended April 30, 2019, our management, with the oversight of the Audit and Finance Committee of the Board of Directors, began the process of remediating the material weakness which continued to exist as of July 31, 2019 as the Company did not have resources to sufficiently address the accounting for non-routine transactions. Progress to date includes engagement of a third party resource to help evaluate the accounting and disclosure for significant transactions each quarter. Management also plans to also add additional experienced accounting staff. In addition, under the oversight of the Audit and Finance Committee, management will continue to review and make necessary changes to the overall design of our internal control environment to improve the overall effectiveness of internal control over financial reporting.

We have made progress in accordance with our remediation plan. However, the material weakness will not be considered remediated until the applicable controls operate for a sufficient period of time and management has concluded, through testing, that these controls are operating effectively. We are committed to continuing to improve our internal control processes and will continue to review, optimize and enhance our financial reporting controls and procedures, however, there can be no assurance that this will occur within 2019.

We are involved in legal proceedings, claims and litigation arising out of the ordinary conduct of our business. Although we cannot assure the outcome, management presently believes that the result of such legal proceedings, either individually, or in the aggregate, will not have a material adverse effect on our consolidated financial statements, and no material amounts have been accrued in our consolidated financial statements with respect to these matters.

You should carefully consider the following risk factors before making an investment decision. If any of the following risks actually occur, our business, financial condition, or results of operations could be materially and adversely affected. In such cases, the trading price of our common stock could decline, and you may lose all or part of your investment.

We have transitioned from a research and development company to a commercial products manufacturer, services provider and developer. We have not been profitable since our year ended October 31, 1997. We expect to continue to incur net losses and generate negative cash flows until we can produce sufficient revenues and margins to cover our costs. We may never become profitable. Even if we do achieve profitability, we may be unable to sustain or increase our profitability in the future. For the reasons discussed in more detail below, there are uncertainties associated with our achieving and sustaining profitability. We have, from time to time, sought financing in the public markets in order to fund operations and will continue to do so. Our future ability to obtain such financing could be impaired by a variety of factors, including, but not limited to, the price of our common stock and general market conditions.

There is uncertainty surrounding our ability to refinance our current senior secured credit facility and uncertainty as to whether we will have sufficient liquidity to fund our business activities. Substantial doubt exists as to our ability to continue as a going concern. Our plans to address our liquidity position may not be successful, and we may be forced to limit our business activities or be unable to continue as a going concern, or may have to seek bankruptcy protection, which would have a material adverse effect on our results of operations and financial condition.

The consolidated financial statements included herein have been prepared assuming we will continue as a going concern. Our ability to continue as a going concern is dependent on generating profitable operating results, having sufficient liquidity, and maintaining compliance with the covenants and other requirements under the Hercules Agreement, refinancing, extending the maturity of the Hercules Agreement, or repaying the indebtedness outstanding under the Hercules Agreement by no later than September 30, 2019 to avoid acceleration and default, provided that, in the event that the outstanding balance of the secured obligations (including interest, fees, costs and charges) under the Hercules Agreement has been paid down to an amount that is less than or equal to $5.0 million on or before September 30, 2019, the repayment date will be automatically extended to October 22, 2019. The Company also has a loan agreement with NRG that has a maturity date of September 30, 2019 and Generate Lending has a call right under the Generate Facility which, if exercised, will require repayment by September 30, 2019. We plan to continue to pursue project financing for our generation backlog. If we are unable to obtain such project financing, we may have events of default under our project finance agreements and our power purchase agreements with customers. In addition, we need to obtain additional working capital to fund our obligations and operations either through a refinancing or other means. There can be no assurance that we will be able to effect a refinancing or obtain project financing on acceptable terms or repay outstanding indebtedness and obtain additional liquidity. If we do not have sufficient liquidity to fund our business activities, we may not be able to sustain future operations. As a result, we may be required to delay, reduce and/or cease our operations and/or seek bankruptcy protection.

Our cost reduction strategy may not succeed or may be significantly delayed, which may result in our inability to deliver improved margins.

Our cost reduction strategy is based on the assumption that increases in production will result in economies of scale. In addition, our cost reduction strategy relies on advancements in our manufacturing process, global competitive sourcing, engineering design, reducing the cost of capital and technology improvements (including stack life and projected power output). Failure to achieve our cost reduction targets could have a material adverse effect on our results of operations and financial condition.

Our workforce reduction may cause undesirable consequences and our results of operations may be harmed.

On April 12, 2019, we undertook a reorganization, which included a workforce reduction of 30%, or 135 employees. This workforce reduction may yield unintended consequences, such as attrition beyond our intended reduction in workforce and reduced employee morale, which may cause our employees who were not affected by the reduction in workforce to seek alternate employment. Additional attrition could impede our ability to meet our operational goals, which could have a material adverse effect on our financial performance. In addition, as a result of the reductions in our workforce, we may face an increased risk of employment litigation. Furthermore, employees whose positions were eliminated or those who determine to seek alternate employment may seek employment with our competitors. Although all our employees are required to sign a confidentiality agreement with us at the time of hire, we cannot assure

you that the confidential nature of our proprietary information will be maintained in the course of such future employment. We cannot assure you that we will not undertake additional reduction activities, that any of our efforts will be successful, or that we will be able to realize the cost savings and other anticipated benefits from our previous or any future reduction plans. In addition, if we continue to reduce our workforce, it may adversely impact our ability to respond rapidly to any new product, growth or revenue opportunities and to execute on our backlog and business plans.

We have debt outstanding and may incur additional debt in the future, which may adversely affect our financial condition and future financial results.

Our total consolidated indebtedness was $121.2 million as of July 31, 2019. This includes approximately $102.0 million of debt at our project finance subsidiaries and $19.2 million of debt at the corporate level. The majority of our debt is long-term with $43.4 million due within twelve months of July 31, 2019. Prior to April 30, 2019, we had approximately $40 million of borrowing capacity under a revolving construction and term project financing facility with NRG under which we drew down approximately $5.8 million in December 2018, which must be repaid by the earliest of (i) the commercial operation date of our 2.8 MW Tulare BioMAT project in California, (ii) September 30, 2019 or (iii) the repayment in full or the closing of a refinancing of the Company’s indebtedness with Hercules. Pursuant to the agreement entered into in conjunction with the December 2018 draw, no further draws on the NRG facility are permitted and the facility expired on March 31, 2019. On December 21, 2018, we entered into a $100 million construction loan agreement with Generate Lending and made an initial draw of $10 million. The Generate loan agreement has a call right that may require repayment by September 30, 2019. On February 28, 2019, we entered into a Construction Loan Agreement with Fifth Third to fund the manufacture, construction, installation, commissioning and start-up of the 7.4 MW fuel cell power plant for the Connecticut Municipal Electric Energy Cooperative located on the U.S. Navy submarine base in Groton, Connecticut. We made an initial draw under this Fifth Third facility on the date of closing of $9.7 million and made an additional draw of $1.4 million in April 2019. The total outstanding balance under this facility as of July 31, 2019 was $11.1 million. On July 24, 2019, the Company entered into the tenth amendment to the Hercules Agreement (the “Tenth Hercules Amendment”). The Tenth Hercules Amendment provides, among other things, that the Company shall pay Hercules $4.0 million no later than July 25, 2019, which amount was paid, and will pay to Hercules 30% of the net proceeds received from the sale of common stock under the Sales Agreement on a weekly basis. The Tenth Hercules Amendment requires repayment of the indebtedness outstanding under the Hercules Agreement by no later than September 30, 2019 to avoid acceleration and default, provided that, in the event that the outstanding balance of the secured obligations (including interest, fees, costs and charges) under the Hercules Agreement has been paid down to an amount that is less than or equal to $5.0 million on or before September 30, 2019, the repayment date will be automatically extended to October 22, 2019. The total outstanding balance under the Hercules Agreement as of July 31, 2019 was $7.4 million.

Our ability to make scheduled payments of principal and interest and required repayments and to refinance our indebtedness depends on our future performance, which is subject to economic, financial, competitive and other factors beyond our control. Our business may not generate cash flow from operations in the future sufficient to service our debt and make necessary capital expenditures. If we are unable to generate such cash flow, we may be required to adopt one or more alternatives, such as selling assets, restructuring operations, restructuring debt or obtaining additional equity capital on terms that may be onerous or dilutive. Management is exploring refinancing alternatives for our senior secured credit facility with Hercules. If we are not able to consummate a refinancing transaction by September 30, 2019, or October 22, 2019, if the outstanding balance of the Hercules loan has been paid down to an amount that is less than or equal to $5.0 million on or before September 30, 2019, and if Hercules is not willing to provide further accommodations, we could default on our obligations under our senior secured credit facility with Hercules, which would trigger additional defaults under other agreements.

It is also possible that we may incur additional indebtedness in the future in the ordinary course of business. If new debt is added to current debt levels, the risks described above could intensify. Our debt agreements contain representations and warranties, affirmative and negative covenants, and events of default that entitle the lenders to cause our indebtedness under such debt agreements to become immediately due and payable.

We are required to maintain effective internal control over financial reporting. Our management has identified a material weakness in our internal control over financial reporting. If we are unable to remediate the material weakness or other control deficiencies are identified in the future, we may not be able to report our financial results accurately, prevent fraud or file our periodic reports in a timely manner, which may adversely affect investor confidence in our company and, as a result, the value of our common stock.

We are required, pursuant to Section 404 of the Sarbanes-Oxley Act, to furnish a report by management on, among other things, the effectiveness of our internal control over financial reporting.

Complying with Section 404 requires a rigorous compliance program as well as adequate time and resources. We may not be able to complete our internal control evaluation, testing and any required remediation in a timely fashion. Additionally, if we identify one or more material weaknesses in our internal control over financial reporting, we will not be able to assert that our internal controls are effective. A material weakness is a deficiency, or combination of deficiencies, in internal control over financial reporting, such that there is a reasonable possibility that a material misstatement of our annual or interim financial statements will not be prevented or detected on a timely basis.

Subsequent to the evaluation made in connection with filing our Form 10-Q for the three and six months ended April 30, 2019, our management, with the oversight of the Audit and Finance Committee of the Board of Directors, began the process of remediating the material weakness, which continued to exist as of July 31, 2019 as the Company did not have resources to sufficiently address the accounting for non-routine transactions. Progress to date includes engagement of a third party resource to help evaluate the accounting and disclosure for significant transactions each quarter. Management also plans to also add additional experienced accounting staff. In addition, under the oversight of the Audit and Finance Committee, management will continue to review and make necessary changes to the overall design of our internal control environment to improve the overall effectiveness of internal control over financial reporting. However, the material weakness will not be considered remediated until the applicable controls operate for a sufficient period of time and management has concluded, through testing, that these controls are operating effectively.

We cannot be certain that these measures will successfully remediate the material weakness or that other material weaknesses and control deficiencies will not be discovered in the future. If our efforts are not successful or other material weaknesses are identified in the future or we are not able to comply with the requirements of Section 404 in a timely manner, our reported financial results could be materially misstated, we would receive an adverse opinion regarding our internal controls over financial reporting from our independent registered public accounting firm, and we could be subject to investigations or sanctions by regulatory authorities, which would require additional financial and management resources, and the value of our common stock could decline.

To the extent we identify future weaknesses or deficiencies, there could be material misstatements in our consolidated financial statements and we could fail to meet our financial reporting obligations. As a result, our ability to obtain additional financing, or obtain additional financing on favorable terms, could be materially and adversely affected which, in turn, could materially and adversely affect our business, our financial condition and the value of our common stock. If we are unable to assert that our internal control over financial reporting is effective in the future, or if our independent registered public accounting firm is unable to express an opinion or expresses an adverse opinion on the effectiveness of our internal controls in the future, investor confidence in the accuracy and completeness of our financial reports could be further eroded, which would have a material adverse effect on the price of our common stock.

Our products compete with products using other energy sources, and if the prices of the alternative sources are lower than energy sources used by our products, sales of our products will be adversely affected.

Our power plants can operate on a variety of fuels including natural gas, renewable biogas, directed biogas and propane. If these fuels are not readily available or if their prices increase such that electricity produced by our products costs more than electricity provided by other generation sources, our products would be less economically attractive to potential customers. In addition, we have no control over the prices of several types of competitive energy sources such as solar, wind, oil, gas or coal or local utility electricity costs. Significant decreases (or short term increases) in the price of these technologies or fuels or grid delivered prices for electricity could also have a material adverse effect on our business because other generation sources could be more economically attractive to consumers than our products.

Financial markets worldwide have experienced heightened volatility and instability, which may have a material adverse impact on the Company, our customers and our suppliers.

Financial market volatility can affect the debt, equity and project finance markets. This may impact the amount of financing available to all companies, including companies with substantially greater resources, better credit ratings and more successful operating histories than ours. It is impossible to predict future financial market volatility and instability and the impact on the Company, and it may have a materially adverse effect on us for a number of reasons, such as:

Our contracted projects may not convert to revenue, and our project pipeline may not convert to contracts, which may have a material adverse effect on our revenue and cash flow.

Some of the orders we accept from customers require certain conditions or contingencies (such as permitting, interconnection or financing) to be satisfied, some of which are outside of our control. The time periods from receipt of a contract to installation may vary widely and are determined by a number of factors, including the terms of the customer contract and the customer’s site requirements. These same or similar conditions and contingencies may be required by financiers in order to draw on financing to complete a project. This could have an adverse impact on our revenue and cash flow and our ability to complete construction of a project.

We have signed product sales contracts, engineering, procurement and construction contracts, PPAs and long-term service agreements with customers subject to contractual, technology and operating risks as well as market conditions that may affect our operating results.

We apply the percentage of completion revenue recognition method to certain product sales contracts which are subject to estimates. On a quarterly basis, we perform a review process to help ensure that total estimated contract costs include estimates of costs to complete that are based on the most recent available information. The percentage of completion for the customer contracts based on this cost analysis is then applied to the total customer contract values to determine the total revenue to be recognized to date.

In certain instances, we have executed PPAs with the end-user of the power or site host of the fuel cell power plant. We may then sell the PPA to a project investor or retain the project and collect revenue from the sale of power over the term of the PPA, recognizing electricity revenue as power is generated and sold.

We have contracted under long-term service agreements with certain customers to provide service on our products over terms up to 20 years. Under the provisions of these contracts, we provide services to maintain, monitor, and repair customer power plants to meet minimum operating levels. Pricing for service contracts is based upon estimates of future costs including future module replacements. While we have conducted tests to determine the overall life of our products, we have not run certain of our products over their projected useful life prior to large-scale commercialization. As a result, we cannot be sure that our products will last to their expected useful life, which could result in warranty claims, performance penalties, maintenance and module replacement costs in excess of our estimates and losses on service contracts.

Our ability to proceed with projects under development and complete construction of projects on schedule and within budget may be adversely affected by escalating costs for materials, tariffs, labor and regulatory compliance, inability to obtain necessary permits, interconnections or other approvals on acceptable terms or on schedule and by other factors. If any development project or construction is not completed, is delayed or is subject to cost overruns, we could become obligated to make delay or termination payments or become obligated for other damages under contracts, experience diminished returns or write off all or a portion of our investment in the project. Each of these events could have an adverse effect on our business, financial condition, results of operations and prospects.

Our growing generation portfolio of operating assets exposes us to operational risks and commodity market volatility.

We have a growing portfolio of generation assets selling power under PPAs and utility tariff programs that exposes us to operational risks and uncertainties, including, among other things, lost revenues due to prolonged outages, replacement equipment costs, risks associated with facility start-up operations, failures in the availability or acquisition of fuel, the impact of severe adverse weather conditions, natural disasters, terrorist attacks, risks of property damage or injury from energized equipment, availability of adequate water resources and ability to intake and discharge water, use of new or unproven technology, fuel commodity price risk and fluctuating market prices, and lack of alternative available fuel sources.

We provide for a warranty of our products for a specific period of time against manufacturing or performance defects. We accrue for warranty costs based on historical warranty claim experience, however, actual future warranty expenses may be greater than we have assumed in our estimates. As a result, operating results could be negatively impacted should there be product manufacturing or performance defects in excess of our estimates.

Our products are complex and could contain defects and may not operate at expected performance levels which could impact sales and market adoption of our products or result in claims against us.

We develop complex and evolving products and we continue to advance the capabilities of our fuel cell stacks and are now producing stacks with a net rated power output of 350 kilowatts and an expected seven-year life.

We are still gaining field operating experience with respect to our products, and despite experience gained from our growing installed base and testing performed by us, our customers and our suppliers, issues may be found in existing or new products. This could result in a delay in recognition or loss of revenues, loss of market share or failure to achieve broad market acceptance. The occurrence of defects could also cause us to incur significant warranty, support and repair costs, could divert the attention of our engineering personnel from our product development efforts, and could harm our relationships with our customers. The occurrence of these problems could result in the delay or loss of market acceptance of our products and would likely harm our business. Defects or performance problems with our products could result in financial or other damages to our customers. From time to time, we have been involved in disputes regarding product warranty issues. Although we seek to limit our liability, a product liability claim brought against us, even if unsuccessful, would likely be time consuming, could be costly to defend, and may hurt our reputation in the marketplace. Our customers could also seek and obtain damages from us for their losses. We have accrued liabilities for potential damages related to performance problems, however, actual results may be different than the assumptions used in our accrual calculations.

We compete on the basis of our products’ reliability, efficiency, environmental considerations and cost. Technological advances in alternative energy products or improvements in the electric grid or other sources of power generation, or other fuel cell technologies may negatively affect the development or sale of some or all of our products or make our products non-competitive or obsolete prior to or after commercialization. Other companies, some of which have substantially greater resources than ours, are currently engaged in the development of products and technologies that are similar to, or may be competitive with, our products and technologies.

Several companies in the U.S. are engaged in fuel cell development, although we are the only domestic company engaged in manufacturing and deployment of stationary carbonate fuel cells. Other emerging fuel cell technologies (and the companies developing them) include small or portable proton-exchange membrane (“PEM”) fuel cells (Ballard Power Systems, Plug Power, and increasing activity by numerous automotive companies including Toyota, Hyundai, Honda and GM), stationary phosphoric acid fuel cells (Doosan), stationary solid oxide fuel cells (Bloom Energy), and small residential solid oxide fuel cells (Ceres Power Holdings and Ceramic Fuel Cells Ltd.). Each of these competitors has the potential to capture market share in our target markets. There are also other potential fuel cell competitors internationally that could capture market share.

Other than fuel cell developers, we must also compete with companies that manufacture more mature combustion-based equipment, including various engines and turbines, and have well-established manufacturing, distribution, operating and cost features. Electrical efficiency of these products can be competitive with our SureSource power plants in certain applications. Significant competition may also come from gas turbine companies and large scale solar and wind technologies.

We derive significant revenue from contracts awarded through competitive bidding processes involving substantial costs and risks. Due to this competitive pressure, we may be unable to grow revenue and achieve profitability.

We expect a significant portion of the business that we will seek in the foreseeable future will be awarded through competitive bidding against other fuel cell technologies and other forms of power generation. The competitive bidding process involves substantial costs and a number of risks, including the significant cost and managerial time to prepare bids and proposals for contracts that may not be awarded to us and our failure to accurately estimate the resources and costs that will be required to fulfill any contract we win. In addition, following a contract award, we may encounter significant expense, delay or contract modifications as a result of our competitors protesting or challenging contracts awarded to us in competitive bidding. In addition, multi-award contracts require that we make sustained post-award efforts to obtain task orders under the contract. We may not be able to obtain task orders or recognize revenue under these multi-award contracts. Our failure to compete effectively in this procurement environment could adversely affect our revenue and/or profitability.

Unanticipated increases or decreases in business growth may result in adverse financial consequences for us.

If our business grows more quickly than we anticipate, our existing and planned manufacturing facilities may become inadequate and we may need to seek out new or additional space, at considerable cost to us. If our business does not grow as quickly as we expect, our existing and planned manufacturing facilities would, in part, represent excess capacity for which we may not recover the cost. In that circumstance, our revenues may be inadequate to support our committed costs and our planned growth, and our gross margins and business strategy would be adversely affected.

Our plans are dependent upon market acceptance of, as well as enhancements to, our products. Fuel cell systems represent an emerging market, and we cannot be sure that potential customers will accept fuel cells as a replacement for traditional power sources or non-fuel based power sources. As is typical in a rapidly evolving industry, demand and market acceptance for recently introduced products and services are subject to a high level of uncertainty and risk. Since the distributed generation market is still evolving, it is difficult to predict with certainty the size of the market and its growth rate. The development of a market for our products may be affected by many factors that are out of our control, including:

If a sufficient market fails to develop or develops more slowly than we anticipate, we may be unable to recover the losses we will have incurred in the development of our products and may never achieve profitability.

As we continue to expand markets for our products, we intend to continue offering power production guarantees and other terms and conditions relating to our products that will be acceptable to the marketplace, and continue to develop a service organization that will aid in servicing our products and obtain self-regulatory certifications, if available, with respect to our products. Failure to achieve any of these objectives may also slow the development of a sufficient market for our products and, therefore, have a material adverse effect on our results of operations and financial condition.

We are substantially dependent on a concentrated number of customers and the loss of any one of these customers could adversely affect our business, financial condition and results of operations.

We contract with a concentrated number of customers for the sale of products and for research and development contracts. There can be no assurance that we will continue to achieve the current level of sales of our products to our largest customers. Even though our customer base is expected to increase and our revenue streams to diversify, a substantial portion of net revenues could continue to depend on sales to a limited number of customers. Our agreements with these customers may be canceled if we fail to meet certain product specifications or materially breach the agreements, or if our customers materially breach the agreements, and our customers may seek to renegotiate the terms of current agreements or renewals. The loss of, or a reduction in sales to, one or more of our larger customers could have a material adverse effect on our business, financial condition and results of operations.

If our goodwill and other intangible assets, long-lived assets, inventory or project assets become impaired, we may be required to record a significant charge to earnings.

We may be required to record a significant charge to operations in our financial statements should we determine that our goodwill, IPR&D, long-lived assets (i.e., property, plant and equipment), inventory, or project assets are impaired. Such a charge might have a significant impact on our reported financial condition and results of operations. We recorded a charge during the nine months ended July 31, 2019 for a specific construction in process asset related to automation equipment for use in manufacturing with a carrying value of $2.8 million, which was impaired due to uncertainty as to whether the asset will be completed as a result of the Company’s liquidity position and continued low level of production rates.

As required by accounting rules, we review our goodwill for impairment at least annually as of July 31 or more frequently if facts and circumstances indicate that it is more likely than not that the fair value of a reporting unit that has goodwill is less than its carrying value. Factors that may be considered a change in circumstances indicating that the carrying value of our goodwill might not be recoverable include a significant decline in projections of future cash flows and lower future growth rates in our industry. We review IPR&D for impairment on an annual basis as of July 31 or more frequently if facts and circumstances indicate the fair value is less than the carrying value. If the technology has been determined to be abandoned or not recoverable, we would be required to impair the asset. We review inventory, long-lived assets and project assets for impairment whenever events or changes in circumstances indicate the carrying amount may not be recoverable. We consider a project commercially viable and recoverable if it is anticipated to be sellable for a profit, or generates positive cash flows, once it is either fully developed or fully constructed. If our projects are not considered commercially viable, we would be required to impair the respective project assets.

The amount of total inventory as of July 31, 2019 and October 31, 2018 was $62.0 million ($2.2 million classified as long-term inventory) and $53.6 million, respectively, which includes work in process inventory totaling $35.3 million and $29.1 million, respectively. We reduced our production rate and have been operating at a lower level for a period of time in order to deploy inventory to new projects and mitigate future increases in inventory. In addition, there are risks that our inventory could lose some or all of its value due to technological obsolescence, shifts in market demand or other unexpected changes in industry conditions and circumstances. If we are unable to deploy our current inventory or new inventory consistent with our business plan, we may be required to sell it at a loss, abandon it or recycle it into different products. These actions would result in a significant charge to earnings. Such a charge might have a significant impact on our financial condition and results of operations.

Our advanced technologies contracts are subject to the risk of termination by the contracting party and we may not realize the full amounts allocated under the contracts due to the lack of Congressional appropriations.

A portion of our fuel cell revenues has been derived from long-term cooperative agreements and other contracts with the U.S. Department of Energy and other U.S. government agencies. These agreements are important to the continued development of our technology and our products. We also contract with private sector companies under certain advanced technologies contracts to develop strategically important and complementary offerings.

Generally, our government research and development contracts are subject to the risk of termination at the convenience of the contracting agency. Furthermore, these contracts, irrespective of the amounts allocated by the contracting agency, are subject to annual Congressional appropriations and the results of government or agency sponsored reviews and audits of our cost reduction projections and efforts. We can only receive funds under these contracts ultimately made available to us annually by Congress as a result of the appropriations process. Accordingly, we cannot be sure whether we will receive the full amounts awarded under our government research and development or other contracts. Failure to receive the full amounts under any of our government research and development contracts could materially and adversely affect our business prospects, results of operations and financial condition.

A negative government audit could result in an adverse adjustment of our revenue and costs and could result in civil and criminal penalties.

Government agencies, such as the Defense Contract Audit Agency, routinely audit and investigate government contractors. These agencies review a contractor’s performance under its contracts, cost structure, and compliance with applicable laws, regulations, and standards. If the agencies determine through these audits or reviews that we improperly allocated costs to specific contracts, they will not reimburse us for these costs. Therefore, an audit could result in adjustments to our revenue and costs.

Further, although we have internal controls in place to oversee our government contracts, no assurance can be given that these controls are sufficient to prevent isolated violations of applicable laws, regulations and standards. If the agencies determine that we or one of our subcontractors engaged in improper conduct, we may be subject to civil or criminal penalties and administrative sanctions, payments, fines, and suspension or prohibition from doing business with the government, any of which could materially affect our results of operations and financial condition.

The U.S. government has certain rights relating to our intellectual property, including the right to restrict or take title to certain patents.

Multiple U.S. patents that we own have resulted from government-funded research and are subject to the risk of exercise of “march-in” rights by the government. March-in rights refer to the right of the U.S. government or a government agency to exercise its non-exclusive, royalty-free, irrevocable worldwide license to any technology developed under contracts funded by the government if the contractor fails to continue to develop the technology. These “march-in” rights permit the U.S. government to take title to these patents and license the patented technology to third parties if the contractor fails to utilize the patents.

We cannot assure you that we will enter into business relationships that are consistent with, or sufficient to support, our commercialization plans and our growth strategy or that these relationships will be on terms favorable to us. Even if we enter into these types of relationships, we cannot assure you that the business associates with whom we form relationships will focus adequate resources on selling our products or will be successful in selling them. Some of these arrangements have required or will require that we grant exclusive rights to certain companies in defined territories. These exclusive arrangements could result in our being unable to enter into other arrangements at a time when the business associate with whom we form a relationship is not successful in selling our products or has reduced its commitment to marketing our products. In addition, future arrangements may also include the issuance of equity and/or warrants to purchase our equity, which may have an adverse effect on our stock price and would dilute our existing stockholders. To the extent we enter into partnerships or other business relationships, the failure of these partners or other business associates to assist us with the deployment of our products may adversely affect our results of operations and financial condition.

We depend on third party suppliers for the development and supply of key raw materials and components for our products.

We use various raw materials and components to construct a fuel cell module, including nickel and stainless steel which are critical to our manufacturing process. We also rely on third-party suppliers for the balance-of-plant components in our products. Suppliers must undergo a qualification process, which takes four to twelve months. We continually evaluate new suppliers, and we are currently qualifying several new suppliers. There are a limited number of suppliers for some of the key components of our products. A supplier’s failure to develop and supply components in a timely manner or to supply components that meet our quality, quantity or cost requirements or our technical specifications, or our inability to obtain alternative sources of these components on a timely basis or on terms acceptable to us could harm our ability to manufacture our SureSource products. In addition, to the extent the processes that our suppliers use to manufacture components are proprietary, we may be unable to obtain comparable components from alternative suppliers.

Due to the Company’s constrained liquidity, the Company has been delaying certain payments to third parties, including its suppliers, to conserve cash. Management has been actively working with suppliers, and entering into forbearance agreements and payment arrangements. However, the Company may not be able to enter into forbearance agreements or suitable payment arrangements with its suppliers, or the terms of any forbearance agreements or payment arrangements may not be favorable to the Company. If the Company is unable to negotiate such forbearance agreements or payment arrangements, suppliers whose payments have been delayed may take action against the Company, including, but not limited to, filing litigation, arbitration or other proceedings against the Company.

We do not know whether we will be able to maintain long-term supply relationships with our critical suppliers, or secure new long-term supply relationships, or whether such relationships will be on terms that will allow us to achieve our objectives. Our business prospects, results of operations and financial condition could be harmed if we fail to secure long-term relationships with entities that will supply the required components for our SureSource products.

We depend on our intellectual property, and our failure to protect that intellectual property could adversely affect our future growth and success.

Failure to protect our existing intellectual property rights may result in the loss of our exclusivity or the right to use our technologies. If we do not adequately ensure our freedom to use certain technology, we may have to pay others for rights to use their intellectual property, pay damages for infringement or misappropriation, or be enjoined from using such intellectual property. We rely on patent, trade secret, trademark and copyright law to protect our intellectual property.

We have licensed our carbonate fuel cell manufacturing intellectual property to POSCO Energy. In addition, effective as of June 11, 2019, the Company entered into the EMRE License Agreement, pursuant to which the Company has agreed, subject to the terms of the EMRE License Agreement, to grant EMRE and its affiliates a non-exclusive, worldwide, fully paid, perpetual, irrevocable, non-transferrable license and right to use the Company’s patents, data, know-how, improvements, equipment designs, methods, processes and the like to the extent it is useful to research, develop, and commercially exploit carbonate fuel cells in applications in which the fuel cells concentrate carbon dioxide from industrial and power sources and for any other purpose attendant thereto or associated therewith. Such right and license is sublicensable to third parties performing work for or with EMRE or its affiliates, but shall not otherwise be sublicensable. We depend on POSCO Energy and EMRE to also protect our intellectual property rights as licensed.

As of July 31, 2019, we, excluding our subsidiaries, had 95 U.S. patents and 154 patents in other jurisdictions covering our fuel cell technology (in certain cases covering the same technology in multiple jurisdictions), with patents directed to various aspects of our SureSource technology, solid oxide fuel cell (“SOFC”) technology, PEM fuel cell technology and applications thereof. As of July 31, 2019, we also had 65 patent applications pending in the U.S. and 115 patent applications pending in other jurisdictions. Our U.S. patents will expire between 2019 and 2037, and the current average remaining life of our U.S. patents is approximately 8.7 years. Our subsidiary, Versa Power Systems, Ltd., as of July 31, 2019, had 33 U.S. patents and 95 international patents covering the SOFC technology (in certain cases covering the same technology in multiple jurisdictions), with an average remaining U.S. patent life of approximately 5.8 years. As of July 31, 2019, Versa Power Systems, Ltd. also had one pending U.S. patent application and nine patent applications pending in other jurisdictions. In addition, as of July 31, 2019, our subsidiary, FuelCell Energy Solutions, GmbH, had license rights to two U.S. patents and seven patents outside the U.S. for carbonate fuel cell technology licensed from Fraunhofer IKTS.

Some of our intellectual property is not covered by any patent or patent application and includes trade secrets and other know-how that is not able to be patented, particularly as it relates to our manufacturing processes and engineering design. In addition, some of our intellectual property includes technologies and processes that may be similar to the patented technologies and processes of third parties. If we are found to be infringing third-party patents, we do not know whether we will be able to obtain licenses to use such patents on acceptable terms, if at all. Our patent position is subject to complex factual and legal issues that may give rise to uncertainty as to the validity, scope, and enforceability of a particular patent.

We cannot assure you that any of the U.S. or international patents owned by us or other patents that third parties license to us will not be invalidated, circumvented, challenged, rendered unenforceable or licensed to others, or that any of our pending or future patent applications will be issued with the breadth of claim coverage sought by us, if issued at all. In addition, effective patent, trademark, copyright and trade secret protection may be unavailable, limited or not applied for in certain foreign countries.

We also seek to protect our proprietary intellectual property, including intellectual property that may not be patented or able to be patented, in part by confidentiality agreements and, if applicable, inventors’ rights agreements with our subcontractors, vendors, suppliers, consultants, strategic business associates and employees. We cannot assure you that these agreements will not be breached, that we will have adequate remedies for any breach or that such persons or institutions will not assert rights to intellectual property arising out of these relationships. Certain of our intellectual property has been licensed to us on a non-exclusive basis from third parties that may also license such intellectual property to others, including our competitors. If our licensors are found to be infringing third-party patents, we do not know whether we will be able to obtain licenses to use the intellectual property licensed to us on acceptable terms, if at all.

If necessary or desirable, we may seek extensions of existing licenses or further licenses under the patents or other intellectual property rights of others. However, we can give no assurances that we will obtain such extensions or further licenses or that the terms of any offered licenses will be acceptable to us. The failure to obtain a license from a third party for intellectual property that we use at present could cause us to incur substantial liabilities, and to suspend the manufacture or shipment of products or our use of processes requiring the use of that intellectual property.

While we are not currently engaged in any intellectual property litigation, we could become subject to lawsuits in which it is alleged that we have infringed the intellectual property rights of others or commence lawsuits against others who we believe are infringing our rights or violating their agreements to protect our intellectual property. Our involvement in intellectual property litigation could result in significant expense to us, adversely affecting the development of sales of the challenged product or intellectual property and diverting the efforts of our technical and management personnel, whether or not that litigation is resolved in our favor.

Our future success will depend on our ability to attract and retain qualified management, technical, and other personnel.

Our future success is substantially dependent on the services and performance of our executive officers and other key management, engineering, scientific, manufacturing and operating personnel. The loss of the services of key management, engineering, scientific, manufacturing and operating personnel, could materially adversely affect our business. Our ability to achieve our commercialization plans and to increase production at our manufacturing facility in the future will also depend on our ability to attract and retain additional qualified management, technical, manufacturing and operating personnel. Recruiting personnel for the fuel cell industry is competitive. We do not know whether we will be able to attract or retain additional qualified management, technical, manufacturing and operating personnel. Our inability to attract and retain additional qualified management, technical, manufacturing and operating personnel, or the departure of key employees, could materially and adversely affect our development, commercialization and manufacturing plans and, therefore, our business prospects, results of operations and financial condition. In addition, our inability to attract and retain sufficient management, technical, manufacturing and operating personnel to quickly increase production at our manufacturing facility when and if needed to meet increased demand may adversely impact our ability to respond rapidly to any new product, growth or revenue opportunities.

We are subject to various federal, state and local laws and regulations relating to, among other things, land use, safe working conditions, handling and disposal of hazardous and potentially hazardous substances and emissions of pollutants into the atmosphere. In addition, it is possible that industry-specific laws and regulations will be adopted covering matters such as transmission scheduling, distribution, emissions, and the characteristics and quality of our products, including installation and servicing. These regulations could limit the growth in the use of carbonate fuel cell products, decrease the acceptance of fuel cells as a commercial product and increase our costs and, therefore, the price of our products. Accordingly, compliance with existing or future laws and regulations could have a material adverse effect on our business prospects, results of operations and financial condition.

Utility companies may resist the adoption of distributed generation and could impose customer fees or interconnection requirements on our customers that could make our products less desirable.

Investor-owned utilities may resist adoption of distributed generation fuel cell plants as such plants are disruptive to the utility business model that primarily utilizes large central generation power plants and associated transmission and distribution. On-site distributed generation that is on the customer-side of the electric meter competes with the utility. Distributed generation on the utility-side of the meter generally has power output that is significantly less than central generation power plants and may be perceived by the utility as too small to materially impact its business, limiting its interest. Additionally, perceived technology risk may limit utility interest in stationary fuel cell power plants.

Utility companies commonly charge fees to larger, industrial customers for disconnecting from the electric grid or for having the capacity to use power from the electric grid for back up purposes. These fees could increase the cost to our customers of using our SureSource products and could make our products less desirable, thereby harming our business prospects, results of operations and financial condition.

We could be liable for environmental damages resulting from our research, development or manufacturing operations.

Our business exposes us to the risk of harmful substances escaping into the environment, resulting in personal injury or loss of life, damage to or destruction of property, and natural resource damage. Depending on the nature of the claim, our current insurance policies may not adequately reimburse us for costs incurred in settling environmental damage claims, and in some instances, we may not be reimbursed at all. Our business is subject to numerous federal, state, and local laws and regulations that govern environmental protection and human health and safety. We believe that our businesses are operating in compliance in all material respects with applicable environmental laws, however, these laws and regulations have changed frequently in the past and it is reasonable to expect additional and more stringent changes in the future.

Our operations may not comply with future laws and regulations and we may be required to make significant unanticipated capital and operating expenditures. If we fail to comply with applicable environmental laws and regulations, governmental authorities may seek to impose fines and penalties on us or to revoke or deny the issuance or renewal of operating permits and private parties may seek damages from us. Under those circumstances, we might be required to curtail or cease operations, conduct site remediation or other corrective action, or pay substantial damage claims.

Our products use inherently dangerous, flammable fuels, operate at high temperatures and use corrosive carbonate material, each of which could subject our business to product liability claims.

Our business exposes us to potential product liability claims that are inherent in products that use hydrogen. Our products utilize fuels such as natural gas and convert these fuels internally to hydrogen that is used by our products to generate electricity. The fuels we use are combustible and may be toxic. In addition, our SureSource products operate at high temperatures and use corrosive carbonate material, which could expose us to potential liability claims. Although we have incorporated a robust design and redundant safety features in our power plants, have established comprehensive safety, maintenance, and training programs, follow third-party certification protocols, codes and standards, and do not store natural gas or hydrogen at our power plants, we cannot guarantee that there will not be accidents. Any accidents involving our products or other hydrogen-using products could materially impede widespread market acceptance and demand for our products. In addition, we might be held responsible for damages beyond the scope of our insurance coverage. We also cannot predict whether we will be able to maintain adequate insurance coverage on acceptable terms.

Since we market our products both inside and outside the U.S., our success depends in part on our ability to secure international customers and our ability to manufacture products that meet foreign regulatory and commercial requirements in target markets. Sales to customers located outside the U.S. accounts for a significant portion of our consolidated revenue. Sales to customers in South Korea represent the majority of our international sales. We have limited experience developing and manufacturing our products to comply with the commercial and legal requirements of international markets. In addition, we are subject to tariff regulations and requirements for export licenses, particularly with respect to the export of some of our technologies. We face numerous challenges in our international expansion, including unexpected changes in regulatory requirements and other geopolitical risks, fluctuations in currency exchange rates, longer accounts receivable requirements and collections, greater bonding and security requirements, difficulties in managing international operations, potentially adverse tax consequences, restrictions on repatriation of earnings and the burdens of complying with a wide variety of international laws. Any of these factors could adversely affect our results of operations and financial condition.

We source raw materials and parts for our products on a global basis, which subjects us to a number of potential risks, including the impact of export duties and quotas, trade protection measures imposed by the U.S. and other countries including tariffs, potential for labor unrest, changing global and regional economic conditions and current and changing regulatory environments. Changes to these factors may have an adverse effect on our ability to source raw materials and parts in line with our current cost structure.

Although our reporting currency is the U.S. dollar, we conduct our business and incur costs in the local currency of most countries in which we operate. As a result, we are subject to currency translation and transaction risk. Changes in exchange rates between foreign currencies and the U.S. dollar could affect our net sales and cost of sales and could result in exchange gains or losses. We cannot accurately predict the impact of future exchange rate fluctuations on our results of operations.

We could also expand our business into new and emerging markets, many of which have an uncertain regulatory environment relating to currency policy. Conducting business in such markets could cause our exposure to changes in exchange rates to increase, due to the relatively high volatility associated with emerging market currencies and potentially longer payment terms for our proceeds. Our ability to hedge foreign currency exposure is dependent on our credit profile with financial institutions that are willing and able to do business with us. Deterioration in our credit position or a significant tightening of the credit market conditions could limit our ability to hedge our foreign currency exposure; and therefore, result in exchange gains or losses.

Exports of certain of our products are subject to various export control regulations and may require a license or permission from the U.S. Department of State, the U.S. Department of Energy or other agencies.

As an exporter, we must comply with various laws and regulations relating to the export of products, services and technology from the U.S. and other countries having jurisdiction over our operations. We are subject to export control laws and regulations, including the International Traffic in Arms Regulation, the Export Administration Regulation, and the Specially Designated Nationals and Blocked Persons List, which generally prohibit U.S. companies and their intermediaries from exporting certain products, importing materials or supplies, or otherwise doing business with restricted countries, businesses or individuals, and require companies to maintain certain policies and procedures to ensure compliance. We are also subject to the Foreign Corrupt Practices Act which prohibits improper payments to foreign governments and their officials by U.S. and other business entities. Under these laws and regulations, U.S. companies may be held liable for their actions and actions taken by their strategic or local partners or representatives. If we, or our intermediaries, fail to comply with the requirements of these laws and regulations, or similar laws of other countries, governmental authorities in the United States or elsewhere, as applicable, could seek to impose civil and/or criminal penalties, which could damage our reputation and have a material adverse effect on our business, financial condition and results of operations.

We are also subject to registration under the U.S. State Department’s Directorate of Defense Trade Controls (“DDTC”). Due to the nature of certain of our products and technology, we must obtain licenses or authorizations from various U.S. government agencies such as DDTC or Department of Energy, before we are permitted to sell such products or license such technology outside of the U.S. We can give no assurance that we will continue to be successful in obtaining the necessary licenses or authorizations or that certain sales will not be prevented or delayed. Any significant impairment of our ability to sell products or license technology outside of the U.S. could negatively impact our results of operations, financial condition or liquidity.

We depend on strategic relationships with third parties, and the terms and enforceability of many of these relationships are not certain.

We have entered into strategic relationships with third parties for the design, product development, sale and service of our existing products and products under development, some of which may not have been documented by a definitive agreement and others of which may require renewal. The terms and conditions of many of these relationships allow for termination by the third parties. Termination or expiration of any of these relationships could adversely affect our ability to design, develop and distribute these products to the marketplace. We cannot assure you that we will be able to successfully negotiate and execute definitive agreements or renewals with any of these third parties, and failure to do so may effectively terminate the relevant relationship.

We are increasingly dependent on information technology, and disruptions, failures or security breaches of our information technology infrastructure could have a material adverse effect on our operations. In addition, increased information technology security threats and more sophisticated computer crime pose a risk to our systems, networks, products and services.

We rely on information technology networks and systems, including the Internet, to process, transmit and store electronic and financial information and to manage a variety of business processes and activities, including communication with power plants owned by us or our customers and production, manufacturing, financial, logistics, sales, marketing and administrative functions. Additionally, we collect and store data that is sensitive to us and to third parties. Operating these information technology networks and systems and processing and maintaining this data, in a secure manner, are critical to our business operations and strategy. We depend on our information technology infrastructure to communicate internally and externally with employees, customers, suppliers and others. We also use information technology networks and systems to comply with regulatory, legal and tax requirements and to operate our fuel cell power plants. These information technology systems, many of which are managed by third parties or used in connection with shared service centers, may be susceptible to damage, disruptions or shutdowns due to failures during the process of upgrading or replacing software, databases or components thereof, power outages, hardware failures, computer viruses, attacks by computer hackers or other cybersecurity risks, telecommunication failures, user errors, natural disasters, terrorist attacks or other catastrophic events. If any of our significant information technology systems suffer severe damage, disruption or shutdown, and our disaster recovery and business continuity plans do not effectively resolve the issues in a timely manner, our product sales, financial condition and results of operations may be materially and adversely affected, and we could experience delays in reporting our financial results, or our fuel cell power plant operations may be disrupted, exposing us to performance penalties under our contracts with customers.

In addition, information technology security threats – from user error to cybersecurity attacks designed to gain unauthorized access to our systems, networks and data – are increasing in frequency and sophistication. Cybersecurity attacks may range from random attempts to coordinated and targeted attacks, including sophisticated computer crime and advanced persistent threats. These threats pose a risk to the security of our systems and networks and the confidentiality, availability and integrity of our data. Cybersecurity attacks could also include attacks targeting customer data or the security, integrity and/or reliability of the hardware and software installed in our products. We have experienced, and may continue to experience in the future, cybersecurity attacks that have resulted in unauthorized parties gaining access to our information technology systems and networks and, in one instance, gaining control of the information technology system at one of our power plants. However, to date, no cybersecurity attack has resulted in any material loss of data, interrupted our day-to-day operations or had a material impact on our financial condition, results of operations or liquidity. While we actively manage information technology security risks within our control, there can be no assurance that such actions will be sufficient to mitigate all potential risks to our systems, networks and data. In addition to the direct potential financial risk as we continue to build, own and operate generation assets, other potential consequences of a material cybersecurity attack include reputational damage, litigation with third parties, disruption to systems, unauthorized release of confidential or otherwise protected information, corruption of data, diminution in the value of our investment in research, development and engineering, and increased cybersecurity protection and remediation costs, which in turn could adversely affect our competitiveness, results of operations and financial condition. The amount of insurance coverage we maintain may be inadequate to cover claims or liabilities relating to a cybersecurity attack.

Litigation could expose us to significant costs and adversely affect our business, financial condition, and results of operations.

We are, or may become, party to various lawsuits and claims arising in the ordinary course of business, which may include lawsuits or claims relating to commercial liability, product recalls, product liability, product claims, employment matters, environmental matters, breach of contract, or other aspects of our business. Litigation is inherently unpredictable, and although we may believe we have meaningful defenses in these matters, we may incur judgments or enter into settlements of claims that could have a material adverse effect on our business, financial condition, and results of operations. The costs of responding to or defending litigation may be significant and may divert the attention of management away from our strategic objectives. There may also be adverse publicity associated with litigation that may decrease customer confidence in our business, regardless of whether the allegations are valid or whether we are ultimately found liable. As a result, litigation may have a material adverse effect on our business, financial condition, and results of operations.

Our results of operations could vary as a result of changes to our accounting policies or the methods, estimates and judgments we use in applying our accounting policies.

The methods, estimates and judgments we use in applying our accounting policies have a significant impact on our results of operations. Such methods, estimates and judgments are, by their nature, subject to substantial risks, uncertainties and assumptions, and factors may arise over time that could lead us to reevaluate our methods, estimates and judgments.

In future periods, management will continue to reevaluate its estimates for contract margins, service agreements, loss accruals, warranty, performance guarantees, liquidated damages and inventory valuation allowances. Changes in those estimates and judgments could significantly affect our results of operations and financial condition. We will also adopt changes required by the Financial Accounting Standards Board and the SEC.

The market price for our common stock has been and may continue to be volatile and subject to extreme price and volume fluctuations in response to market and other factors, including the following, some of which are beyond our control:

In the past, following periods of volatility in the market price of their stock, many companies have been the subject of securities class action litigation. If we became involved in securities class action litigation in the future, it could result in substantial costs and diversion of management’s attention and resources and could harm our stock price, business prospects, results of operations and financial condition.

Provisions of Delaware and Connecticut law and of our certificate of incorporation and by-laws and our outstanding securities may make a takeover more difficult.

Provisions in our certificate of incorporation and by-laws and in Delaware and Connecticut corporate law may make it difficult and expensive for a third-party to pursue a tender offer, change in control or takeover attempt that is opposed by our management and Board of Directors. In addition, certain provisions of the Series 1 Preferred Shares, our Series B Preferred Shares and our Series D Preferred Shares could make it more difficult or more expensive for a third party to acquire us. Public stockholders who might desire to participate in such a transaction may not have an opportunity to do so. These anti-takeover provisions could substantially impede the ability of public stockholders to benefit from a change in control or change in our management and Board of Directors.

Our amended and restated by-laws provide that the Court of Chancery of the State of Delaware is the exclusive forum for substantially all disputes between us and our stockholders, which could limit our stockholders’ ability to obtain a judicial forum deemed favorable by the stockholder for disputes with us or our directors, officers or employees.

Our amended and restated by-laws provide that the Court of Chancery of the State of Delaware is the exclusive forum for any derivative action or proceeding brought on our behalf, any action asserting a breach of fiduciary duty, any action asserting a claim against us arising pursuant to the Delaware General Corporation Law, our certificate of incorporation or our amended and restated by-laws, any action to interpret, apply, enforce, or determine the validity of our certificate of incorporation or amended and restated by-laws, or any action asserting a claim against us that is governed by the internal affairs doctrine. The choice of forum provision may limit a stockholder’s ability to bring a claim in a judicial forum that the stockholder finds favorable for disputes against us or our directors, officers or other employees, which may discourage such lawsuits against us and our directors, officers and other employees. Alternatively, if a court were to find the choice of forum provision contained in our amended and restated by-laws to be inapplicable or unenforceable in an action, we may incur additional costs associated with resolving such action in other jurisdictions, which could adversely affect our business and financial condition.

The implementation of our business plan and strategy will require additional capital.

The implementation of our business plan and strategy requires additional capital to fund operations as well as investment by us in project assets. If we are unable to raise additional capital in the amounts required, or at all, we will not be able to successfully implement our business plan and strategy. There can be no guarantee that we will be able to raise such additional capital at the times required or in the amounts required for the implementation of our business plan and strategy. In addition, the recent change to a more capital-intensive business model increases the risks of our being able to successfully implement our plans, if we do not raise additional capital in the amounts required. If we are unable to raise additional capital, our business, operations and prospects could be materially and adversely affected.

We will need to raise additional capital, and such capital may not be available on acceptable terms, if at all. If we do raise additional capital utilizing equity, existing stockholders will suffer dilution. If we do not raise additional capital, our business could fail or be materially and adversely affected.

We will need to raise additional funds in debt and equity financings, and these funds may not be available to us when we need them or on acceptable terms, if at all. Such additional financings could be significant. If we raise additional funds through further issuances of our common stock, or securities convertible or exchangeable into shares of our common stock, into the public market, including shares of our common stock issued upon exercise of options or warrants, you could suffer significant dilution, and any new equity securities we issue could have rights, preferences and privileges superior to those of our then-existing capital stock. Any debt financing secured by us in the future could involve restrictive covenants relating to our capital raising activities and other financial and operational matters, which may make it more difficult for us to obtain additional capital and to pursue business opportunities. If we cannot raise additional funds when we need them, our business and prospects could fail or be materially and adversely affected. In addition, if additional funds are not secured in the future, we will have to modify, reduce, defer or eliminate parts of our present and anticipated future projects.

Future sales of substantial amounts of our common stock could affect the market price of our common stock.

Future sales of substantial amounts of our common stock, or securities convertible or exchangeable into shares of our common stock, into the public market, including shares of our common stock issued upon exercise of options or warrants, or perceptions that those sales could occur, could adversely affect the prevailing market price of our common stock and our ability to raise capital in the future.

We may be subject to actions for rescission or damages or other penalties in connection with certain sales of shares of our common stock in the open market.

Between August 2005 and April 2017, we sold shares of our common stock pursuant to a series of “at-the-market” sales plans. The shares sold pursuant to these sales plans represented a portion of the shares registered by us pursuant to shelf registration statements we filed with the SEC during this time period. While we reported the actual shares sold and proceeds, net of fees, of sales made during each fiscal quarter pursuant to the sales plans in our annual and quarterly reports on Forms 10-K and 10-Q, we did not file or deliver prospectus supplements at the time of or prior to making these sales. Accordingly, these sales may not have been in compliance with applicable federal and/or state securities laws, and the purchasers of such shares may have rescission rights or claims for damages. In addition, to the extent that these sales were not in compliance with applicable federal and/or state securities laws, we may be subject to penalties imposed by the SEC and/or state securities agencies. We have reported these sales to the SEC, and in response to our report, the SEC has opened an informal investigation of these sales. If purchasers successfully seek rescission and/or damages, and/or the SEC and/or state securities agencies impose financial penalties on us which are not covered by insurance, we may not have sufficient resources to make the necessary payments, and any such claims, damages or penalties could have a material adverse effect on our stock price, business prospects, results of operations, and financial condition. Although we believe we would have defenses to such claims or actions if brought, we are unable to predict the likelihood of any claims or actions being brought against us, or the amount of any damages or financial penalties which could be sought against us, or the extent to which any such financial exposure would be covered by insurance.

The rights of the Series 1 Preferred Shares and the Series B Preferred Stock could negatively impact our cash flows and could dilute the ownership interest of our stockholders.

The terms of the Series 1 Preferred Shares issued by FCE Ltd. provide rights to the holder, Enbridge Inc. (“Enbridge”), which could negatively impact us.

The provisions of the Series 1 Preferred Shares require that FCE Ltd. make annual payments totaling Cdn. $1,250,000, including (i) annual dividend payments of Cdn. $500,000 and (ii) annual return of capital payments of Cdn. $750,000. These payments will end on December 31, 2020. Additional dividends accrue on cumulative unpaid dividends at a 1.25% quarterly rate, compounded quarterly, until payment thereof. On December 31, 2020, the amount of all accrued and unpaid dividends on the Series 1 Preferred Shares of Cdn. $21.1 million and the balance of the principal redemption price of Cdn. $4.4 million must be paid to the holders of the Series 1 Preferred Shares. FCE Ltd. has the option of making dividend payments in the form of common stock or cash under the terms of the Series 1 Preferred Shares.

We are also required to issue common stock to the holder of the Series 1 Preferred Shares if and when the holder exercises its conversion rights. The number of shares of common stock that we may issue upon conversion could be significant and dilutive to our existing stockholders. For example, assuming the holder of the Series 1 Preferred Shares exercises its conversion rights after July 31, 2020 and assuming our common stock price is $0.34 (our common stock closing price on July 31, 2019), and an exchange rate of U.S. $1.00 to Cdn. $1.31 (exchange rate on July 31, 2019) at the time of conversion, we would be required to issue approximately 875,380 shares of our common stock.

The terms of the Series B Preferred Stock also provide rights to their holders that could negatively impact us. Holders of the Series B Preferred Stock are entitled to receive cumulative dividends at the rate of $50 per share per year, payable either in cash or in shares of our common stock. To the extent the dividend is paid in shares, additional issuances could be dilutive to our existing stockholders and the sale of those shares could have a negative impact on the price of our common stock. A share of our Series B Preferred Stock may be converted at any time, at the option of the holder, into 0.5910 shares of our common stock (which is equivalent to an initial conversion price of $1,692 per share), plus cash in lieu of fractional shares. Furthermore, the conversion rate applicable to the Series B Preferred Stock is subject to additional adjustment upon the occurrence of certain events.

We may not be able to make cash payments to redeem the Series D Preferred Shares.

We have the obligation to make bimonthly redemption payments on the Series D Preferred Shares commencing on December 1, 2018. These mandatory redemption payments may each be made, at our option, in cash or in shares of our common stock or in a combination of cash and shares of our common stock, except that our right to make payment in shares of common stock is dependent upon our satisfying certain equity conditions, unless such conditions are waived by the holders of the Series D Preferred Shares or such holders otherwise agree to accept shares of common stock. Among other things, these equity conditions include our continued listing on The Nasdaq Global Market or another permitted exchange, our stock maintaining certain minimum average prices and trading volumes during the applicable measurement period, and the nonexistence of a “triggering event” or an event that with the passage of time or giving of notice would constitute a triggering event.

If we cannot satisfy the equity conditions, we will not be able to make our bimonthly mandatory redemption payments in stock (unless such conditions are waived by the holders of the Series D Preferred Shares or such holders otherwise agree to accept shares of common stock), and we would be forced to make such bimonthly payments in cash. We may not have sufficient cash resources at the applicable time to make those cash payments, or to make such cash payments in full. In addition, certain such cash payments may not be permitted under the terms of our existing or future indebtedness or may cause us to fail to satisfy financial maintenance covenants.

Further, any failure to pay any amounts due to the holders of the Series D Preferred Shares, as well as certain other triggering events, including, without limitation, our failure to timely deliver shares, the suspension of trading of our common stock, our failure to keep reserved for issuance an adequate number of shares of common stock to cover conversion of the Series D Preferred Shares, breaches of certain agreements that permit the other party to such agreement to declare a default or accelerate amounts due, the existence of a circumstance or event that would result in a default under another agreement that would or is reasonably expected to have a material adverse effect, and breaches of certain covenants that are not timely cured, where a cure period is permitted, would permit the holders of the Series D Preferred Shares to require us to redeem such Series D Preferred Shares, in cash at a price equal to the greater of (i) 125% of the stated value of the Series D Preferred Shares being redeemed, as the case may be, plus accrued dividends, if any, and (ii) the market value of the number of shares issuable on conversion of the Series D Preferred Shares valued at the greatest closing sales price during the period from the date immediately before the triggering event through the date we make the redemption payment. If, for any reason, we are required to repurchase the Series D Preferred Shares in cash prior to maturity, no assurance can be given that we would have the cash or financial resources available to us to make such a payment (or that we would be permitted to make such a payment under the terms of our indebtedness), and such an acceleration could have a material adverse effect on our business, results of operations and financial condition.

The Series B Preferred Stock and Series D Preferred Shares rank senior to our common stock with respect to payments upon liquidation, dividends, and distributions.

The rights of the holders of the Series B Preferred Stock and Series D Preferred Shares rank senior to the obligations to our common stockholders. Upon our liquidation, the holders of Series B Preferred Stock are entitled to receive $1,000.00 per share plus all accumulated and unpaid dividends. Until the holders of Series B Preferred Stock receive their Liquidation Preference in full, no payment will be made on any junior shares, including our Series D Preferred Shares and shares of our common stock. Upon our liquidation, the holders of Series D Preferred Shares are entitled to receive an amount per Series D Preferred Share equal to the greater of (A) the stated value thereof on the date of such payment, plus accrued dividends, if any and (B) the amount per share such holder would receive if such holder converted such Series D Preferred Shares into common stock immediately prior to the date of such payment. Further, the holders of Series D Preferred Shares have the right to participate in any payment of dividends or other distributions made to the holders of common stock to the same extent as if they had converted such preferred shares. The existence of senior securities such as the Series B Preferred Stock and Series D Preferred Shares could have an adverse effect on the value of our common stock.

Holders of the Series D Preferred Shares have rights that may restrict our ability to operate our business.

Under the Series D Certificate of Designation, we are subject to certain covenants that limit our ability to create new series of preferred stock, other than series junior to the Series D Preferred Shares with redemption occurring after the maturity date of the Series D Preferred Shares, and our ability to incur certain indebtedness. Such restrictions may have an adverse effect on our ability to operate our business while the Series D Preferred Shares are outstanding.

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:

⁽¹⁾Certain information in this exhibit has been omitted pursuant to Item 601(b)(10)(iv) of Regulation S-K because (i) it is not material and (ii) it would likely cause competitive harm if publicly disclosed.

⁽²⁾Certain attachments have been omitted from this exhibit pursuant to Item 601(a)(5) of Regulation S-K. The Company agrees to furnish a copy of any omitted attachments to the Securities and Exchange Commission upon its request.

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.

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)

		Page

PART I - FINANCIAL INFORMATION

Item 1.	Consolidated Financial Statements (unaudited).

	Consolidated Balance Sheets as of July 31, 2019 and October 31, 2018.	3

	Consolidated Statements of Operations and Comprehensive Loss for the three months ended July 31, 2019 and 2018.	4

	Consolidated Statements of Operations and Comprehensive Loss for the nine months ended July 31, 2019 and 2018.	5

	Consolidated Statements of Changes in Equity for the three and nine months ended July 31, 2019.	6

	Consolidated Statements of Changes in Equity for the three and nine months ended July 31, 2018.	7

	Consolidated Statements of Cash Flows for the nine months ended July 31, 2019 and 2018.	8

	Notes to Consolidated Financial Statements.	9

Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations.	35

Item 3.	Quantitative and Qualitative Disclosures about Market Risk.	60

Item 4.	Controls and Procedures.	60

PART II - OTHER INFORMATION

Item 1.	Legal Proceedings.	62

Item 1A.	Risk Factors.	62

Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds.	77

Item 3.	Defaults Upon Senior Securities.	77

Item 4.	Mine Safety Disclosures.	77

Item 5.	Other Information.	77

Item 6.	Exhibits.	78

Signatures		82

	July 31,		October 31,
	2019		2018
Commercial Customers:
Amount billed	$	2,016	$	7,415
Unbilled receivables⁽¹⁾		6,217		10,632
		8,233		18,047
Advanced Technologies (including U.S. government⁽²⁾):
Amount billed		1,689		1,865
Unbilled receivables		1,969		3,127
		3,658		4,992
Accounts receivable, net and unbilled receivables	$	11,891	$	23,039

	July 31,		October 31,
	2019		2018
Accrued payroll and employee benefits	$	1,730	$	2,550
Accrued product warranty cost ⁽¹⁾		38		147
Accrued service agreement costs⁽²⁾		2,559		2,029
Accrued legal, taxes, professional and other		4,255		2,906
Accrued liabilities	$	8,582	$	7,632

	Series A Warrants			Series C Warrants
Balance as of October 31, 2018		640,000			964,114
Warrants exchanged		(640,000	)		—
Warrants exercised		—			—
Warrants expired		—			—
Balance as of July 31, 2019		—			964,114

Large accelerated filer	☐	Accelerated filer	☒
Non-accelerated filer	☐	Smaller reporting company	☒
Emerging growth company	☐

	October 31, 2018			Adjustments due to Topic 606			Balance at November 1, 2018
ASSETS
Unbilled receivables	$	13,759		$	471		$	14,230
Other assets		13,505			(132	)		13,373

LIABILITIES
Accrued liabilities	$	7,632		$	995		$	8,627
Deferred revenue, current portion		11,347			(240	)		11,107
Long-term deferred revenue		16,793			6,238			23,031

EQUITY
Accumulated deficit	$	(990,867	)	$	(6,654	)	$	(997,521	)

	July 31, 2019
	As reported			Adjustments			Balances without adoption of Topic 606
ASSETS
Unbilled receivables	$	8,186		$	(110	)	$	8,076
Other assets		10,019			(901	)		9,118

LIABILITIES
Accrued liabilities	$	8,582		$	(939	)	$	7,643
Deferred revenue		15,650			(1,518	)		14,132
Long-term deferred revenue		22,190			(7,083	)		15,107

EQUITY
Accumulated deficit	$	(1,039,910	)	$	8,529		$	(1,031,381	)

	For the Three Months Ended July 31, 2019
	As reported			Adjustments		Balances without adoption of Topic 606
Total revenues	$	22,712		$	974	$	23,686
Total cost of revenues		14,747			397		15,144
Gross profit		7,965			577		8,542
Administrative and selling expenses		7,058			—		7,058
Research and development expenses		1,977			—		1,977
Loss from operations		(1,070	)		577		(493	)
Interest expense		(3,536	)		—		(3,536	)
Other expense, net		(685	)		—		(685	)
Loss before provision for income taxes		(5,291	)		577		(4,714	)
Provision for income taxes		(20	)		—		(20	)
Net loss	$	(5,311	)	$	577	$	(4,734	)

	For the Nine Months Ended July 31, 2019
	As reported			Adjustments		Balances without adoption of Topic 606
Total revenues	$	49,711		$	3,315	$	53,026
Total cost of revenues		47,591			1,440		49,031
Gross profit		2,120			1,875		3,995
Administrative and selling expenses		23,622			—		23,622
Research and development expenses		12,435			—		12,435
Loss from operations		(33,937	)		1,875		(32,062	)
Interest expense		(7,807	)		—		(7,807	)
Other expense, net		(556	)		—		(556	)
Loss before provision for income taxes		(42,300	)		1,875		(40,425	)
Provision for income taxes		(89	)		—		(89	)
Net loss	$	(42,389	)	$	1,875	$	(40,514	)

	Operating Leases		Capital Leases
Due Year 1	$	743	$	138
Due Year 2		436		47
Due Year 3		441		10
Due Year 4		405		—
Due Year 5		373		—
Thereafter		2,724		—
Total	$	5,122	$	195

	Three Months Ended July 31,						Change
(dollars in thousands)	2019			2018			$		%
Total revenues	$	22,712		$	12,110		$	10,602		88	%
Total costs of revenues	$	14,747		$	14,166		$	581		4	%
Gross profit (loss)	$	7,965		$	(2,056	)	$	10,021		487	%
Gross margin (loss)		35.1	%		(17.0	)%

Project Name	Location	Power Off-Taker	Rated Capacity (MW)	Actual Commercial Operation Date (FuelCell Energy Fiscal Quarter)	PPA Term (Years)
Central CT State University (“CCSU”)	New Britain, CT	CCSU (CT University)	1.4	Q2 ‘12	10
UCI Medical Center (“UCI”)	Orange, CA	UCI (CA University Hospital)	1.4	Q1 '16	19
Riverside Regional Water Quality Control Plant	Riverside, CA	City of Riverside (CA Municipality)	1.4	Q4 '16	20
Pfizer, Inc.	Groton, CT	Pfizer, Inc.	5.6	Q4 '16	20
Santa Rita Jail	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 '14	15
		Total MW Operating:	26.1

	Payments Due by Period
(dollars in thousands)	Total		Less than 1 Year		1 – 3 Years		3 – 5 Years		More than 5 Years
Purchase commitments⁽¹⁾	$	44,827	$	40,720	$	4,085	$	22	$	—
Series 1 Preferred obligation⁽²⁾		5,041		1,425		3,616		—		—
Term and Construction loans (principal and interest)⁽³⁾		86,888		42,904		16,353		14,469		13,162
Capital and operating lease commitments⁽⁴⁾		5,316		880		934		779		2,723
Sale-leaseback financing obligation ⁽⁵⁾		18,261		3,627		5,684		4,527		4,423
Option fee⁽⁶⁾		300		150		150		—		—
Series B Preferred dividends payable ⁽⁷⁾		—		—		—		—		—
Totals	$	160,633	$	89,706	$	30,822	$	19,797	$	20,308

Period	Total Number of Shares Purchased ⁽¹⁾		Average Price Paid per Share		Total Number of Shares Purchased as Part of Publicly Announced Programs		Maximum Number of Shares that May Yet be Purchased Under the Plans or Programs
May 1, 2019 – May 31, 2019		—	$	—		—		—
June 1, 2019 – June 30, 2019		362	$	1.19		—		—
July 1, 2019 – July 31, 2019		326	$	0.26		—		—
Total		688	$	0.75		—		—

Exhibit No.		Description
3.1		Certificate of Amendment of the Certificate of Incorporation of FuelCell Energy, Inc., dated May 8, 2019 (incorporated by reference to Exhibit 3.1 to the Company’s Current Report on Form 8-K filed on May 8, 2019).

3.2		Certificate of Incorporation of the Company, as amended, July 12, 1999 (incorporated by reference to Exhibit 3.1 to the Company’s Current Report on Form 8-K dated September 21, 1999).

3.3		Certificate of Amendment of the Certificate of Incorporation of the Company, dated October 31, 2003 (incorporated by reference to Exhibit 3.1.1 to the Company’s Current Report on Form 8-K dated November 3, 2003).

3.4		Certificate of Amendment of the Certificate of Incorporation of the Company, dated November 21, 2000 (incorporated by reference to Exhibit 3.3 to the Company’s Annual Report on Form 10-K dated January 12, 2017).

3.5		Amended Certificate of Designation of Series B Cumulative Convertible Perpetual Preferred Stock, dated March 14, 2005 (incorporated by reference to Exhibit 3.4 to the Company’s Annual Report on Form 10-K dated January 12, 2017).

3.6		Certificate of Amendment of the Certificate of Incorporation of the Company, dated April 8, 2011 (incorporated by reference to Exhibit 3.5 to the Company’s Annual Report on Form 10-K dated January 12, 2017).

3.7		Certificate of Amendment of the Certificate of Incorporation of the Company, dated April 5, 2012 (incorporated by reference to Exhibit 3.6 to the Company’s Annual Report on Form 10-K dated January 12, 2017).

3.8		Certificate of Amendment of the Certificate of Incorporation of the Company, dated December 3, 2015 (incorporated by reference to Exhibit 3.1 to the Company's Current Report on Form 8-K dated December 3, 2015).

3.9		Amended and Restated By-Laws of the Company, dated December 15, 2016 (incorporated by reference to Exhibit 3.2 to the Company’s Current Report on Form 8-K dated December 15, 2016).

3.10		Certificate of Amendment of the Certificate of Incorporation of the Company, dated April 18, 2016 (incorporated by reference to Exhibit 3.9 to the Company’s Quarterly Report on Form 10-Q for the period ending April 30, 2016).

3.11		Certificate of Amendment of the Certificate of Incorporation of the Registrant, dated April 7, 2017 (incorporated by reference to Exhibit 3.10 to the Company’s Quarterly Report on Form 10-Q for the period ending April 30, 2017).

3.12		Certificate of Amendment of the Certificate of Incorporation of the Company, dated December 14, 2017 (incorporated by reference to Exhibit 3.1 to the Company’s Current Report on Form 8-K dated December 14, 2017).

10.1		Engagement Letter, dated and effective as of June 2, 2019, between the Company and Huron Consulting Services LLC (incorporated by reference to Exhibit 10.2 to the Company’s Quarterly Report on Form 10-Q for the quarter ended April 30, 2019).

10.2		Fourth Amendment to Loan Agreement, dated as of June 13, 2019, by and among FuelCell Energy Finance, LLC, Central CA Fuel Cell 2, LLC, and NRG Energy, Inc. (incorporated by reference to Exhibit 10.3 to the Company’s Quarterly Report on Form 10-Q for the quarter ended April 30, 2019).

10.3		Second Amendment to Membership Interest Purchase Agreement dated as of May 9, 2019 between Dominion Generation, Inc. and FuelCell Energy Finance, LLC (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on May 14, 2019).

10.4		Credit Agreement, dated as of May 9, 2019 among Dominion Bridgeport Fuel Cell, LLC, as Borrower, Liberty Bank, as Administrative Agent and Co-Lead Arranger and Fifth Third Bank, as Co-Lead Arranger, the Lenders (incorporated by reference to Exhibit 10.2 to the Company’s Current Report on Form 8-K filed on May 14, 2019).

10.5		$12,500,000 Promissory Note from Dominion Bridgeport Fuel Cell, LLC for the benefit of Liberty Bank (incorporated by reference to Exhibit 10.3 to the Company’s Current Report on Form 8-K filed on May 14, 2019).

Exhibit No.		Description
10.6		$12,500,000 Promissory Note from Dominion Bridgeport Fuel Cell, LLC for the benefit of Fifth Third Bank (incorporated by reference to Exhibit 10.4 to the Company’s Current Report on Form 8-K filed on May 14, 2019).

10.7		Security Agreement dated as of May 9, 2019 by Dominion Bridgeport Fuel Cell, LLC in favor of Liberty Bank, as Administrative Agent (incorporated by reference to Exhibit 10.5 to the Company’s Current Report on Form 8-K filed on May 14, 2019).

10.8		Pledge and Security Agreement dated as of May 9, 2019 by FuelCell Energy Finance, LLC for the benefit of Liberty Bank, as Administrative Agent (incorporated by reference to Exhibit 10.6 to the Company’s Current Report on Form 8-K filed on May 14, 2019).

10.9		Credit Agreement, dated as of May 9, 2019 among Dominion Bridgeport Fuel Cell, LLC, as Borrower, and Connecticut Green Bank, as Administrative Agent and Collateral Agent, the Lenders (incorporated by reference to Exhibit 10.7 to the Company’s Current Report on Form 8-K filed on May 14, 2019).

10.10		$6,026,165.34 Promissory Note from Dominion Bridgeport Fuel Cell, LLC for the benefit of Connecticut Green Bank (incorporated by reference to Exhibit 10.8 to the Company’s Current Report on Form 8-K filed on May 14, 2019).

10.11		Security Agreement dated as of May 9, 2019 by Dominion Bridgeport Fuel Cell, LLC in favor of the Connecticut Green Bank, as Administrative Agent. (incorporated by reference to Exhibit 10.9 to the Company’s Current Report on Form 8-K filed on May 14, 2019).

10.12		Pledge and Security Agreement dated as of May 9, 2019 by FuelCell Energy Finance, LLC for the benefit of the Connecticut Green Bank, as Administrative Agent (incorporated by reference to Exhibit 10.10 to the Company’s Current Report on Form 8-K filed on May 14, 2019).

10.13		Eighth Amendment to Loan and Security Agreement, dated May 8, 2019, by and among FuelCell Energy, Inc., Versa Power Systems, Inc., Versa Power Systems Ltd., Hercules Capital, Inc. and Hercules Funding II, LLC (incorporated by reference to Exhibit 10.11 to the Company’s Current Report on Form 8-K filed on May 14, 2019).

10.14		International Swap Dealers Association, Inc. Master Agreement dated as of May 16, 2019 between Fifth Third Financial Risk Solutions and Bridgeport Fuel Cell, LLC (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on May 22, 2019).

10.15		Schedule to the 1992 Master Agreement dated as of May 16, 2019 between Fifth Third Risk Solutions and Bridgeport Fuel Cell, LLC (incorporated by reference to Exhibit 10.2 to the Company’s Current Report on Form 8-K filed on May 22, 2019).

10.16		License Agreement, effective as of June 11, 2019, between ExxonMobil Research and Engineering Company and FuelCell Energy, Inc. (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on June 12, 2019).

10.17^{(1) (}²⁾		Ninth Amendment to Loan and Security Agreement, dated June 11, 2019, by and among FuelCell Energy, Inc., Versa Power Systems, Inc., Versa Power Systems Ltd., Hercules Capital, Inc. and Hercules Funding II, LLC (incorporated by reference to Exhibit 10.2 to the Company’s Current Report on Form 8-K filed on June 12, 2019).

10.18		First Amendment to Construction Loan Agreement dated as of June 28, 2019 by and among FuelCell Energy Finance II, LLC and Generate Lending, LLC (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on July 3, 2019).

10.19		First Amendment to Right to Finance Agreement dated as of June 28, 2019, by and among FuelCell Energy, Inc., FuelCell Energy Finance II, LLC and Generate Lending, LLC (incorporated by reference to Exhibit 10.2 to the Company’s Current Report on Form 8-K filed on July 3, 2019).

Exhibit No.		Description
10.20		Fifth Amendment to Loan Agreement, dated as of July 11, 2019, by and among FuelCell Energy Finance, LLC, Central CA Fuel Cell 2, LLC, and NRG Energy, Inc. (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on July 12, 2019).

10.21		Tenth Amendment to Loan and Security Agreement, dated July 24, 2019, by and among FuelCell Energy, Inc., Versa Power Systems, Inc., Versa Power Systems Ltd., Hercules Capital, Inc. and Hercules Funding II, LLC. (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on July 25, 2019).

10.22*		Employment Agreement, dated as of July 30, 2019, by and between FuelCell Energy, Inc. and Michael Lisowski (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on July 30, 2019).

10.23*		Employment Agreement, dated as of July 30, 2019, by and between FuelCell Energy, Inc. and Anthony Leo (incorporated by reference to Exhibit 10.2 to the Company’s Current Report on Form 8-K filed on July 30, 2019).

10.24		Sixth Amendment to Loan Agreement, dated as of August 8, 2019, by and among FuelCell Energy Finance, LLC, Central CA Fuel Cell 2, LLC, and NRG Energy, Inc. (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on August 13, 2019).

10.25		Second Amendment to Construction Loan Agreement, dated as of August 13, 2019, by and among FuelCell Energy Finance II, LLC, Bakersfield Fuel Cell 1, LLC, BRT Fuel Cell, LLC, CR Fuel Cell, LLC, Yaphank Fuel Cell Park, LLC, Homestead Fuel Cell 1, LLC, Derby Fuel Cell, LLC and Generate Lending, LLC (incorporated by reference to Exhibit 10.2 to the Company’s Current Report on Form 8-K filed on August 13, 2019).

10.26		Second Amendment to Right to Finance Agreement, dated as of August 13, 2019 by and between FuelCell Energy, Inc. and Generate Lending, LLC (incorporated by reference to Exhibit 10.3 to the Company’s Current Report on Form 8-K filed on August 13, 2019).

10.27		Amendment No. 1 to Construction Loan Agreement, dated as of August 13, 2019, by and between Groton Station Fuel Cell, LLC and Fifth Third Bank (incorporated by reference to Exhibit 10.4 to the Company’s Current Report on Form 8-K filed on August 13, 2019).

10.28		Amendment to Engagement Letter, dated August 19, 2019 and effective as of August 26, 2019, between FuelCell Energy, Inc. and Huron Consulting Services LLC (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on August 20, 2019).

10.29*		Employment Agreement, effective as of August 26, 2019, by and between FuelCell Energy, Inc. and Jason B. Few. (incorporated by reference to Exhibit 10.2 to the Company’s Current Report on Form 8-K filed on August 20, 2019).

10.30*		Summary of Cash Incentive Plan of FuelCell Energy, Inc.

10.31*⁽¹⁾		Form of Letter Agreement Issued to Employees Under Cash Incentive Plan of FuelCell Energy, Inc.

Exhibit No.		Description
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		XBRL Instance Document

101.SCH		XBRL Schema Document

101.CAL		XBRL Calculation Linkbase Document

101.LAB		XBRL Labels Linkbase Document

101.PRE		XBRL Presentation Linkbase Document

101.DEF		XBRL Definition Linkbase Document

		FUELCELL ENERGY, INC.
		(Registrant)

September 9, 2019		/s/ Michael S. Bishop
Date		Michael S. Bishop Executive Vice President, Chief Financial Officer and Treasurer (Principal Financial Officer and Principal Accounting Officer)